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Home My WebLink About219-064MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-35 KUPARUK RIV UNIT 3H-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 3H-35 50-103-20805-00-00 219-064-0 W SPT 5927 2190640 1500 730 731 731 730 499 597 596 591 4YRTST P Sully Sullivan 9/5/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3H-35 Inspection Date: Tubing OA Packer Depth 1470 2470 2430 2425IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250907152913 BBL Pumped:1.8 BBL Returned:1.9 Wednesday, October 22, 2025 Page 1 of 1           P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off3H-3550-103-20805-00-00219-06445"32.207"8/1/20253.68/8/2025 From:Brooks, Phoebe L (OGC) To:Regg, James B (OGC) Subject:FW: [EXTERNAL]FW: 10-426 form for 3H-pad SI non-witnessed MIT-IA 6-14-25 Date:Wednesday, July 23, 2025 2:59:06 PM Attachments:image001.png MIT KRU 3H-12, 35 06-14-25 Revised.xlsx Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Wednesday, July 23, 2025 2:55 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL]FW: 10-426 form for 3H-pad SI non-witnessed MIT-IA 6-14-25 Phoebe, The well that was tested was 3H-35 (PTD # 2190640) I will change my form to reflect that. I do apologize for all the errors. We try our best to make sure that our forms are correct. I’m sure we will make more mistakes but I will try to do better. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Wednesday, July 23, 2025 1:19 PM To: NSK DHD Field Supv <n2238@conocophillips.com> Subject: [EXTERNAL]FW: 10-426 form for 3H-pad SI non-witnessed MIT-IA 6-14-25 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Matt/Bruce, The well name for 3H-35 (PTD # 2190640) does not match PTD #1960150 (3H-24); can you tell which well was tested? Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Saturday, June 14, 2025 5:51 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: 10-426 form for 3H-pad SI non-witnessed MIT-IA 6-14-25 Evening, Please see the attached 10-426 form from the 3H-pad SI non-witnessed MIT-IA that was performed on 6-14-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2110810 Type Inj N Tubing 1478 1485 1481 1480 Type Test P Packer TVD 5878 BBL Pump 1.3 IA 365 2225 2160 2145 Interval 4 Test psi 1500 BBL Return 1.2 OA 0 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2190640 Type Inj N Tubing 247 260 253 251 Type Test P Packer TVD 5940 BBL Pump 4.0 IA 65 1820 1750 1730 Interval 4 Test psi 1500 BBL Return 3.0 OA 40 40 40 40 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 3H-12A 3H-35 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3H Pad Cook/Sheets 06/14/25 Form 10-426 (Revised 01/2017)2025-0614_MIT_KRU_3H-35 9 9 9 9 999 99 9 9 9 9 -5HJJ 3H-35 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 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 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 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' MEMORANDUM TO: Jim Regg , 7 P.1. Supervisor i.M� ( / FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConceoPhillips Alaska, Inc. 3H-35 KUPARUK RIV UNIT 31-1-35 Sre: Inspector Reviewed By: P.I. SupryJ� Comm Well Name KUPARUK RIV UNIT 311-35 API Well Number 50-103-20805-00-00 Inspector Name: Brian Bixby Permit Number: 219-064-0 Inspection Date: 6/12021 - Insp Num: mitBDB210602041855 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-35 Type Inj w TVD 59z7 Tubing 2305 - 2305 - 2305 - 2305 - PTD 1 2190640 Type Test SPT Test psi 1 1500 IA 1 1045 1750 - 1710 ' 1705 - BBL Pumped: 11.6 BBL Returned: 1 680 - 680 680 Interval 4YRTST P/F P Notes: Tuesday, June 8, 2021 Page I of I MEMORANDUM TO: Jim Regg -Ref ? 6t f l I7C2� P.I. Supervisor 4 FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 31i-35 KUPARUK RN UNIT 31-1-35 Src: Inspector Reviewed By:�p� P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 31-1-35 API Well Number 50-103-20805-00-00 Inspector Name: Brian Bixby Permit Number: 219-064-0 Inspection Date: 11/3/2020 I115p Num: mitBDB201103121614 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 31-1-35 Type Inj w - jTVD 5927 - Tubing 1365 1367- 1366 - 1366 - PTD 2190640 Type Test SPT Test psi 1500 - IA 820 2130 2070 _ 2060 - BBL Pumped: 3 BBL Returned: 2.9 OA 601 662 656 652 ' Interval IMTAL P/F P Notes: initial MIT -IA as per SUNDRY 320--_373 Tuesday, November 3, 2020 Page 1 of 1 ! " # " $ "% $ &' ( )*! + ($ ,- !. /- ,- 01021+. 1 3, . " ( $ /4565 3 24/00 3 & $ /45) 547/1 24/00 24/0+ 54)57#/45) 2/55#2/00 , 844 .5299 -61 5427+9:$ 24/59;$ < ;, (4 .=<>?< 547/19:$ 2/0+9;$ !; 0 @8 ( * , . ! 5 @ 2" < $ ( " &' ( $ - ( )" < % "$- % %*!A B-B% (!!3 &' -( !-( 8 & & /1+0)2)202 5 ='115)144 < //21 21#15#01612#11#11 6"!!C B5D#52 &-C -C*-!$%!& ;*!::**! 0 ! <4*7" ="< 2 $ ! 0/#1)7#1 < ! " # $ C< 3C< A< %&' ())* 579 1+2E 529 0/7)9 609 01E /9 /9 * 54)159 +)02E 54)719 2/009 ! $ ( *F $ : ; - 26+09 72E /45)9 2/009 1 1 5+07 66 616 7 ,@ 01021+14021+4G02065. #= % #: " #= 0477 011+ 57 57 /5 8! 8 & & & $ "*!A"% +*( ( (< +, !" By Samantha Carlisle at 9:48 am, Oct 20, 2020 Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2020.10.19 11:15:40 -08'00' DSR-10/20/2020 RBDMS HEW 11/13/2020 SFD 10/20/2020 VTL 11/03/20 1 Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 October 19, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding KRU 3H-35 (PTD# 216-020-0). The conversion of the well from development to WAG service is complete and the well was put on injection October 14, 2020. If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2020.10.19 11:15:13 -08'00' !"#$#$! !"# $% !"#$%#$!!&'('( !'" !")*+ ,- "' !% !"#$&#$!%%%.(/0 !" "! '!#!%#$!! '!#'$#$! 1!& 1%%% '!#'(#$!!&"23 ! 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B& DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/25/2020 Electronic File: 3H-35 EOW - NAD27.pdf32250EDDigital DataC3/25/2020 Electronic File: 3H-35 EOW - NAD27.txt32250EDDigital DataC3/25/2020 Electronic File: 3H-35 EOW - NAD83.pdf32250EDDigital DataC3/25/2020 Electronic File: 3H-35 EOW - NAD83.txt32250EDDigital Data0 0 2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS32250LogLog Header ScansC4/23/202013440 8430 Electronic Data Set, Filename: 3H-35_RBT_04MAR20_MAIN.las32801EDDigital DataC4/23/20208850 8430 Electronic Data Set, Filename: 3H-35_RBT_04MAR20_REPEAT.las32801EDDigital DataC4/23/2020 Electronic File: 3H-35_RBT_04MAR20.pdf32801EDDigital DataC4/23/2020 Electronic File: 3H-35_RBT_04MAR20_img.tiff32801EDDigital Data0 0 2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS32801LogLog Header ScansFL8/17/2020126 19383 Electronic Data Set, Filename: DD_Depth_MEM_0.25_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020222 3159 Electronic Data Set, Filename: 3H-35 13.5 Inch Section OTK Memory FE Drilling Data.las33675EDDigital DataFL8/17/202013653 19383 Electronic Data Set, Filename: 3H-35 6.75 Inch Section OTK Memory FE Drilling Data.las33675EDDigital DataFriday, August 21, 2020AOGCCPage 1 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesFL8/17/20203159 13653 Electronic Data Set, Filename: 3H-35 9.875 Inch Section OTK Memory FE Drilling Data.las33675EDDigital DataFL8/17/2020120 19383 Electronic Data Set, Filename: 3H-35 OTK MemoryFE Drilling Data.las33675EDDigital DataFL8/17/2020222 3159 Electronic Data Set, Filename: 3H-35 13.5 Inch Section OTK Realtime FE Drilling Data.las33675EDDigital DataFL8/17/202013653 19383 Electronic Data Set, Filename: 3H-35 6.75 Inch Section OTK Realtime FE Drilling Data.las33675EDDigital DataFL8/17/20203159 13652 Electronic Data Set, Filename: 3H-35 9.875 Inch Section OTK Realtime FE Drilling Data.las33675EDDigital DataFL8/17/2020162 19383 Electronic Data Set, Filename: 3H-35 Composit OTK Realtime FE Drilling Data.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run1_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run2_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run3_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run4_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run5_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020################Electronic Data Set, Filename: DD_Time_Run6_MEM_60s_ConocoPhillips_3H-35.las33675EDDigital DataFL8/17/2020 Electronic File: VSS_DEPTH_MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_MD2MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_MD5MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFriday, August 21, 2020AOGCCPage 2 of 63H-35 OTK MemoryrrFE Drilling Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesFL8/17/2020 Electronic File: FE_LTK_TVD2MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_TVD5MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_MD2MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_MD5MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_TVD2MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_TVD5MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_2MD_RLT Log 160-19383.cgm33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_2TVD_RLT Log 160-5937.cgm33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_5MD_RLT Log 160-19383.cgm33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_5TVD_RLT Log 160-5937.cgm33675EDDigital DataFL8/17/2020 Electronic File: VSS_TIME_MEM_ConocoPhillips_3H-35.cgm33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 13.5 Inch Section OTK Memory FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 6.75 Inch Section OTK Memory FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 9.875 Inch Section OTK Memory FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 OTK Memory FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 13.5 Inch Section OTK Realtime FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 6.75 Inch Section OTK Realtime FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35 9.875 Inch Section OTK Realtime FE Drilling Data.dls33675EDDigital DataFriday, August 21, 2020AOGCCPage 3 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesFL8/17/2020 Electronic File: 3H-35 Composite OTK Realtime FE Drilling Data.dls33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run1_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run2_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run3_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run4_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run5_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: DD_Time_Run6_MEM_60s_ConocoPhillips_3H-35.ASC33675EDDigital DataFL8/17/2020 Electronic File: VSS_DEPTH_MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_MD2MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_MD5MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_TVD2MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_LTK_TVD5MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_MD2MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_MD5MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: FE_OTK_TVD2MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFriday, August 21, 2020AOGCCPage 4 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NAFL8/17/2020 Electronic File: FE_OTK_TVD5MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_2MD_RLT Log 160-19383.pdf33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_2TVD_RLT Log 160-5937.pdf33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_5MD_RLT Log 160-19383.pdf33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_5TVD_RLT Log 160-5937.pdf33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_VSS_RLT_Time Log_Run 6.pdf33675EDDigital DataFL8/17/2020 Electronic File: VSS_TIME_MEM_ConocoPhillips_3H-35.PDF33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_Final Survey DDO.xls33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_Final Surveys.txt33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_Final Surveys.xlsx33675EDDigital DataFL8/17/2020 Electronic File: 3H-35_Final Surveys_2.pdf33675EDDigital Data0 0 2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS2190640 KUPARUK RIV UNIT 3H-35 LOG HEADERS33675LogLog Header ScansFriday, August 21, 2020AOGCCPage 5 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20805-00-00Well Name/No. KUPARUK RIV UNIT 3H-35Completion Status1-OILCompletion Date3/7/2020Permit to Drill2190640Operator ConocoPhillips Alaska, Inc.MD19383TVD5922Current Status1-OIL8/21/2020UICYesComments:Compliance Reviewed By:Date:COMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:3/7/2020Release Date:5/7/2019Friday, August 21, 2020AOGCCPage 6 of 6M. Guhl8/21/2020 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. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3H-35 DATE: 08/19/2020 Transmitted: North Slope, Kuparuk River Unit Via thumb drive ___ 3H-35 Baker Hughes LWD log data Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3H-35- e-transmittal well folder Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 Received by the AOGCC 08/17/2020 PTD: 2190640 E-Set: 33675 Abby Bell 08/20/2020 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR2 3 2020 AOGCC 219064 32801 23 -Apr -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 12N-309 2 2W-12 3 3H -14B 4 3H-26 5 3H-35 6 3H -14B 7 50-103-20293-00 50-029-21240-00 50-103-20092-02 50-103-20208-00 50-103-20805-00 50-103-20092-02 906207893 906212841 906340305 906340306 906363845 906349140 Tarn Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Packer SettingRecord Final -Field Packer Setting Record Final -Field Packer Setting Record Final -Field Leak Detect Log Final -Field Radial Cement Bond Log Final -Field Multi Finger Caliper Final -Field 28 -De -19 c 2 -Jan -20 0 0 1 1 1 -Mar -20 0 28 -Feb -20 0 4 -Mar -20 0 29 -Feb -20 0 1 1 1 1 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Iz I Date: L r� r Signed: V' I 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________1____________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:73.39 17. Field / Pool(s): GL:36.60 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD:19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20 H-40 119 10 3/4 L-80 2946 7 5/8 L-80 5933 4 1/2 L-80 5922 24. Open to production or injection Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press. 24-Hour Rate Sr Pet Eng Sr Pet Geo Sr Res Eng GR/Res 433 Flow Tubing Oil-Bbl:Water-Bbl: 228 1200 4310 2318 173 24 3/28/2020 10hrs 1958 847 73 176 PRODUCTION TEST 3/26/2020 GAS LIFT Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Slotted Liner@: 13634-19361 MD and 5933-5922 TVD ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information 36.8'-130' (Top Job) 34bbls 11.ppg Lead Cement TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD)PACKER SET (MD/TVD 3 1/2 13,547 13490/5927 13489 19361 5922 6 3/4 Uncemented Liner 29.7 37 13640 37 9 7/8x11 1,125sx 15.5ppg, Clas G 220sx 15.8ppg, Class G 12.6 45 1/2 37 3151 37 13 1/2 1,130sx 11.0ppg, Class G 275sx 15.8ppg, Class G 94 37 119 37 42 Installed HOLE SIZE CEMENTING RECORD AMOUNT PULLEDTOP BOTTOM TOP N/A List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data 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 CASING, LINER AND CEMENTING RECORD CASING WT. PER FT.GRAD SETTING DEPTH MD SETTING DEPTH TVD 493378 6009138 489038 6013381 N/A 1697/1662 4123' FNL, 2995' FEL, Sec 28, T13N, R8E, UM N/A 498655 6000096 19383/5922 ADL 25531, ADL 25524, ADL 365501 931882000, 931881000, 931941000, 1561' FNL, 281' FWL, Sec 12, T12N, R8E, UM 2/29/2020 KRU 3H-35 3081' FNL, 3939' FEL, Sec 34, T13N, R8E, UM Kuparuk River Field/Kuparuk Oil Pool ConocoPhillips Alaska, Inc.3/7/2020 219-064/320-067 P.O. Box 100360 Anchorage, AK 99510-0360 1/31/2020 50-103-20805-00-00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAGWINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No ss (attached) Noo REVISED Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 8:41 am, May 06, 2020 G Completion Date 3/7/2020 HEW RBDMS 4/27/2020 DLB 05/06/2020 DSR-5/6/2020 SFD 6/10/2020 VTL 8/12/20 Digitally signed by mark.j.vanderhorst@conocophillips.com DN: CN=mark.j.vanderhorst@conocophillips.co m Reason: I am the author of this document Location: your signing location here Date: 2020-05-01 12:01:12 Foxit PhantomPDF Version: 9.7.0 mark.j.vander horst@conoc ophillips.com 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ________________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:73.39 17. Field / Pool(s): GL:36.60 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20 H-40 119 10 3/4 L-80 2946 7 5/8 L-80 5933 4 1/2 L-80 5922 24. Open to production or injection Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press. 24-Hour Rate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAG ConocoPhillips Alaska, Inc.3/7/2020 219-064/320-067 P.O. Box 100360 Anchorage, AK 99510-0360 1/31/2020 50-103-20805-00-00 1561' FNL, 281' FWL, Sec 12, T12N, R8E, UM 2/29/2020 KRU 3H-35 3081' FNL, 3939' FEL, Sec 34, T13N, R8E, UM Kuparuk River Field/Kuparuk Oil Pool 1697/1662 4123' FNL, 2995' FEL, Sec 28, T13N, R8E, UM N/A 498655 6000096 19383/5922 ADL 25531, ADL 25524, ADL 365501 931882000, 931881000, 931941000, WT. PER FT.GRAD SETTING DEPTH MD SETTING DEPTH TVD 493378 6009138 489038 6013381 N/A AMOUNT PULLEDTOP BOTTOM TOP N/A List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data 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 CASING, LINER AND CEMENTING RECORD CASING 119 37 42 Installed HOLE SIZE CEMENTING RECORD 45 1/2 37 3151 37 13 1/2 1,130sx 11.0ppg, Class G 275sx 15.8ppg, Class G 94 37 Uncemented Liner 29.7 37 13640 37 9 7/8x11 1,125sx 15.5ppg, Clas G 220sx 15.8ppg, Class G 12.6 13489 19361 5922 6 3/4 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD)PACKER SET (MD/TVD 3 1/2 13,547 13490 Slotted Liner@: 13634-19361 MD and 5933-5922 TVD ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information 36.8'-130' (Top Job) 34bbls 11.ppg Lead Cement PRODUCTION TEST 3/26/2020 GAS LIFT Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: 4310 2318 173 24 3/28/2020 10hrs 1958 847 73 176 Sr Pet Eng Sr Pet Geo Sr Res Eng GR/Res 433 Flow Tubing Oil-Bbl:Water-Bbl: 228 1200 WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No ss (attached) Noo Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Jody Colombie at 1:58 pm, Apr 17, 2020 Superseded Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1697 1662 Top of Productive Interval 13301 5902 TD 19383 5922 Kuparuk C 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Mark Vanderhorst Contact Name:Marti Titus Drilling Manager Contact Email:marti.n.titus@cop.com Authorized Contact Phone:265-1192 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: 28. CORE DATA 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): FORMATION TESTS NAME Well tested? Yes No Permafrost - Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Permafrost - Base Formation @ TPI -Kuparuk C 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. Formation at total depth: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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. Authorized Name: Authorized Title: Signature w/Date: INSTRUCTIONS 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. 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. Daily Operations Summary, Definitive Survey, Cement Report, Schematic Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. 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. No No Sidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Drilling Mana 4/17/20 Top W Sak @ 2554' MD / 2468' TVD Base W Sak @ 3004' MD / 2857' TVD Top Moraine @ 11174' MD / 5374' TVD Base Moraine @ 11581' MD / 5481' TVD Base Permafrost @ 1670' MD / 1635' TVD Top Kalubik @ 12497' MD / 5722' TVD Top HRZ @ 12345' MD /5682' TVD Top K1 @ 12960' MD / 5832' TVD 3H-35 Horizontal Kuparuk A-Sand Injector Proposed Wellbore Schematic Surface Casing: 10-3/4" 45.5# L-80 Hydril 563 @ 3,157’ MD / 2,976' TVD, 41° deg Inc Conductor: 20" driven to +/-119' Production Liner: 4-1/2" 12.6# L-80 Hydril 563 w/ perf joints @ 20,156' MD / 5,874' TVD, 89° Inc Tubing: 3-1/2” 9.3# L-80 Hydril 563 9-7/8" x 11" Intermediate Hole 6-3/4" Production Hole FloPro (WBM)13-1/2" Surface Hole Intermediate Casing: 7-5/8" 29.7#, L80, Hydril 563 @ 13,557' MD / 5,883' TVD, 90° Inc Updated: 12/19/19 by M. Titus 5-3/4" x 4-1/2” Swell Packer for fault isolation GLGL GLGL GLGL LSNDSpud Mud3-½”, 2.813" XN Nipple @ ~12,600' MD / 5750' TVD, ~75° 7-5/8" x 5-1/2” Baker ZXP Packer / Flex Lock Liner Hanger @ 13,407' MD / 5880' TVD, ~88° TOC @ 10223' MD / 5124' TVD (250' TVD above top of Moraine) Top A Sand @ 13292' MD / 5874' TVD TOC @ Surface Well plan: wp04 3.5", 2.813" X Nipple @ ~2000' MD / 1946' TVD GLM #1 @ ~8200' MD / 4600' TVD, ~75° GLM #2 @ ~4800' MD / 3700' TVD, ~75° GLM #3 @ ~2600' MD / 2500' TVD Qty (3) 3-½” x 1" Camco KBMG GLMs Fault 2 @ 13254' MD / 5871' TVD Fault 1 @ 12444' MD / 5682' TVD X Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:3H-35 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed GLD & Pulled DFCV 3/10/2020 3H-35 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.8 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 94.00 Grade Top Thread Casing Description SURFACE - ALUMINUM COATED OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 36.8 Set Depth (ftKB) 3,150.8 Set Depth (TVD) … 2,946.3 Wt/Len (l… 45.50 Grade L-80 Top Thread Hyd563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 36.8 Set Depth (ftKB) 13,640.3 Set Depth (TVD) … 5,933.3 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd 563 Casing Description PRODUCTION LINER OD (in) 4.53 ID (in) 3.95 Top (ftKB) 13,489.5 Set Depth (ftKB) 19,361.0 Set Depth (TVD) … 5,922.1 Wt/Len (l… 12.60 Grade L-80 Top Thread Hyd 563 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 13,489.5 5,926.6 85.19 PACKER Packer, "HRDE-ZXP 5.5" x 7 5/8" 4.900 13,509.4 5,928.2 85.75 SEATING NIPPLE RS Packoff Seal Nipple 4.870 13,512.2 5,928.4 85.84 HANGER Liner Hanger - Flex Lock 4.790 13,522.1 5,929.1 86.14 XO Reducing XO Sub 5.5 H563 (B) x 5" H521 (B) 4.380 13,533.5 5,929.8 86.49 SBE Seal Bore Extension 4.000 15,432.9 5,913.6 89.58 SWELL PACKER Packer Swell 5.75" HYD 563 Assembly C 3.910 15,860.4 5,922.8 90.78 SWELL PACKER Packer Swell 5.75" HYD 563 AssemblyA 3.910 Tubing Strings Tubing Description TUBING PRODUCTION String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.6 Set Depth (ft… 13,547.3 Set Depth (TVD) (… 5,930.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.6 32.6 0.00 HANGER Cameron Hanger 11" x 4 1/2" C-SRL-CL Hyd 563 Top/Bttm 2.990 78.6 78.6 0.24 XO REDUCING 4 1/2" HYD 563 x 3 1/2" HYD 563 L-80 2.990 2,149.1 2,084.3 20.28 NIPPLE Landing nipple 3 1/2" X- 2.813" HYD 563 2.990 12,600.0 5,739.5 75.72 LANDING NIPPLE Landing nipple 3 1/2" XN 2.813" HYD 563 2.990 13,522.4 5,929.1 86.15 LOCATOR Seal assy. Below locator 2.990 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,605.8 2,504.4 Camco KBMG 3 1/2 GAS LIFT GLV BK 0.156 1,235.0 3/9/2020 2 4,247.4 3,680.8 Camco KBMG 3 1/2 GAS LIFT GLV BK 0.188 1,257.0 3/9/2020 3 7,622.3 4,520.1 Camco KBMG 3 1/2 GAS LIFT OV BK 0.250 0.0 3/9/2020 Notes: General & Safety End Date Annotation NOTE: HORIZONTAL, 3H-35, 4/14/2020 3:02:31 PM Vertical schematic (actual) PRODUCTION LINER; 13,489.5 -19,361.0 INTERMEDIATE; 36.8-13,640.3 LOCATOR; 13,522.4 Tubing Pup; 13,515.0 Tubing Pup; 12,601.0 LANDING NIPPLE; 12,600.0 Tubing Pup; 12,589.5 Tubing Pup; 7,629.5 GAS LIFT; 7,622.3 Tubing Pup; 7,612.5 Tubing Pup; 4,254.6 GAS LIFT; 4,247.3 Tubing Pup; 4,237.5 SURFACE - ALUMINUM COATED; 36.8-3,150.8 Tubing Pup; 2,613.1 GAS LIFT; 2,605.8 Tubing Pup; 2,596.0 Tubing Pup; 2,150.0 NIPPLE; 2,149.1 Tubing Pup; 2,138.6 CONDUCTOR; 36.8-119.0 SPACE OUT; 80.0 XO REDUCING; 78.6 HANGER; 32.6 KUP PROD KB-Grd (ft) 36.79 Rig Release Date 3/7/2020 3H-35 ... TD Act Btm (ftKB) 19,383.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032080500 Wellbore Status PROD Max Angle & MD Incl (°) 92.95 MD (ftKB) 14,042.08 WELLNAME WELLBORE3H-35 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Page 1/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/22/2020 00:00 1/22/2020 09:00 9.00 MIRU MOVE MOB P Mob Pipeshed/Shop f/2H pad to 3Hpad.(20 miles 8.5hrs). Send trucks back to 2 H pad. 0.0 0.0 1/22/2020 09:00 1/23/2020 00:00 15.00 MIRU MOVE MOB P Mob Rig Module f/ 2H pad to 3H pad: 2H - CPF2= 7hrs Wait on crew changes= 3hrs CPF2 - 2Z pad= 4hrs Let traffic by = 1hr 0.0 0.0 1/23/2020 00:00 1/23/2020 16:30 16.50 MIRU MOVE MOB P Continue Mob Rig Module f/ 2H pad to 3H pad. 2Z pad - "Y" = 1.5hrs "Y" - 1Q = 2hrs Crew changes = 2.25hrs 1Q - CPF3 = 2.75hrs Wait on traffic = 1hr CPF3 - 3M = 3.5hrs 3M - 3H = 2hrs 0.0 0.0 1/23/2020 16:30 1/23/2020 20:30 4.00 MIRU MOVE MOB P PJSM with Pad operator and rig crews, DSV and Field DSV. Position Sub on Pad. Discover bad tire on Sub. Mobilize Pit and Motor complex from 2H to 3H Pad. 0.0 0.0 1/23/2020 20:30 1/24/2020 00:00 3.50 MIRU MOVE MOB T Mobilize crane and tireman to location. Remove Beaver slide and rear wheelroom wall. Pits and Motor complex enroute to 3H. 0.0 0.0 1/24/2020 00:00 1/24/2020 14:30 14.50 MIRU MOVE MOB T Change out tire on Sub , reinstall bracing, wheel room wall , stairs and beaver slide 0.0 0.0 1/24/2020 14:30 1/24/2020 15:30 1.00 MIRU MOVE MOB P PJSM with all hands on moving over well , call pad operator , function E stop on rig ,Crab over , spot rig over well 0.0 0.0 1/24/2020 15:30 1/25/2020 00:00 8.50 MIRU MOVE MOB P Skid rig floor , spot pits, motors and pipe shed. Hook up all service lines. Pipe shed air heaters. Berm rig 0.0 0.0 1/25/2020 00:00 1/25/2020 06:00 6.00 MIRU MOVE RURD P Hook up service lines air,water, and steam , get heaters going in cellar , get heat on stack. Chink up cellar and under rig floor 0.0 0.0 1/25/2020 06:00 1/25/2020 12:00 6.00 MIRU MOVE RURD P Cont rig up service lines. Assemble mud pumps. Work on pre-spud checklist. M/U on inter connects between complex. Work under "Cold Weather Procedure" guidelines. 0.0 0.0 1/25/2020 12:00 1/25/2020 18:00 6.00 MIRU MOVE RURD P PJSM, Install 3.5" X 6" VBR's in lower pipe ram body. Remove surface annular from wellhead. Cont pre-spud checklist. 0.0 0.0 1/25/2020 18:00 1/26/2020 00:00 6.00 MIRU MOVE RURD P PJSM, M/U BOP to Test Stump. M/U choke and kill lines to stack. 0.0 0.0 1/26/2020 00:00 1/26/2020 03:30 3.50 MIRU MOVE RURD P R/U test equipment. Install and M/U test joint to test spool in BOP. Close annular, fill stack with water and purge air from system. Check for leaks. 0.0 0.0 1/26/2020 03:30 1/26/2020 07:00 3.50 MIRU MOVE BOPE T Fix leak's on choke line , grey lock under floor and flange on HCR valve , have to refill system after leaks 0.0 0.0 Rig: DOYON 19 Page 2/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2020 07:00 1/26/2020 16:00 9.00 MIRU MOVE BOPE P BOPE Commisioning Test:Test BOP'S w/ 4" test jt., 3.5 x 6 vbr upper rams & 3.5 x 6 vbr lower rams, Blind rams, Manual & HCR choke & kill valves, 4" demco kill valve, Choke valves 1 thru 14, Test @ 250 low/ 5000 psi high, F/ 10 min ea, Test Annular T/ 250/3500 psi F/10 min each.Perform Koomey draw down test. 0.0 0.0 1/26/2020 16:00 1/26/2020 18:00 2.00 MIRU MOVE BOPE T Blow down BOP and all lines back to pits. Attempt to test upper & lower TD valves = unsuccessful 0.0 0.0 1/26/2020 18:00 1/26/2020 23:00 5.00 MIRU MOVE BOPE T Repair top drive hydraulics and test systems. C/O hyd oil and filter. SIMOPS - N/D BOP from test stump 0.0 0.0 1/26/2020 23:00 1/27/2020 00:00 1.00 MIRU MOVE BOPE P Test upper and lower TD valves. Cont. N/D BOP from test stump. N/D choke and kill lines. 0.0 0.0 1/27/2020 00:00 1/27/2020 01:30 1.50 MIRU MOVE RURD P N/D BOP from test stump and set back on pedestal.Test upper and lower IBOP on Top Drive, 250 psi low/5000 psi high for 5 min low and 10 min high. 0.0 0.0 1/27/2020 01:30 1/27/2020 03:00 1.50 MIRU MOVE RURD P Install second stand pipe tee. Obtain KB measurments 0.0 0.0 1/27/2020 03:00 1/27/2020 05:30 2.50 MIRU MOVE RURD P Nipple up 20" Annular. Cont install of Tee 0.0 0.0 1/27/2020 05:30 1/27/2020 06:30 1.00 MIRU MOVE RURD P Bring up TIW and Dart valve to floor get heat on them. While crew change out. 0.0 0.0 1/27/2020 06:30 1/27/2020 08:00 1.50 MIRU MOVE RURD P Test Mud pump Pop - offs. Mud pump #1 released pressure @ 4310 psi, Mud pump #2 released @ 4235psi. 0.0 0.0 1/27/2020 08:00 1/27/2020 12:00 4.00 MIRU MOVE RURD T Test 5" Dart and FOSV floor valves, 250 psi low / 5000 psi high, 10 min, charted. Tests were visual leak tight, but would not hold a straight line on the chart due to cold weather conditions. Attempt to test Cement line = unsuccessful. 2 Halliburton plug valves failed, will replace. SIMOPs = C/O hyd fitting on Iron Roughneck. 0.0 0.0 1/27/2020 12:00 1/27/2020 22:00 10.00 MIRU MOVE RURD T Attempt to test Mud line and Stand pipe = unsuccessful due to swivel packing leak. C/O swivel packing. Attempt to test again. 2" Demco and 4" standpipe valves leaking at bleed off manifold. Rebuild both valves. SIMOPS = C/O hyd oil and clean filter on Top Drive. Replace drag chain chute. Electrician work on Commission audit. Test rig gas alarms. Install derrick cameras. Load pipe shed with 10 3/4" casing - remove thread protectors. Load Baker tools and HWDP in shed. 0.0 0.0 1/27/2020 22:00 1/28/2020 00:00 2.00 MIRU MOVE RURD P Attempt to test cement line. Unsuccessful. Isolate cement stand pipe and hose, test to 250 psi low for 5 min 5000 psi high for 10 min, good test. Change out 3 cement plug valves. Rig up to retest mud line to Top Drive. 0.0 0.0 Rig: DOYON 19 Page 3/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2020 00:00 1/28/2020 01:00 1.00 MIRU MOVE RURD P Test mud line to 250 psi f/5 min 5000 psi for 10 min. Put oil in top drive.Bring on spud mud 0.0 0.0 1/28/2020 01:00 1/28/2020 04:00 3.00 MIRU MOVE RURD P Unthaw cellar pump. Get super sucker to suck out cellar box. R/U lines on 20" Annular. Install new 2" valves on cement line on rig floor. 0.0 0.0 1/28/2020 04:00 1/28/2020 08:00 4.00 MIRU MOVE RURD P Bring up equipment to floor to rig up top drive.Install saftey cables on derrick board.Adjust kelly hose. 0.0 0.0 1/28/2020 08:00 1/28/2020 12:00 4.00 MIRU MOVE RURD T Change out cement valves in Mezz. Cont. rig up top drive. Function test Annular and knife valve. Knife valve work good , Annular leak around cap. 0.0 0.0 1/28/2020 12:00 1/28/2020 18:00 6.00 MIRU MOVE RURD T R/U rig tongs. M/U Annular cap tourque tool t/5" DP - Attempt to break cap on Annular. Unseccessful . Rebuild cellar pump and function . Bring on a load of spud mud. Install secodary saftey cables on derrick board. 0.0 0.0 1/28/2020 18:00 1/29/2020 00:00 6.00 MIRU MOVE RURD T N/D Surface Annular. Chink holes in derrick windwalls. Lay pit liner and spot cuttings tank for drag chain. Attempt to test cement lines to 250 psi f/5min and 5000 psi f/10 min 0.0 0.0 1/29/2020 00:00 1/29/2020 02:00 2.00 MIRU MOVE RURD T Burm up cuttings tank - Attemept to test CMT line to cold in cellar. Thaw out Annluar in shop 0.0 0.0 1/29/2020 02:00 1/29/2020 06:00 4.00 MIRU MOVE RURD P Bring in Annular nipple up. Chink cellar , get heat on cement line to test 0.0 0.0 1/29/2020 06:00 1/29/2020 07:00 1.00 MIRU MOVE RURD P Rig up Baker BPA on rig floor 0.0 0.0 1/29/2020 07:00 1/29/2020 09:00 2.00 MIRU MOVE RURD T Test cement line.Fix leaks Top drive froze up , get heat on it 0.0 0.0 1/29/2020 09:00 1/29/2020 11:00 2.00 MIRU MOVE RURD P P/U Double of HWDP tag up for BHA numbers @ 43'. Function test knife valve and Annular 37 sec to close. L/D single slip cut drilling line while waiting on loader tire to get fixed. Cont working on cement line. 0.0 0.0 1/29/2020 11:00 1/30/2020 00:00 13.00 MIRU MOVE RURD P Cont Slip cut drilling line , N/U Riser,hole fill, bleeder lines , R/U mud bucket and rig tongs , adjust weight buckets, welder fix cement line in cellar. Cont working on plugging holes in wind walls on rig floor. Make up 4" valves on conductor. 0.0 0.0 1/30/2020 00:00 1/30/2020 06:00 6.00 MIRU MOVE RURD P Work on fixing counter weight buckets in derrick, Test cement line. Work on rig audit checklist . Function test surface Annular with AOGCC witness 0.0 0.0 1/30/2020 06:00 1/30/2020 12:00 6.00 MIRU MOVE RURD P Rig Accepted 06:00 , cont rig up floor. UT stand pipe with tuboscope. Work on Pre-spud check list.P/U BHA to rig floor.R/U steam/water to cuttings tank. Install mousehole 0.0 0.0 1/30/2020 12:00 1/30/2020 13:00 1.00 MIRU MOVE BHAH P M/U stand back 2 stands 5" HWDP. Calibrate block height w/MWD 0.0 0.0 1/30/2020 13:00 1/30/2020 13:30 0.50 MIRU MOVE SFTY P Pre spud saftey meeting with all hands 0.0 0.0 1/30/2020 13:30 1/30/2020 14:30 1.00 MIRU MOVE BHAH P M/u 13 1/2" Baker VM-3 mill tooth bitf/clean out run 0.0 0.0 Rig: DOYON 19 Page 4/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/30/2020 14:30 1/30/2020 18:00 3.50 MIRU MOVE NUND T Fill conductor and check for leaks w/mud. Starting head leak 0.0 0.0 1/30/2020 18:00 1/30/2020 21:00 3.00 MIRU MOVE NUND T Camco service starting head. Test void t/300 psi f/15 min. Simops hang decent device in derrick , tie back bridle lines 0.0 0.0 1/30/2020 21:00 1/30/2020 23:30 2.50 MIRU MOVE NUND T C/o seal on diverter knife valve line. Preform leak test with spud mud - good test. 0.0 0.0 1/30/2020 23:30 1/31/2020 00:00 0.50 MIRU MOVE PRTS P Fill lines w/8.6 ppg spud mud test lines t/3500 psi 0.0 0.0 1/31/2020 00:00 1/31/2020 00:45 0.75 MIRU MOVE DRLG P Finish make up clean out BHA. Clean out conductor T/139' @ 40 RPM 450 GPM 450 PSI 1-5k WOB. 102.0 139.0 1/31/2020 00:45 1/31/2020 02:00 1.25 SURFAC DRILL DRLG P Drill F/139' T/222' @ 40 RPM 450 GPM 450 PSI 1-5k WOB 139.0 222.0 1/31/2020 02:00 1/31/2020 03:30 1.50 SURFAC DRILL TRIP P POOH T/39' 222.0 39.0 1/31/2020 03:30 1/31/2020 04:15 0.75 SURFAC DRILL SFTY P PJSM M/U BHA #1 for drilling 39.0 39.0 1/31/2020 04:15 1/31/2020 04:45 0.50 SURFAC DRILL SVRG P Service rig. Inspect flow paddle 39.0 39.0 1/31/2020 04:45 1/31/2020 07:30 2.75 SURFAC DRILL RGRP T Work on Mud Pump switches and SCR connections 39.0 39.0 1/31/2020 07:30 1/31/2020 09:30 2.00 SURFAC DRILL BHAH P Continue picking up 13-1/2" Surface BHA. M/U MWD/LWD/ GWD to Motor and Bit. 39.0 112.0 1/31/2020 09:30 1/31/2020 10:30 1.00 SURFAC DRILL BHAH P Pug into MWD/ Load data. Connectivity test, Align GWD Orientation W/MWD 112.0 112.0 1/31/2020 10:30 1/31/2020 12:00 1.50 SURFAC DRILL BHAH P Make up and Orient UBHO Sub, M/U 2 NM Flex drill Collars. 112.0 171.0 1/31/2020 12:00 1/31/2020 18:00 6.00 SURFAC DRILL RGRP T Adjust Standpipe Clamp at Gooseneck. Rotate MWD Transducer "T" on Standpipe T/Minimize freezing Transducer. Turn kelly hose to orientation away from piperack when traveling blocks are in motion, Eliminate it from contacting pipe in Derrick. Re-Torque kelly hose Connections 171.0 171.0 1/31/2020 18:00 1/31/2020 19:00 1.00 SURFAC DRILL DDRL P Obtain Gyro survey as per DD @ 175' w/450 gpm 640 PSI 171.0 175.0 1/31/2020 19:00 1/31/2020 20:00 1.00 SURFAC DRILL WASH P Wash and ream F175' T/222' @ 450 gpm 670 PSI 20 RPM 2K TQ. P/U T/216' obtain gyro survey as per DD 175.0 222.0 1/31/2020 20:00 2/1/2020 00:00 4.00 SURFAC DRILL DDRL P Directionally Drill 13 1/2" Surface Interval F/222' MD t/525'MD 522' TVD as per DD - 450 GPM 750 PSI 40 RPM 4-7K TQ 10% Flow out, 10k bit wt, Rot wt.90k, up wt.91k,up wt.91k. ART 2.4 AST .6 ADT 3.0. Jar Hrs- .9 222.0 525.0 2/1/2020 00:00 2/1/2020 06:00 6.00 SURFAC DRILL DDRL P Directionally Drill 13 1/2" Surface Interval F/525' MD T/890'MD 887' TVD as per DD - 450 GPM 820 PSI 40 RPM 2-4K TQ 10% Flow out, 10k bit wt, Rot wt.97k, up wt.92k,up wt.90k. ART 6 AST 1.9 ADT 4.1 Jar Hrs- 3.9 525.0 890.0 Rig: DOYON 19 Page 5/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/1/2020 06:00 2/1/2020 12:00 6.00 SURFAC DRILL DDRL P Driectional drilled 13 1/2" hole surfae hole w/ motor f/890' to 1344' MD 1316' TVD ADT - 3.9 hrs. = ART 1.2 hrs AST 2.7 hrs WOB - 25 k RPM 50 GPM 550 @ 1390 psi PU wt 100 k SO wt 110 k Rot - 100 k Torque 6 k Jar hrs. 7.8 hrs 890.0 1,334.0 2/1/2020 12:00 2/1/2020 18:00 6.00 SURFAC DRILL DDRL P Directionally drilled 13 1/2" surface hole w/ motor f/ 1134' to 2028' MD 1971' TVD ADT - 4 hrs. = AST 1.1 hrs ART 2.9 hrs WOB 22 - 25 k RPM 50 GPM 625 @ 1560 psi PU wt. 117 k SO wt. 118 k Rotwt 121 k Torque on/off btm - 6 k / 4 k Jar hrs. 11.8 1,334.0 2,028.0 2/1/2020 18:00 2/2/2020 00:00 6.00 SURFAC DRILL DDRL P Directionally drilled 13 1/2" surface hole w/ motor f/ 2028' to 2565' MD 2469' TVD ADT - 4.5 hrs. = AST 1.1 hrs ART 3.4 hrs WOB 22 - 25 k RPM 50 GPM 625 @ 1860 psi PU wt. 125 k SO wt. 124 k Rotwt 122 k Torque on/off btm - 6 k / 4 k Jar hrs. 16.3 2,028.0 2,565.0 2/2/2020 00:00 2/2/2020 06:00 6.00 SURFAC DRILL DDRL P Driectional drilled 13 1/2" surface hole w/1.8° adj. bend motor f/2565' to 3023' MD 2849' TVD ADT - 4.3 hrs. = ART 3.0 hrs AST 1.3 hrs WOB - 15-30 k RPM 50 GPM 625 @ 1905 psi PU wt 135 k SO wt 119 k Rot - 128 k Torque 7 k on Torque 5k off Jar hrs. 20.6 hrs Bit HRS 22.3 2,565.0 3,023.0 2/2/2020 06:00 2/2/2020 08:00 2.00 SURFAC DRILL DDRL P Driectional drilled 13 1/2" hole surface hole w/ motor f/3023' to 3159' MD 2953' TVD ADT - 1.3 hrs. = ART 1.0 hrs AST 0.3 hrs WOB - 15-30 k RPM 50 GPM 625 @ 2250psi PU wt 138 k SO wt 125 k Rot - 130 k Torque 7.5 k on Torque 5k off Jar hrs. 21.9 hrs Bit 23.6Hrs Obtained final survey @ TD 3,023.0 3,159.0 2/2/2020 08:00 2/2/2020 09:00 1.00 SURFAC CASING CIRC P Circ 2 X btms up @ 650 GPM @ 2250 psi w/ 50 RPM w/5 k torque PU wt 128 k SO wt 125 k Rot wt. 130 k Stood back 2 stds DP f/ 3159' to 3095' Flow ck - well static 3,159.0 3,095.0 2/2/2020 09:00 2/2/2020 14:30 5.50 SURFAC CASING BKRM P BROOH f/ 3095' to 1670' (base of permafrost) w/ 650 GPM @ 1850 psi w/ 50 rpm @ 5 k torque String wt. PU 115 k SO 110 k 3,095.0 1,670.0 Rig: DOYON 19 Page 6/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/2/2020 14:30 2/2/2020 16:00 1.50 SURFAC CASING TRIP P Observed well for flow ( well static) POOH on elevators f/ 1670' to 454' (top of BHA) String wt PU 118 k SO 110 k - monitoring well on trip tank - hole took proper fill 1,670.0 454.0 2/2/2020 16:00 2/2/2020 16:15 0.25 SURFAC CASING SFTY P Held PJSM w/ Baker DD and crew - laying down BHA 454.0 454.0 2/2/2020 16:15 2/2/2020 19:45 3.50 SURFAC CASING BHAH P Pull and lay down BHA # 1 as per Baker DD & MWD 454.0 0.0 2/2/2020 19:45 2/2/2020 20:00 0.25 SURFAC CASING OWFF P Flow check well - static 0.0 0.0 2/2/2020 20:00 2/2/2020 22:00 2.00 SURFAC CASING BHAH P Clean and clear rig floor of BHA tools and Equip. Remove clay and ice build upon floor from laying down BHA. ready hanger and landing joint for dummy run 0.0 0.0 2/2/2020 22:00 2/2/2020 23:15 1.25 SURFAC CASING PULD P M/U 10 3/4" casing hanger as per Cameron rep. Dummy run to landing ring profile. lay down landing joint and hanger to shed 0.0 0.0 2/2/2020 23:15 2/3/2020 00:00 0.75 SURFAC CASING PULD P PJSM. R/U to run 10 3/4" casing as per GBR , volant tool,350 ton spiders, 150 ton side door elev. 6' bail extention's dog collar 0.0 0.0 2/3/2020 00:00 2/3/2020 02:00 2.00 SURFAC CASING RURD P Cont R/U 10 3/4" casing equip. as per GBR. M/u Volant tool 6' bail ext.install 350 T side door elev. Install 350 T spiders 0.0 0.0 2/3/2020 02:00 2/3/2020 03:15 1.25 SURFAC CASING PUTB P MU & Run 10 3/4" Davis Lynch float shoe - 2 joints 10 3/4" 45.5# L-80 Hrdril 563 csg to 81' - Baker loc connections & torque to 16,200 ft/lbs 0.0 81.0 2/3/2020 03:15 2/3/2020 03:45 0.50 SURFAC CASING SVRG P Service rig , grease top drive and blocks 81.0 81.0 2/3/2020 03:45 2/3/2020 04:30 0.75 SURFAC CASING RGRP T Change oil in top drive and change fillter troubleshoot top drive hydrylics 81.0 81.0 2/3/2020 04:30 2/3/2020 04:45 0.25 SURFAC CASING RURD P Change out bail extensions f/6' to the 4' ones for volant CRT 81.0 81.0 2/3/2020 04:45 2/3/2020 05:15 0.50 SURFAC CASING PUTB P Continue to run 10 3/4" casing - MU 10 3/4" Davis Lynch float collar - 2 jts. 10 3/4" 45.5# L-80 Hyrdil 563 casing - Baker Loc connections & MU to 16,200 ft/lbs torque to 162' Ran( 2) 10 3/4 centralizers as follows 2 on shoe jt 10' up f/ shoe & 10' down f/ collar secured 81.0 161.0 2/3/2020 05:15 2/3/2020 05:30 0.25 SURFAC CASING PUTB P Fill pipe and circ thru shoe track - check floats OK 161.0 161.0 2/3/2020 05:30 2/3/2020 16:00 10.50 SURFAC CASING PUTB P Continue running 10 3/4" 45.5# L-80 Hydril 564 casing f/ 161' to 2987' Total of 75 jts 10 3/4" 45.4 # L-80 Hydril 563 casing Ran 3 jts. 10 3/4" 45.5# L-80 Hydril 563 dopeless R3 w/ Alum coated - MU torque 19,400 ft/lbs - Ran 1 bow spring centralizer on jts. 5 thru 75 in middle of jt.with stop ring MU Cameron 10 3/4" fluted casing hanger and landing jt. to 3114' Final PU wt 208 SO 135 161.0 3,114.0 Rig: DOYON 19 Page 7/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/3/2020 16:00 2/3/2020 20:45 4.75 SURFAC CEMENT CIRC P Break circ and stage pumps up to 6.5 bbls/min @ 130 psi - circ 1 btms up - run in w/ casing hanger & landing jt. - Land casing w/ shoe @ 3150.81' w/ hanger on landing ring - Continue circ and reciprocate casing for cement job @ 6.5 bbls/min@ 290 psi - PU wr 192 SO wt 148 3,114.0 3,150.8 2/3/2020 20:45 2/3/2020 21:00 0.25 SURFAC CEMENT SFTY P Held pre job safety meeting w/ crew and Halliburton on 10 3/4 " cement job 3,150.8 3,150.8 2/3/2020 21:00 2/3/2020 22:15 1.25 SURFAC CEMENT RURD P RU for cement job - blow down TD - RU cement lines - Break circ thru ctm lines w/ rig pump @ 2 bbls/min @ 120 psi (OK) - Circ @ 6 bbls/min @ 290 psi - Shut down pump 3,150.8 3,150.8 2/3/2020 22:15 2/3/2020 22:30 0.25 SURFAC CEMENT RURD P Blow down line to mud pump - Line up to Halliburton - Pumped 10 bbls warm water -Pressure test line to 1000 pis & 3500 psi - leak on hi pressure test in hammer union - repair leak and retest to 1000 & 3500 psi Good test 3,150.8 3,150.8 2/3/2020 22:30 2/4/2020 00:00 1.50 SURFAC CEMENT CMNT P Cement 10 3/4" casing - Pumped 60 bbls of mud push spacer @ 10 ppg treated w/ red dye & 5 # Pol-E -Flake - Dropped bottom plug - began pumping Lead slurry @ 11 ppg. Initial circulating rate 3 bpm- worked up to 5 bpm. 3,150.8 3,150.8 2/4/2020 00:00 2/4/2020 04:45 4.75 SURFAC CEMENT CMNT P Continue cementing 10-3/4" casing. Per cement detail. Reciprocate casing. while cementing up wt. 194k. down wt. 147k. Pumped a total of 500 bls. lead cement and lost returns. Completed pumping 11.0 ppg lead cement total volume lead - 525 bls. Pumped 57 bls. 15.8 tail cement. Drop top plug displace with rig pumping 9.6 ppg. spud mud total mud pumped 283 bls. Initial rate 6 bpm slowed to 3 bpm held until plug bumped at 2,828 strokes. FCP 550 psi build to 1,100 psi. Hold for 5 min. Floats holding. CIP at 04:45 2/4/2020 3,150.8 3,150.8 2/4/2020 04:45 2/4/2020 07:30 2.75 SURFAC CEMENT RURD P Disconnect diverter knife valve Flush water black water 20" riser and Hydril - LD landing jt - blow down cement line - RD 4' bale extensions, side door elevator, 350 T spider - RD Volant CRT - Blow down mud line to pump - clean out valves on cement line Simops - cleaning mud pits 3,150.8 3,150.8 2/4/2020 07:30 2/4/2020 13:30 6.00 SURFAC CEMENT RURD P ND 20" riser & flow line - bleeder & hole fill lines - RD knife valve & adapter flange - ND diverter lines - LD mouse hole & riser - disconnert koomey lines f/ Hydril - ND 20" Hydril - Remove 20" starting head Simops continue to clean mud pits 3,150.8 3,150.0 2/4/2020 13:30 2/4/2020 13:45 0.25 SURFAC CEMENT SFTY P Held PJSM w/ crew and Halliburtion on top job 3,150.0 3,150.8 Rig: DOYON 19 Page 8/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/4/2020 13:45 2/4/2020 18:15 4.50 SURFAC CEMENT CMNT P Blow down 2" hard line f/ rig to cement unit - MU 1" mule shoe & 1 pipe w/XO's - RIH through flutes on casing hanger in the 20" x 10 3/4" annulus to 120' - Break ciec and pumped 22.5 bbls (annular volume) @1 bbl/min @ 215 psi observed returns to surface ( water and some contamated mud Ph-11 - RIH w/1" pipe f/ f/ 120' to 130' tagged up on cement Picke up to 120' ( * all depths are from ground level) RU cement line - break circ w/ water - Mixed and pumped 79 sxs ( 34 bbls) 11.0 ppg Lead cmt blend @ 1 bbl/min @ 430 psi - observed cement to surface @ 20 bbls pumped & 11.0 ppg cmt @ 25 bbls pumped - shut down - CIP@ 17:50 hrs - Observed annulus for cement fall back level remined @ top of flutes on hanger Top Job wittnessed by Adam Earl AOGCC 3,150.8 3,150.8 2/4/2020 18:15 2/4/2020 19:15 1.00 SURFAC CEMENT RURD P Flush cmt line w/ water - Blown down cement line to Halliburton- RD cement line - Pulled and laid down 1" stringer pipe - Fluid level still @ top of flutes - Open 4: valves on conductor & drain cement - Wash seal area on top of hanger Remove 4" valves and install 4" caps 3,150.8 3,150.8 2/4/2020 19:15 2/4/2020 21:00 1.75 SURFAC WHDBOP CLEN P Remove surface equipment from cellar - 20" Hydril - diverter spool - staring head - BOP test stump - 3,150.8 3,150.8 2/4/2020 21:00 2/4/2020 22:45 1.75 SURFAC WHDBOP NUND P Move Cameron casing head into cellar - Install wellhead - Orient wellhaed (* pad operator verified) Tested wellhead seals to 5000 psi for 10 mins( CPAI rep witnessed) 3,150.8 3,150.8 2/4/2020 22:45 2/5/2020 00:00 1.25 SURFAC WHDBOP NUND P Stage BOP nipple up equipment in cellar - DSA MPD flow box - PU Cameron test plug - long & short wear bushings - running tools - stage Baker BHA componets to rig floor 3,150.8 3,150.8 2/5/2020 00:00 2/5/2020 01:45 1.75 SURFAC WHDBOP CLEN P Continue to stage bha components to the rig floor. Load bha into pipeshed as per Baker. Preparing pits for intermediate program, take on 9.6 ppg LSND to pits. Prepare equipment for BOPE testing, grease choke manifold, install annulus 1502 flange to Wellhead & load 7 5/8" casing into pipeshed. 3,150.8 3,150.8 2/5/2020 01:45 2/5/2020 02:15 0.50 SURFAC WHDBOP SVRG P Rig service. 3,150.8 3,150.8 2/5/2020 02:15 2/5/2020 06:00 3.75 SURFAC WHDBOP NUND P Install BOPE adapter spool to wellhead. N/U BOPs to wellhead. Prep MPD equipment for rig up to BOPs. 3,150.8 3,150.8 2/5/2020 06:00 2/5/2020 08:30 2.50 SURFAC WHDBOP NUND P N/U MPD equipment, RCD starting head, orbit valve, 6" return line. 3,150.8 3,150.8 Rig: DOYON 19 Page 9/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2020 08:30 2/5/2020 12:00 3.50 SURFAC WHDBOP NUND T M/U kill line to BOP stack. P/u BOPs and stand back for spacer spool. (need extra height to accomodate choke line) Simops: Change out sprocket & bearings on drag chain. Load one row of 7 5/8" casing to pipe shed. 3,150.8 3,150.8 2/5/2020 12:00 2/5/2020 17:00 5.00 SURFAC WHDBOP NUND P Spacer spool on location at 12:00. NU 24" Spacer spool, flow box, hole full, bleeder lines. New RKB measurements taken. 3,150.8 2/5/2020 17:00 2/5/2020 18:30 1.50 SURFAC WHDBOP BOPE P PU 5" test joint, install test joint per Cameron wellhead rep. Fill stack with fresh water. Line up, check manifold for BOP test. 2/5/2020 18:30 2/5/2020 20:00 1.50 SURFAC WHDBOP BOPE P RU BOP testing equipment, Flood check manifold w fresh water. Verify air out of system. Install drain lines in cellar. Work annular preventor on 5" test joint.. Mu 4.5IF Dart/FOSV on floor. Install test sub to top drive. 2/5/2020 20:00 2/5/2020 21:00 1.00 SURFAC WHDBOP BOPE P Shell test BOP, check manifold to 3500 psi, some minor leaking at flange to kill line, tightened and fixed. Pressure up BOP, verify air out of system. All preparations good. Begin BOPE test. 2/5/2020 21:00 2/6/2020 00:00 3.00 SURFAC WHDBOP BOPE P Test BOPE w 5" test joint. All tests 250 psi low / 3500 psi high for 5 minutes each. Tested as follows: 4" Demco valve, choke manifold, vales #1, 12, 13, 14. Upper VBRs 3.5" x 6". Auto IBOP. HCR kill line. Choke manifold. Valves #9, 11. Manifold. IBOP. Needle valve above #1 chk valve. Valves #5,8,10. 5" dart valve. Choke manifold valves # 4, 6, 7. 5" FOSV, choke manifold valve 2. HCR choke valve. PVT and gas alarms tested successfully. test witnessed by AOGCC rep Adam Earl.All test passed and approved. 2/6/2020 00:00 2/6/2020 02:15 2.25 SURFAC WHDBOP BOPE P Continue testing BOPE to 250/3500 5 min/5 min each. Test as follows: HCR choke, Manual chokes & Kill, LWR 3.5" x 6" VBRs, Valves-3,4,6, blind rams. Perform Poorboy degasser flush & drawdown test on Man & Hyd choke valves to 1100 psi. - Accumulator test- System psi-3150 psi closed, -1400 psi, 200 psi attained in 25 sec. full pressure in 165 sec. 4 N2 bottles at 1975 psi, PVT & gas alarms tested. Test witnessed by AOGCC Rep Adam Earl. 3,150.8 3,150.8 2/6/2020 02:15 2/6/2020 02:45 0.50 SURFAC WHDBOP RURD P RD test equipment - Blow down choke manifold - line up choke manifold for drilling 3,150.8 3,150.8 2/6/2020 02:45 2/6/2020 03:15 0.50 SURFAC WHDBOP MPDA P Pull MPD flowbox - Install MPD test cap - RU test equipment to RCD 3,150.8 3,150.8 2/6/2020 03:15 2/6/2020 04:00 0.75 SURFAC WHDBOP MPDA P Pressure test MPD RCD head to 1200 psi for 10 mins as per MPD rep. - RD MPD test Equipment 3,150.8 3,150.8 Rig: DOYON 19 Page 10/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/6/2020 04:00 2/6/2020 05:15 1.25 SURFAC WHDBOP RURD P Pull test plug - Install wear bushing (10 " id ) - LD running tool & 5" test jt - Blow down kill line - Clean & clear rig floor of excess tools & equipment Simops - load 75 jts. 5" DP in pipe shed 3,150.8 3,150.8 2/6/2020 05:15 2/6/2020 05:45 0.50 SURFAC DRILLOUT SVRG P Service rig 3,150.8 3,150.8 2/6/2020 05:45 2/6/2020 10:00 4.25 SURFAC DRILLOUT RGRP T Trouble shoot top drive link tilt issue - Change filter & hydralic fluid 3,150.8 3,150.8 2/6/2020 10:00 2/6/2020 10:15 0.25 SURFAC DRILLOUT SFTY P PJSM with crew and Baker DD & MWD on making up BHA # 2 3,150.8 3,150.8 2/6/2020 10:15 2/6/2020 15:00 4.75 SURFAC DRILLOUT BHAH P MU BHA # 2 - bit (9 7/8" HCC DD505TX ) ATK stearable sub - Flex sub w/ stab- OnTrak MWD - MWD stab mod - BCPM - NM Sub (Stop) NM Sub ( filter) NM sub ( float) - 2 jts compressive DP - string stab - Sub restrictor - Expandable reamer - 2 DC's - String stab - NM sub (float0 NM sub (float) 6 jts 5" HWDP - jars - 5 jts 5" HWDP - total length 585.24' 3,150.8 3,150.8 2/6/2020 15:00 2/6/2020 16:30 1.50 SURFAC DRILLOUT TRIP P RIH w/ BHA # 2 f/ 585' to 1527' - Shallow pulse test MWD & under reamer @ 600 gpm @ 1750 psi PU wt 105 k S)O wt 102 k under reamer opened @ 600 gpm @ 1320 psi 3,150.8 3,150.8 2/6/2020 16:30 2/6/2020 18:45 2.25 SURFAC DRILLOUT TRIP P Continue RIH f/ 1527' picking up 5" Dp f/ shed to 2941' - PU wt 140 k SO wt 125k 3,150.8 3,150.8 2/6/2020 18:45 2/6/2020 19:45 1.00 SURFAC DRILLOUT CIRC P Circ btms up @ 2941' circ btms up @ 1980 PSI - mud wt., 9.6 ppg in & out - ECD - 10.05 ppg 3,150.8 3,150.8 2/6/2020 19:45 2/6/2020 20:15 0.50 SURFAC DRILLOUT RURD P Blow down TD - RU to test 10 3/4" csg 3,150.8 3,150.8 2/6/2020 20:15 2/6/2020 21:15 1.00 SURFAC DRILLOUT PRTS P Tested 10 3/4" casing to 3500 spi f/ 30 mins. - Pumped 4,6 bbls to pressure up - Good test - Bleed off pressure & RD test equipment 3,150.8 3,150.8 2/6/2020 21:15 2/6/2020 22:15 1.00 SURFAC DRILLOUT WASH P Wash down f/ 2941' to 3063' @ 200 gpm @ 300 psi w/20 rpm - 6.5 k torque - Rot wt. 135 k Tagged up on wiper plugs - Increase pump rate, stage up to 300 gpm @ 740 psi - 600 gpm @ 1950 psi w/ 10 rpm w/ 7 k torque - PU wt. 142 k SO wt 123 k Rot wt. 132 k ( confirmed reamer closed) 3,150.8 3,150.8 2/6/2020 22:15 2/7/2020 00:00 1.75 SURFAC DRILLOUT DRLG P Clean out shoe track f/ 3063' to 3070' w/ 600 gpm @ 2010 psi - 60 rpm w/ 7 - 10 k torque - Rot wt 135 k - tagged float collar @ 3067' 3,150.8 3,150.8 2/7/2020 00:00 2/7/2020 01:45 1.75 SURFAC DRILLOUT DRLG P Cont.drilling shoe track cement f/ 3070' to 3150' top of shoe - drill out shoe to 3151' - clean out rat hole to 3159' GPM 600 @ 1930 psi RPM 60 - torque 6.4 k ft/lbs WOB 7 to 15 k PU wt 142 k SO wt 123 k ROt wt 135 k 3,159.0 3,159.0 Rig: DOYON 19 Page 11/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/7/2020 01:45 2/7/2020 02:00 0.25 SURFAC DRILLOUT DRLG P Drilled 20' new hole f/ 3159' to 3179' MD 2967' TVD GPM 600 @ 1930 psi RPM 80 w/ 7 k torque Rot wt. 137 k 3,159.0 3,179.0 2/7/2020 02:00 2/7/2020 02:45 0.75 SURFAC DRILLOUT CIRC P Back ream f/ 3179' to 3135' while circ 1 x btms up @ 600 gpm @ 1940 psi w/ 60 rpm 7 k torque Stand 1 std of DP to 3135' Blow down TD 3,179.0 3,179.0 2/7/2020 02:45 2/7/2020 03:00 0.25 SURFAC DRILLOUT RURD P OWFF - rig up for Leak off test. 3,179.0 3,179.0 2/7/2020 03:00 2/7/2020 03:45 0.75 SURFAC DRILLOUT FIT P Performed LOT to 14.7 ppg EMW - Pumped @ 1/2 bbl/min to 830 psi - shut in and monitored for 10 mins. Observed break over @ 790 psi - bleed off pressure - RD test equipment 0 Blow down lines 3,179.0 3,179.0 2/7/2020 03:45 2/7/2020 04:15 0.50 INTRM1 DRILL WASH P Wash & ream f/ 3135' to 3179' MD 2967' TVD 600 gpm @ 1990 psi w/ 65 RPM w/ 8.5 k torque ROT wt 138 k Prep to change over to 9.6 ppg LSND mud 3,179.0 3,179.0 2/7/2020 04:15 2/7/2020 06:00 1.75 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/ 3179' to 3225' MD 3000' TVD ADT 1,1 hr. WOB 5 k - GPM 530 @ 1220 psi 80 RPM w/ 7 k torque Jar hrs. 23 Simops - changed over to 9.6 ppg LSND mud while drilling ahead 3,179.0 3,225.0 2/7/2020 06:00 2/7/2020 07:00 1.00 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/ 3225' TO 3300' GPM 530 @ 1220 psi - 80 RPM - WOB 5 k 3,225.0 3,300.0 2/7/2020 07:00 2/7/2020 07:30 0.50 INTRM1 DRILL DHEQ P Opened Under Reamer @ 3300' - I CP 650 gpm @ 1750 psi - 50 rpm torque 5.5 k - FCP 650 gpm @ 1320 psi w/ 50 rpm w/ 6 k toruqe - PU to 3280' to put blades @ casing shoe to confirm opened - 450 psi diff pressure - confirmed tool opened 3,300.0 3,280.0 2/7/2020 07:30 2/7/2020 12:00 4.50 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole f/ 3300' to 3640' MD 3296' TVD ADT 4.3 hrs WOB 8 to 10 k - RPM 120 w/ 7.5 ktorque Jar hrs. 27.3 hrs Take T& D readings every 3 stds. Pumped sweeps every 3 stds 3,280.0 3,640.0 Rig: DOYON 19 Page 12/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/7/2020 12:00 2/7/2020 18:00 6.00 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole f/ 3640 to 3975' MD 3512' TVD ADT 5.5 hrs ECD - 10.19 WOB 8 /20 k - RPM 60 /120 - GPM 600 @ 1250 psi Torque on btm 6/7 k ft. lbs Off btm - 6 k ft/lbs PU wt 156 k SO wt 132 k Rot 140 k jar hrs. 32.8 Pumped sweeps every 3 stds Autotrack unable to build inclination as per well plan, troubleshooting same. SPR # 1- 25 spm 150 psi 35 spm 210 psi SPR # 2 - 25 spm 160 psi 35 spm 210 psi 3,640.0 3,975.0 2/7/2020 18:00 2/7/2020 23:45 5.75 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole f/ 3975' to 4080' MD 3579' TVD ADT 3.6 hrs ECD 10.34 ppg Closed Under Reamer @ 4080' drill ahead checking Atuotrak rib functions Drilled 9 7/8" hole f/ 4080 ' to 4171' MD 3637' TVD. Autotrak unable to build inclination as per plan. Currently 20.9 degrees behind plan. Decision made to pooh for motor correction run. WOB 10/20 k RPM 100 GPM 600 @ 1260 psi Torque on btm - 7 k PU wt 156 k SO 132 k ROT 140 k Jar hrs 36.4 hrs Pump sweeps & took T&D data every 3 stds 3,975.0 4,171.0 2/7/2020 23:45 2/8/2020 00:00 0.25 INTRM1 DRILL DDRL P BROOH f/ 4171' to 4073' @ 600 pm @ 1680 psi 60 rpm 7 k torque PU wt 132 k ROT wt 127 k 4,171.0 4,171.0 2/8/2020 00:00 2/8/2020 00:45 0.75 INTRM1 DRILL REAM T Ream f/ 4073' to 4171' w/ 11" under reamer - 600 gpm @ 1270 psi 70 RPM w/ 7.5 k torque ROT wt. 148 k - Down link to retract Autotrk ribs as per Baker DD - closed 11" under reamer as per SLB reamer rep 4,171.0 4,171.0 2/8/2020 00:45 2/8/2020 01:15 0.50 INTRM1 DRILL CIRC T Circ 2X btms up @ 4171' @ 600 gpm @ 1705 psi w/ 60 rpm w/ 6.7 k torque - Rot wt 132 k 4,171.0 4,171.0 2/8/2020 01:15 2/8/2020 01:30 0.25 INTRM1 DRILL OWFF T Flow check- well static 4,171.0 4,171.0 2/8/2020 01:30 2/8/2020 03:15 1.75 INTRM1 DRILL BKRM T BROOH f/ 4171' to 3131' - 600 gpm @ 1600 psi w/ 60 rpm w/ 6 k torque Rot wt 136 k 4,171.0 4,171.0 2/8/2020 03:15 2/8/2020 03:45 0.50 INTRM1 DRILL CIRC T Circ btms up @ 600 gpm @ 1570 psi w/ 60 rpm Observed excess amount of cuttings @ btms up - circ until clean 4,171.0 4,171.0 2/8/2020 03:45 2/8/2020 04:00 0.25 INTRM1 DRILL OWFF T Blow down TD - Flow ck - Well static 4,171.0 4,171.0 2/8/2020 04:00 2/8/2020 06:45 2.75 INTRM1 DRILL TRIP T POOH on elevators f/ 3131' to 585' (top of BHA PU wt 155 k SO wt 123 k Actual fill 49.5 bbls Calc. 49.6 bbls 4,171.0 4,171.0 2/8/2020 06:45 2/8/2020 07:15 0.50 INTRM1 DRILL OWFF T Flow check - Well static 4,171.0 4,171.0 Rig: DOYON 19 Page 13/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/8/2020 07:15 2/8/2020 07:45 0.50 INTRM1 DRILL BKRM T BROOH f/ 585' to 492' @ 400 gpm @ 650 psi w/ 80 rpm 2 k torque Well was trying to swab 4,171.0 4,171.0 2/8/2020 07:45 2/8/2020 08:00 0.25 INTRM1 DRILL OWFF T Blow down TD - Flow check - well static 4,171.0 4,171.0 2/8/2020 08:00 2/8/2020 09:00 1.00 INTRM1 DRILL TRIP T POOH on elevators f/ 492' 4,171.0 4,171.0 2/8/2020 09:00 2/8/2020 12:00 3.00 INTRM1 DRILL BHAH T PJSM - LD rotary steerable BHA as per Baker rep. 4,171.0 4,171.0 2/8/2020 12:00 2/8/2020 14:00 2.00 INTRM1 DRILL BHAH T MU Motor BHA as per Baker rep. 4,171.0 4,171.0 2/8/2020 14:00 2/8/2020 17:00 3.00 INTRM1 DRILL TRIP T RIH w/ motor BHA to 2405' - fill pipe - Blow down TD 4,171.0 4,171.0 2/8/2020 17:00 2/8/2020 17:30 0.50 INTRM1 DRILL SVRG T Rig Servce; check alll fluid levels and grease blocks. 4,171.0 4,171.0 2/8/2020 17:30 2/8/2020 18:45 1.25 INTRM1 DRILL RGRP T Rig repair; work on top drive service loop. Orient, wrap loop and secure. 4,171.0 4,171.0 2/8/2020 18:45 2/8/2020 19:45 1.00 INTRM1 DRILL TRIP T Trip in from 2405' to 3064' with proper pipe displacement. 4,171.0 4,171.0 2/8/2020 19:45 2/8/2020 20:15 0.50 INTRM1 DRILL SLPC T RU to Slip n Cut, hang blocks and remove hookload load cell. 4,171.0 4,171.0 2/8/2020 20:15 2/8/2020 21:15 1.00 INTRM1 DRILL SLPC T Slip and Cut 38' of drill line. Check & reset C-O-M, function test same. 4,171.0 4,171.0 2/8/2020 21:15 2/8/2020 22:30 1.25 INTRM1 DRILL TRIP T Trip in from 3064' to 4096' with proper displacement. 4,171.0 4,171.0 2/8/2020 22:30 2/8/2020 23:15 0.75 INTRM1 DRILL CIRC T Break circulation and obtain survey to orient and begin sliding. Wash last stand to bottom with 600 GPM, 1650 psi, 40 RPM with 7K torque. 4,171.0 4,171.0 2/8/2020 23:15 2/9/2020 00:00 0.75 INTRM1 DRILL DDRL T Slide drill from 4171' to 4197' (26' @ 35 FPH). 600 GPM with 1620 psi, 4,171.0 4,197.0 2/9/2020 00:00 2/9/2020 06:00 6.00 INTRM1 DRILL DDRL T Directionally drilled 9 7/8" hole w/ motor f/ 4197' to 4512' MD - 3799' TVD ADT 4.7 hrs = ART - 1.4 hrs AST 2.8 hrs. ECD- 10.53 ppg GPM 600 @ 1870 psi - RPM 60 - WOB 10/20 k PU wt. 155 k SO wt. 127 k ROT wt. 141 k Torque on/off btm 7.5 k/ 7 k Obtain T&D data every 3 stds Obtain SPR @ 4381' MD 3744' TVD w/ 9.7 ppg mud wt #1 SPM 25/35 PSI 190/230 psi #2 SPM 25/35 PSI 190/230 psi Jar hrs - 41.6 hrs 4,197.0 4,512.0 2/9/2020 06:00 2/9/2020 09:00 3.00 INTRM1 DRILL DDRL T Directionally drilled 9 7/8" hole w/ motor f/ 4512' to 4760' MD 3855' TVD ADT - 2.1 hrs = ART 1.4 hrs AST .7 hrs - ECD 10.81 ppg GPM 600 @ 1810 psi RPM 60 WOB 15/20 k PU wt. 153 SO wt. 125 ROT 136 Torque on/off btm 7.8/6.5 k Pumped weighted sweeps every 3 stds 4,512.0 4,760.0 Rig: DOYON 19 Page 14/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/9/2020 09:00 2/9/2020 09:30 0.50 INTRM1 DRILL CIRC T Obtain SPR's Obtained SPR's @ 4760' MD 3855 TVD # 1 SPM 25/35 180/220 psi # 2 SPM 25/35 170/220 psi Blow down TD 4,760.0 4,760.0 2/9/2020 09:30 2/9/2020 10:00 0.50 INTRM1 DRILL OWFF T Flow check -Well static 4,760.0 4,760.0 2/9/2020 10:00 2/9/2020 12:45 2.75 INTRM1 DRILL BKRM T BROOH w/ 4760' to 3160' MD @ 600 gpm @ 1640 psi - RPM 60 - Rot wt 136 k w/ 6 k torque 4,760.0 4,760.0 2/9/2020 12:45 2/9/2020 13:45 1.00 INTRM1 DRILL CIRC T Circ 2X btms up @ 600 gpm @ 1640 psi w. 60 rpm @ 5.8 k torque Blow down TD 4,760.0 4,760.0 2/9/2020 13:45 2/9/2020 14:00 0.25 INTRM1 DRILL OWFF T Flow check - well static 4,760.0 4,760.0 2/9/2020 14:00 2/9/2020 14:30 0.50 INTRM1 DRILL CIRC T Attempt to pooh on elevators in the 10.75" casing. Had 15k overpull and swab effect on first std. Tih to 3160' and pumped 35 bbl Nut plug hi-vis sweep @ 600 gpm @ 1540 psi w/ 60 rpm @ 5.5 k torque. Circulated sweep out and noted 40% increase in cuttings. 4,760.0 4,760.0 2/9/2020 14:30 2/9/2020 15:15 0.75 INTRM1 DRILL OWFF T Blow down TD - Flow check - well static 4,760.0 4,760.0 2/9/2020 15:15 2/9/2020 19:30 4.25 INTRM1 DRILL TRIP T POOH on elevators from 3160' to surface. PU = 150K, SO = 78K. 4,760.0 4,760.0 2/9/2020 19:30 2/9/2020 21:15 1.75 INTRM1 DRILL BHAH T PJSM for BHA with crew, Coman, toolpusher and third parties. LD motor BHA, checked alll floats and flushed BHA with water. 4,760.0 4,760.0 2/9/2020 21:15 2/9/2020 21:45 0.50 INTRM1 DRILL CLEN T Clean and clear floor of BHA components. Stage and bring components to rig floor for RSS BHA. 4,760.0 4,760.0 2/9/2020 21:45 2/10/2020 00:00 2.25 INTRM1 DRILL BHAH T PU and MU 9 7/8" x 11" BHA with SLB Rhino Reamer. MU and rerun bit #2. 4,760.0 4,760.0 2/10/2020 00:00 2/10/2020 00:45 0.75 INTRM1 DRILL BHAH T Trip in from 114' to 306', with 9 7/8" x 11" BHA with Rhino reamer.- PU wt 78 k SO wt. 78 k - Plug in & upload MWD 4,760.0 4,760.0 2/10/2020 00:45 2/10/2020 01:45 1.00 INTRM1 DRILL BHAH T Shallow pulse test; good. Open and close reamer; good function test. 4,760.0 4,760.0 2/10/2020 01:45 2/10/2020 04:30 2.75 INTRM1 DRILL TRIP T Trip in from 306' to 3,130' - fillling pipe every 20 stds. - PU wt 148 k SO wt 122 k 4,760.0 4,760.0 2/10/2020 04:30 2/10/2020 05:00 0.50 INTRM1 DRILL CIRC T Cicr btms up @ 3130' - 600 gpm @ 1850 psi - Pulse test MWD (good) 4,760.0 4,760.0 2/10/2020 05:00 2/10/2020 06:30 1.50 INTRM1 DRILL TRIP T Continue TIH f/ 3130' to 4760' - filling pipe every 20 stds. - PU wt 148 k SO wt 122 k Pulse test MWD ( confirmed good ) Actual displacment 30 bbls Calculated 46 bbls 4,760.0 4,760.0 2/10/2020 06:30 2/10/2020 07:00 0.50 INTRM1 DRILL BKRM T Break Circ @ 650 gpm @ 2290 psi w/ 40 rpm 8 k torque - open reamer as per SLM reamer rep. 4,760.0 4,760.0 Rig: DOYON 19 Page 15/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2020 07:00 2/10/2020 14:45 7.75 INTRM1 DRILL BKRM T BROOH f/ 4760' to 4171' - opening 9 7/8" hole to 11" f/ 4629' to 4040' (* ream is 131' behind bit section or hole drilled w/ motor run) GPM 725 @ 2100 psi w/ 80 rpm 8.5 k torque 4,760.0 4,760.0 2/10/2020 14:45 2/10/2020 15:45 1.00 INTRM1 DRILL TRIP T Wash down f/ 4171' to 4359' 2 725 gpm @ 2050 psi - RIH w/ no pump f/ 4359' to 4760' _ SO wt 135 k 4,760.0 4,760.0 2/10/2020 15:45 2/10/2020 20:30 4.75 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with motor from 4,760' to 4,853' MD 3886' TVD ADT - 5.3 hrs = ART 5.3 hrs - ECD 10.25 ppg GPM 600 with 1810 psi, RPM 60- 140K WOB 15/30K PU = 153K SO = 125K ROT = 136K Torque on/off btm 7-6.5K 4,760.0 4,853.0 2/10/2020 20:30 2/10/2020 23:30 3.00 INTRM1 DRILL BKRM T Back-ream 4 stands and run back to bottom to improve hole conditions. 4,853.0 4,853.0 2/10/2020 23:30 2/11/2020 00:00 0.50 INTRM1 DRILL DRLG T Attempt to drill with varied parameters without success. Varied flow rates, varied RPM and WOB without improved results. Closed Rhino reamer without change and downlinked to RSS to retract pads to neutral with no resultant change in progress. Decision made with office team to pull out of the hole to inspect BHA and Rhino reamer. 4,853.0 4,853.0 2/11/2020 00:00 2/11/2020 02:00 2.00 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole F/ 4853' to 4857' MD, 3886' TVD, 375 GPM = 2360 PSI. 80 RPM = 7K TQ on bottom. WOB = 10 - 28K. ECD = 10.25. PUWT = 160K, SOWT = 132K, ROTW = 145K @ 20RPM, TQ = 7K off bottom. Closed RhinoReamer @ 4654' MD SPR's @ 4852' MD, 3886" TVD, w/ 9.6 ppg LSND SPR # 1- 25 spm =150 psi 35 spm 220 psi SPR # 2 - 25 spm 150 psi 35 spm 220 psi ADT = 1.3 hrs, Jars = 49.2 hrs, Bit = 5.3 hrs 4,853.0 4,857.0 2/11/2020 02:00 2/11/2020 02:30 0.50 INTRM1 DRILL DHEQ P Close Auto-Track Ribs, Obtain survey @ 4857' MD 675gpm = 2330psi Due to slow ROP, decision made with office team to pooh w/ bit to inspect & evaluate bha. PJSN F/ POOH, B/D Top Drive 4,857.0 4,857.0 2/11/2020 02:30 2/11/2020 02:45 0.25 INTRM1 DRILL OWFF T Flow Check = Well is static 4,857.0 4,857.0 2/11/2020 02:45 2/11/2020 04:30 1.75 INTRM1 DRILL TRIP T POOH F/ 4857' TO 3125' MD on Elevators. PUWT = 163K 4,857.0 4,857.0 2/11/2020 04:30 2/11/2020 04:45 0.25 INTRM1 DRILL OWFF T Flow Check = Well is static 4,857.0 4,857.0 2/11/2020 04:45 2/11/2020 06:15 1.50 INTRM1 DRILL TRIP T Cont. POOH F/ 3125' to BHA on Elevators. PUWT = 90K 4,857.0 4,857.0 Rig: DOYON 19 Page 16/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/11/2020 06:15 2/11/2020 06:45 0.50 INTRM1 DRILL OWFF T Flow Check = Well is static 4,857.0 4,857.0 2/11/2020 06:45 2/11/2020 09:00 2.25 INTRM1 DRILL BHAH T PJSM, Stand back BHA per Baker Rep 4,857.0 4,857.0 2/11/2020 09:00 2/11/2020 09:45 0.75 INTRM1 DRILL CLEN T Clean / Clear Rig floor. 4,857.0 4,857.0 2/11/2020 09:45 2/11/2020 10:15 0.50 INTRM1 DRILL BHAH T M/U New 9-7/8" AT505TX PDC Bit. 7X14. TFA = 1.0523 sq/in 4,857.0 4,857.0 2/11/2020 10:15 2/11/2020 10:45 0.50 INTRM1 DRILL SVRG T Service Rig. Add oil to Top Drive. 4,857.0 4,857.0 2/11/2020 10:45 2/11/2020 11:30 0.75 INTRM1 DRILL CLEN T Clean / Clear Rig floor. Mobilize BHA to rig floor 4,857.0 4,857.0 2/11/2020 11:30 2/11/2020 13:00 1.50 INTRM1 DRILL BHAH T M/U BHA #5 per Baker Rep. 9-7/8" PDC bit, AutoTrak Stab, MWD, Rhino Reamer, HWDP, Jar 4,857.0 4,857.0 2/11/2020 13:00 2/11/2020 17:00 4.00 INTRM1 DRILL TRIP T RIH F/BHA @585' to 4857' MD. Fill DP every 20 stands. Performed weekly BOP function test f/ TP station. 4,857.0 4,857.0 2/11/2020 17:00 2/11/2020 17:15 0.25 INTRM1 DRILL DHEQ T Opened Under Reamer @ 4826' MD - confirmed tool opened 4,857.0 4,857.0 2/11/2020 17:15 2/11/2020 17:30 0.25 INTRM1 DRILL DDRL T Wash / Ream to bottom. 750 gpm = 2890 psi, 80 rpm = 8K TQ off bottom 4,857.0 4,857.0 2/11/2020 17:30 2/12/2020 00:00 6.50 INTRM1 DRILL DDRL P Drilled 9 7/8" x 11" hole F/ 4857' to 5145' MD, 3952' TVD, 740 GPM = 2200 psi. 120 rpm = 9K TQ on bottom. WOB = 20 - 28K. ECD = 10.65 PUWT = 162K, SOWT = 152K, ROTW = 141K @ 20RPM, TQ = 7K off bottom. Opened RhinoReamer @ 4826' MD Pump 40 bbl Hi-Vis SAPP, Nut Plug Sweep. Slight increase in cuttings at B/U SPR's @ 4852' MD, 3886" TVD, w/ 9.6 ppg LSND SPR # 1- 25 spm =220 psi 35 spm 280 psi SPR # 2 - 25 spm 220 psi 35 spm 280 psi ADT = 5.2 hrs, Jars = 55 hrs, Bit = 5.2 hrs 4,857.0 5,145.0 Rig: DOYON 19 Page 17/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2020 00:00 2/12/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 5145' to 5589' MD, 4054' TVD, 700 to 740 GPM = 2050 - 2275 psi. 2050 & 2210 psi off bottom 120 rpm = 7-9K TQ on bottom. WOB = 10 - 25K. ECD = 11.0 ppg Perform Tq / Drag every 3 stands PUWT = 166K, SOWT = 128K, ROTW = 143K @ 20RPM, TQ = 7.5K off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 5224' and 5503' MD. Observe 20% increase in cuttings at Sweep B/U SPR's @ 5212' MD, 3973' TVD, w/ 9.7 ppg LSND SPR # 1- 25 spm = 220 psi 35 spm 280 psi SPR # 2- 25 spm = 220 psi 35 spm 280 psi ADT = 5.1 hrs, Jars = 60.1 hrs. 5,145.0 5,589.0 2/12/2020 06:00 2/12/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 5589' to 6097' MD, 4170' TVD, 700 GPM = 2150 psi. 2140 psi off bottom 120 rpm = 10K TQ on bottom. WOB = 20 - 25K. ECD = 11.0 Perform Tq / Drag every 3 stands PUWT = 167K, SOWT = 130K, ROTW = 144K @ 20RPM, TQ = 8K off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 5938' MD. Observe 20% increase in cuttings at Sweep B/U ADT = 4.7 hrs, Jars = 64.8 hrs. Bit hrs = 15.6. 4170' TVD 5,589.0 6,097.0 2/12/2020 12:00 2/12/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 6097' to 6610' MD, 4288' TVD, 700 GPM = 2180 psi. 2070 psi off bottom 120 rpm = 11K TQ on bottom. WOB = 15- 25K. ECD = 10.75 Perform Tq / Drag every 3 stands PUWT = 170K, SOWT = 131K, ROTW = 145K @ 20 RPM, TQ = 8.5K off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 6170' and 6450' MD. Observe 20 - 25% increase in cuttings at Sweep B/U SPR's @ 6349' MD, 4227' TVD, w/ 9.75 ppg LSND SPR # 1- 25 spm =220 psi 35 spm 280 psi SPR # 2- 25 spm =230 psi 35 spm 310 psi ADT = 5.40 hrs, Jars = 70.2 hrs. 6,097.0 6,610.0 Rig: DOYON 19 Page 18/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2020 18:00 2/13/2020 00:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 6610' to 7090' MD, 4398' TVD, 700 GPM = 2410 psi on bottom. 2390 psi off bottom. 120 rpm = 12K TQ on bottom. WOB = 15- 25K. ECD = 11.13. Perform Tq / Drag every 3 stands PUWT = 186K, SOWT = 125K, ROTW = 144K @ 20 RPM, TQ = 9.5K off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 6745' and 7070' MD. Observe 25 &- 10% increase in cuttings at Sweep B/U ADT = 4.5 hrs, Jars = 74.7 hrs. Bit hrs = 25.5 6,610.0 7,090.0 2/13/2020 00:00 2/13/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 7090' to 7530' MD, 4498' TVD, 700 GPM = 2490 psi on bottom. 2400 psi off bottom. 120 rpm = 12K TQ on bottom. WOB = 20-30K. ECD = 11.13 Perform Tq / Drag every 3 stands PUWT = 191K, SOWT = 130K, ROTW = 152K @ 20 RPM, 9.8K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 7300' MD. Observe 20% increase in cuttings at Sweep B/U SPR's @ 7387' MD, 4467' TVD, w/ 9.85 ppg LSND SPR # 1- 25 spm = 340 psi 35 spm 420 psi SPR # 2- 25 spm = 340 psi 35 spm 420 psi ADT = 5.0 hrs, Jars = 79.7 hrs. 7,090.0 7,530.0 2/13/2020 06:00 2/13/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 7530' to 8122' MD, 4635' TVD, 700 GPM = 2700 psi on bottom. 2600 psi off bottom. 140 rpm = 15K TQ on bottom. WOB = 20-25K. ECD = 11.16 Perform Tq / Drag every 3 stands PUWT = 195K, SOWT = 131K, ROTW = 153K @ 20 RPM, 10K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 7883' and MD. Observe 20% increase in cuttings at Sweep B/U ADT = 5.0 hrs, Jars = 84.7 hrs. Bit hrs = 35.5. 7,530.0 8,122.0 Rig: DOYON 19 Page 19/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/13/2020 12:00 2/13/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 8122' to 8712' MD, 4769' TVD, 700 GPM = 2600 psi on bottom. 2590 psi off bottom. 140 rpm = 16.5K TQ on bottom. WOB = 20-25K. ECD = 11.32 Perform Tq / Drag every 3 stands PUWT = 204K, SOWT = 130K, ROTW = 154K @ 20 RPM = 11K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 8150' and 8550' MD. Observe 20 & 10% increase in cuttings at Sweep B/U SPR's @ 8431' MD, 4704' TVD, MW = 10.15 ppg LSND SPR # 1- 25 spm = 310 psi 35 spm 400 psi SPR # 2- 25 spm = 290 psi 35 spm 370 psi ADT = 4.7 hrs, Jars = 89.4 hrs, Bit hrs = 40.2 8,122.0 8,712.0 2/13/2020 18:00 2/13/2020 21:00 3.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 8712' to 8996' MD, 4834' TVD, 700 GPM = 2660 psi on bottom. 2600 psi off bottom. 140 rpm = 16K TQ on bottom. WOB = 25-30K. ECD = 11.16 PUWT = 215K, SOWT = 131K, ROTW = 159K @ 20 RPM, 13K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 8911' MD. Observe <10% increase in cuttings at Sweep B/U 8,712.0 8,996.0 2/13/2020 21:00 2/13/2020 21:45 0.75 INTRM1 DRILL DDRL T Re-Activate Rhino Reamer to open position per SLB Rep that closed during drilling. Exercised open-close cycle on the reamer and verified operations. Continued drilling after flow, pressure and MWD RPM's confirmed proper deployment of blades. 8,996.0 8,996.0 2/13/2020 21:45 2/14/2020 00:00 2.25 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 8996' to 9245' MD, 4892' TVD, 700 GPM = 2750 psi on bottom. 2610 psi off bottom. 140 rpm = 19K TQ on bottom. WOB = 25-30K. ECD = 11.17 PUWT = 215K, SOWT = 131K, ROTW = 159K @ 20 RPM, 13K TQ off bottom. 8,996.0 9,245.0 Rig: DOYON 19 Page 20/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/14/2020 00:00 2/14/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 9245' to 9833' MD, 5031' TVD, 700 GPM = 2980 psi on bottom. 2910 psi off bottom. 140 rpm = 20K TQ on bottom. WOB = 20-30K. ECD = 11.52 Perform Tq / Drag every 3 stands PUWT = 223K, SOWT = 134K, ROTW = 162K @ 20 RPM = 12K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 9498' and 9780' MD. Observe 35% and 10% increases in cuttings at Sweep B/U SPR's @ 9563' MD, 4970' TVD, MW = 10 ppg LSND SPR # 1- 25 spm = 340 pi 35 spm 410 pi SPRY # 2- 25 spm = 340 pi 35 spm 410 psi ADT = 4.8 hrs, Jars = 97.9 hrs. 9,245.0 9,833.0 2/14/2020 06:00 2/14/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 9933' to 10320' MD, 5150' TVD, 700 GPM = 2750 psi on bottom. 2650 psi off bottom. 140 rpm = 20.5K TQ on bottom. WOB = 23-28K. ECD = 11.24 Perform Tq / Drag every 3 stands PUWT = 228K, SOWT = 132K, ROTW = 160K @ 20 RPM = 14K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 10295'. Observe 10% increase in cuttings at Sweep B/U ADT = 4.5 hrs, Jars = 102.4 hrs. 9,833.0 10,320.0 2/14/2020 12:00 2/14/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 10320' to 10965' MD, 5314' TVD, 700 GPM = 3020 psi on bottom. 2920 psi off bottom. 140 rpm = 20.5K TQ on bottom. WOB = 23-25K. ECD = 11.17 Perform Tq / Drag every 3 stands PUWT = 235K, SOWT = 132K, ROTW =164K @ 20 RPM = 14.5K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 10800'. Observe 10% increase in cuttings at Sweep B/U SPR's @ 10514' MD, 4198' TVD, MW = 10 ppg LSND SPR # 1- 25 spm = 370 psi 35 spm 410 psi SPR # 2- 25 spm = 310 psi 35 spm 380 psi ADT = 4.5 hrs, Jars = 106.9 hrs. 10,320.0 10,965.0 Rig: DOYON 19 Page 21/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/14/2020 18:00 2/14/2020 21:00 3.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole 10965' to 11267' MD, 5392 TVD, 700 GPM = 2900 psi on bottom. 2750 psi off bottom. 140 rpm = 25K TQ on bottom. WOB = 25K. ECD = 11.4 Perform Tq / Drag every 3 stands PUWT = 245K, SOWT = 135K, ROTW = 168K @ 20 RPM = 14.5K TQ off bottom. 10,965.0 11,267.0 2/14/2020 21:00 2/14/2020 22:15 1.25 INTRM1 DRILL CIRC P CBU 1X. 700 gpm = 2550 psi in preparation to install MPD bearing. R&R DP at 60 rpm = 14K TQ. Hold PJSM to install MPD bearing. 11,267.0 11,267.0 2/14/2020 22:15 2/14/2020 23:00 0.75 INTRM1 DRILL OWFF P Flow Check = well is Static. Install Beyond MPD Bearing at11267' MD. Possible HRZ tops at 11636' and 11845' per Geologist. 11,267.0 11,267.0 2/14/2020 23:00 2/15/2020 00:00 1.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 11267' to 11363' MD, 5417' TVD, 700 GPM = 2830 psi on bottom. 2720 psi off bottom. 140 rpm = 21K TQ on bottom. WOB = 25K. ECD = 11.30 with average BGG 180 units Perform Tq / Drag every 3 stands PUWT = 250K, SOWT = 135K, ROTW = 165K @ 20 RPM = 17K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 11367'. Observe 10% increase in cuttings at Sweep B/U ADT = 2.7 hrs, Jars = 109.6 hrs. 11,267.0 11,363.0 2/15/2020 00:00 2/15/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 11363' to 11985' MD, 5579' TVD, 700 GPM = 3080 psi on bottom. 3020 psi off bottom. 150 rpm = 24K TQ on bottom. Drilling open on MPD chokes, holding 230 psi on connections WOB = 28K. ECD = 11.54 with average BGG 260 units. Perform Tq / Drag every 3 stands PUWT = 255K, SOWT = 132K, ROTW = 168K @ 20 RPM = 17K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 11367 and 11776'. Observe 10% and 30% increases in cuttings at Sweep B/U SPR's @ 10514' MD, 4198' TVD, MW = 10 ppg LSND SPR # 1- 25 spm = 300 psi 35 spm 390 psi SPR # 2- 25 spm = 290 psi 35 spm 390 psi ADT = 4.1 hrs, Jars = 113.7 hrs. 11,363.0 11,985.0 Rig: DOYON 19 Page 22/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/15/2020 06:00 2/15/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 11985' to 12485' MD, 5711' TVD, 700 GPM = 3270 psi on bottom. 3250 psi off bottom. 150 rpm = 22.5K TQ on bottom. Drilling open on MPD chokes, holding 240 psi on connections WOB = 28K. ECD = 11.80 with average BGG 160 units PUWT = K, SOWT = 132K, ROTW = 168K @ 20 RPM = 17K TQ off bottom. Increase Mud wt to 10.2 ppg. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 12420'. Observe 30% increase in cuttings at Sweep B/U ADT = 3.6 hrs, Jars = 117.3 hrs. 11,985.0 12,485.0 2/15/2020 12:00 2/15/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 12485' to 12857' MD, 5800' TVD, 600 GPM = 2600 psi on bottom. 2590 psi off bottom. 120 rpm = 20K TQ on bottom. Drilling open on MPD chokes, holding 240 psi on connections WOB = 28K. ECD = 11.33 with average BGG 160 units Perform Tq / Drag every 3 stands PUWT = 265K, SOWT = 132K, ROTW = 166K @ 20 RPM = 17K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 12600'. Observe 10% increase in cuttings at Sweep B/U ADT = 4.6 hrs, Jars = 121.9 hrs. 12,485.0 12,857.0 2/15/2020 18:00 2/16/2020 00:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 12857' to 13138' MD, 5866' TVD, 600 GPM = 2600 psi on bottom. 2580 psi off bottom. 130 rpm = 20.5K TQ on bottom. Drilling open on MPD chokes, holding 230 psi on connections WOB = 28K. ECD = 11.43 with average BGG 160 units Perform Tq / Drag every 3 stands PUWT = 285K, SOWT = 125K, ROTW = 175K @ 20 RPM = 19.5K TQ off bottom. SPR's @ 13161' MD, 5872' TVD, MW = 10.2+ ppg LSND SPR # 1- 25 spm = 520 psi 35 spm 590 psi SPR # 2- 25 spm = 490 psi 35 spm 550 psi ADT = 5.1 hrs, Jars = 127 hrs. 12,857.0 13,138.0 Rig: DOYON 19 Page 23/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2020 00:00 2/16/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 13138' to 13280' MD, 5898' TVD, 600 GPM = 2580 psi on bottom. 2560 psi off bottom. 140 rpm = 21K TQ on bottom. Drilling open on MPD chokes, holding 150 psi on connections. WOB = 32K. ECD = 11.43 Perform Tq / Drag every 3 stands PUWT = 285K, SOWT = 125K, ROTW = 175K @ 20 RPM = 19.5K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 13166'. Observe 10% increase in cuttings at Sweep B/U ADT = 4.0 hrs, Jars = 131 hrs. 13,138.0 13,280.0 2/16/2020 06:00 2/16/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" hole F/ 13280' to TD at 13653' MD, 5933' TVD, 600 GPM = 2570 psi on bottom. 2550 psi off bottom. 140 rpm = 26K TQ on bottom. drilling open on MPD chokes, holding 150 psi on connections. WOB = 18K. ECD = 11.65 with average BGG 160 units PUWT = 300K, SOWT = 130K, ROTW = 168K @ 20 RPM = 20K TQ off bottom. Pump 30 bbl Hi-Vis SAPP, Nut Plug Sweep at 13653'. Observe 10% increase in cuttings at Sweep B/U ADT = 4.5 hrs, Jars = 135.5 hrs. Total drilling hours for Intermediate Section = 86.3 13,280.0 13,653.0 2/16/2020 12:00 2/16/2020 14:15 2.25 INTRM1 CASING CIRC P Take final survey, pump weighted sweep & CBU 2X. 600 GPM = 2650 psi. R&R drill pipe. 140 rpm = 21.5K TQ ECD = 11.7 ppg. 13,653.0 13,653.0 2/16/2020 14:15 2/16/2020 14:30 0.25 INTRM1 CASING CIRC P Obtain Parameters. PUWT = 308K, SOWT = 108K, ROTW = 168K @ 20 RPM = 22K TQ off bottom. SPR's @ 13653' MD, 5933' TVD, MW = 10.4 ppg LSND SPR # 1- 25 spm = 540 psi 35 spm 610 psi SPR # 2- 25 spm = 530 psi 35 spm 630 psi B/D Top Drive, Prep for MPD drawdown test. 13,653.0 13,653.0 2/16/2020 14:30 2/16/2020 17:30 3.00 INTRM1 CASING OTHR P Rotate pipe at 10 rpm. Perform MPD drawdown test per drawdown schedule. Initial MPD test pressure = 230 psi. Final MPD test stabilization = 205 psi. EMW = 11.1 ppg, 13,653.0 13,653.0 Rig: DOYON 19 Page 24/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2020 17:30 2/16/2020 18:15 0.75 INTRM1 CASING OTHR T Decision made to CBU. Attempt to stage up pumps and reciprocate pipe. Experience tight hole conditions = Overpull, Pack-off,Torque up, and Mud volume fluctuations. Worked pipe and apply 200 psi back pressure. Worked pipe free. Total losses of 247 bbls of LSND 10.4 ppg 13,653.0 13,653.0 2/16/2020 18:15 2/16/2020 21:00 2.75 INTRM1 CASING CIRC P CBU 1X. Stage pumps up to 600 GPM = 2850 psi. 45 rpm = 21K TQ. Initial ECD-12.1 ppg. Max gas at B/U = 528 units Discuss options with well engineer. Decision made to weight up to 11.4 ppg 13,653.0 13,653.0 2/16/2020 21:00 2/17/2020 00:00 3.00 INTRM1 CASING CIRC P CBU 3.5X while weighting in 0.3 ppg increments with 15.0 ppg spike fluid to 11.2 ppg at midnight. Pump 600 GPM = 2850 psi. 45-60 rpm = 19K TQ. ECD = 11.96 with average BGG 30 units 13,653.0 13,653.0 2/17/2020 00:00 2/17/2020 04:00 4.00 INTRM1 CASING CIRC P Continue to weight up Mud in 0.3 ppg increments with 15.0 ppg spike fluid to 11.4 ppg. Pump 600 GPM = 2850 psi. 60 rpm = 21K TQ. ECD = 12.44 with average BGG 220 units decreasing to 70 units with 11.4 ppg. 13,653.0 13,653.0 2/17/2020 04:00 2/17/2020 04:30 0.50 INTRM1 CASING CIRC P Obtain Parameters. PUWT = 228K, SOWT = 110K, ROTW = 158K @ 20 RPM = 23K TQ off bottom. SPR's @ 13653' MD, 5933' TVD, MW = 11.4 ppg LSND SPR # 1- 25 spm = 370 psi 35 spm 480 psi. MPD @ 100/80 SPR # 2- 25 spm = 380 psi 35 spm 470 psi. MPD @ 100/80 13,653.0 13,653.0 2/17/2020 04:30 2/17/2020 15:30 11.00 INTRM1 CASING REAM P BROOH F/13653' to 12392', 580 GPM = 2610 psi. 120 RPM = 22K TQ. MPD holding 200 psi at connections. Observe 30K TQ and mud losses begin 05:00 at 13534' MD. Work pipe and cont. BROOH. Losses at 68 bbls/hr while circulating. Tight spot intervals at: 13,393', 13,360', 13,300', 12,330' 12,285'. Unable to increase backreaming speed due to TQ & pressure increasing while attempting to pull faster. ECD = 12.69, average BGG 27 units Pumped a 30 ppb Nut plug LCM pill/sweep at 12860' MD while BROOH 13,653.0 12,392.0 2/17/2020 15:30 2/17/2020 18:30 3.00 INTRM1 CASING REAM P BROOH, Experience high Torque and packing off F/12392' to 12299', Pump from 480/575 GPM = 2000/2600 psi. 120 RPM = 9-26K TQ. MPD holding 225 psi at connections. Work pipe and slow pulling speed, Mud losses decreased after LCM sweep. 12,392.0 12,299.0 Rig: DOYON 19 Page 25/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/17/2020 18:30 2/17/2020 20:30 2.00 INTRM1 CASING REAM P BROOH, F/ 12299' to above HRZ to 12010'. 580 GPM = 2610 psi with average BGG 30 units. 120 RPM = 20K TQ, MPD holding 200 psi at connections. 12,299.0 12,010.0 2/17/2020 20:30 2/17/2020 22:30 2.00 INTRM1 CASING CIRC P Pump Hi-Vis sweep surface to surface. 570 GPM = 2600 psi 120 RPM = 19K TQ, MPD holding 200 psi at connections. 12,010.0 12,010.0 2/17/2020 22:30 2/18/2020 00:00 1.50 INTRM1 CASING CIRC T Performed multiple attempts to close Rhino-Reamer unsuccessfully. Varied open-close flow rates and reamer was not responding to cycles. Pressures varied for cycling for both Standard method and Continuous Flow method. Neither was successful. Flowed 580 GPM with 2530 psi and 2721 RPM and during cycles could not get the pressure (400 psi) increase indication to signal reamer had indexed. 12,010.0 12,010.0 2/18/2020 00:00 2/18/2020 02:00 2.00 INTRM1 CASING OWFF P B/D Top Drive. FLow check well at 12,010'. Observe well with decreasing flow rate. Continue to observe until no flow. 12,010.0 12,010.0 2/18/2020 02:00 2/18/2020 03:00 1.00 INTRM1 CASING TRIP P SOOH F/ 12010' to 11550'. Attempted to hold MPD to 12.0 ppg EMW. Observed 25 BPH losses at 280 psi at 12.0 ppg EMW inclusive of swab effect while pulling. Discuss options with town. Hold 125 psi on MPD at 11.8 ppg EMW. 12,010.0 11,550.0 2/18/2020 03:00 2/18/2020 04:00 1.00 INTRM1 CASING OWFF P Well appears to be charged up slighly. Observe well again with decreasing flow rate. Continue to observe until no flow, Initial flow back was 4.0 bph decreasing to .5 bph. 11,550.0 11,550.0 2/18/2020 04:00 2/18/2020 09:15 5.25 INTRM1 CASING TRIP P SOOH F/ 11550' to 6770'. Hold 125 psi on MPD at 11.8 ppg EMW back pressure. 11,550.0 6,770.0 2/18/2020 09:15 2/18/2020 11:00 1.75 INTRM1 CASING BKRM P BROOH F/ 6770' to 6699'. 575 GPM = 2000 psi. 120 RPM = 11K TQ, ECD- 12.4-12.6 ppg. Encounter tight hole at 6774'. Observe 30K overpull. B/D Top Drive. Losses at 50 bph w/ pumping. 6,770.0 6,699.0 2/18/2020 11:00 2/18/2020 11:15 0.25 INTRM1 CASING TRIP P SOOH F/ 6699' to 6543'. Hold 90 psi on MPD at 11.6 ppg EMW back pressure. 6,699.0 6,543.0 2/18/2020 11:15 2/18/2020 12:45 1.50 INTRM1 CASING BKRM P BROOH F/ 6543' to 6414'. 575 GPM = 2000 psi. 120 RPM = 11K TQ ECD- 12.5 ppg Encounter tight spot at 6543' Observe 30K overpull. B/D Top Drive 6,543.0 6,414.0 2/18/2020 12:45 2/18/2020 13:15 0.50 INTRM1 CASING TRIP P SOOH F/ 6414' to 6319'. Hold 90 psi on MPD at 11.6 ppg EMW back pressure. 6,414.0 6,319.0 Rig: DOYON 19 Page 26/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/18/2020 13:15 2/18/2020 18:00 4.75 INTRM1 CASING BKRM P BROOH F/ 6319' to 5176'. 600 GPM = 2050 psi. 120 RPM = 11K TQ Encounter tight spot at 6306' Observe 30K overpull. Pump sweep STS while BROOH. ECD-12.5 ppg B/D Top Drive 6,319.0 5,176.0 2/18/2020 18:00 2/18/2020 20:00 2.00 INTRM1 CASING TRIP P SOOH F/ 5176' to 3410' MD. Hold 90 psi on MPD at 11.6 ppg EMW back pressure. 5,176.0 3,410.0 2/18/2020 20:00 2/18/2020 20:45 0.75 INTRM1 CASING CIRC P Pump sweep STS. 580 GPM = 1750 psi. 80 RPM = 7K TQ R&R drill pipe. Observe 30% increase at shakers at B/U. Circulate until shakers cleaned up. 3,410.0 3,410.0 2/18/2020 20:45 2/18/2020 21:30 0.75 INTRM1 CASING OTHR T Attempt to close Rhino-Reamer = unsuccessful B/D Top Drive PUWT = 100K, SOWT = 80K W/ BHA outside of shoe. 3,410.0 3,410.0 2/18/2020 21:30 2/18/2020 22:00 0.50 INTRM1 CASING TRIP P Pull Rhino-Reamer and BHA thru shoe F/ 3410' to 3131' with no significant drag. PUWT = 100K, SOWT = 75K W/BHA inside casing 3,410.0 3,131.0 2/18/2020 22:00 2/18/2020 23:45 1.75 INTRM1 CASING TRIP P SOOH F/ 3131' to 680' MD. Hold 115 psi on MPD at 11.7 ppg EMW back pressure. PUWT = 100k SOWT = 80k 3,131.0 680.0 2/18/2020 23:45 2/19/2020 00:00 0.25 INTRM1 CASING OWFF P FLow check well. Observe well with decreasing flow rate. Continue to observe until no flow. Initial flow was 8.5 bph and decreasing slowly. 680.0 680.0 2/19/2020 00:00 2/19/2020 06:30 6.50 INTRM1 CASING OWFF P Flow check well. Observe well with decreasing flow rate. Continue to observe. Initial flow was 8.5 bph and slowly decreased exponentially to 1.2 bph. PJSM to remove MPD bearing 680.0 680.0 2/19/2020 06:30 2/19/2020 07:30 1.00 INTRM1 CASING OTHR P Remove MPD bearing and install trip nipple. 680.0 680.0 2/19/2020 07:30 2/19/2020 12:45 5.25 INTRM1 CASING BHAH P POOH. Stand back HWDP and Jar. L/D BHA #5 per Baker Directional Rep F/ 680 to surface. 680.0 0.0 2/19/2020 12:45 2/19/2020 14:30 1.75 INTRM1 CASING BHAH P Clear and clean rig floor of all tools. L/D BHA components. Bit Grading-- 1-1WT-A-X-I-CT-TD 0.0 0.0 2/19/2020 14:30 2/19/2020 15:30 1.00 INTRM1 CASING OTHR P Make up stack-washer to Top Drive and flush/wash BOP stack/well head. R/D and B/D Top Drive. 0.0 0.0 2/19/2020 15:30 2/19/2020 16:00 0.50 INTRM1 CASING SVRG P Rig Service 0.0 0.0 2/19/2020 16:00 2/19/2020 18:30 2.50 INTRM1 CASING BOPE P PJSM. Change out upper pipe rams to 7 5/8" solid body rams. 0.0 0.0 2/19/2020 18:30 2/19/2020 19:45 1.25 INTRM1 CASING BOPE P Pull Wear Bushing and install test plug and 7 5/8" test joint. Fill stack with water and purge air from system 0.0 0.0 Rig: DOYON 19 Page 27/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/19/2020 19:45 2/19/2020 21:00 1.25 INTRM1 CASING BOPE P Test annular to 250 psi low / 2500 psi high. Test 7 5/8" upper rams to 250 psi low / 3500 psi high. 5 min each, Charted. Pull Test Plug and L/D test joint. R/D test equip 0.0 0.0 2/19/2020 21:00 2/19/2020 22:00 1.00 INTRM1 CASING BOPE P M/U 7 5/8" Mandrel Casing Hanger to Landing jt. RIH. Perform Hanger Dummy run with Cameron Rep. Confirm Land out at 35.10 ft RKB. 0.0 0.0 2/19/2020 22:00 2/19/2020 23:45 1.75 INTRM1 CASING OTHR P PJSM. R/U GBR to run 7 5/8". R/U Volant CRT, bails, elevators, 7 5/8" spiders and side entry sub. Casing crossover/Safety valve on rig floor, valve open position. Monitor well on trip tank = hole is static 0.0 0.0 2/19/2020 23:45 2/20/2020 00:00 0.25 INTRM1 CASING PUTB P PJSM - Run 7 5/8" 29.7 ppf, L-80, Hydril 563 intermediate casing per running order. Bakerlok shoe track connections to pin end of joint #4 Circulate through shoe track and check floats = good. Torque connections to make up mark at 11,000 ft/lbs. Use Jet Lube Seal Guard casing dope. 0.0 0.0 2/20/2020 00:00 2/20/2020 01:00 1.00 INTRM1 CASING PUTB P Continue - Run 7 5/8" 29.7 ppf, L-80, Hydril 563 intermediate casing shoe track per running order to 169'. Bakerlok shoe track connections up to pin end of joint #4 Pump through float and shoe track to ensure circulation. Check floats = good. Torque connections to make up mark at 11,000 ft/lbs. Use Jet Lube Seal Guard casing dope. 0.0 169.0 2/20/2020 01:00 2/20/2020 08:00 7.00 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/ 169' to 3147'. Fill on the fly and top off every 10 joints. Torque pipe to 11K ft/lbs Monitor displacement closely. Started adjust run speed at 2000' to below the recommended surge analysis due to slight losses. 169.0 3,147.0 2/20/2020 08:00 2/20/2020 09:15 1.25 INTRM1 CASING CIRC P CBU 2X at shoe at 3147' MD. 336 GPM = 230 psi Observe 16 bph loss rate during circulation. Total mud loss from beginning of run to 3147' = 35 bbls Maintain 11.4 ppg MW 3,147.0 3,147.0 2/20/2020 09:15 2/20/2020 14:15 5.00 INTRM1 CASING PUTB P Cont - Run 7 5/8" casing F/ 3147' to 5335' MD. PUWT = 185K, SOWT = 135K. Reducing running speed to minimize losses. 3,147.0 5,335.0 Rig: DOYON 19 Page 28/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2020 14:15 2/20/2020 16:45 2.50 INTRM1 CASING CIRC T Stage up pumps slowly and ciirculate 11.4 ppg MW at 1-4 bpm = 230 psi on up stroke, .5 bmp = 210 psi on down stroke. Observe only 10% returns. Total losses while attempting to circulate was 195 bbls. 5,335.0 5,335.0 2/20/2020 16:45 2/20/2020 19:00 2.25 INTRM1 CASING PUTB P Continue Run 7 5/8" casing F/ 5335' to 6038' MD. Observe no overpull or drag while running casing and no displacement returns = 19.5 bbls loss. Reducing running speed to minimize losses. P/u WT-185K, SO WT-135K 5,335.0 6,038.0 2/20/2020 19:00 2/20/2020 21:00 2.00 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at (3 bpm)124 GPM = 280 psi on up stroke, (1/2 bpm) 22 GPM = 228 psi on down stroke. PUWT = 188K, SOWT = 139K. Observe only 10% returns. Had conference call with office staff to discuss plan forward. 6,038.0 6,038.0 2/20/2020 21:00 2/20/2020 23:00 2.00 INTRM1 CASING PUTB P Cont - Run 7 5/8" casing F/ 6038' to 6845' MD. Observe no over pull or drag while running pipe and no displacement returns = 20.8 bbls loss PUWT = 185K, SOWT = 135K 6,038.0 6,845.0 2/20/2020 23:00 2/21/2020 00:00 1.00 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at (3 bpm) 124 GPM = 280 psi on up stroke, (1/2 bpm) 22 GPM = 230 psi on down stroke. PUWT = 190K, SOWT = 142K. Observe 20% returns on circulation. Total fluid loss for 24 hours = 491 bbls 11.4 LSND 6,845.0 6,845.0 2/21/2020 00:00 2/21/2020 01:00 1.00 INTRM1 CASING CIRC T Work pipe and Circulate 11.4 ppg MW at 3 BPM = 280 psi on up stroke, 1/2 BPM= 230 psi on down stroke. PUWT = 190K, SOWT = 142K. Observe 20% returns on circulation, (80% losses) 6,845.0 6,845.0 2/21/2020 01:00 2/21/2020 04:00 3.00 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 6845' to 7644' MD. Observe normal drag while running pipe and no displacement returns Loss of 20 bbls in 20 joints ran. PUWT = 203K, SOWT = 138K 6,845.0 7,644.0 2/21/2020 04:00 2/21/2020 05:30 1.50 INTRM1 CASING CIRC T Work pipe and Circulate 11.4 ppg MW at 2.5 BPM = 340 psi on up stroke, 1/2 BPM= 290 psi on down stroke. PUWT = 203K, SOWT = 138K. Observe 20% returns on circulation. Pump 116.5 bbls total , Loss of 81 bbls 7,644.0 7,644.0 2/21/2020 05:30 2/21/2020 08:00 2.50 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 7644' to 8454' MD. Observe normal drag while running pipe and no displacement returns. Loss of 37 bbls PUWT = 210K, SOWT = 138K 7,644.0 8,454.0 Rig: DOYON 19 Page 29/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/21/2020 08:00 2/21/2020 09:45 1.75 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 400 psi on up stroke, 1/2 BPM= 320 psi on down stroke. PUWT = 210K, SOWT = 138K. Observe 20% returns on circulation. Pump 123 bbls total Loss of 97 bbls 8,454.0 8,454.0 2/21/2020 09:45 2/21/2020 12:30 2.75 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 8454' to 9251' MD. Observe normal drag while running pipe and no displacement returns. Loss of 37 bbls PUWT = 210K, SOWT = 138K 8,454.0 9,251.0 2/21/2020 12:30 2/21/2020 14:00 1.50 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 420 psi on up stroke, 1/2 BPM= 325 psi on down stroke. PUWT = 225K, SOWT = 138K. Observe 10% returns on circulation. Pump 120 bbls total Loss of 108 bbls 9,251.0 9,251.0 2/21/2020 14:00 2/21/2020 16:15 2.25 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 9251' to 10057' MD. Observe no significant over pull or drag while running pipe and no displacement returns. Loss of 33 bbls SOWT = 138K 9,251.0 10,057.0 2/21/2020 16:15 2/21/2020 18:00 1.75 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 430 psi on up stroke, 1/2 BPM= 350 psi on down stroke. PUWT = 230K, SOWT = 135K. Observe 8% returns on circulation. Pump 120 bbls total Loss of 101 bbls 10,057.0 10,057.0 2/21/2020 18:00 2/21/2020 20:30 2.50 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 10057' to 10860' MD. Observe no significant over pull or drag while running pipe and no displacement returns. Loss of 33 bbls SOWT = 138K 10,057.0 10,860.0 2/21/2020 20:30 2/21/2020 22:00 1.50 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 480 psi on up stroke, 1/2 BPM= 360 psi on down stroke. PUWT = 240K, SOWT = 135K. Observe 8% returns on circulation. Pump 120 bbls total Loss of 100 bbls 10,860.0 10,860.0 2/21/2020 22:00 2/22/2020 00:00 2.00 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 10860' to 11669' MD. Observe no significant drag on down stroke F/ 11223' to 11669' Loss of 30 bbls SOWT = 138K 10,860.0 11,669.0 2/22/2020 00:00 2/22/2020 01:30 1.50 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 480 psi on up stroke. 1/2 BPM= 400 psi on down stroke. PUWT = 250K, SOWT = 125K. Observe 20% returns on circulation. Pump 120 bbls total Loss of 100 bbls 11,669.0 11,669.0 Rig: DOYON 19 Page 30/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2020 01:30 2/22/2020 03:30 2.00 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 11669' to 12471' MD. Observe no significant drag on down stroke No displacement returns SOWT = 130 - 140K 11,669.0 12,471.0 2/22/2020 03:30 2/22/2020 05:00 1.50 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 485 psi on up stroke, 1/2 BPM= 390 psi on down stroke. PUWT = 290K, SOWT = 142K. Observe 5% returns on circulation. Pump 120 bbls total Loss of 116 bbls 12,471.0 12,471.0 2/22/2020 05:00 2/22/2020 06:30 1.50 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 12471' to 13038' MD. Observe no significant drag on down stroke No displacement returns SOWT = 140K 12,471.0 13,038.0 2/22/2020 06:30 2/22/2020 07:00 0.50 INTRM1 CASING CIRC T Circulate 11.4 ppg MW at 2.5 BPM = 520 psi on up stroke, 1/2 BPM= 390 psi on down stroke. PUWT = 290K, SOWT = 142K. Observe 18% returns on circulation. Pump 45 bbls total Loss of 37 bbls 13,038.0 13,038.0 2/22/2020 07:00 2/22/2020 09:00 2.00 INTRM1 CASING PUTB P Run 7 5/8" casing F/ 13038' to 13602' MD SOWT = 135K Displacement losses = 558 bbls 13,038.0 13,602.0 2/22/2020 09:00 2/22/2020 09:30 0.50 INTRM1 CASING PUTB P M/U 7 5/8" Casing Hanger and Landing joint per Cameron Rep. Attempt to establish P/u weight with Hanger above rotarty. Picked up to 350k. Normal p/u-300k. RIH to TD at 13640' MD and land out on casing seat Attempt to pick up on string to 310K with no break-over. Land Hanger on seat and prep to condition mud and cement. Final SOWT = 138K 13,602.0 13,640.0 2/22/2020 09:30 2/22/2020 11:30 2.00 INTRM1 CEMENT CIRC P Attempt to circulate and condition mud. 1/2 BPM = 420 psi, 1.5 BPM = 450 psi. Observe 5% returns. 159 bbls pumped, 151 bbls lost. Clear clean rig floor of casing tools. Mobilize equipment for cement job. Hold PJSM for HES cement job. 13,640.0 13,640.0 2/22/2020 11:30 2/22/2020 12:00 0.50 INTRM1 CEMENT OTHR P R/U Cement Circulating lines to Volant CRT. B/D Top Drive 13,640.0 13,640.0 2/22/2020 12:00 2/22/2020 13:00 1.00 INTRM1 CEMENT CMNT P Break circulation W/ mud pumps thru cement lines. 1.5 BPM = 420 psi, 4 BPM = 620 psi. HES flood circulating lines W/ 5 bbls water. Test surface lines to 3500 psi = Good test. Break out Volant tool. Load Bottom Plug in pipe. Change out Volant CRT 7 5/8" Casing Cup per GBR Rep. 13,640.0 13,640.0 Rig: DOYON 19 Page 31/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2020 13:00 2/22/2020 17:30 4.50 INTRM1 CEMENT CMNT P Drop bottom plug. Verified by Co-man. HES pump 60 bbl Tuned spacer = 12 ppg, 3.18 yield, 20.0 gal/sk with 30 bbl LCM blended in. 4 BPM = 843 psi. Pump 247 bbl Lead Cement = 1125 sks, 15.5 ppg, 1.20 yield, 5.33 gal/sk, with .25 lb/bbl WellLife mixed in on the fly. 4 BPM = 750 psi. Pump 40 bbl Tail Cement = 20 sks, 15.8 ppg, 1.16 yield, 4.97 gal/sk, with .25 lb/bbl WellLife mixed on the fly. 4 BPM = 634 psi. Drop top plug. Verified by Co-man. Kick out plug with 10 bbls water. Swap to rig pumps. Rig pump chase with 619 bbls of 11.4 ppg LSND mud from pits. ICP = 230 psi at 7 BPM. FCP = 710 psi at 2 BPM. Bump plug at 6027 strokes. (pumpout put of .1028 bbl/stk -98%) Pressure up to 1200 psi and hold 5 min. Bleed off and check floats = Good CIP @ 17:00, 2/23/2020 13,640.0 13,640.0 2/22/2020 17:30 2/22/2020 19:15 1.75 INTRM1 CEMENT CMNT P R/D and blow down all cement circ lines and Top Drive. R/D GBR Volant CRT, bales, casing tongs and related tools. C/O cement valves. 13,640.0 2/22/2020 19:15 2/22/2020 20:00 0.75 INTRM1 CEMENT OTHR P R/U 5" elevators and M/U Stack washing tool. RIH to Hanger/Packoff area and wash 2/22/2020 20:00 2/22/2020 21:45 1.75 INTRM1 CEMENT WWSP P C/O elevators. R/U 7 5/8" landing joint to casing pack-off setting tool. RIH with Pack-off and RILDS. Test Pack-off to 5000 psi, 5 min = Good. Test witnessed by Co-man. L/D landing joint and running tool. 2/22/2020 21:45 2/23/2020 00:00 2.25 INTRM1 WHDBOP BOPE P PJSM. C/O 7 5/8" rams to 3.5 X 6 VBR's SIMOPS, C/O Saver sub to XT-38. Wire tie all bolts and keepers. 2/23/2020 00:00 2/23/2020 00:30 0.50 INTRM1 WHDBOP BOPE P Continue to change out Saver Sub on Top Drive to XT-39. Install safety wire ties on all bolts and keepers. Simops: Finish installing VBRs in BOPs. 2/23/2020 00:30 2/23/2020 01:00 0.50 INTRM1 WHDBOP BOPE P Pick up running tool and install test plug as per Cameron Tech. 2/23/2020 01:00 2/23/2020 01:30 0.50 INTRM1 WHDBOP BOPE P Rig up BOPE test equip. Fill stack and choke manifold with water. Rig: DOYON 19 Page 32/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/23/2020 01:30 2/23/2020 09:00 7.50 INTRM1 WHDBOP BOPE P Test BOPE with 3 1/2", 4" and 4 1/2" test joints 250/2500 PSI on Annular Preventer 5/5 min each , 250/3500 PSI 5/5 min each on rams, choke valves and floor valves. tested as followed Annular , 4" Demco valve , choke manifold,valves 1-14 , 3 1/2" x 6" upper/lower rams choke/kill HCR , choke kill manual valves. Blind Rams Perform 1200 PSI choke draw down test Kommey Drawdown test - Int PSI ACC - 3000 PSI Manifold 1450 PSI Annular 925 PSI - ISP = 3000 PSI PAC = 1400 PSI Koomey test = 200 PSi = 24 seconds Full PSI to 3000 PSI = 151 Seconds Nitrogen Bottles = 2000 PSI Average for 4 bottles Test PVT , Gas Alarms Function BOPE remote panel from Boiler room. AOGCC Rep Bob Noble waived witness of test Load pipe shed w/4" DP , prep pits for Flo Pro mud. 2/23/2020 09:00 2/23/2020 09:30 0.50 INTRM1 WHDBOP BOPE P Pull test plug and install 10" ID Wear Bushing per Cameron Rep. 2/23/2020 09:30 2/23/2020 10:15 0.75 INTRM1 WHDBOP BOPE P R/D test Equip. pull test plug , install wear ring as per Cameron. B/D test lines and choke/kill lines , drain stack. B/D mud line to pump room. Install 5" elevators. Blow thru Psi relief valves and function test. Install 5" elevators. Ready rig floor to lay down 5" DP from derrick. 2/23/2020 10:15 2/23/2020 12:00 1.75 INTRM1 CEMENT PULD P Begin L/D 5" DP from derrick thru mouse hole. SIMOPS - Little Red Services - Freeze protect 10 3/4" X 7 5/8" OA with total of 82 bbls of diesel. ICP @ 1 bpm = 500 psi, FCP @ 2 bpm = 1200 psi, FCP @ 1 bpm = 1050 psi, Final shut in pressure = 740 psi 2/23/2020 12:00 2/24/2020 00:00 12.00 INTRM1 CEMENT PULD P L/D 5" DP from derrick through mouse hole. Total of 119 stds laid down at midnight. 2/24/2020 00:00 2/24/2020 07:15 7.25 INTRM1 CEMENT PULD P Conttinue to L/D 5" DP from derrick to pipe shed. Mobilize BHA tools to rig floor. Use rig tongs and steam to break out tight connections. 0.0 0.0 2/24/2020 07:15 2/24/2020 08:00 0.75 INTRM1 CEMENT PULD P Continue to L/D 5" DP from derrick to pipeshed. Mobilize BHA tools to rig floor. Use rig tongs and steam to break out tight connections. Unable to break all connections. Left 3 stands of 5" DP in derrick. 0.0 0.0 Rig: DOYON 19 Page 33/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/24/2020 08:00 2/24/2020 11:30 3.50 INTRM1 DRILLOUT BHAH P PJSM - Make up BHA #6 as per Baker DD and MWD. 6 3/4" PDC bit, Auto-Trac, MWD, Sonic Scope, NM collars, Float subs, HWDP. PJSM, Load RA source per Baker MWD Rep. M/U HWDP, Jar, HWDP. T/ 354' BHA 0.0 354.0 2/24/2020 11:30 2/24/2020 13:30 2.00 INTRM1 DRILLOUT TRIP P P/U 4" XT-39 DP from pipe shed, F/ 354' to 2243'. Fill pipe every 20 stands. PUWT = 93K SOWT = 93K 354.0 2,243.0 2/24/2020 13:30 2/24/2020 14:30 1.00 INTRM1 DRILLOUT DHEQ P Perform Shallow pulse test on MWD. Pump 300 GPM = 1460 PSI - Good test 2,243.0 2,243.0 2/24/2020 14:30 2/24/2020 17:30 3.00 INTRM1 DRILLOUT TRIP P RIH F/ 2243' to 4701' with 4" DP from pipe shed, Fill pipe every 20 stands - PUWT = 93K. Displacement on trip in indicates that floats are not holding. Attempt to work floats closed. 2,243.0 4,701.0 2/24/2020 17:30 2/24/2020 18:15 0.75 INTRM1 DRILLOUT CIRC T Fill pipe with 11.4 ppg LSND. Install TIW valve. Establish circ thru kill line. Space out tool joint and close Annular. Pump down annulus and attempt to seat float valves by pressuring up to 300 psi. Pump 1/2 BPM. At 140 PSI, mud reversed past the floats and out the pipe = Floats are not holding. 4,701.0 4,701.0 2/24/2020 18:15 2/24/2020 18:45 0.50 INTRM1 DRILLOUT CIRC T CBU @ 4701' @ 300 GPM = 1740 PSI to clear float valves. 4,701.0 4,701.0 2/24/2020 18:45 2/24/2020 19:30 0.75 INTRM1 DRILLOUT DHEQ T Attempt to close Float valves again by applying pressure down the annulus. Space out for tool joint placement. Close Annular. Reverse circ. thru kill line @ 1/2 BPM 140 PSI - flow coming out drill pipe Discuss options and plan forward with office team. B/D Top Drive and Kill line. 4,701.0 4,701.0 2/24/2020 19:30 2/24/2020 21:45 2.25 INTRM1 DRILLOUT TRIP T OWFF. POOH F/ 4701' to 158', Flow check at BHA = static. 4,701.0 158.0 2/24/2020 21:45 2/24/2020 22:30 0.75 INTRM1 DRILLOUT BHAH T L/D and inspect Float Subs, Float valves and Filter sub. Found upper Float flapper stuck in open position in valve body. Lower Float was in closed position. Filter was clean. Discuss options and plan forward with office team. 158.0 158.0 2/24/2020 22:30 2/24/2020 23:00 0.50 INTRM1 DRILLOUT BHAH T Pooh to access SLB Sonic Sub and reset clock on Logging tool. Clock will start at 03:45 on 2/25/20 158.0 99.0 2/24/2020 23:00 2/24/2020 23:30 0.50 INTRM1 DRILLOUT BHAH T PJSM. Change out 1 float sub and install 2 new Float valves. Change position of Float subs to be separated by ~30' 99.0 354.0 2/24/2020 23:30 2/25/2020 00:00 0.50 INTRM1 DRILLOUT TRIP T RIH with 4" DP from derrick T/ 1300'. Pipe is taking proper "Dry Pipe" displacement. 354.0 1,300.0 Rig: DOYON 19 Page 34/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/25/2020 00:00 2/25/2020 01:00 1.00 INTRM1 DRILLOUT BHAH T RIH T/1300' - Circ @ 120 GPM 270 PSI - pump 20 BBLS -Shut DN - Close Ann on 4" DP reverse thru DP , confirm floats holding. 1,300.0 1,300.0 2/25/2020 01:00 2/25/2020 02:45 1.75 INTRM1 DRILLOUT TRIP T RIH from derrick f/1300' t/4705' - P/U WT = 115K S/O WT= 98K - Fill pipe every 20 STDS , blow down top drive 1,300.0 4,705.0 2/25/2020 02:45 2/25/2020 03:15 0.50 INTRM1 DRILLOUT SVRG P Service rig while circ to confirm MWD is working @ 260 GPM 1400 PSI 4,705.0 4,705.0 2/25/2020 03:15 2/25/2020 07:00 3.75 INTRM1 DRILLOUT TRIP P RIH w/4" DP F/4705' T/7446' - P/U WT=128K S/O WT=95K 4,705.0 7,446.0 2/25/2020 07:00 2/25/2020 09:15 2.25 INTRM1 DRILLOUT SLPC P Slip and cut 97' Drilling line - Service top drive/ deadman/blocks - top drive inspection (good) - grease IBOP, calibrate hookload - RD slip & cut tools - break out & blow down top drive - Ready rig floor to trip in hole for MAD pass Simops - circ and condition mud @ 11.4 ppg LSND 2 90 gpm @ 490 psi 7,446.0 7,446.0 2/25/2020 09:15 2/25/2020 12:00 2.75 INTRM1 DRILLOUT TRIP P RIH f/ 7441' to 7500' (picking up singles of 4" DP f/ shed) Begin MAD pass f/ 7500' to 8926' @ 1800'/hr -- Picking up pipe f/ pipe shed - filling pipe every 20 stds 7,446.0 8,926.0 2/25/2020 12:00 2/25/2020 18:00 6.00 INTRM1 DRILLOUT TRIP P Cont. RIH w/ 4" DP f/ shed f/ 8926' to 11617' making MAD pass @ 1800'/hr - PU wt. 180 k SO wt 100 k Filling pipe every 20 stds 8,926.0 11,617.0 2/25/2020 18:00 2/25/2020 20:30 2.50 INTRM1 DRILLOUT TRIP P Finished MAD pass @ 11,617' - Cont. RIH f/ 11,617' to 13,488' - picking up 4" DP f/ shed PU wt 128 SO wt. 95 k 11,617.0 13,488.0 2/25/2020 20:30 2/25/2020 23:15 2.75 INTRM1 DRILLOUT CIRC P Circ & condition mud for casing test @ 250 gpm @ 2280 psi Flow out 10 % w/ 40 rpm @ 10 k torque PU wt 185 SO wt 95 k Rot wt. 128 k 10.9+ ppg in / 11.1 ppg out 13,488.0 13,488.0 2/25/2020 23:15 2/26/2020 00:00 0.75 INTRM1 DRILLOUT PRTS P Rig up for casing test Blow down top drive Flow ck ( well static) 13,488.0 13,488.0 2/26/2020 00:00 2/26/2020 01:30 1.50 INTRM1 DRILLOUT PRTS P Test casing to 3500 PSI - for 30 min good test - pump 7.2 BBLS get back 7 BBLS - rig down casing equipment 13,488.0 13,488.0 2/26/2020 01:30 2/26/2020 01:45 0.25 INTRM1 DRILLOUT TRIP P RIH f/13488' to13509' - 250 GPM 1910 PSI - 40 RPM 11K TQ - 190k UP 105K DN 132k ROT WT 13,488.0 13,509.0 2/26/2020 01:45 2/26/2020 03:15 1.50 INTRM1 DRILLOUT CIRC P Circ Cond mud for drilling out - 250 GPM 1910 PSI 190k UP 105k DN 132k Rot 40 rpm 11k TQ 13,509.0 13,509.0 2/26/2020 03:15 2/26/2020 03:30 0.25 INTRM1 DRILLOUT COCF P Wash down from 13509' to 13540' - 250 GPM 2050 PSI 180k UP 100k DN 13,509.0 13,540.0 2/26/2020 03:30 2/26/2020 05:00 1.50 INTRM1 DRILLOUT DRLG P Drill out shoe track from 13540' to 13630' - 250 GPM 2050 PSI 8-10k WOB 40 RPM 11k TQ - 180k UP 100k DN 132k ROT - tag up 10' high on float and shoe - Clean out rat hole to 13653' 13,540.0 13,653.0 Rig: DOYON 19 Page 35/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/26/2020 05:00 2/26/2020 05:30 0.50 INTRM1 DRILLOUT DRLG P Drill 20' new hole to 13673' - 250 GPM 2100 PSI - 8-10k WOB 40 RPM 11- 12k TQ - 180k UP 100k DN 132k ROT WT 13,653.0 13,673.0 2/26/2020 05:30 2/26/2020 06:45 1.25 INTRM1 DRILLOUT CIRC P Circulate B/U @ 250 GPM 2050 PSI 40 RPM 11-12k TQ - 130k ROT WT - work thru shoe twice with rot. see slight over pull of 5-8k 13,673.0 13,673.0 2/26/2020 06:45 2/26/2020 07:00 0.25 INTRM1 DRILLOUT OWFF P Blow down top drive - flow check (Static) 13,673.0 13,673.0 2/26/2020 07:00 2/26/2020 08:15 1.25 INTRM1 DRILLOUT LOT P Rig up to perform LOT/FIT test - PSI up to 1170 - get a leak off of 14.1 PPG EMW - pump 3.2 BBLS get back 2.2 BBLS - 1 BBL lost to formation. Rig down test equipment. Flow ck - well static 13,673.0 13,673.0 2/26/2020 08:15 2/26/2020 09:15 1.00 PROD1 DRILL MPDA P PJSM - Install MPD bearing. Break in bearing per MPD rep. 10rpm f/ 5 minutes. PU=200k S/O= 133k 13,673.0 13,673.0 2/26/2020 09:15 2/26/2020 10:15 1.00 PROD1 DRILL CIRC P Wash down f/ 13603' to 13673' 200gpm. 1470psi. 40 rpm. 11k tq. Rot wt=131k. Continue circulating BU while hoilding PJSM for displacement. 13,673.0 13,673.0 2/26/2020 10:15 2/26/2020 13:00 2.75 PROD1 DRILL CIRC P Displace well f/ 11.4ppg LSND to 10.5ppg FLOPRO. ICP=220gpm/2080psi. 40rpm. 12k tq. Rot wt=133k. 13,673.0 13,673.0 2/26/2020 13:00 2/26/2020 18:00 5.00 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ RSS f/ 13,673' to 14,071' MD 5932' TVD ADT - 3.4 hrs. ECD - 11.88 ppg WOB 9/14 k - GPM 250 @ 2020 psi - RPM 120 Torque on/off btm - 12/16 k / 12 k String wt. - PU 201 k Rot 129 k SPR @ 13673' MD 5933' TVD w/ 10.5 ppg FloPro # 1 15/25 spm 430 / 650 psi #2 15/25 spm 430/620 psi Jars hrs. 3.8 hrs. Bit hrs. 3.8 hrs Taking T&D data every 3 stds. Using MPD to maintain near constant BHP 13,673.0 14,071.0 2/26/2020 18:00 2/27/2020 00:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/ RSS f/ 14071' to 14539' MD 5922' TVD ADT - 5.3 hrs. ECD - 11.88 ppg WOB 10/12 k - GPM 250 @ 2110 psi - RPM 120 Torque on/off btm - 13/16 k / 12 k String wt. - PU 205 k Rot 125 k Jars hrs. 9.1 hrs. Bit hrs. 5.3 hrs Taking T&D data every 3 stds. Using MPD to maintain near constant BHP Keep ROP at 85' per/hr per DE and Geo for data gathering purposes 14,071.0 14,539.0 Rig: DOYON 19 Page 36/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/27/2020 00:00 2/27/2020 06:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/ 14539' to 14966' MD 5912' TVD ADT - 4.6 hrs. ECD - 12.02 ppg WOB 5-8 k - GPM 250 @ 2170 psi - RPM 120 Torque on/off btm - 13.5 k / 11.5 k String wt. - PU122 k Rot 125 k Jars hrs. 13.7 hrs. Bit hrs. 13.7 hrs Taking T&D data every 3 stds. Using MPD to maintain near constant BHP Max gas 1600 units Keep ROP at 85' per/hr per DE and Geo for data gathering purposes SPR @ 14,640' MD 5921' TVD w/ 10.5 ppg FloPro #2 15/25 spm 550/710 psi * pump #1 tied into MPD 14,539.0 14,966.0 2/27/2020 06:00 2/27/2020 12:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/ 14966' to 15,452' MD 5913' TVD ADT - 5.1 hrs. ECD - 12.02 ppg WOB 5-8 k - GPM 250 @ 2260 psi - RPM 120 Torque on/off btm - 12/14 k / 12 k String wt. - PU 300 k Rot 136 k Jars hrs. 18.8 hrs. Bit hrs. 18.8 hrs Taking T&D data every 3 stds. Using MPD to maintain near constant BHP Max gas 1900 units Kept ROP @ 85'/hr as directed by DE and Geo for data gathering purposes 14,966.0 15,452.0 2/27/2020 12:00 2/27/2020 18:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/ 15,452' to 15,790' MD 5921' TVD ADT - 4.8 hrs. ECD - 12.01 ppg WOB 5/15 k - GPM 250 @ 2200 psi - RPM 120 Torque on/off btm. 14 k / 10 k String wt - PU 194 k ROT 131 k Jar hrs. - 23.6 hrs Bit hrs. 23.6 hrs Max gas 767 units Taking T&D data every 3 stds. Using MPD to maintaine constant BHP 15,452.0 15,790.0 2/27/2020 18:00 2/28/2020 00:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/ 15,790' to 16,234' MD 5916' TVD ADT - 5.2 hrs. ECD - 12.15 ppg WOB 5/8 k - GPM 250 @ 2410 psi - RPM 120 Torque on/off btm.- 14.5 k 10.3 k String wt. PU 195 k Rot 138 k Jars hrs.28.8 Bit hrs. 28.8 Max gas 1900 units Taking T&D data every 3 stds. Using MPD to maintain constant BHP 15,790.0 16,234.0 Rig: DOYON 19 Page 37/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/28/2020 00:00 2/28/2020 06:00 6.00 PROD1 DRILL DRLG P Drilled 6 3/4" production hole w/ RSS f/ 16,234' to 16,550' MD 5925' TVD ADT - 4.8 hrs. ECD - 12.07 ppg WOB 12/15 k - GPM 250 @ 2370 psi - RPM 120 Torque on/off btm.- 14.5 k 10.3 k String wt. PU 192 k Rot 140 k Jars hrs.33.6 Bit hrs. 33.6 Max gas 1900 units Taking T&D data every 3 stds. Using MPD to maintain constant BHP SPR @ 16,346' MD 5917' TVD w/ 10.5 ppg FloPro # 2 15/25 spm - 700/880 psi 16,234.0 16,550.0 2/28/2020 06:00 2/28/2020 12:00 6.00 PROD1 DRILL DRLG P Drilled 6 3/4" production hole w/ RSS f/ 16,550' to 17,192' MD 5925' TVD ADT - 4.6 hrs. ECD - 12.28 ppg WOB 5/10 k - GPM 250 @ 2410 psi - RPM 120 Torque on/off btm.- 15 k 11.5 k String wt. PU 202 k Rot 131 k Jars hrs. 38.2 Bit hrs. 38.2 Max gas 1097 units Taking T&D data every 3 stds. Using MPD to maintain constant BHP 16,550.0 17,192.0 2/28/2020 12:00 2/28/2020 18:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/ 17,192' to 17,665' MD 5927' TVD ADT - 4.8 hrs. ECD - 12.26 ppg WOB - 5/10 k GPM 250 @ 2480 psi RPM 120 Torque - on/off btm. 15.5 k / 12 k String wt. PU 204 k ROT 130 K Jar hrs. 43 Bit hrs. 43 Max gas 1400 units Taking T&D data every 3 stds Using MPD to maintain constant BHA SPR 17,392' MD 5923' TVD # 2 - 15/25 SPM @ 680/950 psi 17,192.0 17,665.0 2/28/2020 18:00 2/29/2020 00:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/17,665' MD to 18310 5927' TVD ADT - 4.2 hrs. ECD - 12.26 ppg WOB - 5/10 k GPM 250 @ 2680 psi RPM 120 Torque - on/off btm. 15.5 k / 12 k String wt. PU 213 k ROT 139 K Jar hrs. 47.9 Bit hrs. 47.9 Max gas 1400 units Taking T&D data every 3 stds Using MPD to maintain constant BHA 17,665.0 18,310.0 Rig: DOYON 19 Page 38/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/29/2020 00:00 2/29/2020 06:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/18,310' MD to 18794' 5927' TVD ADT - 4.1 hrs. ECD - 12.26 ppg WOB - 10/15 k GPM 250 @ 2480 psi RPM 120 Torque - on/off btm. 15.5 k / 12 k String wt. PU 225 k ROT 150 K Jar hrs. 52.0 Bit hrs. 52.0 Max gas 1400 units Taking T&D data every 3 stds Using MPD to maintain constant BHP SPR #2 MP 15/25 SPM = 730/930 PSI 210/130 back pressure from MPD 18,310.0 18,794.0 2/29/2020 06:00 2/29/2020 12:00 6.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/18,794' MD to 19,308' MD 5922 TVD ADT - 5.2 hrs. ECD - 12.26 ppg WOB - 10/15 k GPM 250 @ 2480 psi RPM 120 Torque - on/off btm. 15.5 k / 14 k String wt. PU 225 k ROT 150 K Jar hrs. 57.2 Bit hrs. 57.2 Max gas 1400 units Taking T&D data every 3 stds Using MPD to maintain constant BHP 18,794.0 19,308.0 2/29/2020 12:00 2/29/2020 13:00 1.00 PROD1 DRILL DDRL P Drilled 6 3/4" production hole w/ RSS f/19308' MD to 19,383' MD 5922 TVD ADT - .6 hrs. ECD - 12.60 ppg WOB - 7/10 k GPM 250 @ 2860 psi RPM 120 Torque - on/off btm. 16 k / 12.7 k String wt. PU 227 k ROT 128 K Jar hrs. 57.8 Bit hrs. 57.8 Max gas 521 units Taking T&D data every 3 stds Using MPD to maintain constant BHP SPR @ 19,340' MD 5922' TVD w/ 10.5 ppg FlowPro # 2 15/25 spm 640 psi / 950 psi *NOTE TD called @ 19383' MD 5923' TVD 19,308.0 19,383.0 2/29/2020 13:00 2/29/2020 15:00 2.00 PROD1 CASING CIRC P Obtain final survey @ TD 19,383' - Down link to close ATK ribs - Pull up to 19,369' (standing back 1 std 4" DP) - Circ btms up @ 300 gpm @ 3740 psi w/ 150 rpm w/ 14 k torque - rotate & reciepracate pipe 19,383.0 19,383.0 2/29/2020 15:00 2/29/2020 15:15 0.25 PROD1 CASING OWFF P Perform MPD drawdown to establish kill wt mud - w/ 10.5 ppg ISP 280 psi - held 5 mins. - Bleed down to 25 psi - Shut in built to 280 psi in 5 minsi - Line up to trip tank for bleedback - Intinal TT vol. 22.1 bbls - Final trip tank vol. 28.7 bbls - 6.6 bbls total bleed back - KWM = 265 / .052/ 5923 TVD = .9091 + 10.5 = 11.4 ppg + 2 ppg trip margin = 11.6 ppg brine wt. 19,383.0 19,383.0 2/29/2020 15:15 2/29/2020 19:45 4.50 PROD1 CASING CIRC P Circulate hole clean while rotating and reciprocating pipe. 300gpm. 3630psi.150rpm 19,383.0 19,383.0 Rig: DOYON 19 Page 39/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/29/2020 19:45 3/1/2020 00:00 4.25 PROD1 CASING BKRM P BROOH F/19183' T/17687' - W/250 GPM 2800 PSI - 120 RPM 132 ROT WT 13K TQ 19,383.0 17,687.0 3/1/2020 00:00 3/1/2020 06:00 6.00 PROD1 CASING BKRM P BROOH F/17687 T/14886' @ 250 GPM 2620 PSI 120 RPM 10K tq - 138k ROT 17,687.0 14,886.0 3/1/2020 06:00 3/1/2020 08:30 2.50 PROD1 CASING BKRM P BROOH F/14886 T/13603' @ 250 GPM 2620 PSI 120 RPM 10K tq - 138k ROT 14,886.0 13,603.0 3/1/2020 08:30 3/1/2020 11:15 2.75 PROD1 CASING CIRC P Circ x2 Bottoms up until shakers cleaned up @ 300 GPM 3020 PSI - 120 RPM 8K TQ 138k ROT WT. Prep to displace to 11.6ppg NaBr brine. 13,603.0 13,603.0 3/1/2020 11:15 3/1/2020 13:15 2.00 PROD1 CASING CIRC P PJSM Displaced well w/ 11.6 ppg NaBr kill wt brine as follows: Pump 40 bbls 11.6 ppg NAbr Hi-Vis spacer & Pump 514 bbls 11.6 ppg NaBr brine @ 300 GPM @ 2750 psi w/ 120 rpm w/ 7 k torque - PU wt 156 SO wt 120 Rot wt 135 - SPR @ 13,600' MD 5933' TVD # 1 15/25 spm 160/410 psi # 2 15/25 spm 160/410 psi 13,603.0 13,603.0 3/1/2020 13:15 3/1/2020 13:45 0.50 PROD1 CASING OWFF P Observed well for flow - Well static Dropped 2.10" hollow drift w/ 100' slick line attached 13,603.0 13,603.0 3/1/2020 13:45 3/1/2020 15:45 2.00 PROD1 CASING SMPD P SOOH f/ 13,603' to 11,707' w/ MPD holding BP - PU wt 176 k - Incorrect fill volume 13,603.0 11,707.0 3/1/2020 15:45 3/1/2020 16:15 0.50 PROD1 CASING OWFF P Observed well for flow - Well static 11,707.0 11,707.0 3/1/2020 16:15 3/1/2020 17:00 0.75 PROD1 CASING MPDA P Pulled MPD bearing - Install trip nipple as per MPD Rep. 11,707.0 11,707.0 3/1/2020 17:00 3/2/2020 00:00 7.00 PROD1 CASING TRIP P POOH on elevators f/ 11,707' to 3272' 11,707.0 3,272.0 3/2/2020 00:00 3/2/2020 03:00 3.00 PROD1 CASING TRIP P POOH F/3272' T/354' - on elevators Top of BHA 3,272.0 354.0 3/2/2020 03:00 3/2/2020 03:15 0.25 PROD1 CASING OWFF P OWFF - Static - PJSM - L/D BHA 354.0 354.0 3/2/2020 03:15 3/2/2020 04:45 1.50 PROD1 CASING BHAH P Rack back jar std - Break out & LD XO sub - NM float sub - Monel DC - float sub & filter sub PJSM on removing RA sources - Remove RA sources - 354.0 129.0 3/2/2020 04:45 3/2/2020 06:00 1.25 PROD1 CASING BHAH P Continue LD BHA as per Baker DD to 85' 129.0 85.0 3/2/2020 06:00 3/2/2020 06:45 0.75 PROD1 CASING BHAH P Finish LD BHA as per Baker - Break bit Calc hole fill 125.5 bbls Actual hole fill 169 bbls 85.0 0.0 3/2/2020 06:45 3/2/2020 07:15 0.50 PROD1 CASING BHAH P Clean and clear rig floor of BHA tools and Equipment 0.0 0.0 3/2/2020 07:15 3/2/2020 08:45 1.50 COMPZN CASING RURD P Rig up to run 4 1/2" liner - Bring up casing tongs , baker liner tools. 0.0 0.0 Rig: DOYON 19 Page 40/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/2/2020 08:45 3/2/2020 15:15 6.50 COMPZN CASING PUTB P Ran 4 1/2" liner as per detail - 4 1/2" 12.6 # L-80 HYD 563 - Ran 110 jts of blank liner & 31 jts of Perf liner - Mu torque 3800 ft/lbs - Ran 4 1/2" X 6 1/8" centralizers - 1 per jt. free floating to 5808' SO wt. 98 k Calc displacement 26.14 bbls Actual displacement 21 bbls 0.0 5,808.0 3/2/2020 15:15 3/2/2020 16:15 1.00 COMPZN CASING PUTB P PU Baker Seal bore extension & liner hanger assembly - as per Baker rep. - Mix & pour Xan Plex D - and filled to top of liner tieback sleeve - MU XO & ran 1 std DP to 5882' 5,808.0 5,882.0 3/2/2020 16:15 3/2/2020 17:00 0.75 COMPZN CASING RURD P RD GBR casing runnning equipment & clear rig floor of excess tools & equipment Drift 1 std HWDP in derrick w/ 2.3" drift 5,882.0 5,882.0 3/2/2020 17:00 3/2/2020 17:30 0.50 COMPZN CASING RUNL P Break Circ thru liner hanger assy , 2 BPM 100 PSI - 110k UP 90K DN 101K RotWT - 20 RPM 3.7k TQ 5,882.0 5,882.0 3/2/2020 17:30 3/2/2020 18:00 0.50 COMPZN CASING RUNL P RIH on 4" DP from derrick F/5882' T/6824' - SO WT= 107K 5,882.0 6,824.0 3/2/2020 18:00 3/2/2020 23:30 5.50 COMPZN CASING RUNL P RIH on 4" DP F/6824' T/13633' - S/O WT = 105K 6,824.0 13,633.0 3/2/2020 23:30 3/3/2020 00:00 0.50 COMPZN CASING CIRC P Est Circ @ shoe - pump 20 BBLS @ 3 BPM 390 PSI - UP = 174K DN = 105K ROT = 130K with 20 RPM 9K TQ 13,633.0 13,633.0 3/3/2020 00:00 3/3/2020 02:30 2.50 COMPZN CASING RUNL P RIH w/ 4 1/2" liner on DP f/ 13633' to 16293' SO wt 105k 13,633.0 16,293.0 3/3/2020 02:30 3/3/2020 06:00 3.50 COMPZN CASING RUNL P RIH w/ 4 1/2" liner on 4" HWDP f/ 16293' to 18772'. PU and running 4" HWDP f/ pipeshed. SO wt 113k 16,293.0 18,772.0 3/3/2020 06:00 3/3/2020 07:00 1.00 COMPZN CASING RUNL P RIH w/ 4 1/2" liner on 4" HWDP f/ 18772' to 19298'. PU and running 4" HWDP f/ pipeshed.SO wt 117k. MU 1 std of 4" DP and RIH. Space out liner on depth at 19361'. 18,772.0 19,361.0 3/3/2020 07:00 3/3/2020 08:45 1.75 COMPZN CASING PACK P Prep to set liner hanger & ZXP liner top packer - Establish circ - @ 3 / 3.5 bbls/min @ 600 to 860 psi - Obtain data - PU wt 230 k SO wt. 117 k - Dropped 1.625" hanger setting ball - Pumped down ball @ 4 bbls/min @ 1060 psi - slow to 3 bbls/min @ 590 psi - ball on seat @ 1115 stks. - Pressure up to 2400 psi set 50 k down - hanger set - Pressure up to 3000 psi to release running tool - PU wt 205 k - set 75 k down to set ZXP 19,361.0 19,361.0 3/3/2020 08:45 3/3/2020 09:15 0.50 COMPZN CASING PRTS P Blow down TD - Rig up to IA to test ZXP packer - Unable to pressure up ( confirmed packer not set) RD 19,361.0 19,631.0 3/3/2020 09:15 3/3/2020 09:30 0.25 COMPZN CASING PACK P Reset packer as per Baker Rep - Picked up 7 ' slack off w/ 60 k observed indication packer set 19,631.0 19,631.0 3/3/2020 09:30 3/3/2020 10:00 0.50 COMPZN CASING PRTS P RU to IA - test ZXP liner top packer to 3300 psi for 10 mins. - Good test - RD test equipment 19,631.0 19,631.0 Rig: DOYON 19 Page 41/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/3/2020 10:00 3/3/2020 10:15 0.25 COMPZN WELLPR RURD P RU to circulate 19,631.0 19,631.0 3/3/2020 10:15 3/3/2020 13:15 3.00 COMPZN WELLPR CIRC P Pulled up 22' to place set of liner running tool in liner tie back sleeve - Circ & wash top of liner tie back - pulled up to 13468' - circ hole clean @ 8 bbls/min @ 2700 psi - Pumped and spotted 275 bbls 11.6 ppg Inhibited brine to brine 500' above setting depth of btm GLM @ 8040'. 19,631.0 19,631.0 3/3/2020 13:15 3/3/2020 13:45 0.50 COMPZN WELLPR TRIP P Pulled up 1 std DP f/ 13468' to 13,448' and std back - Blow down TD - Prep to LD drill pipe 19,631.0 19,631.0 3/3/2020 13:45 3/4/2020 00:00 10.25 COMPZN WELLPR PULD P POOH laying down 4" HWDP & 4 '' DP fto 3376'. 19,631.0 19,631.0 3/4/2020 00:00 3/4/2020 02:45 2.75 COMPZN WELLPR PULD P POOH sideways from 3376 to surface. 19,631.0 19,631.0 3/4/2020 02:45 3/4/2020 03:30 0.75 COMPZN WELLPR BHAH P Break down Baker running tools and lay out per Baker rep. Inspected tool dogs and shears that looked appropriate for packer setting shear. 19,631.0 19,631.0 3/4/2020 03:30 3/4/2020 05:00 1.50 COMPZN EVALWB CLEN T Clean rigfloor and stage WL tools, spot truck and bring tools and equipment onto rig. PJSM for rigging up WL. 19,631.0 19,631.0 3/4/2020 05:00 3/4/2020 06:00 1.00 COMPZN EVALWB BHAH T RU WL equipment. PU and MU tractor and sonic tools. 19,631.0 19,631.0 3/4/2020 06:00 3/4/2020 12:00 6.00 COMPZN EVALWB BHAH T Complete assembly of WL tools and tractor. Test tools individually, then in combo. Tools would not test properly when powered back up in combo. Trouble-shot tools, surface power, surface equipment and surroundings for interference. 19,631.0 19,631.0 3/4/2020 12:00 3/4/2020 19:30 7.50 COMPZN EVALWB ELOG T Perform logging run from 13,420' to 8,430'. Delineate TOC at 8,645'. 19,631.0 19,631.0 3/4/2020 19:30 3/4/2020 20:30 1.00 COMPZN EVALWB BHAH T LD wireline tools and RD equipment. 19,631.0 19,631.0 3/4/2020 20:30 3/4/2020 22:00 1.50 COMPZN RPCOMP WWWH P MU stack washer and wash stack. Pull wear bushing and wash stack. LD stack washing tool. 19,631.0 19,631.0 3/4/2020 22:00 3/4/2020 22:45 0.75 COMPZN RPCOMP RCST P RU casing equipment and stage jewelry for running. 19,631.0 19,631.0 3/4/2020 22:45 3/5/2020 00:00 1.25 COMPZN RPCOMP RCST P Run upper completion to 251'. with SOW = 66K. 19,631.0 19,631.0 3/5/2020 00:00 3/5/2020 06:00 6.00 COMPZN RPCOMP RCST P Ran 3 1/2" 9.3# L-80 HYD 563 upper completion to 6833' with SOW = 90K. 217 jt ran of 428 jts to run 19,631.0 19,631.0 3/5/2020 06:00 3/5/2020 12:00 6.00 COMPZN RPCOMP RCST P Ran 3 1/2" 9.3# L-80 HYD 563 upper completion f/ 6833' to 12,838' - SO wt - 91 k 408 jts ran of 428 to run 19,631.0 19,631.0 3/5/2020 12:00 3/5/2020 12:30 0.50 COMPZN RPCOMP RCST P 3 1/2" 9.3 # L-80 HYD 563 upper completion f/ 12838' to 13455' PU wt 123 k SO wt 87k 428 jt ran plus seal assembly - Xn nipple w/ dual flapper valve - 3 GLM's - X nipple 19,631.0 19,631.0 Rig: DOYON 19 Page 42/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/5/2020 12:30 3/5/2020 15:00 2.50 COMPZN RPCOMP RCST P PU space out jts. of 3 1/2" 9.3# L-80 HYD 563 jts 429, 430, 431 - Located w/ 1.50' in on jt # 432 LD jt 432 - MU pup jt & TIW valve - close annular & pressure IA to 200 psi (confirmed seals in SBA) strip up thru annular observed pressure drop as seals cleared SBA - LD pup jts & space out jts 431, 430, & 429. 19,631.0 19,631.0 3/5/2020 15:00 3/5/2020 16:00 1.00 COMPZN RPCOMP RCST P MU space out pups 3 1/2" 9.3# L-80 HYD 563 ( 9.85 & 1.94 - OX ) 3 1/2" Hyd 563 (P) x 4 1/2" Hyd (B) - 1 jt 4 1/2" 12.6 # L-80 Hyd 563 - Cameron tubing hanger - MU landing jt - Land tubing hanger - SOW = 85K Tub tail @ 13547' (Space-out = 3.62') - XN nipple @ 12,600' - GLM # 1 7622' - GLM # 2 4247' - GLM # 3 w/ SOV 2605' - X nipple 2149' 19,631.0 19,631.0 3/5/2020 16:00 3/5/2020 17:00 1.00 COMPZN RPCOMP RURD P RU test equipment to test tubing & annulus Simops - Pressure test tubing hanger seals to 5000 psi for 15 minutes - Good test - Test witnessed by CPAI rig supervisor. 19,631.0 19,631.0 3/5/2020 17:00 3/5/2020 18:00 1.00 COMPZN RPCOMP PRTS P Pressure up on tubing to 3500 psi - Observed small leak on sensor - bleed off pressure - repair leak -Pressure up & tested tubing to 3500 psi for 30 minutes. 19,631.0 19,631.0 3/5/2020 18:00 3/5/2020 19:30 1.50 COMPZN RPCOMP PRTS P Bleed off tubing to 2000 psi - Pressure up on IA to 3300 psi for 30 minutes (good tests). Bled off IA to 0 - bled tubing off to 0 psi. Pressure up on IA to 2500 psi to shear SOV without success. Pressure up IA to 3000 psi and tubing to 2500 psi simultaneously. Bled off tubing and observed SOV shear. 19,631.0 19,631.0 3/5/2020 19:30 3/5/2020 19:45 0.25 COMPZN RPCOMP OWFF P Observed well for flow; Static. 19,631.0 19,631.0 3/5/2020 19:45 3/5/2020 20:45 1.00 COMPZN WHDBOP P Installed BPV and pressure tested to 2500 psi for 10 minutes; charted. 19,631.0 19,631.0 3/5/2020 20:45 3/5/2020 22:15 1.50 COMPZN WHDBOP NUND P ND MPD equipment and flowline with SIMOPS; changing the saver sub on top drive. 19,631.0 19,631.0 3/5/2020 22:15 3/6/2020 00:00 1.75 COMPZN WHDBOP NUND P Clean and clear rigfloor, RD drip pan and flow line box. 19,631.0 19,631.0 3/6/2020 00:00 3/6/2020 07:00 7.00 COMPZN WHDBOP NUND P ND MPD equipment. ND BOPE and traverse stack to stump and secure. SimOps: CO saver sub, clean pits and pump off fluids. 0.0 0.0 3/6/2020 07:00 3/6/2020 09:15 2.25 COMPZN WHDBOP NUND P PU tree adapter. Attempt to NU production tree (incorrect assembly orientation per 3H DSO). Send to valve shop to reconfigure and test. PT hanger void/hanger flange adapter to 5000 psi; good. MU wellhead flange to OA. RD choke line and secure for move. RD flow lines and secure for move. Install mouse hole, start to LD 4" drill pipe. 0.0 0.0 Rig: DOYON 19 Page 43/43 3H-35 Report Printed: 4/8/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/6/2020 09:15 3/6/2020 12:00 2.75 COMPZN WHDBOP PULD P Continue to LD 4" DP from derrick. 52 stds LD 9 Stds/hr. 0.0 0.0 3/6/2020 12:00 3/6/2020 17:30 5.50 COMPZN WHDBOP NUND P Receive and install tree as per Cameron rep. PT tree to 250 psi for 5 minutes, 5000 psi for 15 minutes to chart. 0.0 0.0 3/6/2020 17:30 3/6/2020 18:30 1.00 COMPZN WHDBOP NUND P Pull H BPV from wellhead and RU to freeze protect. 0.0 0.0 3/6/2020 18:30 3/6/2020 20:45 2.25 COMPZN WHDBOP FRZP P Hold PJSM for Freeze Protect. Pump 95 bbl of diesel for freeze protect. Continue to LD 4" DP from derrick. (19:00) 0.0 0.0 3/6/2020 20:45 3/7/2020 00:00 3.25 COMPZN WHDBOP FRZP P Line up to U-tube FP. Initial pressure 600 psi. Bled down pressure and 400 psi was stable on both IA and OA. Cameron wellhead tech went to get lubricator to perform work under pressure. Continue to LD all 4" drill pipe. Pull all lines dry in cellar with Vac truck. 0.0 0.0 3/7/2020 00:00 3/7/2020 02:00 2.00 COMPZN WHDBOP OTHR P Cameron wellhead tech installed lubricator to perform work under pressure. Pressured up on lubricator and found leak on 7" Otis cap. Pulled cap and changed O-ring and re- installed; good. Installed H BPV. RD lubricator and secured wellhead. 0.0 0.0 3/7/2020 02:00 3/7/2020 04:00 2.00 DEMOB MOVE DMOB P Continued to RD rig electrical lines and cables. Rig down steam lines and picked up staris and walkways. Released Rig 04:00 3/7/2020 from 3H35. 0.0 0.0 Rig: DOYON 19 &RQRFR3KLOOLSV$ODVND,QFB.XSDUXN ! 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(4#.B5.%)>.(%0*32-71',+!9 ;;+-; !2'+2* '7-55+'- 2!71*1+9* &-7!;'+52'7;9-+51 *712!72'*+'9 9;-75,!+!* 2+;9 2*71;5+2* (4#.B5.%)>.(%0*32-72'5+2; -1+*2 !1;+,* '7-55+-5 2!725!+;! &-79''+,1'7;9-+'! *712!752-+-5 9;-7515+;- *+-* 2*72,9+-9 (4#.B5.%)>.(%0*32-759'+;* -1+'' !29+92 '7-52+-; 2!72;'+-; &-7'5'+,!'7;9;+'- *712!75;5+1; 9;-72!5+;, *+1! 2*75**+9* (4#.B5.%)>.(%0*32-7!!;+9* ;-+*1 !2*+*1 '7-52+;' 2!75'5+1! &-7'-1+*!'7;9;+9* *712!7!9;+2! 9;-71*;+11 5+'; 2*7!';+1- (4#.B5.%)>.(%0*32-7!'9+1' ;-+99 !2,+1! '7-52+-- 2!75*!+91 &-7*12+!1'7;9;+*1 *712!7!'-+'1 9;-71',+!! 5+-9 2*7!,!+', (4#.B5.%)>.(%0*32-7!*2+11 ;-+99 !2,+1! '7-55+1' 2!75*;+9; &-7*1*+1!'7;9;+** *712!7!*9+'; 9;-71'5+*1 1+11 2*7!;1+9, 6D##*&!?9A92?5A2-7!;!+11 ;-+99 !2,+1! '7-55+5, 2!75;9+'; &-7*52+1!'7;9;+;; *712!7!;1+*; 9;-71!,+*2 1+11 2*7915+!5 6D## 2-7!*2+11;-+99!2,+1!'7-55+1''7;9;+**2!75*;+9;&-7*1*+1!*712!7!*9+';9;-71'5+*11+112*7!;1+9, 6D##*&!?9A92?5A Page 1/1 3H-35 Report Printed: 4/14/2020 Cement Detail Report Cement Details Description Surface Casing Cement Cementing Start Date 2/3/2020 22:30 Cementing End Date 2/4/2020 04:30 Wellbore Name 3H-35 Comment Cement 10 3/4" casing - Pumped 60 bbls of mud push spacer @ 10 ppg treated w/ red dye & 5 # Pol-E -Flake - Dropped bottom plug - began pumping Lead slurry @ 11 ppg. Initial circulating rate 3 bpm- worked up to 5 bpm.Continue cementing 10-3/4" casing. Per cement detail. Reciprocate casing. while cementing up wt. 194k. down wt. 147k. Pumped a total of 500 bls. lead cement and lost returns. Completed pumping 11.0 ppg lead cement total volume lead - 525 bls. Pumped 57 bls. 15.8 tail cement. Drop top plug 10 bbl water to flush. Displace with rig pumping 9.6 ppg. spud mud total mud pumped 283 bls. Total displacement volume = 293 BBL. Initial rate 6 bpm slowed to 3 bpm held until plug bumped at 2,828 strokes. As expected per calculated displacement. FCP 550 psi build to 1,100 psi. Hold for 5 min. Floats holding. CIP at 04:45 2/4/2020 Cement Stages Stage # 1 Description Surface Casing Cement Objective Top Depth (ftKB) 130.0 Bottom Depth (ftKB) 3,159.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 5 P Pump Final (psi) 550.0 P Plug Bump (psi) 1,100.0 Recip? Yes Stroke (ft) 15.00 Rotated? Yes Pipe RPM (rpm) Tagged Depth (ftKB) 130.0 Tag Method 1" top job pipe Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost returns with 500 BBL pumped. tagged top. Decision made to perform top job. Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 130.0 Est Btm (ftKB) 2,650.0 Amount (sacks) 1,130 Class G Volume Pumped (bbl) 526.0 Yield (ft³/sack) 2.61 Mix H20 Ratio (gal/sa… 12.50 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,650.0 Est Btm (ftKB) 3,150.8 Amount (sacks) 275 Class G Volume Pumped (bbl) 57.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.05 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/22/2020 00:00 Page 1/1 3H-35 Report Printed: 4/14/2020 Cement Detail Report Cement Details Description Surface Top Job Cementing Start Date 2/4/2020 13:30 Cementing End Date 2/4/2020 18:45 Wellbore Name 3H-35 Comment Performed top job w AOGCC witness Adam Earl. Tagged TOC at 130 ft w 1" pipe. Pumped entire tob w/ string at 120 ft. 22.5 BBL water to flush. 11PPG cement pumped. Cement returns to surface after 20 BBL pumped, good cement to surface after 25 BBL pumped. 34.0 BBL total cement pumped. Cement Stages Stage # 1 Description Surface Top Job Objective Perform top job w returns to surface Top Depth (ftKB) 36.8 Bottom Depth (ftKB) 130.0 Full Return? No Vol Cement … 16.0 Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 2 P Pump Final (psi) 430.0 P Plug Bump (psi) 430.0 Recip? No Stroke (ft) Rotated? No 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 (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface Top Job Job: DRILLING ORIGINAL, 1/22/2020 00:00 Page 1/1 3H-35 Report Printed: 4/14/2020 Cement Detail Report Cement Details Description Intermediate Casing Cement Cementing Start Date 2/22/2020 13:00 Cementing End Date 2/22/2020 17:00 Wellbore Name 3H-35 Comment HES pump 60 bbl Tuned spacer = 12 ppg, 3.18 yield, 20.0 gal/sk with 30 bbl LCM blended in. 4 BPM = 843 psi. Pump 247 bbl Lead Cement = 1125 sks, 15.5 ppg, 1.20 yield, 5.33 gal/sk, with .25 lb/bbl WellLife mixed in on the fly. 4 BPM = 750 psi. Pump 40 bbl Tail Cement = 20 sks, 15.8 ppg, 1.16 yield, 4.97 gal/sk, with .25 lb/bbl WellLife mixed on the fly. 4 BPM = 634 psi. Drop top plug. Verified by Co-man. Kick out plug with 10 bbls water. Swap to rig pumps. Rig pump chase with 619 bbls of 11.4 ppg LSND mud from pits. ICP = 230 psi at 7 BPM. FCP = 710 psi at 2 BPM. Bump plug at 6027 strokes. (pumpout put of .1028 bbl/stk -98%) Pressure up to 1200 psi and hold 5 min. Bleed off and check floats = Good CIP @ 17:00, 2/23/2020 Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Top Depth (ftKB) 8,645.0 Bottom Depth (ftKB) 13,673.0 Full Return? No Vol Cement …Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 7 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 4 P Pump Final (psi) 700.0 P Plug Bump (psi) 700.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 60 BBLS 12 PPG tuned spacer , 247 BBLS 15.5 PPG lead cmt , 40 BBLS 15.8 PPG tail cmt, good lift pressure. Bump plugs , floats holding Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 10,223.0 Est Btm (ftKB) 13,096.0 Amount (sacks) 1,125 Class G Volume Pumped (bbl) 247.0 Yield (ft³/sack) 1.20 Mix H20 Ratio (gal/sa… 5.33 Free Water (%) Density (lb/gal) 15.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 13,096.0 Est Btm (ftKB) 13,640.0 Amount (sacks) 220 Class G Volume Pumped (bbl) 40.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 4.97 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/22/2020 00:00 21go64 322.0 Letter of Transmittal Baker Hughes :�l Date: March 24, 2020 To: From: Abby Bell Michael Soper AOGCC Baker Hughes 333 West 7`" Ave, Suite 100 1 I 795 East 94'h Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H-35 RECEIVED MAR 2 4 2020 AOGCC (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Michael Soper Baker Hughes Applications Engineer Michael.Soper@bakerhughes.com V ic 0 S N O N O p o0 0=_ 0 m �T ,w (n p � C C ■ 000 CA) ii1 / 0 O Q■ C /♦� CD �■ Z v, ✓� M — CD oml � 0 X r. 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w W N W m t0 IV m m m m N A m W A N m V J Ut W Ol O O G C J N O N a W N O Ot O a J a O m J A N Ot m W p N A m �• A N O w m m N m (0 A m N A J m O m m O W O N W O A O C1 (p ro o 0 O o_ o_ A A �D t0 A A A fp t0 t0 A A (O (0 A A A A A (0 t0 A A A A A (0 A A A (0 A A A A A (D A A A A A A L m T m m m M M M V<0 cp (D 1 1 1 1 1 1 1 V V V V V V m A a m m m m J J m 00 (0 t0 O O N N W W W A A N m m T J J m J 1 D D r2 m N m m 0 � N N O m N O J m A W N O m � W t0 O) W t0 J A IO N O �I O do W 3 D w ^d O1 0 V V N N N C (O co O O O O O O O O O O O O O O O O O O -+ O O -� O W A m N A m y C 0 W m Cl) G) (D N N J m N A m (0 fp tO m f.J m N W O N W A m O :NO fnl N m O (O A CJ � W A W N (0 IV O) W O W W V m m fJi N m m W O m O W W O O O' N `C1 m ,GY C V V A A A A W W W W W W W W W W W N N N N N N N N N N N N -+ y ro W W N W A (WJi Om1 m J m (a0 O O r N W d (ml� (JJi J m fN0 W O m N W A m a) m <: O O C co C -- m m m N A N A N N W m O m O W J Ut W Ol O O O m 0 O m J N O N a W N O Ot O a J a O m J A N Ot m W p N A m W J O O Ol A W A m Ot Vt t0 a Ut J m o 0 o_ o_ + + + + + + + + + + + + + + + + + + + + + + + + + + + + + i + p N D D > m m m D D D m W D D N m N D D D m > D D m m D D > > W D D D W > m D D D m m m D D D m > D D m D m m N N D D D D m D Z + + 3 3 + + + 3 3 co + + 3 + + + 3 3 3 + + + + 3 + + + + + + 3 + + + 3 3 3 + + 3 3 + 3 + + + + 3 3 3 3 + a m U) m fA co m U) 0) m U1 OJ U1 m U) N m U7 U7 U) m m U) N m m m V7 m m (A ro m (n (n OA m In N fn� v N v v N v v v v v v v v (n — N N A A A A A A D 0 0 v o' m i c m m m W N m m m m N m m m m m m N N m m m m A A A A A A A A a a a A fJ W W y Z WN O m m V V m A m N N A W (,J N O t0 t0 m N A m N W V W O N m O N A m m O j m m m m m O O O N lD SO m W J m A W N O O O N N SiOj W N O W N m J m W 4l W A A O N N m m A O A m V m N m V N O m m m N 1D W m O W A A J m (D m m m m N m SD A N O A — o m tD A tD .. 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A O O m V N m SO O m N A m tO m N m m m W m A J O m A A A mm pl . m m tO J J ul W m V N N W N A SD m W V O SD (D N tO a W m O O m D D "� y O m N N W W oN N W m O T N SAO m N Om0 W V N ll m O. m m .Cmo m m m O O m m m IJ DC d M N (m N v W W A m to W -� -• (7l -� � m W OD O O W 3 C) C 01 C pl W J J CD m A A m N m W m O m V N m V m J W W m m A W W m (O C N m m A a A A A A A A A A A A A A A A A A A A A A A A A A A A G O A O N O O tO Sp m W t0 W 0 CD M m J CD m A N W O J V m m A V � m T O V m m m W m N m N N m A N N m A A O W N A A W W y� t0 .i y C SO co C U tD �• O m OD a VD7 N O IJ W O O O A CJ V1 V W Ul O A N (J O CD fp V 0 0 0 0 0 0 0 0 o y m m w m N W m (J IJ A N � m J O SO N A N W CJ m N m N A V A N O m m m W m O O O A A J m m J m A CD @P < J V J A A A A A A A A A A A A C S N m m N N Sn N m (T (n A A A A A A fA W A fd m m m m J V J (� V W j O O O O m m y A N O (Jl N m N N o W A A m J A m A A W N O m Wp� W A W M GG N N O SO A m m V m m v m N N (O O A "�_. O C! O SWD C SWD C N T A N O V N A N O (O V N A N O SO V m A N O SO J N a N O m O J O A J m W A m O m A N W A m m W W V m m N W W W O w m m m N m m m m m m N N m m m m A A A A A A A A a a a A fJ W W y Z WN O m m V V m A m N N A W (,J N O t0 t0 m N A m N W V W O N m O N A m m O j m m m m m O O O N lD SO m W J m A W N O O O N N SiOj W N O W N m J m W 4l W A A O N N m m A O A m V m N m V N O m m m N 1D W m O W A A J m (D m m m m N m SD A N O A — o m tD A tD (J fJ Ll fa IJ W W W W W W Gl W W N N N N N N N N N N N N N N N N N a m C O 0 0 m N <Jt A A W W N N O O O m m m W V V V m m m A A W W � NSp A.Z1 Q W A O O m m OD A SWV S Ay(DW Om � Om Wm Wm WN Nm J0 Nm MW Dl ^ WO J m Om WZ 0 D OmO O d m n A 7 (D m U) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o Q 3 7 eD _ o m O m o O o m m m O m o O m m o O m m o m 0 0 m m 0 0 m N 0 (1l 0 0 0 A a a 0 0 0 A A A 0 0 A A 0 0 0 A A A 0 0 A W 0 m W Z N A A A m m O N Ul 4) O) A V m m W N O N A A A A W m W O O W J N J SO V m m W N m V m J m m m W N t0 SO m J (O m m m S N N W O m N O V O O m m J tD N N O N m N J N SO N � O 7 A N V W W m m m O O O O tO O m m O N W N W m m G 0 " o A A A A A A A A A A A A a s a A a s A A A A a A A A A A A A A mm cn O to m to IT m N N ul W <n m w A cn vl A (Dl N m m m m m to m V cn V <n �n �n w m (O Sn m rn w O O rn m O m m m N N m m w W m m A ""' Ill D D m A O m N N W W oN N W m O T N SAO m N Om0 W V N ll m O. m m .Cmo m m m O O m m m IJ p m m M N (m N v W W A m to W -� -• (7l -� � m W OD O O W 3 C) C 01 C pl W J J CD m A A m N m W m O m V N m V m J W W m m A W W m (O C y 3 La m p w N .i y C SO co o O o 0 0 o O O O O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o y m m w w m N W m (J IJ A N � m J O SO N A N W CJ m N m N m N m O m J N W W N d N N m tJ j td m tD m j m m W m m V N W m m m "= O C 0) m 0) m CD @P < J V J V m m m m m m m m m m m N N m m N N Sn N m (T (n A A A A A A fA W A fd W m O m m m V m m J m N m O W N N W A O m m m m J m m m m m m O W N � N j A O SO A m m V m m v m N N (O O A "�_. 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O SWD C SWD C O m m j m J m A W N W tp A SO IJ �I DD O N A A N N m O m m SO N v m NPD m (D O W O W m m m Q7 A m m A W m (O O O O m SO m_ m m O J O A J m W A m O m A N W A m m W W V m m N W W W O w O 0 + + m ++ + m + + + + m m m m + m + + m m + + m m + m + + m m + + m m + m + + + m m m + + + m m m + + m m + + + m m T + + + + m + W + + + + W W N + W + + W W + + W W + m + + N W + + W N + + + + m m + + + m N m + + m W + + + m m W + + W + Q W D D > D D D D D D D D D D D D D D > D > D D D D D D D D D D D > D D D Z . cD . . . m 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 C, m m m m m m m m m m m m m m m m m m m m m m m m m m N m m Ul m m D 0 v 0 a 0 c a0 N IQ (D V m S+ m m m V V V J V J J J J J J J V m m m m m m m m m y Z m m W A W N O cD m m J m N N A W N O N m V V mUt A W W m Ot V (O W m m OJ N A m O N A pp�� m O N A m m O N a m m O N m N m m A O J O A m m N N m N m V m N O m m m O N A m N (0 W A N W m A N m O A N A V m N m O — N m m N m A V N m N N f ym v v, o g g 0 m 0 la b b A A A A a A A m m A m A m A a V V s W a 0 i0 b S b L> W W W W W W W = m m N c p v O A W W m N V j m O N (0 A m W V N m j C (� O w O O O N V] O O t0 m m V V m m pf W m W W m (0 O y Q m m O W " C n J N CD W W m W W OAD W m V W W m N W W y S !p ril (D .(00 m O .n.. y O m J m m A W N O m m m V m N A W N _ O (D m V m (I( A W N O M m N N N W O V m m m OJ A N m m m V V m m (O DJ O O (p ei (C V W V A t0 A O (J( O) O co N W W O O O O O O O O O W m m fp A V N N W O m V a W O J J A O J V N W V W UJ W O O N w110 O V m N m N N m V t0 N CD O W W V m m N m O m m m (0 m m O tp m m m m m m rn rn m m O m rn m m rn S CL O '« ' @ d � Cl)Cl)m -. O O O O O O O O O O O O O O O O O O O O O O O O O O O O TV O 020 3 m m <D (O (O (D m � T O O OD m V v O m m O O m m A O O D OD O m O O OD m � O J O O J J O J O O J J O O V V O O V V O V 8 W W W % 7, C) TV V V mA V (V!( V V N A J J J V V V V V V V V V V V J J V J J V V V V V V V O S = = C C O m A m m m V m m m W W A v DD O p m (O N O O N N N W W W N N O N O W A m O A V m V � m W m O W N m W N N m (0 t0 (0 A W m V V (0 m t0 CT V U 0 N C C �•�/ 3 3 3 3 3 3 3 3 ca 0 0 5�5 535 s�s 535 gg� 535 535 g3g S3S 535 535 535 n (D - N O 535 535 535 535 o d 3 7 a a 7 d v d d d d d d a d d 0 m m + T + + T T + + T T + + T T + + + T T T + + T T + + T T + + + �7 T TI + + + T T T + + T T + T + T + + T T + T + + T + + + T T + m + T Y` y N N m a N c W N o m N N m (o N v, N o N N m m N (n W W 0 W W W 0 0 0 W 0 W W 0 0 W W 0 0 W 0 W 0 W W 0 0 W 0 W 0 W W 0 0 W N 0 + + W m + + + m m + + + m m m + + W a C C D + W + W + + m> + C U) D D D D D > D D D D D D D D D > D D D D D D > D D D D D D D D D D D Z . 7 . + 7 7 + + . . . . . . . . . + + . . . . . . . . . . . . . . + l n + + d . 3 X 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 39 3 39 3 3 3 3 3 3 3 3 3 3 d 7 10 V V V V V N O m m m Ut m j m O U V7 m m N W N A O m A A A N W O W m W W N W j m m W N m A m V V N V N OD W (O Ul _ J W m A O 91W p (O OJ W N � JJ VON m m m m N O 0 NAJ J (O N WO N J m N 0 e'C R t/f Cl) J m m m N N m S+ m m m V V V J V J J J J J J J V m m m m m m m m m y Z m m W A W N O cD m m J m N N A W N O N m V V mUt A W W m Ot V (O W m m OJ N A m O N A pp�� m O N A m m O N a m m O N m N m m A O J O A m m N N m N m V m N O m m m O N A m N (0 W A N W m A N m O A N A V m N m O — N m m N m A V N m N N D 0 0 m 0 o � 0 m x c m m ym v W 01 W W m J W W J m W W m 0 W a a 0 O O N b la b b A A A A a A A m m A m A m A a V V s W a 0 i0 b S b L> W W W W W W W = m m N c p v O A W W m N V j m O N (0 A m W V N m j C (� O w O O O N V] O O t0 m m V V m m pf W m W W m (0 O y Q m m O W N OND C N N J N CD W W m W W OAD W m V W W m N W W y S !p ril (D .(00 .(WO .OD W N v1 m O y `G w (D 0 n m N N m W O V m m m OJ m W V N m m m V V J m W O J (p ei (C jp N O C 7 O O co N W W O O O O O O O O O O O O O O n O O O O < O 0 0 0 0 y A N V N W V W UJ W O O N w110 A A A O (a0 N O O A OV N D) (D O CD N a, a> m m m 9) m m 0) m m m m m m m m m m rn rn m m m rn m rn m m rn S CL O '« ' @ d � Cl)Cl)m -. O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O 020 3 m m <D (O (O (D m � T O O OD m V v O m m O O m m A O O D OD O m O O OD m � O J O O J J O J O O J J O O V V O O V V O V 8 O O V V O m O O m m O O m m m O m O O m m 1-0 N W A a aI Z CD v 3 m O N m A m W w (O N W O Ol J W (O m m W J m m m J OJ � A W W N m m (O O A m m m m m O J N A (T m A A m O aD A m m A W N 10 - W m V m p O N W .T 9) A v DD O p m (O N O O N N N W W W W a s A N S _ W m J 8 A m V A (O J mm A V � m W N V m m N m W O m (0 m A � A N W m W W m (J( V N J m WW A N m m m V 0 w m N O m t0 CT V C d j 3 3 3 3 3 3 3 3 ca 0 0 5�5 535 s�s 535 gg� 535 535 g3g S3S 535 535 535 n (D - N 53g 5�5 535 535 535 535 o d 3 7 a a 7 d v d d d d d d a d d 0 m m + T + + T T + + T T + + T T + + + T T T + + T T + + T T + + + �7 T TI + + + T T T + + T T + T + T + + T T + T + + T + + + T T + m + T Y` D 0 0 m 0 o � 0 m x c m m ym W 01 W W m J W W J m W W m 0 W a a 0 O O a A A A N A A A N W W A A A A a A A m m A m A m A a V V s W a 0 i0 m D D S A (0 A CO W m N V N m -+ m O A W W m N V j m O N (0 A m W V N m j C (� O V m J A N (O m m W N V] O O m N J m O OJ N V7 W V N N A A m W m N m W V V N m W m W W m (0 O W m m W A m m W (0 m O W O C C = D 3 rn rn w ^ N G (JO (JO N O co N W W O O O O O O O O O O O O O O O O O O O O O O O O 0 0 0 0 y A N V N W V W UJ W O O N w110 A A A O (a0 N O O A OV N (NO O J N CL O @ @ < V J c0 N (0 (O N m m <D (O (O (D m m m m m m OD OD m m m V V V V J V J V y V ,,,� m W W W m m N O N j A A U m V m (mD O N N W A a mJwO N W A L(: C! co C c L m J Ut m A W N O (O m �I V V m N A N N N W O t0 aD OD J m m A W N 10 c0 (O fJ( W N N m A N N m m O m V O m W m m m m 0 O m O m A N O O 3 3 3 3 3 3 3 3 3 ca 0 0 5�5 535 s�s 535 gg� 535 535 g3g S3S 535 535 535 S�S 53g 5�5 535 535 535 535 o d 3 7 a a 7 d v d d d d d d a d d v m m + T + + T T + + T T + + T T + + + T T T + + T T + + T T + + + �7 T TI + + + T T T + + T T + T + T + + T T + T + + T + + + T T + m + T Y` + W + + m m + + W + + W W i + + W W W + + m W + + W m + + + m m + + + m m m + + W + N + m + + W W + W + W + + m> + C U) D D D D D > D D D D D D D D D > D D D D D D > D D D D D D D D D D D Z . 7 . + 7 7 + + . . . . . . . . . + + . . . . . . . . . . . . . . + l n + + d . 3 X 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 39 3 39 3 3 3 3 3 3 3 3 3 3 D 0 0 m 0 o � 0 m x c m m N 2 co n n Co CoO O O Vt rm c 'n m m m m m c0 tD c0 c0 t0 (0 cD f0 c0 (0 (D fD to m m tD m m m m m m V V V V a J t0 t0 O) m O O O O O N O p O O p ID O N W O V D) m m v 0 N N m t0 c0 c0 W A N A co O c0 Ip f0 m V A A N V N m O N W a J V O m N N N A m A m m N m m m N m m A m N OD W 1p f0 O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N ' ID c0 t0 {p <O c0 t0 cp t0 t0 (D t0 t0 f0 f0 t0 c0 t0 cD (0 t0 t0 (0 c0 tp t0 ID m m m m N C N N N N N W W W W W W W W W N O m m A N x m V O A V m A W W W N V DD a m A N O m (0tJ O W m W W c0 N J N O N W m w N m W N N N V O N V V V N W V W W O W m m N N A O N w O (O V m m N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N C S m m m m m m m m m m m m m m m m m m m m m 00 m m m m m m V V V a A A W W W W W A a a a m m . 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' ov O` v 3S 0 d S3 d 53 g3 d d S3 d S3 g� 535 535 d d a a g3g y a 0 m 0 m m m + + + + + + + + + + � � X X X A X X X X A � 1 _ m O m N O N N . N N . . N . N N N N rn . . r. N O . .: 0 o D D D D D D D D D D Z C) 0 G) 0 G) G) G G) 0 � 0 0 3 In m m m m m m m m m m - n w � � � o Xco N A U O_ N pp O o N Ul _ co G C 10 m PTD a/9—a64)_ Loepp, Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Tuesday, March 3, 2020 10:35 AM To: Loepp, Victoria T (CED) Cc: Hobbs, Greg S Subject: RE: [EXTERNAL]KRU 3H-35 Intermediate Casing Cement Evaluation Log Follow Up Flag: Follow up Flag Status: Flagged That's what I assumed. We're already in the process of trying to mobilize wireline to the rig. I just wanted to confirm and let you know what was going on. I'll send you the log when it's available. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 -----Original Message ----- From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 03, 202010:29 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Evaluation Log Marti, Yes, a cement log is required, especially considering the losses during the job and the fact that this is an injector. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria.Loepp@alaska.gov SCANNED MAR 1 91010 1 SCANNED MA4 19 �nlQ -----Original Message ----- From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Tuesday, March 3, 2020 10:16 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Evaluation Log Hi Victoria I was just about to email you. Schlumberger just informed me that they have not been able to get any data off of the memory card that came out of their sonic tool. So, as it stands now, we do not have a cement log. Do we need to run a CBL before we run our upper completion? I believe that's the only way we'll get a cement log on this well. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 -----Original Message ----- From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 03, 2020 10:09 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Evaluation Log When will the cement evaluation log be available? -----Original Message ----- From: Loepp, Victoria T (CED) Sent: Monday, February 24, 2020 6:17 PM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: Re: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job Marti, Approval is granted to proceed. Thanx, Victoria Sent from my iPhone > On Feb 24, 2020, at 4:06 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: > Hi Victoria > We should be drilling out early tomorrow morning. Do we have approval to proceed? > Thanks > Marti > Marti Titus > Staff Drilling Engineer > Office: 907-265-1192 > Cell: 713-494-8198 > -----Original Message----- • From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> > Sent: Monday, February 24, 2020 2:07 PM > To: Titus, Marti N <Marti.N.Titus@conocophillips.com> > Subject: Re: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job > Marti, > A cement squeeze may be required. > Is CPAI confident in this cement job or should a CBL be run to determine cement quality and placement now. I would discuss internally. > Thanx, > Victoria > Sent from my iPhone >> On Feb 24, 2020, at 2:01 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: >> Thanks Victoria. We will log free pipe as well. We plan on logging from 7500' to 11500' MD. >> Out of curiosity, what remediation would the AOGCC require if our TOC is not above the Moraine? I haven't had this happen as I'm still relatively new to Alaska so just want to know for my own information. >> Are we okay to drill out and proceed with drilling the production interval? >> Thanks, >> Marti >> Marti Titus >> Staff Drilling Engineer >> Office: 907-265-1192 >> Cell: 713-494-8198 >> -----Original Message----- » From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >> Sent: Monday, February 24, 2020 1:57 PM >> To: Titus, Marti N <Marti.N.Titus@conocophillips.com> >> Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job >> Marti, 3 >> If the sonic indicates poor or inadequ-,e intermediate cement, the AOGCC may r,,,uire remediation. As noted in the PTD conditions of approval, the Sonic must log free pipe as well as log the TOC. >> Thanx, >> Victoria >> Sent from my iPhone »» On Feb 24, 2020, at 1:49 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: >>> Hi Victoria, >>> We plan on running the Sonic tool in our production hole BHA like we did on the 3G wells. It will be logged in memory so we will not have the results until we TD the production section (unless we have to trip sooner for some other reason). >>> Thanks >>> Marti >>> Marti Titus >>> Staff Drilling Engineer >>> Office: 907-265-1192 >>> Cell: 713-494-8198 >>> -----Original Message ----- >>> From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >>> Sent: Monday, February 24, 2020 1:01 PM >>> To: Titus, Marti N <Marti.N.Titus@conocophillips.com> >>> Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job >>> Marti, >>> Is a cement evaluation log planned to determine cement placement before proceeding? If the LWD cement evaluation log shows inadequate cement, remediation may be required on this injector. Let me know your plans for cement evaluation logging. >>> Thanx, >>> Victoria >>> Sent from my iPhone »»> On Feb 24, 2020, at 11:04 AM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: U Loepp, Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Thursday, March 5, 2020 11:55 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 3H-35 Int TOC Approval Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria. Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, March 05, 202011:41 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: [EXTERNAL]KRU 3H-35 Int TOC Approval Hi Marti, I have the info. The log looks good. Approval to proceed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp(4-alaska.gov From: Loepp, Victoria T (CED) Sent: Thursday, March 5, 2020 2:34 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: KRU 3H-35 Intermediate casing TOC Marti, Please send current WBS showing depths of intermediate shoe, HC sand tops. Thanx, Victoria Sent from my Whone On Mar 4, 2020, at 10:55 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: Hi Victoria Please find attached the CBL for the intermediate casing on 31-1-35. Estimated TOC is 8645'. Please let me know if you have any questions. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 <31-1-35 RBT 4MAR2020.pdf> Loepp, Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Wednesday, March 4, 2020 10:55 PM To: Loepp, Victoria T (CED) Subject: 31-1-35 Intermediate casing TOC Attachments: 31-1-35 RBT_4MAR2020.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria Please find attached the CBL for the intermediate casing on 31-1-35. Estimated TOC is 8645'. Please let me know if you have any questions. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 P7 -D.2/9 - oro-+ Loepe, Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Monday, February 24, 2020 4:06 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria We should be drilling out early tomorrow morning. Do we have approval to proceed? Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 -----Original Message ----- From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, February 24, 2020 2:07 PM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: Re: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job Marti, A cement squeeze may be required. Is CPAI confident in this cement job or should a CBL be run to determine cement quality and placement now. I would discuss internally. Thanx, Victoria Sent from my iPhone > On Feb 24, 2020, at 2:01 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: > Thanks Victoria. We will log free pipe as well. We plan on logging from 7500' to 11500' MD. > Out of curiosity, what remediation would the AOGCC require if our TOC is not above the Moraine? I haven't had this happen as I'm still relatively new to Alaska so just want to know for my own information. > Are we okay to drill out and proceed with drilling the production interval? > Thanks, > Marti > Marti Titus > Staff Drilling Engineer > Office: 907-265-1192 > Cell: 713-494-8198 > -----Original Message----- • From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> > Sent: Monday, February 24, 2020 1:57 PM > To: Titus, Marti N <Marti.N.Titus@conocophillips.com> > Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job > Marti, > If the sonic indicates poor or inadequate intermediate cement, the AOGCC may require remediation. As noted in the PTD conditions of approval, the Sonic must log free pipe as well as log the TOC. > Thanx, > Victoria > Sent from my iPhone >> On Feb 24, 2020, at 1:49 PM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: >> Hi Victoria, >> We plan on running the Sonic tool in our production hole BHA like we did on the 3G wells. It will be logged in memory so we will not have the results until we TD the production section (unless we have to trip sooner for some other reason). >> Thanks >> Marti >> Marti Titus >> Staff Drilling Engineer >> Office: 907-265-1192 >> Cell: 713-494-8198 >> -----Original Message----- » From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >> Sent: Monday, February 24, 20201:01 PM >> To: Titus, Marti N <Marti.N.Titus@conocophillips.com> >> Subject: [EXTERNAL]KRU 31-1-35 Intermediate Casing Cement Job >> Marti, >> Is a cement evaluation log planned to determine cement placement before proceeding? If the LWD cement evaluation log shows inadequate cement, remediation may be required on this injector. Let me know your plans for cement evaluation logging. >> Thanx, 2 >> Victoria >> Sent from my Phone »» On Feb 24, 2020, at 11:04 AM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: 31-1-35 Kuparuk A Sand Injector 7-5/8" Intermediate Casing Cement Job Summary Cement Job Overview • Pumped: 0 60 bbls of 12.0 ppg spacer with 0.5 lbs/bbl LCM @ 4-5 bpm 0 247 bbls 15.5 ppg lead cement with 0.25 Ib/bbl WellLife LCM @ 4 bpm 0 40 bbls 15.8 ppg tail cement with 0.25 Ib/bbl WellLife LCM @ 4 bpm 0 10 bbls of water • Displaced with 619 bbls of 11.4 ppg LSND mud @ 4-7 bpm with rig pumps, slowing to 2 bpm prior to bumping plug • Bumped plug at 6027 stks (calculated displacement) • Pressured up to 1200 psi and held for 5 minutes • Floats held Job Comments • Maintained proper cement density • No returns throughout job • Saw good lift pressure • Bumped plug Top of Cement • TOC estimated at —10,200' MD (based on lift pressures the rig recorded while pumping displacement) Cement Detail Report 3H-35 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/22/2020 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/22/2020 13:00 2/22/2020 17:00 31-1-35 Comment HES pump 60 bbl Tuned spacer = 12 ppg, 3.18 yield, 20.0 gal/sk with 30 bbl LCM blended in. 4 BPM = 843 psi. Pump 247 bbl Lead Cement = 1125 sks, 15.5 ppg, 1.20 yield, 5.33 gal/sk, with .25 Ib/bbl WeIlLife mixed in on the fly. 4 BPM = 750 psi. Pump 40 bbl Tail Cement = 20 sks, 15.8 ppg, 1.16 yield, 4.97 gal/sk, with .25 Ib/bbl WeIlLife mixed on the fly. 4 BPM = 634 psi. Drop top plug. Verified by Co -man. Kick out plug with 10 bbis water. Swap to rig pumps. Rig pump chase with 619 bbls of 11.4 ppg LSND mud from pits. ICP = 230 psi at 7 BPM. FCP = 710 psi at 2 BPM. Bump plug at 6027 strokes. (pumpout put of. 1028 bbl/stk -98%) Pressure up to 1200 psi and hold 5 min. Bleed off and check floats = Good CIP @ 17:00,2/23/2020 Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? g IntermediatE(bb:11m... 10,223.0 13,640.0 No Yes Yes Cement Q Pump [nit O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 2 4 700.0 700.0 INo No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 60 BBLS 12 PPG tuned spacer, 247 BBLS 15.5 PPG lead cmt , 40 BBLS 15.8 PPG tail cmt, good lift pressure. Bump plugs , floats holding Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 10,223.0 13,096.0 1,125 G 247.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.20 5.33 15.50 Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 13,096.0 13,640.0 220 G 40.0 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 4.97 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2124/20201 iCem Service CONOCOPHILLIPS - NORTH SLOPE-EBUS Date: Monday, February 24, 2020 31-1-35 Intermediate Job Date: Saturday, February 22, 2020 Sincerely, Julia Nichols Disclaimer: All information in this report is provided subject to the terms and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which professionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simulation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as well as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its decisions which are based on the information provided in this report. _?Oi S H 111!bu�r n nall,g"l 'SeIVrd HALLIBURTON Table of Contents 1.0 Cementing Job Summary ...................... 1.1 Executive Summary ............................................................ 2.0 Real -Time Job Summary ....................... 2.1 Job Event Log...................................................................... 3.0 Attachments .......................................... 3.1 3H-35 Job Chart with Events ............................................... 3.2 31-1-35 Job Chart without Events ......................................... Page 3 Customer: CONOCOPHILLIPS - NORTH SLOPE-EBUS Job: 31-1-35 Intermediate SO#: 906308491 iCem Service (v. 5.0.161.0) Created: Monday, February 24, 2020 HALLIBURTON 1.0 Cementing Job Summary 1.1 Executive Summary Customer: CONOCOPHILLIPS - NORTH SLOPE-EBUS Job: 3H-35 Intermediate I SO#: 906308491 Halliburton appreciates the opportunity to perform the cementing services on the 3H-35 cement Intermediate casing job. A pre -job safety meeting was held before the job where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined. A Halliburton cementing crew arrived on location at 3H-35 on 2/22/2020 in order to pump the 7.625" intermediate casing cement job. Halliburton dropped the bottom plug, then mixed and pumped approximately 60 bbls of Tuned Spacer at an average density of 12.16 Ib/gal, 247 bbls of lead cement at an average density of 15.49 Ib/gal and 40 bbls of tail cement at an average density of 15.82 Ib/gal. Halliburton launched the top plug with 10 bbls fresh water before swapping over to the rig for 619 bbls of 11.4 water based mud displacement. The top plug bumped at calculated displacement and the floats held. Rate was reduced to 1 bpm for a few minutes on three occasions while pumping cement in order to maintain density while swapping silos. There were no shutdowns while pumping spacer or cement. Due to losses observed while drilling and running casing, LCM was included throughout the cementing program. There was 0.5 Ib/bbl WellLife 1094 (fibrous LCM) bulk blended into the 60 bbls of 12 Ib/gal Tuned Spacer and 0.25 Ib/bbl of WellLife 1094 was added to the cement (both lead and tail) on the fly. There were no returns observed throughout the cement job. Based on the lift pressures the rig recorded while pumping displacement, TOC is estimated to be around 10,200'. The plug was bumped at 2bpm and 800 psi. Halliburton safely rigged down and departed location on 2/22/2020. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. 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S th Ia ------------------------------------------------ M 'a E a E 0 0 4 o --------- --------------------------------------a -- _ m e y r S m m 4 - - - t- 5 v V u �000000000ao: v a 0 2 J I N M i Loepp, Victoria T (CED) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, February 17, 2020 5:06 PM To: Loepp, Victoria T (CED); Titus, Marti N Cc: Regg, James B (CED); DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNAL]Re: 3H-35 BOP Extension Request Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank -you - Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, February 17, 2020 3:18 PM To: Titus, Marti N <Marti.N.Titus@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]Re: 31-1-35 BOP Extension Request Marti, Approval is granted for a BOP test extension until after the intermediate casing is run. Victoria Sent from my iPhone On Feb 17, 2020, at 11:41 AM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote: Hi Victoria, Thank you very much for taking the time to talk to me on your day off. As discussed, we are requesting a BOP extension as our current forecast has us testing BOPS on the 21-, after we run and cement our intermediate casing (test is due on the 20=h). I'm very concerned that if we wait to run casing until after we test BOPS, that we risk not getting our casing to bottom. Below is a summary of our recent operations and the basis for my concern. We TD'd the intermediate section and performed our MPD drawdown test to confirm pore pressure and determine our kill weight. When we started circulating after our drawdown test, the hole packed off and we lost over 200 bbls. We regained circulation, weighted up to our 11.4 ppg kill weight, and started backreaming but have been experiencing pack -offs and losses. We believe that the Kalubik shales are causing the hole issues. The longer we leave the shales open before we run casing, the greater the risk of us not getting casing to bottom. We've had quite a few challenges drilling the intermediate section. This was the first time we've run Baker in this part of Kuparuk and we had issues achieving our directional plan at the start of the section so we had to trip and run a motor to get back on plan (drilled with a motor to 4760' MD). We TOOH with the motor and picked up the RSS BHA on 2/9/20. When we ran back in with Baker's rotary steerable system, our ROP was less than 10 fph so we tripped to check the BHA (2/10/20). On 2/11/20 we ran back in the hole and continued drilling our 9-7/8" x 11" hole to TD (reached TD on 2/16/20 at 12:00). Our ROPs were significantly slower on this well than we've seen in the past with Schlumberger which is why we didn't test BOPs when we were out of the hole on the 10th. At the time, our forecast showed that we'd TD and have our 7-S/8" casing run and cemented before the 20,h as it was based on ROPs from recent offsets. Please let me know if you need any additional information. Our current forecast has us laying down BHA tomorrow morning. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 P7-0 Loepp, Victoria T (CED) From: Regg, lames B (CED) Sent: Monday, February 17, 2020 5:11 PM To: Loepp, Victoria T (CED) Subject: RE: 31-1-35 BOP Extension Request Follow Up Flag: Follow up Flag Status: Flagged Does their current stack config include tested casing rams? Should have included that info in their request. If not they have to change rams and test them before running pipe. And it would take 2 maybe 3 additional hrs to test the rest of the stack (Choke manifold and gas detection could be tested offline). Sent via the Samsung Galaxy S8 Active, an AT&T 5G Evolution capable smartphone -------- Original message -------- From: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov> Date: 2/17/20 1:26 PM (GMT -09:00) To: "Regg, lames B (CED)" <jim.regg@alaska.gov> Subject: Fwd: 31-1-35 BOP Extension Request We should probably approve this extension. Any thoughts after reading? They seem to be aware of our concern with extensions. Sent from my Phone Begin forwarded message: From: "Titus, Marti N" <Marti.N.Titus@conocophillips.com> Date: February 17, 2020 at 11:41:52 AM AKST To: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov> Subject: 31-11-35 BOP Extension Request Hi Victoria, Thank you very much for taking the time to talk to me on your day off. As discussed, we are requesting a BOP extension as our current forecast has us testing BOPS on the 21-, after we run and cement our intermediate casing (test is due on the 20th). I'm very concerned that if we wait to run casing until after we test BOPs, that we risk not getting our casing to bottom. Below is a summary of our recent operations and the basis for my concern. We TD'd the intermediate section and performed our MPD drawdown test to confirm pore pressure and determine our kill weight. When we started circulating after our drawdown test, the hole packed off and we lost over 200 bbls. We regained circulation, weighted up to our 11.4 ppg kill weight, and started backreaming but have been experiencing pack -offs and losses. We believe that the Kalubik shales are causing the hole issues. The longer we leave the shales open before we run casing, the greater the risk of us not getting casing to bottom. We've had quite a few challenges drilling the intermediate section. This was the first time we've run Baker in this part of Kuparuk and we had issues achieving our directional plan at the start of the section so we had to trip and run a motor to get back on plan (drilled with a motor to 4760' MD). We TOOH with the motor and picked up the RSS BHA on 2/9/20. When we ran back in with Baker's rotary steerable system, our ROP was less than 10 fph so we tripped to check the BHA (2/10/20). On 2/11/20 we ran back in the hole and continued drilling our 9-7/8" x 11" hole to TD (reached TD on 2/16/20 at 12:00). Our ROPs were significantly slower on this well than we've seen in the past with Schlumberger which is why we didn't test BOPS when we were out of the hole on the 10=h. At the time, our forecast showed that we'd TD and have our 7-5/8" casing run and cemented before the 20th as it was based on ROPs from recent offsets. Please let me know if you need any additional information. Our current forecast has us laying down BHA tomorrow morning. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 THE STATE Marti Titus FIXme03-MV0111 GOVERNOR MIKE DUNLEAVY Staff Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 31-1-35 Permit to Drill Number: 219-064 Sundry Number: 320-067 Dear Mr. Titus: Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je rice Chair DATED this NG day of February, 2020. ROMS O�FEB 1 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED FEB 0 5 2020 pr -S Zl/o/ Z A0GC ; 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Apprropoved[ogram ❑ Plug for Redrill El Perforate New Pool ElRe-enterSusp Well El Alter Casing El Other: R_eWe ial Cement ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development Stratigraphic ❑ Service ❑ 219-064 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-103-20805-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? , KRU 3H-35 Will planned perforations require a spacing exception? Yes ❑ No ❑� ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025531, ADL025524, ADL365501 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 20" 139' 139' Surface 3020' 10-3/4" 3151' 2946' 5,210 psi 2,470 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None N/A 12. Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/4/2020 OIL ❑� • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 2/4/2020 Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Marti Titus Contact Name: Marti Titus Authorized Title: Staff Drilling Engineer Contact Email: marti.n.titus(a)conocoghillips.com % „� ! �/ Contact Phone: 907-265-1192 " ' �Zf� Authorized Signature: z Date: 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDM I± -_w v IY��7 FEB 1 12020 Post Initial Injection MIT Req'd? Yes ❑ No Q� �i7 C �L Z G✓/ 0 L7 Spacing Exception Required? Yes ❑ No Subsequent Form Required: tv,-// 10 — 462 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (vjvt' �rb h6P/2017L // IN-Alffrornthe Submit Form and For3 R i� Approved apOtRil,,G date of approval. �^qchments in Duplicate V 7_0 3H-35 (PTD 219-064) Surface Cement and Top Job Summary On February 4, 2020, the 10-3/4" surface casing primary cement operation was performed on 3H-35. After pumping 500 bbls of 11.0 ppg lead cement, total returns were lost. Spacer was observed at surface but no cement. Wellbore specifics: • Drilled surface hole depth: 3156' MD / 2953' TVD, 40° inclination • Surface Casing: 10-3/4", 45.5#, L-80, Hydril 563 • Surface Casing shoe: 3151' MD • 2 centralizers /joint on each joint of shoe track and 1 centralizer / joint above shoe track. • Circulated and conditioned mud at 6 bpm for 4.75 hrs prior to cement job. Primary Cement Job Summary: • Pumped 60 bbls of 10 ppg Tuned Spacer @ 3-5 bpm. • Dropped bottom plug. • Pumped 525 bbls of 11.0 ppg lead cement @ 4.5 bpm (lost full returns after 500 bbls pumped). • Pumped 57 bbls of 15.8 ppg tail cement @ 3 bpm. • Dropped top plug. • Displaced with 9.6 ppg spud mud @ 3-6 bpm. Total volume pumped was 293 bbls. Bumped plug (FCP 550 psi). Pressure up to 1100 psi and held for 5 minutes. Floats held. • Cement Job Comments: o No issues running casing. Minimal losses (^'26 bbls total RIH with casing). o Minor losses observed while circulating prior to cementjob (^'13 bbls). o Had issues maintaining density and rate throughout the job as a result of the extremely cold temperatures. Top Job: • Based on gauge hole and the volume of cement pumped before we lost returns at surface (500 of 525 bbls of lead), the TOC was estimated to be at —139 ft RKB. • The diverter was nippled down to gain access to top of casing hanger. • Notification was made to AOGCC. Approval was granted to proceed with top job. An AOGCC State Inspector was called to witness the job. • Made up 1" top job string. RIH down the annulus of the surface casing and conductor. • Tagged top of cement at 130' (from ground level) / 167' RKB. Flushed with 22.5 bbls of water. • Pumped 34 bbls of 11.0 ppg lead cement at 1 bpm with cement returns to surface at 20 bbls pumped (11 ppg observed at 25 bbls pumped). CIP at 17:50 hrs on 02/04/2020. Observed annulus for cement fall back. Level remained at top of flutes on hanger. • Top job witnessed by AOGCC (Adam Earl). k e Cement Detail Report 3H-35 String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/22/2020 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/3/2020 22:30 2/4/2020 04:30 3H-35 Comment Cement 10 3/4" casing - Pumped 60 bbls of mud push spacer @ 10 ppg treated w/ red dye & 5 # Pol-E -Flake - Dropped bottom plug - began pumping Lead slurry @ 11 ppg. Initial circulating rate 3 bpm- worked up to 5 bpm.Continue cementing 10-3/4" casing. Per cement detail. Reciprocate casing. while cementing up wt. 194k. down wt. 147k. Pumped a total of 500 bls. lead cement and lost returns. Completed pumping 11.0 ppg lead cement total volume lead - 525 bls. Pumped 57 bls. 15.8 tail cement. Drop top plug 10 bbl water to flush. Displace with rig pumping 9.6 ppg. spud mud total mud pumped 283 bls. Total displacement volume = 293 BBL. Initial rate 6 bpm slowed to 3 bpm held until plug bumped at 2,828 strokes. As expected per calculated displacement. FCP 550 psi build to 1,100 psi. Hold for 5 min. Floats holding. CIP at 04:45 2/4/2020 Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return. Vol Cement... Top Plug? I Btm Plug? Surface Casing Cement 1 130.0 3,150.8 No 0.0 Yes Yes Q Pump [nit (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi)Recip? 1 I Stroke (ft) Rotated? I Pipe RPM (rpm) 6 3 5 550.0 1,100.0 Yes 15.00 Yes Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 130.0 1" top job pipe Comment Lost returns with 500 BBL pumped. tagged top. Decision made to perform top job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 130.0 2,650.0 1,130 G 526.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 2.61 12.50 11.00 Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bb[) Tail Cement 2,650.0 3,150.8 275 G 57.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.05 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/5/2020 a s; Cement Detail Report 3H-35 String: Surface Top Job Job: DRILLING ORIGINAL, 1/22/2020 00:00 Cement Details Description Surface Top Job Cementing Start Date 2/4/2020 13:30 Cementing End Date 2/4/2020 18:45 Wellbore Name 3H-35 Comment Performed top job w AOGCC witness Adam Earl. Tagged TOC at 130 ft w 1" pipe. Pumped entire tob w/ string at 120 ft. 22.5 BBL water to flush. 11 PPG cement pumped. Cement returns to surface after 20 BBL pumped, good cement to surface after 25 BBL pumped. 34.0 BBL total cement pumped. Cement Stages Stage # 1 Description Surface Top Job Ito Objective Perform top job w returns surface Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 130.0 Full Return? No Vol Cement... 16.0 Top Plug? No I Btm Plug? No Q Pump Init (bbl/m... 2 Q Pump Final (bbl/... 2 Q Pump Avg (bbl/... I 2 P Pump Final (psi) 430.0 P Plug Bump (psi) 430.0 Recip? No Stroke (ft) Rotated? No 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 (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration I Conc Unit label Page 1/1 Report Printed: 2/5/2020 Mi SWACt -- AschmmbergerCompany' - WATER-BASED MUD REPORT N0.9 Operator : ConocoPhillips Alaska Report For : M. Brouillet / D. Mickey Well Name: 3H-35 Contractor/Rig: DDI/Doyon 19 Report For: u. Williams / M. barn Field/Area : Kuparuk Depth/TVD : 3159 ft/2952 ft Description : A -Sand Injector Date : 3 -Feb -20 Location : Kuparuk, North slope Spud Date: 31 -Jan -20 Interval: 1 Mud Type: Spud Mud Log -It iF : J2U.000113 Activity : burtace Gement JOB DRILLING ASSEMBLY CASING MUD VOLUME (bbl) IRCULATION DATA 3150 ft, 10.75 in Casing 20 in csg @102 ft (102 TVD) Hole 526.8 Active Pits 200 Pump Make EMSCO FB -1600 Pump Liner x Stk 6A 2in 6xl2in Total Circulating Volume 725.3 Pum Capacity 4.19 al/stk 4.19 al/stk Pump stk/min @95% 1 @95% Depth Drilled Last 24 hr Flow Rate Pump Pressure Volume Drilled Last 24 hr Bottoms U Total Circulation MUD PR PERTIES SOLIDS CONTROL EQUIPMENT Last 24 hr Sample From In @ 21:00 Pit 5 @ 15:00 Out 09:00 Pit 5 @ 03:00 Type Model/Size Hrs Used FlowLine Tem -F 52 52 54 Brandt VSM MS 0/0/0/0 Depth/TVD ft 3159/2952 3159/2952 3159/2952 3159 / 2952 Brandt VSM MS 0/0/0/0 24.0 Mud Weight frem p lb/gal @ °F 9.6051 9.65 @ 52 9.6 @ 54 9.6 a 54 CD 500 HV Funnel Viscosity sec/qt 62 131 245 170 MD3 Shaker 0/0/0/0 Rheolo Tem -F 51 52 54 54 R600/R300 73/46 93/62 1871128 1 100171 R200/R100 35/22 46/30 101/74 57/43 R6/R3 4/4 19/17 31/30 21/21 PV cP 27 31 59 29 DESIRED SPECS Min - Max YP Ibf/100ft' 19 31 69 42 Chlorides 0-2500 LSYP (R3x2)-R6 4 15 29 21 MBT 0-35 1 Os/10r t30m Gel 5125/31 27/34/41 46/57/67 23/34/47 Measured Density 8.7-9.6 API Fluid Loss cc/30min 5.8 5.6 5.2 6 pH 9.5-10 HTHP Fluid Loss cc/30mm YP 30-80 Cake APT/HT 1/32" 2/ 3/ 3/ 3/ Solids %vol 8 8 8.5 8.5 Oil/Water %vol 2.75/89.25 2.75/89.25 2.75/88.75 2.75/88.75 Sand %vol 1.5 1.75 1.75 1.75 MBT lb/bbl 28.5 28.5 27.5 27.5 H / Tem 9.4 @ 51 9.4 @ 52 9.4 52 9.5 @ 54 Atka[ Mud Pm 0.3 0.25 0.3 0.3 n Pf/Mf 0.15/0.6 0.15/0.6 0.15/0.7 0.2/0.7 k Chlorides m /L 600 600 600 600 Tauy Hardness (Ca++) 20 20 20 20 Bit IossN/o, psV% LGS / DS % 7.03/4.36 7.03/4.36 7.27 / 4.74 7.27/4.74 Bit HHP/HIS ECD PWD lb/gal Jet Velocity, Ills Flow Rate gpm Va Pipe, ft/min Pressure psi Va Collars, ft/min ROP ft/hr CVa Pipe, ft/min Top Drive RPM rpm CVa Collars, ft/min Top Drive Torque ft -lbs ECD at Shoe, Ib/gal VSST sag shoe tes ECD at TD, Ib/gal REMARKS AND TREATMENT RIG OPERATIONS SUMMARY Cement rinsate truck picked up 290 bbl black water from mud plant. Black water transferred to cement returns trucks and super sucker. Remaining black water was transferred to rig pits. The rig began running 10 %'% L-80 Hydril casing. From surface to 1,101' MD displacement discrepancies were indicating a 15 bbl loss during running. Water was turned on @ 5 BPH to treat the R/U to run 10 3/4" casing. Service rig. Change hydraulic oil filter in top drive. RIH with casing to displaced mud for increase viscosity and mud weight. From 1,101' MD to TD of 3,150'. Break circulation. Stage pumps up to 170 gpm. C & C. R/U to pump cement. Pressure 3,152' another 11 bbls were lost to formation while running remaining casing. Stage pumps to 4 BPM, Conditioned mud for cement jab using water @ 10-20 test lines. Begin pumping mud push and cement. BPH and CF DESCO II. Condition for 2:40 min continued to circulate and set up cementers and observed 13 bbls lost while circulating (2.6 bbls/hr loss rate). Transferred mud from pits to truck and held for contingency. All trucks put in place for cement job. TIME DISTRIBUTION Last 24 hrs SOLIDS ANALYSIS MUD VOL ACCTG bbl Rig Repair 0.75 NaCl %vol / Ib/bbl 0.02/0.31 Water Added 50 Circulating / Hole Cleaning (Programmed) 3 KCI %vol / Ib/bbl Mud Received Lubricate Rig 0.5 Low Gravity % / Ib/bbl 7.03/63.98 Mud Returned Run Casing / Liner 12.5 Bentonite % / Ib/bbl 2.65/24.1 Formation -Running Casing 26 Cementing Operation 7.25 Drill Solids %/ Ib/bbl 4.36/39.63 Formation - Circulation 13 Weight Material %/ Ib/bbl 0.95/13.6 shakers - Mud On Cuttings 29.7 Chemical Conc Ib/bbl 0.3 Inert/React 1.2 Average SG Solids 2.8 Carb / Bicarb 2.97/5.94 - UB- RFA E LOSSES EInterval Interval 39 Cumulative 39 M-1 Engineer Phone Email Rig Phone Whse Phone John Reinhardt ---907-670_4318 _- DOYONI9-MI-DS-AK&@il lb.com 907-670-4300 907-670-5253 Scot Goulding Loepp, Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophiIli ps.com> Sent: Tuesday, February 4, 2020 9:57 AM To: Loepp, Victoria T (CED) Cc: Regg, James B (CED); DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNAL]KRU 3H-35(PTD 219-064) Surface Casing Cement: Top Job Required Follow Up Flag: Follow up Flag Status: Completed Thanks Victoria. I will let the company man on the rig know that he needs to notify the AOGCC inspectors to witness the top job. Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 04, 2020 9:56 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov> Subject: [EXTERNAL]KRU 3H-35(PTD 219-064) Surface Casing Cement: Top Job Required Marti, Please refer to the AOGCC Guidance Bulletin on Top Jobs(13-001). Notify the AOGCC inspectors to witness the procedure. Verbal approval is granted to proceed as outlined with AOGCC witness. Prepare and submit a 10-403 Sundry for approval as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp@.alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.LoeppCalaska.govov From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Tuesday, February 4, 2020 9:43 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 31-1-35 - 10-3/4" surface cement job - top job required Hi Victoria, We pumped our 10-3/4" surface casing cement job early this morning and experienced losses after pumping —500 bbls of lead cement. We finished pumping the rest of the job (total 525 bbls lead and 57 bbls of tail). We bumped the plug and tested the floats. We did see some spacer back at surface. Our plan forward is as follows: • Nipple down diverter and adapter to gain access to top of casing hanger • Run the top job string (1" pipe) down the annulus of the 10-3/4" casing and conductor and tag top of cement • Flush annulus with water • Pump 11.0 ppg lead slurry until returns are seen at surface (volume TBD). I do not have the exact volume yet as we're still working out how much we think we need to pump. Since we saw some of the spacer back at surface and then no returns after that, we're estimating that we probably need to pump at least 50 bbls. I'll confirm the volume once I get the job report from Halliburton and can work out a more accurate estimate. Please let me know if you have any questions. I'll submit the appropriate paperwork once I have all of the required information. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 Loepp, Victoria T (CED) From: Earl, Adam G (CED) Sent: Wednesday, February 5, 2020 9:44 AM To: Regg, James B (CED) Cc: Loepp, Victoria T (CED) Subject: Surface cement top job Attachments: IMG_4293.MOV; ATT00001.txt Follow Up Flag: Follow up Flag Status: Completed Quick update from 3H-35 last night, top job went good, hung up around 70' but after some efforts, we were able to get to 130'. Pulled up to 120', pumped 22 bbls water, conductor vol.,, cleaned up fairly well. then pumped the cement 11ppg. Figured a few bbls of OH vol. good green cement come back after 20 bbls away. I was told the conductor is 102' GL Boyer, David L (CED) From: Titus, Marti N <Marti.N.Titus@conocophiIIips.com> Sent: Thursday, February 6, 2020 10:27 AM To: Boyer, David L (CED) Subject: RE: [EXTERNAL] Status of KRU 3H-35 Well Hi Dave Our base plan is to pre -produce for approximately 6 months. This is based on a total volume of oil produced so if the well comes on at a higher rate than we originally premised, the timing could be reduced. Thanks Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 From: Boyer, David L (CED) <david.boyer2@alaska.gov> Sent: Thursday, February 06, 2020 9:23 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Subject: [EXTERNAL]Status of KRU 3H-35 Well Hi Marti, I am reviewing the Sundry 320-067 for KRU 31-1-35. 1 went back to the approved PTD package from last May and saw that this water injector will be pre -produced. Will the oil pre -production be less than 3 months? Thank you, Dave Boyer AOGCC P7D 2i17—C6-� Loepp, Victoria T (CED) From: Earl, Adam G (CED) Sent: Wednesday, February 5, 2020 9:44 AM To: Regg, James B (CED) Cc: Loepp, Victoria T (CED) Subject: Surface cement top job Attachments: IMG_4293.MOV; ATT00001.txt Follow Up Flag: Follow up Flag Status: Flagged Quick update from 3H-35 last night, top job went good, hung up around 70' but after some efforts, we were able to get to 130'. Pulled up to 120' , pumped 22 bbls water, conductor vol.,, cleaned up fairly well. then pumped the cement 11ppg. Figured a few bbls of OH vol. good green cement come back after 20 bbls away. I was told the conductor is 102' GL Loepp. Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophillips.com> Sent: Tuesday, February 4, 2020 9:57 AM To: Loepp, Victoria T (CED) Cc: Regg, James B (CED); DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNAL]KRU 3H-35(PTD 219-064) Surface Casing Cement: Top Job Required Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria. I will let the company man on the rig know that he needs to notify the AOGCC inspectors to witness the top job. Marti Marti Titus Staff Drilling Engineer Office: 907-265-1192 Cell: 713-494-8198 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 04, 2020 9:56 AM To: Titus, Marti N <Marti.N.Titus@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]KRU 3H-35(PTD 219-064) Surface Casing Cement: Top Job Required Marti, Please refer to the AOGCC Guidance Bulletin on Top Jobs(13-001). Notify the AOGCC inspectors to witness the procedure. Verbal approval is granted to proceed as outlined with AOGCC witness. Prepare and submit a 10-403 Sundry for approval as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aC)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or'Victoria.Loeppalaska.aov Loepp. Victoria T (CED) From: Titus, Marti N <Marti.N.Titus@conocophiIIips.com> Sent: Tuesday, February 4, 2020 9:43 AM To: Loepp, Victoria T (CED) Subject: 3H-35 - 10-3/4" surface cement job - top job required Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, We pumped our 10-3/4" surface casing cement job early this morning and experienced losses after pumping —500 bbls of lead cement. We finished pumping the rest of the job (total 525 bbls lead and 57 bbls of tail). We bumped the plug and tested the floats. We did see some spacer back at surface. Our plan forward is as follows: • Nipple down diverter and adapter to gain access to top of casing hanger • Run the top job string (1" pipe) down the annulus of the 10-3/4" casing and conductor and tag top of cement • Flush annulus with water • Pump 11.0 ppg lead slurry until returns are seen at surface (volume TBD). I do not have the exact volume yet as we're still working out how much we think we need to pump. Since we saw some of the spacer back at surface and then no returns after that, we're estimating that we probably need to pump at least 50 bbls. I'll confirm the volume once I get the job report from Halliburton and can work out a more accurate estimate. Please let me know if you have any questions. I'll submit the appropriate paperwork once I have all of the required information. 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Alvord THE STAT. ''ALASKA GOVERNOR MIKE DUNLEAVY Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 31-1-35 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-064 Surface Location: 1561' FNL, 281' FWL, SEC. 12, TI 2N, R08E, UM Bottomhole Location: 1755' FSL, 1737' FEL, SEC. 28 T13N, R08E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this % day of May, 2019. STATE OF ALASKA AL. XA OIL AND GAS CONSERVATION COMMI—ION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj r ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Red rill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket FZ] Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 • KRU 31-1-35 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 20158 TVD: 5956 Kuparuk River Field ` Kuparuk Oil Pool - 4a. Location of Well (Governmental Section): 7. Property Designation: , r Surface: 1561' FNL, 281' FWL, Sec 12, T 12N, R 08E, UM ADL025531, ADL025524, ADL365501 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2259 FSL, 1285' FWL, Sec 34, T 13N, R 08E, UM 931882000, 931881000, 931941000 5/19/2019 - 9. Acres in Propertv: 14. Distance to Nearest Property: Total Depth: 1755 FSL, 1737' FEL, Sec 28, T 13N, R 08E, UM 2560, 1920, 640 1337' to ADL355032 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10, KB Elevation above MSL (ft): 75.6' • 15. Distance to Nearest Well Open Surface: x- 498655.41 y- 6000096.24 Zone -4 GL / BF Elevation above MSL (ft): 36.6' to Same Pool: 2044' to 3H-24 16. Deviated wells: Kickoff depth: 230 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3,819 psi Surface: 3,231 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 Surface Surface 119 119 To be installed 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 3577 Surface Surface 3574 3257 1394 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" x 11" 7-5/8" 29.7# L-80 Hyd 563 13319 Surface Surface 13358 5880 357 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6950 13208 5860 20158 5956 N/A: Un -cemented liner 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 P-1 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirementsE 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ben Tolman Authorized Name: G. Alvord Contact Email: ben.v.tolMgg@cop.com Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6828 ^r �` Authorized Signature: : `� - Date: ZC Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a kl-06+ 50- O 3 — a O'S S w DD — 00 1 Date: t requirements. Conditions of approval': If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Y, Other: 130P74 --,r -5 t 7`'D 3-5-6)0 S i Samples req'd: Yes ❑ Noo Mud log req'd: Yes❑ Noll P'S/ easures: Yes No y q' [� No[-] �f-� � fD Z �Udp��6asi � ❑ Directional sv req'd: Yes ,�,/ S� ✓m i fo A06 CC 05 e n c h Spy in ..excels/tu>n-req'd--Yes Inclination -only svy req'd: Yes NoL�' r�No� b ccov" is of va �`1 a b! e- f �� L 07 13,5- Post initial injection MIT req'd: YesEk"No❑ cc c a F)T/ Le';' 7— S �L ' C C l Yl f h f' j D b I C"5 �' � fS 1 a� �t ✓rvr�l L�'�-�-��'"� L �� Cva 1dc� �`✓l fir�rv,rcl,4+:d APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: r 1 �-L / 9 n %1 Submit Form and pjla&- ew d�/2b17 This permit is valid for 4 �p h ¢`OII/ t proval per 20 AAC 25.005( Attaj menu in Duplicate p p Q KRU 3H-35(PTD 219-064) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well KRU 31-1-35(with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Application for Permit to Drill, Well 3H-35 Saved: 26 -Apr -19 ConocoP hilli April 26, 2019 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Injector, 311-35 Dear Commissioner: �{ Or ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore pre -produced injector, a single - lateral horizontal well in the Kuparuk formation. The potential spud date for this well is May 19, 2019. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The intermediate hole section will consist of a 9-7/8" x 11" hole with 7-5/8" casing run to total depth & cemented in place. The production lateral will include a 6-3/4" production hole geo-steered in the Kuparuk formation and lined with 4-1/2" liner with swell packers. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 907-265-6828 (ben.v.tolman(acop.com) or Chip Alvord at 907-265-6120. Sincerely, ,�. (_ A_ _ Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 3H-35 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3H-35 DrRung &Wells Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill Hurst be accompanied by each of the following items, except for an item already 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 total 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 Survey 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* 1561' FNL, 281' FWL, Sec 12, T12N, R08E, UM NGS Coordinates Northings: 6000096.24' Eastings: 498655.41' IRKB Elevation 36.6' AMSL Pad Elevation 75.6' AMSL *As staked location (conductor still to be set) Location at Surface Casing 593' FNL, 351' FEL, Sec 11, T12N, R08E, UM NGS Coordinates Northings: 6000815.8' Eastings: 498022.4' Measured Depth, RKB: 3,574' Total Vertical De th, RKB: 3,257' Total Vertical De th, SS: 3,181' Location at Intermediate Casing 2259' FSL, 1285' FWL, Sec 34, TUN, R08E, UM NGS Coordinates Northings: 6009198.8' Eastings: 493321.5' Measured Depth, RKB: 13,358' Total Vertical Depth, RKB: 5,880' Total Vertical Depth, SS: 5,804' Location at Total Depth 1755' FSL, 1737' FEL, Sec 28, T13N, R08E, UM NGS Coordinates Northings: 6013979.9' Eastings: 488489.7' Measured De th, RKB: 20,158' Total Vertical De th, RKB: 5,956' Total Vertical De th, SS.- 5,880' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale. showing the path of the proposed wellbore. including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names 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 furnished a copy of the application by certified mail: or (B) state that the applicant is the only affected owner. 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 identified in the application: (3) a diagram and description of the bloirout prevention equipment (BOPS) 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. 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, except for an item already on file rrith the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered. criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 3H-35 is 3,231 psi; estimate from a max estimated reservoir pressure (based on offset well injection/pressure data and reservoir simulator), a gas gradient of 0.10 psi/ft, and the estimated formation depth: Kuparuk Sand Estimated BHP = 3819 psi )k 1 z .5 MW(5) w► Arc P Ve,SS, Kuparuk Sand estimated depth = 5,875' TVD • ��"- Ili Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 587 psi (5,875' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3231 psi - (3,819 psi — 5287 psi) (B) data on potential gas _ones; The wellbore 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 =ones. and _ones that have a propensity for differential sticking: See attached Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests. as required under 20 AAC 25.030(l); A procedure is on file with the commission for performing FIT'S/LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with Bre commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program Hole Casing Weight Grade Coupling Length Top Top Bottom Bottom Cement Details (3,574'— 3,074') x 0.3637 ft3/ft x 1.50 (50% excess) = 273 113 Shoe Joint (80') x 0.5400 ft3/ft x 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 191 sx of 12.0 ppg DeepCRETE @ 1.65 ft3/sk MD TVD MD TVD 42" 20" 94# H-40 Welded 80 Surface Surface 119 119 To be installed 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 3,577 Surface Surface 3,574 3,257 1394 sx 11.0 Lead, 191 sx 12.0 Tail 9-718 7-5/8" 29.7# L-80 Hyd 563 13,319 Surface Surface 13,358 5,880 357 sx 15.8 Class G x 11' 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6,950 13,208 5,860 20,158 5,956 N/A: Un -cemented liner 10-3/4" Surface casing run to 3,574' MD / 3,257' TVD Cement surface casing back to surface. Pump a lead slurry with 11.0 ppg LiteCRETE and 500'of tail slurry with 12.0 ppg DeepCRETE. Assume 200% excess open hole annular volume from conductor to base permafrost and 50% from base permafrost to shoe. Lead slurry from 3,074' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119' — 0') x 1.364 ft3/ft x 1.0 (0% excess) = 162 ft3 Bottom of Permafrost to Conductor (1,672'— 119') x 0.3637 ft3/ft x 3 (200% excess) = 1,695 ft3 Bottom of Lead to Permafrost (3,074'— 1,672') x 0.3637 ft3/ft x 1.50 (50% excess) = 765 ft3 Total Volume = 162 + 1,695 + 765 = 2,622 ft3 => 1394 sx of 11.0 ppg LiteCRETE @ 1.91 ft3 /sk Tail slurry from 3,574' MD to 3,074 MD with DeepCREET @ 12 ppg Shoe to Top of Tail (3,574'— 3,074') x 0.3637 ft3/ft x 1.50 (50% excess) = 273 113 Shoe Joint (80') x 0.5400 ft3/ft x 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 191 sx of 12.0 ppg DeepCRETE @ 1.65 ft3/sk 7-5/8" Production casing run to 13,358' MD / 5,880' TVD Single stage slurry is designed to be placed from TD to 250' TVD above hydrocarbon bearing zone 40% excess open hole annular volume. *Note: Top of Kuparuk utilized for cement calculations, if hydrocarbons are present within the Moraine, cement volumes will be adjusted accordingly (same 40% excess would be utilized in calculations). Slurry from 13,358' MD to 12,128' MD with 15.8 ppg Class G + additives 9-7/8" OH x 7-5/8" Annulus (13,358'— 13,238') X 0.2148 ft3/ft X 1.4 (40% excess) = 36 ft3 11" OH x 7-5/8" Annulus (13,238'— 12,128') X 0.3217 113/ft X 1.4 (40% excess) = 357 ft3 Shoe Joint (80') X 0.258 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 36 + 357 + 21 = 414 ft3 => 357 sx of 15.8 ppg Class G @ 1.16 ft;/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file ivith the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must he accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033, Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Surface Intermediate Production 13-1/2" Hole 9-7/8" x 11" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND (WBM) Flo -Pro NT (WBM) Density (ppg) 8.8-9.5 9.0-9.4 10.0 — 12.7 ' PV (CP) ALAP ALAP ALAP YP (lb/100ftz) 30-80 15-30 15-30 Funnel Viscosity 250-300 Base Permafrost 100-150 to TD N/A N/A Gel Strengths (10s/10m) 30-50 / 30-50 9-15/10-18 6-10/8-15 API Fluid Loss (cc/30min) NC < 6 < 6 HTHP Fluid Loss (cc/min at 160 °F N/A < 10 < 10 pH 9.5-10.0 9.5-10.0 9.5-10.5 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) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey/log with MWD/LWD (Gamma Ray, Resistivity) and gyro (as required). 3. Run and cement 10-3/4", 45.54, L80, Hydril 563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig). T V'6 eC ,ham /l r f h / 3 -D O i 4. Remove diverter system, install and test wellhead, and install and test 13-5/8" x 5,000 psi BOPS to 3500 psi high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 9-7/8" PDC bit and directional drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and PWD. RIH and clean out to 100' above shoe. Test surface casing to 3,000 p/13 mutes. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT (to a minimumg), record results. � v b vyn % - - L� 7-/ F1 7- 1-,-, 7. Directionally drill to intermediate hole TD. 8. BROOH to base permafrost, circulate well clean, and then POOH on elevators. 13' 1'�PT YI-1-- 9. Laydown intermediate BHA. 10. Run 7-5/8", 29.7#, L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Top cement to be placed @ +/- 250' TVD above top hydrocarbon bearing zone (Kuparuk or Moraine). 1'74 G e v" t h t J o b 12. If plugs bump, pressure test casing to 3,500 psi for 30 minutes. b" 7ro'-e- 13. Install 7-5/8" packoff & test to 5000 psi. 14. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 15. PU 6-3/4" bit nd_dr_illing assembly with MWD, Gamma Ray, Resistivity, Periscope, Son' Scope, and PWD (S icScope for cement evaluation onl en E- 16. RIH on DP to top of oat equipment. Clean out any residual cement to top of float equipment. Log TOC with sonic I" (log section of free pipe for base line and TOC). If not previously tested, test intermediate casing to 3,500 psi for 30 minutes. 17. Drill out shoe track and 20' of new formation. Perform FIT/LOT and record results. 18. Directionally drill 6-3/4" hole, geo-steering through the Kuparuk formation per directional plan. 19. Circulate 1 BU after TD and BROOH to 7-5/8" shoe. CBU to clean casing and POOH on elevators. 20. Lay down production BHA. 21. PU and run 4-1/2", 12.6# L-80, Hydril 563 liner with liner hanger/packer. The top of liner will be placed at 13,208' (150' overlap in the 7-5/8" casing). 22. Set liner hanger & packer. Test liner top packer. 23. Flow check well. 24. POOH with liner running tools and lay down. 25. Run 3-1/2" 9.3#, L-80, Hydril 563 upper completion and land tubing. 26. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 27. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the follox ing items, except for an item alreadv on file with the commission and identified in the application: (1 d) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 2.1.080 for an annular disposal operation in the well.: Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 113 Facility. If needed, excess cuttings generated will be hauled to Milne Point or 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 Area of Review (AOR) Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Attachment 1: AOR An Area of Review plot is shown below of the 31-1-35 planned wellpath and offset wells. No offset wells were identified within the 1/4 -mile review. 10:5t W1 23 209 3H-35wpO4 Quarter Mile View All Wells Well Status Kuparuk Oil TOC TOC Determined 17500--- Zonal Isolation Cement Operations Name Pool (MD / TVD) By (MD / TVD) uoo i' 4000— Summary Planned: VIV Column of cement to be over 3H-35 Proposed 13,300' MD 12,128' MD Sonic LWD Not Yet Drilled X0500- Well does not Injector V 0 5,626' z exist yet I TVD 7000 s' .4 0 U) IN 3500- -21000 -17500 -14000 -10500 -*00 .3600 '3500 TODD West( -v=- IM (3500 usfttin) Top of Well Status Kuparuk Oil TOC TOC Determined Reservoir Status Zonal Isolation Cement Operations Name Pool (MD / TVD) By (MD / TVD) Summary Planned: Column of cement to be over 3H-35 Proposed 13,300' MD 12,128' MD Sonic LWD Not Yet Drilled 500' or 250' TVD Well does not Injector 5,876' TVD 5,626' (whichever is greater) above exist yet I TVD all hydrocarbon bearing zone C, z u; 3H-35 Grassroots Horizontal A -Sand Inmector Proposed Wellbore Schematic(wp04) Cameron Wellhead & FMC Tree 4-%" tree, top joint is 4-1/Y" 12.6# IBTM 20" Conductor to - 119' 3-1/V' x 1-1/2" Camco MMG GLM Surface Casing 10-3/4" 45.5# L-80 Hydril 563 3,574' MD /3,247' TVD 57° GLM w/ SOOV Tubing: 3-1/2" 9.3 # L-80 HYD563 Baker 2.812" CMU Sliding Sleeve 7-5/8" x 5-%" Baker ZXP�- Packer/Flex Lock Liner Hanger Intermediate Casing 7-518" 29.7# L-80 Hyd563 13,358' MD / 5,880 TVD 3-'/s" 2.75" D Nipple ConocoPhillips Last Edited: Tolman 04/24/19 Base Permafrost 13.5" Surface Hole Base West Salk 9-7/8" Intermediate Hole Top of Cement HRZ 6"x4%" Swell Packerforfaue Kalubik isolation Kuparuk A4 ------- .......................-M ........................................................... TD: 20,158' MD / 5,956' TVD Production Liner: 6-3/4" Production Hole 4-1/2" 12.6# L-80 Hydril 563/TXP w/ Perf Joints > o > o U ¢� 4a F- 4 Q m yC.7 m C? Lil o p 2 O L V) Q LTJ > r L LJ Ln fif m J U > p Z --1 Of O F- w O d Y O J O L� N >- m Z Z O JA Q O p •� m NEl� y b M a X �O � u i O _M L O U N W _ p u O O O'day seal PAW W�+l a400Hpold _- i �iiald d53 a O Lij N � _0 N b M o S O Ln> Tarm oW o n ,n�4 O w 0O M MDJ N n M v Ss >� o N N � � N N N M N Ln Z MQ�M O 0 a- z w o W Of J J LiJ L LI LAm H 0 � n U i F- 3H-35wpO4 As -Built ;�EtPa�� (Plan Summa o° � 1 0F -TI 0 1 4125 8250 12375 1 16500 20625 13-1/2" x 10-3/4" Measured Depth 9 7/8" x 7-5/8" -OADO�T-1 D142 39+36.6 AsBuilt @ 75.60usft (D142) 2p0 a po o 3 o O o O o 0 0 o o I I i : I I I i - I I 0 39 _.._. 232 1 232 --"-® 410 0 1 2500 5000 750D 10000 12500 15000 /17500 330 30 410 - 590 13-1/2" x 10-3/4" 9 7/8" x 7-5/8Fiorizontal Departure 6-3/4" x 4-1/2" 590 - 780 780 - 960 04 - 960 1140 oH-3 w 5 --- ---- -- 300 P ( 60 1140 - 1320 VO g f_ azo - 1900 1500 - 2280 2280 3050 N 3050 3830 ci30 3 02830 2900 270 90 4600 5380 Equivalent Magnetic Distance 5380 - 6190 m H-0 ( H 3 03 6150 - 6930 U 6930 - 7700 0 7700 - 9260 0 2750 5500 8250 11000 13750 16500 19250 240 6 120 9260 - 10810 10810 - 12370 Measured Depth 072 12370 13930 SURVEY PROGRAM 90 05 13930 15490 North I Y: Depth FronDeplh To Survey/Plan Tool East / X: 210 - 070 15490 17040 39.0 01000.00 3H-35wp04 As -Built (3H-35PYD-GC-SS 1000.002000.00 3H-35wp04 As -Built (3H-35MWD OWSG Pad EI6VffiIOn: 36.60 1 17040 ----"- 18600 1000.003573.77 3H 35-1304 As -Built (3H-3WWD+IFR2+SAG+MS TVD MD Name BO 18600 20158 3573.775073.77 3H-35wp04 As -Built (3H-35MWD OWSG 3257.00 3573.77 13-1/2" x 10-314" 3573.7'. 3357.88 3H-35wp04 As -Built (3H-39ytWD+IFR2+SAG+MS Magnetic Model & Date: BGGM2018 15 -Dec -19 13357.884857.88 3H-35wp04 As Built (3H-3WWD OWSG 5879.60 13357.88 9 7/8" x 7-5/8" Magnetic North is 16.22° East of True North M 13357.88!0157.63 3H-35wp04 As -Built (3H-35MWD+IFR2+SAG+MS 5955.60 20157.63 6-3/4" x 4-1/2" 9 (Magnetic Declination) Magnetic Dip & Field Strength: 80.87° 57393nT Sec MD Inc Azi ND +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 Lithology Column 2 231.60 0.00 0.00 231.60 0.00 0.00 0.00 0.00 0.00 KOP: Stat -0.77°1100' DLS, 1.5° TF, for 100' 3 331.60 1.50 90.00 331.59 0.00 1.31 1.50 90.00 -0.77 Start Drop -1.50 4 431.60 0.00 0.00 431.58 0.00 2.62 1.50 180.00 -1.55 Start 37.68°/100' DLS, 2.5° TF, for 500- 5 931.60 12.50 280.00 927.62 9.43 50.88 2.50 280.00 37.68 Start 159.96°1700' DLS, 3° TF, for 500' 1636.6 6 1431.60 19.43 331.07 1410.21 92.10 -144.94 3.00 90.00 159.96 Stat 489.97°/100' DLS, 0° TF, for 1000' 7 2431.60 19.43 331.07 2353.24 383.29 J05.89 0.00 0.00 489.97 Stat 1779.24°/100' DLS, 3° TF, for 1843.89' Base Permafrl 8 4275.49 74.75 330.54 3560.44 1515.58 -941.90 3.00 -0.62 1779.24 Start 9834.78°1100' DLS, 0° TF, for 8408.17 912683.66 74.75 330.54 5772.17 8578.83 4931.40 0.00 0.00 9834.78 Start 10496.59°1100' DLS, 3° TF, for 674.21' 1013357.88 87.00 314.21 5879.60 9102.18 5336.89 3.00 -54.3310496.59 3H-05 Heel BT 042219 Start 10516.29°/100' DLS, 0° TF, for 20' 2469.6 1113377.88 87.00 314.21 5880.65 9116.11 5351.21 0.00 0.0010516.29 Start 10653.08°/100' DLS, 2° TF, for 138.79' Top W Sak 1213516.66 89.78 314.21 5884.55 9212.83 5450.65 2.00 0.0010653.08 Start 11673.12°/100' DLS, 0° TF, for 1034.44' 1314551.10 89.78 314.21 5888.60 9934.07 5192.17 0.00 0.0011673.12 3H-05 Tg101 BT 042219 Start 11700.13°/100' DLS, 2° TF, for 27.39' 2858.6 1414578.49 89.23 314.18 5888.84 9953.16 5211.81 2.00 -177.7711700.13 Start 96' t 13366.32°/100' DLS, 0° TF, for 1689.Base W Sak 31- 1 51 6261.45 135.61516268.45 89.23 314.18 5911.60 11130.90 -7423.57 0.00 0.0013366.32 3H35 Tg102 BT 042219 Stat 13380.04°/100' DLS, 2° TF, for 13.91' 1616282.36 89.50 314.25 5911.75 11140.60 -7433.54 2.00 13.0013380.04 Stat 15958.17°/100' DLS, 0° TF, for 2614.28' 1718896.64 89.50 314.25 5934.60 12964.65 -9306.18 0.00 0.0015958.17 3H-05 Tgt03 BT 042219 Start 16089.61°/100' DLS, 2° TF, for 132.82' Camp SS 1819029.46 89.02 316.86 5936.32 13059.46 -9399.17 2.00 100.4016089.61 Stat 17209.4°/100' DLS, 0° TF, for 1128.16 1920157.63 89.02 316.86 5955.60 13882.54_W70.48 0.00 0.0017209.40 3H-35 Toe BT 042219 TD: 20157.63' KE, 5955.6' TVD 3963.6 C-50 4364.6 C-35 532. 9482. P Moraine 3b t a as ralne - - 14 if Tier 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.) approve it as the basis for the final well plan l and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Section Prepared by: Checked by: ccepted by: Approved by: B. Temple V. Osara J. Ryan B. Tolman AM W M LO T� CD N O O 6 M m 2 �2t oo � ' O O O p 0 £ oon Y -.,6 c'Yj cbC Cl) m Q� � d OS Q M0 C � OS 0901 M h o cooM MOIQ O£ o Q M M ;F= F. OE O M Oti o 0 q FIR � 0 r p ow S�. O SON. (V.. N �N M co- 00 MCD Lon to 09 Cl) M N 0. N 2 0 Q i co Cl) co �� M `- Q3 d co 0 9 Jr N co �... M N M Cl) cl,09 Os, N M cn (.0 0 { 2 Cl) Ok OS Q00 N 0 MN CD Q LO N dm O N M MaQ S M: C'm Q O LOM C� o M 0000 6uiy}PoN OZ Os, c, q Cj q0 M a a- M M M 1_ M M M M Q co MC = c M_ _ O o J = M J CO dL p � o Or Cl) cl,09 Os, N M cn (.0 0 { 2 Cl) Ok OS Q00 N 0 MN CD Q LO N dm O N M MaQ S M: C'm Q O LOM C� o M 0000 6uiy}PoN d 4 o O o M ■ O c O O N �0 �± N O 0p 00p O = .Z O N IT O O F- F- m O 0 v� -� N m m N Q pp 0Q M i Q OO N F- N�- F- 2 M O p O QQQ O x � H m CO H L =0 2 0p 00 0p0 0 6' - N O O Z m H M M 2 M O �p M w O LO M M Q 0CJ (Y) C= _ + 412 M ro O CD W O , OS` O 009' � LOO U) 000 x .0 o 00 0 O o c"4 o x N Ln a s�%y o M o a 0 M c o LO .a� O O o o o O 0 o o O 0 O LO o N 0 0 r+)gIJON/(-)ulnas 0 c� LLJ O 0 L -j LO CRI ca CL OWI61� ir7 - N CtL LL 000q;� O O O LO ca 00' LAG L_J\ 00 00)9i CD 0 CO LO N '\00@06 0 fl II III M I I.- I 0 1 0 C14 cy') VJ CL OD O 0 CIO it I 0 I it I x O I till �00'ot-- 0 0 Lo FZ 060' 6 0 C) '0 'o 0 O Q 000z� cn 0 LO 4- -�e U)(/) E a- 60�9\ LO E au)) C\)\ CL co U) rp �00-9 M 0 LO 10, 1 0 C) 1 did, It 0 C) X 0 (14 0 0 C) I C) 0 0 LO 0 LO C� C%4 qjda(] leoilj@A anal fl II III VJ ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit—2 Kuparuk 3H Pad Plan: 31-1-35 50103xxxxx00 3H-35 Plan: 3H-35wp04 Standard Proposal Report 23 April, 2019 ConocoPhillips V-11 ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc-Kuparuk ND Reference: Project: Kuparuk River Unit -2 MD Reference: Site: Kuparuk 3H Pad North Reference: Well: Plan: 3H-35 Survey Calculation Method: Wellbore: 3H-35 Design: 3H-35wp04 ConocoPhillips Standard Proposal Report Well Plan: 3H-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) " D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature Project Kuparuk River Unit_2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor 4/23/2099 10:47:08AM Page 2 COMPASS 5000.94 Build 85D Site Kuparuk 3H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well Plan: 3H-35 Well Position +N/ -S -14.49 usft Northing: Latitude: +E/ -W -0.03 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 36.60 usft Wellbore 3H-35 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 12/15/2019 16.22 80.87 57,393 Design 3H-35wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 - 0.00 323.77 4/23/2099 10:47:08AM Page 2 COMPASS 5000.94 Build 85D ConocoPhillips p ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 3H Pad Plan: 3H-35 3H-35 3H-35wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 3H-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature Plan Survey Tool Program Date 4/23/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,000.00 3H-35wp04 (3H-35) GYD-GC-SS Gyrodata gyro single shots 2 1,000.00 2,000.00 3H-35wp04 (31-1-35) MWD OWSG OWSG MWD - Standard 3 1,000.00 3,573.77 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + R 4 3,573.77 5,073.77 3H-35wp04 (3H-35) MWD OWSG OWSG MWD - Standard 5 3,573.77 13,357.88 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + R 6 13,357.88 14,857.88 3H-35wp04 (31-1-35) MWD OWSG OWSG MWD - Standard 7 13,357.88 20,157.63 3H-35wp04 (3H-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + h Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) ('/100usft) ("1100usft) (°/100usft) (^) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 231.60 0.00 0.00 231.60 0.00 0.00 0.00 0.00 0.00 0.00 331.60 1.50 90.00 331.59 0.00 1.31 1.50 1.50 0.00 90.00 431.60 0.00 0.00 431.58 0.00 2.62 1.50 -1.50 0.00 180.00 931.60 12.50 280.00 927.62 9.43 -50.88 2.50 2.50 0.00 280.00 1,431.60 19.43 331.07 1,410.21 92.10 -144.94 3.00 1.39 10.21 90.00 2,431.60 19.43 331.07 2,353.24 383.29 -305.89 0.00 0.00 0.00 0.00 4,275.49 74.75 330.54 3,560.44 1,515.58 -941.90 3.00 3.00 -0.03 -0.62 12,683.66 74.75 330.54 5,772.17 8,578.83 -4,931.40 0.00 0.00 0.00 0.00 13,357.88 87.00 314.21 5,879.60 9,102.18 -5,336.89 3.00 1.82 -2.42 -54.33 3H-35 Heel BT 04221 13,377.88 87.00 314.21 5,880.65 9,116.11 -5,351.21 0.00 0.00 0.00 0.00 13,516.66 89.78 314.21 5,884.55 9,212.83 -5,450.65 2.00 2.00 0.00 0.00 14,551.10 89.78 314.21 5,888.60 9,934.07 -6,192.17 0.00 0.00 0.00 0.00 3H-35 Tgt01 BT 0422 14,578.49 89.23 314.18 5,888.84 9,953.16 -6,211.81 2.00 -2.00 -0.08 -177.77 16,268.45 89.23 314.18 5,911.60 11,130.90 -7,423.57 0.00 0.00 0.00 0.00 3H-35 Tgt02 BT 0422 16,282.36 89.50 314.25 5,911.75 11,140.60 -7,433.54 2.00 1.95 0.45 13.00 18,896.64 89.50 314.25 5,934.60 12,964.65 -9,306.18 0.00 0.00 0.00 0.00 31-1-35 Tgt03 BT 0422 19,029.47 89.02 316.86 5,936.32 13,059.46 -9,399.17 2.00 -0.36 1.97 100.40 20,157.63 89.02 316:86 5,955.60 13,882.54 -10,170.48 0.00 0.00 0.00 0.00 3H-35 Toe BT 04221£ 4/23/2019 10:47:08AM Page 3 COMPASS 5000.14 Build 85D f I ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 31-1-35 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Project: Kuparuk River Unit -2 MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad North Reference: True Well: Plan: 3H-35 Survey Calculation Method: Minimum Curvature Wellbore: 3H-35 (°) (usft) Design: 3H-35wp04 (usft) (°/100usft) 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) (°/100usft) (°/100usft) (°/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 0.00 231.60 0.00 0.00 231.60 0.00 0.00 0.00 0.00 0.00 0.00 300.00 1.03 90.00 300.00 0.00 0.61 -0.36 1.50 1.50 0.00 331.60 1.50 90.00 331.59 0.00 1.31 -0.77 1.50 1.50 0.00 400.00 0.47 90.00 399.98 0.00 2.49 -1.47 1.50 -1.50 0.00 431.60 0.00 0.00 431.58 0.00 2.62 -1.55 1.50 -1.50 0.00 500.00 1.71 280.00 499.97 0.18 1.61 -0.81 2.50 2.50 0.00 600.00 4.21 280.00 599.83 1.07 -3.47 2.92 2.50 2.50 0.00 700.00 6.71 280.00 699.36 2.73 -12.84 9.79 2.50 2.50 0.00 800.00 9.21 280.00 798.39 5.13 -26.48 19.79 2.50 2.50 0.00 900.00 11.71 280.00 896.72 8.28 -44.36 32.90 2.50 2.50 0.00 931.60 12.50 280.00 927.62 9.43 -50.88 37.68 2.50 2.50 0.00 1,000.00 12.66 289.40 994.38 13.21 -65.25 49.22 3.00 0.24 13.74 1,100.00 13.47 302.22 1,091.82 23.06 -85.44 69.10 3.00 0.80 12.82 1,200.00 14.83 313.17 1,188.80 38.03 -104.63 92.52 3.00 1.37 10.95 1,300.00 16.63 322.06 1,285.06 58.08 -122.77 119.40 3.00 1.79 8.90 1,400.00 18.72 329.15 1,380.35 83.14 -139.80 149.69 3.00 2.10 7.08 1,431.60 19.43 331.07 1,410.21 92.10 -144.94 159.96 3.00 2.25 6.08 1,500.00 19.43 331.07 1,474.71 112.02 -155.95 182.53 0.00 0.00 0.00 1,600.00 19.43 331.07 1,569.02 141.14 -172.05 215.53 0.00 0.00 0.00 1,700.00 19.43 331.07 1,663.32 170.26 -188.14 248.53 0.00 0.00 0.00 1,800.00 19.43 331.07 1,757.62 199.37 -204.24 281.53 0.00 0.00 0.00 1,900.00 19.43 331.07 1,851.93 228.49 -220.33 314.53 0.00 0.00 0.00 2,000.00 19.43 331.07 1,946.23 257.61 -236.43 347.54 0.00 0.00 0.00 2,100.00 19.43 331.07 2,040.53 286.73 -252.52 380.54 0.00 0.00 0.00 2,200.00 19.43 331.07 2,134.84 315.85 -268.61 413.54 0.00 0.00 0.00 2,300.00 19.43 331.07 2,229.14 344.97 -284.71 446.54 0.00 0.00 0.00 2,400.00 19.43 331.07 2,323.44 374.09 -300.80 479.54 0.00 0.00 0.00 2,431.60 19.43 331.07 2,353.24 383.29 -305.89 489.97 0.00 0.00 0.00 2,500.00 21.49 331.01 2,417.32 404.21 -317.47 513.69 3.00 3.00 -0.09 2,600.00 24.49 330.94 2,509.37 438.35 -336.41 552.42 3.00 3.00 -0.07 2,700.00 27.48 330.88 2,599.25 476.63 -357.71 595.89 3.00 3.00 -0.06 2,800.00 30.48 330.84 2,686.72 518.95 -381.31 643.97 3.00 3.00 -0.05 2,900.00 33.48 330.80 2,771.53 565.19 -407.13 696.54 3.00 3.00 -0.04 3,000.00 36.48 330.76 2,853.45 615.22 -435.12 753.44 3.00 3.00 -0.03 3,100.00 39.48 330.74 2,932.26 668.91 -465.19 814.52 3.00 3.00 -0.03 3,200.00 42.48 330.71 3,007.74 726.12 -497.26 879.62 3.00 3.00 -0.03 3,300.00 45.48 330.69 3,079.68 786.67 -531.24 948.55 3.00 3.00 -0.02 3,400.00 48.48 330.67 3,147.89 850.41 -567.05 1,021.13 3.00 3.00 -0.02 3,500.00 51.48 330.65 3,212.19 917.17 -604.57 1,097.15 3.00 3.00 -0.02 3,600.00 54.48 330.63 3,272.38 986.75 -643.71 1,176.42 3.00 3.00 -0.02 3,700.00 57.48 330.62 3,328.32 1,058.97 -684.37 1,258.71 3.00 3.00 -0.02 3,800.00 60.48 330.60 3,379.84 1,133.64 -726.43 1,343.79 3.00 3.00 -0.01 3,900.00 63.48 330.59 3,426.80 1,210.54 -769.77 1,431.44 3.00 3.00 -0.01 4,000.00 66.48 330.57 3,469.09 1,289.46 -814.27 1,521.41 3.00 3.00 -0.01 4,100.00 69.48 330.56 3,506.57 1,370.20 -859.82 1,613.45 3.00 3.00 -0.01 4,200.00 72.48 330.55 3,539.15 1,452.52 -906.29 1,707.33 3.00 3.00 -0.01 4,275.49 74.75 330.54 3,560.44 1,515.58 -941.90 1,779.24 3.00 3.00 -0.01 4,300.00 74.75 330.54 3,566.88 1,536.17 -953.53 1,802.72 0.00 0.00 0.00 4,400.00 74.75 330.54 3,593.19 1,620.17 -1,000.98 1,898.53 0.00 0.00 0.00 4,500.00 74.75 330.54 3,619.49 1,704.18 -1,048.43 1,994.33 0.00 0.00 0.00 4,600.00 74.75 330.54 3,645.80 1,788.18 -1,095.88 2,090.14 0.00 0.00 0.00 4/23/2019 10:47:08AM Page 4 COMPASS 5000.14 Build 85D Planned Survey Measured ConocoPhillips ConocoPhillips Vertical Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 31-1-35 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D 142) Project: Kuparuk River Unit -2 MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad North Reference: True Well: Plan: 31-1-35 Survey Calculation Method: Minimum Curvature Wellbore: 3H-35 4,700.00 74.75 Design: 3H-35wp04 1,872.19 -1,143.32 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) (°/100usft) (°/100usft) (°/100usft) 4,700.00 74.75 330.54 3,672.10 1,872.19 -1,143.32 2,185.95 0.00 0.00 0.00 4,800.00 74.75 330.54 3,698.41 1,956.19 -1,190.77 2,281.75 0.00 0.00 0.00 4,900.00 74.75 330.54 3,724.71 2,040.19 -1,238.22 2,377.56 0.00 0.00 0.00 5,000.00 74.75 330.54 3,751.02 2,124.20 -1,285.67 2,473.36 0.00 0.00 0.00 5,100.00 74.75 330.54 3,777.32 2,208.20 -1,333.11 2,569.17 0.00 0.00 0.00 5,200.00 74.75 330.54 3,803.62 2,292.21 -1,380.56 2,664.98 0.00 0.00 0.00 5,300.00 74.75 330.54 3,829.93 2,376.21 -1,428.01 2,760.78 0.00 0.00 0.00 5,400.00 74.75 330.54 3,856.23 2,460.22 -1,475.46 2,856.59 0.00 0.00 0.00 5,500.00 74.75 330.54 3,882.54 2,544.22 -1,522.91 2,952.39 0.00 0.00 0.00 5,600.00 74.75 330.54 3,908.84 2,628.23 -1,570.35 3,048.20 0.00 0.00 0.00 5,700.00 74.75 330.54 3,935.15 2,712.23 -1,617.80 3,144.01 0.00 0.00 0.00 5,800.00 74.75 330.54 3,961.45 2,796.24 -1,665.25 3,239.81 0.00 0.00 0.00 5,900.00 74.75 330.54 3,987.76 2,880.24 -1,712.70 3,335.62 0.00 0.00 0.00 6,000.00 74.75 330.54 4,014.06 2,964.25 -1,760.15 3,431.42 0.00 0.00 0.00 6,100.00 74.75 330.54 4,040.37 3,048.25 -1,807.59 3,527.23 0.00 0.00 0.00 6,200.00 74.75 330.54 4,066.67 3,132.25 -1,855.04 3,623.04 0.00 0.00 0.00 6,300.00 74.75 330.54 4,092.97 3,216.26 -1,902.49 3,718.84 0.00 0.00 0.00 6,400.00 74.75 330.54 4,119.28 3,300.26 -1,949.94 3,814.65 0.00 0.00 0.00 6,500.00 74.75 330.54 4,145.58 3,384.27 -1,997.38 3,910.45 0.00 0.00 0.00 6,600.00 74.75 330.54 4,171.89 3,468.27 -2,044.83 4,006.26 0.00 0.00 0.00 6,700.00 74.75 330.54 4,198.19 3,552.28 -2,092.28 4,102.07 0.00 0.00 0.00 6,800.00 74.75 330.54 4,224.50 3,636.28 -2,139.73 4,197.87 0.00 0.00 0.00 6,900.00 74.75 330.54 4,250.80 3,720.29 -2,187.18 4,293.68 0.00 0.00 0.00 7,000.00 74.75 330.54 4,277.11 3,804.29 -2,234.62 4,389.48 0.00 0.00 0.00 7,100.00 74.75 330.54 4,303.41 3,888.30 -2,282.07 4,485.29 0.00 0.00 0.00 7,200.00 74.75 330.54 4,329.71 3,972.30 -2,329.52 4,581.10 0.00 0.00 0.00 7,300.00 74.75 330.54 4,356.02 4,056.31 -2,376.97 4,676.90 0.00 0.00 0.00 7,400.00 74.75 330.54 4,382.32 4,140.31 -2,424.41 4,772.71 0.00 0.00 0.00 7,500.00 74.75 330.54 4,408.63 4,224.31 -2,471.86 4,868.52 0.00 0.00 0.00 7,600.00 74.75 330.54 4,434.93 4,308.32 -2,519.31 4,964.32 0.00 0.00 0.00 7,700.00 74.75 330.54 4,461.24 4,392.32 -2,566.76 5,060.13 0.00 0.00 0.00 7,800.00 74.75 330.54 4,487.54 4,476.33 -2,614.21 5,155.93 0.00 0.00 0.00 7,900.00 74.75 330.54 4,513.85 4,560.33 -2,661.65 5,251.74 0.00 0.00 0.00 8,000.00 74.75 330.54 4,540.15 4,644.34 -2,709.10 5,347.55 0.00 0.00 0.00 8,100.00 74.75 330.54 4,566.46 4,728.34 -2,756.55 5,443.35 0.00 0.00 0.00 8,200.00 74.75 330.54 4,592.76 4,812.35 -2,804.00 5,539.16 0.00 0.00 0.00 8,300.00 74.75 330.54 4,619.06 4,896.35 -2,851.45 5,634.96 0.00 0.00 0.00 8,400.00 74.75 330.54 4,645.37 4,980.36 -2,898.89 5,730.77 0.00 0.00 0.00 8,500.00 74.75 330.54 4,671.67 5,064.36 -2,946.34 5,826.58 0.00 0.00 0.00 8,600.00 74.75 330.54 4,697.98 5,148.37 -2,993.79 5,922.38 0.00 0.00 0.00 8,700.00 74.75 330.54 4,724.28 5,232.37 -3,041.24 6,018.19 0.00 0.00 0.00 8,800.00 74.75 330.54 4,750.59 5,316.37 -3,088.68 6,113.99 0.00 0.00 0.00 8,900.00 74.75 330.54 4,776.89 5,400.38 -3,136.13 6,209.80 0.00 0.00 0.00 9,000.00 74.75 330.54 4,803.20 5,484.38 -3,183.58 6,305.61 0.00 0.00 0.00 9,100.00 74.75 330.54 4,829.50 5,568.39 -3,231.03 6,401.41 0.00 0.00 0.00 9,200.00 74.75 330.54 4,855.80 5,652.39 -3,278.48 6,497.22 0.00 0.00 0.00 9,300.00 74.75 330.54 4,882.11 5,736.40 -3,325.92 6,593.02 0.00 0.00 0.00 9,400.00 74.75 330.54 4,908.41 5,820.40 -3,373.37 6,688.83 0.00 0.00 0.00 _ .9,500.00 _..-_ . 74.75. .. 330.54 ._ 4,934.72 5,904.41 -3,420.82 _ 6,784.64 _ _ . 0.00 0.00 0.00 9,600.00 74.75 330.54 4,961.02 5,988.41 -3,468.27 6,880.44 0.00 0.00 0.00 9,700.00 74.75 330.54 4,987.33 6,072.42 -3,515.72 6,976.25 0.00 0.00 0.00 9,800.00 74.75 330.54 5,013.63 6,156.42 -3,563.16 7,072.05 0.00 0.00 0.00 9,900.00 74.75 330.54 5,039.94 6,240.43 -3,610.61 7,167.86 0.00 0.00 0.00 10,000.00 74.75 330.54 5,066.24 6,324.43 -3,658.06 7,263.67 0.00 0.00 0.00 4/23/2019 10:47:08AM Page 5 COMPASS 5000.14 Build 85D c ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 3H-35 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Project: Kuparuk River Unit -2 MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad North Reference: True Well: Plan: 31-1-35 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-35 Azimuth Depth Design: 3H-35wp04 Section Rate 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) (°/100usft) (°/100usft) (°/100usft) 10,100.00 74.75 330.54 5,092.55 6,408.43 -3,705.51 7,359.47 0.00 0.00 0.00 10,200.00 74.75 330.54 5,118.85 6,492.44 -3,752.95 7,455.28 0.00 0.00 0.00 10,300.00 74.75 330.54 5,145.15 6,576.44 -3,800.40 7,551.08 0.00 0.00 0.00 10,400.00 74.75 330.54 5,171.46 6,660.45 -3,847.85 7,646.89 0.00 0.00 0.00 10,500.00 74.75 330.54 5,197.76 6,744.45 -3,895.30 7,742.70 0.00 0.00 0.00 10,600.00 74.75 330.54 5,224.07 6,828.46 -3,942.75 7,838.50 0.00 0.00 0.00 10,700.00 74.75 330.54 5,250.37 6,912.46 -3,990.19 7,934.31 0.00 0.00 0.00 10,800.00 74.75 330.54 5,276.68 6,996.47 -4,037.64 8,030.11 0.00 0.00 0.00 10,900.00 74.75 330.54 5,302.98 7,080.47 -4,085.09 8,125.92 0.00 0.00 0.00 11,000.00 74.75 330.54 5,329.29 7,164.48 -4,132.54 8,221.73 0.00 0.00 0.00 11,100.00 74.75 330.54 5,355.59 7,248.48 -4,179.98 8,317.53 0.00 0.00 0.00 11,200.00 74.75 330.54 5,381.89 7,332.49 -4,227.43 8,413.34 0.00 0.00 0.00 11,300.00 74.75 330.54 5,408.20 7,416.49 -4,274.88 8,509.14 0.00 0.00 0.00 11,400.00 74.75 330.54 5,434.50 7,500.49 -4,322.33 8,604.95 0.00 0.00 0.00 11,500.00 74.75 330.54 5,460.81 7,584.50 -4,369.78 8,700.76 0.00 0.00 0.00 11,600.00 74.75 330.54 5,487.11 7,668.50 -4,417.22 8,796.56 0.00 0.00 0.00 11,700.00 74.75 330.54 5,513.42 7,752.51 -4,464.67 8,892.37 0.00 0.00 0.00 11,800.00 74.75 330.54 5,539.72 7,836.51 -4,512.12 8,988.17 0.00 0.00 0.00 11,900.00 74.75 330.54 5,566.03 7,920.52 -4,559.57 9,083.98 0.00 0.00 0.00 12,000.00 74.75 330.54 5,592.33 8,004.52 -4,607.02 9,179.79 0.00 0.00 0.00 12,100.00 74.75 330.54 5,618.64 8,088.53 -4,654.46 9,275.59 0.00 0.00 0.00 12,200.00 74.75 330.54 5,644.94 8,172.53 -4,701.91 9,371.40 0.00 0.00 0.00 12,300.00 74.75 330.54 5,671.24 8,256.54 -4,749.36 9,467.21 0.00 0.00 0.00 12,400.00 74.75 330.54 5,697.55 8,340.54 -4,796.81 9,563.01 0.00 0.00 0.00 12,500.00 74.75 330.54 5,723.85 8,424.55 -4,844.25 9,658.82 0.00 0.00 0.00 12,600.00 74.75 330.54 5,750.16 8,508.55 -4,891.70 9,754.62 0.00 0.00 0.00 12,683.66 74.75 330.54 5,772.17 8,578.83 -4,931.40 9,834.78 0.00 0.00 0.00 12,700.00 75.04 330.13 5,776.42 8,592.54 -4,939.20 9,850.45 3.00 1.75 -2.52 12,800.00 76.80 327.63 5,800.76 8,675.56 -4,989.34 9,947.04 3.00 1.77 -2.50 12,900.00 78.59 325.17 5,822.06 8,756.92 -5,043.41 10,044.63 3.00 1.79 -2.46 13,000.00 80.40 322.73 5,840.29 8,836.40 -5,101.27 10,142.95 3.00 1.81 -2.43 13,100.00 82.23 320.33 5,855.39 8,913.79 -5,162.76 10,241.71 3.00 1.83 -2.41 13,200.00 84.07 317.94 5,867.31 8,988.86 -5,227.72 10,340.66 3.00 1.84 -2.39 13,300.00 85.93 315.57 5,876.03 9,061.42 -5,295.96 10,439.52 3.00 1.85 -2.37 13,357.88 87.00 314.21 5,879.60 9,102.18 -5,336.89 10,496.59 3.00 1.86 -2.36 13,377.88 87.00 314.21 5,880.65 9,116.11 -5,351.21 10,516.29 0.00 0.00 0.00 13,400.00 87.44 314.21 5,881.72 9,131.52 -5,367.05 10,538.08 2.00 2.00 0.00 13,500.00 89.44 314.21 5,884.44 9,201.21 -5,438.70 10,636.65 2.00 2.00 0.00 13,516.66 89.78 314.21 5,884.55 9,212.83 -5,450.65 10,653.08 2.00 2.00 0.00 13,600.00 89.78 314.21 5,884.88 9,270.93 -5,510.38 10,735.26 0.00 0.00 0.00 13,700.00 89.78 314.21 5,885.27 9,340.66 -5,582.07 10,833.86 0.00 0.00 0.00 13,800.00 89.78 314.21 5,885.66 9,410.38 -5,653.75 10,932.47 0.00 0.00 0.00 13,900.00 89.78 314.21 5,886.05 9,480.10 -5,725.44 11,031.08 0.00 0.00 0.00 14,000.00 89.78 314.21 5,886.44 9,549.82 -5,797.12 11,129.69 0.00 0.00 0.00 14,100.00 89.78 314.21 5,886.83 9,619.55 -5,868.80 11,228.30 0.00 0.00 0.00 14,200.00 89.78 314.21 5,887.23 9,689.27 -5,940.49 11,326.91 0.00 0.00 0.00 14,300.00 89.78 314.21 5,887.62 9,758.99 -6,012.17 11,425.51 0.00 0.00 0.00 14,400.00 89.78 314.21 5,888.01 9,828.72 -6,083.85 11,524.12 0.00 0.00 0.00 14,500.00_. 89.78 314.21 _ 5,888.40 9,898.44 -6,155.54_ _--11,622.73 0.00 _0.00 0.00 14,551.10 89.78 314.21 5,888.60 9,934.07 -6,192.17 11,673.12 0.00 0.00 0.00 14,578.49 89.23 314.18 5,888.84 9,953.16 -6,211.81 11,700.13 2.00 -2.00 -0.08 14,600.00 89.23 314.18 5,889.13 9,968.15 -6,227.23 11,721.33 0.00 0.00 0.00 14,700.00 89.23 314.18 5,890.47 10,037.84 -6,298.93 11,819.93 0.00 0.00 0.00 14,800.00 89.23 314.18 5,891.82 10,107.53 -6,370.64 11,918.52 0.00 0.00 0.00 4/23/2019 10:47:08AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 31-1-35 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Project: Kuparuk River Unit -2 MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad North Reference: True Well: Plan: 31-1-35 Survey Calculation Method: Minimum Curvature Wellbore: 3H-35 (1) (usft) Design: 3H-35wp04 (usft) (°/100usft) 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) (°/100usft) (°/100usft) 14,900.00 89.23 314.18 5,893.17 10,177.22 -6,442.34 12,017.12 0.00 0.00 0.00 15,000.00 89.23 314.18 5,894.52 10,246.91 -6,514.04 12,115.71 0.00 0.00 0.00 15,100.00 89.23 314.18 5,895.86 10,316.60 -6,585.75 12,214.30 0.00 0.00 0.00 15,200.00 89.23 314.18 5,897.21 10,386.29 -6,657.45 12,312.90 0.00 0.00 0.00 15,300.00 89.23 314.18 5,898.56 10,455.99 -6,729.15 12,411.49 0.00 0.00 0.00 15,400.00 89.23 314.18 5,899.90 10,525.68 -6,800.86 12,510.09 0.00 0.00 0.00 15,500.00 89.23 314.18 5,901.25 10,595.37 -6,872.56 12,608.68 0.00 0.00 0.00 15,600.00 89.23 314.18 5,902.60 10,665.06 -6,944.27 12,707.27 0.00 0.00 0.00 15,700.00 89.23 314.18 5,903.94 10,734.75 -7,015.97 12,805.87 0.00 0.00 0.00 15,800.00 89.23 314.18 5,905.29 10,804.44 -7,087.67 12,904.46 0.00 0.00 0.00 15,900.00 89.23 314.18 5,906.64 10,874.13 -7,159.38 13,003.05 0.00 0.00 0.00 16,000.00 89.23 314.18 5,907.98 10,943.82 -7,231.08 13,101.65 0.00 0.00 0.00 16,100.00 89.23 314.18 5,909.33 11,013.51 -7,302.78 13,200.24 0.00 0.00 0.00 16,200.00 89.23 314.18 5,910.68 11,083.20 -7,374.49 13,298.84 0.00 0.00 0.00 16,268.45 89.23 314.18 5,911.60 11,130.90 -7,423.57 13,366.32 0.00 0.00 0.00 16,282.36 89.50 314.25 5,911.75 11,140.60 -7,433.54 13,380.04 2.00 1.95 0.45 16,300.00 89.50 314.25 5,911.91 11,152.91 -7,446.17 13,397.44 0.00 0.00 0.00 16,400.00 89.50 314.25 5,912.78 11,222.68 -7,517.80 13,496.05 0.00 0.00 0.00 16,500.00 89.50 314.25 5,913.66 11,292.46 -7,589.44 13,594.67 0.00 0.00 0.00 16,600.00 89.50 314.25 5,914.53 11,362.23 -7,661.07 13,693.29 0.00 0.00 0.00 16,700.00 89.50 314.25 5,915.40 11,432.00 -7,732.70 13,791.90 0.00 0.00 0.00 16,800.00 89.50 314.25 5,916.28 11,501.77 -7,804.33 13,890.52 0.00 0.00 0.00 16,900.00 89.50 314.25 5,917.15 11,571.55 -7,875.96 13,989.14 0.00 0.00 0.00 17,000.00 89.50 314.25 5,918.03 11,641.32 -7,947.59 14,087.76 0.00 0.00 0.00 17,100.00 89.50 314.25 5,918.90 11,711.09 -8,019.22 14,186.37 0.00 0.00 0.00 17,200.00 89.50 314.25 5,919.77 11,780.86 -8,090.86 14,284.99 0.00 0.00 0.00 17,300.00 89.50 314.25 5,920.65 11,850.64 -8,162.49 14,383.61 0.00 0.00 0.00 17,400.00 89.50 314.25 5,921.52 11,920.41 -8,234.12 14,482.23 0.00 0.00 0.00 17,500.00 89.50 314.25 5,922.40 11,990.18 -8,305.75 14,580.84 0.00 0.00 0.00 17,600.00 89.50 314.25 5,923.27 12,059.95 -8,377.38 14,679.46 0.00 0.00 0.00 17,700.00 89.50 314.25 5,924.14 12,129.72 -8,449.01 14,778.08 0.00 0.00 0.00 17,800.00 89.50 314.25 5,925.02 12,199.50 -8,520.64 14,876.69 0.00 0.00 0.00 17,900.00 89.50 314.25 5,925.89 12,269.27 -8,592.27 14,975.31 0.00 0.00 0.00 18,000.00 89.50 314.25 5,926.76 12,339.04 -8,663.91 15,073.93 0.00 0.00 0.00 18,100.00 89.50 314.25 5,927.64 12,408.81 -8,735.54 15,172.55 0.00 0.00 0.00 18,200.00 89.50 314.25 5,928.51 12,478.59 -8,807.17 15,271.16 0.00 0.00 0.00 18,300.00 89.50 314.25 5,929.39 12,548.36 -8,878.80 15,369.78 0.00 0.00 0.00 18,400.00 89.50 314.25 5,930.26 12,618.13 -8,950.43 15,468.40 0.00 0.00 0.00 18,500.00 89.50 314.25 5,931.13 12,687.90 -9,022.06 15,567.01 0.00 0.00 0.00 18,600.00 89.50 314.25 5,932.01 12,757.68 -9,093.69 15,665.63 0.00 0.00 0.00 18,700.00 89.50 314.25 5,932.88 12,827.45 -9,165.32 15,764.25 0.00 0.00 0.00 18,800.00 89.50 314.25 5,933.76 12,897.22 -9,236.96 15,862.87 0.00 0.00 0.00 18,896.64 89.50 314.25 5,934.60 12,964.65 -9,306.18 15,958.17 0.00 0.00 0.00 18,900.00 89.49 314.31 5,934.63 12,967.00 -9,308:59 15,961.48 2.00 -0.36 1.97 19,000.00 89.13 316.28 5,935.84 13,038.06 -9,378.92 16,060.38 2.00 -0.36 1.97 19,029.47 89.02 316.86 5,936.32 13,059.46 -9,399.17 16,089.61 2.00 -0.36 1.97 19,100.00 89.02 316.86 5,937.52 13,110.92 -9,447.40 16,159.62 0.00 0.00 0.00 19,200.00 89.02 316.86 5,939.23 13,183.88 -9,515.77 16,258.88 0.00 0.00 0.00 _19,300.00 89.02 316.86 _ _ 5,940.94 _13,256.83 _ . - -9,584.13 16,358.14 0.00 0.00 _ _ _ .0.00. 19,400.00 89.02 316.86 5,942.65 13,329.79 -9,652.50 16,457.40 0.00 0.00 0.00 19,500.00 89.02 316.86 5,944.36 13,402.75 -9,720.87 16,556.65 0.00 0.00 0.00 19,600.00 89.02 316.86 5,946.07 13,475.71 -9,789.24 16,655.91 0.00 0.00 0.00 19,700.00 89.02 316.86 5,947.78 13,548.67 -9,857.61 16,755.17 0.00 0.00 0.00 19,800.00 89.02 316.86 5,949.49 13,621.62 -9,925.98 16,854.43 0.00 0.00 0.00 4123/2019 10:47.08AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips s ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 3H-35 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Project: Kuparuk River Unit -2 MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad North Reference: True Well: Plan: 3H-35 Survey Calculation Method: Minimum Curvature Wellbore: 3H-35 Design: 3H-35wp04 Planned Survey Measured Dip Dir. TVD Vertical +E/ -W Northing Shape (°) Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) 5,955.60 6-3/4" x 4-1/2" (I (usft) (usft) (usft) (usft) (°/100usft) (°I100usft) (°/100usft) 19,900.00 89.02 316.86 5,951.20 13,694.58 -9,994.34 16,953.69 0.00 0.00 0.00 20,000.00 89.02 316.86 5,952.91 13,767.54 -10,062.71 17,052.95 0.00 0.00 0.00 20,100.00 89.02 316.86 5,954.62 13,840.50 -10,131.08 17,152.20 0.00 0.00 0.00 • 20,157.63 89.02 316.86 • 5,955.60 13,882.54 -10,170.48 17,209.41 0.00 0.00 0.00 Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Shape (°) Diameter (I (usft) (usft) (usft) (usft) 3H-35 Heel BT 042219 0.00 0.00 5,879.60 9,102.18 -5,336.89 plan hits target center 7.625 9.875 20,157.63 5,955.60 6-3/4" x 4-1/2" 4.500 Circle (radius 1,320.00) 31-1-35 Tgt01 BT 042219 0.00 0.00 5,888.60 9,934.07 -6,192.17 - plan hits target center - Circle (radius 100.00) 3H-35 Tgt02 BT 042219 0.00 0.00 5,911.60 11,130.90 -7,423.57 plan hits target center Circle (radius 100.00) 3H-35 Tgt03 BT 042219 0.00 0.00 5,934.60 12,964.65 -9,306.18 plan hits target center Circle (radius 100.00) 31-1-35 Toe BT 042219 0.00 0.00 5,955.60 13,882.54 -10,170.48 - plan hits target center - Circle (radius 1,320.00) Casing Points Easting (usft) Latitude Longitude Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 3,573.77 3,257.00 13-1/2" x 10-3/4" 10.750 13.500 13,357.88 5,879.60 9 7/8" x 7-5/8" 7.625 9.875 20,157.63 5,955.60 6-3/4" x 4-1/2" 4.500 6.750 4/23/2019 10:47:08AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP1 Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 31-1-35 Wellbore: 31-1-35 Design: 3H-35wp04 Formations Measured Depth (usft) 1,671.67 2,556.52 3,006.42 3,381.55 5,884.20 7,408.65 11,176.07 11, 582.84 12,346.97 12,445.81 12,499.04 12,961.26 13, 256.12 13, 294.05 2d �lan Annotations Vertical Depth (usft) Name Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: 1,636.60 Base Permafrost 2,469.60 Top W Sak 2,858.60 Base W Sak 3,135.60 Camp SS 3,983.60 C-50 4,384.60 C-35 5,375.60 Top Moraine 5,482.60 Base Moraine 5,683.60 Top HRZ 5,709.60 Fault 1 85' DTE 5,723.60 Base HRZ / Top Kalubik 5,833.60 K1 5,872.60 Fault 2 20' DTE 5,875.60 Top Kuparuk 4949.66- TD • $. 927.62 Cw.�0e i Tw ConocoPhillips Standard Proposal Report Well Plan: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 231.60 231.60 0.00 0.00 KOP: Start -0.77°/100' DLS, 1.5° TF, for 100' 331.60 331.59 0.00 1.31 Start Drop -1.50 431.60 431.58 0.00 2.62 Start 37.68°/100' DLS, 2.5° TF, for 500' 931.60 927.62 9.43 -50.88 Start 159.96°/100' DLS, 3° TF, for 500' 1,431.60 1,410.21 92.10 -144.94 Start 489.97°/100' DLS, 0° TF, for 1000' 2,431.60 2,353.24 383.29 -305.89 Start 1779.24°/100' DLS, 3° TF, for 1843.89' 4,275.49 3,560.44 1,515.58 -941.90 Start 9834.78°/100' DLS, 0° TF, for 8408.17' 12,683.66 5,772.17 8,578.83 -4,931.40 Start 10496.59°/100' DLS, 3° TF, for 674.21' 13,357.88 5,879.60 9,102.18 -5,336.89 Start 10516.29°/100' DLS, 0° TF, for 20' 13,377.88 5,880.65 9,116.11 -5,351.21 Start 10653.08°/100' DLS, 2° TF, for 138.79' 13,516.66 5,884.55 9,212.83 -5,450.65 Start 11673.12°/100' DLS, 0° TF, for 1034.44' 14,551.10 5,888.60 9,934.07 -6,192.17 Start 11700.13°/100' DLS, 2° TF, for 27.39' 14,578.49 5,888.84 9,953.16 -6,211.81 Start 13366.32°/100' DLS, 0° TF, for 1689.96' 16,268.45 5,911.60 11,130.90 -7,423.57 Start 13380.04°/100' DLS, 2° TF, for 13.91' 16,282.36 5,911.75 11,140.60 -7,433.54 Start 15958.17°/100' DLS, 0° TF, for 2614.28' 18,896.64 5,934.60 12,964.65 -9,306.18 Start 16089.61°/100' DLS, 2° TF, for 132.82' 19,029.47 5,936.32 13,059.46 -9,399.17 Start 17209.4°/100' DLS; 0° TF, for 1128.16' 20,157.63 5,955.60 13,882.54 -10,170.48 TD: 20157.63' MD, 5955.6' TVD 4/23/2019 10:47:08AM Page 9 COMPASS 5000.94 Build 85D V/ CL V c 0 A 1 m E E m co W i A, U r 0 N� /i C 0 ■ '0'+ El U � C N U) L d tl1 O C O °? w o y Q m r CL O O 3 U) ° + o M N M C Y N y � 3 � y L I M 3 C y IML � •1 R a N m y d xU M y Q M 0� W W tn 7 °- LL Q M m O 1D °' 'a Q J Q 7 Y m N m `° 7 m - N r S m C O N N JO CL C a c N ° U E ° w E A f0 co in C7 > •M� A D W , O Q V Cl)M x 0 O �C Y = M X W) M M 3.1 LO O Rf Q Y Q Y M o T M V a M L M V/ CL V c 0 A 1 m E E m co W i A, U r 0 N� /i C 0 ■ '0'+ El i.i s ACL 0 0 c 0 V U � C N U) d tl1 O C O °? w o y Q m r a O O 3 U) ° + o M N M C M N y � 3 � y L M 3 C y IML � •1 R a IL m y d xU M y Q M 0� W W tn 7 °- LL t0 d M m O 1D °' 'a Q J Q 7 Y m N m `° 7 m - N r S m C O N N JO C a c U p 2 m m C ° U E ° w O A f0 co in C7 > {O 10 in i i.i s ACL 0 0 c 0 V M, c a O � N W n a U N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N caN a LL a LL LL a a LL a LL a a a a a a LL a n. n. a a LL a a a a_ CL C C C C tti t5 m m m c m N m m m m m d LL LL LL m d LL d LL LL LL a LL U U U j5 (n U U U U U C C C C C C c c a m m m a 0 m 0 N m N a N o w ami am m o a) ° ami ami ami a w W U U U U W U W U U U W U f� m M ao aD M O M O IO O a0 0 1� N O O if1 v 0 co (D (O M O OR N M N O N N O C C C C C c O O` O `p a7 O `O N O p N O `O a O m U (` U C N O C m U C m U U 1 6 aLL 0. 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C LL d z N N N C d d U d o O O O O O O ' c o N N N N N N o - J J J J J J 0 Q a O d Q a d , 0 0 U U U J O O O O O O 2 U M� U 0 2 2 2 2 2 2 x d M M M M M M E va E S r X N 7 N co N N N o 0.0.0..0.0 y 7 N m N N N N N N N C N J J J J J J J U U U U U U U O o 0 0 0 0 0 0 0 Z o 0 (c w d 2 2 2 2 2 2 2 c d a Zo a 0 0 0 0 0 0 0 M M c C N U M M M M M j wd R d ` - co N a a O o J J m m m m m Cl) co IL a. a a 0- o U UJ J J J J J Q Q J J M M 0 0 0 _ _ = Q Q N N � N N N Q Q V M 2 2 N M M m m M M M N N 2 2 2 2 2 2 M M r M 2 2 - - _= M M M M M M Cl) co m m m 2 2 M M - o O N N M M m m S 2 co M co co M d O_ M M � � J J J J J J LL O_ M M J J J J U U U Q Q Q Q Q Q Q Q Q QQ Q Q Q Q Q O O O N N N N M M N N N N N N N N Cl) Cl) M M M M 5 2 2 2 2 5 2 2 2 2 2 22 2 2 2 2 2 2 2 2 2 2 M M M M M M M M M M M M co M M M M M M M M M M O O o N N N N N N N N N N N M M M M M M M M 22 2 2 2 5 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Cl) M co M co co co co co M co M M M M M M M M M M M M co a 0 U co O M 01 12 M, d � a 7 a V C O � a 0 ° C C E (� b O 'E w (`a O. a N 7 a 0 m 410 0 x CD CL a °' E M t 7 M a N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N m m m m m m m m m m m m N m m m m m m m m m m m m m m m m m m a LL a a a. n. a_ a a_ a a a a_ a a a a_ a a a LL a_ LL a_ a_ a_ a_ a_ a M a. CC C C C C C C C C C C C C O O O O O O O O a O O O O O a1 O O O O O O O O O O O i0 U is U N U N U N U O fp U U is U U is U i0 U is 5 (a U is V jp U i0 U m m m m m C m C m C m m m m m m m m LL m W N W (0 W (6 LL m m LL m m LL m m LL 0 W 0 LL m LL m LL m LL m LL a a 0 a 0 m (D a w m N C a N a a N a� m a 0 m a� 0 m m m a m w C C C CO C C C C C C m C m C C C C a m a in a m a m a in m m a m m m a m a T a m a m a m a m N m N m N N N N N N N N N N N N N _a _n m n a n ami n ami ro a ami d w 2 ami ° ami °- (U ami a ami ami ° ami w U w U w U w U w U U w U U W U U W U w U w U w 0 w U w U w U I- r- r 1\ t` r r r r w O m w m N w O to m w to 0 w Lo Ln w V M w w m N m N m N m N m N m m r r r- w w f- r m M O O O O O O V' O N 00 P-: Nrl� N r N r N r N r M O rl M O r M O w OR I� w il� w f-, w r I- m V V wN r N w V M V M w 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m w m w a w m w m w M tc C M to m M w m M a M m M m M m w rl w r- -- M r m r M r M r M to to w w to to to w w O w O w O w 0 w O w I- N 0 w n r to m m N m_ m_ m_ M w m o O O O O O O O O O O w O 1- N O O w m to I� M M M M N to N V f- V f- V I,- V r V h M 1- w M r� w M w w w O w 7 w V w V' N I-- N r N N N N N N N N N N M M V M M M M M M M � M M M rl-M M M M M M M N N N N N N N N N N M N m V m to d' m to w m to M to co w M O p- O f - to m w m w m m m N m O r (O N M N N M N (O M O N O" O N w I- (O Il C V V 'V '7 V V d' * V I- V N to M w w M w Ln N N O N O h O r N r N w M w M w M w M w M N w M N m co N m m r� m m m m w m w o w m w m w O N w O N to O N to N m M m M m M m w 1� w I: r M - Cl) r M r Cl) - Cl) w w w w w (D w w (D r r O O O O O O O O O O m m w O w N O N N to m 0 w w w w N O w O w w O w O w O w O w O w N V f- w Il r w Il V w N M to M N M V O V O O N O N O N O N O N '7 w I- V w It V w V O N O to O m O m N w N w N m N M N M N M N M [t tF to V V try V V o M co m M co M M Cl) V N N N N N N N N N N M N m [Y m w 'V m So w m m M m M 0 M O r o t - to m N m w m m m w m9 r w N Cl N N Cl N w Cl O N O N O N w I� w I- V t V V 7 7 't V V 7 I, V N w co w w co w (o Nan O to O h O r N r N w M w M w M w M w co N w Cl) N m Cl) N m m f- r m m m CIL w m w m w m w m w O N w O N N O N w N m M m M a! M m (O I� ( n r Cl) r M r Cl) r Cl) r Cl) w w w w w w w w w r m m LL a_ J J J < < N N Q Q Q N N N Q Q 2 S M M M to w co M N N N 2 2 2 w (o N N 2 2 2 M M M N N S 2 M M co = = M M m m J J J co M d LL M M M M m M m to to to Lo w N N N N N N N N N N N N 2 2 2 2 2 2 2 2 2 2 2 2 co co co co M co co co M M M M M M co M M M m m m to w to N N N N N N N N N N N N 2 2 2 2 2 2 2 2 2 2 2 2 M M co M Cl) M Cl) M Cl) M co co N 04 m m N N J J 2 2 w w Cl) M N N N N = _ aa M M M M (ao try w w w w N N N N N N 2 2 2 2 2 2 Cl) co Cl) M co M to w w w w w N N N N N N 2 2 2 2 2 2 M M M M M M w O 7 C M L O M .y a La Q 0 0 = a ° M ` E N LL m a m z N N M M m m N N M M m m m m a a° 0 0 0 o d a o_ LL a LL 2 gm ° l-, J J J J J J J J J ',r M U r 2 2 r r r r 2 2 2 2 M . 2= S 2 M M M M M M Y a M M M M La (a M r' o m- m z 0 0 0 0 m m m m m m N NM NCL 7 N a? M M M M M M M M C O N M (a7 M Co M O N' C N N N y Ow 'm a 2 2 2 2 2 2 2 2 2 2 2 2 2 a E - M M M M M M M M M M M M M a m m Z O. M M M M M coCl)Cl)Cl)Cl)M Cl) M V>T C a N N N 2 2 2 2 2 2 2 2 2 2 C c 0 M M M M M M M M co M M y d V O ca co m m LL a_ J J J < < N N Q Q Q N N N Q Q 2 S M M M to w co M N N N 2 2 2 w (o N N 2 2 2 M M M N N S 2 M M co = = M M m m J J J co M d LL M M M M m M m to to to Lo w N N N N N N N N N N N N 2 2 2 2 2 2 2 2 2 2 2 2 co co co co M co co co M M M M M M co M M M m m m to w to N N N N N N N N N N N N 2 2 2 2 2 2 2 2 2 2 2 2 M M co M Cl) M Cl) M Cl) M co co N 04 m m N N J J 2 2 w w Cl) M N N N N = _ aa M M M M (ao try w w w w N N N N N N 2 2 2 2 2 2 Cl) co Cl) M co M to w w w w w N N N N N N 2 2 2 2 2 2 M M M M M M w O 7 IA CL c �CL 0 (i0 i 0 V U) a 0 O E U c 0 R G N N N N N N N N N N N N N N N N NN N N N N C (Q lQ co (0 lQ y N N y N N (0 N (6 (6 (6 (6 N N N (0 (0 ( o- a a a o- a n.. c 0 d c c c `o c c c c m E g o` 9 g o` O o` O m E m LL m (m m LL m LL m LL m LL c m (L R C Nd N d d d d d d d d E 'nW W C() d d C C N O N w N m C m OO UJ UE O GN N N m m ma N mN N GG N c + + +G ai U w o w (5 w U w U ul U w U w U Z r- M n M m m O N V (O O O 7 (p (D + 0+ (D + d V M M N O] V V m m ao '1' c(O M Cl) m co m (D M m N f� 00 M U) (n N U) N (n N > 0' > w> R' O O N M m Ln m ((> m (n f� (n V N C) > > > LL (D O + O + O + ( 0 0 0 0 0 0 0 0 0 0 0 r- 0 0 0 a O O O O O O O O O O O N O O O N OO O O O O O O O O O 7 O O O L y Q 0 0 0 0 0 0 m m O O O O O r m m m m M O O O O n (f1 I-- O �2 V O co Un O N M N M m m r- r M M C r r Ln L(1 M M O r m N V (O V O y- co N N r- O (O - M - N O O w O Ln N V N O N O V r O W O Un CL A$ M N W 6 d y O a O r- O r- r CO (o � O o r` (q I r- m r- C7 Un 0 0 0 o v m Ln O r Ln Ln Lq i r (IJ r N I- N r` N r N U) 7 O o] co C L m m m m m m O N V N O W m m m m m m Cl) (D m d Cc d - - - - .-- LO t0 J. � p d a d � � ++ � (o £ - O co O W N m : O V O O N q: N m N m M m O N O Cl! M w M fl - r OR m M E (D N m N co r- N I-- m I- N N V N LO N 1.11.1 W = C$ E V M m co m M m Lo M N LI) N N C O .9 y C y - - - N o^ d mmmmmmm v% O r- O � r m r- M r M M y Ln O r- N N 0 N N N N Q Q Q Q Q Q Q 3 V N d C y a L (O r� (o � O o r N r- N r N o O O O V m n N r N Ln T r Lq Ln O m m V V V V V V V m = y a N (O f� (O f� m m m m m m M (O r � m G G G G G G G Y! w w 1° v v v n m n n n n n n n M d p - - - -- M M M M M M 2 ) v S 2 2 m m m 2 M O M M M M M M M a y 3in L E M t0 M O O r- t` W m M r- 2 M y N O O u� O M W �2 T F N CO LO V O Cl) L M S M V N 7 O. 7 y (p N04, d V C1 Q E 2 r a a O C O LL N n n v v v a O O Orl� r CO W O c d v w z o o G G O O O O O of o o M m r-� O O o Ln o do 3 3 3 3 3 3 3 o m cori r r— o o Ln Ln M co 41 L G a N N O O O O Q Q M M fl- r r- O LL `. r M co M L m m$ lO ,O __ _ _ N N M M M M M (V O^ N d. to 2 7 C.i d J J J J 07 D] M M S= a S 2 S = S S CL = M M N N N N M M N N M M M M M Q O S S S S w , ` y E M M M M N N S S Q Q M M M M M CA E R = G O (O W Z M M N N C' M M 2 2 M M S 2 2 M M M d N W _ O O O O S S _ _ _ = N Y y d M M m m M M CL 0 - .i •y t•' C O N (JO 0 0 (JO N N N N E E m m m m m Q v� O fT O N C N N N N M M M M- - Q Z •y O N d S S S S S S S S cm') M M M M N N d 'y E M M M M M M M M N O a Q d W m M M M Cl) Cl) E d C a ' V Z G co (O (O (D N N N N N N M M N N N N M M M M C C C C C () d a ; O O (!i U M M M Cl) M M M M M M Q ) 4 H � � to 10:47 Apill 23 2019 3H-35wpO4 Ladder View o m a J 300-- 00 —o 0 .2 (0CL I _o a) (n M i 3 15 0 Ti o 2 c a) M � i U o o I (^ Equivalent Magnetic Distance 0 "' 0 850 1700 2550 3400 4250 5100 5950 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1000.00 3H-35wp04 (31-1-35) GYD-GC-SS 3257.00 3573.7713-1/2" x 10-3/4" 1000.00 2000.00 3H-35wp04 (31-1-35) MWD OWSG 5879.6013357.88 9 7/8" x 7-5/8" 1000.00 3573.77 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS 5955.6C20157.63 6-3/4" x 4-1/2" 3573.77 5073.77 3H-35wp04 (31-1-35) MWD OWSG 3573.7713357.88 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS 13357.8814857.88 3H-35wp04 (31-1-35) MWD OWSG 13357.8820157.63 3H- w 4 MWD+IFR2+ A +M N O ca m a a) a� n C Equivalent Magnetic Distance al U O ami 0 U 0 250 500 750 1000 1250 150 Partial Measured Depth SURVEY PROGRAM From To Tool MD Inc Azi . Dleg TFace Target Annotation 39.00 1000.00 GYD-GC-SS 39.00 0.00 0.00 39.00 0.00 0.00 1000.00 3573.77 MVJD+IFR2+SAG+MS 331.60 1.50 90.00 331.59 1.50 90.00 Start Drop -1.50 3573.77 5073.77 MWD OWSG 431.60 0.00 0.00 431.58 1.50 180.00 Start 37.68'/100' DLS, 2.5* TF, for 500' 3573.7713357.88 MVJD+IFR2+SAG+MS 931.60 12.50 280.00 927.62 2.50 280.00 Start 159.96*/100' DLS, 3' TF, for 500' 13357.8814857.88 MVVD OWSG 1431.60 19.43 331.07 1410.21 3.00 90.00 Start 489.97*/100' DLS, 0' TF, for 1000' 13357.8620157.63 MWD+IFR2+SAG+MS 2431.60 19.43 331.07 2353.24 0.00 0.00 Start 1779.24*/100' DLS, 3' TF, for 1843.89' 4275.49 74.75 330.54 3560.44 3.00 -0.62 Start 9834.78'/100' DLS, Oo TF, for 8408.17' 12683.66 74.75 330.54 5772.17 0.00 0.00 Start 10496.59'/100' DLS, 3o TF, for 674.21' 13357.88 87.00 314.21 5879.60 3.00 -54.33 31-1-35 Heel BT 042219 Start 10516.29'/l 00' DLS, Oo TF, for 20' 13377.88 87.00 314.21 5880.65 0.00 0.00 Start 10653.08'/l 00' DLS, 2* TF, for 138.79' 13516.66 89.78 314.21 5884.55 2.00 0.00 Start 11673.12'/100' DLS, 0' TF, for 1034.44' 14551.10 89.78 314.21 5888.60 0.00 00 31-1-35 Tgt01 BT 042219 Start 11 14578.49 89.23 314.18 5888.84 �0 00 . 16268.45 89.23 314.18 5911.60 0.00 0.00 31-1-35 Tgt02 BT 042219 Start 13380.04'/l 00' DLS, 2' TF, for 13.91' 16282.36 89.50 314.25 5911.75 2.00 13.00 Start 15958.17'/100' DLS, 0' TF, for 2614.28' 111896.64 89.50 314.25 5934.60 0.00 0.00 31-1-35 Tgt03 BT 042219 Start 16089.61'/100' DLS, 2* TF, for 132.82' 20157.63 89.02 316.86 5955.60 0.00 0.00 31-1-35 Toe BT 042219 TD: 20157.63'MD, 5955.6'TVD CASING DETAILS TVD MD Name .• .0 ..0.� &3/4" i`.�'�`Mb g410 39 232 232 410gso81C'i� 590 �`�',, ONE 590 780 / a��lr/��. .oL ► • 1 ��.`�\�J��1111Y41/gC•i+Ii,.yr �• 780 • 60 i 960 1140 a . •s �� '�L1 �i Iii'►/�%/G 1140 1320 Ldp== �:��I��ri'i ,'"� ♦ � •�e�-•,. 1320 1500 I •r. �•�� 1500 2280 I �%t ':mss. ��' �� lI �.�. 2280 3050 WON 3050 - 3830 4600 53: 1 5380 - 6150 6150 6930 6930 7700 ::. ice• �. Y'' , 11 9260 ►4 i..�1��. w 1 9260 10810 ' `E �f N, 10810 12370 13930 15490 1 17040 `18600 17040 1186001 - 20158'1 ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit—2 Kuparuk 3H Pad Plan: 31-1-35 50103xxxxx00 3H-35 Plan: 3H-35wp04 Error Ellipse Survey Report 23 April, 2019 Company: ConocoPhillips Alaskalnc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 3H-35 Wellbore: 3H-35 Design: 3H-35wp04 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3H-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Project Kuparuk River Unit -2, 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 3H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well Plan. 3H-35 Well Position +N/ -S 0.00 usft Northing: Latitude: Position Uncertainty +E/ -W 0.00 usft Easting: 0.00 usft Wellhead Elevation: Longitude: Ground Level: — 36.60 usft Wellbore 3H-35 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 12/15/2019 16.22 80.87 57,393 Design 3H-35wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +NAS +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 323.77 Survey Tool Program Date 4/23/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,000.00 3H-35wp04 (31-1-35) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 3H-35wp04 (31-1-35) MWD OWSG OWSG MWD - Standard 1,000.00 3,573.77 3H-35wp04 (3H-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 3,573.77 5,073.77 3H-35wp04 (31-1-35) MWD OWSG OWSG MWD - Standard 3,573.77 13,357.88 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 13,357.88 14,857.88 3H-35wp04 (31-1-35) MWD OWSG OWSG MWD - Standard 13,357.88 20,157.63 3H-35wp04 (31-1-35) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 4/23/2019 10:47:50AM Page 2 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 3H-35 Wellbore: 31-1-35 Design: 3H-35wp04 Inclination Azimuth Date 4/23/2019 Plan Survey Tool Program Depth From Depth To (usft) (usft) Survey (Wellbore) 1 39.00 1,000.00 3H-35wp04 (31-1-35) 2 1,000.00 2,000.00 3H-35wp04 (31-1-35) 3 1,000.00 3,573.77 3H-35wp04 (31-1-35) 4 3,573.77 5,073.77 3H-35wp04 (3H-35) 5 3,573.77 13,357.88 3H-35wp04 (31-1-35) 6 13,357.88 14,857.88 3H-35wp04 (31-1-35) 7 13,357.88 20,157.63 3H-35wp04 (31-1-35) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Toot Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+I FR2+SAG+M S OWSG MWD + IFR2 + Sag + MWD OWSG OWSG MWD - Standard MWD+I FR2+SAG+MS OWSG MWD + IFR2 + Sag + MWD OWSG OWSG MWD - Standard MWD+I FR2+SAG+MS OWSG MWD + IFR2 + Sag + Well Plan: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semitnajor semi-iior Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azunuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 39.00 0.00. 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.00 - 0:00 0.00 100.00 0.09 0.00 0.09 0.00 2.30 0.00 0.00 0.09 0.09 0.00 GYD-GC-SS (1, 1) 200.00 0.00 0.00 200.00 0.38 0.00 0.38 0.00 2.30 0.00 0.00 0.38 0.38 0.00 GYD-GGSS (1, 1) 231.60 0.00 0.00 231.60 0.47 0.00 0.47 0.00 2.30 0.00 0.00 0.47 0.47 0.00 GYD-GC-SS (1, 1) 300.00 1.03 90.00 300.00 0.63 0.00 0.63 0.00 2.30 0.01 0.01 0.63 0.63 45.00 GYD-GC-SS (1, 1) 331.60 1.50 90.00 331.59 0.69 0.00 0.69 0.00 2.30 0.01 0.01 0.69 0.69 45.00 GYD-GC-SS (1, 1) 400.00 0.47 90.00 399.98 0.84 0.00 0.84 0.00 2.30 0.01 0.01 0.84 0.84 45.00 GYD-GC-SS (1, 1) 431.60 0.00 0.00 431.58 0.92 0.00 0.92 0.00 2.30 0.02 0.02 0.92 0.92 45.00 GYD-GGSS (1, 1) 500.00 1.71 280.00 499.97 1.06 0.00 1.06 0.00 2.31 0.02 0.02 1.06 1.06 5.74 GYD-GCSS (1, 1) 600.00 4.21 280.00 599.83 1.24 0.00 1.24 0.00 2.31 0.04 0.04 1.25 1.24 8.04 GYD-GCSS (1, 1) 700.00 6.71 280.00 699.36 1.45 0.00 1.46 0.00 2.31 0.05 0.05 1.47 1.46 7.80 GYD-GGSS (1, 1) 800.00 9.21 280.00 798.39 1.69 -0.01 1.72 0.00 2.30 0.07 0.07 1.73 1.72 4.91 GYD-GGSS (1, 1) 900.00 11.71 280.00 896.72 1.95 -0.01 2.01 0.00 2.30 0.09 0.09 2.01 2.00 108.19 GYD-GGSS (1, 1) 931.60 12.50 280.00 927.62 2.03 -0.01 2.12 0.00 2.29 0.10 0.10 2.12 2.10 106.81 GYD-GGSS (1, 1) 1,000.00 12.66 289.40 994.38 2.23 -0.01 2.35 0.00 2.29 0.11 0.11 2.35 2.29 99.84 GYD-GCSS (1, 1) 1,100.00 13.47 302.22 1,091.82 2.39 -0.01 2.55 0.00 2.52 0.00 0.01 2.56 2.46 99.82 MWD OWSG (1, 2) 1,200.00 14.83 313.17 1,188.80 2.47 -0.01 2.79 0.00 2.57 0.00 0.01 2.82 2.54 114.99 MWD OWSG (1, 2) 1,300.00 16.63 322.06 1,285.06 2.63 -0.01 3.26 0.00 2.62 0.00 0.01 3.31 2.68 125.09 MWD OWSG (1, 2) 1,400.00 18.72 329.15 1,380.35 2.86 -0.01 3.92 0.00 2.67 0.00 0.01 4.00 2.88 132.12 MWD OWSG (1, 2) 1,431.60 19.43 331.07 1,410.21 2.94 -0.01 4.16 0.00 2.68 0.00 0.01 4.26 2.96 133.77 MWD OWSG (1, 2) 1,500.00 19.43 331.07 1,474.71 3.11 -0.01 4.77 0.00 2.74 0.00 0.01 4.86 3.12 137.21 MWD OWSG (1, 2) 1,600.00 19.43 331.07 1,569.02 3.38 -0.01 5.73 0.00 2.83 0.00 0.01 5.79 3.37 140.40 MWD OWSG (1, 2) 1,700.00 19.43 331.07 1,663.32 3.68 -0.01 6.72 0.00 2.94 0.00 0.01 6.77 3.65 142.36 MWD OWSG (1, 2) 1,800.00 19.43 331.07 1,757.62 4.00 -0.01 7.73 0.00 3.05 0.00 0.01 7.78 3.95 143.68 MWD OWSG (1, 2) 4/23/2019 10:47:50AM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 31-1-35 Wellbore: 31-1-35 Design: 3H-35wp04 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 1,900.00 19.43 331.07 1,851.93 4.35 -0.01 8.76 0.00 3.17 0.00 0.01 8.81 4.27 144.64 MWD OWSG (1, 2) 2,000.00 19.43 331.07 1,946.23 4.70 -0.01 9.81 0.00 3.29 0.00 0.01 9.85 4.60 145.35 MWD OWSG (1, 2) 2,100.00 19.43 331.07 2,040.53 4.59 -0.01 6.01 0.00 3.36 0.00 0.01 6.05 4.53 141.36 MWD+IFR2+SAG+MS (2,2) 2,200.00 19.43 331.07 2,134.84 4.91 -0.01 6.51 0.00 3.48 0.00 0.01 6.55 4.82 142.08 MWD+IFR2+SAG+MS (2,2) 2,300.00 19.43 331.07 2,229.14 5.24 -0.01 7.03 0.00 3.61 0.00 0.01 7.06 5.12 142.65 MWD+IFR2+SAG+MS (2,2) 2,400.00 19.43 331.07 2,323.44 5.57 -0.01 7.54 0.00 3.75 0.00 0.01 7.58 5.43 143.11 MWD+IFR2+SAG+MS (2,2) 2,431.60 19.43 331.07 2,353.24 5.68 -0.01 7.71 0.00 3.79 0.00 0.01 7.74 5.53 143.23 MWD+IFR2+SAG+MS (2,2) 2,500.00 21.49 331.01 2,417.32 5.90 -0.01 8.08 0.00 3.88 0.00 0.01 8.11 5.75 143.50 MWD+IFR2+SAG+MS (2,2) 2,600.00 24.49 330.94 2,509.37 6.21 -0.01 8.67 0.00 4.01 0.00 0.01 8.71 6.08 143.92 MWD+IFR2+SAG+MS (2,2) 2,700.00 27.48 330.88 2,599.25 6.52 -0.01 9.33 0.00 4.14 0.00 0.01 9.37 6.41 144.36 MWD+IFR2+SAG+MS (2,2) 2,800.00 30.48 330.84 2,686.72 6.83 -0.01 10.06 0.00 4.29 0.00 0.01 10.09 6.73 144.82 MWD+IFR2+SAG+MS (2, 2) 2,900.00 33.48 330.80 2,771.53 7.12 -0.01 10.86 0.00 4.45 0.00 0.01 10.89 7.06 145.27 MWD+IFR2+SAG+MS (2, 2) 3,000.00 36.48 330.76 2,853.45 7.40 -0.01 11.74 0.00 4.62 0.00 0.01 11.77 7.37 145.70 MWD+IFR2+SAG+MS (2,2) 3,100.00 39.48 330.74 2,932.26 7.66 -0.01 12.70 0.00 4.81 0.00 0.01 12.72 7.68 146.11 MWD+IFR2+SAG+MS (2,2) 3,200.00 42.48 330.71 3,007.74 7.92 -0.01 13.73 0.00 5.00 0.00 0.01 13.76 7.97 146.50 MWD+IFR2+SAG+MS (2,2) 3,300.00 45.48 330.69 3,079.68 8.15 -0.01 14.85 0.00 5.22 0.00 0.01 14.88 8.26 146.85 MWD+IFR2+SAG+MS (2,2) 3,400.00 48.48 330.67 3,147.89 8.37 -0.01 16.06 0.00 5.44 0.00 0.01 16.08 8.53 147.17 MWD+IFR2+SAG+MS (2.2) 3,500.00 51.48 330.65 3,212.19 8.58 -0.01 17.34 0.00 5.68 0.00 0.01 17.36 8.79 147.47 MWD+IFR2+SAG+MS (2,2) 3,600.00 54.48 330.63 3,272.38 8.57 -0.01 18.47 0.00 5.33 0.00 0.01 18.49 9.51 147.53 MWD OWSG (2,3) 3,700.00 57.48 330.62 3,328.32 8.38 -0.01 19.86 0.00 5.40 0.00 0.01 19.87 9.58 148.00 MWD OWSG (2.3) 3,800.00 60.48 330.60 3,379.84 8.25 -0.01 21.81 0.00 5.54 0.00 0.01 21.82 9.66 148.50 MWD OWSG (2.3) 3,900.00 63.48 330.59 3,426.80 8.17 -0.01 24.25 0.00 5.75 0.00 0.01 24.26 9.76 148.93 MWD OWSG (2,3) 4,000.00 66.48 330.57 3,469.09 8.15 -0.01 27.11 0.00 6.03 0.00 0.01 27.12 9.86 149.27 MWD OWSG (2,3) 4,100.00 69.48 330.56 3,506.57 8.20 -0.01 30.32 0.00 6.38 0.00 0.01 30.32 9.97 149.53 MWD OWSG (2,3) 4,200.00 72.48 330.55 3,539.15 8.32 -0.01 33.80 0.00 6.79 0.00 0.01 33.81 10.08 149.73 MWD OWSG (2,3) 4,275.49 74.75 330.54 3,560.44 8.45 0.00 36.58 0.00 7.14 0.00 0.01 36.59 10.16 149.84 MWD OWSG (2,3) 4,300.00 74.75 330.54 3,566.88 8.57 0.00 37.51 0.00 7.26 0.00 0.01 37.51 10.18 149.88 MWD OWSG (2,3) 4,400.00 74.75 330.54 3,593.19 9.06 0.00 41.35 0.00 7.79 0.00 0.01 41.35 10.28 149.99 MWD OWSG (2,3) 4,500.00 74.75 330.54 3,619.49 9.58 0.00 45.28 0.00 8.34 0.00 0.01 45.28 10.38 150.07 MWD OWSG (2,3) 4,600.00 74.75 330.54 3,645.80 10.14 0.00 49.27 0.00 8.93 0.00 0.01 49.27 10.49 150.14 MWD OWSG (2.3) 4,700.00 74.75 330.54 3,672.10 10.72 0.00 53.31 0.00 9.53 0.00 0.01 53.31 10.60 150.19 MWD OWSG (2,3) 4,800.00 74.75 330.54 3,698.41 11.32 0.00 57.39 0.00 10.15 0.00 0.01 57.40 10.72 150.23 MWD OWSG (2,3) 4,900.00 74.75 330.54 3,724.71 11.94 0.00 61.51 0.00 10.79 0.00 0.01 61.51 10.84 150.27 MWD OWSG (2,3) 5,000.00 74.75 330.54 3,751.02 12.58 0.00 65.65 0.00 11.44 0.00 0.01 65.65 10.96 150.29 MWD OWSG (2,3) 5,100.00 74.75 330.54 3,777.32 9.57 0.00 36.04 0.00 8.49 0.00 0.01 36.05 10.63 149.72 MWD+IFR2+SAG+MS (3,3) 5,200.00 74.75 330.54 3,803.62 9.89 0.00 37.74 0.00 8.83 0.00 0.01 37.74 10.72 149.78 MWD+IFR2+SAG+MS (3,3) 5,300.00 74.75 330.54 3,829.93 10.22 0.00 39.46 0.00 9.18 0.00 0.01 39.46 10.81 149.83 MWD+IFR2+SAG+MS (3,3) 5,400.00 74.75 330.54 3,856.23 10.56 0.00 41.19 0.00 9.54 0.00 0.01 41.19 10.90 149.88 MWD+IFR2+SAG+MS (3,3) 5,500.00 74.75 330.54 3,882.54 10.91 0.00 42.95 0.00 9.91 0.00 0.01 42.95 11.00 149.92 MWD+IFR2+SAG+MS (3, 3) 5,600.00 74.75 330.54 3,908.84 11.27 0.00 44.72 0.00 10.28 0.00 0.01 44.72 11.09 149.96 MWD+IFR2+SAG+MS (3,3) 5,700.00 74.75 330.54 3,935.15 11.63 0.00 46.50 0.00 10.66 0.00 0.01 46.50 11.19 149.99 MWD+IFR2+SAG+MS (3,3) 5,800.00 74.75 330.54 3,961.45 12.00 0.00 48.29 0.00 11.04 0.00 0.01 48.29 11.29 150.02 MWD+IFR2+SAG+MS (3,3) 5,900.00 74.75 330.54 3,987.76 12.38 0.00 50.10 0.00 11.42 0.00 0.01 50.10 11.40 150.05 MWD+IFR2+SAG+MS (3,3) 6,000.00 74.75 330.54 4,014.06 12.75 0.00 51.91 0.00 11.81 0.00 0.01 51.91 11.50 150.07 MWD+IFR2+SAG+MS (3,3) 6,100.00 74.75 330.54 4,040.37 13.14 0.00 53.74 0.00 12.20 0.00 0.01 53.74 11.61 150.09 MWD+IFR2+SAG+MS (3,3) 6,200.00 74.75 330.54 4,066.67 13.53 0.00 55.57 0.00 12.59 0.00 0.01 55.57 11.72 150.11 MWD+IFR2+SAG+MS (3,3) 6,300.00 74.75 330.54 4,092.97 13.92 0.00 57.41 0.00 12.99 0.00 0.01 57.41 11.83 150.13 MWD+IFR2+SAG+MS (3,3) 6,400.00 74.75 330.54 4,119.28 14.31 0.00 59.25 0.00 13.39 0.00 0.01 59.25 11.94 150.14 MWD+IFR2+SAG+MS (3,3) 6,500.00 74.75 330.54 4,145.58 14.71 0.00 61.10 0.00 13.79 0.00 0.01 61.10 12.06 150.16 MWD+IFR2+SAG+MS (3,3) 6,600.00 74.75 330.54 4,171.89 15.11 0.00 62.96 0.00 14.20 0.00 0.01 62.96 12.17 150.17 MWD+IFR2+SAG+MS (3,3) 6,700.00 74.75 330.54 4,198.19 15.51 0.00 64.82 0.00 14.60 0.00 0.01 64.82 12.29 150.18 MWD+IFR2+SAG+MS (3,3) 6,800.00 74.75 330.54 4,224.50 15.92 0.00 66.68 0.00 15.01 0.00 0.01 66.68 12.41 150.19 MWD+IFR2+SAG+MS (3,3) 6,900.00 74.75 330.54 4,250.80 16.33 0.00 68.55 0.00 15.42 0.00 0.01 68.55 12.53 150.20 MWD+IFR2+SAG+MS (3, 3) 7,000.00 74.75 330.54 4,277.11 16.74 0.00 70.43 0.00 15.83 0.00 0.01 70.43 12.66 150.21 MWD+IFR2+SAG+MS (3,3) 4/23/2019 10:47:50AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well Plan: 31-1-35 Project: Kuparuk River Unit -2 TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Well: Plan: 3H-35 North Reference: True Wellbore: 31-1-35 Survey Calculation Method: Minimum Curvature Design: 3H-35wp04 Output errors are at 2.00 sigma Database: OAKEDMP1 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Ertor Bias Error Bias of Bias Error Error Azimuth Tool (usft) {°} (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (I 7,100.00 74.75 330.54 4,303.41 17.15 0.00 72.30 0.00 16.24 0.00 0.01 72.30 12.78 150.22 MWD+IFR2+SAG+MS(3, 3) 7,200.00 74.75 330.54 4,329.71 17.57 0.00 74.18 0.00 16.65 0.00 0.01 74.18 12.91 150.23 MWD+IFR2+SAG+MS (3,3) 7,300.00 74.75 330.54 4,356.02 17.98 0.00 76.06 0.00 17.07 0.00 0.01 76.07 13.04 150.24 MWD+IFR2+SAG+MS (3,3) 7,400.00 74.75 330.54 4,382.32 18.40 0.00 77.95 0.00 17.48 0.00 0.01 77.95 13.17 150.25 MWD+IFR2+SAG+MS (3,3) 7,500.00 74.75 330.54 4,408.63 18.82 0.00 79.84 0.00 17.90 0.00 0.01 79.84 13.30 150.25 MWD+IFR2+SAG+MS (3,3) 7,600.00 74.75 330.54 4,434.93 19.24 0.00 81.73 0.00 18.31 0.00 0.01 81.73 13.43 150.26 MWD+IFR2+SAG+MS (3,3) 7,700.00 74.75 330.54 4,461.24 19.66 0.00 83.62 0.00 18.73 0.00 0.01 83.62 13.57 150.26 MWD+IFR2+SAG+MS (3,3) 7,800.00 74.75 330.54 4,487.54 20.08 0.00 85.51 0.00 19.15 0.00 0.01 85.52 13.70 150.27 MWD+IFR2+SAG+MS (3,3) 7,900.00 74.75 330.54 4,513.85 20.51 0.00 87.41 0.00 19.57 0.00 0.01 87.41 13.84 150.27 MWD+IFR2+SAG+MS (3,3) 8,000.00 74.75 330.54 4,540.15 20.93 0.00 89.31 0.00 19.99 0.00 0.01 89.31 13.98 150.28 MWD+IFR2+SAG+MS (3,3) 8,100.00 74.75 330.54 4,566.46 21.36 0.00 91.21 0.00 20.41 0.00 0.01 91.21 14.12 150.28 MWD+IFR2+SAG+MS(3,3) 8,200.00 74.75 330.54 4,592.76 21.78 0.00 93.11 0.00 20.83 0.00 0.01 93.11 14.26 150.29 MWD+IFR2+SAG+MS (3,3) 8,300.00 74.75 330.54 4,619.06 22.21 0.00 95.01 0.00 21.25 0.00 0.01 95.01 14.40 150.29 MWD+IFR2+SAG+MS (3,3) 8,400.00 74.75 330.54 4,645.37 22.64 0.00 96.92 0.00 21.68 0.00 0.01 96.92 14.54 150.30 MWD+1FR2+SAG+MS (3,3) 8,500.00 74.75 330.54 4,671.67 23.07 0.00 98.82 0.00 22.10 0.00 0.01 98.83 14.69 150.30 MWD+IFR2+SAG+MS (3,3) 8,600.00 74.75 330.54 4,697.98 23.50 0.00 100.73 0.00 22.52 0.00 0.01 100.73 14.83 150.30 MWD+IFR2+SAG+MS (3,3) 8,700.00 74.75 330.54 4,724.28 23.93 0.00 102.64 0.00 22.95 0.00 0.01 102.64 14.98 150.31 MWD+IFR2+SAG+MS (3,3) 8,800.00 74.75 330.54 4,750.59 24.36 0.00 104.55 0.00 23.37 0.00 0.01 104.55 15.13 150.31 MWD+IFR2+SAG+MS (3,3) 8,900.00 74.75 330.54 4,776.89 24.80 0.00 106.46 0.00 23.80 0.00 0.01 106.46 15.28 150.31 MWD+IFR2+SAG+MS (3,3) 9,000.00 74.75 330.54 4,803.20 25.23 0.00 108.37 0.00 24.22 0.00 0.01 108.37 15.43 150.32 MWD+IFR2+SAG+MS (3,3) 9,100.00 74.75 330.54 4,829.50 25.66 0.00 110.28 0.00 24.65 0.00 0.01 110.28 15.58 150.32 MWD+IFR2+SAG+MS(3,3) 9,200.00 74.75 330.54 4,855.80 26.10 0.00 112.20 0.00 25.07 0.00 0.01 112.20 15.74 150.32 MWD+IFR2+SAG+MS (3,3) 9,300.00 74.75 330.54 4,882.11 26.53 0.00 114.11 0.00 25.50 0.00 0.01 114.11 15.89 150.32 MWD+IFR2+SAG+MS (3,3) 9,400.00 74.75 330.54 4,908.41 26.97 0.00 116.03 0.00 25.93 0.00 0.01 116.03 16.05 150.33 MWD+IFR2+SAG+MS (3,3) 9,500.00 74.75 330.54 4,934.72 27.40 0.00 117.94 0.00 26.35 0.00 0.01 117.94 16.20 150.33 MWD+IFR2+SAG+MS (3,3) 9,600.00 74.75 330.54 4,961.02 27.84 0.00 119.86 0.00 26.78 0.00 0.01 119.86 16.36 150.33 MWD+IFR2+SAG+MS (3,3) 9,700.00 74.75 330.54 4,987.33 28.27 0.00 121.77 0.00 27.21 0.00 0.01 121.78 16.52 150.33 MWD+IFR2+SAG+MS (3,3) 9,800.00 74.75 330.54 5,013.63 28.71 0.00 123.69 0.00 27.64 0.00 0.01 123.69 16.68 150.33 MWD+IFR2+SAG+MS (3,3) 9,900.00 74.75 330.54 5,039.94 29.15 0.00 125.61 0.00 28.07 0.00 0.01 125.61 16.84 150.34 MWD+IFR2+SAG+MS (3,3) 10,000.00 74.75 330.54 5,066.24 29.59 0.00 127.53 0.00 28.49 0.00 0.01 127.53 17.00 150.34 MWD+IFR2+SAG+MS (3,3) 10,100.00 74.75 330.54 5,092.55 30.02 0.00 129.45 0.00 28.92 0.00 0.01 '. 129.45 17.16 150.34 MWD+IFR2+SAG+MS (3,3) 10,200.00 74.75 330.54 5,118.85 30.46 0.00 131.37 0.00 29.35 0.00 0.01 131.37 17.33 150.34 MWD+IFR2+SAG+MS (3,3) 10,300.00 74.75 330.54 5,145.15 30.90 0.00 133.29 0.00 29.78 0.00 0.01 133.29 17.49 150.34 MWD+IFR2+SAG+MS (3, 3) 10,400.00 74.75 330.54 5,171.46 31.34 0.00 135.21 0.00 30.21 0.00 0.01 135.21 17.66 150.34 MWD+IFR2+SAG+MS (3, 3) 10,500.00 74.75 330.54 5,197.76 31.78 0.00 137.13 0.00 30.64 0.00 0.01 137.13 17.82 150.34 MWD+IFR2+SAG+MS (3, 3) 10,600.00 74.75 330.54 5,224.07 32.22 0.00 139.06 0.00 31.07 0.00 0.01 139.06 17.99 150.35 MWD+IFR2+SAG+MS (3,3) 10,700.00 74.75 330.54 5,250.37 32.66 0.00 140.98 0.00 31.50 0.00 0.01 140.98 18.16 150.35 MWD+IFR2+SAG+MS (3,3) 10,800.00 74.75 330.54 5,276.68 33.10 0.00 142.90 0.00 31.93 0.00 0.01 142.90 18.33 150.35 MWD+IFR2+SAG+MS (3,3) 10,900.00 74.75 330.54 5,302.98 33.54 0.00 144.82 0.00 32.36 0.00 0.01 144.82 18.50 150.35 MWD+1FR2+SAG+MS (3,3) 11,000.00 74.75 330.54 5,329.29 33.98 0.00 146.75 0.00 32.79 0.00 0.01 146.75 18.67 150.35 MWD+IFR2+SAG+MS (3,3) 11,100.00 74.75 330.54 5,355.59 34.42 0.00 148.67 0.00 33.22 0.00 0.01 148.67 18.84 150.35 MWD+IFR2+SAG+MS (3, 3) 11,200.00 74.75 330.54 5,381.89 34.86 0.00 150.60 0.00 33.65 0.00 0.01 150.60 19.01 150.35 MWD+IFR2+SAG+MS (3, 3) 11,300.00 74.75 330.54 5,408.20 35.30 0.00 152.52 0.00 34.08 0.00 0.01 152.52 19.18 150.35 MWD+IFR2+SAG+MS(3, 3) 11,400.00 74.75 330.54 5,434.50 35.74 0.00 154.45 0.00 34.52 0.00 0.01 154.45 19.36 150.36 MWD+IFR2+SAG+MS (3,3) 11,500.00 74.75 330.54 5,460.81 36.19 0.00 156.37 0.00 34.95 0.00 0.01 156.37 19.53 150.36 MWD+IFR2+SAG+MS (3,3) 11,600.00 74.75 330.54 5,487.11 36.63 0.00 156.30 0.00 35.38 0.00 0.01 158.30 19.71 150.36 MWD+IFR2+SAG+MS (3,3) 11,700.00 74.75 330.54 5,513.42 37.07 0.00 160.22 0.00 35.81 0.00 0.01 160.23 19.89 150.36 MWD+IFR2+SAG+MS (3,3) 11,800.00 74.75 330.54 5,539.72 37.51 0.00 162.15 0.00 36.24 0.00 0.01 162.15 20.07 150.36 MWD+IFR2+SAG+MS (3,3) 11,900.00 74.75 330.54 5,566.03 37.96 0.00 164.08 0.00 36.67 0.00 0.01 164.08 20.24 150.36 MWD+IFR2+SAG+MS (3, 3) 12,000.00 74.75 330.54 5,592.33 38.40 0.00 166.01 0.00 37.11 0.00 0.01 166.01 20.42 150.36 MWD+IFR2+SAG+MS (3, 3) 12,100.00 74.75 330.54 5,618.64 38.84 0.00 167.93 0.00 37.54 0.00 0.01 167.93 20.60 150.36 MWD+1FR2+SAG+MS(3, 3) 12,200.00 74.75 330.54 5,644.94 39.28 0.00 169.86 0.00 37.97 0.00 0.01 169.86 20.78 150.36 MWD+IFR2+SAG+MS (3, 3) 12,300.00 74.75 330.54 5,671.24 39.73 0.00 171.79 0.00 38.40 0.00 0.01 171.79 20.97 150.36 MWD+IFR2+SAG+MS (3,3) 12,400.00 74.75 330.54 5,697.55 40.17 0.00 173.72 0.00 38.84 0.00 0.01 173.72 21.15 150.36 MWD+IFR2+SAG+MS (3,3) 4/23/2019 10:47:50AM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 31-1-35 Wellbore: 31-1-35 Design: 3H-35wp04 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: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°J (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 12,500.00 74.75 330.54 5,723.85 40.61 0.00 175.64 0.00 39.27 0.00 0.01 175.65 21.33 150.36 MWD+IFR2+SAG+MS (3,3) 12,600.00 74.75 330.54 5,750.16 41.06 0.00 177.57 0.00 39.70 0.00 0.01 177.57 21.52 150.37 MWD+IFR2+SAG+MS (3,3) 12,683.66 74.75 330.54 5,772.17 41.43 0.00 179.19 0.00 40.06 0.00 0.01 179.19 21.67 150.37 MWD+IFR2+SAG+MS (3,3) 12,700.00 75.04 330.13 5,776.42 41.48 0.00 179.50 0.00 40.13 0.00 0.01 179.50 21.70 150.37 MWD+IFR2+SAG+MS (3,3) 12,800.00 76.80 327.63 5,800.76 41.86 0.00 181.27 0.00 40.57 0.00 0.01 181.47 21.88 150.35 MWD+IFR2+SAG+MS (3,3) 12,900.00 78.59 325.17 5,822.06 42.25 0.00 182.77 0.00 41.00 0.00 0.01 183.50 22.05 150.30 MWD+IFR2+SAG+MS (3,3) 13,000.00 80.40 322.73 5,840.29 42.62 0.00 184.01 0.00 41.44 0.00 0.01 185.57 22.22 150.23 MWD+IFR2+SAG+MS (3, 3) 13,100.00 82.23 320.33 5,855.39 42.92 0.00 184.97 0.00 41.88 0.00 0.01 187.68 22.37 150.13 MWD+IFR2+SAG+MS (3,3) 13,200.00 84.07 317.94 5,867.31 43.16 0.00 185.67 0.00 42.32 0.00 0.01 189.81 22.51 150.01 MWD+IFR2+SAG+MS (3,3) 13,300.00 85.93 315.57 5,876.03 43.35 0.00 186.10 0.00 42.76 0.00 0.01 191.95 22.64 149.85 MWD+IFR2+SAG+MS (3,3) 13,357.88 87.00 314.21 5,879.60 43.44 0.00 186.22 0.00 43.02 0.00 0.01 193.19 22.71 149.76 MWD+IFR2+SAG+MS (3,3) 13,377.88 87.00 314.21 5,880.65 43.49 0.00 186.53 0.00 42.98 0.00 0.01 193.58 23.14 149.83 MWD OWSG (3,4) 13,400.00 87.44 314.21 5,881.72 43.41 0.00 186.73 0.00 42.98 0.00 0.01 193.76 23.17 149.81 MWD OWSG (3, 4) 13,500.00 89.44 314.21 5,884.44 43.08 0.00 187.70 0.00 42.99 0.00 0.01 194.69 23.34 149.73 MWD OWSG (3, 4) 13,516.66 89.78 314.21 5,884.55 43.03 0.00 187.87 0.00 43.00 0.00 0.01 194.86 23.38 149.71 MWD OWSG (3,4) 13,600.00 89.78 314.21 5,884.88 43.05 0.00 188.80 0.00 43.02 0.00 0.01 195.74 23.59 149.62 MWD OWSG (3,4) 13,700.00 89.78 314.21 5,885.27 43.09 0.00 190.04 0.00 43.06 0.00 0.01 196.91 23.91 149.50 MWD OWSG (3,4) 13,800.00 89.78 314.21 5,885.66 43.15 0.00 191.41 0.00 43.11 0.00 0.01 198.20 24.29 149.36 MWD OWSG (3,4) 13,900.00 89.78 314.21 5,886.05 43.22 0.00 192.91 0.00 43.18 0.00 0.01 199.61 24.73 149.21 MWD OWSG (3,4) 14,000.00 89.78 314.21 5,886.44 43.30 0.00 194.53 0.00 43.27 0.00 0.01 201.13 25.22 149.04 MWD OWSG (3.4) 14,100.00 89.78 314.21 5,886.83 43.40 0.00 196.27 0.00 43.36 0.00 0.01 202.76 25.75 148.86 MWD OWSG (3,4) 14,200.00 89.78 314.21 5,887.23 43.51 0.00 198.13 0.00 43.47 0.00 0.01 204.50 26.32 148.67 MWD OWSG (3,4) 14,300.00 89.78 314.21 5,887.62 43.63 0.00 200.11 0.00 43.60 0.00 0.01 206.35 26.93 148.46 MWD OWSG (3,4) 14,400.00 89.78 314.21 5,888.01 43.77 0.00 202.20 0.00 43.74 0.00 0.01 208.31 27.55 148.25 MWD OWSG (3,4) 14,500.00 89.78 314.21 5,888.40 43.92 0.00 204.39 0.00 43.89 0.00 0.01 210.37 28.20 148.02 MWD OWSG (3,4) 14,551.10 89.78 314.21 5,888.60 44.01 0.00 205.55 0.00 43.97 0.00 0.01 211.46 28.54 147.90 MWD OWSG (3,4) 14,578.49 89.23 314.18 5,888.84 44.14 0.00 206.17 0.00 44.02 0.00 0.01 212.05 28.72 147.84 MWD OWSG (3,4) 14,600.00 89.23 314.18 5,889.13 44.17 0.00 206.67 0.00 44.06 0.00 0.01 212.53 28.87 147.79 MWD OWSG (3,4) 14,700.00 89.23 314.18 5,890.47 44.35 0.00 209.07 0.00 44.23 0.00 0.01 214.78 29.54 147.55 MWD OWSG (3,4) 14,800.00 89.23 314.18 5,891.82 44.54 0.00 211.57 0.00 44.43 0.00 0.01 217.14 30.22 147.31 MWD OWSG (3,4) 14,900.00 89.23 314.18 5,893.17 43.66 0.00 193.82 0.00 43.54 0.00 0.01 200.43 26.42 149.07 MWD+IFR2+SAG+MS (4,4) 15,000.00 89.23 314.18 5,894.52 43.74 0.00 194.51 0.00 43.62 0.00 0.01 201.07 26.72 149.00 MWD+IFR2+SAG+MS (4,4) 15,100.00 89.23 314.18 5,895.86 43.81 0.00 195.23 0.00 43.70 0.00 0.01 201.74 27.04 148.92 MWD+IFR2+SAG+MS (4,4) 15,200.00 89.23 314.18 5,897.21 43.90 0.00 195.98 0.00 43.78 0.00 0.01 202.44 27.36 148.83 MWD+IFR2+SAG+MS (4,4) 15,300.00 89.23 314.18 5,898.56 43.99 0.00 196.75 0.00 43.87 0.00 0.01 203.15 27.68 148.75 MWD+IFR2+SAG+MS (4,4) 15,400.00 89.23 314.18 5,899.90 44.08 0.00 197.54 0.00 43.96 0.00 0.01 203.89 28.01 148.66 MWD+IFR2+SAG+MS (4,4) 15,500.00 89.23 314.18 5,901.25 44.18 0.00 198.36 0.00 44.06 0.00 0.01 204.65 28.35 148.57 MWD+IFR2+SAG+MS (4,4) 15,600.00 89.23 314.18 5,902.60 44.28 0.00 199.20 0.00 44.16 0.00 0.01 205.43 28.69 148.48 MWD+IFR2+SAG+MS (4,4) 15,700.00 89.23 314.18 5,903.94 44.39 0.00 200.06 0.00 44.27 0.00 0.01 206.23 29.04 148.38 MWD+IFR2+SAG+MS (4, 4) 15,800.00 89.23 314.18 5,905.29 44.50 0.00 200.95 0.00 44.38 0.00 0.01 207.06 29.38 148.29 MWD+IFR2+SAG+MS (4,4) 15,900.00 89.23 314.18 5,906.64 44.61 0.00 201.85 0.00 44.50 0.00 0.01 207.91 29.74 148.19 MWD+IFR2+SAG+MS (4,4) 16,000.00 89.23 314.18 5,907.98 44.73 0.00 202.79 0.00 44.62 0.00 0.01 208.77 30.09 148.09 MWD+IFR2+SAG+MS (4,4) 16,100.00 89.23 314.18 5,909.33 44.85 0.00 203.74 0.00 44.74 0,00 0.01 209.66 30.45 147.99 MWD+IFR2+SAG+MS (4,4) 16,200.00 89.23 314.18 5,910.68 44.98 0.00 204.71 0.00 44.87 0.00 0.01 210.57 30.81 147.88 MWD+IFR2+SAG+MS(4,4) 16,268.45 89.23 314.18 5,911.60 45.07 0.00 205.39 0.00 44.96 0.00 0.01 211.21 31.05 147.81 MWD+IFR2+SAG+MS (4,4) 16,282.36 89.50 314.25 5,911.75 45.05 0.00 205.58 0.00 44.98 0.00 0.01 211.34 31.10 147.80 MWD+IFR2+SAG+MS (4,4) 16,300.00 89.50 314.25 5,911.91 45.07 0.00 205.76 0.00 45.00 0.00 0.01 211.50 31.17 147.78 MWD+IFR2+SAG+MS (4,4) 16,400.00 89.50 31425 5,912.78 45.21 0.00 206.78 0.00 45.14 0.00 0.01 212.45 31.53 147.67 MWD+IFR2+SAG+MS (4,4) 16,500.00 89.50 314.25 5,913.66 45.35 0.00 207.81 0.00 45.28 0.00 0.01 213.42 31.89 147.57 MWD+IFR2+SAG+MS (4,4) 16,600.00 89.50 314.25 5,914.53 45.50 0.00 208.87 0.00 45.42 0.00 0.01 214.41 32.25 147.46 MWD+IFR2+SAG+MS (4,4) 16,700.00 89.50 314.25 5,915.40 45.64 0.00 209.94 0.00 45.57 0.00 0.01 215.42 32.61 147.35 MWD+IFR2+SAG+MS (4,4) 16,800.00 89.50 314.25 5,916.28 45.80 0.00 211.04 0.00 45.73 0.00 0.01 216.45 32.97 147.24 MWD+IFR2+SAG+MS (4,4) 16,900.00 89.50 314.25 5,917.15 45.95 0.00 212.16 0.00 45.88 0.00 0.01 217.50 33.33 147.13 MWD+IFR2+SAG+MS (4,4) 17,000.00 89.50 314.25 5,918.03 46.11 0.00 213.29 0.00 46.04 0.00 0.01 218.57 33.69 147.02 MWD+IFR2+SAG+MS (4,4) 4/23/2019 10:47:50AM Page 6 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3H Pad Well: Plan: 31-1-35 Wellbore: 31-1-35 Design: 3H-35wp04 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMP1 Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usfi) (�) 17,100.00 89.50 314.25 5,918.90 46.28 0.00 214.44 0.00 46.21 0.00 0.01 219.65 34.05 146.90 MWD+IFR2+SAG+MS(4,4) 17,200.00 89.50 314.25 5,919.77 46.45 0.00 215.62 0.00 46.38 0.00 0.01 220.76 34.41 146.79 MWD+IFR2+SAG+MS (4,4) 17,300.00 89.50 314.25 5,920.65 46.62 0.00 216.81 0.00 46.55 0.00 0.01 221.88 34.76 146.68 MWD+IFR2+SAG+MS (4, 4) 17,400.00 89.50 314.25 5,921.52 46.80 0.00 218.01 0.00 46.73 0.00 0.01 223.02 35.12 146.56 MWD+IFR2+SAG+MS (4,4) 17,500.00 89.50 314.25 5,922.40 46.98 0.00 219.24 0.00 46.91 0.00 0.01 224.18 35.47 146.45 MWD+IFR2+SAG+MS (4,4) 17,600.00 89.50 314.25 5,923.27 47.16 0.00 220.48 0.00 47.09 0.00 0.01 225.35 35.82 146.34 MWD+IFR2+SAG+MS (4,4) 17,700.00 89.50 314.25 5,924.14 47.35 0.00 221.74 0.00 47.28 0.00 0.01 226.55 36.17 146.22 MWD+IFR2+SAG+MS (4,4) 17,800.00 89.50 314.25 5,925.02 47.54 0.00 223.02 0.00 47.47 0.00 0.01 227.75 36.52 146.11 MWD+IFR2+SAG+MS (4,4) 17,900.00 89.50 314.25 5,925.89 47.73 0.00 224.31 0.00 47.66 0.00 0.01 228.98 36.87 145.99 MWD+IFR2+SAG+MS (4,4) 18,000.00 89.50 314.25 5,926.76 47.93 0.00 225.62 0.00 - 47.86 0.00 0.01 230.22 37.21 145.88 MWD+IFR2+SAG+MS (4,4) 18,100.00 89.50 314.25 5,927.64 48.13 0.00 226.95 0.00 48.06 0.00 0.01 231.48 37.55 145.76 MWD+IFR2+SAG+MS(4,4) 18,200.00 89.50 314.25 5,928.51 48.33 0.00 228.29 0.00 48.27 0.00 0.01 232.76 37.89 145.65 MWD+IFR2+SAG+MS (4,4) 18,300.00 89.50 314.25 5,929.39 48.54 0.00 229.64 0.00 48.48 0.00 0.01 234.05 38.23 145.53 MWD+IFR2+SAG+MS (4,4) 18,400.00 89.50 314.25 5,930.26 48.75 0.00 231.01 0.00 48.69 0.00 0.01 235.35 38.56 145.42 MWD+IFR2+SAG+MS (4,4) 18,500.00 89.50 314.25 5,931.13 48.97 0.00 232.40 0.00 48.90 0.00 0.01 236.68 38.89 145.31 MWD+IFR2+SAG+MS (4,4) 18,600.00 89.50 314.25 5,932.01 49.19 0.00 233.80 0.00 49.12 0.00 0.01 238.01 39.22 145.19 MWD+IFR2+SAG+MS (4,4) 18,700.00 89.50 314.25 5,932.88 49.41 0.00 235.22 0.00 49.34 0.00 0.01 239.36 39.55 145.08 MWD+IFR2+SAG+MS (4,4) 18,800.00 89.50 314.25 5,933.76 49.63 0.00 236.64 0.00 49.57 0.00 0.01 240.73 39.87 144.97 MWD+IFR2+SAG+MS (4,4) 18,896.64 89.50 314.25 5,934.60 49.85 0.00 238.04 0.00 49.79 0.00 0.01 242.06 40.18 144.86 MWD+IFR2+SAG+MS (4,4) 18,900.00 89.49 314.31 5,934.63 49.86 0.00 238.14 0.00 49.80 0.00 0.01 242.11 40.19 144.86 MWD+IFR2+SAG+MS (4,4) 19,000.00 89.13 316.28 5,935.84 50.14 0.00 240.92 0.00 50.03 0.00 0.01 243.50 40.49 144.75 MWD+IFR2+SAG+MS (4,4) 19,029.47 89.02 316.86 5,936.32 50.23 0.00 241.68 0.00 50.10 0.00 0.01 243.91 40.57 144.72 MWD+IFR2+SAG+MS (4,4) 19,100.00 89.02 316.86 5,937.52 50.39 0.00 242.70 0.00 50.26 0.00 0.01 244.90 40.75 144.66 MWD+IFR2+SAG+MS(4,4) 19,200.00 89.02 316.86 5,939.23 50.63 0.00 244.15 0.00 50.50 0.00 0.01 246.31 41.00 144.57 MWD+IFR2+SAG+MS (4,4) 19,300.00 89.02 316.86 5,940.94 50.87 0.00 245.61 0.00 50.74 0.00 0.01 247.74 41.25 144.47 MWD+IFR2+SAG+MS (4,4) 19,400.00 89.02 316.86 5,942.65 51.11 0.00 247.09 0.00 50.98 0.00 0.01 249.17 41.50 144.38 MWD+IFR2+SAG+MS (4,4) 19,500.00 89.02 316.86 5,944.36 51.36 0.00 248.58 0.00 51.23 0.00 0.01 250.62 41.75 144.29 MWD+IFR2+SAG+MS (4,4) 19,600.00 89.02 316.86 5,946.07 51.60 0.00 250.07 0.00 51.48 0.00 0.01 252.08 42.00 144.20 MWD+IFR2+SAG+MS (4,4) 19,700.00 89.02 316.86 5,947.78 51.85 0.00 251.59 0.00 51.73 0.00 0.01 253.56 42.24 144.11 MWD+IFR2+SAG+MS (4,4) 19,800.00 89.02 316.86 5,949.49 52.11 0.00 253.11 0.00 51.98 0.00 0.01 255.04 42.48 144.03 MWD+IFR2+SAG+MS (4,4) 19,900.00 89.02 316.86 5,951.20 52.36 0.00 254.64 0.00 52.24 0.00 0.01 256.54 42.72 143.94 MWD+IFR2+SAG+MS (4, 4) 20,000.00 89.02 316.86 5,952.91 52.62 0.00 256.18 0.00 52.50 0.00 0.01 258.05 42.95 143.85 MWD+IFR2+SAG+MS (4, 4) 20,100.00 89.02 316.86 5,954.62 52.88 0.00 257.74 0.00 52.76 0.00 0.01 259.57 43.19 143.77 MWD+IFR2+SAG+MS(4, 4) 20,157.63 89.02 316.86 5,955.60 53.04 0.00 258.64 0.00 52.91 0.00 0.01 260.45 43.32 143.72 MWD+IFR2+SAG+MS (4,4) 4/23/2019 10:47:50AM Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kuparuk River Unit—2 Site: Kuparuk 3H Pad Well: Plan: 31-1-35 Wellbore: 31-1-35 Design: 3H-35wp04 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 31-1-35 D142 39+36.6 AsBuilt @ 75.60usft (D142) D142 39+36.6 AsBuilt @ 75.60usft (D142) True Minimum Curvature 2.00 sigma OAKEDMP1 Design Targets Measured Vertical Dip Target Name Depth Dip Direction (usft) (usft) Name Lithology hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (1) 3,006.42 (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 31-1-35 Heel BT 042219 0.00 0.00 5,879.60 9,102.18 -5,336.89 - plan hits target center 11,176.07 5,375.60 Top Moraine 11,582.84 5,482.60 - Circle (radius 1,320.00) 12,346.97 5,683.60 Top HRZ 12,445.81 5,709.60 31-1-35 Tgt01 BT 042219 0.00 0.00 5,888.60 9,934.07 -6,192.17 - plan hits target center 13,256.12 5,872.60 Fault 2 20' DTE 13,294.05 5,875.60 - Circle (radius 100.00) 19,806.62 5,949.60 TD 11 1 31-1-35 Tgt02 BT 042219 0.00 0.00 5,911.60 11,130.90 -7,423.57 - plan hits target center - Circle (radius 100.00) 3H-35 Tgt03 BT 042219 0.00 0.00 5,934.60 12,964.65 -9,306.18 - plan hits target center - Circle (radius 100.00) 31-1-35 Toe BT 042219 0.00 0.00 5,955.60 13,882.54 -10,170.48 - plan hits target center - Circle (radius 1,320.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 3,573.77 3,257.00 13-1/2" x 10-3/4" 10.750 13.500 13,357.88 5,879.60 9 7/8" x 7-5/8" 7.625 9.875 L 20,157.63 5,955.60 6-3/4" x 4-1/2" 4.500 6.750 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,671.67 1,636.60 Base Permafrost 2,556.52 2,469.60 Top W Sak 3,006.42 2,858.60 Base W Sak 3,381.55 3,135.60 Camp SS 5,884.20 3,983.60 C-50 7,408.65 4,384.60 C-35 11,176.07 5,375.60 Top Moraine 11,582.84 5,482.60 Base Moraine 12,346.97 5,683.60 Top HRZ 12,445.81 5,709.60 Fault 1 85' DTE 12,499.04 5,723.60 Base HRZ /Top Kalubik 12,961.26 5,833.60 K1 13,256.12 5,872.60 Fault 2 20' DTE 13,294.05 5,875.60 Top Kuparuk 19,806.62 5,949.60 TD 11 1 4/23/2019 10:47:50AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 31-1-35 Project: Kuparuk River Unit -2 TVD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Site: Kuparuk 3H Pad MD Reference: D142 39+36.6 AsBuilt @ 75.60usft (D142) Well: Plan: 31-1-35 North Reference: True Wellbore: 31-1-35 Survey Calculation Method: Minimum Curvature Design: 3H-35wp04 Output errors are at 2.00 sigma 331.60 331.59 Database: OAKEDMP1 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 231.60 231.60 0.00 0.00 KOP: Start -0.77°/100' DLS, 1.5° TF, for 100' 331.60 331.59 0.00 1.31 Start Drop -1.50 431.60 431.58 0.00 2.62 Start 37.68°/100' DLS, 2.5° TF, for 500' 931.60 927.62 9.43 -50.88 Start 159.96°/100' DLS, 3° TF, for 500' 1,431.60 1,410.21 92.10 -144.94 Start 489.97°/100' DLS, 0° TF, for 1000' 2,431.60 2,353.24 383.29 -305.89 Start 1779.24°/100' DLS, 3° TF, for 1843.89' 4,275.49 3,560.44 1,515.58 -941.90 Start 9834.78°/100' DLS, 0° TF, for 8408.17' 12,683.66 5,772.17 8,578.83 4,931.40 Start 10496.59°/100' DLS, 3° TF, for 674.21' 13,357.88 5,879.60 9,102.18 -5,336.89 Start 10516.29°/100' DLS, 0° TF, for 20' 13,377.88 5,880.65 9,116.11 -5,351.21 Start 10653.08°/100' DLS, 2° TF, for 138.79' 13,516.66 5,884.55 9,212.83 -5,450.65 Start 11673.12°/100' DLS, 0° TF, for 1034.44' 14,551.10 5,888.60 9,934.07 -6,192.17 Start 11700.13°/100' DLS, 2° TF, for 27.39' 14,578.49 5,888.84 9,953.16 -6,211.81 Start 13366.32°/100' DLS, 0° TF, for 1689.96' 16,268.45 5,911.60 11,130.90 -7,423.57 Start 13380.04°/100' DLS, 2° TF, for 13.91' 16,282.36 5,911.75 11,140.60 -7,433.54 Start 15958.17°/100' DLS, 0° TF, for 2614.28' 18,896.64 5,934.60 12,964.65 -9,306.18 Start 16089.61'/l 00' DLS, 2° TF, for 132.82' 19,029.47 5,936.32 13,059.46 -9,399.17 Start 17209.4°/100' DLS, 0° TF, for 1128.16' 20,157.63 5,955.60 13,882.54 -10,170.48 TD: 20157.63' MD, 5955.6' TVD Checked By: Approved By: Date: 4/23/2019 10:47:50AM Page 9 COMPASS 5000.14 Build 85D 0 O O LO M - --'el�� o LO M � O a� M U O N M N Q. d co d' O r a w a z 0 � moa o N oso U a -_2 .2 - - a oo9 U F VUUUO m�O�m�o W pmm�vv. (D F¢ - W 0 U m m m m m •- •- m N NRN o m ~N ~N m F �NMm EM Z52222 nmMc�n O O O O O O O O O O Ln O Lf) O Lo M (uMjsn OOS£M+)gIJON/(-)ulnoS 01 m z o a00000 b ySSSM a Daaa6 {a- �UUUO 0 W mmmm� CD a N ' dm- 'o mO els y e i O All 0 All, 401 OD e, c ^ v0 � OR �E N"£ -H£ Pg 0 O �1 MQ e B1 Q�1 O 4�QT L b O� Q CL j N �ry dl W£ 33M-08Ladbg , �� y o ON r w£ ^ a _ o 6� A� bb c`-0 Ila el L v*9#g �`L3PB1 OPB � - �• O M gas, dab 19 F yy �o O + O J� N cw �Op S„p_ 1 r, N O O O O O O CL O O O O O LO O LO O LO f` d' O M (LffAjsn 005£)-(+)gIJON/(-)ulnoS Qi - ■ 8� O CL Q '��■ }' O M r p CY L O W W N O r, N O O O O O O CL O O O O O LO O LO O LO f` d' O M (LffAjsn 005£)-(+)gIJON/(-)ulnoS 13H-35wi304 As Built Surface I M CPAI Coordinate Converter From: T o: Datum: INAD83 Region: jalaska Datum: INAD27 � Region: alaska Latitude/LongitudeIU Latitude/Longitude jbecirr.iN�,ees Decimal Degrees C UTM Zone:F— r South t UTM Zone:-TrueSouth f C State Plane Zone: Units: us -ft j_ r- State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11638687.25 j X: 1 498655.412332359- Y: 15999847.49 Y: 6000096.23784273 .......... - ------ --_--------- ----- --- - - - ------ - 3H-35wp04 As Built Surface M CPAI Coordinate Converter Transform Quit . . .. ... .. .. .. ... .. . . . ............ ...... - 0 x From: To: - Datum: NA563 Region: alaska Datum: INAD27 7,1 Region: [ai7ka__-] Latitude/Longitude Latitude/Longitude IDecimall Degrees iDecimal Degrees UTM Zone: F South UTM Zone: True South r- State Plane Zone: q Units: State Plane Zone: q Units: us ft LQa� DE-c-fi0on flh&J,127 o -11"'I t-- Legal Description (NAD27 only) Starting Coordinates: ---- Legal Description - X: 11638687.25 Township: 01-2 Range: 008 Y: 15999847.49 Meridian: ju :_1 S ection:F12 !PNL 11560.898 FEE j4998.8215 Transform 13H-35wp04 As Built Production Horizon M CPAI Coordinate Converter - ❑ x - From: __ _ —_--i To: - -) Datum: 'NAD83 . Region: alaska . Datum: NAD27 Region: alaska i C' LatitudelLongitude Decimal Degrees f Latitude/Longitude Decimal Degrees I i UTM Zone: ("° South � i" UTM Zone:..: True r South State Plane Zone: q Units: us -ft . State Plane Zane: q : Units: us -ft . Legal Description (NAD27 only) i Legal Description (NAD27 only) I s L--------- . _ _ . _ --- Starting Starting Coordinates: - - - _.__._..____e._.____ __ _ -_ Ending Coordinates: _ ._ _..__ _..__._.__.___.__.. C X: 11633353 I X: 493321.466609401 j 11 Y: 6008950 Y: 6009198.77766063 ----------------- -- - - - - _.._- - f ---- .. --- ........................ _ ................... I Transform Quit..Help 3H-35wp04 As Built Production Horizon M CPA[ Coordinate Converter __.__...___ Datum: NAD83 . Region: alaska C LatitudelLongitude IDecimalDegrees J C UTM Zone: r- South >:' Stake Plane Zone:q Units: us ft r Lega DesCrip= iGn (1' NAD127r -4h,,) Starting Coordinates: X: 11633353 Y: 16008950 — ❑ x Datum:NAD27 . Region: alaska s C' Latitudekon itude i 9 Decimal Degrees C UTM Zone: ITrue South i State Plane Zone: F--.] Units: us -ft . i% Legal Description (NAD27 only) Legal Description -------- ._---- ..._.----- i Township: 013 N . Range: 008 E . f Meridian: U Section:34 FNL 3020.5506 FEL 3995.4750 .................. E Transform Quit Help 3H-35wp04 As Built TD M CPAI Coordinate Converter From: _._. __. Datum: NAD83 .I Region: alaska 7-1 C Latitude/Longitude FDecimal Degrees r UTM Zone: [— r South t: State Plane Zone: q Units: Fit . C Legal Description (NAD27 only) Starting Coordinates: X: 11628521 Y: 6013731 { 1 3H-35wp04 As Built TD M CPA[ Coordinate Converter To:- Datum: NAD27 Region: alaska C Latitude/Longitude Decimal Degrees — C• UTM Zone: True I South G State Plane Zone:q Units: us ft C• Legal Description (NAD27 only) Ending Coordinates: _ -------- -__ ---- X: 488489.674926175 Y: 6013979.85014298 Transform Qurt Help - From: -- Datum: NAD83 Region: jalaska f Latitude/Longitude Decimal Degrees C` UTM Zone: j South s C� State Plane Zone: Units: us ft f t ._iai Starting Coordinates: ---- — ---- ---- X: 11628521 Y: 16013731 - ❑ x -To:- - Datum: NA6-27---:-] Region: alaska i (- Latitude/Longitude Iecimal Degrees r UTM Zone: True r South C State Plane Zone: ---q � Units: us -ft Legal Description (NAD27 only) Legal Description ___.._..-._.----- _.____._._.___ Township: 013 [W:.] Range:008 E Meridian: U w Section:28 FNL3524.8933 FEL w 13542.7098 € -Transform Quit help 10 14/20/19 LGM I KDR I l As—Staked Conductor 35 & 37 1 1 1 1 1 1 0 TP 2 11 IWN21 27 A— 26 b, 25 33_ 4 PROJECT 6 t. B 34 Y T13N Lat. 3 LOCATION T12N PAD 35 1 �r. 6 3J 150' 00' 39.42" 1561' 281' 34.0' 1- 37 6000297.83 498655.43 70' 24' 43.37" 1 113 12 7 8 9 35.8' 3 0 11 15� 13 00 - 18 1t7 16 PF3 1 5 3B 22 23 24 19 21 20 1, 22 2 G VICINITY MAP NOTES: 1"= 2 MILES 1. BASIS OF LOCATION AND ELEVATION IS DS3G MONUMENTATION PER LOUNSBURY & ASSOC. 2. ALASKA STATE PLANE AND GEODETIC COORDINATES ARE, ZONE 4, N.A.D. 27. 3. ELEVATION ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 12, TOWNSHIP 12 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, ALASKA. 5. DATE OF SURVEY 4/17/19 & 4/18/19 STAKED IN FIELD BOOK L19-15-64 THRU 71. 6. ALL DISTANCES SHOWN ARE GROUND. LEGEND 0 AS—STAKED CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATION X ABANDONED CONDUCTOR LOCATION CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12 T. 12 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Section Geographic Coordinates Offset. Elev. Y X Lat. Long. F.N.L. F.W.L. O.G. PAD 35 6000096.24 498655.41 70' 24' 41.39" 150' 00' 39.42" 1561' 281' 34.0' 36.6' 37 6000297.83 498655.43 70' 24' 43.37" 150' 00' 39.42" 1359' 281' 33.7' 35.8' GRAPHIC SCALE SLOUNSBURY & nes, o ioo zoo 400 URVEYORS ENGINEERS PLAN NERS 1 inch = 200 ft. AREA: 3H MODULE: XXXX UNIT: D3 ConocoPhillips DS3H WELL CONDUCTORS 35 AND 37 Alaska, Inc. AS—STAKED LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6308D58 3/13/19 1 NSK 6.308-d58 1 1 OF 1 0 M i O N i a1 F— L- 0 — i0 O O C V) N N a--+ D O 75 a� C O -J c cu O U N N U v qA fB E O O O m � O (ID On U C N C) 4-J Z � Q O v7 O O .;"'i (B QJ O CB O v N_ L i O XN O O O ro v7 nA v N M w ■ a� Q1 — E Q) Q) Q N •— � O QJ � � � c U C +� + QJ N N f0 O bn vi Q c O c aj N U O Q N Q� O O U QJ N cn Q Q nAt C:a-1 O J O v O O O_ s N U v Q ra +-j o o Lei O a� aA NvOi Q� o O J U O O Cn cn i o O C: (u 4A -a O C i C M (U C N U) Y N i ■ ■ — LL ■ wil ■ te A 2 aJ s >. 4 m r_ O L m N > �_ L aJ 5 }' O _ N � U Y N Ll •i L U v CL O -C 4� U N 44- L O U CT m _ m L > s > L- ai QJ a C s L aJ N m M — U N CL s ++ — M Z; m �j N U U V N O +� L N C _ O M — c� U O U O 4 N 0 ++ M f6 ++ r_ OUM M U C: O O� O L C: a" L -0 Q 4) GJ (1) Naj Ln M i �J aJ ( �O U U n i o(IJ O CU C 0 N Q m L =5O L O = CO r (U Y s cn U +-+ N N ++ N V)a--� 4- (31 m m O aJ � O• N iJ �J Y i MC C — S=QJ — N C U A 2 Attachment 5: Drilling Hazards Summary 3H-35 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. Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight / viscosity, pump high viscosity sweeps. Gas Hydrates Low Reduce pump rates, reduce drilling fluid temperatures, additions of lecithin. Hole swabbing / tight hole on trips Moderate Circulate hole clean prior to trip, manage trip speeds, proper hole fillip use of trip sheets), pump out of hole as needed Lost Circulation Moderate Keep hole clean. If losses occur, reduce pump rates and mud rheology. Use LCM. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Abnormal pressure Low Follow mud weight schedule. Adjust mud weight as needed. Ensure weights required adequate kick tolerance prior to drilling pay interval. Utilize MPD Stuck Pipe Low to contain any pressure and prevent allowing an influx in the even pressure is higher than expected. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, proper mud weight. Hole swabbing on trips Moderate Maintain appropriate trip speeds, proper hole filling (use of trip sheets), pump out if required. Strip out with MPD. Shale instability Moderate For the unstable HRZ and Kalubik shales, mitigate with higher mud weight and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD. Lost circulation Moderate Reduce pump rates, adjust mud rheology, add LCM as required. Manage ECD using MPD. Hole swabbing on trips Moderate Manage trip speeds, proper hole filling (use of trip sheets), pump out of hole. 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy High ECD and swabbing with higher mud Moderate Condition mud prior to trips. Monitor ECD with PWD tool. Strip weights required out with MPD to mitigate swab. Stuck Pipe Low Good hole cleaning, stabilized BHA, proper mud weight to minimize differential sticking. Use PWD to monitor ECD. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduce pump rates, adjust mud rheology, and add LCM as required. Hole Swabbing on Trips Moderate Manage trip speeds, proper hole filling (use of trip sheets), pump out of hole. Use MPD to strip out of hole. Abnormal Reservoir Pressure Moderate Follow mud weight schedule. Adjust mud weight as required. Ensure adequate kick tolerance prior to drilling pay interval. Well: KRU 31-1-35 <== Data Input Name: V Loepp <== Data Input gMudWeight (ppg) 12.00 <== Data Input Weak point or LOT - Measured depth (ft) 1 3,574' 1 — Data Input Weak point or LOT True vertical depth (ft) 3,257' — Data Input Weak point or LOT - Hole angle (deg) PIO — Data Input Weak point or LOT - Hole size (in) .750" — Data Input Weak point pressure or LOT - EMW (ppg) 13.50 <== Data Input Zone of interest - Measured depth (ft) 8' <== Data Input Zone of interest - True vertical depth (ft) 5,880' — Data Input Zone of interest - Hole angle (deg) 87.00 — Data Input Zone of interest - Hole size (in) 7.625" — Data Input Zone of interest - Pore pressure EMW (ppg) 12.50 — Data Input Gas gradient (psi/ft) 0.10 — Data Input Bottom hole assembly OD (in) 8.0" <== Data Input Bottom hole assembly length (ft) 200' — Data Input Drill pipe OD (in) 5.500" <== Data Input BHA annular vol. @ zone of interest (bbl/ft) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. weak point bbl/ft -0.0057 0.0271 0.0829 WData Additional safety margin (psi) 0.00 Weak point pressure (psi): PIO 2,286 psi Weak point pressure - Safety margin: Pmax Pmax EMW 2,286 psi 13.50 ppc Max anticipated formation pressure (psi): Pf 3,822 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD} 2,623' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 9,784' Maximum influx height at the bit (TVD ft): H {TVD} 193' Maximum influx height at the bit (MD ft): H {MD) 3,689' Calc. volume of {H) around BHA: Caic. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1bha V1dp V1 -1.1 bbl 94.5 bbl 93.4 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 27.2 bbl Calc. volume of Vwp @ initial shut in: V2 1 . b b Kick Tolerance: V2 6.3 b `, -'— Well: KRU 31-1-35 <== Data Input Name: V Loepp <== Data Input Mud weight (ppg) I . IZ.0v I <== Data Input Weak point or LOT - Measured depth (ft) 1 3,574' 1 <== Data Input Weak point or LOT True vertical depth (ft) 3,257' <== Data Input Weak point or LOT - Hole angle (deg) 54.00 <== Data Input Weak point or LOT - Hole size (in) 0" <== Data Input Weak point pressure or LOT - EMW (ppg) 13.00 <_= Data Input Zone of interest - Measured depth (ft) 1,3.3W <== Data Input Zone of interest - True vertical depth (ft) 5,880' — Data Input Zone of interest - Hole angle (deg) 87.00 — Data Input Zone of interest - Hole size (in) 7.625" <== Data Input interest -Pore pressure EMW (ppg) 12.50 <_= Data Input dient (psi/ft) t 0.10 <_= Data Input Bottom hole assembly OD (in) 8.0" <_= Data Input Bottom hole assembly length (ft) 200' <_= Data Input Drill pipe OD (in) 5.500" <_= Data Input BHA annular vol. @ zone of interest (bbl/ft) -0.0057 DP annular vol. @ zone of interest (bbl/ft) 0.0271 DP annular vol. A weak point (bbl/ft) 0.0829 <== Data Weak point pressure (psi): PIO 2,202 psi Weak point pressure - Safety margin: Pmax 2,202 psi Pmax EMW 13.00 pp Max anticipated formation pressure (psi): Pf 3,822 psi Weak Pt to Zone of Interest distance (ND ft): OH D) 2,623' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 9,784' Maximum influx height at the bit (TVD ft): H (TVD) 31' Maximum influx height at the bit (MD ft): H {MD) 601' Calc. volume of (H) around BHA: V1bha -1.1 bbl Calc. volume of (H) around drill pipe: V1dp 10.9 bbl Calc. volume that H equals @ initial shut in: V1 9.7 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 4.4 bbl Calc. volume of Vwp @ initial shut in: V2 2,6_ bb-, Kick Tolerance: V2 12.6 bbl TE: Transform Points Source coordinate system co P State Plane 1927 - Aaska Zone 4 KRE4 3H-35 Datum: NAD 1927 - North Ame.fta Datum of 1927 (Mean) Tar -get coordinate system Abers Equal Area (-150j Datum: NAD 1927 - North America Datum of 1927 (Mean) — — --------- - ----- [Tyrpe values ir-do the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to copy and Ctd+Vto paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. -- - -------- < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: K R ck, 3 H — 35 PTD: 19 - 06q - Development /Service Exploratory Stratigraphic Test Non -Conventional FIELD: R 1 V r POOL: Ku ava Vc 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 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV-OIL - 490100 18 Well Name: KUPARUK RIV UNIT 31-1-35 Program SER Well bore seg ❑ PTD#: 2190640 Company CONOCOPHILLIPS ALASKA, INC. — —__ Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached NA Yes 2 Lease number appropriate Yes CMT -vol_ adequate to circulate on conductor & surf csg 3 Unique well name and number Yes - 21 CMT vol adequate to tie-in long string to surf csg I4 Well located in -a -defined pool Yes 22 _CMT will cover all known productive horizons 5 Well located proper distance from drilling unit boundary Yes 23 Casing designs adequate for C, T, B & permafrost 6 Well located proper distance from other wells Yes 24 Adequate tankage or reserve pit 7 Sufficient acreage available indrillingunit - Yes 25 If a re -drill, has a 1.0-403 for abandonment been approved 8 If deviated, is wellbore plat included Yes Directional plat and cross-sectional view included. 9 Operator only affected party Yes 10 Operator has appropriate_ bond in force Yes Diverter size and route_ meet regulations 11 Permit can be issued without conservation order_ Yes Yes Appr Date 12 Permit can be issued without administrative approval Yes Yes 13 Can permit be approved before 15-day_wait Yes Yes DLB 4/29/2019 31 Choke manifold complies w/API RP -53 (May 84)_ Yes 14 Well located within area and strata authorized by_Injection Order # (put IO# in comments) (For Yes AIO No. 2C for Kuparuk River Unit & CO 432D 15 All wells within 1/4 mile area of review identified (For service well only) Yes Yes 1-12S measures required 16 Pre -produced injector: duration of pre production less_ than 3 months (For service well only) Yes Yes 17 Nonconven. gas conforms to AS31.05.0300.1-.A),(j.2_.A-D) NA Permit can be issued w/o hydrogen sulfide measures Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date 18 Conductor string provided Yes - 80' conductor driven Engineering 19 Surface casinoprotectsall known_ USDWs Yes Surface casing set to 3574' MD 20 CMT -vol_ adequate to circulate on conductor & surf csg Yes 12.9-% excess cement planned 21 CMT vol adequate to tie-in long string to surf csg No 22 _CMT will cover all known productive horizons No Productive interval will be completed with uncemented production liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste -to approved disposal wells 25 If a re -drill, has a 1.0-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures i27 If diverter required, does it meet_ regulations_ Yes - - - Diverter size and route_ meet regulations Appr Date 28 Drilling fluid program schematic _& equip list adequate Yes Max formation pressure is 3.819 psig(12_.5 ppg EMW); will drill w/ 9.0 to 12.7 ppg EMW VTL 5/3/2019 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments)_ Yes MPSP is 3231 psig; will test BOPs to 3500 psig 31 Choke manifold complies w/API RP -53 (May 84)_ Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes 1-12S measures required 34 Mechanical condition of wells within AOR verified (For service well only) Yes No wells in the AOR I35 Permit can be issued w/o hydrogen sulfide measures No 3H -Pad wells are -H_2S-bearing._H2S_measures are required. - Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA_ DLB 4/29/2019 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date