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Home My WebLink About219-063DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2190630 Well Name/No. KUPARUK RIV UNIT 2M-40 Operator ConocoPhillips Alaska, Inc. MD 21245 TVD 6178 REQUIRED INFORMATION Completion Date 9/6/2019 Mud Log No DATA INFORMATION List of Logs Obtained: GR/Res/Sonic Scope/Neu/Den Well Log Information: Logi Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31186 Digital Data I� ED C 31186 Digital Data ED �1 C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data ED C 31186 Digital Data Completion Status 1-0I1- Current Status 1 -OIL Samples No V API No. 50-103-20804-00-00 UIC No Directional Survey Yes (from Master Well Data/Logs) Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 82 21244 9/10/2019 _ Electronic Data Set, Filename: 2M- 40_Drill_Mech_Depth.las 80 21244 9/10/2019 Electronic Data Set, Filename: CPAI_2M- 40_VI SION_Service_RT_LAS.las 82 2974 9/10/2019 Electronic Data Set, Filename: 2M- 40_LW D001_Scope_RM.las 2928 13496 9/10/2019 Electronic Data Set, Filename: 2M- 40_LW D002_VISION_Resistivity_RM.las 13352 14284 9/10/2019 Electronic Data Set, Filename: 2M- 40_LW D003_Scope_Resistivity_RM.las 14163 21244 9/10/2019 Electronic Data Set, Filename: 2M- 40_LW D004_VIS I ON_Resistivity_RM.las 82 21244 9/10/2019 Electronic Data Set, Filename: CPAI_2M- 40_VI S ION_Service_RM.las 43666 43669 9/10/2019 Electronic Data Set, Filename: 2M- 40_Drill_Mech_Time_LW DOOt.las 43673 43684 9/10/2019 Electronic Data Set, Filename: 2M- 40_Drill _Mech_Time_LW D002.las 43686 43692 9/10/2019 Electronic Data Set, Filename: 2M- 40_Drill_Mech_Time_LW D003.las 43693 43707 9/10/2019 Electronic Data Set, Filename: 2M- 40_Drill_Mech Time_LWD004.las 9/10/2019 Electronic File: WPSettings.dat 9/10/2019 Electronic File: IndexerVolumeGuid 9/10/2019 Electronic File: Drilling Mech Time LAS.txt AOGC'C Pagel of 5 i Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2190630 Well Name/No. KUPARUK RIV UNIT 2M40 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20804-00-00 MD 21245 TVD 6178 Completion Date 9/6/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31186 Digital Data 9/10/2019 Electronic File: 2M-40 EOW LeHer.doc ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI_2M- 40_Ddiling_Mechanics_Depth_RM. PDF ED SII C 31186 Digital Data 9/10/2019 Electronic File: Drilling Mech Depth log.txt ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI _2M - 40_V IS I ON_Service_2MD_RT.pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI - _2M 40_V IS ION_Service_2TV D_RT.pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI_2M- 40_V I SION_Service_5MD_RT.pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI _2M - 40_V IS I ON_Service_STVD_RT. pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI _2M- 40_VISION Service_2MD_RM.Pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI 2M- 40_VISION Service_2TVD_RM.Pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI _2M- 40_VISION Service_5MD_RM.Pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI 2M- 40_VISION Service_5TVD_RM.Pdf ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI 2M- 40_Drilling_Mechanics_Time_RM_LW D001.PDF ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI _2M- 40_Drilling_Mechanios_Time_RM_LW D002.PDF ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI 2M- 40_Drilling_Mechanice_Time _RM_LW D003.PDF ED C 31186 Digital Data 9/10/2019 Electronic File: CPAI_2M- 40_Drilling_Mechanics_Time _ RM _LW D004.PDF ED C 31186 Digital Data 9/10/2019 Electronic File: Drilling Mach Time.txt ED C 31186 Digital Data 9/10/2019 Electronic File: 2M-40_Max ell_Surveylist.csv ED C 31186 Digital Data 9/10/2019 Electronic File: 2M-40 Surveys plus i FinalFinal.xlsx ED C 31186 Digital Data 9/10/2019 Electronic File: Folder info.txt Log 31186 Log Header Scans 0 0 2190630 KUPARUK RIV UNIT 2M40 LOG HEADERS AOGCC Page 2 of 5 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Orill 2190630 Well Name/No. KUPARUK RIV UNIT 2M-40 Operator ConocoPhillips Alaska, Inc. API No. 50-103.20804-00-00 MD 21245 TVD 6178 Completion Date 9/6/2019 Completion Status 1-01L Current Status 1-0I1- UIC No ED C 31301 Digital Data 82 2974 10/4/2019 Electronic Data Set, Filename: 2M- 40_LWD001_Scope RM.las ED C 31301 Digital Data 2928 13496 10/4/2019 Electronic Data Set, Filename: 2M- 40_LW D002_VISION_Resistivity_RM.las ED C 31301 Digital Data 13352 14284 10/4/2019 Electronic Data Set, Filename: 2M- 40_LW D003_Scope_Resistivity_RM.las ED C 31301 Digital Data 14163 21244 10/4/2019 Electronic Data Set, Filename: 2M- 40_LW D004_VISION_Resistivity_RM.las I ED C 31301 Digital Data 82 21244 10/4/2019 Electronic Data Set, Filename: CPAI_2M- 40_VISION Service_RM.las ED C 31301 Digital Data 10/4/2019 Electronic File: LWD001 Surface.zip ED C 31301 Digital Data 10/4/2019 Electronic File: LWD002 Intermediate.zip ED C 31301 Digital Data 10/4/2019 Electronic File: LWD003 Intermediate Il.zip ED C 31301 Digital Data 10/4/2019 Electronic File: LWD004 Production.zip ED C 31301 Digital Data 10/4/2019 Electronic File: CPAI 2M- M- 40_VISIONRMDLI S.pdf 40—VISION RM DI-I ED C 31301 Digital Data 10/4/2019 Electronic File: CPAI 2M- M- 40_VISIONRMDLI S.zip 40—VISION RM DLI ED C 31301 Digital Data 10/4/2019 Electronic File: CPAI _2M- 40_VISION Service_2MD_RM.Pdf 1 ED C 31301 Digital Data 10/4/2019 Electronic File: CPAI-2M- 40—VISION Service_2TVD_RM.Pdf ED C 31301 Digital Data 10/4/2019 Electronic File: CPAI _2M - 40_V I SI ON_Semice_5MD_RM.Pdf ED C 31301 Digital Data 10/4/2019 Electronic File: CPA[ -2M- 40 VISION Service_5TVD_RM.Pdf ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD27 EOW Compass Surveys [Canvas].txt I ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD27 EOW Compass Surveys [Macro].txt I ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD27 EOW Compass Surveys [Petrel].txt ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD27 EOW Compass Surveys [Survey].txt AOGCC Page 3 of 5 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2190630 Well Name/No. KUPARUK RIV UNIT 2M-40 Operator ConoeoPhillips Alaska, Inc. API No. 50-103-20804-00-00 MD 21245 TVD 6178 Completion Date 9/6/2019 Completion Status 1.011- Current Status 1-0I1- UIC No ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD27 EOW Compass Surveys.pdf ED C 31301 Digital Data 10/4/2019 Electronic File: 21040 NAD83 EOW Compass Surveys [Canvas].txt ED C 31301 Digital Data 10/4/2019 Electronic File: 2M40 NAD83 EOW Compass Surveys [Macro].txt ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD83 EOW Compass Surveys [Petrel].txt ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD83 EOW Compass Surveys [Survey].txt ED C 31301 Digital Data 10/4/2019 Electronic File: 2M-40 NAD83 EOW Compass Surveys.pdf Log 31301 Log Header Scans 0 0 2190630 KUPARUK RIV UNIT 2M-40 LOG HEADERS ED C 31593 Digital Data 2714 2893 12/9/2019 Electronic Data Set, Filename: 2M- 40_PLUG_28SEP19_CORRELATION PASS.Ias ED C 31593 Digital Data 2647 2922 12/9/2019 Electronic Data Set, Filename: 2M- 40_PLUG_28SEP19_SETTING PASS.Ias ED C 31593 Digital Data 12/9/2019 Electronic File: 2M-00—PLUG _28SEP19.pdf ED C 31593 Digital Data 12/9/2019 Electronic File: 2M-40_PLUG_28SEP19_1mg.tiff Log 31593 Log Header Scans 0 0 2190630 KUPARUK RIV UNIT 2M40 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Production Test Information Y'V Geologic Markers/Tops U COMPLIANCE HISTORY Directional / Inclination Data Mud Logs, Image Files, Digital Data Y /P Core Chips Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files ! r 1 Core Photographs Y / Daily Operations Summary l.% Cuttings Samples �Y / NA/ Laboratory Analyses Y / A0 G( ( Page 4 of 5 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2190630 Well Name/No. KUPARUK RIV UNIT 2101-40 Operator ConocoPhillips Alaska, Inc. MD 21245 TVD 6178 Completion Date 9/6/2019 Completion Status 1-0I1 Current Status 1-0I1 Completion Date: 9/6/2019 Release Date: 5/7/2019 Description Date Comments Compliance Reviewed By: API No. 50-103-20804-00.00 UIC No Date: 7 I w 2-C AOGC'C Page 5 of 5 Friday, January 3. 2020 WELL LOG TRANSMITTAL #906009512 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2M-40 Run Date: 9/28/2019 21 9063 3 159 3 December 5, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of, Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-40 Digital Data in LAS format, Digital Log Image file E C E I V E D 1 CD Rom 50-103-20804-00 DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: tZMIN Signed: STATE OF ALASKA ALASKH OIL AND GAS CONSERVATION COMMIS£ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ Stratigraphic❑ Service ❑ 219-063-0 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20804-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2M-40 ADL 25586, ADL 25585, ADL 25590 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): POST FRAC REPORT Kuparuk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 21,245 feet Plugs measured None feet true vertical 6,178 feet Junk measured None feet Effective Depth measured 21,201 feet Packer measured 13,893 feet true vertical 6,177 feet true vertical 5,982 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 139 feet 20 176' MD 176' TVD RECEIVED SURFACE 2,928 feet 13 3/8 " 2,965' MD 2652' TVD TERMEDIATE 1 13,451 feet 9 5/8 " 13,486' MD 5806' TVD TERMEDIATE 2 1,025 feet 7 14,283' MD 6075' TVD OCT 2 4 2019 PRODUCTION 7,103 feet 41/2" 21,201'MD 6178'TVD 1^, AOGCC Perforation depth: Measured depth: 14525-20836 feet `" `"l/�, FRAC SLEEVES True Vertical depth: 6100-6175 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L80 14,107' MD 6,042' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER PREMIER PACKER 13,893' MD 5,982' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14,525-21,190 Treatment descriptions including volumes used and final pressure: Total Well - 15 stages 1,501,990lbs placed ...See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: e e o 825 540 Subsequent to operation: 2750 360 1950 1325 250 14. Attachments (required per20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations El � Exploratory ❑ Development [21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 y0 tib,` GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-407 Contact Name: Adam Klem Authorized Name: Adam Klem contact Email: Adam.Klem@cop.com Authorized Title: Sr. Completion Engineer � O y Contact Phone: (907) 263-4529 Authorized Si �� nature: Date: ! Form 30-404 Revised 4/2017 C +� 1 O J G � I ZOI` �� rr�� (�/1Q RBDM Lb�kCT 2 5 2019 Submit Original Only 2M- 40 FRAC STIMULATE DTTMSTJOBTYP SUMMARYOPS 9/15/19 DRILLING BRUSHED GLM POCKET @ 12945' RKB, SET DUMMY SUPPORT- VALVE @ 12945' RKB, CAPITAL HAVE LITTLE RED SERVICE MITT 4700 psi GOOD TEST, MITIA 3850 psi GOOD TEST. IN PROGRESS, READY FOR CTU CLEAN OUT. 9/16/19 DRILLING RIH WITH BAKER FISHING BHA, CIRCULATE BOTTOMS UP SUPPORT- TO EVACUATE DRILLING MUD WITH SLICK DIESEL, PULL CAPITAL DFCV AT 13922' CTMD, READY FOR FRAC 9/21/19 DRILLING PUMPED DATA FRAC AND STAGES 1 THRU 4 OF SUPPORT - FRAC,TOTAL OF 405,033 LBS WANLI 20/40 SAND. WELL IS CAPITAL FREEZE PROTECTED, IN PROGRESS. 9/24/19 DRILLING PUMPED STAGES 5 THRU 10 OF FRAC,TOTAL OF 580,000 SUPPORT - LBS WANLI 20/40 SAND. WELL IS FREEZE PROTECTED, IN CAPITAL PROGRESS. 9/26/19 DRILLING PUMPED STAGES 11 THRU 15 OF FRAC,TOTAL OF SUPPORT - 505,800 LBS WANLI 20/40 SAND. WELL IS FREEZE CAPITAL PROTECTED. READY FOR S/L. KUP Pr 1 WELLNAME 2M-40 WELLBORE 2M-40 ConocoPhillips Alaska, Inc CCr DkTOR: Y NIPPLE: wsun; WNMCE, T 13M l G44 LIFT, GiG LIFT; WS LIFT: PPCFER: NIPPLE', LCCPTOR: MVLECHOE: 10cFvuWe', 19.MO I Mill 1 Xyduln Feeclwq IDlN.O I HO—W F. M... I kw1 Hydraulic Fracturing Fluid Product Compormrd Wormalion Dis. .m Fr¢cEve Me BR1M0 b: NAW cwarb: Xmnwnaa RBINurLv: 601wa0BM NCRM BLOFE EM WYIXmne aM.. IMaO Lanplawft AFO] I-a. nal I.onRM1el rmlx.Borc Nnozf ImamseaNM: vroeM ONwvamaM R.(1vm: Depm , Taal]v.wvoMn wi n .amr. F—W—q Erna C,tm. 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Hurwanm ]Bt d]IBYA c-- 1aY[-]65 W50Y 'rric",au.R 1<BEuai EM macryecron N .��. n �.. .. 586 XatlAwbn Ocew iW w 'ID1811 SIIa EWrcI 6a.11a Wa3 0. JA am«rlc Aum fia> a B)a CM..' i, H>02Jtd Ma' S15DW Na Akre - 81.10.3 3)] OgexE pvnaamn PrtpaM'/ ....�.e ..�.- . 38@ WIIWrIm Oenlw MX I4AINnMm m1811 $GB PnNI«r-r 1<ma�eeXn. a l+wt> omlPrawnamaw-nvemev-, moezma CIII J. mlmMa ¢0.]w a11z nlosa] walromte 13awdee 11,cuu,zaw «law. a7-u-a . mexlas 3033154w+n. mw3aa 1Da mn EmbM 131633 - 31tl msn.1 36 smmmaulnM wa r. 1 mznu rM"' u16r TNN wahr vaumewww mayIMUQna¢nxatx, gduMdv wy«reganwalmr ^ Inlormawn ie EmM w Ne muimum wlantia kr mrcemntiw AHEM nlabAI may ca,1. a. HdFur "d1w40pem Pr i;uuiu=tna"nvdmFM, WMla MO*Informationnn Ennpwldsd a Fk wmynerrll.ar.don lebdww oMlrre]lrom..uwae M.., SMery DmaSree N.D.), PnaWt lM Opaelwia nNma,tebraii—aeM.rmmpelamlDrmation. Aq araswrrsreyrdrptM wraeMWMe MSpS eM1oultlMdrMaito Ne ¢uppiervfn pwieeei[ Tne Cccupalicnd Saltly aM Wssan PWnirealratlane(OSIHI rqulatiorc pwern tM Mlwb Ior1M d¢tlwure NLNe IMormeEm. gene rvce tnal FeMry Laxprolx.6'prepriNary','TeeeamcY', ene'cmfiaerrtial buelneu Irecrmapan" anetM 1rox Mrmiamne4oni r en MSDSi¢¢u0 b18 I eO Hydraulic Fracturing Fluid Product Component Information Disclosure 7J :' 9/21/2019 L. Job End Date: 9/26/2019 M$ State: Alaska Federal Well: County: Harrison Bay NO API Number: 50-103-20804-00-00 ('Total Base Water Volume (gap: Operator Name: ConocoPhillips Company/Burlington 0 Hydraulic Fracturinq Fluid Composition: Resources LWell Name and Number: 2M-40 Latitude: 70.27151900 �. Longitude: -150.10097500 Datum: NAD83 Federal Well: NO Indian Well: NO True Vertical Depth: 6,177 ('Total Base Water Volume (gap: 907,937 Total Base Non Water Volume: 0 Hydraulic Fracturinq Fluid Composition: Supplier V Focus Chemical Disclosure Registry GG��ER Oil & Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)** I by mass)** Sea Water Operator Base Fluid Water 7732-18-5 96.00000 79.37775 Density = 8.530 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.14054 OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below BE -6 MICROBIOCIDE Halliburton Biocide Listed Below MO -67 Halliburton pH Control Additive Listed Below LVT-200 Penreco Freeze Protect Listed Below OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Listed Below SP BREAKER Halliburton Breaker Listed Below CL -31 CROSSLINKER Halliburton Crosslinker Listed Below CL -22 UC Halliburton Crosslinker Listed Below Wanli 20140 Wanli Proppant Company Additive Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below WG -36 GELLING AGENT Halliburton Gelling Agent Listed Below Items atyme are Trade Names with the exception of Base Water Items below am the individual Corundum ingredients. 1302-74-5 65.00000 10.41017 Mullite 1302-93-8 45.00000 7.20704 Sodium chloride 7647-14-5 4.00000 3.30928 Hydrotreated Distillate, light 64742-47-8 100.00000 0.65846 Guar gum 9000-30-0 100.00000 0.30705 Borate salts Proprietary 60.00000 0.06631 Potassium formate 590-294 60.000001 0.06631 Ethanol 64-17-5 60.00000 0.04316 Potassium metaborate 13709-94-9 60.00000 0.03096 Oxylated phenolic resin Proprietary 30.00000 0.02877 Sodium hydroxide 1310-73-2 30.00000 0.02293 Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02158 Ammonium persulfate 7727-54-0 100.00000 0.02120 Cured acrylic resin Proprietary 30.00000 0.00636 Crystalline silica, quartz 14808-60-7 30.00000 0.00597 Poly(oxy-1,2ethanediy0, alpha-(4-nonylphenyl)- omega-hydroxy-, branched 127087-87-0 5.00000 0.00360 Naphthalene 91-20-3 5.00000 0.00360 • Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total may be over 1o0% ^• If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Nola : For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Dale Sheets (MSDS) Potassium hydroxide 1310-58-3 5.00000 0.00258 2-Bromo-2-niter l,3- 52-51-7 100.00000 0.00163 propanediol Sodium carboxymethyl 9004-324 1.00000 0.00111 cellulose Sodium glycollate 2836-32-0 1.00000 0.00111 Acrylate polymer Proprietary 1.00000 0.00111 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 1,2,4 Tdmethylbenzene 95E3-6 1.00000 0.00072 Sodium persulfate 7775-27-1 100.00000 0.00037 Sodium sulfate 7757-82-6 0.100001 0.00000 • Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total may be over 1o0% ^• If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Nola : For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Dale Sheets (MSDS) HALLIBURTON Sales Order# 0905963300 Conoco Phillips Alaska 2M-40 Intervals 1-15 C -Sand Formation Harrison Bay County, AK API: 50-103-20804 Preparedfor: Scott Pessetto September 26, 20/9 Stimulation Treatment Post Job Report #30 Hybor G Prepared By: Jean Goueth/ Keegan Lambe Chad Burkett Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. H^AA. LMTON I Pn^",.nx�n CnMvecwn�nc Table of Contents Pa e(S) Section Executive Summary Wellbore Information Actual Design B-23 Interval Summary 1425-36 Fluid System-Proppant Summary Interval 1 Plots inteml2 Plots Interval 3 Plots Interval4 Plots Interval s Plots M-59 Interval 6 Plots 60-63 Interval? Plots 64-67 Interval8 Plots 68-71 Interval Plots 72-75 Interval 10 Plots 76-82 Interval 11 Plots 83 - 87 Interval 12 Plots 89-91 Interval 13 Plots 92-95 Interval 14 Plots %-99 Interval 15 Plots 100 pendix 101 Well Summary 102 Chemical Summary 103 -105 Planned Design 106 Water Straps Day 1 107 Water Straps Day 2 109 Water Straps Day 3 109 Water Analysis Day 1 110 Water Analysis Day 2 111 Water Anal is Da 3 112 Real -Time Oc 113 Prejob Break Teat Day 1 114 Prejob Break Test Day 2 115 Prejob Break Test Day 3 116 Farm 15 Zone 1 117 Farm 15 Zone 2 118 Fann 15 Zone 119 Farm 15 Zone 4 120 Fann 15 Zone 5 121 Fann 15 Zone 6 122 Farm 15 Zone 7 123 Farm 15 Zone 8 124 Fart 15 Zone 9 125 Farm 15 Zone 10 126 Farm 15 Zone 11 127 Farm 15 Zone 12 128 Farm 15 Zone 13 129 Fann 15 Zone 14 130 Fann 15 Zone 15 131 Event Log Day 1 132 Event Lag Day 2 133 Event Log Day 3 134-135 Lab Testing Conoco Phillips Alaska - 2M-40 TOC Engineering Executive Summary On September 21, 2019 a stimulation treatment was performed in the C -Sand formation on the 2M-40 well in Harrison Bay County, AK. The 2M-40 was a 15 stage Horizontal Sleeve Design. The proposed treatment consisted of: 826,520 gallons of #30 HyborG 42,795 gallons of #30 WaterFrac G 5,040 gallons of Freeze Protect 1,500,000 pounds of Wanli 20/40 The actual treatment fully completed 14 of 15 stages. 0 stages were skipped, and 1 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 867,244 gallons of #30 HyborG 40,693 gallons of #30 WaterFrac G 4,366 gallons of Freeze Protect 1,500,100 pounds of Wanli 20/40 A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: During interval 7, the pumps sanded off during 6ppg proppant. The call was made to flush the well, cutting approximatly 10, 000lbs from design. The interval was successfully flushed and the pumps were then cleared of proppant. Pumping was resumed once proppant was cleared. During Day 3, an issue with a pump required the well to be flushed. Once the well was successfully flushed the pump was repared and re -tested. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. Chemicals were adjusted as needed to maintain the targeted parameters. 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. Thank you, Keegan Lambe Technical Professional Halliburton Energy Services Conoco Phillips Alaska - 2M-40 Executive Summary Jean Goueth Senior Technical Professional Halliburton Energy Services i Canso Phillips Alaska -2Mi0 Wellbore Information a- . Conoco Phillips Alaska - 2M40 Actual Design �•>. �� —ems m��m�� - ® ��®�a��r�a �aaaaaaa�mmm��>•�mm®®� mom. -.gym �®Ea[->•��®®� �r>•mm��m�®®� �� >♦�sr- c�,..��mmm•®®�®m•®�mam.�m®gym®®mt� ce-aS��mm�®®�®�©®mai�liv®gym®®®� ® Q�®®®©®�m•m•��®�mmm®gym®®®� �sa-��ao•mme�:�m�mmlEct•�.si� -- ®�¢"e•-.��-�m�eu�atam•m�€r.��e�® ®�rr��.®�sa+t•ca��r.^>_�r,-na®®�r-_a©�mmmm,�mml�� 0�Exram��•t•��®m•m•mmmm��s.�®m�.a� ®�c.+��t�®cs m•®®®m•®®tri mm®®gym®m•®� ®�.�ca�®�mcs>• ©�mR �c��c�mr+>•�*-�®��m•m•®Est�mmm®gym®ins®� t®gym®m•m•mm®®gym®®®� ®arsmscs�tr_��C•!• m ®��am•®�®®mm®®gym®mmt� �r� m �sr>_�c� ®®�-•�� ta:'>im�t+�iF��cr>•aca�E��x�� m r,....��,-,�-f.,.,.�� ®�v �t•�� m•m•m.s:..,-�mmmt®�rno��m� �*�a-�^'�a>•m�amD:>��®m•�usrammm��cr>tta�E�mm ®®er��r.�� m ��—+m��.>• �.� rn �� ia��s�m•�a• mm�u�s•��rnn�m��m Conoco Phillips Alaska - 2M40 Actual Design — ",.e, . e ii—se, Conoco Phillips Alaska - 2M40 Actual Design 11 �Wlmram 101. pasessas a— Is I Em Conoco Phillips Alaska - 2M40 Actual Design wnmmeR U w.- 1 .1% .11 1 Conom Phillips Maska - 2M�O �ual Design Interval Summary Start Date/Time: 9121119 11:58 End Date/Time: 9/21119 14:25 Pump Time: 86 min Initial Rate (Breakdown): 14.6 bpm Initial Surface Pressure (Breakdown): 6,359 psi Initial BH Pressure (Breakdown): 5,670 psi Max Rate: 28.5 bpm Max Surface Pressure: 7,222 psi Max BH Pressure: 6,426 psi Average Rate: 23.1 bpm Average Missile Pressure: 6,274 psi Average Surface Pressure: 6,259 psi Average BH Pressure: 6,082 psi Average Missile HHP: 3,558 hhp Initial CA Pressure: 397 psi Max CA Pressure: 524 psi Max Proppant Concentration: 4.14 PP9 Average Vise: 28.8 cp Average Temp: 84.7 F Average pH: 9.1 ISIP: 2455 psi Initial Fracture Gradient: 0.397 psilft Initial 5 min: 1753 psi Initial 10 min: 1566 psi Initial 15 min: 1455 psi Proppant Summary Wanli 20/40 Pumped: 96,200 lbs Total Proppant Pumped* : 96,200 lbs Proppant in Formation: 96,200 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 92,300 gal 2,198 bbis #30 WaterFrac G Volume: 9,713 gal 231 bbis Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 24,109 gal 574 bbis Proppant Laden Fluid Volume: 45,029 gal 1,072 bb/s Flush Volume: 9,713 gal 231 bbls Minifrac Volume: 14,124 gal 336 bb1s Spacer and Ball drop Volume: 1,024 gal 24 bbls Interval Status: Completed a minarac was pumpeu trom ii:*�m to 1�:uivm on wrziu�uiv. maximum ratewas, zu.�jopm, tngineer Jean Goueth x Surface Pressure was 7136psi, Max Downhole Pressure was 6374. Average rate was Treater Joshua Capin 11 bpm, Average surface pressure was 5862psi, average treating pressure was 5905psi an arage downhole pressure was 5889psi. The Minifrac took 33 minutes and had an average Supervisor. Chad Burkett sepower of 3033. Closure was, observed using the G -Function plot at 4145psi. Pumping re,, I - ---- ------ ---- Conoco Phillips Alaska - 2M-40 Interval Summary 'Values for proppant are taken from soft,,vare calculations based on multiple variables Proppaid! is billed off of weight ticket volumes and may vary slightly from this number Conoco Phillips Alaska - 2M-40 Interval Summary Customer Engineer. Scott Pessafto Customer Rep: Paul Bassette 2M-40 - C -Sand - Interval 2 Interval Summary Start Daterl-ime: 9/21119 14:25 End Daterrime: 9/21/19 15:38 Pump Time: 73 min Initial Rate (Breakdown): 11.9 bum Initial Surface Pressure (Breakdown): 7,129 psi Initial BH Pressure (Breakdown): 8,081 psi Max Rate: 27.9 bpm Max Surface Pressure: 7,363 psi Max BH Pressure: 8,081 psi Average Rate: 24.3 bpm Average Missile Pressure: 6,509 psi Average Surface Pressure: 6,541 psi Average BH Pressure: 5,990 psi Average Missile HHP: 3,877 hhp Initial CA Pressure: 517 psi Max CA Pressure: 543 psi Max Proppant Concentration: 3.91 PPg Average Visc: 29.6 cp Average Temp: 85.6 F Average pH: 9.21 Proppant Summary Wanli 20/40 Pumped: 95,780 lbs Total Proppant Pumped - : 95,780 lbs Proppant in Formation: 95,780 Its Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 Hyboi Volume: 71,144 gal 1,694 bbis #30 WaterFrac G Volume: 0 gal 0 bills Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 24,053 gal 573 bbls Proppant Laden Fluid Volume: 45,523 gal 1,084 bbis Spacer and Ball drop Volume: 1,568 gal 37 bbls Interval Status: Completed Comments: Treatment pumped as designed, when stivapping sand castle lost sand during the 4 ppg stage, but Engineer. Jean Goueth recovered and finish the stage as designed. Treater. Joshua Capho Supewiscr. Chad Burkett I �Values for propparit are taken from software calculations lesed oil multiple variables Customer Engineer Scott Pessetto Propient is billed off of weight ticket volumes and may vary slightly from this number Customer Rep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 10 2M-40 - C -Sand - Interval 3 Interval Summary Start Date/Time: 9121119 15:38 End Daterlime: 9/21/19 16:49 Pump Time: 71 min Initial Rate (Breakdown): 15.3 bpr" Initial Surface Pressure (Breakdown): 6,959 psi Initial BH Pressure (Breakdown): 7,161 psi Max Rate: 27.8 bpm Max Surface Pressure: 7,300 psi Max BH Pressure: 8,402 psi Average Rate: 24.9 bpm Average Missile Pressure: 6,424 psi Average Surface Pressure: 6,467 psi Average BH Pressure: 5,606 psi Average Missile HHP: 3,919 hhp Initial CA Pressure: 543 psi Max CA Pressure: 556 psi Max Proppant Concentration: 4.20 pPg Average Visc: 27.6 CID Average Terri 85.2 F Average pH: 9.35 Proppant Summary Wanli 20/40 Pumped: 104,055 lbs Total Proppant Pumped* : 104,055 lbs Proppant in Formation: 104,055 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 70,817 gal 1,686 bills #30 WaterFrac G Volume: 0 gal 0 blils Freeze Protect Volume: 0 gal 0 bills Fluid Summary (by stage description) Pad Volume: 24,103 gal 574 bbls Proppant Laden Fluid Volume: 45,325 gal 1,079 bbis Spacer and Ball drop Volume: 1,388 gal 33 bbis Interval Status: Completed Comments: Treatment pumped as designed Engineer. Jean Goueth Treater Joshua Capno Supervisor Chad Burkett -Values for proppant are taken from software calculations based oil multiple variables Customer Engineer. Scott Pessetc, Proppant is billed off of weight ticket volumes and may very slightly from this number Customer Rep: Paul Bessefte Conoco Phillips Alaska - 2M-40 Interval Summary 11 2M-40 - C -Sand - Interval 4 Interval Summary Start DateurTime: 9121/19 16:49 End Dateffinne: 9121/19 18:06 Pump Time: 77 min Initial Rate (Breakdom): 15.1 bpm Initial Surface Pressure (Breakdom): 7,174 psi Initial BIH Pressure (Breakdom): 8,402 psi Max Rate: 27.9 bpm Max Surface Pressure: 7,300 psi Max BH Pressure: 8,402 psi Average Rate: 23.7 bpm Average Missile Pressure: 6,294 psi Average Surface Pressure: 6,330 psi Average BH Pressure: 5,873 psi Average Missile HHP: 3,656 hhp Initial CA Pressure: 552 psi Max CA Pressure: 562 psi Max Proppant Concentration: 4.56 ppg Average Visc: 25.5 cp Average Temp: 87.34 F Average pH: 9.35 ISIP: 3286 psi Initial Fracture Gradient: 0.534 psilft Initial 5 min: 2291 psi Initial 10 min: 2126 psi Proppant Summary WanIl 20140 Pumped: 108,998 lbs Total Proppant Pumped* : 108,998 lbs Proppant in Formation: 108,998 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gat 0 bb1s #30 HyborG Volume: 70,359 gat 1,675 bbis #30 WaterFrac G Volume: 7,335 gat 175 bibis Freeze Protect Volume: 1,473 gat 35 bibis Fluid Summary (by stage description) Pad Volume: 24,016 gal 572 bbls Proppant Laden Fluid Volume: 46,343 gal 1,103 bbis Flush Volume: 7,335 gal 175 bbis Freeze Protect Volume: 1,473 gal 35 bbis Interval Status: Completed Comments: Treatment pumped as designed Engineer Jean Goueth Theater Joshua Capno Supervisor Chad Burkett 'Values for Proppant are taken from software calculations based on multiple variables Customer Engineer. ScottPessetto Proppant is thitled off of weightticket volumes and may vary slightly from this number CustomerRep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 12 2M40 - C -Sand - Interval 5 Interval Summary Start Date/Time: 9/24/19 9:58 End Date/Time: 9124/19 11:34 Pump Time: 96 min Initial Rate (Breakdom): 11.8 bpm Initial Surface Pressure (Breakdom): 6,535 psi Initial BH Pressure (Breakdom): 6,520 psi Max Rate: 25.6 bpm Max Surface Pressure: 7,038 psi Max BH Pressure: 7,828 psi Average Rate: 23.4 bpm Average Missile Pressure: 5,338 psi Average Surface Pressure: 5,337 psi Average BH Pressure: 6,220 psi Average Missile HHP: 3,067 hhp Initial CA Pressure: 399 psi Max CA Pressure: 535 psi Max Proppant Concentration: 4.23 clog Average Visc: 25.8 cp Average Temp: 87.38 F Average pH: 9.5 Proppant Summary Wanli 20/40 Pumped: 96,324 ins Total Proppant Purrl : 96,324 lbs Proppant in Formation: 96,324 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 77,235 gal 1,839 blits #30 WaterFrac G Volume: 0 gal 0 bb1s Freeze Protect Volume: 0 gal 0 blits Fluid Summary (by stage description) Pad Volume: 24,027 gal 572 bbis Proppant Laden Fluid Volume: 44,746 gal 1,065 bbls Spacer and Ball drop Volume: 6,831 gal 163 bbls Interval Status: Completed Comments: Lost pumps 4 & 5 during pad stage on interval 5, customer approve to shutdotivin after ball seats to Engineer Jean Goueth fix the pumps. Treater Joshua Caprio Supervisor Joshua Capric 'Values for proppart are taken front software cafculations based on rultiple variables Customer Engineer. Scott Pessefto Propleant is billed off of weight ticket volurres and runny vary slightly fron this number Customer Rep: Paul Bessefte Conoco Phillips Alaska - 210-40 Interval Summary 11 3 2M-40 - C -Sand - Interval 6 Interval Summary Start Datef rime: 9/24/19 12:35 End Date/Time: 9/24/19 14:02 Pump Time: 87 min Initial Rate (Breakdom): 11.9 bpm Initial Surface Pressure (Breakdom): 7,296 psi Initial Bld Pressure (Breakdown): 8,423 psi Max Rate: 29.1 bpm Max Surface Pressure: 7,050 psi Max BH Pressure: 6,542 psi Average Rate: 25.2 bpm Average Missile Pressure: 6,538 psi Average Surface Pressure: 6,482 psi Average BH Pressure: 5,767 psi Average Missile HHP: 4,038 hhp Initial CA Pressure: 533 psi Max CA Pressure: 566 psi Max Proppant Concentration: 4.37 pp9 Average Vlsc� 27.2 cp Average Temp: 90.2 F Average pH: 9.68 Proppant Summary Werth 20/40 Pumped: 104,810 lbs Total Proppant Purl : 104,810 lbs Proppant in Formation: 104,810 lbs Fluid Summary (by Hold description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 72,139 gal 1,718 bbis #30 WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal bbls Fluid Summary (by stage description) Pad Volume: 26,123 gal 622 bbis Proppant Laden Fluid Volume: 44,935 gal 1,070 bbis Spacer and Ball drop Volume: 1,081 gal 26 bbis Intewal Status: Completed Comments: Shutdown after ball seated, to fix pumps 4 & 5, once we tried to resume pumping formation was Engineer. Jean Goueth close down Trisater Joshua Capho Supervisor Joshua Caprio Walues for proppant are taReq from software, caiculahons rased on muliple variables Customer Engineer. Scott Pessetto Proppant is billed off of weight ticket volumes ard may vary slightly from this �umber Customer Rep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 14 211,11-40 - C -Sand - Interval 7 Interval Summary Start Date/Time: 9124/19 14:02 End Date/Time: 9124/19 14:54 Pump Time: 52 min Initial Rate (Breakdown): 12.1 bpm Initial Surface Pressure (Breakdown): 6,894 psi Initial BH Pressure (Breakdown): 6,765 psi Max Rate: 2&6 bpm Max Surface Pressure: 7,096 psi Max BH Pressure: 7,656 psi Average Rate: 20.7 bpm Average Missile Pressure: 5,857 psi Average Surface Pressure: 5,809 psi Average BH Pressure: 5,476 psi Average Missile HHP: 2,970 hhp Initial CA Pressure: 566 psi Max CA Pressure: 566 psi Max Proppant Concentration: 6.34 Ppg Average Visc: 28.7 cp Average Temp: 84.3 F Average pH: 9.72 Propprant Summary Wanli 20140 Pumped: 87,451 lbs Total Proppant Pumped* : 87,451 lbs Proppant in Formation: 87,451 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls #30 HyborG Volume: 42,238 gal 1,006 bills #30 WaterFrac G Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Pad Volume: 15,015 gal 358 bbis Proppant Laden Fluid Volume: 26,065 gal 621 bbis Spacer and Ball drop Volume: 1,158 gal 28 bbls Interval Status: Cut Short Lost a few pumps that sanded off during the 6 ppg� We have to finish the job at low rate. Fluid looks Lngfnser Jean Goueth good, ball drop and ball seat are good. Cut 6 piag stage short by 100 Sacks. Tmater. Joshua Capno Supervisor Joshua Capno �Valucs for Proppant are taken from software calCUflations based on multiple variables Customer Engineer. Scott Pessetto Proppant is billed off of weight ticket volumes and may vary slightly from this number Custorri Paul Bessette, Conoco Phillips Alaska - 210-40 Interval Summary 15 2M-40 - C -Sand - Interval 8 Interval Summary Start Daterf-ime: 9/24/19 14:54 End Dateffinne: 9/24/19 16:46 Pump Time: 92 min Initial Rate (Breakdown): 13.1 bpm Initial Surface Pressure (Breakdown): 4,038 psi Initial BH Pressure (Breakdown): 6,339 psi Max Rate: 30.3 bpm Max Surface Pressure: 7,053 psi Max Bld Pressure: 5,542 psi Average Rate: 22.9 biorn Average Missile Pressure: 6,014 psi Average Surface Pressure: 5,968 psi Average BH Pressure: 5,350 psi Average Missile HHP: 3,374 hhp Initial CA Pressure: 541 psi Max CA Pressure: 546 psi Max Proppant Concentration: 6.28 pp9 Average Vise: 31.3 CID Average Temp: B4.7 F Average pH: 9.69 Completed Proppant Summary Wanli 20/40 Pumped: 99,104 lbs Total Proppant Pumped* : 99,104 its Proppant in Formation: 99,104 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 59,776 gal 1,423 bbis #30 WaterFrac G Volume: 7,928 gal 189 bbls Freeze Protect Volume: 0 gal 0 bills Fluid Summary (by stage description) Pad Volume: 15,017 gal 358 bb/s Proppant Laden Fluid Volume: 27,871 gal 664 bbis Spacer Volume: 14,368 gal 342 bbis Shut -In Volume: 0 gal 0 bbls Spacer and Ball drop Volume: 1,053 gal 25 bbis Interval Status: Completed Flush Stage Stage 8 pad, and shutdown to worK on the pumps that sandout during the U ppg send triginear. Jean Goueth stage. After cleaning up the pumps resume the job per design. Treatinc Joshua Caputo Supervisor. Joshua Call Values for propped are taken from soRware calculations based on multiple variables Customer Engineer Scott Pessetto Proppant is billed off of weight ticket volumes and may vary slightly from this number Customer Rep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 16 2M40 - C -Sand - Interval 9 Interval Summary Start Daterlime: 9124/19 16:46 End Date/Time: 9124/19 17:35 Pump Time: 49 min Initial Rate (Breakdom): 12.1 born Initial Surface Pressure (Breakdom): 6,821 psi Initial BH Pressure (Breakdom): 6,479 psi Max Rate: 27.2 born Max Surface Pressure: 7,024 psi Max BH Pressure: 7,614 psi Average Rate: 23.8 bpm Average Missile Pressure: 6,241 psi Average Surface Pressure: 6,196 psi Average BH Pressure: 5,293 psi Average Missile HHP: 3,641 hhp Initial CA Pressure: 528 psi Max CA Pressure: 542 psi Max Proppant Concentration: 6.14 PP9 Average Visc: 24.6 cp Average Temp: 88 F Average pH: 9.62 Propparn Summary Wanli 20/40 Pumped: 97,303 lbs Total Proppant Pumped* : 97,303 lbs Proppant in Formation: 97,303 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 43,989 gal 1,047 bbis #30 WaterFrac G Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Pad Volume: 15,049 gal 358 bbis Proppant Laden Fluid Volume: 27,752 gal 661 bbis Spacer and Ball drop Volume: 1,188 gal 28 bbls Interval Status: Completed Comments: Pumped as designed no pumps issue. Engineer Jean Goueth Treater Joshua Caprio Supervisor Joshua Caprio for proppant are taken front software calculations based on multiple variables. Customer Engineer Scott Pessetto Proppart is billed off of weight UGket volumes and may vary slightly from this number Customer Rep: Paul Bessefte Conoco Phillips Alaska - 2M-40 Interval Summary 17 2M-40 - I -Sand - Interval 10 Interval Summary Start Dateffinfe: 9/24/19 17:35 End Date/Time: 9124/19 18:25 Pump Time: 50 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 6,479 psi Initial BH Pressure (Breakdown): 7,598 psi Max Rate: 26.8 bpm Max Surface Pressure: 7,168 psi Max BH Pressure: 7,262 psi Average Rate: 22.9 biont Average Missile Pressure: 6,325 psi Average Surface Pressure: 6,278 psi Average BH Pressure: 5,507 psi Average Missile HHP: 3,542 hhp Initial CA Pressure: 532 psi Max CA Pressure: 541 psi Max Proppant Concentration: 6.25 Ppg Average Visc: 29.4 cp Average Temp: 87.6 F Average pH: 9.6 ISIP: 3466 psi Initial Fracture Gradient: 0.565 psilft Proppant Summary Wanli 20/40 Pumped: 101,869 lbs Total Proppant Pumped* : 101,869 lbs Proppant in Formation: 101,669 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 43,363 gal 1,032 libis #30 WaterFrac G Volume: 5,576 gal 133 bills Freeze Protect Volume: 1,393 gal 33 tribis Fluid Summary (by stage description) Pad Volume: 15,095 gal 359 bbls Proppant Laden Fluid Volume: 28,268 gal 673 bbls Flush Volume: 5,576 gal 133 bbis Freeze Protect Volume: 1,393 gal 33 bbis Imentai Status: Completed Comments: Pumped as designed no pumps I ssue Engineer Jean Goueth Tireater. Joshua Caprio Supervisor Joshua Caprio Values for propicant are taken from software calculations ba,,,J 11 rill � ln 1! Customer Engineer Scott Pessetto Prol is billed off of weight ticket volumes and may vary E51 � I Customer Rep. Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 18 21111 - C -Sand - Interval 11 Interval Summary Start Date/Time: 9/26/19 9:33 End Date/Time: 9/26119 10:46 Pump Time: 73 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 6394 psi Initial BH Pressure (Breakdown): 7154 psi Max Rate: 25.2 bpm Max Surface Pressure� 6,955 psi Max BH Pressure: 5,123 psi Average Rate: 20.0 bpm Average Missile Pressure: 5,314 psi Average Surface Pressure: 5,291 psi Average BH Pressure: 4,887 psi Average Missile HHP: 2,609 hhp Initial CA Pressure: 136 psi Max CA Pressure: 136 psi Max Proppant Concentration: 6.26 ppg Average Visc: 27 cp Average Temp: 89.9 F Average pH: 9.49 Proppant Summary Wanli 20140 Pumped: 96,702 Ibis Total Proppant Punl : 96,702 lbs Proppant in Formation: 96,702 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 46,781 gal 1,114 bbis #30 WaterFrac G Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Pad Volume: 15,007 gal 357 bbis Proppant Laden Fluid Volume: 27,480 gal 654 bbis Spacer and Ball drop Volume: 1,049 gal 25 bbis Interval Status: Completed Comments: Dropped rate as pressure trended upwards during the higher proppant concentrations. Proppant Engineer Keegan Lambe pumped to design. Theater Joshua Capric, Superhasor. Chad Burkett 'Values for Poppaut are taken from software caiculations based on moil variables Customer Engineer Adam Klem Proppan, is tilted off of weight ticket volumes and may vary slightly from ths number CustomerRep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 19 Start DaterTime: 9/26/19 11:54 End DatefTime: 9/26119 12:49 Pump Time: 55 min Initial Rate (Breakdom): 12.3 bpm Initial Surface Pressure (Breakdom): 6205 psi Initial BIH Pressure (Breakdovil 6806 psi Max Rate: 25.2 bpm Max Surface Pressure: 6,906 psi Max BH Pressure: 4,965 psi Average Rate: 22.2 bpm Average Missile Pressure: 5,346 psi Average Surface Pressure: 5,321 psi Average BIH Pressure: 4,666 psi Average Missile HHP: 2,910 hhp Initial CA Pressure: 461 psi Max CA Pressure: 492 psi Max Proppant Concentration: 6.42 pp9 Average Visc: 27 cp Average Temp: 90.4 F Average pH: 9.53 Proppant Summary Wanli 20140 Pumped: 97,173 lbs Total Proppant Punrl : 97,173 lbs Proppant in Formation: 97,173 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gai 0 bbis #30 HyborG Volume: 43,291 gal 1,031 bb1s #30 WaterFrac G Volume: 6,180 gal 147 bbis Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 13,354 gal 318 bbls Proppant Laden Fluid Volume: 27,708 gal 660 bills Spacer Volume: 6,180 gal 147 bola Spacer and Ball drop Volume: 736 gal 18 bbis Interval Status: Completed After Seating the ball had to comeoffline, due to a leak in the Chicksan. Flushed the wall with linear Engineer. Keegan Lambe to prevent gelling off the well. One of the pumps had something pass through resulting in a rate Theater Joshua Capho dip. Supervisor Chad Burkett 'Values for Proppant are taken from software miculations based on multiple v.p.bl.s Customer Engineer. Adam KJerh Proppant is billed off of weight ticket volumes and may vary sliginfly from this number I Customer Rep: Paul Bessette Conoco Phillips Alaska - 21V-40 Interval Summary 20 Interval Status: Completed for PToppant are taken from software calcriations based oil Iniftiple variables t is billed off of werght ticket volumes and may vary slightly from this number Treater Joshua Capno Supervisor Chad Burkett Customer Engineer Adam Klern Customer Rex Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 21 interval Summary Start Datel-l-ime: 9/26119 12:49 End DatetTime: 9126119 13:39 Pump Time: 50 min Initial Rate (Breakdown): 10.1 blim Initial Surface Pressure (Breakdown): 6213 psi Initial BH Pressure (Breakdown): 7055 psi Max Rate: 25.2 bpm Max Surface Pressure: 6,927 psi Max Bld Pressure: 5,405 psi Average Rate: 23.3 bpm Average Missile Pressure: 5,662 psi Average Surface Pressure: 5,639 psi Average BH Pressure: 4,765 psi Average Missile HHP: 3,227 hhp Initial CA Pressure: 490 psi Max CA Pressure: 519 psi Max Proppant Concentration: 6.31 ppg Average Visc: 27 CP Average Tell 91.69 F Average pH: 9.55 Proppant Summary Wanli 20140 Pumped: 100,063 lbs Total Proppant Pumped" : 100,063 lbs Proppant in Formation: 100,063 lbs Fluid Summary (by I'luid description) Sea Water Volume: 0 gal 0 blits #30 HyborG Volume: 43,911 gal 1,046 bbls #30 WaterFrac G Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 blils; Fluid Summary (by stage description) Pad Volume: 15,014 gal 357 bbis Proppant Laden Fluid Volume: 28,112 gal 669 bbls Spacer and Ball drop Volume: 785 gal 19 bbis Interval Status: Completed for PToppant are taken from software calcriations based oil Iniftiple variables t is billed off of werght ticket volumes and may vary slightly from this number Treater Joshua Capno Supervisor Chad Burkett Customer Engineer Adam Klern Customer Rex Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 21 2111,140 - C -Sand - Interval 14 Interval Summary Start Date/Time: 9/26119 13:39 End Daterrime: 9/26/19 14:28 Pump Time: 49 min Initial Rate (Breakdom): 12.0 bpm Initial Surface Pressure (Breakdom): 6350 psi Initial BH Pressure (Breakdoi 6857 psi Max Rate: 25.5 bpm Max Surface Pressure: 6,973 psi Max BH Pressure: 5,265 psi Average Rate: 23.2 bpm Average Missile Pressure: 6,030 psi Average Surface Pressure: 5,908 psi Average BH Pressure: 5,031 psi Average Missile HHP: 3,432 hhp, Initial CA Pressure: 517 psi Max CA Pressure: 527 psi Max Proppant Concentration: 6.35 pP9 Average Visc: 27 cp Average Teri 91.5 F Average pH: 9.59 PiroppantSummary, Wanli 20/40 Pumped: 98,979 lbs Total Proppant Purri : 98,979 lbs Proppant in Formation: 98,979 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 44,284 gal 1,054 bbis #30 WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bb1s Fluid Summary (by stage description) Pad Volume: 15,027 gal 358 bbls Proppant Laden Fluid Volume: 28,118 gal 669 bbis Spacer and Ball drop Volume: 1,139 gal 27 bbis Interval Status: Completed Comments: Pumps had internal issues. Proppant placed to design. Engineer Keegan Lambe Tineater. Joshua Caprio Supervisor. Chad Burkett -values for proppant are taken from sogware, cailctilations based oil multiple variables Customer Engineer. Adam Klem Proppant is billed off of weight ticket volumes and may vary slightly from this number CustomerRep: Paul Bessette Conoco Phillips Alaska - 2M-40 Interval Summary 22 2M.40 - C -Sand - Interval 15 Interval Summary Start Date/Time: 9/26/19 14:28 End Daterl-ime: 9126/19 15:20 Pump Time: 52 min Initial Rate (Breakdom): 11.9 bpm Initial Surface Pressure (Breakdom): 6601 psi Initial BH Pressure (Breakdom): 7178 psi Max Rate: 25.0 bpm Max Surface Pressure: 7,213 psi Max BH Pressure: 4,998 psi Average Rate: 23.7 bpm Average Missile Pressure: 6,019 psi Average Surface Pressure: 5,999 psi Average BH Pressure: 4,867 psi Average Missile HHP: 3,489 hhp Initial CA Pressure: 523 psi Max CA Pressure: 532 psi Max Proppant Concentration: 6.47 ppg Average Visc: 26 CP Average Temp: 91.2 F Average pH: 9.55 ISDP: 4676 psi Final Fracture Gradient: 0.767 psilft Final 5 min: 4451 psi Final 10 min: 4373 psi Final 15 min: 4324 psi Proppant Summary Wanli 20/40 Pumped: 117,179 lbs Total Proppant Pumpecl* : 117,179 lbs Proppant in Formation: 117,179 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #30 HyborG Volume: 45,618 gal 1,086 bbls #30 WaterFrac G Volume: 3,961 gal 94 bills Freeze Protect Volume: 1,500 gal 36 bbis Fluid Summary (by stage description) Pad Volume: 15,014 gal 357 bbis Proppant Laden Fluid Volume: 30,604 gal 729 bbis Flush Volume: 3,961 gal 94 bbls Freeze Protect Volume: 1,500 gal 36 bbls Interval Status: Completed Comments: Proppantjaurnped to design. Flush vvias completed using LVT. Engineer- Keegan Lambe Treater. Joshua Capho Supervisor Chad Burkett values for proppamare taken from software .1culailom, based on multiple variables Customer Engineer Adam Klem Prappant is thilled off of weigh[ ticket volumes and may vary slightly from this number CustomerRep: Paul Bessefte Conoco Phillips Alaska - 2M-40 Interval Summary 23 �Rsdxdxser Cmom Phillips Alaslas IdIrl C land Lease 2.'t. API wt. �Rsgxl Date Septerl WOR.-spe, Ir,- I-ItIl HALLIBURTON Pla-d pe,orded - - pr,:PpRrvF is bilhad find. .4M Titket -lu..a �Fsoco Phillip AlaslRa - 21040 Fluid Ssterp-Proppant Summary Fluids Prop ants hall passage Max #30 Hpb.. M..1-Irstti Ir,- I-ItIl Intel Ffi,nd ul M/4d Total Pnop,dant BITPnrl age Base slim Term PH BH Prdsdurd Rate .1 FRI '.1 Ig gal bb! Red bb! lbs !its 1 6OF2 23 ' 211 798 847 91 6426 28, w'soo 2A98 1711 231 102013 2A29 96,200 K2. 2 SIRD 24.3 30 M 9.2 WO&I V.9 71,10 11::4 7LW 116% 95,7.13 %'780 3 IF.d 249 28 85 � 4 .401 278 70817 1 6 70,917 � 686 lFl I(A.055 4 lill 213 16 91 9.4 SAWFZ 27.9 MM 1,675 7,B5 175 L."s 35 �jo' tan ll G220 2�,d 26 P, M. 2� � 77 23S 1,839 77r23S � R�� 1� 124 96 32,F 6 5767 25.2 27 90 9.7 `ss"2 29.1 72,139 %7. �139 1.718 1K.10 stPi'SID 7 547G 2��7 21 v 9 1 7F56 IR.6 42,23R F. s2,73R 1 ". R7,41F .7,45F 5350 2LR 31 M 9.7 SW 10.3 59,77: 7,928 Is" 6l J.6U Rl "'i" 52tF3 R 23 8 25 Sit 7614 27 2 43,�. �:173 .1 43,989 1,F47 97,303 97.�. 10 550 2�'. �S 88 9.6 720 26.9 43,30 11. 5,576 .1 1,393 33 SM32 "'In, 101,869 s01,869 it l8g7 2.� D so 91 5123 �S I 4Fr7Rs 1,114 s6,7" Ir'14 96,702 967.1 12 ARASS 22 '7 "' 9� 47 25.2 C3,291 L031 6,180 147 49,471 I'm 97,173 .71173 ls� 4765 2 '1 323 27 K g� 14tl 2 52 41,911 luus� 43,911 F'Cl lFull ll`.F.t� 14 5D31 23.2 27 92 9,6 1105 25,5 44,284 1:05`1 0,2U 1,04 98,979 still Is 4.7 1 231 26 1 91 96 4�. , 250, 'I'll F'..F 1,110 16 11,011 1,211 117,171 1 ' RAInfin- dM. Mind 3961 1393 11 41211 "'d .'d'F .741� A., 57816 U77 on m I'Vis U mw 14sti, =33 1:01121 nAl 923M 2t. 9713 2�1 ISM I.M3 14D 11717q IM79 Pla-d pe,orded - - pr,:PpRrvF is bilhad find. .4M Titket -lu..a �Fsoco Phillip AlaslRa - 21040 Fluid Ssterp-Proppant Summary Pressure Test - Day I 9;2112'0'19 1 .. .- . I. .— W21/2019 Time Global Event Log Pressure -Test 11:07:20 Pressure Test Q 9500 psi 11:14:53 Pressure Test §9500 psi for 5 min 11:19:38 Good Test bleed down 11 20:02 O.stomer: CONOCOR-ILLIPS NORTH SLOPE - EBUS I Job Date: 20 -Sep -2019 Well DescCiption: 2M 40 LW: 50-10�20804 �n.�. Philli, Al.�lo - 2M40 InWrv.1 I PIOU 25 Test - Prejob Test �Pl lm� Incil � I'l C;lnh, I PI Kickout Pressure (psi) - Ball Drop Pressure (psi) 11:30 11 35 11AU -1 1:40 912112019 Time �112019 Customer: CONOCO t-ILLIPS SLOPE- EB 6 1 Job Ita: 20 -Sep -20119 Sales Order # 0905963800 Wall Description: 2M 40 LW 50-103-20804 Will, AI.,k. � 2M40 lnte�al I Ploo, A 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 Blender Chemical Plot - Bucket Tests Day 1 CFL -31 Cone 'g8"Mga" A CL-22UCConc(gal/Mgal)— A MO -67 Cone (galfMgal)— A El Optiflo-11 Cone (lb/Mgal)— 8 B _iOl�t,fl,_jllC,nI(lbIMg,l�— 2.5 -2.0 -1.5 -1.0 -0.5 10:37 10:38 10:39 10:40 10:41 10:42 10.43 912IJ2019 Time W2112019 PHILLIPS NORTH SLOPE- EBUS I =�We: 20 -Sep -2019 I Sales Order#: 090 50-103-20804 Conow Phillips Alaska - 2M40 Ints.1 I Plots 27 ADP Chemical Plot - Bucket Tests Cust�r: GONOGOPHLLFS �RTH �LU�- Job Date: 20 -Sep -2019 Sales Order#. 0905963800 MjjDescnF3fnn: 2M40 - LW: 50-103-20804 �n.. Phflll� Al�.� - 2M40 Me"al 1 PIO" Treatment Plot - Minifrac A B ISlurry Proppent Conc lblgal� - C BH Proppant Conc (lb/gal) C Gauge BH Pres (psi) A Actual BH Temp ff) — DI C lime ONOCOPHILLIPS NORTH SLOPE - EBUS I Lb )ate: 2,0LSeP-2019 I S.I.. Order #- 0905963800 =ription: 2CM40 5�103�20804 Carom Phillip Alaska - 2M40 lmr�.I I Mists D 75 50 25 00 Blender Chemical Plot - Minifrac CL -31 Co - (gal/Mgal) — A CL -22 UC c (gaVMgal) — A MO -67 Cone (gal/Mgal) — A A optiflo-111 one (lb/Mgal) — B Optiflo-11 Cone (lb/Mgal) — B I Ime -FJ COPFILLIPS NORTH SLOPE - EBLK Tb EWW. 20 -Sep -2019 Sales Order#: 0907n =notion: = LW, 5"103�20804 1 ConowPhdfipsAlas" 2M� InW�.I I PI.0 ADP Chemical Plot - M inifrac �112019 Time Custorner: W��ILLS� l�M I M 0-- 50_10�20804 \Nell Description: 2M 40 Car� Phillip Alaska - 2M,40 lnter�al I Plot$ Halliburton Pumping Diagnostic Analysis Minifrac - G Function — Gauge BH Pres (Psi) A — Smoothed Pressure (psi) A Closure 1.60 4145 4147 710.3 457T74] D Toolkit G(nnne) Oustorl CONOOOPHILLIPS NORTH bl-U�- USU, Job Date: 20-SeP-2019 Sales Order #: 09059638 0 wsk! Description: 2M 40 JIM 50-103-20804 32 ot,�o PhillipsAll - 2M40 lotel,al I Plots A 100 Treatment Plot - Interval 01 Treating Pressure (psi) Slurry Proppant Conic (lb1gal) — C BH Proppant Conic (Iblgal) B GauaeBHpms(,)si)— A Actual BHTemp('F)— C1 C D 13:00 13:20 13:40 14:00 14:ZU 9121=19 Time W2112019 CCus�t.—C�ONKO=O�ILLIPS �NORTH SLOPE - �EBLJS �JbD�.W: 20-SeP-2011 Sales, Order #: 0905963800 MU Disseniption: 2M 40 1 UVIA: 50-103-20804 1 D 75 �now Phillip Alas" - 2M� lnte�al 1 Plats 33 Blender Chemical Plot - Interval 01 I CL-31�Conc (gal/Mgal) A CL-22UC ne(gal/Mgal)— 7 Cone (gal/Mgal) — A A ot'll III Cone (ib/Mgal) B Optiflo-11 Cone (lb/Mgal) — B 9121iiM Time rr CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 20 -Sep -2019 I Sales Order#: 0905963800 Wso'Zeription: 2M40 LW: 50-103�208134 Gar� Phillips Alas" - 2M40 lnt...l I Plts 34 ADP Chemical Plot - Interval 01 A gal) B W21.1. Time &T,-t,�.CONOCOPHI-LIPS NORTH SLOPE- EBUS Job Date: 20 -Sep -2019 Well O�scription: 2M 40 1 W. 50-103-20804 Conoco Phillips Alas" - 2M-40 Intemal 1 Plots A 1001 Treatment Plot - Interval 02 Treating Pressure (psi) A Slung Rate (bpm) B Slung Proppant Cone (lb/gal) C BH Proppant Cone (lb/gal) C B Gauae BH Pres (psi) A Actual BH Temp ('Fj D C D 9I2112019_ --- 912112019 Time Well D sCONOCOFHLLIPS NORTH SLOPE- EBLIS .bb Date: 20 -Sep -2079 Sales Order #: 0905983800 Well ecriPtbn: 2M 40 UM: 50-I03-20804 50 25 Conoco Phillips Alaska -2Mi0 Interval 2 Plots 37 Blender Chemical Plot - Interval 02 A 1.6- 1.4- 1.2- 1.0- 0.8- 0.6- 0.4- 0.2- CL -31 Conc (gal/Mgal) A CL -22 UC Cone (gal/Mgap — A MO -67 Cone (gal/Mgal) A Optiflo-lll Conc (Ib/Mgal) B Optiflo-ll Conc (Ib/Mgal) B IL 0.0 --r 14:20 1440 15:00 15.20 15:40 9/21/2019 9121/2019 Time Custaner: CONOCOPFALLIPS NORTH SLOPE- EBt1S ,bb Date::Sep-2019 Sales Order #: 0905963800 '-"' Well Description: 2M40 lhM: 50-10320804 B ?.5 2.0 1.5 1.0 0.5 wo Conoco Phillips Alaska -2M-40 Inteml2 Plotz 38 ADP Chemical Plot - Interval 02 (Ib/Mgal) B 9i2iizai9- Time Customer. CONOCOPHILLIPS NORTH SLOPE- FBUS Job Oete: 245ep-2019 Sales Order 8: 0905963800 "-"�' We0 Description: 2M40 IAM: 5040320804 Canaca Phillips Alaska- 2M40 Imerval 2 Plots 59 Net Pressure Plot- Interval 02 Net Gauge BH Pres (psi) A RH Prnnnant Cnnc !16/oan B B I Time (min) Custoaer: CONOCOPHILLIPS NORTH SLOF£-SUS Job Date: 20 -Sep -20 I Sales Order M: 0905963800 ""'"-" Well Description: 2M 40 UM: 50-103-20804 Con.. Phillips Alaska - 2Md0 Ioteml2 Plots A 100( 1 Treatment Plot - Interval 03 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conic (Ib/gal) C BH Proppant Conc (lb/gal) B Gauoe BH Pres (psi) A Actual BH Temp (`Fi— C D I C D W21IM19 Time 8121/2019 Custarer: CONOOOPHILLIPS NORTH SLOPE- FBUS I .bb Dete: 20 -Sep -2019 I Saks Order M: 0905983800 Well Description: 2M 40 UM: 50-103-20804 75 Con000 Phillips Alaska - 2M-40 Inteml3 Plots 41 Blender Chemical Plot - Interval 03 enc (gallMgal) A CL -22 UC Conc (gaUMgal) — A M067 Conc (gal/Mgal) A B n .(g l/Mgal) a Ootiflo-11 Conc (Ib/Mgal) B Well De criptbn: 2M40 I MM: 50-10320804 Conosa Phillips Alaska - 2M-40 Interval 3 Plots 42 ADP Chemical Plot - Interval 03 t n�rt_arutn Onnc laal/Maall A WG -36 Conc (16/Mgap B B RY11261e Time Customer. CONOCOPHILLPS NORTH SLOPE- EBl1S Job Date: 20 -Sep -2019 We0 Description: 2M40 I INN: 50-10320804 Conoco Phillips Alaska - 2M40 Interval 3 Plots 43 Net Pressure Plot - Interval 03 — Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B B Time (min) Customso CONOCAPFILLWB NORTH SLOF£- B311S Job Gate: 20 -Sap -2019 Saks Order N: 0905983800 Well Description: 2M 40 IPM: 50-103-2(1804 Conoco Phillips Alaska - 3M40 InWml3 MU 44 Treatment Plot - Interval 04 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conic (Ib/gap C BH Proppant Conic (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp ("F) — C D 9 175 150 125 100 lime Custorrer: CONCCOPHILLIPS NORTH SLOPE- EBUS I =Date: 20-Sep2019 Sales Order #: 0905963800 Well Description: 2M 40 IPM: 50.10&20804 Conoco Phillips Ales" .2M.0 Intervsl4 Plots 45 Blender Chemical Plot - Interval 04 CL -31 Conc (gal/Mgaq A CL -22 UC Conc (gal/Mgap — A M0-67 Conc (gal/Mgal) A Optiflo-III Conc (Ib/Mgal) B Optiflo-II Conc (Ib/Mgal) B B 2.5 2.0 1.5 1.0 0.5 0.0 0.0 16:50 17:00 17:10 17:20 17:30 17:40 17:50 18:00 18:10 anv2019 9Y21Y1019 Time Custoner. DONOOOPHILLIPS NORTH SLOPE- ®LIS .bb Date: 20 -Sep -2019 Sales Order #: 0905963800 CMU1 Description: 2M40 IMA: 50-10320804 Conoco Phillips Alaska -210-40 Interval4 Plots 46 ADP Chemical Plot - Interval 04 (Ib/M9al) B 921/2019 Time -------- Customerr CONOCOPHLLIPS NORTH SLOPE- ®L6 I Joti Dale: 24Sep-2079 I Sales Ortler Well Description: 2M40 Uj 50.10320804 Cnnaco Phillips Alaska -210-4 Interval Pbts 47 Net Pressure Plot - Interval 04 1:—N et Gauge BH Pres (psi) A A — BH Propoant Conc Ob/gap B B IU Time (min) Cuswrrer: CONOOOPHILLIPS NORTH SLOPE- EBUS Job Date: 20 -Sep -2019 Sales Order #: 0905983800 WeliDescription: 2M40 UM: 50-103.20804 Conga Phillips Alaska - 21%4d0 Inteml4 Plots 48 It Global Kickout Pressure Test- Day 2 P1 Kickout Pressure (psi) 9/24/2x19 9/24/2019 Time Global Event Log Pressure Test - Globals 09:36:50 0 Pressure Test -Locals 09:37:48 Q Pressure Test -Locals 09:38:38 0 Pressure Test@ 9,500 psi 094232 7 Pressure Test After 4 min CusL called good 09:45:53 Custoner: CONOWPHILLIPS NORTH SLOPE- EBUS .bb Date: 24 -Sep -2019 Saks Order k 0905963800 Well Desoriptlon: 2M 40 INN: 50-103-20804 Conoco Phillips Alaska -2M40 Inteml5 Plots 49 Blender Chemical Plot - Bucket Tests Day 2 CL -31 Conc (gal/Mgal) A CL -22 UC Conc (gal/Mgap - A MO -67 Conc (gal/Mgal) A Optiflo-III Conc (Ib/Mgal) B Optiflo-II Conc (Ib/Mgal) B 0.0 07:35 07:40 07:45 07:50 07:55 anazola enazol9 Time Custorrer: CONOCOPHILLIPS NORTH SLOPE- ®L6 Job Date: 24 -Sep -2019 Sales Order* 0905983800 Nall Description: 2M40 IIWi 50-103-20804 B 2.5 M 1.5 We 0.5 am Conoco Phillips Alaska -2M40 Inteml5 Plotz 50 0.0 07:35 07:40 07:45 07:50 07:55 anazola enazol9 Time Custorrer: CONOCOPHILLIPS NORTH SLOPE- ®L6 Job Date: 24 -Sep -2019 Sales Order* 0905983800 Nall Description: 2M40 IIWi 50-103-20804 B 2.5 M 1.5 We 0.5 am Conoco Phillips Alaska -2M40 Inteml5 Plotz 50 ADP Chemical Plot -Bucket Tests Day 2 A I Losurf3001D Cone (gal/Mgal)A WG -36 Cone (Ib/Mgal) B B I Ime Custoner: CONOCOPHILLFS NORTH SLOPE- ®U$ Job Date: 24Sep�2019 I Sales Order #: 0905983800 Well Description: 2M 40 IMA: 54103-20804 Conow Phillips Alaska-2MA Inter l5 Plats Treatment Plot - Interval 05 Sluny Proppant Conc (ib/gal) C BH Proppant Conc (Ib/gal) C Gauge BH Pres (psi) A Actual BH Temp ('F) D C D lime Customer: CONOCORALLIPS NORTH SLOPE- EBBS =Date: 524- 94 Sales Order #: 0905963800 WeA Description: 2M40 IAM: 50-10320804 Conoco Phillips Alaska - 21010 Intery l5 Plots 75 Blender Chemical Plot - Interval 05 A 1.6- 1.4 1.2- 1.0- 0.8- 0.6- 0.4- 0.2 - CL -31 Conc (gal/Mgal)A CL -22 UC Conc (gal/Mgal)- A MO -67 Cone (gal/Mgal) A Optiflo-lll Conc (Ib/Mgal) S Optiflo-II Conc (Ib/Mgal) B FT V • • • • • • • M B -2.5 -2.0 -1.5 -1.0 0.5 0.0 0.0 10:00 10:20 10:40 11:00 11:20 11:40 911412019 9124/2019 Time Customer: CONOOOPHILUPS NORTH SLOPE- EBUS I ob Date: 24 -Sep -2019 I Sales Order p: 0905963800 Well Descriptim: 2M40 tPM: 50-103-20804 Conoco Phfilips Alaska - 2M40 lotemal5 Plotz 53 A 2. 1. 1. 1. 1. 1. 0. 0. 0. 0.2 0.0 ADP Chemical Plot - Interval 05 Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgap g 0 8 6 4 2 0 8 6 4 • 10:00 9124)2019 Well Description: 2M 40 1020 10:40 11:00 Time 'S NORTH SLOPE- ®US I .bb Date: 24 -Sep -2019 LNA: 50-103-20804 B 100 90 80 70 60 50 40 30 20 10 0 11:20 11:40 a2aza19 Conoco Phillips Alaska- 210-40 1nterval5 Plots 54 Net Pressure Plot- Interval 05 — Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib /gal) B Time (min) Customer. CONOOOPHILLIPS NORM SLOPE- EBLkS Job Date: 24 -Sep -2079 Sales Order M 0905983800 Well Description: 2M40 I LMA: 50.103_20804 0.703-20804 Conoco Phillips Alaska .2M40 Interval5 Plota Treatment Plot - Interval 06 Treating Pressure (psi)A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gap C A B Gauge BH Pres (psi) A Actual BH Temp ("Fl D C ume CLstorrer: CONOOOPMLLIPS NORTH SLOPE- EBt1S Job Date: 2a-Sep-2019Sales Order M: 0905983900 WBII Description: 21040 INN: 50-10&20804 Conoco Phillips Alaska - 2M40 Intarval6 Plots D 175 50 94 A 1.E 1. 0. 0. 0. 0. 0. 12:50 13:00 9124=19 Blender Chemical Plot - Interval 06 CL -31 Conc (gal/Mgal) A CL -22 UC Conc (gal/Mgap A M0-67 Conc (gal/Mgal) A Optiflo-III Conc (Ib/Mgal) B Optiflo4i Conc (Ib/Mgal) 8 0 8 6 4 2 0 9 0 0 9 M WeY Description: 2M40 13:10 13:20 13:30 Time IRTH SLOPE- EBUS Job Date: 24-Sep�2019 LAM: 50-103-20804 13:40 13:50 912dI2019 les Order#: 0905963800 B ?.5 Zi7 1.5 1.0 0.5 iP Conoco Phillips AlasW -2M40 Interval6 Pbts 57 ADP Chemical Plot -Interval 06 I nsuA-amo Cnnc foal/Maall A WG -36 Conc (Ib/Mgal) 6 Glslon : t.UMUI:UFMLi-" M I n Jwrz- mw .uv w.c. arwr�-� We0 Description: 2M 40 lNd: 50-10&20804 Conow Phillips Alaska - 2M40 Interva16 Plots Net Pressure Plot- Interval 06 — Net Gauge BH Pres (psi) A A — BH Pronnant Conc (Ib/oal) B 8 Time (min) Custoner: CONOCOPHLUPS NORTH SLOPE- ESUS I Job D.24-Sep�2019 Sales OPAer #: 0905963800 "'"�'�' WellDescription: 2M40 IPM: 50-10320804 Conoco Phillips Alaska- 2M-40 Inte,al6 Plots A 1001 r Treatment Plot - Interval 07 Slurry Proppant Conc (Ib/gal) C BH Proppant Conic (Ib/gal) C B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D " "" Time 0905983800 1 ""'-'-"' Well Description: 2M 40 1 INN: 50-103-20804 Conoco Phillips Alaska - 2M40 Interval 7 Plots W Blender Chemical Plot - Interval 07 CL -31 Cone(gal/Mgap A CL -22 UC one (gal/Mgal) — A MO -67 Cone (gal/Mgal) A A Optiflo-Ill Cono (Ib/ l B Optiflo-II Cone (Ib/Mgal) B Sii4i: to . .. _ _ - -. - _ 9/2412018 Time Custoner: CONN000PI-IILUPS NORTH SLOPE- EBUS Job S0- 0320804 Sales Order N: 0905963800 Conan Phillips Alaska -2M40 Interval? Plots 61 ADP Chemical Plot - Interval 07 A I Losurf-300D Cone (gal/Mgal) A WG -36 Cone (Ib/Mgal) B B 14:00 14:10 14:20 14:30 14:40 9/2412019 91242(119 Time Custorrar: CONOOOPHILLIPS NORTH SLOPE- EBUS I =Dale: 24 -Sep -2b19 Sales Order #: 0905963800 Well Description: 21,140 LM7: 50-70&20804 ConO Phillips Alaska -2M-40 Interval?%o6 Net Pressure Plot - Interval 07 NetGauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B TV Time (min) Customs: CONOCOPHILLIPS NORTH SLOPE- EBUS I JobDate: 24 -Sep -2019 Saks Order #: 0905963800 Well Description: 2M 40 LAM: 50-103-20804 Conom Phillips Alaska - 2M-40 Interval 7 Plots 63 Treatment Plot - Interval 08 Sluts Proppant Conic (lb/gal) C BH Proppant Cono (IWgal) C A B Gauge BH Pres (psi) A Actual BH Temp ("F) D C D 924/2019 - - - 9/2112019 Time Custoner: CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 24 -Sep -2019 Sales Order 4: 0905963800 Wetl Description: 2M40 Lmt 50-10320804 Conoco Phillips Alaska -2Md0 Inleml8 Plots 84 Blender Chemical Plot - Interval 08 CL -31 Conc (gal/Mgap A CL -22 UC Conc (gal/Mgap — A M0-67 Conc (gal/Mgal) A A Optiflo-III Conc (ib/Mgap B Optiflo-ll Conc (Ib/Mgal) B 9;2V2019 912412019 Time Ostomr: CONOCOPHILLIPS NORTH SLOPE- EBUS I JObDate: 20 -4 -Sep -2081M 04 Qp-20019 I Sales Order * 0905963800 Well Description: 2M 40 Co wco Phillips Alaska - 2M40 Interval 8 Plots A 2.0- 1.8- 1.6- 1.4- 1.2- 1.0 0.8 0.6 0.4 0.2 0.0 ADP Chemical Plot - Interval 08 A WG-36Ccnc(Ib1Mca1) B Well 15:00 15:20 15:40 16:00 9242019 Time 2M 40 I UW: Conoco Phillips Alaska - 2M -da Interval 8 PIo4 16:20 11i:4U 91242018 Sales Order #: 0905963800 B 100 90 80 70 60 50 40 30 20 10 -0 0000 0 0 40 00 Well 15:00 15:20 15:40 16:00 9242019 Time 2M 40 I UW: Conoco Phillips Alaska - 2M -da Interval 8 PIo4 16:20 11i:4U 91242018 Sales Order #: 0905963800 B 100 90 80 70 60 50 40 30 20 10 -0 Net Pressure Plot - Interval 08 Net Gauge BH Pres (psi) A A — AH Proouant Conc (Ib/aal) 13 B M Time (min) Custotrer: CONOCOPFiLL�S NORTH SLOPE- 63115 Job Date: 24 -Sep -2019 Sales Order M 0905983800 Well Description: 2M40 LW: 50-103-20804 Conoco Phillips Alaska.2Mia Interval Plots Treatment Plot - Interval 09 Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gaupe BH Pres (psi) A Actual BH Temp ('F) D C D J 175 150 125 100 "" "" Time Customer: CONOCOPHILLIPS NORTH SLOPE- €BUS I Job Gate: 24-Sep-2ul s Well De criptlon: 2M 40 LRM: 50-103-20804 Order A: 0905963800 1 - Conoco Phillips Alaska -1M-40 Interval 9 Plats 68 Blender Chemical Plot - Interval 09 CL-31lflo-Conc (gal/Mgal) A CL -22 UC Cone (gal/Mgal)— A MO -67 Cone (gal/Mgal) A A Optlll Cone (Ib/Mgal) B Optiflo-II Cone (Ib/Mgal) B 9/241W19 924/2019 Time Customer CONOCOPHILLIPS NORTH SLOPE -BLS .bb [Date: 24 -Sep 09 Sales Ortlef p: 09059fi3800 Well Description: 2M 40 INA: 50.10320804 Conan Phillips Alaska - 2M40 Interval 9 Plots 69 ADP Chemical Plot - Interval 09 A Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgal) B B W2V2019 8124/2019 Time Cus[orrer: CANOCOPHILLIPS NORTH SLOPE- FBUS I Job Date: 245ep-2019 Sales Order M: 0905963800 Well Description: 2M 40 LW: 50-10&20804 Comm Phillips Alaska - 2M40 Interval 9 Plots 70 Net Pressure Plot- Interval 09 Net Gauge BH Pres ) A A — BH Proppant Conc (Ib/g(psial) B B Time (min) Custorrer: CONOCOPHILLIPS NORTH SLOPE- BBUS Job Date: 24Sep-2019 Sales Order M: 0905963800 Well Description: 2M40 LAM: 50-103-20804 Cunoco Phillips Alaska -2M-00 IMeml9 Plots 71 A 1001 i Treatment Plot - Interval 10 Slurry Proppant Conc (Ib/gap C BH Proppent Conc (Ib/gap C 8 Gauge BH Pres (psi) A Actual BH Temp ff) D I C D &24/2019 _ 9/2a2019 Time Cus[orrer: CONOCOPHILLIPS NORTH SLOPE- PBUS Job r: 24 -Sep -2019 Sales Order #: 09059fi3a00 Well Description: 21040 lNt•1: 50-70320804 75 Conoco Phillips Minh - 2M40 Irter al 10 Plots 72 Blender Chemical Plot - Interval 10 CL -31 Conc (gal/Mgal) A CL -22 UC Conc (gal/Mgal) — A Ivlt f wnc (gaurvigap r A nntifln-Ill Cnnn (Ih/Maall B ODliflo-II Conc (Ib/Mgap B I B wea�o,a Time Castwer: OONOCOPHILLIPS NORTH SLOPE- ®US .lob Date: 24 -Sep -2019 Well Desonption: 2M40 I LAM: 50-103-20804 condo Phillips Alaska - ]Mi Interval 10 Plots J3 ADP Chemical Plot -Interval 10 A I Losurf-3000, Conc (oal/1) A WG -36 Cone (Ib/Mgal) 6 B 9/24/2019 Time y�w�V 19 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 24Sep-2019 Well Description: 2M40 LW: 50-10&20804 CArow Phillips Alaska - 2M-00 Interval 10 Plots Net Pressure Plot -Interval 10 Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B lu Tme (min) Customer CONOCOPFILLIPS NORTH SLOPE- PBUS Job Date: 24 -Sep -2019 Sales Order*. 0905963800 Wag Description: 2M 40 1 IMA: 50-103-20804 Conoco Phillips Alaska - 2M-40 Interval 10 Plats 75 Pressure Test - 3 111 Global KICkoUt Pressure (psi) Pi Kickout Pressure (psi) .1—... Time Cus[orrer: CONOCOR-0LLIPS NORTH SLOPE- ®I1S Job Date: 26 Sep -2019 Sales Order k: 0905963800 Well Description: 2M40 IMA: 50-10&20804 Conoco Phillips Alaska - 3M40 Interval 11 Plots 76 Pressure Test-Globals 08:55:01 0 Pressure Test -Locals 08:55:40 06 Pressure Test - Max Pressure 09:00:16 07 Bump Trucks 090223 ❑8 Smell weep hole on pump 09:05:43 ❑9 Bleed off to swap Chicksan 09:07:04 Pump Repaired 09:18:01 11 PressureTest 09:19:38 -A Pressure Test -Max 09:22:30 FIN Good Test 09:26:58 Cus[orrer: CONOCOR-0LLIPS NORTH SLOPE- ®I1S Job Date: 26 Sep -2019 Sales Order k: 0905963800 Well Description: 2M40 IMA: 50-10&20804 Conoco Phillips Alaska - 3M40 Interval 11 Plots 76 0. 0.0 Blender Chemical Plot - Bucket Tests Day 3 Losorf-300D Conc (gal/Mgal) — A CL -22 UC Conc (gal/Mgal) — A MO -67 Cone (gal/Mgal) A OptiHo-lll Conc (Ib/Mgal) B Optiflo-ll Conc (Ib/Mgal) B 2 Cust.mar: 06:44 06:46 06:48 06:50 W� 10 Time CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 28-8eµ2079 2M40 I tNA: 50-10&20804 4. 1: yi B 2.5 2.0 1.5 M 3.5 0.0 06:56 9/2fi/2U19 Conom Phillips Alaska - 2Md Interval 11 Plw 77 Cust.mar: 06:44 06:46 06:48 06:50 W� 10 Time CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 28-8eµ2079 2M40 I tNA: 50-10&20804 4. 1: yi B 2.5 2.0 1.5 M 3.5 0.0 06:56 9/2fi/2U19 Conom Phillips Alaska - 2Md Interval 11 Plw 77 ADP Chemical Plot - Bucket Tests Day 3 A --l. Time D,etome : CONOCOPiILLIPS NORTH SLOPE- EBUS I Job Date: 26 -Sep -2019 V IDe cnplion: 21040 UK& 50-10320804 Conow Phillips Alaska - 3M40 Interval 11 Plats 78 A Treatment Plot - Interval 11 Slurry Proppant Cone (Ib/gal) r ..o au Pres rnci)— BH Proppant Cone (Ib/gal) Actual BH Temp ("F) — CD I C w`"""" Time Well Description: 2M 40 1 LM4: 50-103-20904 Conoco Philllps Alaska - 2M40 Interval 11 Plots D 75 Blender Chemical Plot - Interval 11 CL -31 Conc (gal/Mgal) A CL -22 UC Conc (gal/Mgal)— A MO -67 Cone (gal/Mgal) A A Ootiflo-III Conc (Ib/Meal) B Optiflo-ll Conc (Ib/Mgal) B B Coeto"r: Ilme CONOCOPHILLIPS NORTH SLOPE- FHUS Job Date: 26 -Sep -2019 I Selee Order #: 0905963800 2M 40 IMA: 50-103-20804 Conom Phllll, Alaska -2M30 Intewal 11 Plots ADP Chemical Plot - Interval 11 I n��n anon cone (oat/Moan A WG -36 Conc (Ib/Mgal) 6 ..cuts Time Custonnr: CONOCOPHILLIPS NORTH SLOPE- ®lA . 13 I.Bse: Well Description: 2M 40 IMA: 50-103-20804 Conoos Phillips Alaska- 21040 Interval 11 Plots Net Pressure Plot - Interval 11 — Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gap B Time (min) Customer. CONOCOPHILLIPS NORTH SLOPE-EBUS Job Dale: 26SeP-2019 Sales Orderrl: 0905983800 W.1 Description: 2M40 UWI: 50-10320804 Conoco Phillips Alaska -2MA0 Interval 11 Plots Pressure Test - Day 3 Part 2 h.,—I.— r lI h.l Ki,knuA Prncaure Insil P7 Kickout Pressure (psil 11:45 11:46 11:47 11:48 11:49 11:50 11:51 9125/2019 &ZBl2p'19 Time Global Event Log PressureTest 11:44:39 Customer: OONOOA ILLIPS NORTH SLOPE- EBUS I Job Date: 26 -Sap -2019 Sales Order M 0905963800 2M 40 INA: 50-103-20804 Conoco Phillips Ahska - 21010 Interval 12 Plots 85 Treatment Plot - Interval 12 A B ISlurry Prcppant Cone (Ib/gal) C BH Proppant Cone (lb/gal) C Gauge BH Pres (psi) A Actual BH Temp ('F) D C D ume Custorrer: OONOOOPHILLIPS NORTH SLOPE- ESUS Job Date: 26 -Sep -2019 Saks Order #: 0905983800 Well Description: 2M40 IMA: 50-W&20904 Conoco Phillips Alaska -2MA0 Interval 12 Plots A 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 Blender Chemical Plot - Interval 12 CL3t Conc (gal/Mgal) Optiflo-III Conc (Ib/Mgal) A B CL -22 UC Con c (gal/Mgal)— Optiflo-ll Conc (Ib/Mgal) A M067 Conc (gal/Mgap A B ( 12:00 WMM19 Well Description: 2M 40 1210 1220 12:3C Time 'S NORTH SLOPE- EHUS I Job Date: 26 -Sep -2019 LW: 50-10&20804 12:40 B !.5 R Ito ).5 0.0 12:50 WM2019 Conoco Phillips Alaska -2M40 Interval 12 Plots 85 ADP Chemical Plot - Interval 12 A I Losurf-300D Conc (aal/Maall A WG-% Conc (Ib/Mgal) 8 B Time Custorrer: CONOCORMLLIPS NORTH SLOPE- FBl1S Job Date: 26 -Sep -2019 Sales Order #: 0905983800 "—"' Well Description: 2M 40 LANA: 50-103-20804 Conoco Phillips Alaska -2M30 Interval 12 Plots 96 Net Pressure Plot - Interval 12 — Net Gauge BH Pres (psi) A A — BH Proppant Cone (IDlgal) B B I Time (min) Customer. CONOCOPHILLIPS NORTH SLOPE -EBUS I JODDate: 26 -Sep -2019 Sales Order#:0905983800 Well Description: 2M 40 DWI: 50-103-20804 Conoco Phillips Alaska -2M-00 Interval 12 Plots 87 A Treatment Plot - Interval 13 Slurry Proppant Cone (Ib/gal) R l4auae BH Pres (esi)- C BH Proppant Cone (lb/gal) A Actual BH Temp (T) C Well Description: 2M 40 erne .bb Dale::Sep�2019 Saks Order #: 0905983800 tPM: s0-103-20804 D 75 M Conow Phillips Alaska -]Md0 Interval 13 Plots 89 Ill Blender Chemical Plot - Interval 13 nrvua�_w f:nnn nh/Maall B Ootiflo-ll Conc (Ib/Mgal)B I B 9/2812019 _ _ — 9IZ8/2019 Time Order A: 0905963800 1 Well Description: 2M 40 I IMA: 50-103-20804 Conoco Phillips Alaska - 2M-40 Interval 13 Plots ADP Chemical Plot - Interval 13 A Losurt-3O0D Conc (aal/MgaD A WG -36 Conc (Ib/Mgal) B Customer. CONOCAPHILLIPS NORTH SLOPE- EBUS I Job Date: 26 -Sep -2019 Saks Order #: 0905963800 M' Well Description: 2M 40 lluM: 50-103-20804 Conoco Phillips Alaska - 2M-00 Interval 13 Plats 90 Net Pressure Plot - Interval 13 Net Gauge BH Pres (psi) A 0 Customer: 2M 40 Time (min) Job Date: 26 -Sep -2019I Sales Order#: UWI: 50-10320804 Conoco Phillips Alaska - 2M30 Interval 13 Plots A 1 Treatment Plot - Interval 14 Slurry Proppant Conc (Ib/gap C BH Proppant Conic (Ib/gal) 8 Gauae BH Pres (osi)A Actual BH Temp (`F)— customer: `F)— C DI C D ) X175 912612019 •�. �" ...__ . .- - _ 9/2612019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- FBl1S I Job Date: 26 -Sep -2019 Well Description: 2M 40 LAM: 50-103-20804 150 125 100 Conoco Phillips Alaska - 21040 Interval 14 Plots 92 Blender Chemical Plot - Interval 14 A Ontiflo-lll Conc Ob/Maall B Optiflo-Il Conc (Ib/Mgal) B a 9/2&3019VJV__ 912&2019 Time Oustoncr: CONOCOPHLLIPS NORTH SLOPE- EBUS Job Date: 26sp-2019 Sales Order *: 0905963800 Well Description: 2M 40 1 LW: 50-103-20804 Conoco Phillips Alas" -2M-40 Interval 14 Plots 93 ADP Chemical Plot - Interval 14 Losurf-3O0D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgal) B B Time Customer: CONOCOPHLLIPS NORTH SLOPE- PBUS Job Oste: 28 -Sep -2019 Sales Order #: 0905983800 Well Description: 2M40 I LMA: 50-103-20804 Conoco Phillips Alaska- 210-40 Interval M Plots Net Pressure Plot - Interval 14 —et Gauge 8H Pres (psi) NA A — BH Proppant Conc (Ib/gal) B IB 1U Time (min) Customer CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 2"ep-2019 Sales Order#: 0905963800 Wetl Description: 2M 40 UWI: 50-103-20804 Wnam Phillips Alaska - 2M40 Interval 14 Plots A 1001 Treatment Plot - Interval 15 Slurry PiC BH loroppant Col B Gauge BH Pres (psi) A Actual BH Temp c D C D 1 175 150 125 . ------ Time Customer: CONOCOPHILLIPS NORTH SLOPE- B3US Job Date: 26 -Sep -2019 WellDescription 2M40 IPM: 50-103-20804 Sales Order #: 100 Conoco Phillips Alaska - 2M-40 Interval 15 Plots 96 A 1.E M OJ 0.( 0, 0.: Aft, Blender Chemical Plot - Interval 15 CL -31 Cc (gal/Mgal) A CL -22 UC Conc (gal/Mgal) — A MO -67 Conc (gal/Mgal) A Opt So-onlll Conc (Ib/Mgal) B Optiflo-ll Conc (Ib/Mgal)B Rk t--77tl • 14:30 92612019 Custoner: OONOC Well Description: 2M40 14:40 14:50 15:00 Time :TH SLOPE- EBUS I .lob Date: 28 -Sep -2019 IAM: 50-103-20804 B 2.5 2.0 1.5 1.0 -0.5 0.0 15:10 15:20 9@62019 0905983800 Conoco Phillips A.A.- 2M40 Interval 15 Plats 97 ADP Chemical Plot - Interval 15 A gal) B B --w WW2019 Time Customer. OONWOPHILLIPS NORTH SLOPE- HBUSI Job Date: 26 -Sep -2019 Description: scription: 2M 40 LW: 50-10&20814 mnom Phillips Alaska - 2M40 Interval 15 Plots 98 Net Pressure Plot - Interval 15 — Net Gauge BH Pres (psi) h /� — BH Proppant Conc(lb/gal) B Time (min) Customer. CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 26-Sep�2019 Sales Order#: 0905963800 We0 Description: 2M 40 UWI: 50-103-20804 Conoco Phillips Alaska -2M-40 Interval 15 Plots HALUBURTON ~vies Cirder# 0905963800 Conoco Phillips Alaska - 2M-40 Conoco Phillips Alaska 2M-40 Intervals 1-1-5 C -Sand Formation Harrison Bay County, AK API: 50-103-20804 Prepared for: Scott Pessetto September 26, 2019 Stimulation Treatment Appendix - Well Summary - Chemical Summary - Planned Design - Water Straps - Water Analysis - Real -Time QC - Prejob Break Test - Farm 15 Minute - Event Log - Lab Testing Appendix 9.9 Conoco Phillips Alaska - 210-40 Well Summary 101 2M-40 Interval Highlights Interval Date Designed Proppant (Ibs) Proppant in Formation (Ibs) Vol Clean (bbl) Vol Slurry (bbl) Top Perf (ft) Bottom Perf (ft) Fluid System 1 9/21/2019 100000 96200 2429 2,533 21,189 21,190 Hybor G 2 9/21/2019 100000 95780 1694 1,798 20,836 20,837 HyborG 3 9/21/2019 100000 104055 1686 1799 20,190 20,191 HyborG 4 9/21/2019 100000 108998 1885 2003 19,809 19,810 HyborG 5 9/24/2019 100000 96324 1839 1944 19,385 19,386 HyborG 6 9/24/2019 100000 104810 1718 1831 18,703 18,704 HyborG 7 9/24/2019 100000 87451 1006 1101 18,195 18,196 HyborG 8 9/24/2019 100000 99104 1612 1717 17,729 17,730 HyborG 9 9/24/2019 100000 97303 1047 1153 17,264 17,265 HyborG 10 9/24/2019 100000 101869 1198 1309 16,798 16,799 HyborG 11 9/26/2019 100000 96702 1114 1219 16,187 16,188 Hybor G 12 9/26/2019 100000 97173 1178 1283 15,842 15,843 HyborG 13 9/26/2019 100000 100063 1046 1154 15,455 15,456 HyborG 14 9/26/2019 100000 98979 1054 1162 14,990 14,991 HyborG 15 9/26/2019 100000 117179 1216 1343 14,525 14,526 Hybor G Conoco Phillips Alaska - 210-40 Well Summary 101 Cuslemer Coleco Phillips Alaska HA"IBURTOM ('e Pormasion C -Sana Lease 2M 40 M 50-103-208M Dare 9/21/2019 Inhrval5u mmary - Chemica6 Interval Louk Aatlllhes Dry AtltliNll la5urt-3000 M03] CL 22 UC 4-31 LVRZ00 WG -36 gE6 O tSblll 0 UFbll SP (god) (gull (aep (pall —11 (lbs) (1651 (1651 (16x1 fibs) Pelme Up 0 0 0 0 0 0 0 0 0 30 0 0 3 % 66 90 40 42 3496 17 1% ]0 51 69 35 42 2302 15 180 35 0 2 70 50 66 35 42 2226 15 135 18 0 8 75 49 65 35 1554 3206 16 150 30 15 4 JJ 64 ]5 40 42 2572 12 108 19 0 g 77 59 69 32 84 2244 12 107 18 0 6 2 42 42 42 21 84 1416 6 82 11 0 66 46 66 26 84 2118 30 107 17 0 8 44 44 40 22 84 1401 8 u 31 0 g 49 43 68 54 3402 1464 7 98 12 15 10 21 41 34 47 20 0 16" 7 94 12 0 12 49 32 43 22 0 1499 7 99 12 0 44 32 H 22 0 1390 J 8g 11 0 13 44 33 M 22 0 1423 7 89 11 0 14 46 19 52 11 3570. 14M 7 133 9 5 15 89fi 674 881 443 9030 287N153 1750 136 35 Total 674 881 443 9030 28760 353 1750 236 35 w/p Prime Up 8% Conoco Phillips Alaska - 2M40 Chemical Summary 102 wx. eio".. .uu.m�ui ,. �a 1 r.i °--- .w A,. o see r �6r__. ..,. rTyT.... xe —IsI Conoco Phillips Alaska - 2M-00 Planned Design 103 ��J��f!'J1f17�■1.�7f1'Jf�fl'J�fr;'! ®��j ®� �i��0m67•m1�m�0�Fs� � SS ��.p��mA� gym•®��mmmtmt�m®m•mf 0 ��g��1�0®� .:. ®ism++a�-+.snm-n�t^rg e4 ti�0�s.�®0�b�®®EC)•mm�'.��ctmm�B� �®„"�r�nswn'm��d�ie7•itl��SOC��®�i1��0m®��i2lmia��t ��0�m®gym®®��I. !il•�a....'La•�.T-!,� '�' IL•1.0�®��®it�1. ® r.-.w�+nn'.+'�I��®Ili➢�®0�©��Im��m�0®� m�ci•��3?n ®�C(^I��^�^I^F��0osS1¢��®1L4�®iC7•mm� ®@.�@f•ID�. �L})♦00�0m®��®gym/�0�m®!>•1•�� Conoco Phillips Alaska - 2M-00 Planned Design 103 s�°,— °onero=o ,.�,,,,,,,e, __ ° E. •nrn "".'_ neo i.— FM r r��K Irewl xalmn �nlro I I C.nee. Phillipa Alai - 2MAO Planed Design 104 mmmm ®sem�MfSE• 00��®mom®®gym®®� mt]lwe.IDr�^��At£'.)•®�4��P"._)•��®mQ'.1�t.L'f�m®lJ�� mom 0�-�® 0 m®m•®®®m•®m�mm��®®mm,� 0soa�srm}�MMOSOM 0 sea®�r_�®r"a m®©�®mom®©�®mom®mom®®mm•� spa m®m�� m�si;•�� ss sesr:.as�a®sz�� m ®�®®®so®� 1111liM m sm�s��sm�c� sego �t»a0s>sa s�•as�mms'm�m®sr��m m mms�� ®smsas�^.m�ly� mo ©e�a�sxrs mm�m m m.m.;s®s_>�i�+nc>• mA �.�®®se©�s�me+:>t��ia�� mmir�m,m mina-�ra,T.» ma>.�o� ��a� ' ��alarammEom�r:�m III - �� ..cas»o�s�®®so��mmmm�.a�mmEst•�m o�®0�m��mmmm�mmmm,m sa>•sme�®r.�sn$m�mo®0�s's��mmm��m®spm m�s�ss� rnms�®m .: msma�sr.�s�mo©ems®�®®rr.�sraa•m®®s��mmi�®m mseamss�ma•sas m�� ®®sn®�� m®m®gym®mem E>u�m s>�s �>.s�mms-:>.m�mmm111IFFRIIIIIIIIIIm a0 m®�mrm ease•,^.as>mmo�::;.��scv�®m�mm� IIIIIIIIIIIE16110�®��ms�®m�l��m��mm® sn�mcas�m�� ®®sow s��s mmsa�� mm��m C.nee. Phillipa Alai - 2MAO Planed Design 104 • In _ as WAN �mmg��mmB� as >♦�I�®®®tat��mlipmm�m�� mIMEMIN 0®�®®� �� tulip. ®g®.'SSd•�� m�m��®�,1�sf� INIgn"gggg ®��g®��gm©®m•®®®m•�oaammm��®�m�� 11111110111 ®®®Q'fE0<['.1��L�g®i3c�g�� ®g�A...>♦g�I'9�!Jg�^IDL'®©E�AO� rmEum� ®�.arm+>•m_m��em�m•0m•®�.s®®mm®mem . _. ®®r,�.�tm�.�m�.Jnr•�.dP��©©�®®!4"�g��mmgoalm�m®g�� ® .,.,_ ,..��.,,�.�sm©m•�m.��gill {� IFER OEM � Mimimmm��®®m�� gliggill ®� ®m e�� m ®mom ®!e�^—��m• mal ©c:� ®®� g®®®ven_�v�mo m0 ©®a0 m•m•®mm�sgm.� m�� ®s�„E��.'1��®0�3L")•g�®�Sis�g®mmmm�m®�<3F1•� OEiC�®®gfil�®s�mmae ®�P.SRd•@T_®®gym meea�sa 111111111110111111 on giFt;•g®�g�.��m0��®a��g®g�mmm®gym®m®� ®�,��,�� g®g0 �� gAgO m• g®®m m m�� m®m®�, ®��g®0g��g�g®®©m•�mmmm�®®m®� mmm®� Il m��®� Etss� g�gQT-��T� ®0��m•0�s�� mmm�m®m®111136011 Egli�� Conoco Phillips Alaska - 210W0 Planned Design 105 WAN �mmg��mmB� as Conoco Phillips Alaska - 210W0 Planned Design 105 Customer: Conoco Phillips Alaska Well: 2M-40 Date: 9/21/2019 Formation: C -Sand sna. 0905963800 C-oco MOP Alaska -2M 10 MterS aq Day wn General Beginning Strap Ending Strap Tank Type Water Source inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF2. 99 19,950 475 101 9 1,722 41 2 Wichita CPF2. 100 20,160 480 101 9 1,722 41 3 Wichita CPF2. 97 19,530 465 103 9 1,722 41 4 Wichita CPF2. 101 20,370 485 102 9 1,722 41 5 Atigan CPF2. 87 16,273 387 103 9 1,262 30 6 Atigan CPF2. 102 19,175 457 104 9 1,262 30 7 Atigan CPF2. 100 18,788 447 105 5 532 13 8 Atigan CPF2. 89 16,660 397 106 9 1,262 30 9 Atigan CPF2. 102 1 19,175 1 457 105 38 6,555 156 10 Atigan CPF2. 100 18,788 447 101 89 16,660 397 11 Wichita CPF2, 96 19,320 460 103 95 19,110 455 12 Wichita CPF2. 100 20,160 480 102 51 9,870 235 13 Wichita CPF2. 93 18,690 445 105 56 10,920 260 14 Wichita CPF2. 100 20,160 480 105 9 1,722 41 15 Wichita CPF2. 99 19,950 475 101 9 1,722 41 16 Wichita CPF2. 98 19,740 470 109 9 1 1,722 41 17 Wichita CPF2. 95 19,110 455 102 9 1,722 41 18 Wichita CPF2. 92 18,480 440 104 9 1,722 41 19 Wichita LPF2. 101 20,370 485 103 9 1,722 41 20 Wichita CPF2. 98 19,740 470 104 9 1,722 41 21 Wichita CPF2. 98 19,740 470 102 9 1,722 1 41 Location Summary Usable 1,748 Starting Volume Ending Volume Total Used 73397 Gallons Barrels Gallons Barrels Gallons Barrels 493 52678 404,329 9,627 88,097 2,098 316,231 F7,529 Pre -lob Barrel Bottoms Zones: Volume Needed for X Intervals (BBL(: Number of Tanks Needed: Tank Bottome(BBI: 4-lan 0 458 0 458 0 458 0 458 C-oco MOP Alaska -2M 10 MterS aq Day wn Customer: Conoco Phillips Alaska Well: 21040 Date: 9/24/2019 Formation: A -Sand conoto MI'pn AIa:W-21010 MWr Strain Dry 107 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature(°F) s Barrels 1 Wichita CPF2, 102 20,580 490 113 41 2 Wichita CPF2. 102 20,580 490 108 41 3 Wichita CPF2. 104 21,000 500 112 41 4 Wichita CPF2. 100 20,160 480 114 2 M91,262 41 5 Atigan CPF2. 101 18,981 452 115 2 30 6 Atigan CPF2. 104 19,562 466 109 2 30 7 Atigan CPF2. 102 19,175 457 114 2 30 8 Atigan CPF2. 99 18,595 443 109 2 30 9 Atigan CPF2. 106 19,949 475 99 9 1,262 30 10 Atigan CPF2. 101 18,981 452 101 91 17,047 406 11 Wichita CPF2. 108 21,000 500 103 91 18,270 435 12 Atigan CPF2, 112 21,013 500 109 50 8,910 212 13 Wichita CPF2. 104 21,000 500 106 53 10,290 245 14 Wichita CPF2. 106 21,000 500 107 18 3,402 81 15 Wichita CPF2. 106 21,000 500 109 9 1,722 41 16 Wichita CPF2. 105 21,000 500 105 9 1,722 41 17 Wichita CPF2. 105 21,000 500 111 9 1,722 41 18 Wichita CPF2. 101 20,370 485 105 9 1,722 41 19 Wichita CPF2. 103 20,790 495 104 9 1,722 41 20 Wichita CPF2. 102 20,580 490 106 1 9 1,722 41 21 Wichita CPF2. 103 20,790 495 111 9 1,722 41 Location Summary Usable 1,630 Starting Volume Ending Volume Total Used 68472 Gallons Barrels Gallons I Barrels Gallons Barrels 424 50665 427,106 10,169 1 83172 1 1,980 343,934 8189 Pre -Job Barrel Bottoms Zones: Volume Needed for % Intervals (BBL): Number of Tanks Needed: Tank Bottoms BBL): 6 0 484 0 484 0 484 0 484 conoto MI'pn AIa:W-21010 MWr Strain Dry 107 Customer: Conoco Phillips Alaska Well: 2111 Date: 9/25/2019 Formation: A -Sand Tank noncaFaann Conoco Phillips Alaska - 2M40 Water Straps Day 3 102 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF2. 101 20,370 485 112 9 1,722 41 2 Wichita CPF2. 100 20,160 480 108 9 1,722 41 3 Wichita CPF2. 104 21,000 500 108 9 1,722 41 4 Wichita CPF2. 102 20,580 490 106 9 1,722 41 5 Atigan CPF2. 101 18,981 452 109 9 1,262 30 6 Atigan CPF2. 106 19,949 475 107 9 1,262 30 7 Atigan CPF2. 106 19,949 475 109 9 1,262 30 8 Atigan CPF2. 99 18,595 443 1 110 9 1,262 30 9 Atigan CPF2. 110 20,722 493 104 9 1,262 30 10 Atigan CPF2. 101 18,981 452 96 61 11,200 267 11 Wichita CPF2. 99 19,950 475 97 99 19,950 475 12 Atigan CPF2. 110 20,722 493 96 93 17,434 415 13 Wichita CPF2. 101 20,370 485 112 97 19,530 465 14 Wichita CPF2. 101 20,370 485 123 66 13,020 310 15 Wichita CPF2. 101 20,370 485 10541 7,812 186 16 Wichita CPF2. 101 20,370 485 109 9 1,722 41 17 Wichita CPF2. 82 16,380 390 93 85 17,010 405 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 344,708 8,207 127,764 1 3,042 216,944 5,165 Pre -lob Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 5 5,381 11 166 0 483 0 483 0 483 Conoco Phillips Alaska - 2M40 Water Straps Day 3 102 ra,�mnnunb. Juno vn",[,uh+n orvt HALLIBURTON Alaska oirtritt Field QC Prejob Water Anaty[i[ on Location COnO60 Phillips nmpanY Well Name: M 401-0 PF3 Water Souris: Specific Tenting Qissohretl Iron CM110ritle Sulfate @Icium MyneA. TOWI linear Water Gel Pox-Uo[slink OasxNX gac[era Tem era[ure Less Cf 50 [ G[ [ ,A Para Kx H N H Gmi -F mg/L mg/L mg/L mg/\ mg/L mg/t CP IY/NI BQV81ue oigital Strip Strip Titration Total Hard... ¶\radon FANN-35 Probe Probe Probe - MymmHer Trak p Hectometer Thenoameter Strip Minus Unum 1.@0 58.2 0 14,110 800 1,200 2,000 3,200 30 7.06 7.50 9.50 Y 65.917 ] 2 1.O1H 56.8 0 16,400 BW 1,200 2bW 4.000 32 7.20 JA0 9.60 Y 39,5R 1.@0 SJ.1 0 1],690 eW 1200 2403 3,200 28 6.98 7.45 9.60 Y 75,782 3 56.4 0 34,0]0 BW 1,300 ],600 2,80] 30 6.93 79.35 9.70 Y 31,513 q 1.020 1.018 56.1 0 13,080 800 1600 LOW 3,303 31 G.% 7.60 9.60 Y 1821820 5 57.3 0 14,310 WO 2.000 BW 2,800 35 689 740R9AO Y 33,038 6 1.021 565 5 12,120 am 11600 11600 3,200 32 6.80 7.60Y 45,7993 7 1.020 56.8 5 14,110 803 1,400 1,603 3,200 33 6.90 7.50Y 5,795 0 1.022 0 14,110 003 1100 2A00 3,603 38 6.80 7.4EY 34.264 9 1.020 561 55.1 0 19,080 1,200 ],200 2.030 3,200 3] 6.01 7.33Y 13,390 10 31 1.010 1.020 SL9 5 30,850 I,3W 1,200 1,600 2,800 31 603 ].54Y 49,960lE 55.1 0 40,890 803 1,203 2,000 3,300 36 6.80 7.20 Y 116,]]313 1.@0 SS.J 0 1],690 1,200 1,600 3,000 3sM 28 6.85 J 60 Y 7$33 14 1.030 55.6 0 16400 1,200 1,603 800 2,400 30 6.75 ] 40 Y B,NO 15 1.018 566 0 22,250 1,200 800 3,200 4,033 32 6.00 ].30 T 6,503 1.030 5].3 0 17,690 1,200 1,200 2,000 3300 30 6.79 7.22 Y 0,743 16 0 14,110 a[0 1,200 1,600 2bW 316.80 ]A] Y 8,171 17 1.018 5145 9.5 0 12,120 1,200 1]00 3803 4,003 33 675 ].IS 910 Y 10,031 10 1.020 1.018 58.1 0 14,110 000 1.ELtl 3400 3,603 28 6.795 79.31 940 T "22 19 61.1 0 16,403 BOo 1,600 BW 3,9079 29 6.00 79.10 930 Y 6,516 2p 1020 603 0 19,080 800 3,030 003 2,603 30 6.60 ].10 9.30 Y 10,286 21 10]8 57.0 1 18118 933 1362 1838 3303 30 6.85 7.3] 9.51 35628.0 Average 49.Id7 5 40,090 1,200 E,OLtl 3,203 4,003 35 79.20 79.60 9.]0 183,820 Matlmum 1010.030 61.1 WO 800 803 3,40] 26 6.60 7.10 930 S,J95 Minimum 1.016 Sd.9 0 13,320 400 1,200 2,400 1,030 9 060 0.50 0.50 177,025 R!21L- 1016.984 63 s xan6 ra,�mnnunb. Juno vn",[,uh+n orvt nm.omsyu.ua2u+p wv«umyr. orz Cwnpany HALLIBURTON Alaska D'udict FWW DC P,ejob Water Analysis on location Conoco Phillips Wall Name: 2M-401ntervak 5-]0 Waterseuree: CVF2 Spaifls G.i Testing Tem ntum Dissolved Iron Fe° ChWrlda CY Sultan, CakWm Me,".m Total LM., 0 ° ow M za HaMness VN.a Water H 60 N Post-bpssOnk X -.-line Betletla .F m.A m8/L m8/I m8/L 0003 cp (Y/N) MWlue Tankp Hydrometer Di8Ha1 Ther meter Sttip SuiO Strip Titnlm, Total Hardness Snip FANN-35 Minus Calcu m Robe probe Probe - Newormter 1 1025 75.2 5 12,120 400 3,200 4,800 0.020 34 7.01 7.00 9.00 Y U66 2 LOO 74.6 20 8830 800 L200 3,800 5,000 34 7.08 J.JO 8.80 Y 2,462 3 1028 ]].2 20 12,120 800 3,200 4,800 BOW 30 ].0] 7.30 9.00 V 3,623 4 1.030 78.4 5 6 MO 800 3,200 1,800 5000 33 7.00 7.20 9.00 y 3,664 5 1.026 79.3 30 11,210 1.200 2,800 3,200 6,400 30 7.0 MO 9.10 y 1,460 6 LOW 785 5 5.170 800 3,200 4,800 8,00] 25 ]O6 7.30 490 V 1,280 J 1.027 80.1 20 14,110 1.200 2,800 2800 S,CW 20 7.07 7.20 9.20 Y 2,187 8 1025 1 796 20 1 0,830 800 3300 2,91,4 6,800 21 7.06 7.20 900 Y 2,617 9 1.030 7)8 5 11,210 NO 3,200 4.800 SON 27 7.04 7.30 9.3D Y 5,054 14 1.029 79.3 5 8.830 NO 1800 2,200 S,WO 26 7.10 1 7.40 900 Y 999 15 1.030 76.8 20 10,370 1.200 LBOD 3,200 6,WO 27 700 1 7.20 9.10 Y 11200 16 1.029 77.6 20 8AW 1,20D 2,WD 5,200 81000 28 7.02 1 7.30 9.20 Y 1,084 17 1026 78.9 5 6,840 800 3,200 2.800 61000 29 7,03 10 ]17.10." 9.10 V S46 18 1030 74.9 5 12,120 1,200 2,Bo0 5,200 0,000 26 Y 916 19 1.031 71.1 5 8,030 3,200 3,200 E,BW 6.000 26 Y 847 20 1.028 81.1 6840 200 3.200 4800 80 30 Y21 LOW 82.3 5 6,200 1,200 3,200 2,BOO 6,000 31 M0�0. YAverage 1028 77.8 11 9340 90 2941 3647 6588 28 1 1957.1 Manmum 1.03 82.3 E0 14,11D 1,200 3,200 S,2W 8,000 34 0 5,454 Minimum 1.025 71.1 5 5,170 400 1,200 LB00 S,WO 20 846 15 0.940 000 3,000 3,400 3000 14 0 4,208 nm.omsyu.ua2u+p wv«umyr. orz [morn 000000 NssYa ]u ro wnernwMun+v] HALLIBUATON Alaska District Field M Prejob Water Matteis 00 LOCACA Conoco Phillips ompany: :Mao lntervzl:l3-ls Well rvame: PF2 Water sours: Spet2Nc Testing PPtasaium OWOI Iron Chloride Sulfite Ultlum Magnesi0m Total Linear Water Gel Post-Gosslink Gosslink BaetMia Grav' Tem erdere K Fe's [f SO' U'* M - Hardness VI=I H H N rF mg/L mg/L mg/L m L m L mg/L UC03 PBGValueTanke Digital Strip Strip Strip il[ra0on Total Hardness StripFANN 35 Probe Probe Probe - Mcometer Hytlramehr Thermometer Titration 5 13)00 Minus Callum1 8,800 S0,W0 26 ].02 ].30 9.10 Y 3,664 1.020 ]0.1 0 13,]00 ,200 6,090 8,0W 26 6.9E ].10 9.14 Y 2,178 2 1A20 )86 0 14,810,000 ,200 6,000 8,000 28 6.99 ].31 899 Y 1,288 3 1.020 J8 &9 5 O 9,600 12,D00 28 6.85 ].32 9.21 Y 9,610 1 1.018 79 0 ,40D ],200 10.000 30 ].10 7.42 932 Y 4.211 5 1.016 0 ,,800 1&010,200 8.wD 12,000 26].11 9.14 Y 1.288 6 1016776 0 130,)001,Ma 10,BW 13,000 36 It ).05 ].16 9.33 Y 2,187 ] 1.000 ]83 20 14,8101,200 8,000 10,0D0 26 ).08 ].22 9.24 Y 1,8649 8 ]020 ]8.9 514,1102,400 11,600 14,000 2H ).10 ].31 9.20 Y 4A3I14 1.016 )&1 0 S6p102,000 6,400 9,200 28 6.99 ]21 9.31 Y 1,544 1.010 ]8 0 13]00 2,400 11,600 14,000 2] 678 ].15 9.41 Y 1,288201].300 15 1020791 3,800 9,300 12,Om 38 ].03 7.11 9.24 Y 1.18] lJ 1026 ]8.9 5 6,840 800 3,200 2.890 6,000 29 7.03 7.10 9.10 Y 846 3.024 ]&5 5 33185 831 2215 8338 10554 ffi ].00 ).20 9.R 3352.8 gveraBe 0 20 130,700 ],300 3.200 11,000 14,000 30 ).10 )41 9.41 4,411 Maaimum 1.000 ]9.1 0 6,840 400 1,200 2,800 6,000 26 6.78 7.10 ads Minimum 1.016 ➢.6 0 BD0 1 31000 1 8,000 1 4 10.331 0.32 1 0.42 3,565 Ran a D.064 1.5 0 20 1231800 1 [morn 000000 NssYa ]u ro wnernwMun+v] Cn,mm¢r Lnn4wP61111 Fk,s 1n¢ H A L L I B U R T O N Weliname ffi #: 2M49 Date. Se m6er 21, 2019 Linear XL Linear Linear XL Interval Sue Vise H Tem T H Cammems Interval Sue Vise H Tem 7 H Comment I Mini -Fm 23 ].03 873 8.83 921/2019 11 Pad 32 ].08 83.4 9.4 92fiR019 Pad 21 686 ]9.5 8.63 Increased MO -67 I# 27 6.86 93J 944 IN 32 6.82 82.5 92 29 27 689 93.2 9.41 29 33 6.83 876 9.18 39 26 688 919 9.51 39 32 6.79 84.9 9.16 49 26 6.9 89.2 942 44 32 678 86.5 9.41 5# 26 687 89 9.59 6# 26 691 887 9.65 2 Pad 30 6.87 83.1 92 9212019 12 Pad 27 687 82.3 9.43 92fi2019 IN 34 fi68 869 9.13 IN 26 6.91 94.2 9.52 29 32 67 89.4 9.17 29 27 6.83 912 948 3# 27 6.76 86 9.22 34 21 69 90.1 9.52 44 25 675 82.2 9.JI 4# 27 6.86 919 953 54 27 6.89 92.6 964 bit 26 685 90.5 9.61 3 Pad 28 6]7 86] 9.44 9/21/2019 13 Pad 29 691 93.2 9.51 926/2019 Ik 28 6.86 849 932 29 694 2# 28 674 871 923 26 691 915 9.51 3# 26 684 83.1 944 $U4# 26 6.94 926 962 4# 28 6 81 84 9.3 24 694 91 9.54 2] 69590.7 955 26 693 89.1 955 4 Pad 27 6.81 905 9.31 9212019 14 Pad 24 6,96 94.6 9.54 1# 27 6.88 88.8 9.31 I# 26 694 91.5 9.56 9262019 29 23 695 874 9.23 29 28 6.91 91.9 9.54 39 26 685 849 9.44 39 27 6.95 91.2 961 49 25 684 85.1 9.38 4N 29 694 90.8 921 5# 30 694 914 9.64 6# 27 6.98 89.2 9.59 924/2019 9/2612019 5 Ped 27 664 807 9.13 15 Pad 25 6.96 856 962 IN 26 68 883 9.55 IN 28 699 98 9.53 2# 24 6.85 89 961 2k 26 6,96 98 9.51 3# 27 6.82 88.1 955 3# 26 698 957 9.5 49 25 6.83 908 9.66 4# 27 7.02 88.3 957 5# 28 698 26.1 9. 54 69 23 697 M 9.55 9242019 6 Pad 22 97.8 968 19 28 681 95 9.58 29 30 684 i 86 9.76 31 27 6,77 92.5 9fi] 4# 29 69 88.8 9.71 924/2019 ] Ped 29 679 93 9 9.64 IN 28 686 82.5 9.72 2N 30 6,78 82.4 963 3# 27 6.82 82.7 9.74 4# 28 fi81 843 991 5# 27 683 82] 979 60 32 Cal 81.3 9]8 9242019 a Pad 32 6.81 87.2 968 1# 42 6.76 85.1 9.82 2N 36 681 856 972 3# 33 6.87 86.1 9.59 4# 28 679 a 7 964 5k 25 67] 85.1 9]I 6# 23 6.82 ]7.3 9.67 9242019 9 Pad 19 6.79 92.4 964 I# 26 6.83 90.8 964 2# 26 68 89 9.38 3# 25 6.85 88.5 961 4# 27 679 86 9fi] 5# 26 6.87 83.1 9.73 6# 23 6.86 86.1 966 10 Ped 22 687 861 9.62 9242019 IN 34 6.88 89.9 9.58 2# 39 6.86 88.7 9.54 3# 32 689 894 9.59 4# 25 691 867 9.64 59 26 6.92 86.7 966 6# 28 691 85.8 9.67 ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Company: Con000PhIHIPs Project Well Name: 2Md0 Stag, BHST (-F): 166 Water Sou Depth: 6600 Water Formation: A -Sand Hydration Analyst: 9rmr Gonad Hydration visc: _ 1 FlaWIs oRniS0 P Zone 1 Crosslink Tests —Serwal .1 PPB —2 PPB —3 PPH —4 PP9 �5 PP9 4500 4000 3500 30M a 2soo y 2W0 S 1500 ON NO 0 WOMEN M„SOMMEON NE009AMM EMEMEMEN MEN &\, NOR 0 EMOMEMNon MEMMOM %MENEM 0 No 0 on on EMEMEMEMOM MEMEMOMENO Timelmm:>ecl Conon PhIHIPs Ma0a-2Md0 IaOE a—k rertoay3 113 ALASKA DISTRICT LABORATORY 16 Minute Farm Model 35 Crosslinked Fluid Report Lm xUl 1 FWdtl .keni1300 Zone 1 Crosslink Tests —Seneei —i pN —2pn —3M —4 ppb �5pp9 . Fluid System: Date: Company: ConocoPhillips Project No: Well Name: 210.40 Stage(s): BHST(°F): 155 Water Source: Depth: 6600 Water pH: Formation: ASand Hydration pH: Analyst .*w Snami Hydration Visc: Lm xUl 1 FWdtl .keni1300 Zone 1 Crosslink Tests —Seneei —i pN —2pn —3M —4 ppb �5pp9 . ." 111111"1111"1111111'11111111 1,11x1'1,,1,1111111111111111111 .. '1,111111111,11111111111111111 111111111111111,11111111111111 7i(re n:.) CanoesiMlllq.Phska-EM�ie helob BreakiereUryE 114 ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Company: ConocoPhillips Project No: Well Name: 2111140 Stage(s): BHST (°F): 156 Water Source: Depth: 6600 Water pH: Formation: A -Sand Hydration pH: Analyst: -*=y'au+h Hydration Vise: NlcMmlcw wrc dwionc aco 1400 1200 g toxo Zone 1 Crosslink Tests �6erkel �1PW �2M —OPnI —4 pp �5PP9 SEEMS � EM ■\ Radom ■■ moose 0■■■■E■■■■■■01\0 . Solon 51 NOOSE OUR /IMEN ■NOR on 0■0■■0t■t■■■t1■■■■ 0 I►■O■■■■■ MI ■■■■■■ N.E...O..EM..M.. MEMNON on MEN ■■SENSE ONE t■NEEM■ ■■■M■■t■■■■■■ Tinre eNn:seDl Canna MIIIIps Plaska-2M-9D Prelobsra ins DaV3 115 w0 20M so0 Zone 1 Crosslink Tests —Pad iM —2PP8 —3m —4 PP9 —5 PP9 111111111111111111111111111111 1111111111111111111111111111111 11111111111111111111111111111111 1'11111111111111111!!!!!!!!!!! rime (min:sro) L Num°n—a ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 1 Company: ConocoPhlllips Project No: Well Name: 2M30 Stage(s):_ BHST(°F): 90 Water Source:_ Depth: 5500 Water pH:_ Formation: ASand Hydration pH:_ Analyst: A Hydration Vsc: 0F9 w0 20M so0 Zone 1 Crosslink Tests —Pad iM —2PP8 —3m —4 PP9 —5 PP9 111111111111111111111111111111 1111111111111111111111111111111 11111111111111111111111111111111 1'11111111111111111!!!!!!!!!!! rime (min:sro) L Num°n—a I—P'F PR LOSIIRFd000 CL3211C CL.l Mod? 004 11 MiniFrac Pad 1PPG 80.7 9.80 1.00 0.90 0.45 1.25 2.00 2PPG 80 9.90 1.00 0.90 0.45 1.25 2.00 3PPG 80 10.00 1.00 0.90 0.45 1.25 2.00 4PPG Cmnen PM1illipiMxMa 3MJO Fann 11 Zone] 116 F""""°"en9300cp Zone 2 Crosslink Tests Ped �1 ppg �2ppp —3m —4 PP9 —5 PP9 ME, woo 25M 20M ,600 S ,000 wo ,,0 osmosis ,,,,,,,,,,,,, `•■wlloom ■,,.,,,,,,,,,,,,,,,,,,,,,,,, loolons Ron Timelmin:drcl An cnemmm corcemrmmne oss. so In vnbns lerthomsM I pounds Por zMusaM Lot Numbrt—+ TempoF pX LelAW-3001) CLU NC CLJ, MCBT omeom Pad 1 ppg 80 9.90 1.00 0.90 0.45 1.26 2.00 2 ppg 3 ppg 75 10.00 1.00 0.90 0.45 1.25 2.00 4 pp9 wno<evnznm siar,.zwm w.n uz".ea ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: Company: Conocolshillips Project No:_ Well Name: 2M-40 Stage(s):_ BHST ('F): 155 Water Source:_ Depth: 6600 Water pH:_ Formation: A -Sand Hydration pH: Analyst: 5 :Na600&fi Hydration Vise: cp F""""°"en9300cp Zone 2 Crosslink Tests Ped �1 ppg �2ppp —3m —4 PP9 —5 PP9 ME, woo 25M 20M ,600 S ,000 wo ,,0 osmosis ,,,,,,,,,,,,, `•■wlloom ■,,.,,,,,,,,,,,,,,,,,,,,,,,, loolons Ron Timelmin:drcl An cnemmm corcemrmmne oss. so In vnbns lerthomsM I pounds Por zMusaM Lot Numbrt—+ TempoF pX LelAW-3001) CLU NC CLJ, MCBT omeom Pad 1 ppg 80 9.90 1.00 0.90 0.45 1.26 2.00 2 ppg 3 ppg 75 10.00 1.00 0.90 0.45 1.25 2.00 4 pp9 wno<evnznm siar,.zwm w.n uz".ea Nl memlcal conx�rtrtllons L Nume — b"°w H300A Zone 3 Crosslink Tests —Fea 3M —3PPJ —4 PP9 —5 PP9 Sao 350 u 3 1 n � to ALASKA DISTRICT LABORATORY 15 Minute Farm Model 36 Crosslinked Fluid Report Fluid System: Date: I Company: ConocoPhillips Project No: Well Name: 2111-40 Stage(s):_ BHST(°F): 166 Water Source:_ Depth: 6600 Water pH:_ Formation: ASand Hydration pH:_ Analyst: I M6Pa&5 Hydration Visc: <PQ Nl memlcal conx�rtrtllons L Nume — b"°w H300A Zone 3 Crosslink Tests —Fea 3M —3PPJ —4 PP9 —5 PP9 Sao 350 u 3 1 n � to Temp°F PH LOSUaF400D CLE UC CL3t M047 Owffdll Pad t PPg 2 PPg 3 PPg 4 PPg 5 PPg rH�lmin: al Cmow PMlllpf <Inps� iMi° Fann 15IDne 5 118 1711— 1.1 Temp°F PH LOSUaF400D CLE UC CL3t M047 Owffdll Pad t PPg 2 PPg 3 PPg 4 PPg 5 PPg rH�lmin: al Cmow PMlllpf <Inps� iMi° Fann 15IDne 5 118 a `111111111111111111111111111111 ,111■■■/I♦�/♦1��■/��1/1■■■■■ 111 1-1 111111111�11��1��111 „■■■■■■■■■■■■■■■■■■■■1■■wo■■■■'I rm.lmin: ml I La N.m ,— PH WSORFJ D CL -22 UC CW1 Mod] 00ifl"I Pad 1 PP9 84 9.90 2 PP9 3 PP9 74 10.00 4 PPg Cona[o Vh11Y0s<IaaYa-3MJ0 Poen lS Zoned 119 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date:_ Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s):_ BHST CF): 166 Water Source:_ Depth: 6600 Water pH:_ Formation: ASand Hydration PH:_ Analyst: 9•X/wAd Hydration Visc: Dpd a `111111111111111111111111111111 ,111■■■/I♦�/♦1��■/��1/1■■■■■ 111 1-1 111111111�11��1��111 „■■■■■■■■■■■■■■■■■■■■1■■wo■■■■'I rm.lmin: ml I La N.m ,— PH WSORFJ D CL -22 UC CW1 Mod] 00ifl"I Pad 1 PP9 84 9.90 2 PP9 3 PP9 74 10.00 4 PPg Cona[o Vh11Y0s<IaaYa-3MJ0 Poen lS Zoned 119 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 36 Crosslinked Fluid Report Fluid System: Date: 91241201 Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s): 6 BHST VF): 166 Water Source: 2M-40 Depth: 6600 Water pH: Formation: ASand Hydration pH: Analyst: 9. Malin" Hydration Visc: -pe Mid islatmenaf A Zone 5 Crosslink Tests wpb —Ippg —2m —3m —4Ppg —5PP9 Time lm .seal All cliemlcW m-aMrMlons b,J w are ingailena W mo -and I pounds peemaeuno Ld Num.— LOT NUMBER Tempi W64fl Te1npoF PX LOSURF4000 CL4UUC CW1 .7 Opggo-Ill Pad test 1 Pad 111010111=10 1 PP9 2 ppg test 2 2 ppg 84 10.00 3 PP9 I IN 3 PP9 "MIN 4 PP9 4 PP9 A nnn Soon 78 10.10 ,,,,,,,,,,,,,,,, FallInmrom Time lm .seal C—w Philips Natal - lM-90 I— t, IDa.1 120 All cliemlcW m-aMrMlons b,J w are ingailena W mo -and I pounds peemaeuno Ld Num.— LOT NUMBER Tempi W64fl Te1npoF PX LOSURF4000 CL4UUC CW1 .7 Opggo-Ill Pad test 1 Pad 1 Ppg 1 PP9 2 ppg test 2 2 ppg 84 10.00 3 PP9 3 PP9 4 PP9 4 PP9 A nnn Soon 78 10.10 C—w Philips Natal - lM-90 I— t, IDa.1 120 M0 wo So 1° Zone 6 Crosslink Tests QPM �1PP9 �2PN —2PP9 —4 pP9 �5PP9 ALASKA DISTRICT LABORATORY 16 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No: Well Name: 2M40 Stage(s):_ BHST VF): 166 Water Source:_ Depth: 6600 Water PH:_ Formation: A -Band Hydration pH:_ Analyst: J. Mdvv" Hydration Vise: -P4 M0 wo So 1° Zone 6 Crosslink Tests QPM �1PP9 �2PN —2PP9 —4 pP9 �5PP9 rimsl"1n:sw1 L. Nu.. —+ PN LOSURFd000 CL -22 UC CL41 M047 .,HwPu1 owl Pad 1 PP9 2 PP9 3 Ppg 88 10.00 4 pP9 5 pp9 6 pp9 C,—Mllllps Nasw 2N Fann 11.n.. u1 I INS ,■,,,,,,,,111001111111 ,,, 1 Emilio in 11111111101101 .0101111111 rimsl"1n:sw1 L. Nu.. —+ PN LOSURFd000 CL -22 UC CL41 M047 .,HwPu1 owl Pad 1 PP9 2 PP9 3 Ppg 88 10.00 4 pP9 5 pp9 6 pp9 C,—Mllllps Nasw 2N Fann 11.n.. u1 flNd w Ann. .12W, Zone 7 Crosslink Tests DPW 2PM —39M —4 pP9 �5pP9 2 S HALLIBURTON ALASKA DISTRICT LABORATORY 16 Minute Farm Model 36 Crosslinked Fluid Report Fluid System: Date: f Company: ConocoPhlllips Project No:_ Well Name: 2M-40 Sol BHST (nF): 165 Water Source: _ Depth: 6600 Water PH:_ Formation: A -Sand Hydration pH:_ Analyst: Aara4oP&6 Hydration Vise: cpg flNd w Ann. .12W, Zone 7 Crosslink Tests DPW 2PM —39M —4 pP9 �5pP9 2 S Tinge ung secl All chemical concon,11cn: Cel—. in yenons Perticuund I PwM. PerlhoOaaW La Number—+ Temple PH LOeHeF4000 CL -220C C141 MOAT 0011o411 pad 1 ppg 78 10.10 2 PP9 3PP9 4 PP9 5 PP9 77 10.10 Fann 1S Tani 122 ,' . '. ,1111111111111111111111'11111 MINIMUM _111,1111„11111111'1111111„1 11111'111111111111111111111111 Tinge ung secl All chemical concon,11cn: Cel—. in yenons Perticuund I PwM. PerlhoOaaW La Number—+ Temple PH LOeHeF4000 CL -220C C141 MOAT 0011o411 pad 1 ppg 78 10.10 2 PP9 3PP9 4 PP9 5 PP9 77 10.10 Fann 1S Tani 122 ALASKA DISTRICT LABORATORY 16 Minute Fann Model 36 Crosslinked Fluid Report Fluid System: Date: 9126/201 Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s): 8 BHST (PF): 166 Water Source: 2M-40 Depth: 6600 Water pH: Formation: A -Sand Hydration pH: Analyst: % Me6po0Pk Hydration Ysc: -p@ La x�n,e.r� "ui°""'°kst,at 0P Zone 8 Crosslink Tests — 2M —RPP] —4 pp9 —5 PP9 uo wo PH LOSURF41ND CL32 UC CLJ+ M047 pad I ppg 78 10.10 2 pp9 3pp9 4 pp9 5 pp9 77 10.10 6 ",,,,,,,,,,,,,,,,,,,,,,,,,,,, ,,,,,,,,,,,,,,,,,,,,,,,,, ,'iMuNia... ��WENINNOWNEi „_1_111,_ ■1■�::�■t■■1■111■49=9 miss ,son ■1�0,0■N� ■1■1■1■1111■1■ soon ,,,11111,11, ,11111,11,111, M■■■MEN■E■M NN■■■■■■N■■■■■■■■■ Optnfl ll <won PMllipsAbstr -3M 40 Fsn 352ane8 l23 ALASKA DISTRICT LABORATORY 15 Minute Fane Model 36 Crosslinked Fluid Report Fluid System: 'n 0 i °fe6v of 0°° Zone 9 Crosslink Tests —Pm �I PN —2M —3m �4pP9 —5Pp9 All cNemleal wrczmrrtune IRkW are In Pell—P Lw N"n,Ner Temv F WGd LOSURF400D CL42UC CLaI 4087 ooiMll Pad 1 ppg 2 pp9 3 ppg 4 ppg P .0 Fermv"um Ti.. Imm:ax) I.— 14,11,n a:4.� .�. nn. 115 n.s l' ua I Date: 9124/2 Company: ConocoPhiliips Project No: Well Name: 2M-40 Stage(s): 9 BHST ("F): 166 Water Source: 2M - Depth: 6600 Water pH: Formation: A -Sand Hydration pH: Analyst 9• *do" Hydration Vise: cp 'n 0 i °fe6v of 0°° Zone 9 Crosslink Tests —Pm �I PN —2M —3m �4pP9 —5Pp9 All cNemleal wrczmrrtune IRkW are In Pell—P Lw N"n,Ner Temv F WGd LOSURF400D CL42UC CLaI 4087 ooiMll Pad 1 ppg 2 pp9 3 ppg 4 ppg P .0 Fermv"um Ti.. Imm:ax) I.— 14,11,n a:4.� .�. nn. 115 n.s l' ua I ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: . Nu.M —+ Pad 1 ppg 2 ppg 3 pp9 4 ppg 5pp9 ■■■■0000000000001 ■■■■■■■■■■■■■■■■■■■■■■� 00000 ENEE'■��■��■■�� I am NW W'.CO W'.CO 0700 DOW 09M 10.00 110 12:00 13:M T (.m:F ) MG s LOSURFIWD 0622 U0 CLJ1 MOdi Optuwa r. _,,,1-11.o.m IIs Date: Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s): BHST ff): 166 Water Source: Depth: 6600 Water pH: Formation: ASand Hydration pH: Analyst: 7. Ma6aa6p6 Hydration Vsc: . Nu.M —+ Pad 1 ppg 2 ppg 3 pp9 4 ppg 5pp9 ■■■■0000000000001 ■■■■■■■■■■■■■■■■■■■■■■� 00000 ENEE'■��■��■■�� I am NW W'.CO W'.CO 0700 DOW 09M 10.00 110 12:00 13:M T (.m:F ) MG s LOSURFIWD 0622 U0 CLJ1 MOdi Optuwa r. _,,,1-11.o.m IIs Analyst- .y. Maio," Hydration Vise: cp@ Loi xomner Pad Testt 1 PP9 P PP9 3 PP9 <PP9 5pP9 `"'tl„btak..'pdeP Zone 11 Crosslink Tests —Pad —1 Pp9 —2M —3 PN —4 ppg —5 ppg I2M 1000 'o a00 D 600 3 aee S 200 0 no st. — NI chemic concentrYbns mlow arc M gallons Pm thousand wG.X LosuRF0(s) CL32 uc slat M081 opinath Cena[nrhhim,uadU 1. no. 11 zuneu 0700 mad 0900 1000 11:0 12M Timc(min:.) ALASKA DISTRICT LABORATORY 15 Minute Fann Model 36 Crosslinked Fluid Report Fluid System: Date: 1 Company: ConocoPhillips Project No:_ Well Name: 2Md0 Stage(s(:_ BHST(PF): 155 Water Source:_ Depth: 6600 Water pH:_ Formation: A -Sand Hydration pH: Analyst- .y. Maio," Hydration Vise: cp@ Loi xomner Pad Testt 1 PP9 P PP9 3 PP9 <PP9 5pP9 `"'tl„btak..'pdeP Zone 11 Crosslink Tests —Pad —1 Pp9 —2M —3 PN —4 ppg —5 ppg I2M 1000 'o a00 D 600 3 aee S 200 0 no st. — NI chemic concentrYbns mlow arc M gallons Pm thousand wG.X LosuRF0(s) CL32 uc slat M081 opinath Cena[nrhhim,uadU 1. no. 11 zuneu 0700 mad 0900 1000 11:0 12M Timc(min:.) 111 rV29 I 1. 01 in - ----- Sao 7t, OB:CO WW Sam 11:. t2r, 13:oU 140] Ss rim.ImiR:.�i LOS N—Wr� Aloha IcW PH LOSURF. D CL@UC CL41 M 7 OptifloAN pad 1 pp9 78 10.10 2 ppg 3pp9 4 pp9 5 pp9 77 10.10 ConttopMllips Plaska iMM F. -111—U "I ALASKA DISTRICT LABORATORY 16 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s):_ BHST (°F): 155 Water Source: _ Depth: 6600 Water pH:_ Formation: A -Sand Hydration pH:_ Analyst: 9Wfin" Hydration vsc: epg 111 rV29 I 1. 01 in - ----- Sao 7t, OB:CO WW Sam 11:. t2r, 13:oU 140] Ss rim.ImiR:.�i LOS N—Wr� Aloha IcW PH LOSURF. D CL@UC CL41 M 7 OptifloAN pad 1 pp9 78 10.10 2 ppg 3pp9 4 pp9 5 pp9 77 10.10 ConttopMllips Plaska iMM F. -111—U "I Ruldls"° at' p Z 41 C 1' k T u Nume.r—, Waw losuRFa0)0 Cut uc cw1 MOL1 OMlsmw Pad 1 ppg 2 Ping 3 ppg 4 ping 5PP9 one ross In eats —Pae —1 M —2 PPP —3 Ping —4 ppg —5 pW I Paull. Wihousmd Tim.(min:s ) m.... FneuP.ni.:M-2M..o F... Zz. ue ALASKA DISTRICT LABORATORY 16 Minute Fann Model 35 Crosslinked Fluid Report WI Fluid System: Date: 9/26/2019 Company: ConocoPhillips Project No: Well Name: 2M-40 Stage(s): 13 'n 40i BHST (PF1: 155 Water Source: CPF 2 L' S Depth: 6600 Water pH: � S Formation: A -Sand Hydration pH: Analyst: I WA6 r" Hydration Viso: cp@ t01 u Nume.r—, Waw losuRFa0)0 Cut uc cw1 MOL1 OMlsmw Pad 1 ppg 2 Ping 3 ppg 4 ping 5PP9 one ross In eats —Pae —1 M —2 PPP —3 Ping —4 ppg —5 pW I Paull. Wihousmd Tim.(min:s ) m.... FneuP.ni.:M-2M..o F... Zz. ue Fwa; b.-.r100cp i Zone 14 Cross6nk Tests —Pea —1 ppa —� ppo —3 ppg —d PP9 —6 PP9 ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ Ew��G�C��C�CC�� rm.lmm:s..l All cMmlcal CDmemstllMs bvl Lot NumGel— 1e p7 WC:,IB LOSORFd D CL-IIDC CLd1 M043 Pad 1 Ppg 2 pPg 3 PPg d Ppg 6ppg OpllaoJll Cano[o PMIIIps PhsMa-lM fO F-152ane 14 ALASKA DISTRICT LABORATORY 16 Minute Fan Model 36 Crosslinked Fluid Report Fluid System: ua Date: 9/26/2019 400 Company: ConocoPhillips Project No: ssa Well Name: 2M-40 Stage(s): 14 3N BHST (pF): 166 Water Source: CPF 2 of � Depth: 6600 Water pH: xool Formation: A -Sand Hydration pH: ; t5q Analyst: y..Mahow" Hydration Vise: cp IWl i Zone 14 Cross6nk Tests —Pea —1 ppa —� ppo —3 ppg —d PP9 —6 PP9 ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ Ew��G�C��C�CC�� rm.lmm:s..l All cMmlcal CDmemstllMs bvl Lot NumGel— 1e p7 WC:,IB LOSORFd D CL-IIDC CLd1 M043 Pad 1 Ppg 2 pPg 3 PPg d Ppg 6ppg OpllaoJll Cano[o PMIIIps PhsMa-lM fO F-152ane 14 Lol xumM, .6 LOSURFdWD CL- UC CLi1 Pad I pPg 2 ppg 3 ppg 4 ppg 5ppg 16 r"1tl" k° a21W p Zone 15 Crosslink Tests �vae —1oW �2w, —a ec& —4 ppg �5PP9 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 36 Crosslinked Fluid Report Fluid System: Date: 1 Company:_ ConocoPhillips Project No: Well Name: 2M40 Stage(s):_ BHST(eF): 155 Water Source:_ Depth: 6600 Water pH:_ Formation: A -Sand Hydration pH:_ Analyst: Rdr.6er%fi Hydration Visc: cpS Lol xumM, .6 LOSURFdWD CL- UC CLi1 Pad I pPg 2 ppg 3 ppg 4 ppg 5ppg 16 r"1tl" k° a21W p Zone 15 Crosslink Tests �vae —1oW �2w, —a ec& —4 ppg �5PP9 M047 OpnfloA Conan VMlllpi Alahe � 2M -,c fann]Slene l5 rima (inin: a ) cemwe cermeanae ... i' .................... mmE7 ..on IBMon M047 OpnfloA Conan VMlllpi Alahe � 2M -,c fann]Slene l5 rima (inin: a ) cemwe cermeanae sw F3•. 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B1 5103.33 15 513046 Y a Puff Nat Treatment }roalment lnbm110 ]]4]54 65646 4NI2A5 XMS a Pad P41,02 16.1 5093 95 43 11:.:01 BaII on Yat Bell on Stet u141 34 4]888] 512691 H ]135:09 Oreak Fomb<bn ..ak formal].. ).08-00 ).868 13 43 3N119 504851 3 N40 NM Aa a ]. 20/. at BIW.94674244 49 33 6538.5 ]551.9) 3 l2:OP.]B Natl Sbe }.4 for. µa.11 81®61 6823 4 1):56:39 Nett S4 341 3040 Wanll Y..1 X08621 33.1 413.6) s ])56.48 HMS a..INgp 8401.♦ 635955 6336.36 4820] 6 1 00:3] nt St.— xx00 - a,... 5]88 .3!09 33.3 53)415 18 NenI SR a 0 8555.6 61..73 63695.9 3333.1] ]817AS an . 344,x6 552213561899 38:33:4]Frc Nni sla Flush 889385 6.5.31 6003]4 125 SR9.6 10:}5:33 a eb Proteq 91471 36 6440 I45 6551.0] 309 51.-01 13; 21 A3 ]SIP NeM SR ]SIP 4f).% NE6.49 3486 0 OY!33 19:09:45 End 1pb sF upin /or FEi MaI la FMtne Inn 4a7.86o u.... ]93fi _ __ t]29]3 0 4533E HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2069584-1 Customer: ConocoPhillips Well Name & Number: 2M-40 Fluid System: Hybor G Date: September 19, 2019 Technician(s) Performing Testing: Jason Reviewed & Approved By: 19063 31301 THE SL._E 01ALASKA GOVERNOR MIKE DUNLEAVY Scott Pessetto Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-40 Permit to Drill Number: 219-063 Sundry Number: 319-407 Dear Mr. Pessetto: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.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, essi�hmielowski Commissioner DATED this I I day of September, 2019. 3BDMS7� SEP 12 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑� • Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development ❑� • Stratigraphic ❑ Service ❑ 219-063 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20804-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU 2M-40 - Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025586', ADI -025585' ADI -025590 Ku aruk River Field, Ku aruk River 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): 21,245 6,177 21,201 6,177 7,550 Casing Length Size MD TVD Burst Collapse Structural Conductor 139' 20" 176' 176' Surface 2,928' 13 3/8" 2,965' 2,653' Intermediate 1 13,451' 95/81, 13,486' 5,806' Intermediate 11 1,025' 7" 14,283' 6.075' Liner 7,103' 4 1/2" 21,201' 6.177' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 1/2" L80 14,095' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Baker Premier Packer, No SSSV 13,892' MD, 5984' TVD 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 mrk: Commencing Operations: 9/16/2019 OIL [D WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: 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. Contact Scott Pessetto, 907-263-4523 Email scott.t. essettO Conoco Philli S.com Printed Name Scott Pessetto Title Completions Engineer /& i8eoemt' i Signature Phone 907-263-4523 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 313pMSr;�`"VSEP 12 2019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: ti APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: v Form 1Q 03 Revised 11/2015 V' L- ydpp'W ed application i li r 2 h fr m he ate of approval. �w 9/40120 s --411,714 1 R4'_ NA I Submit Form and Anachme sin Duplicate g�f /o �/ 2h. 40 Final Wellbore Schematic �✓ Producer w/Frac ConocoPhillips Updated: 9/6/2019 by S. Pessetto Conductor Installed: 20" set at 176' MD 16" Surface Hole lvfl Landing nipple (DS), 2.813" at 2,151' MD Tu in : 3-'h" 9.3N L-80 EUE 8rd 74°Tangent 12-1/4" Intermediate Hole 8-1/2" x 9-7/8" Intermediate Hole Surface Casing: Below West Sak 13-3/8" 68M L-80 Hydril 563 2,965' MD / 2,653' TVD Frac Sleeve Depth, MD 15 14,525 14 14,990 13 15,455 12 15,942 11 16,187 10 16,798 9 17,264 8 17,729 7 18,195 6 18,703 5 19,385 4 19,809 3 20,190 2 20,836 1(Perf Pup) 21,189 6-,� IMC 40%&xc, &11175tMb %1101 )1`,e, HRD-E ZXP Packer 7" x9 5/8" Flex -Lock liner hanger 13,258' MD / 5,692' TVD `60' Intermediate 1: 9 5/8" 47p, L80, HYD 563,13,486' MD/5,806' TVD 5&,k. Scope. shows GooQ caovw.A, bee" 71' 14cr; Ll ar wlt( iUC �J Lros4,.P 1323'�°'MD. Loi Landing nipple (D5),2.75" w/ dual flapper installed at 13,921' MD DHG @ 13,774' MD / 5930' TVDPremier Packer @ 13893' MD HRD-E ZXP Packer ' 7" x 4-h" Baker Flex Lock Liner hanger 14,120' MD / 6,045' TVD `76' Intermediate 2: 7" 26tf, L80, Hydri156314,283' MD/6,074' TVD 6-1/8" Production Hole 21,245' MD / 6178' TVD 5-%"Swel1 Packers- for fault isolation Ball Activated Frac Sleeves Production Liner: 4-1/2" 12.66 L-80 HYD563 21,201' M D/6,177 TVD it AA fl 3jk1,4 Section 1 -Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). art TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K. Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2M-40 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA m THIRD JUDICIAL DISTRICT Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton, and I have personal knowledge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations CNotice"). 4. On or about September 5, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 5'^ day of September, 2019. Paul K. r-r.r STATE OF ALASKA THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 51' day of September, 2019, by Paul K. Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBI_1 ' REBECCA SINENSEN MI! rawniasion Ex me Au . 2t, 2640. ConocoPhillips Alaska Paul K. Wharton Staff Landman P.O. Box 100360 —Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone(907)263-4076 Paul. K. W harton@conocophillips. corn To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2M-40 Well Kuparuk River Unit, Alaska ADL 25586, ADL 25585; and ADL 25590 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAP') as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2M-40 Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about September 5, 2019. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, ooa4_� A/. 1_4AZ.V�J Paul Wharton Staff Landman cc: Scott Pessetto Rebecca Swensen 21A-40 Hydraulic Fracturing Notice Letter September 5, 2019 Page 2 Exhibit 1 o� o at i ADL025571 Mti ADL392628 ; ADL -0503 >i Kuparuk River Unit =i----�` ADL025586 Ct 41 a�nj N lop/ CI g � 0 9 t 7 A1.36 pM-361.8.1 \ j 2M,37�3 1M,03MY 0 1 71de1 2M25 M t' ADL025585 dU ti2M\M24 t 2M-38 y M1 ^ r t i ADL025589 i o � m Ce • Frac Ports M r p I - Well Trajectory 2 I ADL026590 j - Open Interval i Wells within Trajectory Radius 1 j Half Mile Frac Port Radius 1 i Q Halt Mile Well Trajectory Radius 1 CPAI Lease BRPC Lease ConocoPhillips Alaska ADL025603 'S N 2M-40 ADL380051 Lease Plat 0 0.2 0.4 0.6 0.8 Miles 9/512019 210-40 Hydraulic Fracturing Notice Letter September 5, 2019 Page 3 Exhibit 2 Mineral Owners Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Misty Alexa, Manager NS Development Non -Operators: ConocoPhillips Alaska II, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Misty Alexa, Manager NS Development Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Ms. Lisa Cross Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within 0.5 miles o =, eADLO25571 nt� ADL392629 ; ADL390603 J Vr i Kuparuk River it I ADL025596 OI 'JJ:I:W A436 b 2_� %IZT ADLO25586 IM ?.� 21A-30 I z G ry 1 v _ TJINRBE a fiGNR8r- 1 � jADL025689 11 m m a m I / • =rec Pal 'r pQ -',1@Il Trepakry I / ADL025590 Open Interval i i r -5ltira v,tlein Trapclay Wdita -Idf 1163 Frac Put Radius 6 lett Afik. WNl irejecmry ReEsls ' r CPAI Lease i LIQ'_ ConocoPhillips ' iNo ADLO25603 N \ ADL36005t \, LeaseasePlat A --- __ o 0.2 — o.a 0.6 a.e — ---MMMMKz===IMMMr=MIIuS M:2019 Table 1: Wells within .5 miles Wells within 1/2 mile buffer of well track Data from SDE laver: AK WELL BOTTOM TD ATDB DD83 Port IAPI J-WELLNAME j Status 1_ jTyPe J. Rados 501032018500 2M-01 SUSP PROD no 503032017900 210-02 ACTIVE INJ no '501032016000 2M-03 ACTIVE INJ no '501032018200 2M-04 ACTIVE INJ no '501032016800 2M-05 PA INJ no '501032017600 2M-06 ACTIVE INJ no '501032017800 210-07 ACTIVE PROD no 501032018400 210-08 ACTIVE PROD no '501032018463 2M -08L1 ACTIVE PROD no '501032018464 210-0811-01 ACTIVE PROD no '501032017700 2M-09 PA INJ no '501032017701 2M -09A PA INJ no '501032015700 210-10 ACTIVE PROD no '501032015900 2M-11 ACTIVE PROD no '501032018100 2M-12 ACTIVE PROD no '501032016100 2M-13 ACTIVE PROD no '501032017300 2M-14 ACTIVE INT no 501032015400 210-15 ACTIVE PROD no '501032015300 210-16 ACTIVE INJ no '501032015000 2M-17 ACTIVE INJ no 501032015100 2M-18 ACTIVE INJ no 501032015800 2M-19 ACTIVE INJ no '501032016900 2M-20 ACTIVE PROD no '501032015600 210-21 ACTIVE PROD no '501032017000 210-22 ACTIVE PROD no '501032015500 2M-23 PA DISP no '501032017100 2M-24 ACTIVE PROD no 501032015200 2M-25 ACTIVE PROD no 501032017200 2M-26 ACTIVE INT no '501032017500 2M-27 ACTIVE INJ no '501032017400 2M-28 ACTIVE PROD no 501032018300 210-29 ACTIVE PROD no '501032018000 2M-30 ACTIVE INJ no 501032024100 2M-31 ACTIVE INJ yes 501032018600 2M-32 ACTIVE PROD no '501032018660 2M-321-1 ACTIVE PROD no 501032018661 2M-3211-01 ACTIVE PROD no 501032018670 2M-32L1PB1 PA EXPEND no '501032018671 2M-32L1PB2 PA EXPEND no '501032024000 21033 ACTIVE PROD yes 501032024200 210-34 ACTIVE INJ no '501032024300 2M-35 ACTIVE INJ no '501032069100 2M-36 ACTIVE PROD no 501032069170 2M-36PB1 PA EXPEND no '501032074500 2M-37 ACTIVE INJ no '501032074600 2M-38 ACTIVE PROD yes 501032079500 210-39 ACTIVE PROD yes '501032079570 210-39P81 PA EXPEND yes '501032079000 2M-41 ACTIVE PROD no '501032073300 25-14 ACTIVE PROD yes SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a''/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field". SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 13 & 3/8" casing cement pump report on 7/24/2019 shows that the original job pumped as designed but did not get cement returns to surface. The cement job was pumped with 11 ppg DeepCrete lead and 12.Oppg tail cement, displaced with 9.5ppg mud. The plug bumped at 330 psi and held 853 psi for five minutes. Due to no cement returns to surface a top job of 38.1 barrels of 11 ppg Deeperete was pumped after tagging top of cement at 176'MD. The combination of holding 853psi on the original job and a top job indicate competent cementing operations. The 9 & 5/8" casing cement report on 8/10/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 140.2 barrels of 15.8ppg class G cement. The cement was displaced with 975.7 barrels of 10.5ppg LSND drilling mud. The plug bumped at 712 psi and continued to pressure up to 1200 psi for five minutes. The floats were checked and they held. The combination of holding 1200psi and holding floats indicate a competent cement job. The 7" casing cement report on 8/16/19 shows that the job was pumped as designed. The first stage cement job was pumped with 65 barrels of 15.8ppg class G cement. The cement was displaced with 331 barrels of 10.5 LSND drilling mud. The plug bumped at 1,020 psi and was then pressured up to 3000 psi for five minutes. Floats were checked and they held. The combination of holding floats and holding 3000 psi for five minutes indicate competent cementing operations. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 7/27/2019 the 13-3/8"" casing was pressure tested to 3,000 psi for 30 minutes On 8/12/2019 the 9-5/8" casing was pressure tested to 3,500 psi for 30 minutes. On 8/19/2019 the 7" casing was pressure tested to 3,500 psi for 30 minutes. The 3.5 tubing will be pressure tested to 4,700 psi prior to frac'ing. The 7" casing will be pressure tested to 3,850 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,550 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7" Annulus pressure test 3,850 3-1/2" Tubing pressure Test 4,700 Nitrogen PRV 8,550 Highest pump trip 8,050 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size .-Weight Grade API Burst API Collapse 13 & 3/8" 68 L-80 5,020 2,260 psi 9 & 5/8" 47 L-80 5,745 psi 3,086 psi 7" 26 L-80 7,240 psi 5,411 psi 4.5' 12.6 L-80 8,430 psi 7,500 psi 3.5 9.3 L-80 10,160 psi 10,540 psi Table 2: Wellbore pressure ratings eland r Tana Tale Tar* Stimulation Surface Rig -Up Frec Pump 4 a S • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV Iii PaPOR rw* Pump Tna* Frac Pimp Frac Pune Cd..d U `m a 0 POP -Oa Talk gi> FJ 1 Frac Pump Frec Pump 4 a S • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV Iii PaPOR rw* Pump Tna* Frac Pimp Frac Pune Noe: Dimensional infamodon reflected on rlds drawing are estimated measurements only. 13 Kuparuk 1 OK Frac Tree 4' IOK Valve + Thee Cap — 395- 4' 10K Valve +,r 10K a 4" 1002 — 32.25" Con ocoPhil lips Drill Site 2S- I OK Frac Tree Weight of entire tree is—6,2001bs 4" IOK HWO Valves—8601bs Thee Cap —250 Is I CAMERON SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Kuparuk interval is approximately 105' TVD thick at the heel of the lateral, and there are no significant changes to thickness along the lateral. The Kuparuk interval thickness is derived from the partial penetration in the 2M-40 lateral and the partial penetration in the 2M-39 lateral in addition to offset well thicknesses in the 2M drill site. The Kuparuk Interval is composed of medium and fine-grained sandstones, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 13.1 ppg. Top Kuparuk was penetrated at 14,222 MD /-5,930 TVDSS. The overlying confining zone consists of approximately 350' TVD of Lower Kalubik, Upper Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 16 ppg. Top HRZ was encountered at 13,395 MD / -5,638 TVDSS. The underlying confinement zone consists of greater than 500' TVD of mudstones comprising the Miluveach Shale. The estimated fracture gradient for the Miluveach Shale is 15.5 ppg with fracture gradient increasing with depth. The Top Miluveach was not encountered in either the 2M-40 lateral or the recently drilled 2M-39 lateral. Based on offset thicknesses, the top Miluveach is projected to be between 6040'— 6130 TVDSS along the length of the lateral. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2M-39: The 7" casing cement report on 6/22/2019 reported full returns throughout the job. The cement job was pumped with 125 barrels of 15.8ppg Class G cement and displaced with 429 barrels of 10.8ppg LSND. Plug was bumped to 1500psi and floats held. 2M-38: The T' casing cement report on 1/31/2017 reported full returns throughout the job. The cement job was pumped with 67 barrels of 15.8ppg Class G cement. Plug was pumped to 1,100pis and the floats held. 2M-31: The 7" casing rig report on 05/09/1996 reported full returns throughout the cement job. The cement job was pumped with 230 sacks of Class G cement. The well last had a passing MIT -IA on 2/27/2017 to 3200 psi. 2M-33: The 7" casing rig report on 4/17/1996 reported full returns throughout the cement job. The cement job was pumped with 250 sacks Class G Cement. The floats were checked and held. The well last had a passing MIT -IA on 8/22/2017 to 2800 psi. 2S-14: The 7-5/8" cement report on 7/29/2016 reported full returns throughout the job. The cement job was pumped with 63 barrels of 15.8 Class G cement and displaced with 9.6 LSND mud. Plug was bumped to 1700 psi for five minutes and the floats held. Ar Y N r � Efa e� e.S �8 Fr e8 E n F, O - a z = � Ss U V U A — $ tR lg U O u� V F ut in in N in in t V F a a" a o 0 o i o O F 3 r SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that nine faults or fracture systems transect the Kuparuk formation or enter the confining zone within one half mile radius of the wellbore trajectory for 2M-40. • The first and second faults were not penetrated with the 2M-40 well bore but are interpreted in seismic data and expressed in the Kuparuk section to the northeast of the 2M-40. The first and second faults have down to the north throws of 30' and 20' respectively. • The third fault was interpreted from seismic data prior to drilling as intersecting the reservoir in the Kuparuk section —550' east of the drilled well path but showed little expression in the wellbore above the overlying confinement zone where it was crossed. This fault is —550' to the east and parallel to the 2M-40 drilled well path for the entirety of the lateral, with a down to the east throw of 40 — 50'. • The fourth and fifth faults were interpreted from seismic data prior to drilling as one fault and confirmed with log data while drilling as a fault zone with two discrete faults at 16,400' MD (fault throw of 10') and 16,535' MD (fault throw of 10') for a combined throw of 20' down to the north. • The sixth fault was mapped with seismic data prior to drilling and confirmed with log data while drilling while drilling at 19,065' MD with a fault throw of 5' down to the south. • The seventh fault was mapped with seismic data prior to drilling and confirmed with log data while drilling at 20,492' MD with a fault throw of 5' down to the north. • The eighth fault was crossed in offset horizontal lateral well 2M-39 with a throw of 5' down to the north, was not crossed in the 2M-40, but is projected to be 625' south of the 2M-40 TD based on seismic data. • There is an additional ninth fault with a down to the north throw of 16' that is located —1,950' south of the TD of the 2M-40 lateral. This fault was crossed with the offset horizontal producer well 2S-14. Fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Maximum principle stress orientation in the area for the Kuparuk interval is N30W to N1 5W and hydraulic fractures are expected to propagate at an oblique angle 25 — 35 degrees to the drilled wellbore. Faults observed in the wellbore and in seismic data will be isolated with swell packers and blank pipe and we do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Fault Well Depth Depth Vertical Loss number Name MDft ( ) TVD55 ( ft ) Displacement (bbls/hr) (ft) 2,150' 1 northeast N/A N/A 30 N/A of 2M-40 1,250' 2 northeast N/A N/A 20 N/A of 2M-40 3 550' east N/A N/A 50 N/A of 2M-40 4 2M-40 16,400 6002 10 None 5 2M-40 16,535 6004 10 None 6 2M-40 19,065 6020 5 None 7 2M-40 20,492 6044 5 None 625' 8 south of N/A N/A 5' N/A 2M-40 TD 1,950' 9 south of N/A N/A 15' N/A 2M-40 TD Plat 2: 2M-40 Fault Analysis G nth ADL392628 ADL3905D3 ADL025571 D 1D4:.I Kuparuk River Unit s; cl t. 'o yi to °f m -+ •- . _ ADL025686 2M J y F- ADL0255a5 .--�� 2M�qTwv ^_r Q A to .a i 1 i 1 f � I 1 4 l I 1 f o� • =rac Pots m n 1 —'del; vafe_kvy � C I. �Open lnWol ADL025590 1. Wch, Mihir Fmc POII Radius 1 W.II1M1 F'&: �M R9.113 1 � �Wf ilia Fac?crl Radius 1 Q self Mio Well ire]ecmry Radus 1 + CPA]Lease - r ConocoPhillips -- wsy<e �� ADLO25603 N ��_ 2M-40 ADL381051 Fault Analysis A --_ _ 0 0.2 0.4 0.6 0.8 '- ®Miles x5:2019 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2M-40 was completed in 2019 as a horizontal producer in the Kuparuk A and C formation. The well was completed with a 3.5" tubing upper completion and 4.5" liner with ball actuated sliding sleeves lower completion. The first stage will be pumped through a perforated pup in the toe of the lateral. After the V stage we will drop a ball to shift open the 2nd stage sleeve and isolate the first stage. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Kuparuk A/C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 24,000 barrels are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU HES Frac Equipment. 6. PT Surface lines to 9,500 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. 9. Pump the 310 bbl breakdown stage (30# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following attached HES schedule @ 30bpm with a maximum expected treating pressure of 7,550 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). NSEDMEP (gnxo%illl�paNxYa qPl E0�1033WW BED(R/9a1( 65a M•ia' p w Ipi 3033193<P8 Conoco Phillips Alaska - 2M-40 Planned Design C0530MER IgNWa API E0.10}2CBW Of0(M/9a1( 6.59 IAT M2718NM .11 SALES ORDER 6611'"1 1 X M "-' EONO .150097E613 FORM"ON CMSatl GATE Mea P,easu. 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SW 30 5000 119 1. 25 W] 00452 011:13 IW 050 100 W 015 0.25 bor6 P .Laden Fluid Wan1120 40 6 W 30 4700 112 143 Dodds 0:06:20 ] W 0.50 1 W 050 3000 015 360 035 9.8 11,I tl30H bor6 Sroat ranb BalldreP a 151000 2d 24 003:35 001:35 SD] 050 1f0 050 30 W 3000 015 0.15 3 W 025 0,25 101 MHluR Ped 3p 15003 $52 357 0:1154 3:O 15 m 050 1. 050 30.00 015 3.00 163 p30N bore pro and latlen Fluy [,1120. ID 30 3]00 76 DO 3200 00739 0:55:15 303 0.50 SW 0.50 30.00 035 t03 p30H bor6 P ant Latlen Flultl Wan113p. 200 30 33. 79 86 6. 00251 0:52:36 3M DID 1.. 0.50 0.15 2.00 035 a Y 164 tl30H here pro a IUtlen Flub WanIi2D. 30 509 319 135 ]$tl0 04:31 0:49:45 S:W 0.50 l.W 050 30.00 0.15 2.00 035 a am t65 30H bore Pm a [4den Fluid Wan1120. 400 30 559 331 I55 22 W] 0'05:]0 0:15:]1 LW 0.50 100 0.50 30 p3 30.00 0.15 015 2M 200 OES 075 166 P30HborG Pro ant laden Fluii Wan1130. SW 30 S 319 t46 250.0 Od 53 O:.W SW D.50 iW P. 3040 015 200 025 10J N30H bore pro dnt4dan fluff an1120. 6.0] 3D 4]00 113 Ida 3 Lp 04;45 0:35 I3 3.00 D.00 1N 0.50 IOn 0]5 1DD I p30Waterne.GFlush 30 6 65 163 163 0M ]7 6.3027 1M 3000 015 2. 200 025 025 ® 109 Freexe P,e[en taunt 2 x1. 50 50 O2SED D:25W IW]. 025 O,Sp IP10 $nuNn SM1u,-In Conoco Phillips Alaska - ZM-40 Planned Design NS]OMER rcv PM5pUkfYa API 3610SEWW BFDll6/golf114vsureun UT J0.E)IBE4e LEASE SAIESOPOER 1111T (7) ""' LOHG-]S0.W)B61E Maa Alai[iw Paa MF Addltlw Pale Conoco Phillips Alaska - 2M-40 Planned Design 1 FORMA)IGN [,re .1 Mea Pressure 1pe0 PropWntTVpe OeYN Toial(.,1 1 Wflun. 1 10..A., 1 Ch22.0 C 31 1 LWrW 1 WG -36 1 AMMue4 OgmnF 111 OPaFloil Treatment IntervalNumber "me 11.0 OesW tion Stay Oevl Bvn Pmppant DesaI Ion Pm0 We SWrry Pale OagnOon Volume I Lmem Clean Volume b61 Ommgmgam, V.I.-TYtal Destm mop Ibf stage nam,Tlme g]r:mm:a emal XM1:mma Un.. Erratum I pt) MOb] Bator, I) Ch22 VC neWkAr 11 Cali GmT#r lr (art LV]2W inxu enlrc (apt) VI BrF. g1`6 antYaYn ra"Flo94,. OptIl g Mla Y a tatler 128,9 11-1 Shut in shutin0;46:33 11*2 X30X 5 cerend Ball aro IS SOS 24 24 0:01:35 0:46:33 050 3W 30 C0 O15 SCO (T25 IIJ X30X Establbb Stable 11.11 15 4205 IO] 1W 0W. 0:44:58 100 050 LW 050 3000 0.15 SCO 025 114 X30X MHPad 3P W 0:11;54 0:38:18 1 W 050 1 W 050 go. 015 SW 0.25 _ v= 11-5 13011MA ben Fluid Wang2Wl ].W 30 330] 76 a) 00239 02624 1W 050 I. 0.50 30O] 0.13 SO] 025 q 116 30 dnrG Pra dm Fluid Wanll3 40 2.W 30 9 06 6600 002:51 0:23:44 T. 0.50 SW aw 30OJ 0.15 2.M 025 Fr¢n ]11 tl;pXbmG Pra a den Fluld Wanll3 W 3.DJ 30 119 335 15CW 00431 0:20:53 1W 0.50 I. 050 30.W 0.35 SW 025 bvr0 Pro atLaden Fluid Wan112040 40] 30 131 355 22 WJ 005:10 0:16:22 1. 0.50 IJJ 0.50 30W 0.35 2W 025 ^M 119 P30H bor6 11,1-1 Lara, Fluid 40 30 5W0 119 146 350.0 004:52 r3; 11:13 IW I 0.50 30W 0.15 2A0 0.25 11110 P10Hb.6 and Laden Fluid 120/40 30 4)W 112 143 28EW 004:45 00610 W. 0.15 1W 0.25 1331 1S I.0.W 24 1:35 1W 0.25 ]S1 t1vtmrG 30 1505 35] 357 0:11:54 0:38:18 1W 050 LW 0.50 30W 0.15 2. 0.25 13-2 X30 m,G ant Leam, Fud W-11 101, iW 30 32W 16 W 32W SN 030 T. 0.50 30W 015 SW 0.25 lE-3 p30Ha, ant Uden Fluid emn20an SW 30 33W 79 e6 66W 44 r30 OSO Tr 0.50 30W ..Is SW 025 3d _ce 13-4 I H m .mtatlenf.M Wan112040 3.W 30 50W 119 135 1". 53 :00 050 1r 0.50 300] OI$ LW 035 133 p3DX bwG nt lahnFlrid Wan12040 IW 30 SSW 131 t55 EE 32 O.SrI IrL O50 30W O.Is SW 035 _ 116 11.11m. ant tadenf ud ammii1040 SW 30 SOS 119 146 25 OS 452 0.1333 0.50 1W 0.50 30W 015 SW 035 32-] X30X r0 nm ani taden Fluld WaM120M 6N: 30 4]CO 311 t43 202W 0:09:x5 OM:SO ]W 050 SW ..W 30.W 0.15 SW 0.25 118 X30M9batG 5r-and0aldmp 13 LOQ 24 29 Ot35 OM:35 100 050 1W 0.50 30W 015 2.W 035 33-1 P30N bor6 Pan 30 15. 33) 357 0]1:54 0:38:18 10O 0.50 1W 050 30.W 0.15 SW 015 13.2 Nl-r Pro attaden Fluid Wang 2005 l.IXl 30 32W 16 80 32W 002:39 0:26:24 IW 050 I'm 050 30W 015 3W I36 den Fluid Wang 00 2W 30 33W 79 e6 66m 002:5] 023:49 1W OW lm 050 SW 3{ -vC 13.4 Laben Fluid Wanli3 4O 3.W 30 5mm 119 ISOS 00431 0]0:53 SW 0.W 1W 0.W q It 135 30Hd Laden Fluid Wanli 20/m AW 30 S.SW 131 I55 22W 005:10 0:16:12 050 SW 050 _ 13fi u30X boG 30/40 S.m 3r1 S.00J 119 146 452 0;1]:]3 13�7 430M bor6 Itr-Flail 30 47W 112 143 381. 00445 O:G6:20 . 050 W 05D 30W 0.15 ]W 0.25 13M8 a;1 Ball dmp ]5 T'.. 14 001:35 0:01:35 lm 0.50 Im 0.50 30m 14m1 8,30 HYborG Patl 30 15. 1 317 351 1 11154 038:18 I 050 lm OW 30W 0.35 SW 025 Ip2 p3OM berG Laren Fluld Wanll3./40 1.W 30 32WIn 3 m 002;39 02614 Lm O50I I050 30 r%I 0.15 LW 0.35 3 J.Itram,G -Pmpp,nt Pm atLaden Fluid Wanli 2040 Sm 30 33W )9 86 fim 002:51 02344 1W 050 Im 0.W 30m 015 SOD 0.35 cnrs fIn RMrlbmr Pra ant laden ImItl Wanl11)140 3W 30 Sm] 1t9 135 1500-0 OA4:3] 0:30:53 ]m O.W SW 030 30m 0.15 Lm 015 Z% 5 430 bor6 Pro ..laden Fluld Wanr 20W 4W 30 SS. 131 I55 22 OM:1. 0:16:22 Lm OW lm OW 30m 015 1W 025 v6�LL 10.6 al0 mb.. Pra ant Laden Fluld We'll 20W 503 Stlq "I 146 25 OW:32 01113 1. 0.50 1m O.W 30m 0.15 1m.21 ® I6] M30XbvrG Pro ant Laden Fluld 120/90 6m m 4M 112 143 28300 OM:45 ..d D I OW 1W 050 30M 0.15 EAO 0.25 19-e 1 110 .'em. Spar and Ball bm15 1W0 39 24 091:35 001:35 Sw 0.50 LW 050 30.W Oct 2W 0.23 ISl bor6 lab 30 15 rD] 35] 357 0:11:54 1W:W T. OW Lm 0.50 30W 15.2 bor6 Pro aIladen FluM .112.. 1W 30 33m 76 80 32W ODI:39 054tfi 1.. G.W IW 0.50 30W I15 It, 15d bor6 Pro ant laden Fluty Varm"040 SW 30 33W )9 86 6K0 OA231 031:27 1. ..W 1. It 30W 0.15 3W 013 •age 15. al,Hbvr6 Pro anlladen Flu. Wan112040 3.W 30 50.0 119 135 Ss,, 094:31 IY4.5 1.. 0.50 1.W 050 30W 015 SW 025 115 #30 Hyb,,G [Laden Fluk Wmg. 40 4W 30 SSW 1st 155 2305 OA5:10 044M I.W O.W ].W 0.50 30.W 0.15 3.[0 01s ga 7 156 tLad-Fluid Wanll2(140 SW 30 T9 146 15 OS OA4:SS 038:55 1. 0.50 1W OW 30m 2,130025 015 iS) en Fluid Wan113040 6M 30 4= 112 143 M. OA4'As 0:34A2 I. 0.50 t.O.W 30W 220 025 OE5 SSB mmw:aebiFT. 1 0 5405 Il9 319 0W:17 029:3) iW 2Ap 025 0.50 Q SS9 resbut ra5but 2 21W 50 50 O35Yt 035W ILO].W 1510 rn Maa Alai[iw Paa MF Addltlw Pale Conoco Phillips Alaska - 2M-40 Planned Design 1 PropWntTVpe OeYN Toial(.,1 1 Wflun. 1 M0.6> 1 Ch22.0 C 31 1 LWrW 1 WG -36 1 BE OgmnF 111 OPaFloil SP ..It 1w. 2'.= i Team) 1 ar m) I fea)m+ Poa ma m" les Inllial Desi6^Mammal V,Imm,I 855.] I 412E I 825.3 1 4126 1 6,3 () 1 25,6704 1 128,9 1 L711.4 313.9 19.9 Maa Alai[iw Paa MF Addltlw Pale Conoco Phillips Alaska - 2M-40 Planned Design Hydraulic Fracturing Fluid Product Component In Jon Disclosure 5 n ymaraMd Blak; C..nvl uamNa:OPamcrxnwWell Name aM Naddar0Icnd.:lalnwe:.ymaa Pori.—P...,TneNnktl onam pWlro"MWMNVdum1 Httlraulla Imann, 11. Corr sdda: CM1emiral Meahnum Rbatrat MumWmin9atlNmt Ingredient trete Name Supplier purpase In9reEienta Sand. LOnuadmtlbn In Atltlixve Canwnbauanin In9mtlient Mass ColrmeMs Company Fbst'Mama Leat Name Eman ph. Number(CRS I% by mus)" HF Fluid I% by IW Pe Fnq Wale, ]]33.145 laayr.e e T]312V CmaA =flI9] fiE�6 XyliEWm Blmle IiMN Bfbv La.. Btl>.v MICROapCIOE 0 N9 II,rc —..n,r INdBebx I:Y. eYa. 0 x1 CL.31 XdaY.- Crura. LYN BM.r INM Btlav CROaaLIbma 0 N9 106V l-ano D.ticbulxtan 4d. &Vw L¢Im etlar 0 ILl M?9] XnYiEWm woormy.1ne Ina. P&w le]Obx 0 IN GPMO-11 d. Na.wm 6rmMar t,a..' t,mad w RE 0 eR.a R OP IN rO 'ED a.E NaIIbWm arMar Ya14r unarbNcw RELFME 0 Nq BR R ER WIId,rm ar Ilgp pepv 0 N4 .".R .I W6.i'i GELLING lyyurlm GeRgOpa {yy BYu Iblel Etlw RG M ny' 0 H5 LVr-3V Pmrca FrmePmM Lie1N &bv IiYei B9w 0 N1 WM w.eimwb Pnprem eeea.e uew en.re uudeHw o xa 1 Idlef aww L'a1N M+.e Iza TnnM 6 a .a]za an z.&wnoNatlol.b 6x.61.] 1$ Crmd.'U . NamWm.3m0 gmea T,dr® M.r,aa Mk^m R4rebry, 1. o.oPlnn[ 10$ N. BamlWsrm WmWm Corea TIaF %rxv E.. lbalm. Wlbirm.m ]H1d/ISld TX Mo. .1 .1. Nmma..o nn.a mu rraaeT[Xa 9aae Me PrmlNam 11 ...,,..,_. 6120 Nalleurm 0. Ye Tmk IWIRWmm .1-81-fid Cmunw lyyt ]65 IMW]3 < IYureeil4a, am lem4sc] sTa bm.er aM Coen wNK �* Prmr¢lary 60e HallfiWm manse rmk NYmunmm xeie]ImiB Ellatl U1].6 Glv SADDO aaadi seep. MN r1 46 ...3a 3Yd 2*6 rasa O.IaMe .sa7ua.9 00A Ablbe 3 sB ]1L® ry& M.2 3B OnbeTurna tyhM PlnnRc in PrcpYWy In. Ores ....,+re Z]01 Xamulm OnW 'k drxy Wmals.m mtan,MUS Pavlmv-1?nrwwoML aP." mnNWanNl ansganyarmv. 1VOP-810 sy mam. Ptlwim(amel, eepm-0 BIYI Ptlnsaml,rwtl 1310553 23] Ptlammnandarale 13]W4le mit H biamu 9Aa3N 103 boa—'aMe mi]-1L5 SWum Icdble mL3b0 ',C3� sm.m nmvna 1310T12 rndran noesis ]]3Z]-1 wIM n5/@B waer costes warn, 1m11 Tata Water vaad. enurm may... Imnmw,p..d rnday,eomm mi. vnler Imamatlonla bmWontomamum Wwbalbrwncen onaMtM Ne Md may bea'ar 1W% _ We. Far FitlJ CeMognml RONcte (goLch Pal4gn MII FCPI, MSpS laVel dJy irltom.Npn I1W pBen paN061' NIO. Wnem IMorma4on(IelMwan Gala SNeai(Memel.NaWor IM OpmWie nmraWMNe IOrieddy rare mLLb IncalLear Indect,'on MryN.a WMBmalne MSp$91.a30M'aMt0e er,adhymninsul>dialean,(OM)r, vMo pvideE il. TM Calpticna' 3aeryeno XMtlI Mmiaamtidra (OSFIFI regNNmegarern to ailerie for metletlmure alis iaormenm. %eaesnaelM yderegaargte eWnlia Federal Lau pdab'popl8tery', teOBewM', anE "c WOEBMeI bldnasln(omlAwl"aMte ailena fanou ulia irllormation lar n e CF 101 anE 5a m. KRU 2M-40 (1/2) Stage Job Size (lb) Top TVD (ft) Top MD (ft) Propped Half-length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 100,000 6,055 21,1189 660 240 0.175 2 100,000 6,060 20,826 640 235 0.176 3 100,000 6,070 20,190 660 225 0.174 4 100,000 6,055 19,809 640 240 0.174 5 100,000 6,045 19,385 640 250 0.173 6 100,000 6,045 18,703 520 235 0.150 7 100,000 6,035 18,195 520 235 0.150 8 100,000 6,010 17,729 520 255 0.148 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results KRU 2M-40 (2/2) Stage Job Size (lb) Top TVD (ft) Top MD (ft) Propped Half-length (ft) Fracture Height (ft) Avg Fracture Width (in) 9 100,000 6,005 17,264 500 240 0.148 10 100,000 5,995 16,798 520 250 0.148 11 100,000 6,040 16,187 520 230 0.148 12 100,000 6,060 15,842 580 205 0.150 13 100,000 6,040 15,455 520 235 0.148 14 100,000 6,035 14,990 520 235 0.148 15 100,000 6,025 14,525 500 235 0.148 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a de -sander unit until the fluids clean up at which time it will be turned over to production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oi10 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20MC 25.105 20AAC 25A 10 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development [Z Exploratory ❑ Service ❑ Stratigraphic Test 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/6/2019 14. Permit to Drill Number/ Sundry: ' 219-063/319-352 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/19/2019 15. API Number: 60-103-20604-00-00 4a. Location of Well (Governmental Section): Surface: 113' FSL, 59' FWL, Sec 27, T11N, R8E, UM Top of Productive Interval: 2695' FNL, 218' FEL, Sec 31, T11 N, R8E, UM Total Depth: • 4232' FNL, 1800' FEL, Sac 6, TION, R8E, UM 8. Date TO Reached: 8/24/2019 16. Well Name and Number: KRU 2M-40 9. Ref Elevations: KB:137.53 ' GL: 100.70 ' BF: 17. Field / Pool(s): Kupamk River Field/Kupamk Oil Pool ' 10. Plug Back Depth MD1TVD: 21201/6178 18. Property Designation: - ADL 25586, ADL 25585, ADL 25590 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 487899 y- 5948985 Zone- 4 TPI: x- 477064 y- 5946202 Zone- 4 Total Depth: x- 475486 y- 5939391 Zone- 4 11. Total Depth MD/TVD: 21245/6178 , 19. DNR Approval Number: 931894000,931893000,931898000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDITVD: 1486/1478 ' 5. Directional or Inclination Survey: Yes ❑+ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MDITVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Sonic Scope/Neu/Den 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD I HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 37 176 37 176 42 Installed 13318 58 L-80 37 2965 37 2652 16 1545sx 11.0ppg Class G, 9518 47 L-80 35 13486 35 5806 12 1 / 4 679sx 15.8ppg Class G 7 26 L-80 13258 14283 5693 6075 8 1/2x9 7/8 200sx 15.8ppg Class G 41/2 12.6 L-80 14098 21201 6040 6178 61/8 Uncemented Liner 24. Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): FRAC SLEEVES @: 14525-21201 MD and 6100-6178 TVD.... 9/1/2019 COMPLETION D �7 rp 20(q VE. IFIED .__�� 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDlf VD) 3112 14107 13893 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1MOUNT AND KIND OF MATERIAL USED Top Job - 37-176 38.1 9b -s- 11.0ppg cmt 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOKUP Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 ROised 5/20177 117'1 /0/,7.3// CONTINUED IP PAGE 2pSubmit ORIGINIAL onrLs 00 ck DDMS =OCT O O 2019 � 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑Q If Yes, list formations and intervals cored (MDfTVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� if yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1486 • 1478 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 14221 6066 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C • TO 21245 6178 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloo6cal report. production or well test results, r 20 AAC 25,070, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name:G.L. Alvord Contact Name: Keith Herrin Authorized Title: Alaska Drilling; Manager Contact Email: keith.e.herrin co .com Contact Phone: 263-4321 Authorized�� 'T Signature: Date: 25� INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only 2M-41 ,nal Wellbore Schematic '111", Producer w/Frac ConocoPhillips 16" Surface Hole MD / 2,931' TVD 74°Tangent 12-1/4" Intermediate Hole TVD TOC at 11,775' MD / 5,146' TVD 13,433' MD 8-1/2" x 9-7/8" Intermediate Hole Updated: 9/10/2019 by K. Herring Conductor Installed: 20" set at 176' MD Landing nipple (DS), 2.813" at 2,151' MD Surface Casing: Below West Sak 13-3/8" 68# L-80 Hydril 563 2,965' MD / 2,652' TVD GUMS. 3-K" x 1" KBMG: 412,729' MD—DV #2 6,625' MD — DV 93 9,615' MD — DV #411,559' MD—DV #5 12,945' M D — DV #6 13,715' M D - DV Tubing: 3-W' 9.3# L-80 EUE 8rd HRD-E 2XP Packer 7" x 9 5/8" Flex -Lock liner hanger 13,258' MD / 5,693' TVD 62' Intermediate 1: 9 5/8" 47#, L80, HYD 563, 13,486' MD/5,806' TVD Downhole gauge at 13,774' MD Premier Packer at 13,893' MD Landing nipple IDS), 2.75" at 13,921' MD Itl elf Paaken—}yrfault lsoladon Hall Adtiwed Frac Sleeves _ Production Liner: 4-1/2" 12.6# L-80 HYD563 21,201' MD/6,178 TVD KUP PROD WELLNAME 2M-40 WELLBORE 2M40 COIIOCOftillIps Alaska. Inc. IwRlzoxTAL.2Mi0. wurvle l67wAM completion Details N'EUIWSIIaDc (xWap no, "C' TOPInd Top MKS) RxLB r) Sea Can; Co. xomiwl In ur) HANOEn:$4 324 32,4 0.00 HANGER Cameron 4-1IT Tubing Hanger, Hy 5563 3.900 76.3 76.3 0.12 jX0 REDUCING X0.4-112",126%, LAO, HYD 563 B X P 3.1c?%9.3X, EUE 3.000 2,1512 ,094.1 3353 NIPPLE Landing Nipple, DS, 33' x 2,813" EUE (2101' TVD, 33.65 deg) 2.813 13,]]4.0 5,939.5 6227 GAUGE HES CURSE Mandrel EUE ^^boAouciod; 9fisnea 13,892.9 5,901.9 ]09) PACKER PACKER, 3-12 X T', Baker PREMIER 2.890 NIPPLE; 2.1512 13,920.9 5,990.8 71J8 NIPPLE Landing N,,ple, 3.S x 2.75', D, EUE 2.750 GAe urp isms 14,0936 6038.5 ]606 LOCATOR Mechanical Le6abr 3.020 14,094.6 6030.8 1608 MULESHOE BakerWLEG 2990 SURFACE; W.l-.966 I Mandrel Inserts sL pap LIFT: 6,&06 N pp9 UFi; 9,610.8 N Topo",C) Top(MB) MIM Make Mo4el Valve LSICM1 PoA81te T OB Q(P-1) n) Sery Type Typa pn) Ips9 RYn Gah C. 1 2,7289 ,522.8 CAMCO KBMG 1 GAS LIFT DMY BK 2019 6,6246 ] .3 CAMCO KBMG 1 GAS LIFT DMY BK 3rz019 GAs UFT: n.Sxa 9,6149 4. .d CAMCO KBMG 1 GAS LIFT DMY BK I3I2019 4 11,5586 5. .9 CAMCO KBMG 1 GDMY BK AS LIFT 91312019 GAs uFr:rzxse 7--72-9451 5,5.9 CAIAW KBMG 1 GAS LIFT DMY BK 91312019 6 13,715.1 5915.9 CAMCO KBMG 1 GAS LIFT DMY BK 91312019 Notes: General & Safety EW Oah AnnoWbon INTERMEaNIEII:N.T- a4M.6 91 1NOTE View Schematic wl Alaska SchemadC10.0 pA9 LIFT; 19.]15.1 GAUGE: 1,7140 PPLRER; 13,W3B NIPPLE 13 Si U.—CE: 1a.099.6 MULE 9XGE: 14'.. INTERMED ATE 21,386 142m3 PRODUCTION LINER: 14, 9.1 t -,n 21,m10 Uperations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Jab: DRILLING ORIGINAL Time Log Stan Dep h Start Time End Time our (hr) Phase op Coda Activity Code Torre P -T -x Operation (HKB) End Depth (IIKB) 7/17/2019 7/17/2019 2.00 MIRU MOVE MOB P Cont. to prep for dg move. Clean & 0.0 0.0 12:00 14:00 clear floor. B/D lines Prep cellar. Rig move check list 7/17/2019 7/17/2019 1.25 MIRU MOVE MOB P Prep to move pits/motors. Move away 0.0 0.0 14:00 15:15 pits/motors complex. Cont. work on high drum clutch on draw works. 7/17/2019 7/17/2019 1.00 MIRU MOVE MOB P Skid rig floor into moving position 0.0 0.0 15:15 16:15 7/17/2019 7/17/2019 4.00 MIRU MOVE MOB P Raise wind walls & stompers and prep 0.0 0.0 16:15 20:15 to move sub. Trouble shot sub moving system. Add fresh hydrauilic fluid to system. Move sub off of well 2M-39 and back down to east side of pad. 7/17/2019 7/18/2019 3.75 MIRU MOVE MOB P Pull mats & herculite. Grade & prep 0.0 0.0 20:15 00:00 pad. Move annular & diverter line from 2M-39 to 2M-40 with crane. Prep sub base to remove wind walls. 7/18/2019 7/18/2019 6.00 MIRU MOVE MOB P N/U diverter. Cont. to prep & grade 0.0 0.0 00:00 06:00 1 1 pad (brought in 5loads of gravel) 7/18/2019 7/18/2019 6.00 MIRU MOVE MOB P Lay out herulite & mats for rig toot 0.0 0.0 06:00 12:00 print. Prep cell around well. Spot equipment in cellar. 7/18/2019 7/18/2019 6.00 MIRU MOVE MOB P Prep GRD, LVL location, Move Sub 0.0 0.0 12:00 18:00 over well, Adjust move System HPU pump, Set pads F/ stompers, lower stopers & wind walls 7/18/2019 7119/2019 6.00 MIRU MOVE MOB P Prep RIF for skidding, skid rig floor, 0.0 0.0 18:00 00:00 prep pits for movig, move pits, spot pipe house, 7/19/2019 7/19/2019 6.00 MIRU MOVE MOB P Spot pipe shed. Work on SCR's. Work 0.0 0.0 00:00 06:00 on changing out valves in pits. Modify & N/U riser. N/U hole fill & bleeder lines. Spot site control shack & pipe shed heater. 7/19/2019 7/1912019 5.00 MIRU MOVE MOB P Build containment & spot MPD shack. 0.0 0.0 06:00 11:00 Take on spud mud. Finalize rig acceptance check list. Pre -spud derrick inspection. Hook up annular diverter hoses & charge Koomy. Rig Accepted 11:00 Hrs 7/19/2019 7/19/2019 2.75 MIRU MOVE RURD P Install mouse hole. P/U msic tools & 0.0 0.0 11:00 13:45 equipment. Hook up black water line to conductor. test knife valve on diverter. 7/19/2019 7/19/2019 3.50 MIRU MOVE PULD P P/U & std back 5 aids HWDP I jars, 0.0 0.0 13:45 17:15 PJSM PIU clean out Assembly per DD. 7/19/2019 7/1912019 0.50 MIRU MOVE BOPE P Fuction test Diverter system, Knife 0.0 0.0 17:15 17:45 valve open @ 1 sec. Annular prev. closed @ 50 sec 7/19/2019 7/19/2019 4.50 MIRU MOVE RURD P Clear pipe house, Excess of toolos, 0.0 0.0 17:45 22:15 Take on spud mud, Build Pro -core pill in pit #6, CLN 5 7/8 dip threads. 7/19/2019 7/19/2019 0.25 MIRU MOVE PRTS P Fill hole w/ spud mud, check for leaks, 0.0 0.0 22:15 22:30 PT surface lines @ 3300 psi. 7/1912019 7/19/2019 0.50 SURFAC MOVE SFTY P Pre spud meeting, FI drilling surface 0.0 0.0 22:30 23:00 7/19/2019 7/20/2019 1.00 SURFAC DRILL DRLG P Spud in & clean out conductor to 125' 0.0 125.0 23:00 00:00 MD. 475 gpm, 270 psi, PU wt 75 k, SO wt 75 k, ROT wt 75 k, 25 rpm, On/Off lrq 1 k/ft lbs, 7120/2019 7/20/2019 4.00 SURFAC DRILL RGRP T Trouble shoot top drive IBOP actuator 125.0 125.0 00:00 04:00 1 valve & shot pin easy. 1 Page 1/29 Report Printed: 9/19/2019 Summary (with Timelog Depths) 2M-40 lipOperations Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start DapM StagTne End Tme Dur(hr) Phase Op Code I Activity Code 7nne P -T -X Dperauon (ftKB) End Depth(RKB) 7/20/2019 720/2019 1.25 SURFAC DRILL DRLG P Clean out conductor to 125' to 176' 125.0 176.0 04:00 05:15 MD. 475 gpm, 250 psi, PU wt 75 k, SO wt 75 k, ROT wt 75 k, 40 rpm, OntOff trq 1 k/ft Ibs, 7/20/2019 7/20/2019 0.25 SURFAC DRILL TRIP P POOH & rack back 1 stand HWDP 176.0 35.0 05:15 05:30 f/176' to 35'. 7/20/2019 7/2012019 2.75 SURFAC DRILL BHAH P PJSM. M/U remaining BHA 35.0 176.0 05:30 08:15 components as per SLB & scientific drilling to 176' 7/20/2019 7/20/2019 1.25 SURFAC DRILL DDRL P Drill ahead w/Gyro f/176'to 217'w/450 176.0 217.0 08:15 09:30 gpm, 250 psi 7/20/2019 720/2019 1.00 SURFAC DRILL SRW T Trouble shoot GYRO tools 217.0 217.0 09:30 10:30 7/20/2019 720/2019 1.50 SURFAC DRILL DORL P Drill ahead w/Gyro f/217'to 359' MD / 217.0 359.0 10:30 12:00 359' TVD, ADT 0.91 Hrs, 450 gpm, 470 psi, PU wt 89 k, SO wt 85 k, ROT wt 87 k, 40 rpm, On/Off lrq 2/1 k/R lbs, 5-15 k wob 7/20/2019 7/20/2019 1.25 SURFAC DRILL DDRL P Drill ahead w/Gyro f/359' to 460" MD, 359.0 460.0 12:00 13:15 gpm, 470 psi, PU wt 101 k, SO wt 95 k, ROT wt 98 k, 40 rpm, On/Off try 2/1 k/ft lbs, 5-13 k wob, pump nut plug/ DRI -zone/ sapp sweeps F/ BHA balling @ 460' 7/20/2019 720/2019 0.50 SURFAC DRILL OTHR T Drag chain packed off W/ clay, adjust 460.0 460.0 13:15 13:45 1 shaker screens & gates. 7/20/2019 7/20/2019 2.25 SURFAC DRILL DDRL P Drill ahead w/Gyro f/46010 636' MD, 460.0 636.0 13:45 16:00 TVD 635.9' gpm, 470 psi, PU wt 101 k, SO wt 95 k, ROT wt 98 k, 40 rpm, On/Off trq 2/1 k/ft lbs, 5-13 k wob, pump nut plug/ DRLzone/ sapp sweeps F/ BHA balling @ 460' 7/20/2019 72012019 0.50 SURFAC DRILL BKRM P BROOH F1636' T/ 543'T/ pickup jar 636.0 636.0 16:00 16:30 std. @ 450 gpm, 50 rpm, 2k trq, n wt 99k, @ 550' incountered pack off. P/U Wt 106K, slow pumps T/ 4009pm, 720/2019 7/20/2019 0.50 SURFAC DRILL TRIP T RIH with jar std TI 636', observed loss 636.0 636.0 16:30 17:00 of full returns, Attempt to circ with no relurns.Top fill hole w/ hole fill. Decision made to POOH to BHA and lay in ProCore pill while pulling out. 7120/2019 7/20/2019 0.50 SURFAC DRILL PMPO T Pump OOH laying in ProCore pill 636.0 177.0 17:00 17:30 w/1 bpm and filling from the top with hole fill. No returns while laying in ProCore pill. 7/20/2019 7/20/2019 1.75 SURFAC DRILL BHAH T POOH f/177'to bit. Racked back 177.0 0.0 17:30 19:15 NMFC & MWD. BHA completely packed off from top stab to bit. Use shovels & pressure washer to remove Flay from BHA. 7/2012019 7202019 0.50 SURFAC DRILL CLEN T Clean and clear dg Floor. 0.0 0.0 19:15 19:45 7/20/2019 7202019 0.75 SURFAC DRILL RGRP T Trouble shoot TD, shot pin pressure, 0.0 0.0 19:45 20:30 function test FI proper Aligment T/ handling ring assy. 7/20/2019 720/2019 0.50 SURFAC DRILL SHAH T M/U BHA per SLB 0.0 177.0 20:30 21:00 7/202019 7/20/2019 1.75 SURFAC DRILL TRIP T RIH F/177' T/ 436', W/ 5 7/8 HWDP, 177.0 436.0 21:00 22:45 BID 100K 7/20/2019 7/20/2019 0.25 SURFAC DRILL REAM T Wash and ream F/ 436'T/ 636/, GPM 436.0 636.0 22:45 23:00 1 I 520, SPP 520, Trq 3K, Rpm 40, ROT 103K, Add soap sticks A connections. Page 2/29 Report Printed: 9/1 912 01 9 Operations Summary (with Timelog Depths) " 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stat rime End Time our (hr) Phew Op Code Activity Cotle Time P-T-X Operation (M(B) End Depth (KKB) 7/20/2019 7/20/2019 0.25 SURFAC DRILL PULD T UD 1 joint of HWDP, Scord Sealing 636.0 636.0 23:00 23:15 face on box end. 7/20/2019 7/21/2019 0.75 SURFAC DRILL DDRL P Drill ahead w/Gyro V636' to 680' MD / 636.0 680.0 23:15 00:00 680' TVD, ADT 0.56 Hrs, 500 gpm, 650 psi, PU wt 108 k, SO wt 89 k, ROT wt 99 k, 50 rpm, On/Off trq 3/2 k/ft Ibs,8-12 k wob (TourADT = 2.36 Hrs) Adding soap sticks on connections and Skreen Kleen to aid in clay management. 7/21/2019 7/2112019 12.00 SURFAC DRILL DDRL P Drill ahead f/ 680' to1,623' MD/ 1,611 680.0 1,623.0 00:00 12:00 TVD, ADT 8.64 Hrs, 600 gpm, 770 psi, PU wt 125 k, SO wt 120 k, ROT wt 123 k, 60 rpm, On/Off trq 3.5/2 k/ft lbs, 8-10 k wob. (Adding soap sticks on connections and Skreen Kleen to aid in clay management along with nut plug drill zone sweeps) 7/21/2019 7/2212019 12.00 SURFAC DRILL DDRL P Drill ahead f/1,623'to 2,611' MD / 1,623.0 2,612.0 12:00 00:00 2,455', ADT 7.72 Hrs, 750 gpm, 1550 psi, PU wt 155 k, SO wt 140 k, ROT wt 145 k, 60 rpm, On/Off trq 8/3.5 k ft/lbs, 5 - 30 k wob. (Adding soap sticks on connections and Skreen Kleen to aid in clay management along with nut plug drill zone sweeps) 7/22/2019 7/22/2019 5.50 SURFAC DRILL DDRL P Drill ahead f/2,611' to TD of 2,975' 2,612.0 2,975.0 00:00 05:30 MD / 2,656', ADT 3.7 Hrs, 750 gpm, 1470 psi, PU wt 153k, SO wt 135 k, ROT wt 140 k, 60 rpm, On/Off trq 614.5 k (tubs, 13 - 15k wob. (Adding soap sticks on connections and Skreen Kleen to aid clay management along with nut plug drill zone sweeps) 7/22/2019 712212019 2.75 SURFAC CASING CIRC P Obtain final surveys. Pump 54 bbls 2,975.0 2,800.0 05:30 08:15 Pr000r sweep & circ hole clean for 2+ B/U w/750 gpm, 1450 psi, 60 rpm, 5 - 6 k trq. Rack back 2 stands to 2,800' 7/22/2019 7/2212019 0.25 SURFAC CASING OWFF P FIC (static) 2,800.0 2,800.0 08:15 08:30 7/22/2019 7/2212019 3.50 SURFAC CASING BKRM P BROOH f/2,800 to 1,952'w/800 gpm, 2,800.0 1,952.0 08:30 12:00 1400 psi, 75 rpm, 5 - 7 k trq, PU wt 140 k 7/22/2019 7/22/2019 3.00 SURFAC CASING BKRM P BROOH f/1,952'to 1,482' w/800 gpm, 1,952.0 1,482.0 12:00 15:00 1400 psi, 75 rpm, 5 - 7 k trq, PU wt 140 k. Slowed down pulling speed and pumped sweeps to aid in hole cleaning below base of permafrost. 7/222019 7/22/2019 0.75 SURFAC CASING OWFF P F/C (static). 1,482.0 1,482.0 15:00 15:45 7/22/2019 7/22/2019 2.25 SURFAC CASING TRIP P POOH on elevators V1,482'to NMFC 1,482.0 177.0 15:45 18:00 722/2019 7/22/2019 0.25 SURFAC CASING CIRC P Pump low vis nut plug drill zone 177.0 177.0 18:00 18:15 sweep to clean condcutor & scour BHA w/600 - 750 gpm, 800 - 1150 psi. 7/222019 7/222019 2.50 SURFAC CASING BHAH P POOH & UD BHA as per SLB & 177.0 0.0 18:15 20:45 Scientific drilling. 7/222019 7/222019 2.25 SURFAC CASING RURD P Clean & clear rig floor of drilling tools. 0.0 0.0 20:45 23:00 j PILI csg running equip. 71222019 7/2312019 1.00 SURFAC CASING RURD P Dummy Run 13 3/8 casing hander on 0.0 0.0 23:00 00:00 1 1 1 1 landing jt, UD same. 7/23/2019 7/2312019 1.50 SURFAC CASING RURD P Rig up T/ run 13 3/6, 68# HYD 563 0.0 0.0 00:00 01:30 I I casing. Page 3129 Report Printed: 911912019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log steel Depen Start Time End Time Dur (hr) Phase Op Coda AcMiry Cade Time P -T -X Operation (flKB) End Depth mKS) 7123/2019 7/23/2019 7.75 SURFAC CASING PULD P PJSM, M/U she track, Run 13 3/6, 0.0 1,499.0 01:30 09:15 68# HYD 563 casing T/ 499', 7/23/2019 7/23/2019 1.25 SURFAC CASING CIRC T Attempt to circulate @ 1499', Staging 1,499.0 1,499.0 09:15 10:30 pump up F/.5 bpm TI 2.5 bpm, ICP80 FCP 110 psi. unsuccessful no returns, 35 bbl loss while pumping. 7/23/2019 7123/2019 2.00 SURFAC CASING PULD P Continue running 13 316, 68# HYD 1,499.0 1.989.0 10:30 12:30 563 casing F/ 1499' T/1989' p/u 207K, S/O 110K, no returns. losses -10 bbis plus displacement. 7/23/2019 7123/2019 1.00 SURFAC CASING CIRC P Attempt to regain cicrulation @ 1998', 1,989.0 1,989.0 12:30 13:30 pump @ .5 bbl/ min 90 psi T/ 2.5 bbl/min @ 180 psi, slow returns on up stroke, no returns on DWN stroke, p/u wt 235k, s/o 11 Ok, decission made T/ TIH to bottom. 7123/2019 723/2019 3.50 SURFAC CASING PULD P Continue RIH W/ 13 3/6,68# HYD 563 1,989.0 2,922.0 13:30 17:00 casing, F/ 1989'T/ 2922; P/U 275K, S10 1101k, no returns. 7/23/2019 723/2019 1.25 SURFAC CASING PULD P M/U 13 3/8 Hanger assembly per 2,922.0 2,965.0 17:00 18:15 cameron Rep, Install landing joint T/ hanger, remove spiderslips, RIH FI 2922' T/ 2965' Very landing on seat, plu 275K, s/o 110k. 7/23/2019 71232019 3.75 SURFAC CASING CIRC T Attempt to regain circulation, w/ 2,965.0 2,965.0 18:15 22:00 recipulating casing, W/ 1-2 bbl/min, SPP 120 - 170, on up stroke, no returns. P/U 2601k, 8/0 150k mud losses @ 90 bbls hr. hanger flute sheared F/ set screws while recipating casing. 7/23/2019 7/242019 2.00 SURFAC CASING CIRC T Recip. CSG pump 29.5 bbl Procor pill 2,965.0 2,965.0 22:00 00:00 @ 1 BPM, 140 psi, 2 bpm = 180 psi, chase W/ 9.5 ppg spud mud, P/U 260, S/0 150, no returns 7/24/2019 7/242019 13.25 SURFAC CASING CIRC T Recipate CSG @ 2947', while 2,965.0 2,965.0 00:00 13:15 attempting to regain circulation. Pump Pr000r LCM pill. adjusting pump rates F/.5 T/ 8 bbl/min spp 130 / 270, P/U 2551k, SIO 165K, slight returns observed. 7/24/2019 7/24/2019 5.00 SURFAC CASING CIRC P Regain circulation, Recip. pipe, & 2,965.0 2,965.0 13:15 18:15 circulate @ 3 / 6 bpm, spp 120 / 150, p/u 265k, S/o 165k 7/2412019 724/2019 0.25 SURFAC CASING CIRC T Re -Install hanger flute assembly, W/ 2,965.0 2,965.0 18:15 18:30 set screws, wash dwn hanger to landing ring @ 6bbl/min, spp 120 S/O 175K 7/24/2019 724/2019 0.25 SURFAC CASING OWFF P OWFF, slight returns, continue 2,965.0 2,965.0 18:30 1845 circulating @ 1 BPM. 7/24/2019 7/24/2019 0.75 SURFAC CASING CIRC P Continue circ. @ 1 BPM prep tools 2,965.0 2,965.0 18:45 19:30 &equip F/ cmt job. 7/24/2019 7/24/2019 0.25 SURFAC CASING OWFF P OWFF, well static. 2,965.0 2,965.0 19:30 19:45 7/24/2019 7/24/2019 0.25 SURFAC CASING RURD P BD top drive, R/U cement circ equip, 2,965.0 2,965.0 19:45 20:00 T/ volant crt, check valve alignment. 7/24/2019 724/2019 0.50 SURFAC CASING CIRC P Est circulation thru cmt lines, T/ 13 318 2,965.0 2,965.0 20:00 20:30 casing, @ 1 BPM, 60 psi, increase T/ 6 BPM @ 270 psi, Attempt to pull hanger F/ seat, P/U t/ 298K, Decission made to let hanger set F/ cmt job until needed. Page 4129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur ft) Phase op Code Activity Cade Time P -T -X operation (eKB) End Depth(flKB) 7/24/2019 7/25/2019 3.50 SURFAC CEMENT CMNT P Line up T/ SLB cementers, pump 5 2,965.0 2,965.0 2030 0000 bbls CW 100, shut in T/ psi test surface equip, test surface equip. @ 2500 psi, pump 35 bbls CW 100 @ 4 BPM, 114 psi, pump 80 bbls 10.5 Mud Push II @ 4 BPM, 118 psi, Drop bottom plug, pump 525 bbls, 11 ppg Lead cement @ 6 BPM, 123 / 216 psi 7/2512019 7125/2019 1.75 SURFAC CEMENT CMNT P Continue pumping cement, Pump 71 2,965.0 0.0 00:00 01:45 bbls 12 ppg Tail cmt, Drop top plug, K/O W/ 10.5 bbls 1-12), Displace w/ 419 bbls 9.5 spud mud,. Last return @ 366 bbls into displacement. 165 bbls mud loss w/ displacing, bumped plug @ 3552 stks, icp = 330 psi FIC= 580 psi, Plug bumped @ 01:40 hrs 7-5-19 - no cement returs to surface. 7/25/2019 7/2512019 0.50 SURFAC CEMENT CMNT P Bleed off psi, OWFF Floats holding. 0.0 0.0 01:45 02:15 7/25/2019 7/25/2019 1.75 SURFAC CEMENT RURD P R/D Volant running tool, UD landing it, 0.0 0.0 02:15 04:00 and handling equip. 7/25/2019 7/25/2019 1.75 SURFAC CEMENT RURD P R/U cand flush annular and riser, 0.0 0.0 04:00 05:45 install bell guide on top drive. 7/25/2019 7/25/2019 3.25 SURFAC CEMENT NUND P N/D Surface riser, annular, Remove 0.0 0.0 05:45 09:00 diverter line, knife valve and diverter spool 7/25/2019 712512019 2.00 SURFAC CEMENT RURD T Prep cellar and dg up tools to perform 0.0 0.0 09:00 11:00 CMT lop job 7/25/2019 7/2512019 5.00 SURFAC CEMENT CMNT T Attempt to run 1/2" pipe F/ tap job, 0.0 0.0 11:00 16:00 collars too big F/ hanger fluks, Dicission made to cut knotch in conductor pipe. RIH W/ V@" sech 80 pipe. Tagged @ 175', rig up cementers to 1?2" pipe. 7/25/2019 7/25/2019 4.00 SURFAC CEMENT CMNT T Fill lines W/ 0.8 bbls H2O, PT lines @ 0.0 0.0 16:00 20:00 1000 psi, pump 25.7 bbls water, @ 0.4 BPM = 300 psi, observe mud push until H2O observed, pump 38.1 bbls 11.0 ppg cement @ 0.4 BPM ICP = 430 psi, FCP = 710 psi, CIP @ 19:48 hrs, AOGCC BOB Noble witness cmet Hob. 7/25/2019 7/25/2019 1.75 SURFAC CEMENT RURD T R/D cementing equip. flush circ. lines 0.0 0.0 20:00 21:45 w/ water in cellar, B/D lines, T/ cementers, cleasn cellar box, p/u and clr work area, f/ NIU well head. 7/25/2019 7/26/2019 2.25 SURFAC WHDBOP NUND P PJSM, N/U well head Per cameron & 0.0 0.0 21:45 00:00 well site operator, PT well head @ 5000 psi F/ 10 min, 7/26/2019 7/26/2019 4.00 SURFAC WHDBOP NUND P NIU BOP'S, M/U kill and choke lines, 0.0 0.0 00:00 04:00 7126/2019 7/26/2019 5.00 SURFAC WHDBOP NUND P PJSM, Rig up MPD orbit valva, run 0.0 0.0 04:00 09:00 control lines, 2" me T/ annulas, mud lines & fie box. 7/26/2019 7/26/2019 1.50 SURFAC WHDBOP NUND P R/U T/ test bonnet, orbit valve, & 2" 0.0 0.0 09:00 10:30 manifold. 7/26/2019 7/26/2019 1.50 SURFAC WHDBOP NUND P Trouble shoot orbit valve actuator, Re- 0.0 0.0 10:30 12:00 Test MPD orbit vlv & manifold, test good 7/2612019 7/26/2019 0.75 SURFAC WHDBOP BOPE P PJSM, R/U to test bop's, flood & purge 0.0 0.0 12:00 12:45 lines. Page 5/29 ReportPrinted: 9/19/2019 operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Dept, Start Time End Turn Dur(hr) Phase op Cade Adivlty Code I'm P -T -X Operation (10(8) End Depth(ftKB) 7/26/2019 7126/2019 7.25 SURFAC WHDBOP BOPE P Test BOP'S w/ 5 7/8 test it. Test 0.0 0.0 12:45 20:00 Annular, upper & 3.5 x 6 vbr lower rams, Blind rams, HCR choke / kill valves, 4" demco kill valve, choke valves 1 thru 14, Floor safety valves, upper & lower TO valves, @ 250 low/ 3500 psi F/ 5 min ea, (IBOP valve failed,) Test gas alarms -AOGCC BOB NOBLE waived Witness of BOP Test. 7/26/2019 7/27/2019 4.00 SURFAC WHDBOPBOPE T Change out IBOP valve on top drive, 0.0 0.0 20:00 00:00 test /BOP @ 250/3500 psi F/ 5 min ea. 7127/2019 7/27/2019 2.00 SURFAC WHDBOP BOPE T Continue to install Fedder ring and 0.0 0.0 00:00 02:00 safety wire same. 7127/2019 7/27/2019 1.00 SURFAC DRILLOUT PULD P RIH w/ 4 stds HWDP F/ derrick, UD 0.0 0.0 02:00 03:00 down 12 its HWDP. 7/27/2019 7/27/2019 0.50 SURFAC DRILLOUT BOPE P PIU test it. Make up wear ring running 0.0 0.0 03:00 03:30 tool, install 12.25 ID wear bushing. 7/27/2019 7/27/2019 2.50 SURFAC DRILLOUT BHAH P PJSM, PIU & RIH with 12 1/4 0.0 365.0 03:30 06:00 1 1 intermediate BHA T/ 365' 7/27/2019 7/27/2019 1.50 SURFAC DRILLOUT TRIP P Trip in hole F/ 365'T/ 1774', w/ 5 7/8 365.0 1,774.0 06:00 07:30 DR. Shallow test MWD W/ 360 GPM, SPP 700 7/27/2019 7/27/2019 1.25 SURFAC DRILLOUT TRIP P Continue TIH F/ 1774' 712622', W/ 5 1,774.0 2,622.0 07:30 08:45 7/8 dip F derrick. 7/27/2019 7/27/2019 1.50 SURFAC DRILLOUT SVRG P PJSM, cul and slip 60' ddg line, 2,622.0 2,662.0 08:45 10:15 Service TD, Blocks, Draworks 7/27/2019 7/27/2019 1.25 SURFAC DRILLOUT PRTS P R/U T/ test CSG, flood lines, Test 2,662.0 2,662.0 10:15 11:30 13.375 casing @ 3000 PSI f/ 30 MIN, (Test good) rig dwn testing equip. 7/27/2019 7/27/2019 1.25 SURFAC DRILLOUT WASH P Wash down F/ 2662' T/ 2882'7/ 625 2,662.0 2,882.0 11:30 12:45 gpm, 720 SPP, 50 RPM, 4.5 TRQ 7127/2019 7/27/2019 3.00 SURFAC DRILLOUT DRLG P Tag Plug @ 2882', Drill out shoe track 2,882.0 2,975.0 12:45 15:45 rat hole F/ 2882 T/2975' 7127/2019 7/27/2019 0.25 SURFAC DRILLOUT DRLG P Drill F/ 2976M2995' MD, TVD 2667' 2,975.0 2,995.0 15:45 16:00 7/27/2019 7/27/2019 0.50 SURFAC DRILLOUT BKRM P BROOH F/ 2995'T/ 2905'W/ 800 2,995.0 2,995.0 16:00 16:30 GPM, 1110 SPP, 50/70 RPM, 4/21k TORQ 7/2712019 7/27/2019 1.25 SURFAC DRILLOUT FIT P PJSM, RID for FIT Test, Perform FIT 2,995.0 2,995.0 16:30 17:45 PSI up T/ 900 psi, 16.0 ppg EMW (2.2 bbls vol pumped, 1.0 bbls bleed back. R/D testing equip 7/27/2019 7127/2019 0.50 INTRMI DRILL WASH P W/R F/2905 T/ 2995'w/ 625 gpm, 730 2,995.0 2,995.0 1745 18:15 spp, 60 rpm, 2.5 / 7.5k lrq. 7/27/2019 712812019 5.75 INTRMI DRILL DDRL P Displace T/ mud T/ LSNDmud wt 3% 2,995.0 3,565.0 18:15 00:00 ddllzone, Drill 12 1/4 intrm 1 hole F/2995' TI 3565", W/ 1000 GPM,180, SPM 180 SPP, 1350,F10 out 20, RPM,180 WOB, 6k P/U 150k, SIO 1301 k ROT 137k, 6kTORQ. ADT 4.5 Irm Bit 4.70 hm Jars 25.32 hm 7/28/2019 728/2019 5.00 INTRMI DRILL D -DR L P Cont. Drilling 12.251NTERM 1 section 3,565.0 4,062.0 00:00 05:00 F/ 3565 T/ 4062' MD 3001 TVD, W/ 1000 GPM, 1430 SPP, 202 SPM, WOB 8 /10K, 9K TRQ, P/U 155k, SID 130K, ROT143K, TRQ OFF BOTT. 4.5K -ADT 3.7 HR BIT HRS 8.4 Jar HRS 29.02 7/28/2019 7/28/2019 0.75 INTRMI DRILL CIRC T Pump High Vis sweep, Recip. and 4,062.0 4,062.0 05:00 05:45 Rotate while chasnging swab & liner in PUMP @ Page 6129 ReportPrinted: 9119=19 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Actwity Code Time P-T-X Dperadon (WB) End Depth (RKB) 7/28/2019 7/28/2019 6.25 INTRMI DRILL DDRL P Cont. Drilling 12.25 INTERM 1 section 4,062.0 4,693.0 05:45 12:00 F/ 4062' T 4693' MD 3175 TVD, WI 1000 GPM, 1480 SPP, 202 SPM, WOB 4 77 K, 8 K TRQ, P/U 161 k, SID 130K, ROT145 K, TRQ OFF BOTT. 5.5K - ADT 8.25 HR BIT HRS 8.25 Jar HRS 33.57 7/28/2019 7/28/2019 6.00 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 4,693.0 5,405.0 12:00 18:00 F14693' T/54061 MD, 3371' TVD, W/ 1000 GPM, 1620 SPP, 202 SPM, 180 RPM, 517 k WOB, 8 K TRQ, PIU 170k, S/O 137K, ROT150 K, TRQ OFF BOTT 6.5K - ADT 5.0 HR BIT HRS 17.95 Jar HRS 38.57 7/28/2019 7/29/2019 6.00 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 5,405.0 6,012.0 18:00 00:00 F/ 5405' T/ 6012' MD, 3535' TVD, W/ 1000 GPM, 1790 SPP, 204 SPM, 180 RPM, 8/10 k WOB, 9.5 KTRQ, PIU 170 k, SIO 142K, ROT155 K, TRQ OFF BOTT 6.5K - ADT 4.40HR BIT HRS 22.35 Jar HRS 42.97 7/29/2019 7/29/2019 12.00 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 6,012.0 7,313.0 00:00 12:00 F/ 6012' T/ 7313'MD, 3902' TVD, W/ 1000 GPM, 1880 SPP, 204 SPM, 180 RPM, 8/10 k WOB, 13 K TRQ, P/U 197 k, S/O 150K, ROT165 K, TRQ OFF BOTT 8 K - ADT 9.3 HR BIT HRS 31.58 Jar HRS 52.20 7/29/2019 7/29/2019 6.00 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 7,313.0 8,060.0 12:00 18:00 F/ 7313'T/ 8060,MD, 4105" TVD, W/ 1000 GPM, 2020 SPP, 204 SPM, 180 RPM, 10/12 k WOB, 14.5 K TRQ, P/U 220k, S/O 150, ROT172 K, TRQ OFF BOTT 10 K - ADT 5.02 HR BIT HRS 36.60 Jar HRS57.22 7/29/2019 7/30/2019 6.00 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 8,060.0 8,555.0 18:00 00.00 F/ 8060' T/ 8555' ,MD, 4243' TVD, W/ 1000 GPM, 1830 SPP, 204 SPM, 180 RPM, 5/7 k WOB, 14 K TRQ, P/U 225k, S/O 153, ROT 175 K, TRQ OFF BOTT 12 K - ADT 4.3 HR BIT HRS 40.96 Jar HRS 61.58 7130/2019 7/30/2019 9.50 INTRMI DRILL DDRL P Cont. Drilling 12.251NTERM 1 section 8,555.0 9,589.0 00:00 09:30 F/ 8,555' T/ 9,589' ,MD, 4,530' TVD, W/ 1000 GPM, 2280 SPP, 204 SPM, 160 RPM, 5/8 k WOB, 15 K TRQ, P/U 230k, S/O 163, ROT 173 K, TRQ OFF BOTT 9 K - ADT 7.88 HR BIT HRS 48.84 Jar HRS 69.46 7/30/2019 7/30/2019 1.75 INTRMI DRILL CIRC P CBU 2 x's 1,000gpm, 2,230psi 9,589.0 9,401.0 09:30 11:15 160rpm's 10.51k Tq Rack back 1 stand per B/U 7/30/2019 7/30/2019 0.25 INTRMI DRILL OWFF P Flow check well, Static, after mud 9,401.0 9,401.0 11:15 11:30 decompression. Rot 20rpms 11k Tq 7/30/2019 7/3112019 12.50 INTRMI DRILL BKRM P BROOH F/9,401'to 5,635' 700-800fph 9,401.0 5,635.0 11:30 00:00 string speed. 1,0009pm 2,200-1,880 psi, 160rpm's 10-7.7k Tq, 10.38 ppg ECD, UP Wt 145k. Multiple tight connection breaks encountered. 7/31/2019 7/31/2019 10.50 INTRMI DRILL REAM P BROOH F/5,635'To 3,022"700- 5,635.0 3,022.0 00:00 10:30 800fph string speed. 1,000gpm 2,200- 1,880 psi, 160rpm's 10-7.7k Tq, 10.38 ppg ECD, UP Wt 145k. Multiple tight connection breaks encountered. Page 7129 Report Printed: 9/1912019 Uperations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Tme P-T-X Operation (ftKB) End Depth(W[3) 7/3112019 7131/2019 1.00 INTRMI DRILL CLEN P The hole unloaded & packed off the 3,022.0 3,022.0 10:30 11:30 flowline @ 3,022' Cleared flowline & drip pan. 7/31/2019 7/31/2019 0.50 INTRMI DRILL CIRC P @ 3,022' re-establish Circulation & 3,022.0 2,905.0 11:30 12:00 Brooh ou of the hole F/ 3,022' to 2,905'W/ 850 GPM, @ 1215 psi 100 Rpm, 5k Torque. ECD-10.1 no overpull gbserved. Pull to the shoe @ 2,965'. 7/31/2019 7/31/2019 1.25 INTRMI DRILL CIRC P Circ & cond . @ 2,905' 1000 gpm, 2,905.0 2,905.0 12:00 13:15 1530 psi, 100 Rpm, 3.7 k torque, string wt up 135k, pump hi vis Sweep nut plug sweep. 7/31/2019 7/3112019 2.00 INTRMI DRILL CLEN P Clean out the drip pan & flow box and 2,905.0 2,905.0 13:15 15:15 Check the flowline. 7/31/2019 7/31/2019 1.50 INTRMI DRILL RGRP P Change out the saver sub, Ser# 2,905.0 2,905.0 15:15 16:45 636223, & service the rig. 7/31/2019 8112019 7.25 INTRMI DRILL TRIP P Trip in the Hole F/2,905'10 9,312' 2,905.0 9,312.0 16:45 00:00 fillingt the pipe every 1000' Trip speed: 2,000ft/hr Hole giving correct displacement. 8/112019 8/112019 1.75 INTRMI DRILL REAM P Safety Wash to bttm F/9,312'to 9,589' 9,312.0 9,526.0 00:00 01:45 to w/ 1000 Gpm, @ 1,790 Psi, 160 Rpm, 13.5K Torque. 8/12019 8/1/2019 0.75 INTRMI DRILL MPDA P Pull the trip Nipple & Install the the 9,526.0 9,526.0 01:45 02:30 RCD Head. 8/1/2019 8/12019 0.25 INTRM1 DRILL MPDA P Break in the RCD head Per Beyond 9,526.0 9,526.0 02:30 02:45 MPD Rep W/500 to 1000 GPM, 800 to 1950 psi, 20 to 160 RPM, 11.5 to 15k torque. 8/1/2019 8/1/2019 0.50 INTRMI DRILL REAM P Wash & Ream to BTTM F/9,526'to 9,526.0 9,590.0 02:45 03:15 9,590' 8/1/2019 8/1/2019 2.75 INTRMI DRILL DDRL P Drill the12.25" Hole 9,590'to 9,878' 9,590.0 9,878.0 03:15 06:00 MD 4,610' TVD, W/1000 GPM @ 2,250 Psi, 160 RPM, 15 to 16k Torque. 13/15k Bit Wt. 12.5 LBS Torque, @ 2,150 psi. SPR'S, #1 Pump 30140 SPM @ 180 psi 1220 psi.# 2 @30/40 SPM =190/230 psi. 8/1/2019 8/1/2019 2.75 INTRMI DRILL DDRL P Drill the12.25" Hole 9,878'to 10,1614' 9,878.0 10,161.0 06:00 08:45 MD 4,610' TVD, W/1000 GPM @ 2,250 Psi, 160 RPM, 16k Torque. 12k Bit Wt. 12.5 LBS Torque, @ 2,175 psi. ECD-10.83 8/1/2019 8/1/2019 0.75 INTRMI DRILL CIRC P @ 10,161' CBU W/ 1000 GPM, @ 10,161.0 10,161.0 08:45 09:30 2,030 Psi 160 RPM, 13k Torque. 8/1/2019 8112019 0.50 INTRMI DRILL OTHR P @ 10,161' Perform Formation 10,161.0 10,161.0 09:30 10:00 FingerPrint, INITIAL PSI BUILD-76 PSI Final -32 PSI 8/12019 8/1/2019 8.00 INTRMI DRILL DDRL P Drill the 12.25" Intermedite Hole 10,161.0 10,337.0 10:00 18:00 Section F/10,161' to 10,337' MD . 4,738' TVD W/1000 GPM @ 2,170', 160 RPM 16K torque, 12K Bit WLECD -10.83 8/1/2019 8/2/2019 6.00 INTRMI DRILL DDRL P Drill The 12.25" Intermediate Hole 10,337.0 11,479.0 18:00 00:00 Section F/10,337'to 11,479' MD. 5,063' TVD, 1000 gpm, 2170 psi, 160 rpm, 21k TO, 10-12k WOB. Off Bottom PU Wt 243k, SO Wt 162k, ROT Wt 192k, 15.5k TQ, 2,170 psi. ADT 4.42, Bit His 63.49, Jar Him 84.11. SPRs taken. Page 8129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log scan Depm Stan Time Ertl Time Dur (hr) Phase Op cme AnWy Cotle Time P-T-X Operation (ftKB) Ertl Dept (RKB) 8/2/2019 8/2/2019 6.00 INTRMI DRILL DDRL P Drill The 12.25" Intermediate Hole 11,479.0 12,139.0 00:00 06:00 Section F/11,479'to 12,139' MD. 5,253' TVD, 1000 gpm, psi, 2215,160 rpm, 22k TO, 13k WOB. Off Bottom PU Wt k, SO Wt 164k, ROT W245 k, 185k TQ, 2230 psi. ADT 5.10, Bit Hrs 58.39, Jar Hrs 79.01. 8/2/2019 8/2/2019 6.00 INTRMI DRILL DDRL P Drill The 12.25" Intermediate Hole 12,139.0 12,745.0 06:00 12:00 Section F/12,139'to 12,745' MD. 5,466' TVD, 1000 gpm, 2150 psi, 160 rpm, 23k TO, 13k WOB. Off Bottom PU Wt 260k, SO Wt 165k, ROT Wt 185k, 10k TO, 2380 psi. ADT 5. 10, Bit Hrs 73.20, Jar Hrs 93.82. SPRS @ 12,235'MD 5,273 TVD. MUD WT 9.6. #1 Pump @ 30 SPM 250 PSI. @ 40 SPM 280 PSI ... #2 MUD PUMP @ 30 SPM.270 PSI. 40 SPM 300 PSI. 8/2/2019 8/2/2019 6.00 INTRMI DRILL DDRL P Drill The 12.25" Intermediate Hole 12,745.0 13,225.0 12:00 18:00 Section F/12,745' to 13,225' MD. 5,253' TVD, 1000 gpm, 2200 psi, 160 rpm, 21k TO, 16k WOB. Off Bottom PU Wt 275k, SO Wt 175k, ROT Wt 213k, 19.5k TO, 2200 psi. ADT 5.05, Bit Hrs 78.25, Jar Hrs 98.87. 8/2/2019 8/2/2019 4.25 INTRMI DRILL DDRL P Drill The 12.25" Intermediate Hole 13,225.0 13,496.0 18:00 22:15 Section F/13,225'to 13,496' MD. 5,780' TVD, 1000 gpm, 1950 psi, 160 rpm, 21k TO, 15k WOB. Off Bottom PU Wt 275k, SO Wt 175k, ROT Wt 213k, 19.5k TO, 2200 psi. ADT 3.37. Bit Hrs 81.62, Jar Hrs 102.24.. 8/2/2019 8/3/2019 1.75 INTRMI CASING CIRC P Circ & Cond, W/ 1000GPM, @ 2280 13,496.0 13,456.0 22:15 00:00 PSI, 160 RPM, 20k Torque, ECD @ 10.81, @ 13,469', R/B 1 STAND Circ BTTMS UP, MUD WT 9.6-10 PPG. 8/3/2019 8/3/2019 3.50 INTRMI CASING CIRC P @ 13,4566' Continue to weight up the 13,456.0 13,456.0 00:00 03:30 System F/9.7 PPG to 10.0 PPG. and Maintain 11.0 PPG ECD.with 1000 to 850 GPM AT 2380 PSI to 1810 psi. 160 RPM @ 18 K torque. 8/3/2019 8/3/2019 0.25 INTRMI CASING OTHR P GET THE SPR'S, #2 Pump 25 SPM 13,456.0 13,456.0 03:30 03:45 1 1 @ 290 PSI 350SPM @ 370 PSI 8/3/2019 8/3/2019 0.25 INTRMI CASING OTHR P OWFF w/ 5-10 rpm 17.5k torque. 13,456.0 13,456.0 03:45 04:00 8/3/2019 8/3/2019 6.00 INTRMI CASING BKRM P BROOH F/13,456' TO 12,415' W/ 800 13,456.0 12,415.0 04:00 10:00 TO 850 GPM, 1,710 PSI TO 1,800 PSI. 160 RPM TO 150 RPM 19.K TORQUE. 8/3/2019 8/3/2019 1.50 INTRMI CASING CIRC P CIRC BTTMS UP W/150 RPM, 17.5K 12,415.0 12,415.0 10:00 11:30 TORQUE.(ECD INCREASE AND INCREASE IN CUTTINGS RETURNS). x/3/2019 8/4/2019 12.50 INTRMI CASING BKRM P BROOH F/12,415' TO 9,500'W/ 800 12,415.0 9,500.0 11:30 00:00 TO 850 GPM, 1,710 PSI TO 1,800 PSI.160 RPM TO 150 RPM 19.K TORQUE. 8/4/2019 8/4/2019 1.00 INTRMI CASING BKRM P BROOH F/ 9,500'to 9,312'W/800 9,500.0 9,312.0 00:00 01:00 GPM @ 1600 PSI. 100 RPM, 13K TORQUE. 8/4/2019 8/4/2019 2.50 INTRMI CASING CIRC P CXIRC BTTMS UP F/9,31270 9,124' 9,312.0 9,124.0 01:00 03:30 CBU X 2, W/800 GPM @ 1610 PSI, 100PM 14K TORQUE. Page 9/29 Report Printed: 911912019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Tme End Time Dw (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 8/4/2019 8/4/2019 1.50 INTRMI CASING CIRC P WT UP TO 10.3 PPG, W/800-650 9,124.0 9,124.0 03:30 05:00 GPM @ 1610-1160 PSI 100 RPM 14K TORQUE (MAINT 11 PPG ECD. 8/4/2019 8/4/2019 0.25 INTRMI CASING CIRC P GETTHE SPR'S.#1 PUMP259PM 9,124.0 9,124.0 05:00 05:15 150 PSI, 35 SPM @ 180 PSI, #2 PUMP AT 25 SPM 140 PSI, 35 SPM @ 180 PSI, @ 9,124' MUD WT 10.3 PPG 81412019 8/4/2019 0.25 INTRMI CASING CIRC P OWFF, NO FLOW THE WELL IS 9,124.0 9,124.0 05:15 05:30 STATIC. 814/2019 8/4/2019 1.75 INTRMI CASING SMPD P SOOH F/9,124' TO 8,350' HOLDING 9,124.0 8,350.0 05:30 07:15 BACK PRESSURE @ 90 PSI, 40 K OVERPULL @ 8,350', 8/412019 8/4/2019 2.00 INTRMI CASING CIRC P CBU STAGING THYE PUMPS UP TO 8,350.0 8,350.0 07:15 09:15 625 GPM,1030 PSI,80 RPM. 11K TORQUE. 8/4/2019 8/4/2019 1.75 INTRMI CASING SMPD P SOOH F/8,350' TO 8,090' HOLDING 8,350.0 8,090.0 09:15 11:00 BACK PRESSURE @ 90 PSI, 40 K OVERPULL @ 8,135', 8/4/2019 8/4/2019 1.75 INTRMI CASING SMPD P SOOH F/8,090" TO 8085HOLDING 8,090.0 8,085.0 11:00 12:45 BACK PRESSURE @ 90 PSI, 40 K OVERPULL. COULDN'T SOOH ANY LONGER. PU WT 210K SOW 140K. 8/4/2019 8/4/2019 5.50 INTRMI CASING BKRM P BROOH F/ 8,085' TO 7,333'600 GPM 8,085.0 7,333.0 12:45 18:15 930 PSI, 80 RPM @ 11.2K TORQUE. TRYING TO PACK OFF. 8/4/2019 8/4/2019 0.50 INTRMI CASING OTHR P PULL THE MPD HEAD & INSTALL 7,333.0 7,333.0 18:15 18:45 THE TRIP NIPPLE. 8/4/2019 8/4/2019 3.00 INTRMI CASING BKRM P BROOH F/ 7,333' TO 7,200'600 GPM 7,333.0 7,200.0 18:45 21:45 930 PSI, 80 RPM @ 13.5K TORQUE. TRYING TO PACK OFF. 8/412019 8/512019 2.25 INTRMI CASING CIRC P CBU X3 @ 1000 GPM, 1,975 PSI, 7,200.0 7,200.0 21:45 00:00 ECD @ 10.89 PPG. 8/512019 8/512019 6.00 INTRMI CASING BKRM P BROOH to 6,676' MD, 950-1,000 gpm, 7,200.0 6,676.0 00:00 06:00 1840-2050 psi, 70-80 rpm, TQ 10k. Slight packoff observed @ 7,115', pumped High Viz weighted (2lbs over) sweep, increase in cutting observed. 615/2019 8/5/2019 0.25 INTRMI CASING PULD P Lay Down Reamer. PU Wt 185k, SO 6,676.0 6,676.0 06:00 06:15 Wt 140k. 8/5/2019 8/5/2019 5.75 INTRMI CASING BKRM P BROOH to 5,675' MD, 1,000 gpm, 6,676.0 5,675.0 06:15 12:00 1 11,900 psi, 160 rpm, TQ 10k. 8/5/2019 815/2019 4.00 INTRMI CASING BKRM P BROOH to 5,258' MD, 1,000 gpm, 5,675.0 5,258.0 12:00 16:00 1,900 psi, 160 rpm, TQ 10k. Hi Vis nut plug sweep pumped. No change in cuttings returning at surface. 8!5/2019 8/5/2019 3.25 INTRMI CASING PMPO P Pump OOH with no rotation. 85 gpm, 5,258.0 4,506.0 16:00 19:15 260 psi. 8/5/2019 8/5/2019 2.25 INTRMI CASING CIRC P Circ & Stage the pumps up to 1000 4,506.0 4,506.0 19:15 21:30 Gpm @ 1,760 psi. Pump a high vis sweep. with no change at the shakers. 8/5/2019 8/6/2019 2.50 INTRMI CASING BKRM P BROOH to 4,129' MD, 1,000 gpm, 4,506.0 4,129.0 21:30 00:00 1,700 psi, 160 rpm, TO 6.5k. Hi Vis nut plug sweep pumped. No change in cuttings returning at surface. 8/6/2019 8/6/2019 8.00 INTRMI CASING BKRM P BROOH to 3,050' MD, 1000 gpm, 4,129.0 3,050.0 00:00 08:00 1650 psi, 160-180 rpm, TQ 5-6k. (@3,600' MDand 3,100' MD pump Hi Vis NP sweep, 30% increase in cuttings observed at shakers. @3,200' MPD cutting increased. Observed Slight Packoffs during BROOH. Page 10/29 ReportPrinted: 9/19/2019 Uperations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time our inn Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth dWE1) 8/6/2019 8/6/2019 1.25 INTRMI CASING BKRM P BROOH and pull into shoe to 2,905' 3,050.0 2,905.0 08:00 09:15 MD, 1000 gpm, 1650 psi. Slight packoff with 1 Ok overpull due top cuttings on BHA. Rotated 20 rpm, TO 5k from 2,975' MD to 2,905' MD. PU Wt 145k, SO Wt 120k. 8/6/2019 8/612019 1.75 INTRMI CASING CIRC P Circulate hole dean from 2,905' MD to 2,905.0 2,810.0 09:15 11:00 2,810' MD. 1000 gpm, 1580 psi, 100- 80 rpm, TO 5k. Pump Hi Vis Nut Plug sweep x2. observed increase in cuttings on tat sweep. During circulation observed in excess of 500 large 4"-6" clay balls that were hardened coming across the shakers in addition to heavy 1"-4" hardened day cuttings. Cuttings cleaned up to minimal size and volume. 8/6/2019 816/2019 0.25 INTRMI CASING OWFF P Observe Well for Flow. (Static) 2,810.0 2,810.0 11:00 11:15 8/612019 8/6/2019 0.75 INTRMI CASING PMPO P Pump OOH to 2,530' MD, 1000 gpm, 2,810.0 2,530.0 11:15 12:00 1560 psi. PU Wt 145k, SO Wt 125k. 8/6/2019 8/6/2019 4.25 INTRMI CASING PMPO P Pump OOH to 360' MD', 1000 gpm, 2,530.0 360.0 12:00 16:15 1560 psi. PU Wt 145k, SO Wt 125k. 816/2019 8/6/2019 0.25 INTRMI CASING OWFF P Observe Well for Flow. (Static) 360.0 360.0 16:15 16:30 8/6/2019 8/6/2019 2.00 INTRMI CASING BHAH P Lay Dawn Intermediate BHA, standing 360.0 0.0 16:30 18:30 back HWDP in derrick and laying down BHA components. 8/6/2019 8/6/2019 1.25 INTRMI CASING OTHR P Clean the Rig floor and put everything 0.0 0.0 18:30 19:45 back in its Place. 8/6/2019 8/6/2019 0.50 INTRMI WHDBOP OTHR P Flush the BOP with the wash tool 0.0 0.0 19:45 20:15 8/6/2019 8/6/2019 0.75 INTRMI WHDBOP OTHR P Pull the Wear out of the well head. 0.0 0.0 20:15 21:00 The wear Bushing looked Good. 8/612019 816/2019 1.50 INTRMI WHDBOP RURD P Pull the 3 112" X 6" upper pipe rams, 0.0 0.0 21:00 22:30 and Install the 9 5/8" Casing Rams. 8/6/2019 817/2019 1.50 INTRMI WHDBOP RURD P Set the Test plug With the 9 518" test 0.0 0.0 22:30 00:00 joint. 817/2019 8/7/2019 6.00 INTRMI WHDBOP BOPE P Test BOPE. (ALL TESTS PASS) 250 0.0 0.0 00:00 06:00 psi Low / 3,500 psi High, 5 min each (Charted) Test Bag and UPR 9-518" rams with 9-5/8" Test Joint. Test Bag and LPR 3.54" VBRs with 5-7/8" test joint. Test chokes valves 1-14, neddle Valve above #1, Auto/Manual, IBOP, HCR Choke, HCR Kill, 4" DEMCO, 5- 718" FOSV and Dart, Blinds. Accumulator tested - FSP 3100 psi, PAC 1450 psi, 200 psi build 22 sec, FSP 144 sec. 4 Nitrogen bottle 2050 average pressure. Performed 1500 psi drawdown test on manual and hydraulic choke. Tested gas alarms, PVT, Flow meter. Witnessed by AOGCC Representative Guy Cook. 8/712019 8R/2019 1.00 INTRMI WHDBOP RURD P Rig Down BOP test equipment. Well 0.0 0.0 06:00 07:00 STATIC entire test. 8/712019 8/7/2019 0.50 INTRMI CASING PULD P Dummy Run 9-5/8" Cameron Hangar. 0.0 0.0 07:00 07:30 8/7/2019 817/2019 3.00 INTRMI CASING RURD P Rig Up to run 9-5/8" casing. 0.0 0.0 07:30 10:30 817/2019 817/2019 0.25 INTRMI CASING SFTY P PJSM Running Casing with all hands 0.0 0.0 10:30 10:45 and vendors involved present. Page 11129 ReportPrinted: 911912019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Damm start Time End Time Dm (no Phase Op code Actively code Time P -T -X Operation (fiKB) I End Depth (aKB) 8/7/2019 8/7/2019 0.50 INTRMI CASING PUTS P Pick Up and Make Up sShow 0.0 133.0 10:45 11:15 assembly Baker Locking connection to the pin on joint if4. Check floats (good). 817/2019 8/7/2019 0.75 INTRMI CASING PUTB P Pick Up 9-7/8" casing and run per 133.0 258.0 11:15 12:00 casing detail to 258' MD. 8/7/2019 8/7/2019 7.00 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 258.0 2,927.0 12:00 19:00 1 1 run per casing detail to 4,090' MD. 8/7/2019 6/7/2019 1.00 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 to 2,927.0 2,966.0 19:00 20:00 4 bpm, 100 psi. 10.3 ppg in/out. PU Wt 170k, SO Wt 150k. 8/7/2019 8/712019 2.25 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 2,966.0 3,864.0 20:00 22:15 run per casing detail to 3,864' MD. 8/7/2019 8/712019 0.25 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 to 3,864.0 3,864.0 22:15 22:30 4 bpm, 150 psi. 10.3 ppg infoul. PU Wt 190k, SO Wt 163k. 8/7/2019 8/8/2019 1.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 3,864.0 4,121.0 22:30 00:00 run per casing detail to 4,121' MD. 8/8/2019 8/8/2019 2.50 INTRMI CASING PUTS P Continue to Pick Up 9-7/8" casing and 4,121.0 5,100.0 00:00 02:30 mn per casing detail to 5,100' MD. SO Wt 155k. 8/8/2019 8/8/2019 1.50 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 to 5,100.0 5,100.0 02:30 04:00 4 bpm, 140 psi. 10.3 ppg in/out. PU Wt 21 Ok, SO Wt 165k. 8/8/2019 8/8/2019 2.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 5,100.0 6,165.0 04:00 06:30 run per rasing detail to 6,165' MD. SO Wt 165k. 8/812019 8/812019 2.50 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 to 6,165.0 6,165.0 06:30 09:00 4 bpm, 180 psi. 10.3 ppg in/out. PU Wt 230k, SO Wt 175k. 8/8/2019 8/8/2019 2.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 6,165.0 7,212.0 09:00 11:30 run per casing detail to 7,212' MD. SO Wt 167k. 8/8/2019 8/8/2019 2.75 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 to 7,212.0 7,212.0 11:30 14:15 4 bpm, 200 psi. 10.3 ppg in/out. PU Wt 250k, SO Wt 180k. 818/2019 818/2019 3.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 7,212.0 8,266.0 14:15 17:45 1 1 run per casing detail to 8,266' MD. 818/2019 8/812019 2.50 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 8,266.0 8,266.0 17:45 20:15 (130 psi) to 4 bpm (250 psi). 10.3 ppg in/out. PU Wt 275k, SO Wt 175k. 8/8/2019 8/8/2019 3.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 8,266.0 9,317.0 20:15 23:45 run per casing detail to 9,317' MD. 8/8/2019 8/9/2019 0.25 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 9,317.0 9,317.0 23:45 00:00 bpm (140 psi). 10.3 ppg in/out. PU Wt 31 Ok, SO Wt 170k. 8/9/2019 819/2019 3.50 INTRMI CASING CIRC P Continue Circulate BU, stage pumps 9,317.0 9,317.0 00:00 03:30 to 4 bpm (300 psi). 10.3 ppg in/out. PU Wt 295k, SO Wt 185k. 8/9/2019 81912019 3.50 INTRMI CASING PUTS P Continue to Pick Up 9-5/8" casing and 9,317.0 10,363.0 03:30 07:00 run per casing detail to 10363' MD. SO Wt 185k. 819/2019 8/9/2019 3.00 INTRMI CASING CIRC P Circulate BU, stage pumps to 5 bpm 10,363.0 10,363.0 07:00 10:00 (320 psi). 10.3 ppg in/out. PU Wt 325k, SO Wt 185k. 81912019 8/912019 3.25 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" rasing and 10,363.0 11,413.0 10:00 13:15 run per casing detail to 11,413' MD. SO Wt 175k. 8/9/2019 8/9/2019 3.50 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 11,413.0 11,413.0 13:15 16:45 bpm (320 psi) to 4 bpm (370 psi). 10.3 ppg in/out. PU Wt 345k, SO Wt 185k. Page 12129 ReportPrinted: 9/1912019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sled Depth start Time EMTme Dur rv) Phase Op Code AOviry CWe Time P-T-X Openebm (fIKB) End Dept (f1KB) 8/9/2019 8/9/2019 3.75 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 11,413.0 12,468.0 16:45 20:30 run per casing detail to 12,440' MD. SO Wt 185k. 8/9/2019 8/10/2019 3.50 INTRMI CASING CIRC P Circulate BU, stage pumps from 0.5 12,468.0 12,468.0 20:30 00:00 (310psi) to 5 bpm (450 psi). 10.3 ppg in/out. (Increase in cutting observed at BU.) Initial PU Wt 425k. PU Wt 370k, SO Wt 1761k. 8/10/2019 8/10/2019 1.00 INTRMI CASING CIRC P Continue to Circulate BU,at 5 bpm 12,468.0 12,468.0 00:00 01:00 (430 psi). 10.3 ppg in/out. PU Wt 375k, SO Wt 1801k. 8/10/2019 8/10/2019 1.50 INTRMI CASING PUTS P Continue to Pick Up 9-5/8" casing and 12,468.0 12,960.0 01:00 02:30 run per casing detail to 12,960' MD. SO Wt 175k. Observed taking weight. 8/10/2019 8/10/2019 5.50 INTRMI CASING PUTB P Continue to Pick Up 9-5/8" casing and 12,960.0 13,445.0 02:30 08:00 wash down per casing detail to 12,440' MD. SO Wt 185k. 8/10/2019 8/10/2019 0.50 INTRMI CASING PUTB P Pick Up Casing Hanger and landing 13,445.0 13,485.0 08:00 08:30 joint. Circulate while running in. Lands on shoulder on appropriate depth. 8/10/2019 8/10/2019 4.00 INTRMI CEMENT CIRC P Circulate and Condition mud and 13,485.0 13,485.0 08:30 12:30 clean hole while recipricating pipe 10'- 20' strokes 8/10/2019 8/10/2019 0.75 INTRMI CEMENT RURD P Shut down pumps to hook up cement 13,485.0 13,485.0 12:30 13:15 lines to Volant tool. Finish hooking up cement unit to dg. 8/10/2019 8/10/2019 1.00 INTRMI CEMENT CIRC P Circulate and condition mud. String 13,485.0 13,485.0 13:15 14:15 not free with 45-50k overpull so decision to leave seated on hanger for duration on job. SIMOPS: PJSM for Cement job. 8/10/2019 8/10/2019 5.25 INTRMI CEMENT CMNT P Pump Cement Job. 5 bbls water. 13,485.0 0.0 14:15 19:30 Pressure test lines to 3500 psi. Pump 55.0 bbis of 13.25 ppg - 13.5 ppg Mud Push II @ 3-5 bpm, 320-178 psi). Drop Bottom Plug (confirmed by CoMan). Pump 140.2 bbls 15.8 ppg Class G Cement @ -5 bpm, 350-56 psi. Drop 2 Top plugs (locking plug first in hole, HES -HWE plug 2nd in hole, Confirmed by CoMan ). Pump 10 bbls water clean up and switch to Rig Pumps for remaining displacement. Pump 975.7 bbls of 10.5 ppg LSND drilling mud. FCP 713 psi. Pressure up to 1200 psi for 5 minutes. CHeck floats. Float held. Cement in place 18:59. 8/10/2019 8/10/2019 1.75 INTRMI CEMENT RURD P Rig Down Cement Iines,UD volant 0.0 0.0 19:30 21:15 lool,UD Landing joint, & UD the long Bales. 8/10/2019 8/10/2019 1.00 INTRMI CEMENT SVRG P Service the rig and the top drive. 0.0 0.0 21:15 22:15 8/10/2019 8/10/2019 0.50 INTRMI CEMENT RURD P Install the Rig's Bales & elevator,and 0.0 0.0 22:15 22:45 the link tilt. 8/10/2019 8/10/2019 0.75 INTRMI CEMENT PULD P Break a single Joint of pipe off of 0.0 0.0 22:45 23:30 stand of Drill pipe to run to run the wash tool. 8/10/2019 8/11/2019 0.50 INTRMI WHDBOP OTHR P M/U the stack washing tool & wash 0.0 0.0 23:30 00:00 1 out the BOPE before Setting the 9 5/8" Packoff. Page 13129 Report Printed: 9119/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth stat Time End Time our (hr) Phase Op Cote A vmty Code nme P -T -X Operetlon (IIKS) End Depth (XKB) 8/11/2019 8/11/2019 3.00 INTRMI WHDBOP WWSP P Drain Stack. WU Pack -Off Running 0.0 0.0 00:00 03:00 tool. Set Packoff and RILDS. Test Packoff to 5,000 psi for 10 min. SIMOPS: Work on Top Drive. 8/11/2019 8/11/2019 1.25 INTRMI WHDBOP RURD P Change Out Upper Rams bodeis to 0.0 0.0 03:00 04:15 4.5" x 7" VBRs. SIMOPS: Work on Top Drive. 8/11/2019 8/11/2019 0.50 INTRMI CEMENT SVRG P Service Top Drive Blocks. 0.0 0.0 04:15 04:45 1 1 StMOPS: Work on Top Drive. 8/11/2019 8/11/2019 4.25 INTRMI CEMENT SVRG T Work on Top Drive. 0.0 0.0 04:45 09:00 SIMOPS: Maintain Drag Chain. Work on mud Pump Liners. Load 5-7/8" Drill Pipe and 7" Casing/Liner in Pipe Shed. 8/11/2019 8/11/2019 5.00 INTRMI CEMENT FRZP P Freeze Protect Well. Flush with 200 0.0 0.0 09:00 14:00 bbls of water with rig pumps (4 bpm, ICP 130 psi, FCP 800 psi). Chase with 135 bbfs Diesel pumped by LRS (2 bpm, ICP 580, FCP 800). SIMOPS: Test 7" and 5-7/8" joints on 4.5"x7" VBRs were changed out. Process 5-7/8" Drill Pipe and 7" casing in pipe shed. 8/11/2019 8/11/2019 0.50 INTRMI CEMENT RURD P Rig Down Freeze Protect. 0.0 0.0 14:00 14:30 SIMOPS: Test 7" and 5-7/8" joints on 4.5"x7" after VBRs were changed out. Continue Processing 7" casing in pipe shed. 8/11/2019 8/11/2019 0.50 INTRMI WHDBOP BOPE P Test 7" and 5-7/8" joints on 4.5"x7" 0.0 0.0 14:30 15:00 VBRs after VBRs were changed out. 8/11/2019 8/11/2019 0.75 INTRMI WHDBOP RURD P Pull Test Plug and Set Wear Ring. 0.0 0.0 15:00 15:45 8/11/2019 8/11/2019 0.25 INTRMI DRILLOUT SFTY P PJSM, PU BHA Intermediate 2. 0.0 0.0 15:45 1600 8/11/2019 8/11/2019 3.00 INTRMI DRILLOUT BHAH P PU Intermediate 2 BHA per SLB DD. 0.0 350.2 16:00 1900 8/11/2019 8/11/2019 2.00 INTRMI DRILLOUT TRIP P Trip in hole with 5-7/8" Drill Pipe 350.2 2,198.0 19:00 21:00 stands out of derrick to 2,198' MD. 8/11/2019 8/11/2019 0.50 INTRMI DRILLOUT CIRC P Shallow Pulse Test of BHA/MWD. 2,198.0 2,198.0 21:00 21:30 8/11/2019 8/11/2019 1.00 INTRMI DRILLOUT SLPC P Slip and Cut 98' Drilling Line. 2,198.0 2,198.0 21:30 2230 8/11/2019 8/1112019 0.50 INTRMI DRILLOUT SVRG P Service Rig and Top Drive inspection. 2,198.0 2,198.0 22:30 23:00 8/11/2019 8/11/2019 0.50 INTRMI DRILLOUT SVRG T Inspect RLA shot pin, grab head 2,198.0 2,198.0 23:00 23:30 solenoid. 8/1112019 8/12/2019 0.50 INTRMI DRILLOUT TRIP P Trip in hole with 5-7/8" Drill Pipe 2,198.0 3,001.0 23:30 00:00 stands out of derrick to 3,001' MD. 8/12/2019 8/12/2019 11.25 INTRMI DRILLOUT TRIP P Trip in hole with Intermediate *2 8 1/2" 3,001.0 13,392.0 00:00 11:15 BHA to 13,13,392' MD to tag washing down last 48'@ 100 gpm, 640 psi. PU Wt 300k, SO Wt 100k.. 8/12/2019 8/12/2019 3.25 INTRMI DRILLOUT CIRC P Circulate BU. 13,392.0 13,395.0 11:15 14:30 SIMOPS: RU for Casing lest.and rig down testing Equipment. 8/12/2019 8/12/2019 4.75 INTRMI DRILLOUT DDRL P Drill the wiper plugs F/13,395', Float 13,395.0 13,496.0 14:30 1915 Collar, and the cement and the float shoe, @ TO 13,496' 8/12/2019 8/12/2019 1.00 INTRMI DRILL DDRL P Drill 20' of new formation for fit test f/ 13,496.0 13,516.0 19:15 20:15 13,496'to 13,516' 8/12/2019 8/12/2019 0.75 INTRMI DRILL CIRC P Circ the Hole Clean for the fit test @ 13,516.0 13,516.0 20:15 21:00 13,516' Page 14129 Report Printed: 9/1912019 Uperations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Dept Start Time End Time Dur(hr) Phase Op Code Adrvity Code Time P -T -X Operabon (ftKB) End Depth(ftKB) 8/12/2019 8/12/2019 0.25 INTRMI DRILL TRIP P TOOH f/ 13,516' MD to 13,375' MD 13,516.0 13,375.0 21:00 21:15 into the 9 5/8" Casing for FIT test. 8/12/2019 8/12/2019 0.75 INTRMI DRILL FIT P Perform the FIT test to a 16.0 PPG 133,750.0 13,375.0 21:15 22:00 equivalent. the test held good @ 660 psi. 8/12/2019 8/12/2019 1.50 INTRM2 DRILL RURD P POOH to 13,343' MD. Pull the flow 13,375.0 13,343.0 2200 2330 Nipple And Install the MPD bearing. 8/12/2019 8/13/2019 0.50 INTRM2 DRILL TRIP P Tih The hole f/ 13,343' to 13,470'to 13,343.0 13,470.0 2330 0000 start displacing the 10.3 ppg mud W/ the 10.5 ppg mud. 8/13/2019 8/13/2019 2.75 INTRM2 DRILL CIRC P Continue to circulate new mud 13,470.0 13,470.0 00:00 02:45 system, 10.5 ppg LSND, 400-500 gpm, 1500-2000 psi, 30 rpm, TO 17k. PU Wt 280k, SO Wt 120, ROT Wt 175k. 8/13/2019 8/13/2019 0.25 INTRM2 DRILL WASH P TIH to 13,516' MD Wash and 13,470.0 13,516.0 02:45 03:00 Reaming, 500 gpm, 2040 psi, 70 rpm, TO 22k. 8/13/2019 8/13/2019 3.00 INTRM2 DRILL DDRL P Drill 81/2" hole from 13516'- 13,516.0 13,626.0 03:00 06:00 13626'with #2 mud pump, 500 GPM - 2020 PSI, 80 RPM's - 28K TQ. Drop flow to 210 GPM's - 71 PSI for 2.5 minutes, ten increasing flow to 500 GPM's - 1730 PSI to open the underreamer. (TRPM Open / closed - 3164 PSI / 3906 PSI with 510 GPM's) From 13615'- 13606', Pull 5K on the shoe on depth. ( Verify open reamer.) Ream from 13606'- 13626' with 500 GPM's - 1750 PSI, 120 RPM's - 30K TQ, 8/13/2019 8/13/2019 0.75 INTRM2 DRILL DDRL P Drill 8 1/2" x 9 7/8" hole from 13626' T/ 13,626.0 13,626.0 06:00 06:45 13606, (BROOH T/ 13615' W/ 500 gpm, 2020 SPP, 80 RPM, 28k trq, drop flo T/ 210 gpm, 710 psi F/ 2.5 mion, increase Flo T/ 500 gpm, 1730 psi, TRPM open/close = 3164/3906 @ 510 gpm, F/ 3615 T 13606 pull 5k on shoe verdddy RMR open, ream F/ 13606' T/ 13626'w/ 500 gpm, 1750 spp, 120 rpm, 30K trq. 8/13/2019 8/13/2019 5.25 INTRM2 DRILL DDRL P Drill 8 1/2" hole F/13626' T/ 13834' 13,626.0 13,834.0 06:45 1200 DRLG 8.5 X 9 7/8 int # 2 hole, W/ 500 GPM- 1820 SPP. 150 RPM'S, 30K TO. wob 10/15k, p/u 275k, DAN 175K, RWT 175K 8/13/2019 8/13/2019 6.00 INTRM2 DRILL DDRL P Drill 8 1/2" hole F/ 13834'T/ 14078' 13,834.0 14,078.0 12:00 1800 MD, 6035' TVD, DRLG 8.5 X 9 7/8 int # 2 hole, W/ 500 GPM- 1820 SPP. 150 RPMs, 29/33K TO. wob 10/16k, holding 660 psi BP on connection W/ MPD, p/u 275k, DAN 128K, RWT 180K, off bottom TRQ 17K, ADT 5.25 Bit HRS 11.51 Jar HRS 11.51 8/13/2019 8/14/2019 6.00 INTRM2 DRILL DDRL P Drill 8 1/2" hole F/ 14078'T/ 14285.0 14,078.0 14,285.0 18:00 00:00 MD, 6075' TVD, DRLG 8.5 X 9 7/8 int # 2 hole, W/ 500 GPM- 1810 SPP. 150 RPM'S, 31 K TQ. wob 15/17k, holding 660 psi BP on connection W/ MPD, p/u 275k, D/W 125K, RWT 185K, off bottom TRQ 17K, ADT 5.01 Bit HRS 16.52 Jar HRS 16.52 8/14/2019 8/14/2019 1.75 INTRM2 DRILL CIRC P Recip. pipe & CBU @ 14285', W/ 500 14,285.0 14,285.0 00:00 01:45 GPM, 1700 SPP, 150 RPM, 30K TRQ, p/u 295k, S/O 120k, ROT185k. Page 15/29 ReportPrinted: 9/19/2019 Operations Summary (with Timelog Depths) qW2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(Irn Phase Op Code Activity Code Time P -T-% Operation (ftKB) End Depth(ftKB) 8/14/2019 8/14/2019 1.00 INTRM2 DRILL MPDA P Draw DWN test @ 14285', Ramp 14,285.0 14,285.0 01:45 02:45 DWN holding 585 psi F/ 10 min. Bleed own T/ 0 psi, in 150 psi inc. Open choke @ 50% F/ 5 min, shut in to verify 0 psi build up, rotate @ 5 rpm, 1 OK lorq, OWFF on T/T, 1 bbl gain F/ bleed off. 8/14/2019 8/14/2019 3.50 INTRM2 DRILL CIRC P CBU, @ 14225', Weight up mud 14,285.0 14,225.0 02:45 06:15 system F/ 10.5 T/ 10.8 ppg, W/ 4751 525 gpm, 1600 T/1770 SPP, 100 RPM, 30K TRQ, maint. 13.0 ECD'S, Drop Flo T/ 215 gpm 700 SPP F/ 2.5 min, T/ close RMR, 475 GPM 1850 SPP TRPM, FR/ 3067 T/ 3632 T/ verify closed. P/U 295K, S/O 135K, ROT 180K 8/14/2019 8/14/2019 0.25 INTRM2 DRILL OWFF P OWFF (Static) 14,225.0 14,225.0 06:15 06:30 8/14/2019 8/14/2019 2.00 INTRM2 DRILL SMPD P Line up & SOOH F/ 14225' 14,225.0 13,407.0 06:30 08:30 T/13407; (observed 35K over pull) in / out slips = 100 / 250 psi. Drop 2.35" HID @ 13882.' P/U 295K, S/O 135K, 8/14/2019 8/14/2019 2.25 INTRM2 DRILL CIRC P CBU @ 13407', W/ 475 GPM, 1870 13,407.0 13,407.0 08:30 10:45 SPP, 40 RPM, 13K TRQ 8/14/2019 8/14/2019 0.25 INTRM2 DRILL OWFF P OWFF, well Static. 13407.0 12,458.0 10:45 11:00 8/14/2019 8/14/2019 1.00 INTRM2 DRILL SMPD P SOOH F/ 13,407'T/ 12458', P/U 12,458.0 0.0 1100 12:00 280K, S/O 135K, In / Out Slips, 65/ 200 psi. 8/14/2019 8/15/2019 12.00 INTRM2 DRILL SMPD P SOOH F/ 12458', T/ 2707', wrk w/ 1200 0000 tight connections on 5 7/8 DP, P/U 142K, In / Out Slips, 65/ 200 psi. 8/15/2019 8/15/2019 1.75 INTRM2 DRILL SMPD P Continue SOOH F/ 2720'to 789' with 2,720.0 789.0 0000 01:45 MPD, P/U 100K, SO Wt 90K. In / Out Slips, 60/ 80 psi. 8/15/2019 8/15/2019 0.25 INTRM2 DRILL OWFF P OWFF. ( Static) ( DIMOPS: PJSM - 789.0 789.0 01:45 02:00 1 PJSM -pulling MPD Bearing.) 8/15/2019 8/15/2019 0.50 INTRM2 DRILL MPDA P Pull MPD bearing / Install Trip nipple. 789.0 789.0 0200 0230 8/15/2019 8/15/2019 1.25 INTRM2 DRILL TRIP P Trip out of hole form 789'to 318'. 789.0 318.0 0230 0345 Observed correct hole fill off of trip tank. Up - 85K, SO WT -80K. Calculated hole fill at 169.4 BBLS - Aclual - 175.5 8/15/2019 8/15/2019 0.25 INTRM2 DRILL OWFF P OWFF. ( Static) (DIMOPS: PJSM - 318.0 318.01 03:45 04:00 PJSM -Lay down BHA 8/15/2019 8/15/2019 3.00 INTRM2 DRILL PULD P POOH from 318', breakout and lay 318.0 0.0 04:00 07:00 down BHA as per DD & MWD reps.lnspect and grade bit to 0 -1 -WT - G -I -NO -TD 8/15/2019 8/15/2019 0.50 INTRM2 CASING BHAH P Clean and clear rig floor area. Send 0.0 0.0 07:00 07:30 tools out. Monitor well on TT, static. 8/15/2019 8/15/2019 1.75 INTRM2 CASING RURD P Pull tools to rig floor. Rig up GBR 0.0 0.0 0730 0915 casing with power tongs to run liner Make up mud fill up line. Held PJSM with entire crew, GBR and Baker reps. 8/15/2019 8/15/2019 0.50 INTRM2 CASING SVRG P Service rig. Inspect and clear debris 0.0 0.0 09:15 0945 from electronic eye on pipe machine. Function test to verify all good. Page 16129 Report Printed: 911 912 01 9 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stele Time End Time our (hr) Phase Op Code Activiry Cade Time P-T-X Operation Stall Deplh (kKa) End Depth (ftKa) 8/15/2019 8/15/2019 2.25 INTRM2 CASING RUNL P Make up 7" 26# shoe track with Davis 0.0 903.0 09:45 12:00 Lynch float shoe, plug landing collar and float collar. Make up torque on connections 9400 Ft/lbs, with shoe track baker locked. Fill shoe track with mud, and verify floats functioning. All good. Continue pick up 7" liner and RIH. Crew Change 8/15/2019 8/15/2019 0.50 INTRM2 CASING RUNL P Continue run 7" 26# liner as per detail 903.0 993.0 12:00 12:30 with a total of 24 JNTs ran. Centralizers in place as per plan. Make up Torque - 9400 FUlbs as planned. 8/15/2019 8/15/2019 1.00 INTRM2 CASING RUNL P Make up Baker 7" x 9 68" Liner 993.0 1,033.0 12:30 13:30 hanger and packer assembly. Verify plugs pinned and in place. Verify Xan Plex D made up and poured into tieback assembly. Secure lock down screws. Make up torque - 22K on 4 1/2" x 5 7/8" crossover. 8/15/2019 8/15/2019 0.50 INTRM2 CASING CIRC P Make up 1 stand of 5 7/8" OR Screw 1,033.0 1,033.0 13:30 14:00 into Top Drive and pump 50 BBLS at 3 BPM - 120 PSI as per Baker rep. 8115/2019 8/1512019 0.25 INTRM2 CASING SVRG P Observed Top Drive issues with IBOP 1,033.0 1,123.0 14:00 14:15 function. Trouble shoot same. Service rig. 8/15/2019 8/15/2019 3.50 INTRM2 CASING RUNL P Trip in hole F/ 1123'T/ 4797,' with 7" 1,123.0 4,797.0 14:15 17:45 26# Liner assembly, Liner hamger and packer assembly. Running speeds at 90 FUMin as per Baker rep. Observed correct hole fill, and displacement. 8/15/2019 8/15/2019 1.50 INTRM2 CASING RGRP T Work on top Drive, change out 4,797.0 4,797.0 17:45 19:15 pressure reducing cartridge, pump up accumaltor check shock pin. 8115/2019 8/16/2019 4.75 INTRM2 CASING RUNL P Trip in hole F/ 4805' T/ 10450', with 7" 4,797.0 10,450.0 19:15 00:00 26# Liner assembly, Liner hamger and packer assembly. Running speeds at 90 Ft/Min as per Baker rep. Observed correct hole fill, and displacement. (Fill pipe every 20 stds) 8/16/2019 8/1612019 3.50 INTRM2 CASING RUNL P RIH w/ T' 26# L-80 Hydrill 563 Liner, 10,450.0 13,463.0 00:00 03:30 On DP, F/ 10450'T/ 13'463', filling pipe every 20 stds. S/O 125K, 8/16/2019 8/16/2019 1.25 INTRM2 CASING CIRC P CBU @ 13463', Staging pumps up T/ 13,463.0 13,463.0 03:30 04:45 8 BPM, SPP 760, P/U 270K, S/O 144K 8116/2019 8/1612019 1.50 INTRM2 CASING RUNL P RIH w/ 7" 26# L-80 Hydrill 563 Liner, 13,463.0 14,219.0 04:45 06:15 On DP, F/13'463' T/ 14219', filling pipe every 20 stds. P/U 290K, S/O 130K, 8/16/2019 8/16/2019 0.50 INTRM2 CASING RUNL P Wash down 7" 26# L-80 Hydrill 563 14,219.0 14,283.0 06:15 06:45 Liner, On DP, F/ 14219'T/14285', Q 2bpm, 480 psi, set down IOK T/ confirm bottom. 8/16/2019 8/16/2019 1.75 INTRM2 CASING CIRC P Circulate & cond. mud Staging rate up 14,283.0 14,283.0 06:45 08:30 T/ 8 BPM, 850 psi, P/U 305K, S/O 127K. 8/1612019 8/1612019 0.75 INTRM2 CASING RURD P Rig up cement lines, cement head. 14,283.0 14,283.0 08:30 09:15 Schlumberger on locaflon rigging up. 8/16/2019 8/16/2019 1.50 INTRM2 CEMENT CIRC P Continue circulating thru cement line, 14,283.0 14,283.0 09:15 10:45 @ 3 BPM, ICP 540 psi,FCP 430 psi, P/U 305K, S/O 127K Page 17129 ReportPrinted: 9/1912019 Uperations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log SWM1 Depth De StanTns End Time our (hr) Phase Op Cade Asti Code N Time P-T-X Operatioe (rt End OepN (XKa) 8/16/2019 8/16/2019 2.25 INTRM2 TEMENT P Cement 7" liner per SLM SCH D, 14,283.0 14,283.0 10:45 13:00 pump 5 bbls FW, PT cmt lines @ 4500 psi, pump 45 bbls 14PPG MP11 @ 5 BPM, @ 492/500 pdi, drop bottom dart ( no flag confirmation that. dart away), Discuss Engineer and Baker office. Decision to keep pumping. Pump 65 bbls 15.8 ppg cmt @ 4 BPM, 102 psi, Drop top dart, ( Flag indicated dart away) pump 10 bbls FW, line up T/ rig , Displace @ 10.8 ppg W/ LSND mud, @ 7BPM, 740 / 920 PSI, reduce Rale @ 4BPM @ 720 psi, Final circ psi = 1020, Plug bumped @ 3310 stks. Increase psi.T/ 3000 psi hold F/ 5 Min. F/ liner hanger set. cement in place @ 12:58 PM 8/16/2019 8/16/2019 8/16/2019 1.50 INTRM2 CEMENT PACK P Set Flex Lock liner hanger per BOT 14,283.0 14,283.0 13:00 14:30 rep. P/U 300K, SIO 145K, PKR set, Increase PSI T/ 1000 psi, T/ release RS pack - off, OWFF (Static), POOH 30', T/ Gear from TOL @ 13258', ( PSI drop confimed), Circ out excess cement T/ surface @ 9 BPM, ICP = 1240 psi, FIC = 1015. 8/16/2019 8/16/2019 1.00 INTRM2 CEMENT CMNT P Rig DWN cementing equip. 14,283.0 14,283.0 14:30 15:30 8/16/2019 8/16/2019 1.50 INTRM2 CEMENT PRTS P POOH, F/13228' T/ 13124'W/ liner 14,283.0 13,124.0 15:30 17:00 Running tools, R/U & test PKR @ 1000 psi F/ 10 min. Record on chart,Test Good, R/D testing equip. 8/16/2019 8/16/2019 0.50 INTRM2 CEMENT TRIP P Pump 22 bbl dry job, Prep tools F/ 13,124.0 13,124.0 17:00 17:30 tripping ouit of hole. 8/16/2019 8/16/2019 3.75 INTRM2 CEMENT TRIP P Trip out of hole F/ 13124' T/ 8355'w/ 13,124.0 8,355.0 17:30 21:15 liner running tools, racking back 5 7/8" DP. Breakout torque normal on the connections that we had Kopper Kote pipe dope on. 8/16/2019 8/16/2019 0.50 INTRM2 CEMENT SVRG P Rig service, 8,355.0 8,355.0 21:15 21:45 8/16/2019 8/17/2019 2.25 INTRM2 CEMENT TRIP P Trip out of hole F/ 8355' T/ 5238'W/ 8,355.0 5,238.0 21:45 00:00 liner running tools.Bmakout torque normal on the connections that we had Kopper Kote pipe dope on. 8/17/2019 8/17/2019 3.00 INTRM2 CEMENT TRIP P Continue to TOH from 5250'- 1350' 5,238.0 1,350.0 00:00 03:00 racking back 5 7/8" DP. Observed proper displacement. Total racked back 135 stnds. 8/17/2019 8/17/2019 4.50 INTRM2 CEMENT TRIP P Continue POOH with 5 7/8" DP laying 1,350.0 50.0 03:00 07:30 down last 42 joints in string. Observed breakout torques up to 74K utilizing larger HT 100 rig tongs and snubbing off procedures to breakout. Observed proper displacement. 8/17/2019 8/17/2019 0.75 INTRM2 CEMENT PULD P Inspect liner running tools and Baker 50.0 0.0 07:30 08:15 rep verified all good on the tool. Breakout and lay down same. 8/17/2019 8/17/2019 1.00 INTRM2 CEMENT CLEN P Clean & Clear dg floor area of tools. 0.0 0.0 08:15 09:15 Send out HT100 Rig tongs. Rig up GV91 Rig Tongs. 8/17/2019 8/17/2019 0.75 INTRM2 CEMENT P Make up BOP stack washer tool, and 0.0 0.0 09:15 10:00 flush BOP stacck at 9 BPM - 80 PSI. I JWASH Rig down washing tool, and srain BOP stack. Page 18/29 Report Printed: 9/1912019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Our (hr) phase op code Activity Code Time P -T -X operatlon (ftKB) End Depth (ftKB) 8/17/2019 8/17/2019 2.00 INTRM2 CEMENT BOPE P Held PJSM with crew. Discuss ram 0.0 0.0 1000 12:00 changing operation. Discuss safety hazards/ (SIMOPS) Remove 4 1/2" x 7" VBR's. Clean and lay down same. Install 3 1/2" x 6" VBRs. Change out Top Drive 5 7/8" saver sub. Crew Change 8/17/2019 8/17/2019 0.75 INTRM2 CEMENT RURD P BOLDS, Pull wear ring. Install test 0.0 0.0 12:00 12:45 plug. 8/17/2019 8/17/2019 2.00 INTRM2 WHDBOP RURD P Rig up lines and test chart to test 0.0 0.0 12:45 14:45 BOP'S.. Hold PJSM with crew. Discuss high pressure isues, and safety hazards. Set out BOP test warning signs. Observed outer OA at 600 PSI. 8/17/2019 8/17/2019 7.25 INTRM2 WHDBOP BOPE P Test BOP'S. Test w/ 3 1/2" - 4" & 5 7/8 0.0 0.0 14:45 22:00 test Its, Test Ann, upper 3 1/2" X 6" VBR, Lower rams, Blid rams, choke valves, 1 thru 14, - 4" & 5 7/8 Dart valve, 4" & 51718 FOSV's, 4" demoo fill valve, HCR kill & choke valves, Auto IBOP & manual IBOP valves, perform Super choke & man. choke draw down, W/ 1200 psi. Gas alarms tested, Perform Accumlator Test - Int = 3100 - PAC = 1525, 200 psi = .26 sec - FSP 150 sec - 4 bit average = 2000 psi Test BOP'S & Valves @ 250 / 3500 psi F/ 5 min ea. 8/17/2019 8/18/2019 2.00 INTRM2 WHDBOP RURD P Rig down testing equip.install 12.5 0.0 0.0 22:00 00:00 short wear bushing, finish getting tools & equip. F/ 6 1/8 bha T/ RF. Crew Change 8/18/2019 8/18/2019 0.50 INTRM2 DRILLOUT RURD P Continue pull production BHA tools 0.0 0.0 00:00 00:30 and equipment to dg floor. SIMOPS - Load pits with 9.2 PPG Flo Pro. 8/18/2019 8/18/2019 0.25 INTRM2 DRILLOUT SFTY P Held PJSM with rig crew, DD & MWD. 0.0 0.0 00:30 00:45 Discuss picking up 6 1/8" BHA procedure, safety hazards and mitigation. Discuss safety of installing nuclear source in BHA. 8/18/2019 8/18/2019 1.75 INTRM2 DRILLOUT PULD P Make up 6 1/8" Smith bit and drilling 0.0 137.0 00:45 02:30 BHA. Install floats. 8/18/2019 8/18/2019 0.75 INTRM2 DRILLOUT PULD P Clear Rig floor, Load nuclear source in 137.0 137.0 02:30 03:15 BHA. 8/18/2019 8/18/2019 3.00 INTRM2 DRILLOUT TRIP P Trip in hole, picking up 4" DP from 137.0 2,230.0 03:15 06:15 shed. Drift DP to 3.25". 6/18/2019 8/18/2019 0.75 INTRM2 DRILLOUT TRIP P Perform shallow pulse test @ 2230". 2,230.0 2,230.0 06:15 07:00 Mud weight - 10.8 PPG. Pumps at 230 GPM's - 1220 PSI. Good test. Blow down TD. 8/18/2019 8/18/2019 2.00 INTRM2 DRILLOUT TRIP P Continue tripping in hole with 4" DP F/ 2,230.0 3,997.0 07:00 09:00 2230' T/3997' S/o 97K 8/18/2019 8/18/2019 1.50 INTRM2 DRILLOUT TRIP P Fill pipe @ 3997', Down link T/ tum on 3,997.0 3,997.0 09:00 10:30 sonicScope, logging tools W/ 245 gpm, 1550 SPP 8/18/2019 8/18/2019 1.25 INTRM2 DRILLOUT DLOG P F/ 3997'T/ 4501', RIH w/ 4" DID 3,997.0 4,501.0 10:30 11:45 logging Fries Ringing pipe. So 97K 8/18/2019 8/18/2019 0.75 INTRM2 DRILLOUT TRIP P @ 4501', down link T/ turn off 4,501.0 4,501.0 11:45 12:30 sonicscope. per SLB D.D, W/ 240 gpm, 1604 SPP Page 19129 Report Printed: 9/19/2019 Gperations Summary (with Timelog Depths) /r>~ 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Star) Time End Time Dur (hr) Phase Op Code Activity Cade Tme P -T -X Operation (f1Ka) End Cap (KKB) 8/18/2019 8/18/2019 6.75 INTRM2 DRILLOUT TRIP P Continue RIH F/ 4501' T/ 9609' W/ 4" 4,501.0 9,609.0 12:30 19:15 DP F1 shed, Fill pipe every 20 std. @ 9418' p/u std of 5" dp w/ XO'S, RIH w/ 1 std 5 7/8 DP. M/U TO & circ @ 33slks/ min 8/18/2019 8/18/2019 0.75 INTRM2 DRILLOUT SVRG P Service rig, change oil in top drive. 9,609.0 9,609.0 19:15 20:00 8/18/2019 8/18/2019 1.25 INTRM2 DRILLOUT SLPC P Cut & slip 90' Drilling line. 9,609.0 9,609.0 2000 21:15 8/18/2019 8/19/2019 2.75 INTRM2 DRILLOUT TRIP P Continue RIH W/61/8 BHA F/9609 9,609.0 12,527.0 21:15 0000 T/ 12527' W/ 57/8 DP F/ derrick Filling pipe every 1000'. 8/19/2019 8/19/2019 0.25 INTRM2 DRILLOUT QEVL P Turn on Sonic Scope @ 14527'W/ 12,527.0 12,527.0 00:00 00:15 260 gpm, 2240 spp. 8/19/2019 8/19/2019 5.25 INTRM2 DRILLOUT QEVL P Logging W/ sonicScope F/ 12527'T/ 12,527.0 14,128.0 00:15 05:30 14128', W/R down F/ 13909'T/ 1394' & F/ 14019 T/ 14128'W/ 230 GPM, 2000 SPP, 3o ROM, 13K trl 8/19/2019 8/19/2019 2.25 INTRM2 DRILLOUT RGRP T CBU @ 14128' W/ 255 GPM, 2200 14,128.0 14,128.0 05:30 07:45 SPP, while repairing lop drive service loop gaurd. 8/192019 8/19/2019 1.75 INTRM2 DRILLOUT PRTS P PJSM, R/u to test 7" csg. Test casing 14,128.0 14,128.0 07:45 09:30 @ 3500 psi for 30 min. 8/19/2019 8/192019 0.25 INTRM2 DRILLOUT PRTS P Rig dwn testing equip. and blow dwn 14,128.0 14,128.0 09:30 09:45 choke & kill line. 8/19/2019 8/19/2019 0.25 INTRM2 DRILLOUT WASH P Wash & Ream F/ 14128'T/ 14150' 14,128.0 14,147.0 09:45 10:00 W/230 gpm, Tagged Plugs @ 14147' 8/19/2019 8/19/2019 2.50 INTRM2 DRILLOUT DRLG P Drill out she frac F/ 14150 T/ 14283' w/ 14,147.0 14,283.0 10:00 12:30 200/240 GPM, 1450/2105 SPP, 50(70 RPM, 16/19k TORO, 5112K WOB, ROT wt 175K 8/19/2019 87192019 0.50 INTRM2 DRILLOUT DDRL P Drill F/ 14283 T/ 14305 (20' new 14,283.0 14,305.0 12:30 13:00 formation), W 1220 GPM, 1710 SPP, 70 RPM, 16K TORO, 5112K WOB, 175K ROT ADT .31 TVD 6080', BIT HR .31 Jar HRS .31 8/19/2019 8/19/2019 2.25 INTRM2 DRILLOUT CIRC P Rot / Recip. pipe F/ 14305/ T/ 14128' 14,305.0 14,283.0 13:00 15:15 & cond mud F/ FIT lest W/ 250 gpm, 2110 SPP, 60 RPM, 16K TRQ, MW 10.8 IN / OUT 8/19/2019 8/19/2019 0.25 INTRM2 DRILLOUT OWFF P OWFF, well static. 14,283.0 14,283.0 15:15 15:30 8/19/2019 8/19/2019 1.00 INTRM2 DRILLOUT FIT P PJSM, R7U test equip. Perforin FIT @ 14,283.0 14,283.0 15:30 16:30 14.3 EMW, pump 3.9 We T/ 1170 psi, psi bleed T/ 1110 in 10 min, 4 bbls return on bleed off. Rig dwn testing equip. & B/D test lines. 8/19/2019 8/19/2019 0.25 PRODt DRILLOUT OWFF P OWFF, well static. 14,283.0 14,283.0 16:30 16:45 8/192019 8/192019 1.25 PROD1 DRILL MPDA P PJSM, Attempt to B/OTop single, 14,283.0 14,283.0 16:45 18:00 ( Tight connection), p/u single F/ shed, pull trip nipple, install MPD RCD per MPD rep, L/D single, break circulation thr MPD system W/ 100 GPM 890 SPP, P/U 275k, S/O 125K. 8/19/2019 8/192019 0.75 PRO131 DRILL REAM P Wash & ream F/ 14222'/ 14305', W/ 14,283.0 14,305.0 18:00 18:45 240 gpm, 2020 SPP, RPM 60, Trq 16K, p/u 277K, SIO 121 K, ROT 175K Page 20129 ReportPrinted: 9 /1 912 01 9 Operations Summary (with Timelog Depths) 2M-40 qW Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur inn Phase Op Code Activity Code Time P-T-A Operation (M[3) End Depth (fiKa) 8119/2019 8/20/2019 5.25 PROD1 DRILL DDRL P Ong 6 1/8 prod. hole F/ 14305' T/ 14,305.0 14,452.0 18:45 00:00 14452', MD, 6097 TVD. Hold 10.7 T/ 11.0 ppg W/ MPD on connections, 260 GPM, 2183 SPP, 60 RPM, 12/15 WOB, P/U 275k, S/O 125k, ROT 175K, 12K TRQ, Displace 10.8 PPG -SND mud W/ 9.2 ppg FLO PRO mud while drilling. ADT 4.73 Bit Hrs 5.04, Jar Hrs 5.04 8/20/2019 8/20/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 14452'T/ 14,452.0 14,825.0 00:00 06:00 14825', MD, 6100 TVD. Hold 10.7 T/ 11.0 ppg WI MPD on connections, 270 GPM, 2060 SPP, 140 RPM, 10/13 WOB, P/U 243k, S/O 117k, ROT 170K, 17K TRQ, ADT 4.81 Bit Hrs 9.84, Jar Hrs 9.84 8/20/2019 8/20/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 14825'T/ 14,825.0 15,353.0 06:00 12:00 15353', MD, 61 09'TVD. Hold 10.7 T/ 11.0 ppg W/ MPD on connections, 270 GPM, 2330 SPP, 150 RPM, 8/12 WOB, P/U 247k, S/O 117k, ROT 167K, 17K TRQ, ADT 4.50 Bit Hrs 14.34, Jar Hrs 14.34 SPR @ 15070' MD, 6097' TVD, MW 9.3 @ 08:30 #1 on MPD #2 @ 20 / 30 =810/416 = 950/353 8/20/2019 8/20/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 15353'T/ 15,353.0 15,896.0 12:00 1800 15896' MD.TVD 6130', GPM, 270 SPP, 2320 RPM, 140 WOB 11/15k, P/U 220k, 8/0 125k, ROT 175K, 9K TRQ, Hold 10.7 T/ 11.0 ppg W/ MPD on connections, ADT 4.75 Bit His 19.09, Jar Hrs 19.09 8/20/2019 8/21/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 15896'T/ 15,896.0 16,376.0 1800 0000 16,376.0' MD.TVO 6139", GPM, 270 SPP, 2315 RPM, 140 WOB 11/15k, P/U 225k, S/O 135k, ROT 175K, 9K TRQ, Hold 10.7 T/ 11.0 ppg W/ MPD on connections, ADT 4.68 Bit Hrs 23.77, Jar Hrs 23.77 8/21/2019 8/21/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 16376'T/ 16,376.0 16,859.0 00:00 06:00 16,859' MD.TVD 6125', GPM 270, SPP 2390, RPM 140, WOB 7/10k, P/U 231k, S/O 133k, ROT 173K, 14K TRQ, Hold 10.8 T/ 11.0 ppg W/ MPD on connections, ADT 4.68 Bit Hrs 28.24Jar Hrs 28.24 8/21/2019 8/21/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 16859' T/ 16,859.0 17,398.0 06:00 12:00 17398' MD.TVD 6132', GPM 270, SPP 2400, RPM 140, WOB 13/15k, P/U 235k, S/O 133k, ROT 173K, 17K TRQ, Hold 10.8 ppg W/ MPD on connections, SPR @ 17236' MD, 6063' TVD, MW 9.4, @ 10:15 hrs. #1 MPD; #2 @ 20/30 = 910/384; 1080/310 ADT 9.6 Bit Hrs 32.62, Jar Hrs 32.62 Page 21129 ReportPrinted: 9/19/2019 Uperations Summary (with Timelog Depths) LA, 2M-40 10 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code ANvity Code Time P -T -A Operation mKB) End Depth (ftKB) 8/21/2019 8/21/2019 6.00 PROD1 DRILL DDRL P Drlg 61/8 prod. hole F/ 17398'T/ 17,398.0 17,989.0 12:00 18:00 17989' MD.TVD 6137', GPM 270, SPP 2430, RPM 140, WOB 10/12k, P/U 238k, S/O 132k, ROT 178K, 18K TRQ, Hold 11 ppg W/ MPD on connections, ADT 5.44 Bit Hrs 37.47, Jar Hrs 37.47 8/21/2019 8/22/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 17989'T1 17,989.0 18,490.0 18:00 00:00 18490' MD.TVD 6146', GPM 270, SPP 2480, RPM 140, WOB 5/12k, P/U 240k, S/O 125k, ROT 170K, 19K TRQ, Hold 11 ppg W/ MPD on connections, ADT 9.54 Bit Hrs 42.16, Jar Hrs 42.16 8/22/2019 8/22/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 18490'T/ 18,490.0 18,840.0 00:00 0600 18840' MD.TVD 6149', GPM 270, SPP 2420, RPM 140, WOB 7/10k, P/U 235k, S/O 127k, ROT 171 K, 19K TRQ, Hold 11 ppg W/ MPD on connections, ADT 4.68 Bit Hrs 46.84, Jar Hrs 46.84 8/22/2019 8/22/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 184840'T/ 18,840.0 19,178.0 06:00 1200 19178' MD.TVD 6160', GPM 270, SPP 2460, RPM 140, WOB 5/10k, P/U 243k, S/O 123k, ROT 176K, 21 K TRQ, Hold 11 ppg W/ MPD on connections, SPR @ 19123' MD, 6158' TVD, MW 9.3+, 10:30 hrs. #1 MPD; #2 20/30 = 1020/430 1220/353 ADT 4.92 Bit His 51.76, Jar Hrs 51.76 8/22/2019 8/22/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 19178' 19,178.0 19,543.0 12:00 18:00 T/19543' MD.TVD 6154', GPM 270, SPP 2510, RPM 140, WOB 5/15k, P/U 255k, S/O 110k, ROT 182K TRQ 22k, Hold 11 ppg W/ MPD on connections, ADT 5.44 Bit Hrs 5720, Jar Hrs 57.20 8/22/2019 8/23/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 19543' T/ 19,543.0 19,782.0 18:00 0000 19782' MD.TVD 6159', GPM 260, SPP 2490, RPM 140, WOB 5/15k, P/U 255k, S/O 110k, ROT 182K TRQ 23k, Hold 11 ppg W/ MPD on connections, SPR @ 19688' MD, 6158' TVD, MW 9.3+. #1 MPD; #2 20/30 = 1120/421 1300/344 ADT 5.30 Bit Hrs 62.50, Jar Hrs 62.50 8/23/2019 8/23/2019 6.00 PROD1 DRILL DDRL P Drlg 6 1/8 prod. hole F/ 19782' T/ 19,782.0 20,124.0 00:00 06:00 20124' MD.TVD 6169', GPM 260, SPP 2480, RPM 100, WOB 6/8k, P/U 258k, S/O 115k, ROT 180K TRQ 18k, Hold 11 ppg W/ MPD on connections, ADT 5.12 Bit Hrs 67.62, Jar Hrs 67.62 8/23/2019 8/23/2019 6.00 PROD1 DRILL DDRL P Ddg 6 1/8 prod. hole F/ 20124'T/ 20,124.0 20,436.0 06:00 1200 20436' MD.TVD 6180', GPM 260, SPP 2430, RPM 90, WOB 6/8k, P/U 270k, S/O 110k, ROT 180K TRQ 21.5k, Hold 11 ppg W/ MPD on connections, ADT10.33 Bit Hrs 72 83, Jar Hrs 72.83 Page 22129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase op Code Activity Cede Time P -T -X operation (eKB) End Depth (ftKB) 8/23/2019 8/23/2019 6.00 PROD1 DRILL DDRL P Ddg 6 118 prod. hole F/ 20436' 20,436.0 20,761.0 12:00 18:00 T/2076'MO, tvd 6177' GPM 260, SPP 2430, RPM 120, WOB 8110k, P/U 270k, S/O 110k, ROT 185K TRQ 25k, Hold 11 ppg W/ MPD on connections, ADT Bit Hrs xxxx, Jar Hrs xxxxx 8/23/2019 8/24/2019 6.00 PROD? DRILL DDRL P Drlg 6 1/8 prod. hole F/ 20,761'T/ 20,761.0 21,045.0 18:00 00:00 21045'MD.TVD 6177", GPM 270, SPP 2500, RPM 105, WOB 5/10k, P/U 270k, SIO 125k, ROT 187K TRQ k, Hold 11 ppg W/ MPD on connections, SPR @ 21038' MP1 20/30 =380/930 MP2 @ 2/30 = 320/1150 psi ADT 8.9 Bit Hrs 81 .73, Jar Hrs 8.9 6124/2019 8/24/2019 4.00 PROD? DRILL DDRL P Drlg 6 1/8 prod. hole F/ 21045'T/ 21,045.0 21,245.0 00:00 04:00 21245'MD.TVD 617811, GPM 260, SPP 2360, RPM 100, WOB 13/15k, P/U 273k, SIO 120k, ROT 184K TRQ 26 k, Hold 11 ppg W/ MPD on connections, SPR @ 21038' MP1 20130 =4551960 MP2 @ 2/30 = 375/1130 psi ADT 3.76 Bit Hrs 85.49 , Jar Hrs 85.49 824/2019 8/24/2019 2.25 PRODI CASING CIRC P Circulate & recpi. pipe F/ 21245 T/ 21,245.0 21,245.0 04:00 06:15 21194'w/ 270 gpm, 2460 spp, 1001 120 rpm, 2527 tort, 8124/2019 8/24/2019 1.50 PROD? CASING MPDA P Perform formation draw down, Initial 21,245.0 21,245.0 06:15 07:45 PSI build T/ 605 psi, 16 bbls bleed back, Decission made to CBU. 8/24/2019 824/2019 5.25 PRODI CASING CIRC T Circulate 2 bottoms up W/270 gpm, 21,245.0 21,194.0 07:45 13:00 2490 spp, 1001120 rpm,23/27 K TORQ, MAX GAS UNITS = 10333 units Rack back stand. 8/24/2019 8/24/2019 4.00 PRODI CASING CIRC T PIU single F/ shed, Continue circ@ 21,194.0 21,045.0 13:00 17:00 21054', W/ 270 gpm, 2490 spp, 1001120 rpm,23127 K TORQ, gas units = 6925 8/24/2019 8/24/2019 1.00 PROD1 CASING MPDA T Bleed off psi increase hold MPD 660 21,045.0 21,045.0 17:00 18:00 psi W/ MPD, increase T/ 695. 8124/2019 8/25/2019 6.00 PROD1 CASING CIRC T Continue circ gas out, W/ 270 gpm, 21,045.0 21,045.0 18:00 00:00 2600 spp, 75190 rpm, 14K trq. 11,61 T/ 11.7 ECD Holding BEYON psi @ 249 in @ 365, Max gas = 6722 units 825/2019 825/2019 12.00 PRODI CASING CIRC T Continue circulating out gas / W 270 21,045.0 21,045.0 00:00 12:00 gpm 2600spp, 50 rpm, std/ bk 1 stasnd DP, Holding 11.7 ppg emw wl MPD 8/25/2019 8/25/2019 6.00 PROD? CASING CIRC T Continue circulating out gas / W 270 21,045.0 21,045.0 12:00 18:00 gpm 2600spp, 50 rpm, 13.5 k torq. , Holding 11.7 ppg emw w/ MPD 8/25/2019 8/25/2019 1.25 PRODI CASING MPDA T Perform formation draw down test, 21,045.0 21,045.0 18:00 1915 Trap 760 psi W/MPD bleed down T/ 736 psi = 11.5 PPG 8/25/2019 8/25/2019 2.75 PRODI CASING CIRC T circulating bottoms up @ 21037'/ W 21,037.0 21,037.0 19:15 22:00 270 gpm 2600spp, 50 rpm, 13.5 It torq. , Holding 11.7 ppg emw w/ MPD, Max gas 5052 units 8/25/2019 826/2019 2.00 PRODI CASING CIRC T Increase MPD psi TI 11.8 EMW, 21,037.0 21,037.0 22:00 00:00 continue curclating out gas. 489 max gas units 16 bbl loss @11.8 ppg 95 bbls lost to formation FI last 24hr Page 23129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start oepdr Start Time End Tema Our limit Please Op Code Activity Cade Time P -T -X Operation (WE) End Depth (W[3) 8/26/2019 8/26/2019 6.00 PROM CASING CIRC T Continue circulating out gas @ 2103', 21,037.0 21,037.0 00:00 06:00 W/ 270 gpm, 2600 spp, 50 rpm, 13.5 trq, holding 11.8 emw with mpd while waiting on new 9.2 ppg Flo Pro mud 8/26/2019 8126/2019 1.75 PRODi CASING TRIP T Trip in hole F/ 21037'T/ 21245' 21,037.0 21,245.0 06:00 07:45 8/26/2019 8/26/2019 4.25 PROM CASING CIRC T Cir & cond mud @ 21245', W/ 270 21,245.0 21,245.0 07:45 12:00 gpm, 2650 spp, 50 rpm, 19 trq, holding 11.8 emw with mpd while waiting on new 9.2 ppg Flo Pro mud, p/u 186k, Slo 177k 8/26/2019 8/2612019 8.50 PROM CASING CIRC T Cir & cond mud @ 21245', W/ 270 21,245.0 21,245.0 12:00 20:30 gpm, 2650 spp, 90 rpm, 19 trq, holding 11.8 emw with mpd while waiting on new 9.2 ppg Flo Pro mud, p/u 186k, S/o 177k 8/26/2019 8/27/2019 3.50 PROD1 CASING BKRM P BROOH Fl 21245'T/ 20340', W/ 270 21,245.0 20,340.0 20:30 00:00 gpm, 2650 spp, 90 rpm, trq 15 k, holding 835 psi wl MPD = 11.8 EMW. p/u 180K SIO 170k 8/27/2019 8/27/2019 13.00 PROD1 CASING BKRM P BROOH F/20340' to 16,524', W/ 270 20,340.0 16,524.0 00:00 13:00 gpm, 2650 spp, 90 rpm, trq 10 k, holding 835 psi w/ MPD = 11.8 EMW. plu 180K S/O 170k. 8127/2019 8/27/2019 5.50 FROM CASING BKRM T Observe pack off at 16524' MD, work 16,524.0 16,460.0 13:00 18:30 varying parameters to get through spot. Reduce pump rate to 200 gpm & pull through with no rotation to gel past. Ream through 16510'& 16544'- 16555'to clean up with 270 gpm, 2520 psi, 140 rpm, Tq 12-15K. Back ream to top of stand & drift to simulate liner run 120 gpm, 1350 psi, no rotation. Observe tight spot while BROOH at 16508'-16492' MD, Reduced pump rate & pull through with no rotation. Hold back pressure w/ MPD = 11.8 EMW while working through section.. 8/27/2019 8/28/2019 5.50 FROM CASING BKRM P BROOH F/16,460'to 15,323', W/ 270 16,460.0 15,323. 0 18:30 00:00 gpm, 2650 spp, 90 rpm, trq 10 k, holding 835 psi w/ MPD = 11.8 EMW. p/u 168 K S/O 160 k. 8/28/2019 8/28/2019 4.50 FROM CASING BKRM P BROOH F/15,323- to 14,222', W/ 270 15,323.0 14,222.0 00:00 04:30 gpm, 2540 spp, 100 rpm, trq 10 k, holding back pressure w/ MPD = 11.8 EMW. plu 163 K. 8128/2019 8/28/2019 5.50 FROM CASING CIRC P CBU 3X, 270 gpm, 2440 psi, 30 rpm, 14,222.0 14,280.0 04:30 10:00 Tq 7K, PU 166K, SO 160K, holding an EMW of 11.8 ppg with MPD. 8/28/2019 3.00 PROD1 CASING CIRC T Circulate at 270 gpm, 2590 psi, 14,280.0 14,280.0 18/28/2019 10:00 13:00 holding an EMW of 11.8 ppg with MPD. Waiting on pressure schedule revision. 8/28/2019 8/28/2019 1.00 FROM CASING CIRC P Pump high vis sweep.and spot it 14,280.0 14,280.0 13:00 14:00 F/14,285'to 13,485' 8128/2019 8/28/2019 2.00 PRODt CASING SMPD P Soon F/14,285'to 13,653'. Holding 14,280.0 13,653.0 14:00 1600 11.8 ppg ECD w/ MPD. 8/28/2019 8/28/2019 1.75 PROD1 CASING CIRC T Circulate and holding 700 psi w/ MPD 13,653.0 13,653.0 16:00 17:45 Waiting on Displacement schedule revision. 8128/2019 8/28/2019 5.00 PROD1 CASING CIRC P Disp the hole w/ 11.8 ppg kill wt Brine. 13,653.0 13,653.0 17:45 22:45 Pumping 200 Gpm @ 1260 psi. Page 24129 Report Printed: 9119/2019 Aimlow 5 Operations Summary (with Timelog Depths) fr ¢!i 2M-40 mv Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time I End Time our (tin Phase Op Cade Activity Code Time P -T -X Operation Stan Depth nti(B) End Depth(ftKB) 8/28/2019 8/29/2019 1.25 PROD1 CASING COND T Close the choke and Monitor the well 13,653.0 13,653.0 22:45 00:00 while weighting the pits up to 11.8ppg-r o psi build up on MPD chokes. 8/29/2019 8/29/2019 3.75 PROD1 CASING COND T Close the choke and Monitor the well 13,653.0 13,653.0 00:00 03:45 while weighting the pits up to 11.8ppg..no psi build up on MPD chokes. 8/29/2019 8/29/2019 3.25 PROD1 CASING CIRC P Circulate 11.8 ppg kill weight brine 13,653.0 13,653.0 03:45 07:00 surface to surface with 200 gpm, 1180 psi. 8/29/2019 8/29/2019 0.50 PROD1 CASING OWFF P Monitor well, observe slight flow to no 13,653.0 13,653.0 07:00 07:30 flow. Monitor 30 minutes static. SIMOPS blow down TD. 8/29/2019 8/29/2019 4.50 PRODi CASING TRIP P Strip out of hole w/ MPD from 13653'- 13,653.0 10,456.0 07:30 12:00 10456' MD, PU 160K. Drop 2.12" hollow metal drift on wire, at stand #140. 8/29/2019 8/29/2079 1.00 PROD1 CASING TRIP P Sooh F/ 10,456' to 9,418' 10,456.0 9,418.0 12:00 13:00 8/29/2019 8/29/2019 1.75 PROD1 CASING OTHR P Flow Check No Flow.Hold a Pism to 9,418.0 9,418.0 13:00 14:45 Pull The RCD. 8/29/2019 8/29/2019 1.00 PRODi CASING OTHR P Pull The 5.875 Red & Install the 4" 9,418.0 9,418.0 14:45 15:45 RCD. 8/29/2019 8/29/2019 1.75 PROD1 CASING TRIP P SOOH F/9,418'to 7,295' 9,418.0 7,295.0 15:45 17:30 8/29/2019 8/30/2019 6.50 PROD1 CASING TRIP P SOOH LAYING DOWN the 4" D.P to 7,295.0 2,118.0 17:30 00:00 the pipe shed F/7,295' to 2,118'. 8/30/2019 8/30/2019 2.25 PROD1 CASING TRIP P SOON LAYING DOWN the 4" D.P to 2,118.0 314.0 00:00 02:15 the pipe shed F/ 2,118'. to the BHA. 8/30/2019 8/30/2019 1.50 PROD1 CASING OTHR P Pull the Red & Install the Trip Nipple. 314.0 314.0 02:15 03:45 8/30/2019 8/30/2019 0.75 PROD1 CASING OTHR T Install the Trip Nipple, And clamp was 314.0 314.0 03:45 04:30 hard to put back together Would not allow the trip Nipple to Seal Properly. 8/30/2019 8/30/2019 3.75 PROD1 CASING PULD P Laydown Schlumberger Directiopnal 314.0 0.0 04:30 08:15 tools,& pull the Nuculer Source. finish laying down the tools. 8/30/2019 8/30/2019 1.00 PRODi CASING OTHR P Pull the wear Bushing , P/U the stack 0.0 0.0 08:15 09:15 washer and wash The Bope's out. 8/30/2019 8/30/2019 2.25 PROD1 CASING RURD P Rig up to test BOPE. Flood lines & 0.0 0.0 09:15 11:30 work air out. Perform shell test. 8/30/2019 8/30/2019 0.50 PROD1 CASING BOPE P Test BOPS. (ALL TESTS PASS) 250 0.0 0.0 11:30 12:00 psi Low/ 3,500 psi High, 5 min each (Charted) Test Bag 5.875 Test Joint. Perform test #1. 8/30/2019 8/30/2019 3.00 PRODi CASING OTHR T Observe pressure bleed off, during 0.0 0.0 12:00 1500 2nd test. Isolate equipment to find test plug leaking. Pull The Test plug, the seal was scarred. Install a new test plug seal, and the seal tested good. Page 25/29 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sort Time End Time our (h) Phase Op Cotle Activity Cotle Time P -T -X Operation Stan Depth (fIKB) End Depth (MB) 8/30/2019 8/30/2019 6.00 PROD1 CASING BOPE P Test BOPE. (ALL TESTS PASS) 250 0.0 0.0 15:00 21:00 psi Low / 3,500 psi High, 5 min each (Charted) Test Bag with 5.875 Test Joint. Test Bag and LPR 3.5x6" VBRs with 3 .1/2" test joint. Test chokes valves 1-14, neddle Valve above #1, Auto/Manual, IBOP, HCR Choke, HCR Kill, 4" DEMCO, 5-7/8" FOSV and Dart, Blinds. Accumulator tested - FSP 3100 psi, PAC 1450 psi, 200 psi build 22 sec, FSP 144 sec. 4 Nitrogen bottle 2050 average pressure. Performed 1500 psi drawdown test on manual and hydraulic choke. Witness waived by AOGCC Rep Guy Cook. 8/30/2019 8/30/2019 1.25 PROD1 CASING RURD P Blow Down Test Iines,Rig Dn Testing 0.0 0.0 21:00 22:15 Equipment,pull the Test Plug & Set the wear Bushing.. Wear Bushing ID IS 12 1/2" ID. 8/30/2019 8/31/2019 1.75 COMPZN CASING RURD P Hold A PJSM, And rig up to run the 4 0.0 0.0 22:15 00:00 1/2" Production Liner. 8/31/2019 8/31/2019 5.50 COMPZN CASING PUTB P Make up & run 4.5", 12.6#, L-80, Hyd 0.0 2,881.0 00:00 05:30 563, liner from surface to 2881' MD. Install 1 Hydroform centralizer each joint, torque to 3800 fUlbs, using Seal Guard on connections. Baker Rep & CPAI Rep verify frac sleeve size & placement. 8/31/2019 8/31/2019 0.50 COMPZN CASING SVRG P Perform rig service. SIMOPS rig up 2,881.0 2,881.0 05:30 0600 GBR casing power unit. 8/31/2019 8/31/2019 6.00 COMPZN CASING PUTB P Make up & run 4.5", 12.6#, L-80, Hyd 2,881.0 6,757.0 06:00 12:00 563, liner from surface to 2881' MD. Install 1 Hydroform centralizer each joint, torque to 3800 ft/lbs, using Seal Guard on connections. Baker Rep & CPAI Rep verify frac sleeve size & placement. 8/31/2019 8/31/2019 0.25 COMPZN CASING PUTB P Make up & run 4.5", 12.6#, L-80, Hyd 6,757.0 7,148.0 12:00 12:15 563, liner F/ 6,757' TO 7,148' MD. Install 1 Hydroform centralizer each joint, torque to 3800 ft/Ibs, using Seal Guard on connections. Baker Rep & CPAI Rep verify frac sleeve size & placement. Total of 182 4.5"X5.875" Hydroform centralizers ran. 8/31/2019 8/31/2019 0.75 COMPZN CASING PUTB P Pick up the liner hanger Per Baker 7,148.0 7,148.0 12:15 13:00 Rep 8/31/2019 8/31/2019 0.25 COMPZN CASING PUTB P Mix ZanPlexd For the Liner &pour, 7,148.0 7,148.0 13:00 13:15 8/31/2019 8/31/2019 1.50 COMPZN CASING OTHR P Change out handling equipment & PU 7,148.0 7,148.0 13:15 1445 XO subs. Obtain T/D W/ Liner Hanger U/D/ Rot=1 I 2/94/103K WT.With 20 GPM W 70 PSI.O TO @ 5 Rpm =2.4K.10 Rpm=2.5k TQ,20 RPM =2.6k TQ -Without The Pumps U/D/Rot=113/96/103K. 8/31/2019 8/31/2019 1.50 COMPZN CASING PUTB P F/7,148'to 9,228' Run on 4" D.P. as 7,148.0 9,228.0 14:45 1615 I per Baker Running Speed. 8/31/2019 8/31/2019 0.25 COMPZN CASING PUTB P Pick up the 5" Rubicon Swivel Master. 9,228.0 9,228.0 16:15 16:30 SER# 18-3175. Page 26129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Durnn Phase Op Code Activity Cotle Time P-T-X Operation Start Depth (ftKB) End Depih(WB) 8/31/2019 8/31/2019 0.25 COMPZN CASING RUNL P T/D W/ 5.875 D.P U/D/ 9,228.0 9,228.0 16:30 1645 Rot=130/104/129K WT.With 20 GPM W 50 PSI.O TQ @ 5 Rpm=.5K.10 Rpm=.6 TKQ,20 RPM =.7k TQ„Without The Pumps U/D=130/105/K. 8/31/2019 8/31/2019 6.25 COMPZN CASING RUNL P F/ 9,228'to 14,235'. Run The 41/2" 9,228.0 14,235.0 16:45 2300 Liner on the 5.875" D.P. as Per Baker Running Speed. 8/31/2019 8/31/2019 0.25 COMPZN CASING RUNL P T/D W/ 5.875 D.P @ 14,235' U/D/ 14,235.0 14,235.0 23:00 23:15 Rol=204/144/185 K WT.With 20 GPM W 70 PSI.O TO @ 5 Rpm=.5K.10 Rpm=.6 TKQ,20 RPM =.7k TQ-Without The Pumps U/D=204/151/K. 8/31/2019 9/1/2019 0.75 COMPZN CASING RUNL P F/ 14,235to 14,460'. Run The 41/2" 14,235.0 14,460.0 23:15 00:00 Liner on the 5.875" D.P. as Per Baker Running Speed. 9/1/2019 9/1/2019 17.75 COMPZN CASING RUNL P Run 4-1/2" liner on 5-7/8" DP, f/ 14,460.0 21,201.0 00:00 1745 14460'-21,201' The liner is at setting depth of 21,201' MD, SO 130K, fill pipe every 10 stands, begin rabbiting DP from derrick on stand 115.W/ The 2.31 Drift. Calc/Act Disp=139.71 - 83.71 Bbis lost to the hole. 9/1/2019 9/1/2019 2.00 COMPZN WELLPR PACK P Get the up and down weight's with the 21,201.0 14,141.0 17:45 19:45 liner on depth off 21,201', up=275k, Dn 145k. Break the Connection and drop the 1.625" Ball pump the ball On w/ 126 GPM @ 350 Psi. slowed the Pump Down at 2200 STKS T/28 GPM. @ 70 psi.- the Ball was on Seat w/ 2535 Stks, Pressure up to 3900 Psi. S/O and set Hanger with 80K Down. bleed the psi off to confirm the Tool Released. P/U 275k to expose the Dog Sub. SIO to 50K to nset the liner top packer. P/U wt while rotating 15 RPM. TO= 13.3K Rot wt =205k. S/0 55k ON on Up X 2 Stop Rotating P/U to Neutral WT.Liner top at 14098' MD. 9/1/2019 9/1/2019 1.75 COMPZN WELLPR DHEQ P Rig up to test the liner top and chart 14,141.0 14,141.0 19:45 21:30 the same to 3900 psi for 10 min, the test held Good. 9/1/2019 9/2/2019 2.50 COMPZN WELLPR CIRC P Circ 2 Bttms up @ 270 Gpm @ 360 14,141.0 14,141.0 21:30 0000 psi..we got 3456 units of Gas on the first Bttms Up. 9/2/2019 9/2/2019 2.00 COMPZN WELLPR CIRC P Continue circulating casing clean at 14,141.0 14,141.0 00:00 0200 275 gpm, 510 psi. 9/2/2019 9/2/2019 2.00 COMPZN WELLPR CRIH P Pump 320 bbls of corrosion inhibited 14,141.0 14,141.0 02:00 04:00 11.8 ppg brine &spot with 304 bbls of 11.8 ppg brine at 6 bpm, 510 psi. 9/2/2019 9/2/2019 0.25 COMPZN WELLPR PULD P TOH laying down 4 joint of 5-7/8" DP f/ 14,141.0 14,012.0 04:00 04:15 14141'-14012' MD, PU 265K, 9/2/2019 9/2/2019 1.50 COMPZN WELLPR SLPC P Cut and slip 75' of drill line. SIMOPS 14,012.0 14,012.0 04:15 05:45 monitor well circulating across the top of the hole, static. 9/2/2019 9/2/2019 0.50 COMPZN WELLPR SVRG P Service top drive & blocks. Blow down 14,012.0 14,012.0 05:45 0615 top drive. Page 27129 Report Printed: 9/19/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Phase Op Code Activity Cotle Time P.T-X Opereuon Depth (ftKB) End Depth(ftKB) 9/2/2019 9/3/2019 17.75 COMPZN WELLPR PULD P TOH laying down 5-7/8" DP from 14,012.0 6,040.0 06:15 0000 14012' To 6,040' MD, F/ 8,740' the Drill pipe is hard to Break the Connectiuons.Rig up and use the ST_ 100Tongs to break the Connections. Its taking F/ 75K to 100K to Break the connections. 9/3/2019 9/3/2019 12.00 COMPZN WELLPR PULD P POOH, from 6040'- 2333'. Breakout & 6,040.0 2,333.0 00:00 12:00 lay down 5 7/8" DP Breakout torques observed up to 100K. UP WT = 90K. 9/3/2019 9/3/2019 0.75 COMPZN WELLPR PULD P Run 8 stands of 5 7/8" DP. POOH, lay 2,333.0 2,330.0 12:00 1245 down same. 9/3/2019 9/3/2019 4.25 COMPZN WELLPR PULD P Continue POOH from 2330- surface, 2,330.0 0.0 12:45 17:00 breakout and lay down 4" DR Inspected the running tool observing dog sub sheared, and hydraulic set.. Tool complete. as per Baker rep. Breakout and lay down running tool assembly. 9/3/2019 9/3/2019 1.75 COMPZN WELLPR WWWH P Rig up and flush the BOP stack. 0.0 0.0 17:00 18:45 BOLDS, & Pull the wear bushing. Re - Flush BOP slack. 9/3/2019 9/3/2019 2.75 COMPZN RPCOMP RCST P Rig up to run 3 1/2" completion string. 0.0 0.0 18:45 21:30 Make up Baker WLEG, and Baker Premier 3 1/2" x 7" packer,and HES Gauge mandrel as per tally.Attach TEC wire & test same. Test to 9500 psi F/ 15 mins Witnessed by CPAI Company Rep. 9/3/2019 9/4/2019 2.50 COMPZN RPCOMP PUTB P PJSM W/ the rig crew,Baker tool 0.0 343.0 21:30 00:00 hand,GBR casing crew,And HEC Personnel. Run the 3 1/2" Tubing per the Pipe Tally.F/ SUR to 343' 9/4/2019 9/4/2019 0.25 COMPZN RPCOMP PUTB P Make up Gauge mandrel at 343'. 343.0 343.0 00:00 00:15 Install Tec wire & test same. 9/4/2019 9/4/2019 11.25 COMPZN RPCOMP PUTB P Continue run 3 1/2" completion string 343.0 5,882.0 00:15 11:30 from 343'- 5882'. Observed proper displacement. Crew Change 9/4/2019 9/4/2019 10.25 COMPZN RPCOMP PUTS P Continue run 3 1/2" completion string 5,882.0 10,891.0 11:30 21:45 from 5882 - 10,891'. Observed proper displacement.. 9/4/2019 9/4/2019 0.50 COMPZN RPCOMP SVRG P Rig Service the Skate and Replace a 10,891.0 10,891.0 21:45 2215 Hydralic Hose. 9/4/2019 9/4/2019 0.25 COMPZN RPCOMP PUTB P Test the hec Tech Wire 10,891.0 10,891.0 22:15 2230 9/4/2019 9/5/2019 1.50 COMPZN RPCOMP PUTB P Continue run 3 1/2" completion string 10,891.0 11,353.0 22:30 0000 from 10,891'to 11,353' Observed proper displacement. as per Tally w/ the tee wire. 9/5/2019 9/5/2019 7.75 COMPZN RPCOMP PUTB P Run the 3 1/2" tubing F/11,353'to 11,353.0 14,022.0 00:00 07:45 14,022',With HES Tech Wire as per the Pipe TaIIy. The Collars on the 3 1/2" were Hanging up on 7 " X 9 5/8" liner top work the Couplings through the liner top F/13,306'to 13,512' setting 15K down on the liner top and working the Couplings through, 9/5/2019 9/5/2019 2.00 COMPZN RPCOMP PUTS P Run the 3 1/2" tubing f/ 14,022'to 14,022.0 14,111.0 07:45 09:45 14,111', locate the 4 1/2" Liner top @ 14,098' Set 1 OK on the shear sub & shear the Pins, tag the No -Go W/5K Twice.@ 14,111', M/S Depth,Space out F/3.55 F/ Fully Located ( UPON =132/92K. Page 28129 ReportPrinted: 9119/2019 Operations Summary (with Timelog Depths) 2M-40 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (Wlih End Depth (ftKa) 9/5/2019 9/5/2019 1.75 COMPZN RPCOMP PUTB P M/U the Landing JT, The Hanger & 14,111.0 14,111.0 09:45 11:30 Terminate The Hes Tech Wire,The Tech Wire still had good Communication When It was Terminated.Test & Land the Hanger U/D=135/97K Check for Flow for Mins.No flow Observed. 9/5/2019 9/5/2019 0.50 COMPZN RPCOMP PRTS P MILDS Test the hanger seal's To 5000 14,111.0 14,111.0 11:30 12:00 Psi F/10 mins. the test held Good. 9/5/20199/5/2019 2.75 COMPZN RPCOMP PMTS P R/U Set Pkr/ test the 3 1/2" tubing to 14,111.0 14,111.0 12:00 14:45 4500 psi F/30 mins. Test PKR F/ IA to 3850 psi F/ 30 Mins. Bleed Dawn The IA to 3000 psi, bleed down the Tubing to 0 Psi, Shear SOV. 9/512019 9/5/2019 0.75 COMPZN RPCOMP PRTS P UD the Landing Joint & Manifold, Set 14,111.0 14,111.0 14:45 15:30 The BPV 9/5/2019 9/5/2019 0.25 COMPZN RPCOMP PMTS P Test The BPV T/ 2500 psi F/ 10 Mins 14,111.0 14,111.0 15:30 15:45 9/5/2019 9/5/2019 1.50 COMPZN RPCOMP RURD P B/D Lines, Rig Down the casing 14,111.0 14,111.0 15:45 17:15 Crews Equipment, and Rig Down HES Equipment. 9/5/2019 9/5/2019 3.50 COMPZN WHDBOP KURD P Rig Down the MPD equipment. 14,111.0 14,111.0 17:15 20:45 9/5/2019 9/5/2019 1.75 COMPZN WHDBOP NUND P N/D the choke & kill Lines, Rack thye 14,111.0 14,111.0 20:45 22:30 bope on the Pedestal. 9/5/2019 9/6/2019 1.50 COMPZN WHDBOP NUND P N/ U Tree & Tq as nper Cameron. 14,111.0 14,111.0 22:30 00:00 Install the tree dart & Presssure test the Production tree to 250 psi / 10,000 psi for & Test the Packoffs to 250 psi / 10,000 psi.pull the tree dart. pull then HP Bpv, No Freeze protect Pumped. and set the H -BPV 9/6/2019 9/6/2019 1.50 COMPZN WHDBOP DHEA P Rig up and test the tree to 10K. As per 14,111.0 14,111.0 00:00 01:30 Cameron Rep. 9/6/2019 9/6/2019 1.00 COMPZN WHDBOP SEQP P Install HP- BPV. Secure well. Close 14,111.0 14,111.0 01:30 02:30 all tree valves. Recorded pressure - OA = 250 PSI, IA = 0 PSI, Tubing = 0 PSI 9/6/2019 9/6/2019 5.50 DEMOB MOVE DMOB P Prepare rig for Demob. Clean & Flush 14,111.0 14,111.0 02:30 08:00 pits, disconnect mud lines, and electrical. Disconnect service lines. Remove equipment from the pad. SIMOPS - laying matting boards on road. 9/6/2019 9/6/2019 4.00 DEMOB MOVE DMOB P Continue prep rig for Demob. Rig off 14,111.0 14,111.0 08:00 12:00 of hi -Line power at 0800 HRS. Prep complexes to move. Pull pipe shed away from sub and spot on the pad. Pull the Power pack modules away from the rig. Prep sub base to jack up. Rig rel3eased from 2M -40 at 1200 HRS Page 29/29 ReportPrinted: 9/19/2019 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-40 ConocoPhillips Definitive Survey Report 06 September, 2019 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. E Yes ❑ No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates [D Declination & Convergence 2) GRS Survey Corrections EJ Survey Tool Codes stephen.fell@contr "'"".'"_,�,,.� actor.conocophillipsz =_.d. _ SLB DE: .com - Keith ` "=2 . Client Representative: g � Herrin� szP 6.2019 9 Date: ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 2M40 Project: Kupamk River Unit TVD Reference: 2M40 actual @ 137.53usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M40 actual @ 137.53usft (D19) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40 Database: OAKEDMP1 Project Kupamk River Unit North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zane: Alaska Zone 04 Using geodetic scale factor Well Rig: 2M40 From Audit Notes: Well Position +NIS D.00 usft Northing: 5,948,985.28 usft Latitude: 70° 16'18.573 N ACTUAL +E/ -W 0.00 usft Easting: 487,899.20 usft Longitude: 150° 5'52.326 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 10D.70 usft (9 13,433.152M40 Srvy 4- SLB _MWD+GMAG(2M4 36.83 0.00 0.00 271.84 Wellbore 2M40 14,218.66 21,182.962M40 Srvy 6- SLB _MWD+GMAG(2M4 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station CorreU8/19/20191245 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0.00 0.00 UNDEFINED 124.39 0 (7 (nn A3.14 BGGM2018 7/20/2019 16.37 80.78 57,397 Design 2M40 Date From Audit Notes: Map (usfq (usft) Survey (Wellbore) Version: 1.0 Phase: ACTUAL lie On Depth: 36.83 Vertical Section: Depth From (TVD) +NIS +FJ -W Direction 2,912.50 (usft) (usft) MR) (9 13,433.152M40 Srvy 4- SLB _MWD+GMAG(2M4 36.83 0.00 0.00 271.84 Survey Program Date From To Map (usfq (usft) Survey (Wellbore) Tool Name Description Survey Date 124.39 2,005.62 2M40 Srvy 1 - SLB_NSG+SSHOT (2M4 GYD-GCSS Gyrodata gyro single shots 7/20/2019 1:42:- 2,100.13 2,876.002M40 Srvy 2-SLB_MWD+GMAG(2M4 MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Mufti -Station Correcl7/21/2019 2:24: 2,912.50 2,912.502M40 Srvy 3- SDI _MWD+SAG(2M40) MWD+SCC+SAG MWD+ Short Collar correction + BHA SAG Correc7/22/2019 2:36- 3,007.85 13,433.152M40 Srvy 4- SLB _MWD+GMAG(2M4 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correcl7/27/201910:38 13,530.17 14,218.662M40 Srvy 5 -SLB MWD+GMAG(2M4 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correcl8/11/201910:38: 14,218.66 21,182.962M40 Srvy 6- SLB _MWD+GMAG(2M4 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station CorreU8/19/20191245 Survey 9/52019 1:15:49PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MO Inc Azi TVD TVDSS -NIS +E/ -W Northing Easting DLS Section (usft) (1) (') (wfq (usft) (usft) (usft) (ft) (ft) (°/180') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -100.70 0.00 0.00 5,948,985.28 487,899.20 0.00 0.00 UNDEFINED 124.39 0.26 116.02 124.39 A3.14 -0.09 0.18 5,948,985.19 487,899.38 0.30 -0.18 GYD-GC-SS(1) 175.99 0.99 106.35 175.99 38.46 4).26 0.71 5,948,985.01 487,899.91 1.42 -0.72 GYD-GC-SS(1) 259.08 0.13 71.98 259.07 121.54 -0.44 1.49 5,948,984.84 487,900.69 1.07 -1.50 GYD-GC-SS(1) 318.56 2.18 277.91 318.56 181.03 -0.26 0.43 5,948,985.02 487,899.63 3.86 4).44 GYD-GC-SS(1) 410.34 3.01 298.65 410.23 272.70 1.14 -3.41 5,948,986.42 487,895.79 1.35 3.44 GYD-GC-SS(1) 500.17 3.48 304.72 499.91 362.38 3.82 -772 5,948,989.11 487,891.49 0.65 7.84 GYD-GC-SS 01 595.16 4.54 307.00 594.67 457.14 7.72 -13.09 5,948,993.02 487,886.12 1.13 13.33 GYD-GC-SS(1) 689.17 5.82 303.05 688.29 550.76 12.56 -20.06 5,948,997.87 487,879.16 1.41 20.45 GYD-GC-SS(1) 782.02 6.32 302.17 780.62 643.09 17.85 -28.33 5,949,003.17 487,870.90 0.55 28.89 GYD-GC-SS(1) 9/52019 1:15:49PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversicn Local Coordinate Reference: Well Rig: 2M40 Project: Kuparuk River Unit TVD Reference: 2M40 actual @ 137.531 lot 9) Site: Kuparuk 2M Pad MD Reference: 2M-40 actual @ 137.53usft (D19) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum CuNature Design: 2M40 Database: OAKEDMPI Survey Map Map vertical MD Inc Aid TVD TVDSS +hi +E/ -W Northing Easting DLS Section (usft) (*) C) (Us t) (usfq (ueft) (usft) (ft) Ift) ('11001 (ft) Survey Tool Name 877.34 7.20 304.45 875.28 737.75 24.02 3270 5,949,009.36 487,861.54 0.97 MAS GYD-GCSS(1) 972.22 7.44 307.09 969.38 831.85 31.09 47.50 5,949,016.44 487,851.75 0.44 48.48 GYD-GGSS(1) 1,067.57 8.33 304.86 1,063.83 926.30 38.76 58.10 5,949,024.13 487,841.17 0.99 59.31 GYDGCSS(1) 1158.46 7.21 304.01 1,153.89 1016.36 45.70 58.23 5,949,031.09 487,831.05 1.24 69.66 GYDGCSS(1) 1,251.99 7.49 297.33 1,246.65 1,109.12 51.79 -78.51 5,949,037.19 487,820.78 0.96 80.14 GYDGCSS(1) 1,348.17 8.79 291.36 1,341.86 1,204.33 57.34 -90.93 5,949,042.76 487,808.37 1.61 92.72 GYD-l(1) 1,441.26 8.88 284.41 1,433.85 1,296.32 61]2 -104.51 5,949,047.16 487,794.80 1.15 1W.44 GYDGC-SS(1) 1,534.73 11.62 278.53 1,525.82 1,388.29 64.91 -120.81 5,949,050.38 487,778.51 3.13 122.83 GYDGCSS(1) 1,629.W 13.13 270.09 1,617.93 1,460.40 66.34 -140.92 5,949,051.84 487,758.40 2.49 142.97 3YDGCSS(1) 1,720.90 17.71 271.32 1,706.47 1,568.94 66.68 -165.33 5,949,052.22 487.733.99 5.00 167.39 GYDGCSS(1) 1,816.57 20.01 270.18 1,797.0 1,659.47 6706 -196.25 5,949,052.65 487,703.07 2.43 198.31 GYDGG-SS(1) 1,911.92 25.29 271.05 1,884.97 1 ]47.44 67.49 -232.05 5,949,053.14 487,666.38 5.55 235.05 GYDGCSS (1) 2,005.62 27.37 270.9 1,968.94 1,831.41 67.89 -274.51 5,999,053.60 487,624.83 2.27 276.55 GYDGCSS(1) 2,100.13 31.64 265.77 2,051.19 1,913.66 66.09 J20.98 5,949,051.88 487,578.35 5.05 322.94 MWD+IFR2+SAG+MS(2) 2,134.66 33.31 265.05 2,080.31 1,942.78 64.74 539.47 5,949,050.56 487,559.86 4.84 341.38 MWD+IFR2+SAG+MS(2) 2,231.99 34.63 266.21 2,161.03 2,023.50 60.98 -393.73 5,949,046.88 487,505.61 1.37 395.48 MWD+IFR2+SAG+MS(2) 2,324.66 36.34 266.68 2,236.50 2,098.97 57.65 447.43 5,949,043.64 487,451.91 1.87 449.05 MWD+IFR2+SAG+MS(2) 2,418.77 39.51 267.55 2,310.71 2,173.18 54.75 505.18 5,949,040.84 487,394.16 3.42 5W.67 MWD+IFR2+SAG+MS(2) 2,514.13 43.75 265.97 2,381.98 2,244.45 51.13 568.40 5,949,037.32 487,330.94 4.58 559.75 MWD+IFR2+SAG+MS(2) 2,608.67 48.54 266.35 2,447.46 2,309.93 46.58 536.40 5,949,032.88 487,262.94 5.07 637.57 MWD+IFR2+SAG+MS(2) 2,703.54 52.78 265.47 2,507.59 2,370.06 41.33 -709.57 5,949,027.75 487,189.77 4.53 710.53 MWD+IFR2+SAG+MS(2) 2,798.55 54.94 265.95 2,563.62 2,426.05 35.60 -786.08 5,949,022.14 487,113.26 2.31 786.82 MWD+IFR2+SAG+MS(2) 2,876.00 57.21 264.97 2,605.84 2,469.31 30.50 450.14 5,949,017.15 487,049.20 3.11 850.68 MWD+IFR2+$AG+MS(2) 2,912.50 59.21 266.88 2,626.07 2,488.54 28.30 481.08 5,949,015.05 487,018.26 7.05 881.53 MWD+SCC+SAG(3) 2,965.12 60.55 265.54 2,652.47 2,514.94 25.29 -926.49 5,949,012.06 486,972.84 3.37 926.83 Interpolated Station 133!8" 3,007.85 61.65 264.48 2,673.12 2,535.59 22.04 -963.76 5,949,008.86 4881935.58 3.37 963.97 MWD+IFR2+SAG+MS(4) 3,029.75 62.45 264.23 2,683.39 2,545.86 20.13 .83.01 5,949,005.99 486,916.32 3.79 983.15 MWD+IFR2+SAG+MS(4) 3,124.54 65.97 262.27 2,724.63 2,587.10 10.08 -1,067.74 5,948,997.03 486,831.58 4.15 1,067.52 MWD+IFR2+SAG+MS(4) 3,218.32 68.78 261.65 2,760.70 2,623.17 -2.03 -1,153.45 5,948,985.11 486,745.87 3.W 1,152.79 MWD+IFR2+SAG+MS(4) 3,312.03 71.51 261.72 2,792.52 2,654.99 -14.77 -1,240.65 5,948,972.50 486,658.65 2.91 1,239.54 MWD+IFR2+SAG+MS(4) 3,405.97 74.45 261.49 2,820.31 2,682.78 -28.03 -1,330.45 5,9481959.40 486,568.84 3.11 1,328.86 MWD+IFR2+SAG+MS(4) 3,501.51 73.79 261.27 2,846.18 2,708.65 41.66 -1,420.35 5,948,945.91 486,478.92 073 1,418.28 MWD+IFR2+SAG+MS(4) 3,595.17 73.71 260.91 2,872.39 2,734.86 55.58 -1,509.19 5,9481932.13 486,390.08 0.38 1,506.62 MWD+IFR2+SAG+MS(4) 3,689.03 74.10 260.79 2,898.41 2,760.88 59.92 -1,598.22 5,9481917.93 486,301.03 0.43 1,595.15 MWD+IFR2+SAG+MS (4) 3,783.05 73.76 260.31 2,924.43 2,786.90 54.76 -1,687.34 5,948,903.25 486,211.89 0.61 1,683.75 MWD+IFR2+SAG+MS (4) 3,877.52 74.14 259.88 2,950.55 2,813.02 -100.37 -1,776.77 5,948,887.77 486,122.44 0.59 1,772.64 MWD+IFR2+SAG+MS(4) 3,972.00 74.08 259.88 2,976.42 2,838.89 -116.34 -1,866.23 5,948,871.95 486,032.97 0.06 1,861.53 MWD+IFR2+SAG+MS (4) 4,065.94 74.04 259.63 3,W2.22 2,864.69 -132.40 -1,955.12 5,948,856.3 485,944.07 0.26 1,949.86 MWD+IFR2+SAG+MS(4) 4,160.31 74.11 259.48 3,028.11 2,890.58 -148.86 -2,044.36 5,948,839.72 485,854.81 0.17 2,038.53 MWD+IFR2+SAG+MS(4) 9/82019 1:15.49PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 2M40 Project Kuparuk River Unit TVD Reference: 2M40 actual Q 137.53usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M40 actual (5) 137.53usft (D19) Non: Rig: 2M40 North Reference: True Welltwrs: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40 Database: OAKEDMPi Survey Map Map vertical MD Inc Azl TVD TVDSS +NIS +E/ -W Northing Easting DLS Sedan (usft) (*) (9 (-ft) rysR) (us/t) (aeft) (R) (11) (.1100') (m Survey Tool Name 4,254.03 73.98 258.98 3,053.87 2,916.34 -165.70 -2,132.88 5,948,823.03 485,766.27 0.53 2,126.46 MWD+IFR2+SAG+MS(4) 4,348.22 74.05 258.85 3,079.81 2,942.28 -183.10 -2,221.74 5,948,805.77 485,677.39 0.15 2,214.72 MWD+IFR2+SAG+MS(4) 4,442.38 74.01 258.84 3,105.72 2,968.19 -200.62 -2,310.56 5,948,788.0 485,588.55 0.04 2,302.93 MWD+IFR2+SAG+MS(4) 4,535.93 74.14 258.58 3131.39 2,993.% -218.23 -2,398.78 5,948,770.93 485,500.31 0.30 2,390.53 MWD+IFR2+SAG+MS(4) 4,629.44 74.04 258.13 3,157.02 3,019.49 -236.38 -2,486.85 5,948,752.92 485,412.22 0.47 2,477.98 MWD+IFR2+SAG+MS(4) 4,723.91 74.02 258.23 3,183.01 3,045.48 -254.99 -2,575.75 5,948,734.46 4a5,323.30 0.10 2,566.24 MWD+IFR2+SAG+MS(4) 4,818.26 74.01 258.02 3,209.00 3,071.47 -273.65 -2,664.51 5,948,715.94 485,234.52 0.21 2,654.35 MWD+IFR2+SAG+MS(4) 4,912.73 74.08 258.20 3,234.96 3,097.43 -292.36 -2,753.39 5,948,697.37 485,145.61 0.20 2,742.59 MWD+IFR2+SAG+MS(4) 5,005.61 74.05 258.20 3,260.46 3,122.93 510.63 -2,840.82 5,948,679.25 485,058.17 0.03 2,829.38 MWD+IFR2+SAG+MS(4) 5,099.87 73.98 257.71 3,286.42 3,148.89 529.54 -2,929.44 5,948,660.49 484,969.53 0.51 2,917.35 MWD+IFR2+SAG+MS(4) 5,194.19 74.05 257.77 3,312.40 3,174.87 54879 5,018.04 5,948,641.38 484,880.90 0.10 3,005.29 MWD+IFR2+SAG+MS(4) 5,291.07 74.02 257.95 3,339.04 3,201.51 468.38 4,109.10 5,948,621.94 484,789.82 0.18 3,095.67 MWD+IFR2+SAG+MS(4) 5,385.06 74.08 258.95 3,364.87 3,227.34 586.47 5,197.64 5,948,603.99 484,701.26 1.02 3,183.59 MWD+IFR2+SAG+M$(4) 5,479.66 74.08 259.12 3,390.82 3,253.29 403.78 4,285.95 5,948,586.83 484,611.93 0.17 3,272.30 MWD+IFR2+SAG+MS (4) 5,574.22 74.08 259.69 3,416.76 3,279.23 420.50 5,376.34 5,948,570.25 484,522.53 0.58 3,361.10 MWD+IFR2+SAG+MS (4) 5,668.01 74.17 260.45 3,442.41 3,304.98 435.05 4,465.20 5,94$554.84 484,433.65 0.79 3,449.41 MWD+IFR2+SAG+MS (4) 5,760.65 73.95 260.88 3,467.86 3,330.33 450.50 5,553.10 6,948,540.54 484,345.74 0.51 3,636.80 MWD+IFR2+SAG+MS(4) 5,854.69 74ffi 260.73 3,493.80 3,356.27 464.95 4,642.32 5,948,526.24 484,256.50 0.17 3,625.52 MWD+IFR2+SAG+MS(4) 5,948.35 73.99 260.76 3,519.61 3,382.8 479.43 5,731.19 5,948,511.90 484,167.62 0.04 3,713.87 MWD+IFR2+SAG+MS(4) 6,042.81 73.99 260.85 3,545.66 3,408.13 493.94 4,820.82 5,948,497.54 484,077.98 0.09 3,802.99 MWD+IFR2+SAG+MS(4) 6,136.81 73.95 260.51 3,571.62 3,434.09 508.57 5,909.97 5,948,483.05 483,988.81 0.35 3,891.62 MWD+IFR2+SAG+MS(4) 6,231.51 74.11 26070 3,597.67 3,460.14 523.43 4,999.79 5,948,468.33 483,898.97 0.26 3,980.92 MWD+IFR2+SAG+MS (4) 6,325.02 74.21 260.40 3,623.20 3,485.67 -538.20 4,088.53 5,948,453.71 483,810.22 0.33 4.069.14 MWD+IFR2+SAG+MS(4) 6,419.25 74.04 260.97 3,648.97 3,511.44 552.67 4.177.97 5,948,439.18 483,720.76 0.61 4,158.07 MWD+IFR2+SAG+MS(4) 6,513.84 74.08 260.86 3,674.95 3,537.42 567.23 4,267.78 5,948,424.97 483,630.94 0.12 4,247.37 MWD+IFR2+SAG+MS (4) 6,608.21 74.07 261.08 3,700.84 3,563.31 581.47 4,357.41 5,946,410.87 483,541.30 0.22 4,336.49 MWD+IFR2+SAG+MS(4) 6,701.68 74.08 261.10 3,726.49 3,588.96 595.40 4,446.20 5,946397.09 483,452.49 0.02 4,424.80 MWD+IFR2+SAG+MS(4) 6,796.15 73.92 260.90 3,752.53 3,615.00 509.60 4,535.90 5,948,383.03 483,362.78 0.26 4,513.99 MWD+IFR2+SAG+MS(4) 6,890.30 74.11 260.84 3,778.46 3,640.93 -623.96 4,625.26 5,948,368.82 483,273.40 0.21 4,602.84 MWD+IFR2+SAG+MS(4) 6,984.43 74.09 260.74 3,804.24 3,666.71 538.45 4.714.62 5,946354.47 483,164.03 0.10 4,691.69 MWD+IFR2+SAG+MS(4) 7,078.36 7371 26086 3,830.29 3,692.76 652.88 4,803.71 5,948,340.19 483,094.93 0.42 4,780.27 MWD+IFR2+SAG+MS(4) 7,173.61 73.84 260.94 3,856.91 3,719.38 667.35 4,894.01 5,948,325.87 483,004.61 0.16 4,870.06 MWD+IFR2+SAG+MS(4) 7,267.33 73.84 261.06 3,882.99 3,745.46 681.43 4,982.92 5,948,311.93 482,915.69 0.12 4,958.47 MWD+IFR2+$AG+MS(4) 7,361.03 73.87 260.43 3,909.05 3,771.52 -695.90 5,071.75 5,948,297.60 482,826.84 0.65 5,046.79 MWD+IFR2+SAG+MS (4) 7,456.54 73.87 259.86 3,935.58 3,798.05 -711.61 5,162.15 5,946282.05 482,736.43 0.57 5,136.64 MWD+IFR2+SAG+MS(4) 7,551.6 73.71 259.0 3,962.08 3,824.55 -728.01 5,251.81 5,948,265.78 482,646.75 0.49 5,225.72 MWD+IFR2+SAG+MS (4) 7,644.09 73.85 259.28 3,987.95 3,850.42 -744.47 5,339.21 5,946249.47 482,559.33 0.20 5,312.56 MWD+IFR2+SAG+MS(4) 7,738.24 73.78 259.36 4,014.20 3,876.67 -761.22 6,428.07 5,946232.86 482,470.46 0.11 5,400.83 MWD+IFR2+SAG+MS(4) 7,832.19 73.68 259.22 4,040.52 3,902.99 -777.98 5,516.68 5,948,216.25 482,381.82 0.18 5,488.86 MWD+IFR2+SAG+MS(4) 7,926.05 73.82 259.15 4,066.78 3,929.25 -794.89 5,605.19 5,948,199.48 482,293.30 0.17 5,576.78 MWD+IFR2+SAG+MS(4) 9/8/2019 1:15:49PM Page 4 COMPASS 5000.14 Build 86 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 2M40 Project: Kuparuk River Unit TVD Reference: 2M-40 actual @ 137.53usR (D19) Site: Kuparuk 2M Pad MD Reference: 2M-40 actual @ 137.53ush (D19) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40 Database: OAKEDMPI Survey Map Map vertical MD Inc Aid TVD TVDSS +wS +E1 -W Northing Easting OLS Section (USM (1) P) (usft) (usft) (usft) (usft) (to (ft) (°11001 (ft) Survey Tool Nam 8,020.75 73.74 259.11 4,093.23 3,955.70 -812.04 5,694.49 5,948,182.48 482,203.98 0.09 5,665.48 MWD+IFR2+SAG+MS(4) 8,114.76 73.93 258.91 4,119.41 3,981.88 -829.25 5,783.13 5,948,165.41 482,115.32 0.29 5,753.52 MWD+IFR2+SAG+MS(4) 8,208.73 73.90 258.41 4,145.44 4,007.91 447.01 5,871.66 5,948,147.80 482,026.78 0.51 5,841.44 MWD+IFR2+SAG+MS(4) 8,302.84 73.91 258.99 4,171.53 4,034.0 -864.72 -5,960.32 5,948,130.23 481,938.09 0.59 5,929.49 MWD+IFR2+SAG+MS (4) 8,398.21 73.81 259.12 4,198.04 4,060.51 4182.12 5,050.27 5,948,112.98 481,848.12 0.17 6,018.83 MWD+IFR2+SAG+MS(4) 8,491.41 73.75 259.38 4,224.06 4,086.55 -898.81 5,138.19 5,948,096.43 481,760.19 0.28 6,106.17 MWD+IFR2+SAG+MS(4) 8,586.99 74.00 259.43 4,250.62 4,113.L6 -915.69 5,228.44 S.M,079.70 481,659.91 0.27 6,195.83 MWD+IFR2+SAG+MS(4) 8,680.26 73.77 259.75 4,276.51 4,138.98 -931.88 5,316.57 5,948,063.65 481,581.77 0.41 6,283.40 MWD+IFR2+SAG+MS(4) 8,774.69 73.93 260.09 4,302.78 4,165.25 -947.76 5,405.88 5,948,047.92 481,492.45 0.39 6,372.14 MWD+IFR2+SAG+MS(4) 8,858.66 73.83 259.99 4,328.87 4,191.39 -%3.37 4,49419 5,948,032.45 481,403.52 0.15 6,46051 MWD+IFR2+SAG+MS(4) 8,961.20 74.06 260.45 4,354.6 4,216.93 -978.48 4,582.43 5,M.017.48 481,315.86 0.64 6,547.62 MWD+IFR2+SAG+MS (4) 9,056.29 73.86 260.56 4,380.74 4,243.21 493.55 4672.57 5,948,002.56 481,225.71 0.24 6,637.23 MWD+IFR2+SAG+MS(4) 9,149.79 74.00 260.54 4,4 .62 4,269.D9 -1,008.30 5,761.19 5,947,987.95 481,137.07 0.15 6,725.33 MWD+IFR2+SAG+M$(4) 9,244.16 73.83 260.79 4,432.76 4,295.23 -1,023.01 4,850.67 5,947,973.38 481,047.58 0.31 6,814.29 MWD+IFR2+SAG+MS(4) 9,338.49 74.03 261.41 4,458.8B 4,321.35 -1,037.04 4,940.22 5,947,959.51 480,958.02 0.67 6,903.35 MWD+IFR2+SAG+MS(4) 9,432.37 73.86 261.65 4,484.84 4,347.31 -1,050.32 -7,029.45 5,947,946.36 480,868.77 0.31 6,992.11 MWD+IFR2+SAG+MS(4) 9,526.59 74.06 261.40 4,510.87 4,373.34 -1,063.67 -7,119.02 5,947,933.16 480,779.19 0.33 7,081.19 MWD+IFR2+SAG+MS(4) 9,626.50 73.71 260.99 4,538.61 4,401.08 -1,078.36 -7,213.87 5,947,918.63 480,684.33 0.53 7,175.53 MWD+IFR2+SAG+MS (4) 9,720.21 73.91 261.01 4,564.73 4,427.20 -1,092.44 -7,302.75 5,947,904.69 480,595.43 0.21 7,263.91 MWD+IFR2+SAG+MS(4) 9,814.77 73.93 260.26 4,590.93 4,453.40 -1,107.23 -7,392.40 5,947,890.05 480,505.76 0.76 7,353.04 MWD+IFR2+SAG+MS(4) 9,909.15 73.71 260.20 4,617.23 4,479.70 -1,122.61 -7,481.73 5,947,874.82 480,416.42 0.24 7,441.83 MWD+IFR2+SAG+MS(4) 10,002.90 73.85 260.01 4,643.41 4,505.88 -1,138.08 -7,570.41 5,947,859.49 480,327.73 0.25 7,529.97 MWD+IFR2+SAG+MS(4) 10,096.89 73.90 259.70 4,669.52 4,531.99 -1,153.98 -7,659.29 5,947,843.73 480,238.83 0.32 7,618.29 MWD+IFR2+SAG+MS(4) 10,191.50 73.93 259.92 4,695.73 4,558.20 -1,170.06 -7,748.76 5,947,827.79 480,149.34 0.23 7,707.20 MWD+IFR2+SAG+MS(4) 10,284.79 73.65 260.43 4,721.77 4,584.24 -1,185.35 -7,837.03 5,947,812.65 480,061.06 0.60 7,794.93 MWD+IFR2+SAG+MS(4) 10,379.15 73.84 260.0 4,748.18 4,610.65 -1,200.74 -7,926.30 5,947,797.40 479,971.77 0.48 7,883.66 MWD+IFR2+$AG+MS(4) 10,473.82 73.66 260.11 4,774.68 4,637.15 -1,216.44 5,015.82 5,947,781.85 479,88223 0.22 7,972.63 1MD+IFR2+SAG+MS(4) 10,568.78 73.35 259.86 4,801.64 4,664.11 -1,232.27 -8,105.49 5,947,765.16 479,792.55 0.41 8,061.74 MWD+IFR2+SAG+MS(4) 10,663.08 73.26 259.95 4,828.73 4,691.20 -1,248.11 -8,194.41 5,947,750.47 479,703.61 0.13 8,150.11 MWD+IFR2+SAG+MS(4) 10,756.91 73.42 260.16 4,855.63 4,718.10 -1,263.63 -8,282.95 5,947,735.09 479,615.05 0.27 8,238.11 MWD+IFR2+SAG+MS(4) 10,850.59 73.48 259.54 4,882.31 4,744.78 -1,279.46 -8,371.35 5,947,719.41 479,526.64 0.64 8,325.95 MWD+IFR2+SAG+MS(4) 10,945.50 73.64 259.32 4,909.17 4,771.64 -1,296.15 4,460.83 5,947,702.86 479,437.14 0.28 8,414.85 MWD+IFR2+SAG+MS (4) 11,039.88 73.48 259.6 4,935.89 4,798.36 -1,313.13 -8,549.75 5,947,686.03 479,348.21 0.31 8,503.18 MWD+IFR2+SAG+MS (4) 11,133.26 73.49 259.57 4,962.43 4,824.90 -1,329.73 4,637.72 5,947,669.57 479,260.22 0.52 8,590.57 MWD+IFR2+SAG+MS(4) 11,227.50 73.17 259.58 4,989.46 4,851.93 -1,346.07 4,726.51 5,947,653.38 479,171.41 0.34 8,678.79 MWD+IFR2+SAG+MS(4) 11,321.29 73.37 259.65 5,016.46 4,878.93 -1,362.26 -8,014.86 5,947,637.33 479,083.04 0.22 8,766.58 MWD+IFR2+SAG+MS(4) 11,415.90 73.52 259.70 5,043.42 4,905.89 -1,378.51 4,904.08 5,947,621.22 478,993.81 0.17 8,855.23 MWD+IFR2+SAG+MS(4) 11,510.78 73.52 259.57 5,070.34 4,932.81 -1,394.88 4,993.58 5,947,605.00 478,904.29 0.13 8,944.15 MWD+1FR2+SAG+MS (4) 11,604.98 73.45 259.41 5,097.11 4,959.58 -1,411.36 -9,082.37 5,947,588.67 478,815.48 0.18 9,032.38 MWD+IFR2+SAG+MS(4) 11,699.15 73.36 259.79 5,124.01 4,986.48 -1,427.65 -9,171.14 5,947,572.52 478,726.69 0.40 9,120.57 MWD+IFR2+SAG+MS (4) 9/62019 1:15:49PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 21440 Project: Kuparuk River Unit TVD Reference: 2M40 actual @ 137.53usft (019) Site: Kuparuk 2M Pad MD Reference: 2M40 actual @ 137.53usft (D19) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40 Database: OAKEDMPI Survey 9/62019 1:15:49PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (wiry C) 0 (uslt) (usft) (usft) (uaR) (ft) (it) (ileo') (it) Survey Toot Name 11 ]93.59 73.27 259.56 5,151.12 5,013.59 -1,443.86 5,260.14 5,947,556.45 478,637.60 0.25 9,209.01 MWD+IFR2+SAG+MS (4) 11,987.87 73.33 259.32 5,178.22 5,040.69 -1,460.41 5,348.91 5,947,540.05 478,548.89 0.25 9,297.20 MWD+IFR2+SAG+MS(4) 11,982.04 73.56 259.06 5,205.05 5,067.52 -1,477.34 -9,437.58 5,947,523.26 478,460.20 0.36 9,385.28 MWD+IFR2+SAG+MS(4) 12,075.84 73.30 258.86 5,231.80 5,094.27 -1,494.54 5,525.82 5,947,506.21 478,371.94 0.33 9,472.92 MWD+IFR2+SAG+MS (4) 12,169.79 73.56 258.28 5,258.59 5,121.06 -1,512.37 5,614.08 5,947,488.52 478,283.66 0.67 9,560.57 MWD+IFR2+SAG+MS (4) 12,263.64 71.70 253.87 5,286.62 5,149.09 -1,533.90 5,701.00 5,947,467.13 478,196.72 4.90 9,646.75 MWD+IFR2+SAG+MS 14) 12,358.15 70.02 249.38 5,317.62 5,180.09 -1,562.02 5,785.71 5,947,439.15 478,111.97 4.83 9,730.51 MWD+IFR2+SAG+MS(4) 12,452.32 68.10 244.88 5,351.29 5,213.76 -1,596.17 -9,866.72 5,947,405.14 478,030.91 4.91 9,810.39 MWD+IFR2+SAG+MS(4) 12,545.71 67.46 243.02 5,386.61 5,249.08 -1,634.13 -9,944.39 5,947,367.30 477,953.19 1.97 9,886.80 MWD+IFR2+SAG+MS(4) 12.639.27 66.95 242.24 5,422.86 5,285.33 -1,673.78 -10,020.99 5,947,327.78 477,876.53 0.94 9,962.08 MWD+IFR2+SAG+MS(4) 12,733.63 64.93 240.43 5,461.33 5,323.80 -1715.10 -10,096.59 5,947,286.59 477,WO.BB 2.77 10,036.31 MWD+IFR2+SAG+MS(4) 12,826.90 65.21 237.56 5,500.65 5,363.12 -1,758.66 -10,169.07 5,947,243.14 477,728.33 2.81 10,107.36 MWD+IFR2+SAG+MS(4) 12,921.62 64.65 234.20 5,540.80 5,403.27 -1,806.77 -10,240.09 5,947,195.15 477,657.24 3.27 10,176.80 MWD+IFR2+SAG+MS(4) 13,016.26 64.09 230.67 5,581.74 5,444.21 -1,85816 -10,307.71 5,947,143.26 477,589.54 3.41 10,242.72 MWD+IFR2+SAG+MS(4) 13,110.91 62.84 226.90 5,624.04 5,486.51 -1,914.55 -10,371.40 5,947,087.60 477,525.77 3.80 10,304.59 MWD+IFR2+SAG+MS(4) 13,204.28 62.01 223.88 5,667.27 5,529.74 -1,972.65 -10,430.32 5,947,029.59 477,466.76 3.00 10,361.61 MWD+IFR2+SAG+MS(4) 13,299.26 61.46 220.44 5,712.26 5,574.73 -2,034.65 -10,486.46 5,946,967.70 477,410.53 3.24 10,415.73 MWD+IFR2+SAG+MS(4) 13,393.39 59.64 215.27 5,758.56 5,621.03 -2,099.31 -10,536.76 5,946,903.12 477,360.13 5.16 10,463.93 MWD+IFR2+SAG+MS(4) 13,433.15 58.71 212,0 5,778.94 5,601.41 -2,127.66 -10,555.77 5,946,874.80 477,341.07 6.62 10,482.02 MWD+IFR2+SAG+MS(4) 13,485.62 58.57 209.48 5,806.25 5,668.72 -2,166.09 -10,578.80 5,946,836.42 477,317.98 4.76 10,503.80 Interpolated Station S.M.. 13,530.17 58.50 206.99 5,829.50 5,691.97 -2,199.56 -10,596.78 5,946,802.98 477,299.96 4.76 10,520.69 MWD+IFR2+SAG+MS(5) 13,623.45 62.31 203.58 5,875.57 5,738.04 4!,272.89 -10,631.37 5,946,729.71 477,265.25 5.17 10,552.91 MWD+IFR2+SAG+MS(5) 13,717.90 65.59 200.93 5,917.05 5,779.52 -2,351.41 -10,611 5,946,651.25 477,233.03 4.29 10,582.48 MWD+IFR2+SAG+MS (5) 13,812.59 68.42 200.58 5,954.04 5,816.51 -2,432.92 -10,694.35 5,946,569.80 477,202.02 3.01 10,610.73 MWD+IFR2+SAG+MS(5) 13,906.06 71.39 202,4 5,986.15 5,848.62 -2,514.56 -1D,726.55 5,946,488.22 477,169.70 3.69 10,640.28 MWD+IFR2+SAG+MS(5) 14,000.70 73.86 201.61 6,014.41 5,876.88 -2,598.29 -10,760.41 5,946,404.55 477,135.70 2.74 10,671.44 MWD+IFR2+SAG+MS(5) 14,094.17 76.07 200.08 6,038.66 5,901.13 -2,682.64 -10,792.52 5,946,320.26 477,103.45 2.84 10,700.83 MWD+IFR2+SAG+MS(5) 14,188.60 78.66 197.48 6,059.32 5,921.79 -2,769.87 -10,822.17 5,94fi,233.09 477,073.67 3.84 10,727.65 MWD+IFR2+SAG+MS(5) 14,218.66 79.97 195.97 6,064.89 5,927.36 -2,798.16 -10,830.67 5,946,204.82 477,065.12 6.58 10,735.25 MW0+11FR2+SAG+MS(5) 14,283.00 81.99 194.94 6,074.98 5,937.45 -2,859.40 -10,847.60 5,946,143.61 477,048.10 3.52 10,750.20 Interpolated Station T., 14,317.59 83.08 194.39 6,079.47 5,941.94 -2,892.58 -10,856.28 5,946,110.45 477,039.36 3.52 10,757.82 MW1)+IFR2+SAG+MS(6) 14,350.73 83.13 191.87 6,083.45 5,945.92 -2,924.62 -10,863.76 5,946,078.42 477,031.84 7.55 10,769.26 MWD+IFR2+SAG+MS(6) 14,444.18 84.08 191.03 6,093.86 5,956.33 -3,015.64 -10,B82.19 5,945,987.44 477,013.26 1.35 10,779.76 MW0+IFR2+SAG+MS(6) 14,537.96 87.67 190.65 6,100.60 5,963.07 3,107.49 -10,899.78 5,945,895.63 476,995.53 3.85 10,794.39 MWD+IFR2+SAG+MS(6) 14,632.12 90.20 188.88 6,102.35 5,964.82 -3,200.26 -10,915.74 5,945,802.90 476,979.41 3.28 10,807.37 MWD+IFR2+SAG+MS(6) 14,727.46 90.38 194.95 6,101.87 5,964.34 -3,293.50 -10,935.42 5,945,709.70 476,959.59 6.37 10,824.04 MWD+IFR2+SAG+MS(6) 14,821.92 90.79 192.49 6,100.90 5,963.37 -3,385.25 -10,957.82 5,945,617.99 476,937.05 2.64 10,843.48 MWD+IFR2+SAG+MS(6) 14,915.33 90.69 192.33 61099.70 5,962.17 3,476.47 -10,977.89 5,945,526.81 476,916.83 0.20 10,860.61 MWD+IFR2+SAG+MS(6) 9/62019 1:15:49PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 2M40 Project: Kuparuk River Unit TVD Reference: 2M40 actual @ 137.53usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M40 actual @ 137.53usft lot 9) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum Curvature Design: 21040 Database: OAKEDMPI Survey Map Map vertical MD Inc Azi TVD TVDSS +W.4 +EFAN Northing Easting DLS Section (us!" (1) (') Will) Net) (usft) (uslt) (ft) (Iq (611001) (ft) Survey Tool Name 15,010.10 89.97 192.90 6,099.15 5,961 62 -3,568.94 -10,998.62 5,945,434.38 476,895.95 1.00 10,87B.35 MWD+IFR2+SAG+MS (6) 15,104.56 88.73 195.18 6,100.22 5,962.69 3,660.56 -11,021.57 5,945342.81 476,872.86 2.71 10,898.36 MWD+IFR2+SAG+M$(6) 15,198.39 88.72 200.83 6,102.31 5,964.78 3,749.74 -11,050.55 5,945,253.69 476,843.74 6.02 10,924.46 MWD+IFR2+SAG+MS(6) 15,293.13 87.32 197.16 6,105.59 5,968.6 -3,839.25 -11,081.36 5,945,164.24 476,812.78 4.14 10,952.38 MWD+IFR2+$AG+M$(6) 15,386.46 87.26 196.06 6,110.00 5,972.47 3,928.58 -11,108.01 5,945,074.96 476,785.99 1.18 10,976.15 MWD+IFR2+SAG+MS(6) 15,481.77 87.26 200.37 6,114.56 5,977.03 -0,018.99 -11,137.76 5,944,984.60 476,756.10 4.52 11,002.98 MWD+IFR2+SAG+MS(6) 15,575.89 86.87 199.28 6,119.38 5,981.85 4,107.41 -11,169.64 5,944,896.24 476,724.08 1.23 11,032.01 MWD+IFR2+SAG+MS(6) 15,669.72 88.09 196.91 6,123.50 5,985.97 4,196.51 -11,198.75 5,944,807.20 476,694.83 2.84 11,058.24 MWD+IFR2+SAG+MS(6) 15,762.72 88.60 195.99 6,126.19 5,988.66 4,285.66 -11,225.08 5,944,718.10 476,668.37 1.13 11,081.69 MWD+IFR2+SAG+MS(6) 15,856.82 88.63 196.05 6,128.46 5,990.93 4,376.00 -11,251.04 5,944,627.73 476,642.26 0.07 11,104.74 MWD+IFR2+SAG+MS(6) 15,953.26 88.50 191.91 6,130.88 5,993.35 4,469.62 -11,274.33 5,944,534.24 476,618.83 4.29 11,125.01 MWD+IFR2+SAG+MS(6) 16,047.53 88.60 184.22 6,133.27 5,995.74 4,562.85 -11,287.54 5,941,441.03 476,605.47 8.16 11,135.22 MWD+IFR2+SAG+MS(6) 16,139.54 88.70 183.16 6,135.44 5,997.91 4,654.65 -11,293.46 5,944,349.26 476,599.40 1.16 11,138.19 MWD+IFR2+SAG+MS(6) 16,236.67 89.18 186.27 6,137.24 5,999.71 4,751.42 -11,301.44 5,944,252.51 476,591.27 3.24 11,143.06 MWD+IFR2+SAG+MS (6) 16,329.91 89.15 189.81 6,138.59 6,001.06 4,84372 -11,314+8 5,944,160.24 476,578.08 3.80 11,153.13 MWD+IFR2+SAG+MS(6) 16,424.35 88.94 188.63 6,140.17 6,002.64 4,936.92 -11,329.61 5,944,067.07 476,552.80 1.27 11,165.26 MWD+IFR2+SAG+MS(6) 16,518.13 89.45 189.89 6,141.49 6,003.96 5,029.47 41,344.69 5,943,974.55 476,547.57 1.45 11,177.36 MWD+IFR2+SAG+MS(6) 16,612.10 91.45 191.09 6,140.75 6,003.22 5,121.86 -11,361.80 5,943,882.20 476,530.31 2.48 11,191.50 MWD+IFR2+SAG+MS(6) 16,705.73 93.41 192.16 6,136.78 5,999.25 5,213.48 -11,380.65 5,943,790.62 476,511.32 2.38 11,207.39 MWD+IFR2+SAG+MS(6) 16,800.12 93.49 194.19 6,131.10 5,993.57 5,305.22 -11,402.12 5,943,698.93 476,489.70 2.15 11,225.91 MWD+IFR2+SAG+MS(6) 16,893.93 89.99 196.67 6,128.25 5,990.72 5,395.58 -11,427.07 5,943,608.62 476,464.61 4.57 11,247.94 MWDNFR2+SAG+MS(6) 16,987.95 89.00 199.29 6,129.08 5,991.55 5,485.00 -11,456.08 5,943,519.26 476,435.46 2.98 11,274.07 MWD+IFR2+SAG+MS(6) 17,082.16 90.01 194.63 6,129.89 5,992.36 5,575.08 -11,483.56 5,943,429.23 476,407.84 5.06 11,298.64 MWD+IFR2+SAG+MS(6) 17,176.36 90.18 191.10 6,129.74 5,992.21 5,666.90 -11,504.53 5,943,337.45 476,386.73 3.75 11,316.65 MWD+IFR2+SAG+MS(6) 17,270.70 89.20 189.63 6,130.25 5,992.72 5,759.70 -11,521.50 5,943,244.69 476,369.61 1.87 11,330.63 MWD+IFR2+SAG+MS(6) 17,364.75 90.04 186.61 6,130.87 5,993.34 -5,852.79 -11,534.78 5,943,151.63 476,356.17 3.33 11,300.92 MWD+IFR2+SAG+MS (6) 17,460.29 90.35 186.56 6,130.55 5,993.02 5,947.70 -11,545.74 5,943,056.74 476,345.07 0.33 11,348.82 MWD+IFR2+SAG+MS (6) 17,554.46 90.01 187.76 6,130.25 5,992.72 5,041.13 -11,557.48 5,942,963.34 476,333.18 1.32 11,357.56 MWD+IFR2+SAG+MS (6) 17,648.66 88.66 186.80 6,131.34 5,993.81 6,134.56 -11,569.41 5,942,869.94 476,321.10 1.76 11,366.49 MWD+1FR2+SAG+MS (6) 17,742.98 88.91 188.50 6,133.34 5,995.81 6,228.02 -11,581.96 5,942,776.51 476,308.39 1.82 11,376.03 MW13+1FR2+SAG+MS (6) 17,835.82 89.25 187.81 6,134.83 5,997.30 5,319.91 -11,595.13 5,942,684.65 476,295.08 0.83 11,386.24 MWD+IFR2+SAG+MS(6) 17,930.82 89.39 189.09 6,135.96 5,998.43 5,413.87 -11,609.09 5,942,590.72 476,280.97 1.36 11,397.18 MWD+IFR2+SAG+MS(6) 18,025.20 89.25 189.80 6,137.08 5,999.55 6,506.96 -11,624.58 5,942,497.66 476,265.34 0.77 11,409.67 MWD+IFR2+SAG+MS(6) 18,119.41 89.35 191.94 6,138.23 6,000.70 5,599.47 -11,642.34 5,942,405.20 476,247.43 2.27 11,424.45 MWD+IFR2+SAG+MS(6) 18,213.26 88.49 191.64 6,140.00 6,002.47 501.32 -11,661.51 5,942,313.38 476,228.11 0.97 11,490.65 MWD+IFR2+SAG+MS(6) 18,306.92 88.94 190.05 6,142.10 6,004.57 6,783.28 -11,679.13 5,942221.46 476,210.34 1.76 11,455.32 MWD+IFR2+SAG+MS(6) 18,402.78 86.94 193.05 6,143.88 6,006.35 5,877.18 -11,690.32 5,942,127.61 476,191.01 3.13 11,471.48 MWD+IFR2+SAG+MS(6) 18,497.59 88.87 196.21 6,145.69 6,008.16 5,968.88 -11,722.26 5,942,035.95 476,166.92 3.33 11,492.47 MWD+IFR2+SAG+MS(6) 18,591.11 89.22 195.60 6,147.25 6,009.72 -7,058.81 A1,747.88 5,941,946.07 476,141.16 0.75 11,515.19 MWD+IFR2+SAG+MS(6) 18,684.78 89.77 203.74 6,148.07 6,010.54 -7,146.94 -11,779.38 5,941,858.01 476,109.52 8.71 11,543.85 MWD+IFR2+SAG+MS(6) 9/6!2019 1:15:49PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 2M-40 Project Kuparuk River Unit TVD Reference: 2M40 actual @ 137.53usft (D19) Site; Kuparuk 2M Pad MD Reference: 2M40 actual @1 137.53usft (1319) Well: Rig: 2M40 North Reference: True Wellbore: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40 Database: OAKEDMP1 Survey 9/6/2019 1:15:49PM Page 8 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS +WS +E/ -W Northing Easgng DLS Section (udt) C) P) (uslt) (usft) (usft) (usft) (1q (ft) C1100') (ft) Survey Tool Name 18,779.17 88.04 201.33 6,149.88 6,012.35 -7,234.09 -11,815.55 5,941,770.92 476,073.22 3.14 11,577.19 MWD+IFR2+SAG+MS(6) 18,873.26 87.83 198.23 6,153.27 6,015.74 -7,322.56 -11,847.37 5,941,682.50 476,041.26 3.30 11,606.15 MWD+IFR2+SAG+MS 16) 18,968.53 89.01 194.99 6,155.90 6,018.37 -7,413.81 -11,874.58 5,941,591.31 476,013.90 3.62 11,630.43 MWD+IFR2+SAG+MS(6) 19,062.29 89.11 192.33 6,157.43 6,019.90 -7,504.90 -11,896.72 5,941,500.27 475,991.62 2.84 11,649.63 MWD+IFR2+SAG+MS(6) 19,155.32 90.19 191.99 6,158.00 6,020.47 -7,595.84 -11,916.32 5,941,409.37 475,971.88 1.22 11,666.30 MWD+IFR2+SAG+MS(6) 19,250.40 93.54 189.83 6,154.91 6,017.38 -7,689.13 -11,934.30 5,941,316.12 475,953.74 4.19 11,681.27 MWD+IFR2+SAG+MS(6) 19,345.40 90.43 189.36 6,151.62 6,014.09 -7,782.73 -11,950.12 5,941,222.55 475,937.77 3.31 11,694.08 MWD+IFR2+SAG+MS(6) 19,438.85 89.59 190.08 6,151.60 6,014.07 -7,874.84 -11,965.90 5,941,130.47 475,921.85 1.18 11,706.90 MWD+IFR2+SAG+MS(6) 19,533.15 88.38 193.23 6,153.27 6,015.74 -7,967.17 -11,984.94 5,941,038.19 475,902.66 3.58 11,722.97 M1vD+IFR2+SAG+MS(6) 19,627.20 88.57 192.81 6,155.78 6,018.25 -8,058.77 -12,006.13 5,940,946.63 475,881.33 0.49 11,741.20 MWD+IFR2+SAG+MS(6) 19,721.37 89.32 188.64 6,157.51 6,019.98 -8,151.26 -12,023.64 5,940,854.18 475,863.67 4.50 11,755.73 MWD+IFR2+SAG+MS(6) 19,816.82 89.05 185.07 6,158.87 6,021.34 -8,246.00 -12,035.03 5,940,759.47 475,852.13 3.75 11,764.08 MWD+IFR2+SAG+MS(6) 19,910.57 88.40 182.39 6,160.95 6,023.42 -8,339.52 -12,041.13 5,W,665.97 475,845.88 2.94 11,767.17 MWD+IFR2+SAG+MS(6) 20,004.67 87.85 183.89 6,164.03 6,026.50 -8,433.42 -12,N6.28 5,940,572.08 475,840.58 1.70 11,769.30 MWD+IFR2+SAG+MS(6) 20,097.76 87.28 187.71 6,167.99 6,030.46 -8,525.93 -12,055.68 5,940,479.59 475,831.03 4.15 11,775.72 MWD+IFR2+SAG+MS(6) 20,192.59 88.02 193.78 6,171.88 6,034.35 -8,618.98 -12,073.34 5,940,386.58 475,813.23 6.44 11,790.38 MWD+IFR2+SAG+MS (6) 20,286.66 88.29 198.19 6,174.91 6,037.38 -8,709.34 -12,099.22 S.W.296.27 475,787.20 4.69 11,813.35 MWD+IFR2+SAG+MS(6) 20,380.29 87.69 202.06 6,178.20 6,040.67 -8,797.18 -12,131.41 5,M,208.49 475,764.87 4.18 11,842.71 MWD+IFR2+SAG+MS(6) 20,475.11 89.04 207.71 6,180.91 6,043.38 .8,883.13 -12,171.26 5,940,122.62 475,714.87 6.12 11,879.79 MWD+IFR2+SAG+MS(6) 20,570.58 88.52 2N.49 6,182.94 6,045.41 -8,968.83 -12,213.26 5,w,aw.99 475,672.75 3.42 11,919.01 MWD+IFR2+SAG+MS(6) 20561.72 93.04 201.08 6,181.70 6,044.17 -9,052.82 -12,248.54 5,939,953.07 475,637.34 6.21 11,951.57 MWD+IFR2+SAG+MS(6) 20,765.90 92.27 198.42 6,177.33 6,039.80 -9,141.35 -12,280.33 5,939,864.59 475,605.41 2.94 11,980.50 MWD+IFR2+SAG+MS(6) 20,850.79 90.62 197.83 6,174.94 6,037.41 -9,231.50 -12,309.84 5,939,774.50 475,575.76 1.85 12,007.10 MWD+IFR2+SAG+MS(6) 20,946.44 88.86 194.21 6,175.38 6,037.85 -8,323.42 -12,336.23 5,939,682.64 475,549.23 4.21 12,030.53 MWD+IFR2+SAG+MS(6) 21,038.85 89.59 195.19 6,176.63 6,039.10 -9,412.79 -12,359.68 5,939,593.31 475,525.64 1.32 12,051.09 MWD+IFR2+SAG+MS(6) 21,132.89 89.27 190.54 6,177.56 6,040.03 &,SN.44 -12,380.61 5,939,501.70 475,504.56 4.% 12,069.07 MWD+IFR2+SAG+MS(6) 21,182.96 90.22 188.99 6,177.78 6,040.25 -9,553.79 -12,389.10 5,939,452.38 475,495.99 3.63 12,075.97 MWD+IFR2+SAG+MS(6) 21,201.00 90.22 188.99 6,177.72 6,040.19 &,571.60 -12,391.92 5,939,434.57 475,493.14 0.00 12,078.22 Interpolated Station 41/2" 21,245.00 90.22 188.99 6,177.55 6,040.02 4t,615.06 -12,398.80 5,939,391.12 475,485.20 0.00 12,083.70 PROJECTED WTD 9/6/2019 1:15:49PM Page 8 COMPASS 5000.14 Build 85 a Cement Detail Report 2M-40 String: Surface Cement Job: DRILLING ORIGINAL, 7/17/2019 12:00 Cement Details Description Surface Cement Cementing Start Date 7/24/2019 21:15 Cementing En tl Date 71 in 019 01:45 Wellbore Name 2M-40 Comment Line up T/ SLB cementers, pump 5 bbls CW 100, shut in T/ psi test surface equip, test surface equip. @ 2500 psi, pump 35 bbls CW 100 @ 4 BPM, 114 psi, pump 80 bbls 10.5 Mud Push II @ 4 BPM, 118 psi, Drop bottom plug, pump 525 bbls, 11 ppg Lead cement @ 6 BPM, 123 / 216 psi. Continue pumping cement, Pump 71 bbls 12 ppg Tail cmt, Drop lop plug, K/O W/ 10.5 bbls 1-12), Displace w/ 419 bbls 9.5 spud mud,. Lost return @ 366 bbis into displacement. 165 bbls mud loss w/ displacing, bumped plug @ 3552 slks, icp = 330 psi FIC= 580 psi, Plug bumpetl @ 01:40 hrs 7-5-19 -no cement relurs to surface. Mud Push was returned to surface but cement was not. Cement Stages Stage # 0 Description Surface Cement Objective Top Depth (ftKB) 176.0 Bottom Depth (ftKB) 2,965.0 Full Return? No Vol Cement... Top Plug?Btm Yes Plug? Yes Q Pump Init (bbllm... 6 Q Pump Final (bbll... 3 Q Pump Avg (bbl/... 6 P Pump Final (psi) 347.0 P Plug Bump (psi)Recip? 853.0 No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped Lead cement until MP seen at shakers Cement Fluids & Additives Fluid Fluid Type Chem Wash Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) 40.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) 8.33 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Spacer Fluid Description 1 Estimated Top (108) 32.0 1 Est Son (ftKB) 200.0 Amount (sacks) Class Volume Pumped (bbl) 80.0 Yield (fV/sack) Mix H2O Ratio (Sallee... Free Water (%) Density (Ib/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Lead Cement Fluitl Description Estimated Top (ftKB) 200.0 Est etm (ftKB) 2,465.0 Amount (sacks) 1,545 Class G Volume Pumped (bbl) 525.7 Yield (ft'lsack) 1.91 Mix H2O Ratio (gallsa... 6.67 Free Water (%) 1 Density (lb/gal) 11.00 Plastic Viscosity (cP) 73.3 Thickening Time (hr) 19.10 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,485.0 Eat Bt-(ftKB) 2,965.0 Amount (sacks) 242 Class G Volume Pumped (bbl) 71.0 Yield (ft /sack) 1.65 Mix H2O Ratio (gallsa... 5.61 Free Water (%) Density (Ib/gal) 12.00 Plastic Viscosity (0) 97.5 Thickening Time (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 9119/2019 Cement Detail Report 2M-40 String: First Intermediate Casing Job: DRILLING ORIGINAL, 7/17/201912:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name First Intermediate Casing 8/10/2019 14:35 8/10/2019 1859 29-40 Comment 5 bbis water. Pressure test lines to 3500 psi. Pump 55.0 bbis of 13.25 ppg - 13.5 ppg Mud Push II @ 3-5 bpm, 320-178 psi). Drop Bottom Plug (confirmed by CoMan). Pump 140.2 bbis 15.8 ppg Class G Cement @ -5 bpm, 350-56 psi. Drop 2 Top plugs (locking plug first in hole, HES -HWE plug 2nd in hole, Confirmed by CoMan ). Pump 10 bbis water clean up and switch to Rig Pumps for remaining displacement. Pump 975.7 bbis of 10.5 ppg LSND drilling mud. FCP 713 psi. Pressure up to 1200 psi for 5 minutes. CHeck floats. Float held. Cement in place 18:59. Cement Stages Stage 91 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? First Intermediate Casing 11,124.6 13,486.0 Yes Yes Yes 0 Pump Init (bbl/m.. 0 Pump Final (bbd... O Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 656.0 712.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump Cement Job. 5 bbis water. Pressure test lines to 3500 psi. Pump 55.0 bbis of 13.25 ppg - 13.5 ppg Mud Push II @ 3-5 bpm, 320-178 psi). Drop Bottom Plug (confirmed by CoMan). Pump 140.2 bbls 15.8 ppg Class G Cement @ -5 bpm, 350-56 psi. Drop 2 Top plugs (locking plug first in hole, HES -HWE plug 2nd in hole, Confirmed by CoMan ). Pump 10 bbis water clean up and switch to Rig Pumps for remaining displacement. Pump 975.7 bible of 10.5 ppg LSND drilling mud. FCP 713 psi. Pressure up to 1200 psi for 5 minutes. CHeck floats. Float held. Cement in place 18:59. Cement Fluids & Additives Fluid Fluid Type Fluid DescriptionEstimatetl Top (ftKB) El11' Est Bbn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement .6 13,496.0 679 G 140.2 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.0 1 15.80 194.9 7.65 Additives Additive Type Concentration Cone Unit label I rage 1/1 ReportPrinted: 9/19120191 Cement Detail Report 2M-40 String: 2 nd Intermediate Casing Job: DRILLING ORIGINAL, 7/17/201912:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 2 nd Intermediate Casing 8/16/2019 10:45 8/16/2019 00:00 2M-40 Comment Pump 5 bbls FW, Test surface Equipment @ 4500 psi. Pump 45 bbls 14.0 ppg of Mud Push 11. @ 5BPM, Drop bottom dart, ( no indication of flag confirmation dart away), Discuss with CPAI & Baker offices, decision to continue pumping. Pump 65 bbls 15.8 ppg of cement. Drop top dart, observed confirmation of flag dart dropped, pump 10 bbs water clean up and switch to Rig Pumps for remaining displacement. Pump 331 bbls of 10.5 ppg LSND drilling mud. FCP 1020 psi. Pressure up to 3000 psi for 5 minutes. CHeck floats. Float held. Cement in place 12:58 8/16/2019. Cement Stages Stage # 1 Description Objective Top Depth (ttKB) Bottom Depth (RKB) Full Return? Vol Cement... TopPlug? Btm Plug? 2 nd Intermediate Casing 7" Liner cemented in. 13,258.0 14,285.0 Yes 5.0 Yes Yes Q Pump Init (bbl/m... Q Pump Final (boll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (it) Rotated? Pipe RPM (rpm) 1,240 1,015 7 1,020.0 1,070.0 Yes I 15.00 No Tagged Depth (RKB) Tag Method Depth Plug Drilled Out To (RKB) Drill Out Diameter (in) Comment Pump 5 bbls FW, Test surface Equipment @ 4500 psi. Pump 45 bbls 14.0 ppg of Mud Push 11. @ 5BPM, Drop bottom dart, ( no indication of flag confirmation dart away), Discuss with CPAI & Baker offices, decision to continue pumping. Pump 65 bbls 15.8 ppg of cement. Drop top dart, observed confirmation of flag dart dropped, pump 10 bbs water clean up and switch to Rig Pumps for remaining displacement. Pump 331 bbls of 10.5 ppg LSND drilling mud. FCP 1020 psi. Pressure up to 3000 psi for 5 minutes. CHeck floats. Float held. Cement in place 12.58 8/16/2019. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (RKB) I Est Btm (RKB) I Amount (sacks) Class Volume Pumped (bbl) Mud Push 45.0 Yield (Wlsack) I Mix H2O Ratio (gal/sa... Free Water (°/,) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 4.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (nKB) Est Btm (RKB) Amount (sacks) Class Volume Pumped (bbl) Cement 13,258.0 14,285.0 200 G Yield (R'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.10 15.80 156.5 Additives Additive Type Concentration Conc Unit label I rage in ReportPrinted: 9/19/20191 I rage 1/1 Report Printed: 9/19/20191 Cement Detail Report 2M-40 String: Surface Top Job Job: DRILLING ORIGINAL, 7/17/2019 12:00 Cement Details Description Surface Top Job Cementing Start Date 7/25/2019 16:00 Cementing End DateWe 7125/2019 20:00 e' bore Name 2M-40 Comment Pumped 38.1 bbls of 11.0 cement cement returns verified by weighing cmt. Witnessed by AOGCC rep. Bob Noble Cement Stages Stage # 1 DescriptionObjective Surface Top Job Top Depth (RKB) Bottom Depth (ftKB) Fill voitl from 176' 37.1 176.0 Full Return? Yes Vol Cement... 16.0 Top Plug? No Bin Plug? No O Pump Ind (bbl/m... 0 0 O Pump Final (bbl/... Q Pump Avg (bbl/... 300 P Pump Final (psi) P Plug Bump (psi) 300.0 Recip? No Stroke (R) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Flushed with 25.7bbls of H2O and then pumped 38.1 bbls of 11 ppg cmnt until good 11 ppg back. Filled void with full returns from 176' to surface. Calculated volume 22.1 bbls ditives nTypeZF1!urd Fluid Description Estimated Top (ftKB) 36.0 Est Btm(ftKB) 36.0 Amount (sacks) Class Volume Pumped(bbl) 25,7Mix 1120 Ratio (gausa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) tves Additive Type Concentration Cone Unit label Fluid Fluid Type Fill Cement Fluid Description I Estimated Top (ftKB) 36.0 Est Btm (RKB) 176.0 Amount (sacks)Class 112 Volume Deep Crete 38.1 Pumped (bbl) Yield (ft'/sack) 1.91 Mix 1120 Ratio (gal/sa... 6.67 Free Water (%) Density, (Ib/gal) 11.00 Plastic Viscosity (CP) 88.2 Thickening Time (hr) CmprStr 8.90 1 (psi) Additives Additive Type Concentration Cone Unit label I rage 1/1 Report Printed: 9/19/20191 2M-40 REMEDIAL CEMENT - TOB JOB DTTM JOBTYP SUMMARYOPS START 7/22/19 DRILLING Drill ahead f/2,612' to TD of 2,975'. Circ hole clean to 2,800'. ORIGINAL BROOH f/2,800' to 1482'. POOH & L/D BHA. R/U to run casing 7/23/19 DRILLING M/U shoe track, Run 13 3/6, 68# HYD 563 casing Attempt to ORIGINAL circulate @ 1499', Staging pump up F/.5 bpm T/ 2.5 bpm, ICP80 FCP 110 psi. unsuccessful no returns, 35 bbl loss Continue running casing F/ 1499'T/1989' p/u 207K, S/O 110K, no returns. Attempt to regain cicrulation @ 1998', pump @ .5 bbl/ min 90 psi T/ 2.5 bbl/min @ 180 psi, slow returns on up stroke, no returns . M/U 13 3/8 Hanger, Install landing, RIH F/ 2922'T/ 2965' Very landing on seat, .Attempt to regain circulation, w/ recipulating casing, W/ 1-2 bbl/min, no returns. 7/24/19 DRILLING Regain circulation, recip pipe and circulate @ 3 BPM 120 psi, ORIGINAL increase pumps T/ 6 BPM, 150 psi, Hook up cementing equipmenbt, re- establish circulation, Line uip SLB cementers, start cement Job 7/25/19 DRILLING Continue pumping cement, Pump 71 bbls 12 ppg Tail cmt, ORIGINAL Drop top plug, Displace w/ 419 bbls 9.5 spud mud,.Rig DWN CMT equip, N/D diverter system, Rig up T/ perform TOP job, pump 38.1 bbls 11.0 ppg cmt, rig dwn cmt equip, M/U well head R tP.Rt n/u hons 7/26/19 DRILLING Nipple up bop's, rig up MPD equipment, Test BOP'S, ORIGINAL 7/27/19 DRILLING Finish installing IBOP, L/D HWDP, Run W/R, Pick up 12-1/4" ORIGINAL BHA,RIH T/ 1774', test mwd, RIH T/2882 tag plug, DRLG out shoe track & 20' new, perform FIT, @ 16.0 EMW(test Good) Displace mud T/ LSND mud, Drill 12 1/4 INTRM 1 hole. 7/28/19 DRILLING Continue DRLG 12.25 INTRM 1 section F/ 3565'T/ 6012' MD, ORIGINAL 3535' TVD, 7/29/19 DRILLING Cont. Drilling 12.25 INTERM 1 section F/ 6012'T/ 8555' ,MD, ORIGINAL 4243' TVD, 7/30/19 DRILLING Cont. Drilling 12.25 INTERM 1 section F/ 8,555'T/ 9,591' ,MD, ORIGINAL 4512' TVD, Wiper trip to 5635' MD. ConocoPPhilll s p Transmittal #1254 Detail Date: 9/10/2019 Sent Via: Hand delivery 2 190 63 311186 From (CPAI Contact): Email*: richard.e.elgarico@conocophillips.com First Name*: Ricky Last Name*: Elgarico Phone Number: (907) 265-6580 Company: To (External Party): Email*: steve.davies@alaska.gov First Steve Name*: AK Last Name*: Davies Phone (907) 793-1224 Number: Company: AOGCC Address: 333 W. 7th Ave., Ste. 100 City: Anchorage State: AK Zip Code: 99501 Sent Via: Hand delivery 2 190 63 311186 From (CPAI Contact): Email*: richard.e.elgarico@conocophillips.com First Name*: Ricky Last Name*: Elgarico Phone Number: (907) 265-6580 Company: ConocoPhillips Address: 700 G Street City: Anchorage State: AK Zip Code: 99501 Transmittal Info Tracking M RECE IVED SEP112019 AOG r Justification: LWD and Directional Survey data to supplement CPAI's sundry application to fracture s timulate KRU 2M40 Data Detail Quantity*: Description*: 1 LWD and survey data Attachments: Rec ived By: Signat _- Type*: LAS, excel Date: Approver: Signature: Date: PT -0 21 9-063 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Saturday, August 31, 2019 9:49 AM To: Herring, Keith E Subject: Re: KRU 2M-40 (PTD 219-063) Intermediate II cement evaluation Keith, Thank you for the log. The cement looks good Victoria Sent from my iPhone On Aug 31, 2019, at 9:30 AM, Herring, Keith E <Keith.E.Herring@conocophillips.com> wrote: Good morning Victoria, We just received the processed cement evaluation log from the SonicVision tool on the 2M-40 Production drilling BHA; attached above. Good cement behind 7" Intermediate II liner was observed with cement to the liner top at 13,258' MD. The 7" Intermediate II liner casing shoe is at 14,283' MD. Please let me know if you have any questions or concerns. Thanks, Keith Herring Drilling Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO —1560 Keith.EFlerrirgi_conccoUtii llh s m_ i ConocoPhillips Alaska <Co no co P h i l l i ps_2 M-40_So n icSco pe_To p_of_Ce m e nt. pdf> Schlumbegep U 1 R j U D1 C y � O • • • • • of Ni a 3 y g N , V L . 1,9 d c O S 4ai O y T WE 90 4440 '& 40 • 00 80 53 � k �n � 51 J d c� A 5-5 E 3 E - ConocoPhillips pp .r 3 6 � C F @ p � 4l Y a " API# 50-029-23637-00-00 Elevations: °' $ 8 �+ Field: KuparikRiver D. F.137.5ft E m m 'z X: E 1,627,932.72 G.L. 100.7fl 3 HI 3 s o « a a w z cC J J a 0 Y:N 5,948,735.34 g EES pP' N N N° 9 0 � W � 0 C' C � � $ c J S d GN COMPANY: ConocoPhillips Alaska LLC. a N WELL: 2M-40 a $ FIELD: Kuparuk Rivero 2 Z t d Alaska it :9STATE: w g .A a COUNTRY: USA o & o a40 O C TlO U J C SII LL Q m E O n 0 Well: 2M-40 UNIT: I Elevation: X. SP Short nacre: Elevation datum Y: Co Lang name: Total depth: -999.29 Longitude: -150.10097 degrees Sta Coordinate system: Latitude: ]0.2]1519 degrees O Casing mmmm mmm— ��wesa mrmo .r3o csio vn�m 5 in 8 SPR.MH-F/LR i 5 in 8 40 usM 240 VEMEN9 DTSH MH FAP 1 31MM9 .84.40 40 USM 240 In) WFA_MHT R FILT-1 -R 1 DTCO MH FA R 1 c srnq amplitude WFA MHT -R-FILT 1 - R t 1:480 0 3000 40 usIft 240 -20 unMess 100 0 3000 � 1 I � - 4000 !1) 41 sh� — 4100 `I - 1#,FI ri I .d r7 - 4200- 7 -4300 )111- idb t 'M1�IJ�I f: Ir I!! c -4400- I ■ If fi i.� Ago. {i! Mj 4 s h*1 3 1 Company: Conocoips Alaska, Inc. u m e r e r Well: 2M-40 Field: Kuparuk RRivver Unit State: Alaska Country: USA SonicScope Top of Cement THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Keith Herring Senior Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 2M-40 Permit to Drill Number: 219-063 Sundry Number: 319-352 Dear Mr. Herring: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.cogcc.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, Daniel T. Seamount, Jr. Commissioner DATED this Z day of August, 2019. RBWAs4' AUG 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUL 2 b 20,19 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Remedial Cement 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: �.1 ConocoPhillips Alaska, Inc. Exploratory E]Development ❑i Stratigraphic Service El 219-063 Y 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-103-20804-00-00 T If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Ir Will planned perforations require a spacing exception? Yes ❑ No ❑Q KRU 2M-40 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025586 ,'ADLO25585-ADL( I Kuparuk River Field / Kuparuk Oil Pool ' it. 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 139' 20" 176' 176' Surface 2928' 13-3/8" 2965' 2652' 5,020 psi 2,260 psi Intermediate Production Liner Perforation Depth MID(ft) : Perforation Depth TVD (ft): Tubing Size: Tubing Grad e: 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: 7/25/2019 OIL ❑' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 7/25/2019 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: Keith Herring Contact Name: Keith Herring Authorized Title: Senior Drilling Engirppr Contact Email: keith.e.herrin COnOCO hilli S.COrn Contact Phone: 907-263-4321 7 Authorized Signature: Dale: / ?4p �4% COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q-35 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,1-0 ET <L° Y/lrr fyi(SS JLsu Cr a, O/ L°<tvt frit f fo lj cam/ Post Initial Injection MIT Req'd? Yes ❑ No LJ PTD) Spacing Exception Required? Yes ❑ No Subsequent Farm Required: L{-Q.� �� < PAS AUG 0 5 Z RBD APPROVED BY / T 2, Approved by: COMMISSIONER THE COMMISSION Date: �D[ 4/ Fo 03 Rev 4/ 7 Approved applicaflonQ I f r h f tlate of a rovel. Submit Form and Attachments in Duplicate -PA9 *s�t't 2M-40 (PTD 219-063) Surface Cement and Top Job Summary On July 25, 2019 the 13-3/8" surface casing primary cement operation was performed on 2M-40. During the cement job, lost returns were observed. Approximately 40 bbls of MudPush II was circulated/observed at surface however, no cement was observed at surface. On July 25, 2019 a top job was performed (witnessed by AOGCC Inspector Bob Noble). Wellbore specifics: • Drilled surface hole depth: 2975' MD / 2657' TVD, 62' inclination • Surface Casing: 13-3/8", 68.0#, L-80, Hydril 563 • Surface Casing shoe: 2965' MD / 2652' TVD • While running casing lost returns at 1500' MD and once casing was on depth full returns were established after 18 hours of reciprocating casing and pumping LCM pills. o 1 centralizer/joint was run and 2 centralizers/joint on each joint on shoe track. • Staged pumps (to 7 bpm) and circulated and conditioned mud for 5.5 hours prior to cement job. Primary Cement Job Summary: • Pumped 40 bbls ChemWash and 80 bbls 10.5 ppg MudPush II • Dropped bottom plug • Lead Cement: 525 bbls 11.0 ppg LiteCRETE lead cement o First 300 bbls contained 1 ppb Cemnet • Tail Cement: 71 bbls 12.0 ppg DeepCRETE tail cement • Dropped top plug • Displacement 431 bbls • Plugs bumped and floats held • Cement Job Summary: o While running casing lost returns at 1500' MD and once casing was on depth full returns were established after 18 hours of reciprocating casing and pumping LCM pills. o Circulated and conditioned mud with full returns for an additional 5.5 hours. o Pumped spacer program and lead slurry without any issues. o While pumping tail slurry observed a decrease in returns to 39% o Lost returns were observed with 366 bbls of displacement away. o The cement program was continued as per plan. o Lift pressure was observed while pumping displacement. o No issues maintaining cement density throughout job. o -40 bbls of Mud Push was seen at surface. Top Job: • Based on gauge hole, the volume of Mud Push seen at surface (leaving -40 bbls in hole), and the reduced rate of returns to surface we anticipate finding top of cement 80' to 411' below surface. • The diverter was rippled 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 jab. • A top job string of pipe was run down the annulus of the conductor and surface casing. • Tagged top of cement at 176' MD. Tag witnessed by AOGCC State Inspector. • Pumped 25.7 bbls of fresh H2O followed by 31.8 bbls of 11.0 ppg LiteCRETE cement with cement returns to surface. Cement job witnessed by AOGCC State Inspector. AL Cement Detail Report 2M-40 String: Surface Cement Job: DRILLING ORIGINAL, 7/17/2019 12:00 Cement Details Description Surface Cement Cementing Start Date 7/24/2019 21:15 Cementing End Date 7/25/2019 01:45 Wellbore Name 2M-40 Comment Line up T/ SLB cementers, pump 5 bbls CW 100, shut in T/ psi test surface equip, test surface equip. @ 2500 psi, pump 35 bbls CW 100 @ 4 BPM, 114 psi, pump 80 bbls 10.5 Mud Push II @ 4 BPM, 118 psi, Drop bottom plug, pump 525 bbis, 11 ppg Lead cement @ 6 BPM, 123 1216 psi. Continue pumping cement. Pump 71 bbls 12 ppg Tail cmL Drop top plug, K/O W/ 10.5 bbls 1-12), Displace w/ 419 bbls 9.5 spud mud,. Lost return @ 366 bbls into displacement. 165 bbls mud loss w/ displacing, bumped plug @ 3552 silks, icp = 330 psi FIC= 580 psi, Plug bumped @ 01'.40 hrs 7-5-19 - no cement returs to surface. Mud Push was returned to surface but cement was not. Cement Stages Stage # 0 Description Surface Cement Objective Top Depth (ftKB) Bottom Depth (ftKB) 2,965.0 Full Return? No Vol Cement... Top Plug? Yes etm Plug? Yes Q Pump Init (bbl/m... 6 3 Q Pump Final (bblTT—.gmeptl Avg (bbl/... P Pump Final (psi) 347.0 P Plug Bump (psi) 853.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) od Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped Lead cement until MP seen at shakers Cement Fluids & Additives Fluid Fluid Type Chem Wash Fluid Description Estimated Top (ftKB) Est Btm (ftKB) I 1 Amount (sacks) Class 1 Volume Pumped (bbl) 40.0 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ihigal) 8.33 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) 32.0 Est Btm (ftKB) 200.0 Amount (sacks) Class Volume Pumpetl (bbl) 80.0 Yield (Wisack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 10.50 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 200.0 Est Btm (ftKB) 2,465.0 Amount (sacks) 1.545 Class G Volue Pumped (bbl) 525.m7 Yield (ft' /sack) 1.91 Mix H2O Ratio (gal/sa... 6.67 Free Water (%) DensiTy (Ib/gal) 11.00 Plastic Viscosity (cP) 73.3 Thickening Time (hr) 9.10 CmprStr i (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,465.0 Est atm (ftKB) 2,965.0 Amount (sacks) 242 Class G Volume Pumped (bbl) 71.0 Yield (ft /sack) 1.65 Mix H2O Ratio (gal/sa... 5.61 Free Water (%) Density (Ibigal) 12.00 1975. Plastic Viscosity (cP) Thickening Time (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 7/26/2019 r Cement Detail Report 2M-40 String: Surface Top Job Job: DRILLING ORIGINAL, 7/17/2019 12:00 Cement Details Description Surface Top Job Cementing Start Date 7/25/2019 16:00 Cementing End Date 7/25/2019 2000 Wellbore Name 2M-40 Comment Pumped 38.1 bbls of 11.0 cement cement returns verified by weighing cmt. Witnessed by AOGCC rep. Bob Noble Cement Stages Stage # 1 Description Surface Top Job Objective I Fill void from 176' Top Depth (ftKB) 36.0 Bottom Depth (ftKB) 176.0 Full Return? Yes I Vol Cement... 16.0 Top Plug? No I Son Plug? INO Q Pump Init (bbl/m.. 0 Q Pump Final (bbll... 0 IQ Pump Avg (bbil... 1300 P Pump Final (psi) 300.0 P Plug Bump (psi) Recip? No IStroke (ft) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Flushed with 25.7bbis of H2O and then pumped 38.1bbis of 11ppg cmnt until good 11ppg back. Filled void with full returns from 176'to surface. Calculated volume 22.1bbls Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) 36.0 Est Bi (ft(B) 36.0 Amount (sacks) Class Volume Pumped (bbl) 25.7 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water I%) Density (lb/gal) 28.33 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fill Cement Fluid Description Estimated Top (ftKB) 36.0 Est eon (ftKB) 176.0 Amount (sacks) 112 Class Deep Crele Volume Pumped (bbl) 38.1 Yield (Wisack) 1.91 Mix H2O Ratio (gallsa... 6.6 Free Water (%) 1 Density (Ib/gal) 1 11.00 Plastic Viscosity (CP) 88.2 Thickening Time (hr) 8.90 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 7126120191 Loepp, Victoria T (CED) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Sunday, July 28, 2019 5:06 PM To: Loepp, Victoria T (CED) Cc: Pessetto, Scott T Subject: KRU 2M-40 (PTD #219-063) Surface Casing FIT Attachments: 21V-40 Surface Casing - Test-FIT.xlsx Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Please see the attached 2M-40 Surface Casing FIT. Thanks, Keith Herring Drilling Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO —1560 Keith. E.Herrin20conoconhillios.com ConocoPhillips 1 Pro Ql?-063 Loepp, Victoria T (CED) From: Herring, Keith E <Keith.E.Herring @conocophill ips.com> Sent: Thursday, July 25, 2019 2:18 PM To: Loepp, Victoria T (CED) Cc: Tolman, Ben V; Rohifing, Jenaya J; Herbert, Frederick O Subject: RE: [EXTERNAL]Re: KRU 2M-40 (PTD #219-063) Surface Casing Cement Top Job Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Victoria, As per our phone conversation, a top job string of W pipe was run down the annulus of the conductor and surface casing on 2M-40. Top of cement was tagged at 176' MD and the tag was witnessed by Mr. Bob Noble of the AOGCC. ConocoPhillips is planning to move forward with pumping a top job on the 21V-40 surface casing as per approved plan by the AOGCC. The 10-403 Sundry for approval will be submitted tomorrow as morning as per our discussion. If you have any questions or comments please let me know. Thank you for your time. Keith Herring Drilling Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO —1560 Keith. E.HerrinvPconoco0iIli ps.com ConocoPhillips AlaSka From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, July 25, 2019 7:18 AM To: Herring, Keith E <Keith.E.Herring@conocophiIIips.com>; Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]Re: KRU 21V-40 (PTD #219-063) Surface Casing Cement Top Job Keith, If cement is not tagged, notify the AOGCC before pumping cement. Please refer to the AOGCC Guidance Bulletin on Top Jobs(13-001). Notify the AOGCC inspectors to witness the procedure. Approval is granted to proceed as outlined with attempting to tag the TOC. Prepare and submit a 10-403 Sundry for approval. Thanx, Victoria Sent from my iPhone On Jul 25, 2019, at 4:41 AM, Herring, Keith E <Keith E Herring@conocophillips.com> wrote: Victoria, As discussed on the phone, we finished pumping our surface casing cement job early this morning. During the job, returns were lost and cement was not circulated to surface. Below is outline of the cement job and our plan forward for the remedial cement job. Based on current operations, we should anticipate to have the diverter nippled down and ready to start lowering our small diameter pipe down the annulus sometime this morning between 08:00 and 09:00 hrs. Wellbore Specifics • Drilled surface depth: 2,975' MD / 2,657' TVD @ 62.25" inclination • Surface Casing: 13-3/8", 68#, L-80, HYD563 • Surface Casing set depth: 2,965' MD / 2,652' TVD • While running casing lost returns at 1500' MD and once casing was on depth full returns were established after 18 hours of reciprocating casing and pumping LCM pills. o 1 centralizer/joint was ran and 2 centralizers/joint on each joint of shoe track. • Circulated and conditioned mud with full returns for 5.5 hrs prior to cement job. Cement Program: • Spacer: 40 bbls Chem Wash & 80 bbls MudPush II • Dropped bottom plug • Lead Cement: 525 bbls 11.0 ppg DeepCrete Lead cement o First 200 bbls contained 1 ppb Cemnet • Tail Cement: 71 bbls 12.0 ppg DeepCrete Tail cement • Dropped top plug • Displacement: 431 bbls • Plugs pumped. Floats held. • Cement job summary: o While running casing lost returns at 1500' MD and once casing was on depth full returns were established after 18 hours of reciprocating casing and pumping LCM pills. o Circulated and conditioned mud with full returns for an additional 5.5 hours. o Pumped spacer program and lead slurry without any issues. o While pumping tail slurry observed a decrease in returns to 39% o Lost returns were observed with 366 bbls of displacement away. o The cement program was continued as per plan. o Lift pressure was observed while pumping displacement. o No issues maintaining cement density throughout job. o -40 bbls of Mud Push was seen at surface. Plan Forward • Based on gauge hole, the volume of Mud Push seen at surface (leaving -40 bbls in hole), and the reduced rate of returns to surface we anticipate finding top of cement 80' to 411' below surface. • Nipple down diverter and adapter to gain access to top of casing hanger. • Run in with 3/4" pipe ("spaghetti" string) down the annulus until tag up/take weight on cement. • Displace/flush annulus with fresh water. • Pump 11.0 DeepCrete cement as required to circulate cement to surface. If you have any questions or concerns please contact me. Thanks, Keith Herring Drilling Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO —1560 Keith.E.Herring@conocophillips.com <image001.png> PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 2M40 I Rig: Date: 1 8/19/2019 1 Vglum,,ln w Volume/Stroke Pump Rate: Drilling Supervisor: IJimmy u, -ed: •2 Mud Pump Type of Test: Gazing Shore Test LOT/TIT Pumping down annulus and DP. Strokes 1w 0.1010 Bbls/St1w -.:Sbl/min l Casing Test r988Ura I es[ Hole Size: 6-1/8, Cast Store De W Hole De Pum i Shut-in Pumping Shut-in RKB-CH Ft 14283.0 t 6075.0 Fl- 1431: Ft 6077.0 F[ -TVD irks Min s1 Min Psi Casing Size and Description: T 2(W/Ft L-80 BTC -Moo 0 01 01 3650 2 0.00 1160 Calling Test Pressure Int iarltvTest6 1501 1 3625 4 0.25 1160 Mud Weight: -:.a Mud 10 min Gel: 12.0 Test Pressure: 3500.0 Rotating Weigh: 140.0 BiocksrTop Drive Weight 60000.0 Estimates for Test: 7. ppg Lb1100 Ft2 psi Lbs Lbs bbls Mud 10 min Gel:Lb/100 Rotating Weight:Lbs Mud Weight:A1460 BbckslTop Drive Weight:Lbs Desired PIT EMW:ppg Estimates for Test: ppg Ft2 I 2.5 bbls 10 247 2 3625 6 0 1155 14 406 3 3625 -8-222 1. 0 1150 18 530 4 3625 10 275 1.50 1150 22 676 5 3620 12 36 2.00 1145 26 805 6 3620 14 408 2.50 1140 30 930 -7-362-0 1600 3.00 1140 34 1075 8 3620 18 540 3.50 1140 W =Lea 4 ressure • e g = 1110 f 20 8 0.052 x TVD 0.052 x 6075 EMW at 14283 Ft -MD 6075 Ft -TVD = 14.3 ppS 15 Second Shut4n Pressure i 38 1190 9 3620 20 615 4.00 1135 42 1290 10 3620 22 688 4.5 1130 1 1160 46 1396 15 3620 241 7301 5.00 1130 Lost 40 psi during test, 501 15341 20 3610 26 8151 5.50 1130 4000- 1660 25 3610 28 890 6.00 1125 sse0 8 1760 30-761-0 30 915 6.50 1125 62 1910 32 1020 7.00 1120 66 2023 34 1074 7.50 1120 3000 70 2120 36 1111 8.00 1120 74 2280 38 1178 8.50 1115 - - - w 2$00 - 78 2417 9.00 7116 zw0 - r. _ _ 1 -- - 82 2542 9.50 1110 H 86 2688 10.00 711 w Cc two _ .- 90 2835 94 970 _ 1 98 3085 102 3242 - - 106 3370 500 ---------_-� 110 3500 112 3590 114 3650 a 0 3 4 B 5 10 13 140 Barrels .G IW TEST �L K-0FTEST 5 0 IS 30 35 30 Shut -In time, Minutes 0 PITPoinl umeVo Pum ume Bled Beck Volume Pum d s Vo ume Bled Back S omments Summery Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 2M-40 Rig: Doyon 19 Date: 8/19/201" _ Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Jimmy Greco / Scoff Heim Pump used: a2 Mud Pump v Type of Test: Casing Shoe Test LOT/FIT a Pumping down annulus and DP. Hole Size: 6-1/8" CasinggShoe De h HOIe De h Strokes Pumping 9w 0251 0. 1, Bbls/Strk 'W 0.50 Bbl/min 1w Test PreS3Uf@ Int ri @St Shut-in Pum in Shut-in RKB-CHF: Ft 14283.0 Ft -MD 6075.0 Ft -TVD 0 Ft -MD 6077 ^ Ft -TVD Casing Size and Description: 7.26#/Ft L-80 BTC -Moo Strks psi Min psi Strks psi Min psi 0 0 0 2 381 0.00 1160 CasingTest Pressure Int egrityTest 6 150 1 4 1001 0.25 1160 Mud Weight:0.8 Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weightj Estimates for Test: ppg Lb/100 Ft2 psi Lbs Lbs bbis Mud Weight: Mud 10 min Gel: Rotating Weight: Blocks/Top Drive Weight: Desired PIT EMW: Estimates for Test: ppg Z' Lb/100 Ft2 140.0 Lbs 60000.0 Lbs 14.5 ppg 1169 psi 2.5 bbis 10 247 2 6 168 0.50 1155 12.0 14 406 3 i 8 222 1.00 1150 3500.0 18 530 4 5 10 275 1.50 2.00 2.50 1--9 1140 140.0 22 676 5 3620 12 360 60000.0 26 8051 6 3620 14 408 7.3 30 930 71 36201 16 500 3.00 1140 34 1075 8 36201 18 540 3.50 1140 EMW = Leak -off Pressure + Mud Weigh = 1110 0.052 x TVD 0.052 x 6075 + 10'8 EMW at 14283 Ft -MD 6075 Ft -TVD = 14.3 ppg PIT 15 Second Shut-in Pressure, psi 38 1190 9 3620 20 615 4.00 1135 42 1290 10 3620 22 688 4.50 1130 1160 46 1396 15 3620 24 730 5.00 1130 4000 3500 3000 w 2500 0) 2000 w Ir 1500 1000 500 0 Lost 40 psi during test, o, 50 1534 20 3610 26 815 5.50 1130 54 1660 25 3610 28 890 6.00 1125 58 17601 30 3610 30 915 6.50 1125 62 1910 32 1020 7.00 1120 66 2023 1 1 34 1074 7.50 1120 70 2120 36 1111 8.00 1120 74 2280 1 1 38 1178 8.50 1115 78 2417 1 1 9.00 1115 82 2542 9.50 11 10.00 1 86 2688 90 2835 94 2970 98 3085 101111111111 102 3242 106 3370 110 3500 112 '590 0 5 10 15 20 25 30 Shut4n time, Minutes 0 PIT Point 114 . �)O 0 2 4 6 8 10 12 14 Barrels � CASING TEST BLEAK -OFF TEST Volume Pumped o ume Bled Back Volume Pumped V01ume Bled Back 1 .5 Bbls 10 s bls 4.0 bls Comments: ?M -An Prnritintion FIT 6-26 Vpr 1-3 Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 2M-40 Rig: Doyon Date: 7/27/201 S Drilling Supervisor: R, BJOrhus / J. Greco __[Pun. #2 Mud Pump 1 , Strokes Type Of Test: Casing Shoe -Test LOT/FIT Pumping down annulus and DP. 'w Volume Input 'W Volume/Stroke Pump Rate: 0.1180 Bbls/Strk qW 0.50�i Bbl/min Casing Test Pressure In tegri'y es Hole Size: va" Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in R - F: 3 t 965.0 t- 2 4 . 288_.0 t- 2651.0 t- Casina Size and Description: 13-3/8• 68#/Ft L-80 BTC tr s psi In psi s psi In psi 0 0 0 3110 1 40 0.00 894 asma Test ressureintearty est 2 30 1 3110 50 0. 5 880 ud Weight: 9.5 ppg u eight: 5 ppg Mud 10 min Gel: ' - Lb/100 Ft2 Mud 10 min Gel: 11.0 Lb/100 Ft2 Test Pressure: psi Rotating Weight: �# Lbs Rotating Weight: lbs Blocks/Top Drive Weight: 60000.0 Lbs Blocks/Top Drive Weight Lbs Desired PIT EMW: 6. ppg Estimates for Test: 4. bbis Estimates for Test: 4 psi 1.4 bbis w 4 50 27170- 3-60 8 6 110 3 '"� 4 100 1. 825 8 200 4 5 140 1.50 8+ 7 _71901 10 320 5 ; , i 0 6 180 12 510 6 31 7 220 14 650 7 3110 -8---267 7501 16 820 8 3110 9 300 3.50 730 EMW = ea 4 Pressure + u e g = 894 0.062 x TVD 0.052 x 2646 + 9.5 EMW at 2965 Ft -MD (2646 Ft -TVD = 16.0 PIT 15 Second Shut-in Pressure, psi 1S 950 9 3110 16 34 4. 720 20 1100 10-770- 11 380 4.5 710 880 22 1200 15 3110 12 420 5.00 700 Lost 10 psi during test, I 7% f test 24 1330 20 3110 13 460 5.50 690 3500 26 1420 25 3110 14 500 6.00 680 28 1530 30 3100 15 535 6.50 670 3000 30 1660 16 570 7.00 660 32 1800 17 600 7.50 650 2500 34 1950 18 630 8.00 640 36 2070 19 655 8.50 S30 38 2170 20 685 9.00 0 K 2000 to 40 2320 21 725 9.50 42 2430 22 750 10.00 rn 44 2550 1 1 23 780 K 1500 a46 2690 24 800 47 2770 25 825 1000 48 2850 26 850 49 2920 27 885 so0 50 3010 28 894 51 3060 0 0 1 2 3 4 5 5 Barrels -qbr.CASING TEST BLEAK -OFF TEST 7 0 5 10 15 20 25 30 Shut -In time, Minutes o PIT Point 52 311 Volume Pum ed Volume Bled Back olume Pum ed Volume Bled Back s779brs s Comments: Tested casing with 9.5ppg Spud mud Performed FIT with 9.5ppg Spud Mud ofiuoSU. iace-easing- Tet, rFtT.Alsx Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 2M-40 Rig: Doyon 19 Date: 7/27/2019 Volume Input Volume/Stroke P mp Rate: Drilling Supervisor: R. Bjorhus / J Pump used: #2 Mud Pump Type of Test: casing shoe Test Lor/FIT ® Pumping down annulus and DP. qw Hole Size: 12-1/4" Casing Shoe De th Hole Depth Strokes Pumping 1w Casing 0.1180 Bbls/Strk W 0.50 Bbl/min Test I Pressure Integrity Test Shut-in Pumping Shut-in IV RKB-CHF: 36.8 Ft 2965.0 Ft-MD 2646.0 Ft-TVD 2888.0 m-MD 26.51 0 Ft-TVD Strks i Min psi Strks psi Min psi Casing Size and Description: 113-3/8"68#/Ft L-80 BTC w 0 0 0 ti 1 40 0.00 894 CasingTest Pressure Int ri Test 2 30 1 3110 2 50 0.25 880 Mud Weight: ppg Mud 10 :in Gel: 3 0 Lb/100 Ft2 Test Pressure: 3000.0 psi Rotating Weight: ###### Lbs Blocks/Top Drive Weight 60000.0 Lbs Estimates for Test: 4.8 bbls Mud Weight: 9.5 ppg Mud 10 min Gel: 11.0 Lb/100 Ft2 #### Lbs8 Rotating Weight:g60 Blocksrrop Drive Weight:000.0 Lbs Desired PIT EMW:16.0 ppg Estimates for Test: 894 psi 1.4 bbls w 4 50 2 3110 3 60 0.50 850 6 110 3 3110 4 100 1.00 825 200 4 3110 5 140 1.50 6 180 2.00 10 320 5 3110 12 510 6 3110 7 220 2.50 760 14 650 71 3110 8 260 3.00 750 16 820 81 31101 9 300 3.50 730 EMW = Leak-off Pressure + Mud Weight = 780 +9.5 0.052 x TVD 0.052 x 2646 EMW at 2965 Ft-MD (2646 Ft-ND) = 15.2 ppg PIT 15 Second Shut-in Pressure, psi 18 950 9 3110 10 340 4.00 720 20 1100 10 31101 11 380 4.50 710 860 22 1200 15 31101 12 420 5.00 700 350024 Lost 10 psi during test, 1330 20 31101 131 4601 5.50 690 26 1420 25 31101 14 5001 6.00 680 28 1530 30 3100 15 535 6.50 670 3000 30 1660 16 570 7.00 660 32 1800 17 600 7.50 650 34 1950 18 630 8.00 640 2500 36 2070 19 655 8.50 630 w 38 2170 20 685 9.00 620 X 2000 D 40 2320 21 725 9.50 610 U) 42 2430 22 750 10.00 f LU 1500 2550 23 780 2690 24 800 a 2770 25 825 1000 2850 149 26 850 2920 27 885 soo 3010 28 894 3060 3110 00 1 2 3 4 5 e 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes CASING TEST -0-LEAK-OFFTEST o PIT Point Volume Pumped Volume Bled Back Votume Volume Pum ed Bled Back S 8 S S Comments: Tested casing with 9.5ppg Spud mud Performed FIT with 9.5ppg Spud Mud Summary MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �1?`"��1�,z�/c� DATE: 7/26/2019 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Remedial Cement Petroleum Inspector KRU 21VI-40 CPAI PTD 2190630; Sundry 319-352 7/25/2019: AOGCC received a notification telling us that Doyon 19 on CPA, KRU 2M- 40 did not get cement to surface when doing their surface casing cement job. I got in contact with CPAI representative Rick Bjorhus on their plan and timing. I travelled to KRU 21VI-40 and witnessed them running 1 -inch tubing into the surface casing by conductor annulus. They tagged at 176 ft and was calculated to require 22.1 barrels of cement to fill. They pumped 25.7 barrels of water and then they switched to 11 ppg Deep -Crete cement. Good cement came back to surface at 21 barrels pumped. Schlumberger had another 6 barrels of cement mixed so they pumped it to for a total of 27 barrels pumped. Attachments: none 2019-0725_Surface_Csg_Topj ob_KRU_2M-40_bn.docx Page I of I THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord 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 w .aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-40 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-063 Surface Location: 113' FSL, 59' FWL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 4302' FNL, 1435' FEL, SEC. 6, TION, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced development 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, Z4�� Daniel T. Seamount, Jr. Commissioner DATED this �� f May, 2019. i6=i,oI=I V C: Li STATE OF ALASKA AL ,SKA OIL AND GAS CONSERVATION COMMISSION APR 2 2 2019 PERMIT TO DRILL 20 AAC 25.005 Ia. Type of Work: 11b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well ispropose for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development - Oil El Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket E] Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2M-40 . 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360, Anchorage, AK 99510-0360 MD: 21,241 TVD: 6,110 Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 113' FSL & 59' FWL, Sec 27, Tl IN, R8E, UM ADL025586 / ADL025585 / ADL025590 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2730' FNL & 192' FEL, Sec 31, T11 N, R8E, UM 931894000 1931893000 / 931898000 6/2/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4302' FNL & 1735' FEL, Sec 6, TION, R8E, UM 2560 / 2491 / 2501 3299' to ADL390680 ' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 137.6 15. Distance to Nearest Well Open Surface: x- 487899.20 y- 5948985.28 Zone- 4 GL / BF Elevation above MSL (ft): 100.7 to Same Pool: 917'to 2S-14 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.64 degrees Downhole: 3670 Surface: 3066 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 139 Surf Surf 176 176 Installed 16" 13-3/8" 68# L-80 Hyd 563 2956 Surf Surf 2993 2638 1627 sx 11 ppg lead, 232 sx 12ppg tail 12-1/4" 9-5/8" 47# L-80 Hyd 563 13136 Surf Surf 13173 5778 706 sx 15.8 ppg Class G 8-12" x 9-7/e' 7" 26# L-80 Hyd 563 1242 12973 5701 14215 6036 332 sx 15.8 ppg Class G 6-1/8" 4-1/2" 12.6# L-80 Hyd 563 7226 14015 6022 21241 6110 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): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes❑D No ❑ 20. Attachments: Property Plat ❑ BOP Sketch Drilling ProgramTime e v. Depth Plot a e Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirementsB 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring - Authorized Name: Chip Alvord Contact Email: keith.e.herrin COP.COm Authorized Title: Alaska Drilling Manager Contact Phone: 907-263-4321 Authorized Signature: _ 4--{ ( Date: 4(2-2 jLU (Cl Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: Q 50- 10,:3 - C)C)!304- - 0 - Q Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Samples mq'd: Yes ❑ NoRr Mud to re d: Yes No ,BOP tr�5fi -to 35l>n�s/ g q' ,❑�/ Ca' VNo,❑,/ �- fc) z 5rZjCe: S mqeasures: Yes Directional svy req'd: Yes L`7 No El �1./,'1 .jvb?vij-" to 4a6rCr' x75 c4c)-7 Spacing excepanreq'd: Yes❑ No LV Inclination-onlysvyreq'd: Yes[] Noor 17,,e-oY✓7fS a Va / /,? b le : Post initial injection MIT req'd: Yes ElNo L7 /T� 5v/fatrC'a37�'7q F/Lb7 'CCrt�nntJob �>nf2� rfSv/f.S l-��t/d✓/d L07-rrt/,n /5 ��- • GCI'i-r Cnl- CVQ/ 1Dqq �l't 'r2 �M Vlr S C pt/ach<c/ Co11,9y1'-iov�S Of �`Rp zvv�1 APPROVED BY / -7 / / / Approved by: COMMISSIONER THE COMMISSION Date:S/7 �q y I , Z- P1311-2Submit Form and , rrq to A q4sJ2oi7 This permit is valid to r�oi)ttGJtf tk approval per 20 AAC 25.005(8) AOa melts in Duplicate KRU 2M-40(PTD 219-063) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well KRU 2M-40 (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. Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4321 Email: keith.e.herrinq(cDconocophillips.com April 10, 2019 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 2M-40 Dear Commissioner: Application for Permit to Drill, Well 2M-40 Saved: 22 -Apr -19 ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grassroots onshore producer, a single lateral horizontal well in the Kuparuk C sand. The expected spud date for this well is June 2, 2019. It is planned to use rig Doyon 19. A 16" surface hole will be drilled on diverter & 13-3/8" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 19'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 first intermediate hole section will be a 12-1/4" hole with 9-5/8" casing run to total depth & cemented in place. The second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner run to total depth and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and lined with 4-1/2" liner with swell packers and frac sleeves. The upper completion will be run with 3-1/2" tubing. Please rind 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 layout 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 Keith Herring at 907-263-4321 (keith.e.herring(&conocophillips.com) or Chip Alvord at 907-265-6120. Sincerely, Chip A vor Drilling Manager Application for Well Name Requirements of 20 AAC 25.005 (fl The well for which this application is submitted will be designated as KRU 2M-40 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the follotring items, except for an item already on file it the commission and identified in the application: (2) a plat identifying the property and the property's owners and shotring (4)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 113' FSL 59' FWL, Sec 27, TI IN, R008E, UM NGS Coordinates Northings: 5948985.28' Eastings: 487899.20' RKBElevation 137.6'AMSL Pad Elevation 100.7' AMSL Location at Top of Production Interval Ku aruk C -sand 2730.23' FNL, 191.93' FEL, Sec 31, TI IN, R008E, UM NGS Coordinates Northings: 5946167.16' Eastings: 477090.88' Total Vertical De th, Z. 6110' Measured Depth, RKB: 14215' Total Vertical Depth, RKB: 1 6036' Total Vertical Depth, SS: 1 5898' Location at Total Depth 4301.59' FNL, 1734.59' FEL, Sec 06, TION, ROME, UM NGS Coordinates Northings: 5939321.30' Eastings: 475551.71' Measured De th,RKB: 21241' Total Vertical De th, Z. 6110' Total Vertical Depth, SS: 5973' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a teell is to be intentionally deviated, the application fora Pennil to Drill (Form 10-401) must (I) include a plat, drmvn to a suitable scale. showing the path of the proposed trellbore, including all adjacent it ellbores trdhin 200 feet ofany portion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed it ellbore (A) list the names of the operators of those wells. to the extent that those names are known or discoverable in public records. and shote 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 far a Permit to Drill must be accompanied by each of rhe follmring items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blavout 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 19 & within this PTD application. Due to lower formation pressure in the overburden, a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations of the Intermediate 1 section, graphic attached. Drilling Hazards Information Renuirements 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 alreadv on file with the commission and identified in the application: (4) information on drilling ha=ards. including (A) the maximum dou nhole pressure that ,toy be encountered, criteria used to determine a, and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 2M-40 is 3066 psi (estimate from reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,087' TVD: C Sand Estimated. BHP = 3,670 psi C Sand estimated depth = 6,036' TVD ' Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of fill gas column = 604 psi (6,036' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,066 psi • (3,670 psi — 604 psi) (B) data on potential gas cones; Z fVl w The wellbore is not expected to penetrate any shallow gas zones. G 3 And (C) data concerning potential causes of hole problems such as abnormally geo-press:red strala. lost circulation =ones, mtd cones that have a propensity for d ferenhal sucking; See attached 2M-40 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill umst be accompanied by each of the following items, except for an item already on file it A the commission and ideni fed in the application: (5) a description of the procedure for conductingformation integrity tests, as required under 20 AAC 25.03069: A procedure is on file with the commission for performing FIT/LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill nmsi he accompanied hy, each of the following items. except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program Hole Casing Weight Grade Coupling Length Top MD Top TVD Bottom MD Bottom TVD Cement Details 42" 20" 944 H-40 Welded 139 Surface Surface 176' 176' Installed 16" 13-3/8" 68# L-80 Hyd 563 2,956' Surface Surface 2,993' 2,638' 1627 sx 11.0 ppg Lead, 232 sx 12.0 ppg Tail 12.25" 9-5/8" 474 L-80 Hyd 563 13,136' Surface Surface 13,173' 5,778' 706 sx 15.8 ppg Class G 8-1/T'x 9-7/8" 7" 264 L-80 Hyd 563 1,242' 12,973' 5,701' 14,215' 6,036' 332 sx 15.8 ppg Class G 6-1/8" 4-1/2" 12.64 L-80 I Hyd 563 7226' 14,015' 6,022' 21,241' 6,110' N/A: Un -cemented liner 13-3/8" Surface casing run to 2,993' MD / 2,638' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a lead slurry with 11.0 ppg LiteCRETE. Assume 200% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 9-5/8" Intermediate I casing run to 13,173' MD / 5,778' TVD Single stage slurry is designed to be placed from TD to 11,381' MD/5,186' TVD; 40% excess annular volume. 9-5/8" Intrm 1 Cement Calculations 13-3/8" Surface Cement Calculations Cement yield = 1.16 Design: 500' of Tail Cmt @ 50% excess in OH & Lead Cmt to surface @ 200% excess in OH Tail Cement yield = 1.65 1 ft-3/sk I Lead Cement yield= 1 1.91 ft-3/sk 5.9 11.0 ppg LiteCRETE Lead Slurry Shoe to Top of Cement = (13173'- 11381') x 0.0558 bbl/ft x 1.4 (40% excess) CONDUCTOR = 176'x 0.1862 bbl/ft x 1.0 (0% excess) 32.8 bbis Btm of Lead to COND = (2493'- 176') x 0.0749 bbl/ft x 3 (200% excess) 520.7 bbls Total Lead Cement = 553.5 bbis or 3107.4 ftA3 or 1 1627 sks 12.0 ppg DeepCRETE Tail Slurry Shoetrack = 80'x 0.1497 bbl/ft x 1.0 (0% excess) 12.0 bbls Shoe to Top of Tail = (2993'- 2493') x 0.0749 bbl/ft x 1.5 (50% excess) 56.2 bbis Total Tail Cement = 68.2 bbis or 382.7 ftA3 I or 1 232 sks Displacement = (2993'- 80') x 0.1497 bbl/ft = 436.2 bbls 9-5/8" Intermediate I casing run to 13,173' MD / 5,778' TVD Single stage slurry is designed to be placed from TD to 11,381' MD/5,186' TVD; 40% excess annular volume. 9-5/8" Intrm 1 Cement Calculations Design: UniSLURRY Class G 15.8 ppg Cement @ 40% excess in OH Cement yield = 1.16 1 ftA3/sk I Planned TOC = 11381' MD Shoe Track 80'x 0.0732 bbl/ft x 1.0 (0% excess) 5.9 bbis Shoe to Top of Cement = (13173'- 11381') x 0.0558 bbl/ft x 1.4 (40% excess) 140.0 bbls Total Cement Volume = 145.8 bbls or 818.6 ftA3 I or 1 706 sks Displacement = (13173'- 80') x 0.0732 bbl/ft = 958.5 bbis 7" Intermediate 11 Liner run to 14,215' MD / 6,036' TVD Single stage slurry is designed to be placed from TD to the 7" liner top at 12,973' MD with 30% excess annular volume. 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, erept for an item alreaQv on file with 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 be 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 7" Intrm 2 Cement Calculations Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-718" Hole 7" Liner Design: UniSLURRY Class G 15.8 ppb Cement to 7" Liner Top Mud System Spud (WBM) Cement yield = 1.16 ftA3/sk Planned TOC = 12973' MD Shoe Track = 80'x 0.0383 bbl/ft x 1.0 (0% excess) 3.1 bbis 8-1/2" OH x 7" Annulus = 110'x 0.0226 bbl/ft x 1.3 (30% excess) 3.2 bbls 9-7/8" OH x 7" Annulus = 932'x 0.0471 bbl/ft x 1.3 (30% excess) 57.1 bbis 9-5/8" Csg x 7" Annulus = 200'x 0.0256 bbl/ft x 1.0 (0% excess) 5.1 bbis Total Cement Volume = 68.5 bbis or 1 384.7 ftA3 I or 1 332 sks 10-12 11-15 Displacement = (14135'- 12973') x 0.0383 bbl/ft + 12973'x 0.0235 bbl/ft = 349.3 1 bbis 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, erept for an item alreaQv on file with 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 be 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 19 Mud System is on file with AOGCC. Surface 16" Hole 13-3/8" Casing Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-718" Hole 7" Liner Production 6-1/8" Hole 4-1/2" Liner Mud System Spud (WBM) LSND (WBM) LSND (WBM) Flo -Pro NT (WBM Density 8.8-9.5 9.5-10.5 10.5-12.2 10.5-12.2 PV 30-50 10-20 10-20 10-20 yP 30-80 16-24 17-28 16-24 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A N/A Initial Gel 30-50 10-12 11-15 5 - 8 10 minute Gel 30-50 10-18 12-22 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 120 F N/A < 10 <10 < 10 H 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 19 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 Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Reauirements 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 Reauirements of 20 AAC 25.005 (c)(13) An application far a Permit to Drill must be accompanied by each of the folloiring items, except for an item alreadv on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Move in / rig up Doyon Rig 19. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point as per directional plan with 5-7/8" DP. Survey & log with MWD, GWD, GR. 3. Run and cement 13-3/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Pe—F 4IeZ5 B vl / s f. H 13-061 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 12-1/4" PDC bit and directional drilling assembly, with MWD, Gamma Ray, & Resistivity. RIH to 100' above float collar with 5-7/8" DP. Test surface casing to 3,000 psi for 30 minutes. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 1 ppg EMW, record results. 5v 14va C 7. Directionally drill to 12-1/4" intermediate 1 hole to TD in the HRZ. /'J• Jr LoT m� h 8. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Lay down intermediate I BHA. PIP) 10. Run 9-5/8", 474/409 L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Displace cement with mud and check floats upon bumping plug. Top cement to be placed@ +/- 11,381' MD/5,186'TVD. svb^ YntJab �ss�li5 fo f}DC2GG 12. install 9-5/8" packoff & test to 5000 psi. 13. PU 8-1/2" bit, and drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and Neutron Density. 14. RIH on 5-7/8" DP to top of float equipment. Test casing to 3,500 psi for 30 minutes. 15. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 13.0 ppg EMW recording results. 16. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel to freeze protect. 17. Directionally drill 8-1/2" x 9-7/8" hole to TD in the Kuparuk C sand. 18. Circulate I BU and flow check. POOH on elevators to 9-5/8" shoe. CBU to clean casing & POOH on elevators. 19. Lay down intermediate 2 BHA. 20. Rig up & Run 7", 26#, L-80, Hydril 563 liner and liner top packer. Change out handling gear and RIH with 7" Liner on 5-7/8" DP to bottom. 21. Pump cement job as per Schlumberger proposal. Displace cement with mud. Top of cement to be at t1le liner hanger +/- 12,973' MD/5,701' TVD. '+O ZZ OC 22. Release liner running tool and set packer. PU and pressure test packer to 1,000 psi for 10 minutes. 23. PU 6-1/8" bit and drilling assembly with MWD, Gamma Ray, Resistivity, Neutron Density, Periscope, and Sonic. RIH, log top of cement for Intermediate 11 casing, and clean out cement to float equipment. Test the liner to 3,500 psi for 30 min, record results. 24. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 13.0 ppg EMW, recording results. 25. Directionally drill the 6-1/8" production section, geo-steering in the Kuparuk C sand to TD. 26. Circulate Ix BU at TD and flow check. 27. BROOH to the 7" shoe. CBU and POOH on elevators. 28. Lay down the 6-1/8" production BHA. 29. PU and run 4-1/2", 12.6# liner with liner hanger/packer, swell packers, and frac sleeves. 30. Set liner hanger & packer. 31. Pressure test liner top packer to 3,000 psi, chart results. 32. Flow check well. 33. POOH with liner running tools and lay down. 34. Run 3-1/2" 9.3#, L-80, EUE 8RD upper completion and land tubing. 35. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 36. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An appltcation for a Permit to Drill nutsic be accompanied by each tf the following Items. ercepl for an uem already onfile with the commission and identified in the application: (14) a general description of hint the operator plans to dispose of drilling mud and adtings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the yell.: 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 1B 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 BOP Ram Placement for Intermediate I Section Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Intrm 1 BOA' Configuration Intrm 2 & Production Operations 2M-40wp1., rroposed Wellbore Schematic `' Producer w/Frac ConocoPhillips Spud mud 8.69.5 PPG 4,032' MD / 2,977' ND '. Camn55 LSND WBM 9.5-9.8 PPG 9,6721/ 4,673' ND 13,167' MD / 5,776' ND Conductor installed: 20" set at 176' Updated: 4/17/2019 by K. Herring 16" Surface Hole 1 Surface Casing: Below West Sak 13-3/8" 684 L-80 Hydril 563 2,993' MD / 2,638' TVD 73° Tangent 12-1/4" Intermediate Hole Tubing: 3-%" 9.3# L-80 EUE 8rd TOC at 11,381' MD / 5,186' TVD HRD-E 7XP Packer 7" x 9 5/8" Flex -Lock liner hanger Intermediate 1: 9 5/8" 40#, L80,BTC-M +/-13,173' MD/5,778' TVD LSND WBM o° 8-1/2" x 9-7/8" Intermediate Hole 10.5-KWF PPG \Q 14,215' MD / 6,036' ND N Premier Packer ' HR0�2Y(1r Packer. -' Kuparuk C Sand 7" Y4 -Y." Baker Fre-AotkUner hanger Intermediate 2: 7" 264, L80, Hydril563 14,215"MD/6,036' TVD FloPro (VJBMI J9.8x0.5 ppg with MPD to WiF PPB Lrr L� Ir Irr Lr sweu Padcers-tbrtatik isulaatln Ball Activated I,racSleeves 4-1/2" 126# L-80 HVD563 +/-21,241' MD/6,110 TVD (33) 99 31 I IA' DRILL SITE 2M DRILL SITE PLOT PLAN DRAWN BY: ALKET MICI SCALE 100 D 50 100 DRAF DOYON 19 LAYOUT 31 33 34 35 11 12 13 14 15 16 17 18 19 38 21 22 3 24 2526 ❑ ❑° ❑ m Pipelines Conocophillips TITLE: DS2M LAYOUT DRAWING Kaska, Inc. DRAWN BY: ALKET MICI DATE: ApO 20;9 REY. 1 0 2M-40wp13 - .. PermitPac Plan Summa 0/ 13-3/8 x 16 10 13-3/8 x O '60— r E 030— 0 U 0 4125 18250 12375 t 1 16500 20625 �- 9-5/8 x 12-1/4 Measured Depth 7" x 8-1/2 by 9-7/8•' 4-1/2 x 6-1/8 As Built 36.9+100.7 D19 @ 137.60usft (D19) 0 0 � Ill I East /X: Checked by: .r, r•D i.4 38.90 1500.00 2MJOwy19 (Plan: 2M-40) GVD-GGSS 1500.002500.00 2M>O.ry13 (Plan: 2"0) MWO Petl EIBVatlon: 100.70 180 I l AMEMEN■t■ 1500.002992.58 2=13 (Plan: 2M 0) MWONFR-AK-CA -SC ND MD Name V. Osara 19598 21242 2992s8 4492.58 2"0113 (Plan: 2M♦0) MWD 2992.583173.26 2M-4Mg13 fPlan: 2"0) MWD+IFR-AK-CA -SC 263].Jg 2QJ2.56 13318 x 16 Magnetic Model & Date: BGGM2018 01 -May -19 OEM l Magnetic North is 16.49' East of True North (Magnetic Declination 9 ( 9 N � 6035.60 14215.2W" z 8-1 /2 6y 9-7/8" 6110.29 21241.08 4-1/2 x 6-1/8 Magnetic Dip & Field Strength: 80.79¢ 57404nT N la�slm - � twa�m. J] 299 _ _ ill"' 'wm ..n.rste°z'Imoax� roonuw mos . ''c ♦Base zI. ne n. �:l' zh:almmmv M-3 wPt 0 290 — 468 2500 5000 --7500 10000 12500 15000 17500, 330 - 30 400 — am 9-5/8 x 12-1/4 Horizontal Departure 7" x 8-1/2 by 9-7/8" 4-1/2 x 6-1/ e1 668 — am lmia Base WS D oiW s. r,<:nzu im,i•®n. 858 1038 Ill I East /X: Checked by: .r, r•D i.4 38.90 1500.00 2MJOwy19 (Plan: 2M-40) GVD-GGSS 1500.002500.00 2M>O.ry13 (Plan: 2"0) MWO Petl EIBVatlon: 100.70 180 I l AMEMEN■t■ 1500.002992.58 2=13 (Plan: 2M 0) MWONFR-AK-CA -SC ND MD Name V. Osara 19598 21242 2992s8 4492.58 2"0113 (Plan: 2M♦0) MWD 2992.583173.26 2M-4Mg13 fPlan: 2"0) MWD+IFR-AK-CA -SC 263].Jg 2QJ2.56 13318 x 16 Magnetic Model & Date: BGGM2018 01 -May -19 OEM 5777.9013173.26 9-13312-1/4 Magnetic North is 16.49' East of True North (Magnetic Declination 9 ( 9 13173.2842 15.20 2M♦O.W 13 (Pore 2M♦0) MWD.IFR AK-CAZ-6C 14215.20 9880.00 2"0,13 all n: 2"0) MM 14215.281241.08 211"n: 2"0) MWD+lFR-AK-CA2-SC 6035.60 14215.2W" z 8-1 /2 6y 9-7/8" 6110.29 21241.08 4-1/2 x 6-1/8 Magnetic Dip & Field Strength: 80.79¢ 57404nT N la�slm 1 0 2750 5500 8250 11000 13750 16500 19250 9)38 11308 IIIIIIIti� a Depth FmWeM To u y n ao East /X: Checked by: .r, r•D i.4 38.90 1500.00 2MJOwy19 (Plan: 2M-40) GVD-GGSS 1500.002500.00 2M>O.ry13 (Plan: 2"0) MWO Petl EIBVatlon: 100.70 180 0 1]95 19598 1500.002992.58 2=13 (Plan: 2M 0) MWONFR-AK-CA -SC ND MD Name V. Osara 19598 21242 2992s8 4492.58 2"0113 (Plan: 2M♦0) MWD 2992.583173.26 2M-4Mg13 fPlan: 2"0) MWD+IFR-AK-CA -SC 263].Jg 2QJ2.56 13318 x 16 Magnetic Model & Date: BGGM2018 01 -May -19 13173.284215.20 2M40ip13 (Plan: 2"Ch MWD 5777.9013173.26 9-13312-1/4 Magnetic North is 16.49' East of True North (Magnetic Declination 9 ( 9 13173.2842 15.20 2M♦O.W 13 (Pore 2M♦0) MWD.IFR AK-CAZ-6C 14215.20 9880.00 2"0,13 all n: 2"0) MM 14215.281241.08 211"n: 2"0) MWD+lFR-AK-CA2-SC 6035.60 14215.2W" z 8-1 /2 6y 9-7/8" 6110.29 21241.08 4-1/2 x 6-1/8 Magnetic Dip & Field Strength: 80.79¢ 57404nT N la�slm ner-3 d v�.�mv.Xmmas'mn'.a®a twa�m. 2750 5500 8250 11000 13750 16500 19250 9)38 11308 IIIIIIIti� a Depth FmWeM To u y n ao East /X: Checked by: 16318 17958 38.90 1500.00 2MJOwy19 (Plan: 2M-40) GVD-GGSS 1500.002500.00 2M>O.ry13 (Plan: 2"0) MWO Petl EIBVatlon: 100.70 180 0 1]95 19598 1500.002992.58 2=13 (Plan: 2M 0) MWONFR-AK-CA -SC ND MD Name V. Osara 19598 21242 2992s8 4492.58 2"0113 (Plan: 2M♦0) MWD 2992.583173.26 2M-4Mg13 fPlan: 2"0) MWD+IFR-AK-CA -SC 263].Jg 2QJ2.56 13318 x 16 Magnetic Model & Date: BGGM2018 01 -May -19 13173.284215.20 2M40ip13 (Plan: 2"Ch MWD 5777.9013173.26 9-13312-1/4 Magnetic North is 16.49' East of True North (Magnetic Declination 9 ( 9 13173.2842 15.20 2M♦O.W 13 (Pore 2M♦0) MWD.IFR AK-CAZ-6C 14215.20 9880.00 2"0,13 all n: 2"0) MM 14215.281241.08 211"n: 2"0) MWD+lFR-AK-CA2-SC 6035.60 14215.2W" z 8-1 /2 6y 9-7/8" 6110.29 21241.08 4-1/2 x 6-1/8 Magnetic Dip & Field Strength: 80.79¢ 57404nT nmos.lslr,b Checked by: x mm am am m ¢m am ��ay m am m .11 a w in moo Lilholagy, Column B. Temple V. Osara rvw nu a m inim a� . om um 41. DE _ Nn.na �mm" amm mzi; 1rag 14 1. la�slm ner-3 d v�.�mv.Xmmas'mn'.a®a twa�m. K-15 aI.o Zo tl �irw mtlB.cPa:m �: _ _ ill"' 'wm ..n.rste°z'Imoax� roonuw mos ''c ♦Base zI. ne n. �:l' zh:almmmv ro,aan,. Imu°msaaaen°n mu•Xmom.Ta.bua Perm mmnlu :oIW ,.c n im' iinz®:�isurz am w� ::v:a Sak D _ all, I.ms1 .11 Xmb$Trt bAu m�SYm ll ® M. pS VRw>iev lmia Base WS D oiW s. r,<:nzu im,i•®n. moa °z h:°b� ¢mole. mice I . Camp SS IDm1Om � ' am N :zal.m ms of zl�a.. amlm,.�c aaot.or.�s„ ro n C-50 C-37 / Top I C-35 By signing this I acknoWedge that I have been informed of all risks, checked that the data is correct, ensured its completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as sal out in the audit pad.l approve it as the basis for the foal well plan w O.M and ilsite drawings, I also a&nowedge that unless notified otherwise all targets have a 100 feet lateral tolerance. I .M repared by Checked by: ccepted by: Approved by: B. Temple V. Osara J. Ryan DE 13:35 A ril 11 2019 2M-40wpl3 36.90 To 21242.01 Spider 20b,06 p 2M-19 . 60 60 40 SO ._..... I l A+1-41 2' 50 o 2f&05 p0 2M 8 2M-2 � 2 6 60 40 0 - 2M-36 30 50 0 0 3 go 2M-376 - �bpQQ2M-1 -25 ODM o P O h 2M -382M-24 _ _ _. -28 29 o 3 -26 o -0 PO -14A p 60 0 0 �0 O ... 60 0 5p -31 0 o 170 0 30 p 210-22 g0 o Z O - - -2M-17 v 5 050 40 2M- 2M-02 ¢M o -07 2M-14 0 `So 50 50 50 S0 _.. 0 15 50 _ o 0 2M-33 2M-40wp13 2M -32L1 PB1 �� 4 -60 M-08 g %-09 FIL 1 _-_- -... -2M 2K -34L1 2K -086P --- 33 III 25-14 60 -32L1 PB2 2M-34 2JAL1 . -. _ 2M-38wp1 60 �I- 2M-35 2M-08 - 01 1 25-11 Easting (3000 usftfin) 2M-40wp13 Plan Vmew While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. N � p 13-3/8 x 16- - 0 d o 0 d o 0 0 0 d 0 0 d o 0 9-5/8 x 12-1/4 d 0 0 -2000 �o CD 0 00 7" x 8-1/2 by 9-7/8"_14000_ 2M-40 TO 020818 J -4000 ,0 2M-40 T02 020818 J t z b000 2M-40 T03 020818 J 1 7.000 2M-40 T04 020818 J �° 6000 2M-40 T05 020818 J 2M-40 T06 020818 J 19000 2M-40 T07 020818 J -8000 20000 27M-40 T08 020818 J 2M-40 T09 020818 J 4-1/2 x 6-1/8 21000 -10000 1242 2M-40 T10 020818 J -10000 -8000 -6000 -4000 -2000 0 -12000 West(-)/East(+) 2M-40wp13 Section View -15 0 ase Perm 3° 1004Y' Base WS D 1500 amp Q 0 - ----- ------------ ------------- -------------------------- o C-50 13-3/8 1 x o C-37 Top Iceberg > 00 F` C-35 4500Irl O O N Top Kupar k rn- ox�ao 00 o ________ __ 6000 -- � ----- - - - -- 9-5/8 x 12-1 (4 � 7" x 8-1 /2 by 9-7/8" 0 4-1 /2 x 6-1 /so 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 192.000 A O O N ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 2M Pad Plan: 2M-40 50103xxxxx00 Plan: 2M-40 Plan: 2M-40wp13 Standard Proposal Report 16 April, 2019 ConocoPhillips ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska lnc_Kupawk Project: Kuparuk River Unit -2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M-40 Design: 2M40wp13 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well Plan: 2M40 TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) MD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D79) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupamk 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 Kupawk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10, Well Plan'. 2M-40 Well Position +NI -S -0.54 usft Northing: Latitude: +EAW 39.75 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: Wellbore Plan. 2M-40 Magnetics Model Name Sample Date Declination Dip Angle BGGM2018 51112019 16.49 6079 Design 2M-40wpl3 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.90 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction lush) lush) (usft) (°I 36.90 0.00 0.00 192.00 100.70 usft Field Strength (nT) 57,404 4/16/2019 8:48:32AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPt Company: ConowPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 2M Pad Well: Plan: 2M40 Wellbore: Plan: 2M40 Design: 2M40wpl3 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Survey Tool Program Date 4/16/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 36.90 1,500.00 2M-40wpl3(Plan'. 2M40) GYD-GC-SS Gyrodate gyro single shots 2 1,500.00 2,500.00 2M40wp13 (Plan: 2M40) MWD MWD - Standard 3 1,500.00 2,992.58 2M-40wp13(Plan: 2M40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 2,992.58 4,492.58 2M-40wpl 3 (Plan: 2M-40) MWD MWD - Standard 5 2,992.58 13,173.26 2M40wpl 3(Plan: 2M40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6 13,173.26 14,215.20 2M40wpl3(Plan: 21040) MWD MWD - Standard 7 13,173.26 14,215.20 2M-40wpl3(Plan: 2M40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8 14,215.20 18,680.00 2M40wp13 (Plan: 2M40) MVOD MWD - Standard 9 14,215.20 21,241.08 2M4Uwp13 (Plan: 21040) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ConocoPhillips Standard Proposal Report Well Plan: 2M40 As Built 36.9+100.7 D19 @ 137.60usft (Di9) As Built 36.9+100.7 D19 @ 137.60usft (D19) True Minimum Curvature 411612019 8: 48: 32AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupamk River Unit -2 Site: Kupamk 2M Pad Well: Plan: 210-40 Wellbore: Plan: 2M-40 Design: 2M-40wp13 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 2M40 As Built 36.9+100.7 D19 @ 137.60usft (D79) As Built 36.9+100.7 D19 @ 137.60usft (D19) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth -NAS +Er -W Rate Rate Rate TFO (usft) (') V) (usft) (usft) (usft) (-/100usft) (°1100usft) (°1100usft) V) Target 36.90 0.00 0.00 36.90 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 3.00 290.00 499.91 1.79 4.92 1.50 1.50 0.00 290.00 1,000.00 3.00 290.00 999.22 10.74 -29.51 0.00 0.00 0.00 0.00 1,434.00 13.85 290.00 1,427.90 32.46 -89.17 2.50 2.50 0.00 0.00 1,537.00 13.85 290.00 1,527.90 40.89 -112.34 0.00 0.00 0.00 0.00 2,992.58 63.10 263.35 2,637.90 24.25 -978.59 3.50 3.38 -1.83 -31.00 3,012.58 63.10 263.35 2,646.95 22.19 -996.30 0.00 0.00 0.00 0.00 3,312.58 72.50 260.00 2,760.20 -18.24 -1,270.74 3.30 3.13 -1.12 -18.95 12,212.56 72.50 260.00 5,436.48 -1,492.17 -9,629.87 0.00 0.00 0.00 0.00 13,477.17 68.01 206.20 5,893.48 -2,167.35 -10,542.71 4.00 -0.36 -4.25 -104.43 13,527.02 68.01 206.20 5,912.15 -2,208.83 -10,563.12 0.00 0.00 0.00 0.00 14,015.22 86.00 198.38 6,021.65 -2,647.24 -10,741.57 4.00 3.69 -1.60 -23.98 14,215.22 86.00 198.38 6,035.60 -2,836.57 -10,804.47 0.00 0.00 0.00 0.00 2M-40 T01 020818 JA 14,235.22 86.00 198.38 6,037.00 -2,855.51 -10,810.76 0.00 0.00 0.00 0.00 14,329.73 88.84 198.38 6,041.25 -2,945.09 -10,840.52 3.00 3.00 0.00 0.00 15,162.43 88.84 198.38 6,058.18 -3,735.16 -11,103.01 0.00 0.00 0.00 0.00 2M-40 T02 020818 JA 15,609.00 88.56 189.45 6,068.33 -4,168.07 -11,210.25 2.00 -0.06 -2.00 -91.83 16,007.39 88.56 189.45 6,078.31 -4,560.94 -11,275.64 0.00 0.00 0.00 0.00 16,142.36 90.00 191.74 6,080.00 -4,693.58 -11,300.44 2.00 1.06 1.69 57.90 2M-40 T03 020818 Jh 16,224.39 91.64 191.74 6,078.83 -4,773.89 -11,317.12 2.00 2.00 0.00 0.00 16,596.20 91.64 191.74 6,068.18 -5,137.78 -11,392.71 0.00 0.00 0.00 0.00 2M-40 T04020818 Jh 16,639.57 90.78 191.63 6,067.26 -5,180.25 -11,401.49 2.00 -1.99 -0.23 -173.30 17,221.22 90.78 191.63 6,059.36 -5,749.89 -11,518.78 0.00 0.00 0.00 0.00 17,260.20 90.00 191.66 6,059.09 -5,788.07 -11,526.65 2.00 -2.00 0.07 177.94 21040 T05 020818 Jh 17,362.56 87.95 191.66 6,060.92 -5,888.29 -11,547.33 2.00 -2.00 0.00 -179.99 17,998.70 67.95 191.66 6,083.64 -6,510.90 -11,675.83 0.00 0.00 0.00 0.00 18,090.14 89.78 191.67 6,085.45 -6,600.43 -11,694.32 2.00 2.00 0.01 0.26 2M-40 T06 020818 Jh 18,806.25 89.78 191.67 6,088.18 -7,301.74 -11,839.16 0.00 0.00 0.00 0.00 2M-40 T07 020818 Jh 18,831.15 89.28 191.69 6,088.38 -7,326.12 -11,844.20 2.00 -2.00 0.07 178.00 19,687.98 89.28 191.69 6,099.09 -8,165.13 -12,017.75 0.00 0.00 0.00 0.00 2M-40 T08 020818 JA 19,732.94 88.39 191.63 6,100.00 -8,209.15 -12,026.84 2.00 -2.00 -0.14 -176.05 20,251.93 88.39 191.63 6,114.61 -8,717.29 -12,131.37 0.00 0.00 0.00 0.00 20,332.73 90.00 191.72 6,115.75 -8,796.40 -12,147.72 2.00 2.00 0.12 3.44 2M-40 T09020818 JIB 20,350.11 90.35 191.72 6,115.70 -8,813.43 -12,151.25 2.00 2.00 0.00 0.00 21,241.08 90.35 191.72 6,110.29 -9,685.80 -12,332.26 0.00 0.00 0.00 0.00210-40 T10020818 Jh 411612019 8:48.32AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP1 Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 2M Pad Well: Plan: 21440 Wellbore: Plan: 210-40 Design: 2M40wp13 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 21040 As Built 36.9+100.7 D19 @ 137.60usft (D19) As Built 36.9+100.7 D19 @ 137.60usft (D19) True Minimum Curvature Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate (usft) V) (1) (usft) (usft) (usft) (usft) ("1100usft) ("1100usft) ('1100usft) 36.90 0.00 0.00 36.90 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 1.50 290.00 399.99 0.45 -1.23 -0.18 1.50 1.50 0.00 500.00 3.00 290.00 499.91 1.79 -4.92 -0.73 1.50 1.50 0.00 600.00 3.00 290.00 599.77 3.58 -9.84 -1.46 0.00 0.00 0.00 700.00 3.00 290.00 699.63 5.37 -14.76 -2.19 0.00 0.00 0.00 800.00 3.00 290.00 799.50 7.16 -19.67 -2.91 0.00 0.00 0.00 900.00 3.00 290.00 899.36 8.95 -24.59 -3.64 0.00 0.00 0.00 1,000.00 3.00 290.00 999.22 10.74 -29.51 -4.37 0.00 0.00 0.00 1,100.00 5.50 290.00 1,098.94 13.27 -36.47 -5.40 2.50 2.50 0.00 1,200.00 8.00 290.00 1,198.24 17.29 47.52 -7.04 2.50 2.50 0.00 1,300.00 10.50 290.00 1,296.93 22.79 -62.62 -9.27 2.50 2.50 0.00 1,400.00 13.00 290.00 1,394.83 29.76 -81.75 -12.11 2.50 2.50 0.00 1,434.00 13.85 290.00 1,427.90 32.46 -89.17 -13.21 2.50 2.50 0.00 1,500.00 13.85 290.00 1,491.98 37.86 -104.02 -15.41 0.00 0.00 0.00 1,537.00 13.85 290.00 1,527.90 40.89 -112.34 -16.64 0.00 0.00 0.00 1,600.00 15.78 285.82 1,588.81 45.80 -127.67 -18.26 3.50 3.06 -6.63 1,700.00 18.96 280.94 1,684.24 52.60 -156.72 -18.86 3.50 3.18 -4.89 1,800.00 22.24 277.43 1,777.83 58.13 -191.45 -17.05 3.50 3.28 -3.51 1,900.00 25.57 274.79 1,869.24 62.38 -231.74 -12.83 3.50 3.33 -2.64 2,000.00 28.94 272.72 1,958.13 65.33 -277.43 -6.22 3.50 3.37 -2.06 2,100.00 32.34 271.06 2,044.15 66.97 -328.36 2.76 3.50 3.40 -1.67 2,200.00 35.75 269.68 2,127.00 67.30 -384.34 14.08 3.50 3.41 -1.38 2,300.00 39.18 268.51 2,206.36 66.31 445.15 27.69 3.50 3.43 -1.17 2,400.00 42.62 267.50 2,281.93 64.01 -510.57 43.54 3.50 3.44 -1.01 2,500.00 46.06 266.62 2,353.44 60.41 -580.36 61.57 3.50 3.45 -0.88 2,600.00 49.52 265.83 2,420.62 55.52 -654.25 81.72 3.50 3.45 -0.79 2,700.00 52.97 265.12 2,483.21 49.35 -731.98 103.91 3.50 3.46 -0.71 2,800.00 56.43 264.47 2,540.98 41.94 -813.24 128.06 3.50 3.46 -0.65 2,900.00 59.89 263.87 2,593.73 33.31 -897.74 154.07 3.50 3.46 -0.60 2,992.58 63.10 263.35 2,637.90 24.25 -978.59 179.74 3.50 3.47 -0.56 3,000.00 63.10 263.35 2,641.26 23.49 -985.16 181.85 0.00 0.00 0.00 3,012.58 63.10 263.35 2,646.95 22.19 -996.30 185.44 0.00 0.00 0.00 3,100.00 65.83 262.33 2,684.63 12.35 -1,074.56 211.33 3.30 3.12 -1.17 3,200.00 68.97 261.21 2,723.05 -0.88 -1,165.92 243.26 3.30 3.13 -1.12 3,300.00 72.10 260.13 2,756.37 -16.17 -1,258.94 277.56 3.30 3.14 -1.07 3,312.58 72.50 260.00 2,760.20 -18.24 -1,270.74 282.04 3.30 3.14 -1.05 3,400.00 72.50 260.00 2,786.48 -32.71 -1,352.85 313.27 0.00 0.00 0.00 3,500.00 72.50 260.00 2,816.55 -49.27 -1,446.77 349.00 0.00 0.00 0.00 3,600.00 72.50 260.00 2,846.63 -65.84 -1,540.70 384.73 0.00 0.00 0.00 3,700.00 72.50 260.00 2,876.70 -82.40 -1,634.62 420.45 0.00 0.00 0.00 3,800.00 72.50 260.00 2,906.77 -98.96 -1,728.54 456.18 0.00 0.00 0.00 3,900.00 72.50 260.00 2,936.84 -115.52 -1,822.46 491.91 0.00 0.00 0.00 4,000.00 72.50 260.00 2,966.91 -132.08 -1,916.39 527.63 0.00 0.00 0.00 4,100.00 72.50 260.00 2,996.98 -148.64 -2,010.31 563.36 0.00 0.00 0.00 4,200.00 72.50 260.00 3,027.05 -165.20 -2,104.23 599.09 0.00 0.00 0.00 4,300.00 72.50 260.00 3,057.12 -181.76 -2,198.16 634.81 0.00 0.00 0.00 4,400.00 72.50 260.00 3,087.19 -198.32 -2,292.08 670.54 0.00 0.00 0.00 4,500.00 72.50 260.00 3,117.26 -214.89 -2,386.00 706.27 0.00 0.00 0.00 4,600.00 72.50 260.00 3,147.33 -231.45 -2,479.92 741.99 0.00 0.00 0.00 4,700.00 72.50 260.00 3,177.40 -248.01 -2,573.85 777.72 0.00 0.00 0.00 4,800.00 72.50 260.00 3,207.47 -264.57 -2,667.77 813.45 0.00 0.00 0.00 4/182019 8:48.32AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Coordinate Reference: Well Plan: 2M40 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (1319) Project: Kuparuk River Unit_2 MD Reference: As Built 36.9+100.7 DI9 @ 137.60usft (D79) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-40 Azimuth Depth Design: 2M40wp13 Section Rate Planned Survey Measured Vertical Vertical Doilies Build Tum Depth Inclination Azimuth Depth +N/ -S +El -W Section Rate Rate Rate (usft) (^) (•) (usft) (usft) (usft) (usft) (*Moousft) (°/100usft) (°/100usft) 4,900.00 72.50 260.00 3,237.54 -281.13 -2,761.69 849.17 0.00 0.00 0.00 5,000.00 72.50 260.00 3,267.61 -297.69 -2,855.62 884.90 0.00 0.00 0.00 5,100.00 72.50 260.00 3,297.68 -314.25 -2,949.54 920.63 0.00 0.00 0.00 5,200.00 72.50 260.00 3,327.75 -330.81 -3,043.46 956.36 0.00 0.00 0.00 5,300.00 72.50 260.00 3,357.83 -347.37 -3,137.38 992.08 0.00 0.00 0.00 5,400.00 72.50 260.00 3,387.90 -363.94 -3,231.31 1,027.81 0.00 0.00 0.00 5,500.00 72.50 260.00 3,417.97 -380.50 -3,325.23 1,063.54 0.00 0.00 0.00 5,600.00 72.50 260.00 3,448.04 -397.06 -3,419.15 1,099.26 0.00 0.00 0.00 5,700.00 72.50 260.00 3,478.11 -413.62 -3,513.08 1,134.99 0.00 0.00 0.00 5,800.00 72.50 260.00 3,508.18 -430.18 -3,607.00 1,170.72 0.00 0.00 0.00 5,900.00 72.50 260.00 3,538.25 446.74 -3,700.92 1,206.44 0.00 0.00 0.00 6,000.00 72.50 260.00 3,568.32 463.30 -3,794.84 1,242.17 0.00 0.00 0.00 6,100.00 72.50 260.00 3,598.39 479.86 -3,888.77 1,277.90 0.00 0.00 0.00 6,200.00 72.50 260.00 3,628.46 496.42 -3,982.69 1,313.62 0.00 0.00 0.00 6,300.00 72.50 260.00 3,658.53 -512.99 -4,076.61 1,349.35 0.00 0.00 0.00 6,400.00 72.50 260.00 3,688.60 -529.55 -4,170.53 1,385.08 0.00 0.00 0.00 6,500.00 72.50 260.00 3,718.67 -546.11 4,264.46 1,420.80 0.00 0.00 0.00 6,600.00 72.50 260.00 3,748.74 -562.67 -4,358.38 1,456.53 0.00 0.00 0.00 6,700.00 72.50 260.00 3,778.81 -579.23 -4,452.30 1,492.26 0.00 0.00 0.00 6,800.00 72.50 260.00 3,808.88 -595.79 -4,546.23 1,527.99 0.00 0.00 0.00 6,900.00 72.50 260.00 3,838.95 -612.35 -4,640.15 1,563.71 0.00 0.00 0.00 7,000.00 72.50 260.00 3,869.03 -628.91 -4,734.07 1,599.44 0.00 0.00 0.00 7,100.00 72.50 260.00 3,899.10 -645.47 -4,827.99 1,635.17 0.00 0.00 0.00 7,200.00 72.50 260.00 3,929.17 -662.04 -4,921.92 1,670.89 0.00 0.00 0.00 7,300.00 72.50 260.00 3,959.24 -678.60 -5,015.84 1,706.62 0.00 0.00 0.00 7,400.00 72.50 260.00 3,989.31 -695.16 -5,109.76 1,742.35 0.00 0.00 0.00 7,500.00 72.50 260.00 4,019.38 -711.72 -5,203.69 1,778.07 0.00 0.00 0.00 7,600.00 72.50 260.00 4,049.45 -728.28 -5,297.61 1,813.80 0.00 0.00 0.00 7,700.00 72.50 260.00 4,079.52 -744.84 -5,391.53 1,849.53 0.00 0.00 0.00 7,800.00 72.50 260.00 4,109.59 -761.40 -5,485.45. 1,885.25 0.00 0.00 0.00 7,900.00 72.50 260.00 4,139.66 -777.96 -5,579.38 1,920.98 0.00 0.00 0.00 8,000.00 72.50 260.00 4,169.73 -794.52 -5,673.30 1,956.71 0.00 0.00 0.00 8,100.00 72.50 260.00 4,199.80 -811.09 -5,767.22 1,992.43 0.00 0.00 0.00 8,200.00 72.50 260.00 4,229.87 -827.65 -5,861.14 2,028.16 0.00 0.00 0.00 6,300.00 72.50 260.00 4,259.94 -844.21 -5,955.07 2,063.89 0.00 0.00 0.00 6,400.00 72.50 260.00 4,290.01 -860.77 -6,048.99 2,099.61 0.00 0.00 0.00 8,500.00 72.50 260.00 4,320.08 -877.33 -6,142.91 2,135.34 0.00 0.00 0.00 8,600.00 72.50 260.00 4,350.15 -893.89 -6,236.84 2,171.07 0.00 0.00 0.00 8,700.00 72.50 260.00 4,380.23 -910.45 -6,330.76 2,206.80 0.00 0.00 0.00 8,800.00 72.50 260.00 4,410.30 -927.01 -6,424.68 2,242.52 0.00 0.00 0.00 8,900.00 72.50 260.00 4,440.37 -943.57 -6,518.60 2,278.25 0.00 0.00 0.00 9,000.00 72.50 260.00 4,470.44 -960.14 -6,612.53 2,313.98 0.00 0.00 0.00 9,100.00 72.50 260.00 4,500.51 -976.70 -6,706.45 2,349.70 0.00 0.00 0.00 9,200.00 72.50 260.00 4,530.58 -993.26 -6,800.37 2,385.43 0.00 0.00 0.00 9,300.00 72.50 260.00 4,560.65 -1,009.82 -6,894.30 2,421.16 0.00 0.00 0.00 9,400.00 72.50 260.00 4,590.72 -1,026.38 -6,988.22 2,456.88 0.00 0.00 0.00 9,500.00 72.50 260.00 4,620.79 -1,042.94 -7,082.14 2,492.61 0.00 0.00 0.00 9,600.00 72.50 260.00 4,650.86 -1,059.50 -7,176.06 2,528.34 0.00 0.00 0.00 9,700.00 72.50 260.00 4,680.93 -1,076.06 -7,269.99 2,564.06 0.00 0.00 0.00 9,800.00 72.50 260.00 4,711.00 -1,092.62 -7,363.91 2,599.79 0.00 0.00 0.00 9,900.00 72.50 260.00 4,741.07 -1,109.19 -7,457.83 2,635.52 0.00 0.00 0.00 10,000.00 72.50 260.00 4,771.14 -1,125.75 -7,551.75 2,671.24 0.00 0.00 0.00 10,100.00 72.50 260.00 4,801.21 -1,142.31 -7,645.68 2,706.97 0.00 0.00 0.00 10,200.00 72.50 260.00 4,831.28 -1,158.87 -7,739.60 2,742.70 0.00 0.00 0.00 4116/2019 8:48:32AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 2M40 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D79) Project: Kuparuk River Unit _2 MD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M40 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-40 Design: 2M-40wpl3 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +E/ -W Section Rate Rate Rate (usft) (^) (^) (usft) (usft) (usft) (usft) (°I100usft) (°1100usft) ("/100usft) 10,300.00 72.50 260.00 4,861.35 -1,175.43 -7,833.52 2,778.43 0.00 0.00 0.00 10,400.00 72.50 260.00 4,891.42 -1,191.99 -7,927.45 2,814.15 0.00 0.00 0.00 10,500.00 72.50 260.00 4,921.50 -1,208.55 -8,021.37 2,849.88 0.00 0.00 0.00 10,600.00 72.50 260.00 4,951.57 -1,225.11 -8,115.29 2,885.61 0.00 0.00 0.00 10,700.00 72.50 260.00 4,981.64 -1,241.67 -8,209.21 2,921.33 0.00 0.00 0.00 10,800.00 72.50 260.00 5,011.71 -1,258.24 -8,303.14 2,957.06 0.00 0.00 0.00 10,900.00 72.50 260.00 5,041.78 -1,274.80 -8,397.06 2,992.79 0.00 0.00 0.00 11,000.00 72.50 260.00 5,071.85 -1,291.36 -8,490.98 3,028.51 0.00 0.00 0.00 11,100.00 72.50 260.00 5,101.92 -1,307.92 -8,584.91 3,064.24 0.00 0.00 0.00 11,200.00 72.50 260.00 5,131.99 -1,324.48 -8,678.83 3,099.97 0.00 0.00 0.00 11,300.00 72.50 260.00 5,162.06 -1,341.04 -8,772.75 3,135.69 0.00 0.00 0.00 11,400.00 72.50 260.00 5,192.13 -1,357.60 -8,866.67 3,171.42 0.00 0.00 0.00 11,500.00 72.50 260.00 5,222.20 -1,374.16 -8,960.60 3,207.15 0.00 0.00 0.00 11,600.00 72.50 260.00 5,252.27 -1,390.72 -9,054.52 3,242.87 0.00 0.00 0.00 11,700.00 72.50 260.00 5,282.34 -1,407.29 -9,148.44 3,278.60 0.00 0.00 0.00 11,800.00 72.50 260.00 5,312.41 -1,423.85 -9,242.37 3,314.33 0.00 0.00 0.00 11,900.00 72.50 260.00 5,342.48 -1,440.41 -9,336.29 3,350.06 0.00 0.00 0.00 12,000.00 72.50 260.00 5,372.55 -1,456.97 -9,430.21 3,385.78 0.00 0.00 0.00 12,100.00 72.50 260.00 5,402.62 -1,473.53 -9,524.13 3,421.51 0.00 0.00 0.00 12,200.00 72.50 260.00 5,432.70 -1,490.09 -9,618.06 3,457.24 0.00 0.00 0.00 12,212.58 72.50 260.00 5,436.48 -1,492.17 -9,629.87 3,461.73 0.00 0.00 0.00 12,300.00 71.66 256.43 5,463.38 -1,509.15 -9,711.28 3,495.26 4.00 -0.96 4.08 12,400.00 70.78 252.31 5,495.59 -1,534.64 -9,802.44 3,539.15 4.00 -0.88 -4.12 12,500.00 70.00 248.15 5,529.16 -1,566.49 -9,891.06 3,588.73 4.00 -0.78 -0.16 12,600.00 69.31 243.94 5,563.94 -1,604.55 -9,976.73 3,643.76 4.00 -0.69 -4.20 12,700.00 68.73 239.70 5,599.75 -1,648.62 -10,059.01 3,703.98 4.00 -0.58 -4.24 12,800.00 68.25 235.44 5,636.43 -1,698.49 -10,137.52 3,769.08 4.00 -0.48 -0.27 12,900.00 67.89 231.14 5,673.79 -1,753.92 -10,211.87 3,838.76 4.00 -0.37 4.29 13,000.00 67.63 226.83 5,711.65 -1,814.64 -10,281.69 3,912.67 4.00 -0.25 4.31 13,100.00 67.49 222.50 5,749.84 -1,880.36 -10,346.65 3,990.46 4.00 -0.14 4.33 13,200.00 67.47 218.17 5,788.15 -1,950.75 -10,406.42 4,071.74 4.00 -0.02 4.33 13,300.00 67.56 213.85 5,826.41 -2,025.47 -10,460.73 4,156.12 4.00 0.09 4.33 13,400.00 67.77 209.53 5,864.42 -2,104.16 -10,509.30 4,243.18 4.00 0.21 -4.32 13,477.17 68.01 206.20 5,893.48 -2,167.35 -10,542.71 4,311.94 4.00 0.31 -4.30 13,500.00 68.01 206.20 5,902.03 -2,186.35 -10,552.05 4,332.46 0.00 0.00 0.00 13,527.02 68.01 206.20 5,912.15 -2,208.83 -10,563.12 4,356.76 0.00 0.00 0.00 13,600.00 70.68 204.95 5,937.89 -2,270.42 -10,592.59 4,423.13 4.00 3.66 -1.72 13,700.00 74.35 203.29 5,967.93 -2,357.46 -10,631.54 4,516.36 4.00 3.67 -1.66 13,800.00 78.04 201.69 5,991.79 -2,447.17 -10,668.67 4,611.83 4.00 3.69 -1.60 13,900.00 81.74 200.14 6,009.34 -2,539.11 -10,703.80 4,709.07 4.00 3.70 -1.56 14,000.00 85.44 198.61 6,020.51 -2,632.84 -10,736.75 4,807.61 4.00 3.70 -1.53 14,015.22 86.00 198.38 6,021.65 -2,647.24 -10,741.57 4,822.69 4.00 3.70 -1.52 14,100.00 86.00 198.38 6,027.56 -2,727.50 -10,768.23 4,906.74 0.00 0.00 0.00 14,200.00 86.00 198.38 6,034.54 -2,822.17 -10,799.68 5,005.87 0.00 0.00 0.00 •14,215.22 86.00 198.38 6,035.60 -2,836.57 -10,804.47 5,020.96 0.00 0.00 0.00 14,235.22 86.00 198.38 6,037.00 -2,855.51 -10,810.76 5,040.79 0.00 0.00 0.00 14,300.00 87.94 198.38 6,040.42 -2,916.89 -10,831.16 5,105.08 3.00 3.00 0.00 14,329.73 88.84 198.38 6,041.25 -2,945.09 -10,840.52 5,134.61 3.00 3.00 0.00 14,400.00 88.84 198.38 6,042.68 -3,011.77 -10,862.68 5,204.43 0.00 0.00 0.00 14,500.00 88.84 198.38 6,044.71 -3,106.65 -10,894.20 5,303.79 0.00 0.00 0.00 14,600.00 88.84 198.38 6,046.75 -3,201.53 -10,925.72 5,403.15 0.00 0.00 0.00 14,700.00 88.84 198.38 6,048.78 -3,296.41 -10,957.24 5,502.51 0.00 0.00 0.00 14,800.00 88.84 198.38 5,050.81 -3,391.29 -10,988.77 5,601.87 0.00 0.00 0.00 4/1012019 8:48:32AM Page 7 COMPASS 5000.14 Build 850 ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 15,000.00 15,100.00 15,162.43 15,200.00 15,300.00 15,400.00 15,500.00 15,600.00 15,609.00 15,700.00 15,800.00 15,900.00 16,000.00 16,007.39 16,100.00 16,142.36 16,200.00 16,224.39 16,300.00 16,400.00 16,500.00 16,596.20 16,600.00 16,639.57 16,700.00 16,800.00 16,900.00 17,000.00 17,100.00 17,200.00 17,221.22 17,260.20 17,300.00 17,362.56 17,400.00 17,500.00 17,600.00 17,700.00 17,800.00 17,900.00 17,998.70 18,000.00 18,090.14 18,100.00 18,200.00 18,300.00 18,400.00 18,500.00 18,600.00 18,700.00 18,800.00 18,806.25 18,831.15 OAKEDMPI ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 2M Pad Plan: 2M40 Plan: 2M40 2M-40wpl3 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 21040 TVD Reference: As Built 36.9+100.7 D19 ® 137.60usft (019) MO Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Dogleg Build Tum Vertical Rate Rate Inclination Azimuth Depth -NIS +E/ -W (°) 0.00 (1) 0.00 (usft) (usft) (usft) 88.84 5,961.98 198.38 0.00 6,054.88 -3,581.05 -11,051.81 88.84 -2.00 198.38 2.00 6,056.91 -3,675.93 -11,083.33 88.84 -0.06 198.38 6,298.81 6,058.18 -3,735.16 -11,103.01 88.81 2.00 197.63 -2.00 6,058.95 -3,770.89 -11,114.62 88.75 6,498.62 195.63 0.00 6,061.08 -3,866.68 -11,143.23 88.69 0.00 193.63 0.00 6,063.32 -3,963.41 -11,168.47 88.63 0.00 191.63 6,805.61 6,065.66 4,060.96 -11,190.33 88.57 2.00 189.63 1.69 6,068.11 -4,159.21 -11,208.76 88.56 6,998.15 189.45 2.00 6,068.33 4,168.07 -11,210.25 88.56 0.00 189.45 0.00 6,070.61 4,257.82 -11,225.19 88.56 0.00 189.45 7,298.03 6,073.12 4,356.43 -11,241.60 88.56 0.00 189.45 0.00 6,075.62 4,455.04 -11,258.01 88.56 7,437.55 189.45 -1.99 6,078.12 4,553.65 -11,274.42 88.56 0.00 189.45 0.00 6,078.31 -4,560.94 -11,275.64 89.55 0.00 191.02 7,797.94 6,079.83 4,652.06 -11,292.09 90.00 0.00 191.74 0.00 6,080.00 4,693.58 -11,300.44 91.15 8,019.13 191.74 0.00 6,079.42 4,750.02 -11,312.16 91.64 0.07 191.74 2.00 6,078.83 4,773.89 -11,317.12 91.64 -2.00 191.74 8,197.86 6,076.66 4,847.89 -11,332.49 91.64 0.00 191.74 0.00 6,073.80 4,945.76 -11,352.82 91.64 8,497.66 191.74 0.00 6,070.93 -5,043.63 -11,373.16 91.64 0.00 191.74 0.00 6,068.18 -5,137.78 -11,392.71 91.57 0.00 191.73 8,797.47 6,068.07 -5,141.50 -11,393.49 90.78 2.00 191.63 0.01 6,067.26 -5,180.25 -11,401.49 90.78 8,997.44 191.63 0.00 6,066.44 -5,239.43 -11,413.68 90.78 0.00 191.63 0.00 6,065.08 -5,337.36 -11,433.84 90.78 0.00 191.63 9,397.43 6,063.72 -5,435.30 -11,454.01 90.78 0.00 191.63 0.00 6,062.36 -5,533.24 -11,474.17 90.78 9,603.68 191.63 0.00 6,061.00 -5,631.17 -11,494.33 90.78 0.07 191.63 6,059.64 -5,729.11 -11,514.50 90.78 191.63 6,059.36 -5,749.89 -11,518.78 90.00 191.66 6,059.09 -5,788.07 -11,526.65 89.20 191.66 6,059.37 -5,827.05 -11,534.69 87.95 191.66 6,060.92 -5,888.29 -11,547.33 87.95 191.66 6,062.26 -5,924.94 -11,554.90 87.95 191.66 6,065.83 -6,022.81 -11,575.10 87.95 191.66 6,069.40 -6,120.68 -11,595.30 87.95 191.66 6,072.97 -6,218.56 -11,615.50 87.95 191.66 6,076.54 -6,316.43 -11,635.70 87.95 191.66 6,080.12 -6,414.30 -11,655.90 87.95 191.66 6,083.64 -6,510.90 -11,675.83 87.98 191.66 6,083.69 -6,512.18 -11,676.10 89.78 191.67 6,085.45 -6,600.43 -11,694.32 89.78 191.67 6,085.49 -6,610.09 -11,696.31 89.78 191.67 6,085.87 -6,708.02 -11,716.54 89.78 191.67 6,086.25 -6,805.96 -11,736.77 89.78 191.67 6,086.63 -6,903.89 -11,756.99 89.78 191.67 6,087.01 -7,001.82 -11,777.22 89.78 191.67 6,087.39 -7,099.75 -11,797.45 89.78 191.67 6,087.78 -7,197.69 -11,817.67 89.78 191.67 6,088.16 -7,295.62 -11,837.90 89.78 191.67 6,088.18 -7,301.74 -11,839.16 89.28 191.69 6,088.38 -7,326.12 -11,844.20 Vertical Dogleg Build Tum Section Rate Rate Rate (usft) ('1100usft) (*1100usft) (°1100usft) 5,800.59 0.00 0.00 0.00 5,899.96 0.00 0.00 0.00 5,961.98 0.00 0.00 0.00 5,999.34 2.00 -0.06 -2.00 6,098.99 2.00 -0.06 -2.00 6,198.85 2.00 -0.06 -2.00 6,298.81 2.00 -0.06 -2.00 6,398.75 2.00 -0.06 -2.00 6,407.73 2.00 -0.06 -2.00 6,498.62 0.00 0.00 0.00 6,598.49 0.00 0.00 0.00 6,698.36 0.00 0.00 0.00 6,798.23 0.00 0.00 0.00 6,805.61 0.00 0.00 0.00 6,898.16 2.00 1.06 1.69 6,940.51 2.00 1.06 1.69 6,998.15 2.00 2.00 0.00 7,022.53 2.00 2.00 0.00 7,098.11 0.00 0.00 0.00 7,198.07 0.00 0.00 0.00 7,298.03 0.00 0.00 0.00 7,394.19 0.00 0.00 0.00 7,397.99 2.00 -1.99 -0.23 7,437.55 2.00 -1.99 -0.23 7,497.97 0.00 0.00 0.00 7,597.96 0.00 0.00 0.00 7,697.95 0.00 0.00 0.00 7,797.94 0.00 0.00 0.00 7,897.93 0.00 0.00 0.00 7,997.91 0.00 0.00 0.00 8,019.13 0.00 0.00 0.00 8,058.11 2.00 -2.00 0.07 8,097.91 2.00 -2.00 0.00 8,160.45 2.00 -2.00 0.00 8,197.86 0.00 0.00 0.00 8,297.80 0.00 0.00 0.00 8,397.73 0.00 0.00 0.00 8,497.66 0.00 0.00 0.00 8,597.60 0.00 0.00 0.00 8,697.53 0.00 0.00 0.00 8,796.17 0.00 0.00 0.00 8,797.47 2.00 2.00 0.01 8,887.58 2.00 2.00 0.01 8,897.45 0.00 0.00 0.00 8,997.44 0.00 0.00 0.00 9,097.44 0.00 0.00 0.00 9,197.44 0.00 0.00 0.00 9,297.44 0.00 0.00 0.00 9,397.43 0.00 0.00 0.00 9,497.43 0.00 0.00 0.00 9,597.43 0.00 0.00 0.00 9,603.68 0.00 0.00 0.00 9,628.57 2.00 -2.00 0.07 4/162019 8:48:32AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 19,000.00 19,100.00 19,200.00 19,300.00 19,400.00 19,500.00 19,600.00 19,687.98 19,700.00 19,732.94 19,800.00 19,900.00 20,000.00 20,100.00 20,200.00 20,251.93 20,300.00 20,332.73 20,350.11 ConocoPhillips Standard Proposal Report OAKEDMPI 90.35 Local Co-ordinate Reference: Well Plan: 2M40 ConocoPhillips Alaska Inc-Kuparuk TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Kuparuk River Unit -2 20,600.00 MD Reference: As Built 36.9+100.7 D19 ® 137.60usft (019) Kuparuk 2M Pad 20,700.00 North Reference: True Plan: 2M40 20,800.00 Survey Calculation Method: Minimum Curvature Plan: 2M-40 20,900.00 90.35 191.72 2M40wp13 21,000.00 90.35 191.72 21,100.00 90.35 191.72 Vertical Vertical Dogleg Build Tum Inclination Azimuth Depth +NIS +El -W Section Rate Rate Rate (°) (1) (usft) (usft) (usft) (usft) (°1100usft) (°1100usft) (°/100usft) 89.28 89.28 89.28 89.28 89.28 89.28 89.28 89.28 89.04 88.39 88.39 88.39 88.39 88.39 88.39 88.39 89.35 90.00 90.35 191.69 191.69 191.69 191.69 191.69 191.69 191.69 191.69 191.67 191.63 191.63 191.63 191.63 191.63 191.63 191.63 191.68 191.72 191.72 20,400.00 90.35 191.72 20,500.00 90.35 191.72 20,600.00 90.35 191.72 20,700.00 90.35 191.72 20,800.00 90.35 191.72 20,900.00 90.35 191.72 21,000.00 90.35 191.72 21,100.00 90.35 191.72 21,200.00 90.35 191.72 21,241.08 90.35 191.72 6,090.49 -7,491.46 -11878.40 9,797.41 6,091.74 -7,589.38 -11898.66 9,89740 6,092.99 -7,687.30 -11,918.91 9,997.39 6,094.24 -7,785.22 -11,939.17 10,097.38 6,095.49 -7,883.14 -11,959.42 10,197.37 6,096.74 -7,981.05 -11,979.68 10,297.36 6,097.99 -8,078.97 -11,999.93 10,397.36 6,099.09 -8,165.13 -12,017.75 10,485.33 6,099.27 -8,176.89 -12,020.19 10,497.35 6,100.00 -8,209.15 -12,026.84 10,530.28 6,101.89 -8,274.81 -12,040.34 10,597.31 6,104.71 -8,372.72 -12,060.49 10,697.27 6,107.52 -8,470.62 -12,080.63 10,797.23 6,110.34 -8,568.53 -12,100.77 10,897.18 6,113.15 -8,666.44 -12,120.91 10,997.14 6,114.61 -8,717.29 -12,131.37 11,049.05 6,115.56 -8,764.36 -12,141.08 11,097.11 6,115.75 -8,796.40 -12,147.72 11,129.84 6,115.70 -8,813.43 -12,151.25 11,147.22 6,115.39 -8,862.27 -12,161.39 11,197.11 6,114.79 -8,960.19 -12,181.70 11,297.10 6,114.18 -9,058.10 -12,202.02 11,397.10 6,113.57 -9,156.01 -12,222.34 11,497.10 6,112.97 -9,253.92 -12,242.65 11,597.09 6,112.36 -9,351.84 -12,262.97 11,697.09 6,111.75 -9,449.75 -12,283.28 11,797.09 6,111.15 -9,547.66 -12,303.60 11,897.09 6,110.54 -9,645.57 -12,323.92 11,997.08 6,110.29 -9,685.80 -12,332.26 12,038.16 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -2.00 -2.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.14 -0.14 0.00 0.00 0.00 0.00 0.00 0.00 0.12 0.12 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4/162019 8:48:32AM Page 9 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Coordinate Reference: Well Plan: 2M40 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Project: Kupamk River Unit -2 MD Reference: As Built 38.9+100.7 D19 @ 137.60usft lot 9) Site: Kuparuk 2M Pad North Reference: True Well: Plaw 2M-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-40 -2,836.57 -10,804.47 Design: 2M-40wpl3 6,035.60 7" x 8-1/2 by 9-7/e" Design Targets Vertical Casing Hole Target Name Depth Diameter Diameter -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W -Shape (°) 2,992.58 (°) (usft) (usft) (usft) 210-40 T01 020818 JM 0.00 0.00 6,035.60 -2,836.57 -10,804.47 - plan hits target center 14,215.20 6,035.60 7" x 8-1/2 by 9-7/e" 7.000 -Circle (radius 1,320.00) 21,241.08 6,110.29 4-1/2x6-1/8 4.500 2M-40702020818 JM 0.00 0.00 6,058.18 -3,735.16 -11,103.01 - plan hits target center - Circle (radius 100.00) 2M-40 T05 020818 JM 0.00 0.00 6,059.09 -5,788.07 -11,526.65 - plan hits target center - Circle (radius 100.00) 2M-40 T04020818 JM 0.00 0.00 6,068.18 -5,137.78 -11,392.71 - plan hits target center - Circle (radius 100.00) 2M-40 T03 020618 JM 0.00 0.00 6,080.00 -4,693.58 -11,300.44 - plan hits target center - Circle (radius 100.00) 210-40 T06 020818 JM 0.00 0.00 6,085.45 -6,600.43 -11,694.32 - plan hits target center - Cimle (radius 100.00) 210-40 T07 020818 JM 0.00 0.00 6,088.18 -7,301.74 -11,839.16 - plan hits target center - Circle (radius 100.00) 2M40 TO8 020818 JM 0.00 0.00 6,099.09 5,165.13 -12,017.75 - plan hits target center - Circle (radius 100.00) 210-40 T10 020818 JM 0.00 0.00 6,110.29 -9,685.80 -12,332.26 - plan hits target center - Circle (radius 1,320.00) 2M-40 T09 020818 JM 0.00 0.00 6,115.75 -8,796.40 -12,147.72 - plan hits target center - Circle (radius 100.00) Casing Points Northing Easting (usft) (usft) Latitude Longitude Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,992.58 2,637.90 13-3/8 x 16 13.375 16.000 13,173.26 5,777.90 9-5/8x12-1/4 9.625 12.250 14,215.20 6,035.60 7" x 8-1/2 by 9-7/e" 7.000 9.875 21,241.08 6,110.29 4-1/2x6-1/8 4.500 6.125 4/182019 8:48:32AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPh i I I i ps Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 2M-40 Company: ConowPhillips Alaska Inc_Kuparuk TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Project: Kuparuk River Unit -2 MD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-40 Base Perm 0.00 Design: 2M-40wpl3 W Bak D 0.00 Formations 2,603.60 Base WS D 0.00 Measured Vertical Dip Depth Depth Vertical Dip Direction (usft) (usft) Name Lithology (1) O 450.64 450.60 T-3 0.00 579.80 579.60 K-15 0.00 1,485.19 1,477.60 Base Perm 0.00 2,061.74 2,011.60 W Bak D 0.00 2,919.89 2,603.60 Base WS D 0.00 4,032.23 2,976.60 Camp SS 0.00 8,019.52 4,175.60 C-50 0.00 9,672.30 4,672.60 C-37 / Top Iceberg 0.00 12,036.73 5,383.60 C-35 0.00 13,167.25 5,775.60 THRZ 0.00 13,544.50 5,918.60 BHRZ/TKLB 0.00 13,713.83 5,971.60 K-1 0.00 14,215.22 6,035.60 Top Kuparuk 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 36.90 36.90 0.00 0.00 KOP: Start -0.73°/100' DLS, 1.51 TF, for 200' 300.00 300.00 0.00 0.00 Start Build 1.50 500.00 499.91 1.79 -4.92 Start 500.00 hold at 500.00 MD 1,000.00 999.22 10.74 -29.51 Start Build 2.50 1,434.00 1,427.90 32.46 -89.17 Start 179.74°/100' DLS, 3.51 TF, for 1455.58' 1,537.00 1,527.90 40.89 -112.34 Start 185.441/100' DLS, 01 TF, for 20' 2,992.58 2,637.90 24.25 -978.59 Start 282.041/100'DLS, 3.31 TF, for 300' 3,012.58 2,646.95 22.19 -996.30 Start 3461.731/100' DLS, 01 TF, for 8900' 3,312.58 2,760.20 -18.24 -1,270.74 Start 4311.94°/100' DLS, 41 TF, for 1264.59' 12,212.58 5,436.48 -1,492.17 -9,629.87 Start 4356.761/100' DLS, 01 TF, for 49.85' 13,477.17 5,893.48 -2,167.35 -10,542.71 Start 4822.691/100' DLS, 41 TF, for 488.2' 13,527.02 5,912.15 -2,208.83 -10,563.12 Start 5020.961/100' DLS, 01 TF, for 200' 14,015.22 6,021.65 -2,647.24 -10,741.57 Start 5040.791/100' DLS, 01 TF, for 20' 14,215.22 6,035.60 -2,836.57 -10,804.47 Start 5134.611/100' DLS, 31 TF, for 94.51' 14,235.22 6,037.00 -2,855.51 -10,810.76 Start 5961.981/100' DLS, 01 TF, for 832.7' 14,329.73 6,041.25 -2,945.09 -10,840.52 Start 6407.731/100' DLS, 21 TF, for 446.57' 15,162.43 6,058.18 -3,735.16 -11,103.01 Start 6805.611/100' DLS, 01 TF, for 398.39' 15,609.00 6,068.33 -4,168.07 -11,210.25 Start 6940.511/100' DLS, 21 TF, for 134.97' 16,007.39 6,078.31 -4,560.94 -11,275.64 Start 7022.5311100' DLS, 21 TF, for 82.03' 16,142.36 6,080.00 -4,693.58 -11,300.44 Start 7394.1911100' DLS, 01 TF, for 371.81' 16,224.39 6,078.83 -4,773.89 -11,317.12 Start 7437.551/100' DLS, 21 TF, for 43.37' 16,596.20 6,068.18 -5,137.78 -11,392.71 Start 8019.131/100' DLS, 01 TF, for 581.65' 16,639.57 6,067.26 -5,180.25 -11,401.49 Start 8058.111/100' DLS, 21 TF, for 38.98' 17,221.22 6,059.36 -5,749.89 -11,518.78 Start 8160.451/100' DLS, 21 TF, for 102.36' 17,260.20 6,059.09 -5,788.07 -11,526.65 Start 8796.171/100' DLS, 01 TF, for 636.14' 17,362.56 6,060.92 -5,888.29 -11,547.33 Start 8887.581/100' DLS, 21 TF, for 91.44' 17,998.70 6,083.64 -6,510.90 -11,675.83 Start 9603.68°/100' DLS, 0' TF, for 716.12' 18,090.14 6,085.45 -6,600.43 -11,694.32 Start 9628.571/100' DLS, 21 TF, for 24.89' 18,806.25 6,088.18 -7,301.74 -11,839.16 Start 10485.331/100' DLS, 01 TF, for 856.84' 18,831.15 6,088.38 -7,326.12 -11,844.20 Start 10530.28°/100' DLS, 21 TF, for 44.96' 19,687.98 6,099.09 -8,165.13 -12,017.75 Start 11049.05'/100' DLS, 01 TF, for 516.99' 19,732.94 6,100.00 -8,209.15 -12,026.84 Start 11129.84'/100' DLS, Y TF, for 80.8' 20,251.93 6,114.61 -8,717.29 -12,131.37 Start 11147.22'/100' DLS, T TF, for 17.39' 20,332.73 6,115.75 -8,796.40 -12,147.72 Start 12038.161/100' DLS, 0' TF, for 890.97' 20,350.11 6,115.70 -8,813.43 -12,151.25 TD: 21241.08' MD, 6110.29' TVD 21,241.08 6,110.29 -9,685.80 -12,332.26 TD at 21241.08 4/162019 8:48:32AM Page 11 COMPASS 5000.14 Build 85D ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 2M Pad Plan: 2M-40 Plan: 2M-40 50103xxxxx00 2M-40wp13 ConocoPhillips Clearance Summary Anticollision Report 16 April, 2019 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M40 - Plan: 2M40 - 2M40wp13 Well Coordinates: Datum Height: As Built 36.9+100.7 D19 @ 137.60usft (D19) Scan Range: 0.00 to 21,242.01 usft. Measured Depth. Scan Radius is 2,320.51 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 86D Scan Type: GLOBAL FILTER APPLIED'. All wellpaths within 200" 100/1000 of reference Scan Type: " "® ConocoPhillips ✓ ConocoPhillips ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 Anticollision Report for Plan: 2M-40 - 2M-40wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M -4D - Plan: 2M-40 - 2M-00wp13 Scan Range: 0.00 to 21,242.01 usft Measured Depth. Scan Radius is 2,32D.51 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2M Pad 2M -01 -2M -01-2M-01 792.61 36.76 792.61 26.69 800.00 3.652 Ellipse Separation Pass - 2M -01 - 2M-01 - 2M-01 892.59 38.18 892.59 26.80 900.00 3.356 Clearance Factor Pass - 2M-02- 2M-02- 2M-02 492.64 24.41 492.64 18.17 500.00 3.913 Ellipse Separation Pass - 2M -02 - 2M-02 - 2M-02 592.33 26.81 592.33 19.27 600.00 3.557 Clearance Factor Pass - 2M -03 -2M -03-2M-03 694.80 81.61 694.80 73.14 700.00 9.636 Ellipse Separation Pass - 2M -03- 2M-03- 2M-03 3,113.84 304.32 3,113.84 260.44 3,000.00 6.935 Clearance Factor Pass - 2M -04- 2M-04- 2M-04 191.60 9.67 191.60 7.30 200.00 4.076 Centre Distance Pass - 2M -04- 2M-04- 2M-04 291.59 10.14 291.59 6.46 300.00 2.761 Ellipse Separation Pass - 2M -04- 2M-04- 2M-04 391.64 13.10 391.64 8.14 400.00 2.638 Clearance Factor Pass - 2M -05 -2M -05-2M-05 191.60 5.81 191.60 3.42 200.00 2.435 Centre Distance Pass - 2M -05- 2M-05- 2M-05 291.59 6.58 291.59 2.90 300.00 1.787 Ellipse Separation Pass - 2M -05 -2M -05-2M-05 391.42 8.43 391.42 3.46 400.00 1.695 Clearance Factor Pass- 2M -O6 -2M -O6 -2M-06 291.60 19.62 291.60 16.21 300.00 5.486 Ellipse Separation Pass - 2M -06 -2M -O6 -2M-06 490.42 26.04 490.42 19.90 500.00 4.239 Clearance Factor Pass - 2M -07 -2M -07-2M-07 291.60 35.05 291.60 31.36 300.00 9.507 Centre Distance Pass - 2M -07 -2M -07-2M-07 390.81 35.93 390.81 30.95 400.00 7.210 Ellipse Separation Pass - 2M -07 -2M -07-2M-07 668.45 48.25 668.45 39.52 700.00 5.524 Clearance Factor Pass- 2M -08 -2M -08-2M-08 389.26 49.48 389.26 44.53 400.00 10.005 Ellipse Separation Pass - 2M -08 - 2M-08 - 2M-08 565.30 64.04 565.30 56.51 600.00 8.499 Clearance Factor Pass - 2M-08 - 2M-0811 - 2M-0811 389.26 49.48 389.26 44.53 400.00 10.005 Ellipse Separation Pass - 2M -08 -2M -081-1-2M-0811 585.30 64.04 585.30 56.51 600.00 8.499 Clearance Factor Pass - 2M-08-2M-081-1-01-2M-OBL7-01 389.26 49.48 369.26 44.53 400.00 10.005 Ellipse Separation Paw - 2M-08-2M-081-1-01-2M-OBL1-01 565.30 64.04 585.30 56.51 600.00 8.499 Clearance Factor Pass - 2M -09- 2M-09- 2M-09 291.58 64.78 291.58 61.17 300.00 17.919 Centre Distance Pass - 2M -09 -2M -09-2M-09 369.96 65.66 389.96 60.75 400.00 13.371 Ellipse Separation Pass - 2M -09 -2M -09-2M-09 565.84 60.79 585.84 73.29 600.00 10.771 Clearance Factor Pass - 2M -09- 2M -09A- 2M -09A 291.58 64.78 291.58 61.17 300.00 17.919 Centre Distance Pass - 2M -09 -2M -09A -2M -09A 389.96 65.66 389.96 60.75 400.00 13.371 Ellipse Separation Pass- 16 April, 2019- 8:33 Page 2 of COMPASS ConocoPhillips Anticollision Report for Plan: 2M-40 - 2M-40wpl3 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M -4D - Plan: 210-40 - 2M-40vry13 Scan Range: 0.00 to 21,242.01 usft. Measured Depth. Scan Radius is 2,320.51 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Measured Minimum @Measuretl Ellipse @Measured Clearance Summary Based on She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2M-09 - 2M -09A- 210-09A 585.64 80.79 585.84 73.29 600.00 10.771 Clearance Factor Pass - 2M-10 - 2M-10 - 21V1-10 189.60 80.65 189.60 78.58 200.00 39.001 Centre Distance Pass - 2M -10 -2M -10-2M-10 289.59 81.40 289.59 78.02 300.00 24.150 Ellipse Separation Pass - 2M -10- 2M-10- 2M-10 1,173.69 138.02 1,173.69 123.12 1,200.00 9.262 Clearance Factor Pass - 2M -11- 2M-11- 2M-11 189.60 105.46 189.60 103.39 200.00 51.003 Centre Distance Pass - 2M -11- 2M-11- 2M-11 387.32 106.74 387.32 102.13 400.00 23.151 Ellipse Separation Pass - 2M -11- 2M-11- 2M-11 1,075.18 144.55 1,075.18 130.90 1,100.00 10.590 Clearance Factor Pass- 210-12 - 2M-12 - 2M-12 290.60 129.71 290.60 126.11 300.00 36.006 Centre Distance Pass - 2M -12 -2M -12-2M-12 387.80 130.42 387.80 125.52 400.00 26.626 Ellipse Separation Pass - 2M -12 -2M -12-2M-12 1,170.92 173.31 1,170.92 158.24 1,200.00 11.501 Clearance Factor Pass - 2M -13- 2M-13- 2M-13 189.60 220.61 189.60 218.54 200.00 106.656 Centre Distance Pass - 2M -13 - 2M-13 - 2M-13 289.60 221.34 289.60 217.97 300.00 65.764 Ellipse Separation Pass - 2M -13 -2M -13-2M-13 1,142.34 328.23 1,142.34 313.24 1,200.00 21.900 Clearance Factor Pass - 2M -27- 2M-27- 2M-27 893.65 37.86 893.65 26.37 900.00 3.293 Clearance Factor Pass - 2M -28-210-28-2M-28 794.42 52.71 794.42 42.66 800.00 5.244 Ellipse Separation Pass - 2M -28- 2M-28- 2M-28 4,335.00 282.72 4,335.00 186.33 4,100.00 2.933 Clearance Factor Pass - 2M -29- 2M-29- 2M-29 496.73 106.75 496.73 100.32 500.00 16.596 Centre Distance Pass - 2M -29-2M-29-210-29 596.62 106.95 596.62 99.22 600.00 13.835 Ellipse Separation Pass - 2M -29- 2M-29- 2M-29 4,333.78 1,045.90 4,333.78 949.66 4,100.00 10.868 Clearance Factor Pass- 2M -30-2M-30-210-30 191.60 124.76 191.60 122.41 200.00 53.060 Centre Distance Pass - 2M -30 -2M -30-2M-30 291.60 124.96 291.60 121.35 300.00 34.630 Ellipse Separation Pass - 2M -30-210-30-2M-30 890.87 184.83 890.87 173.51 900.00 16.327 Clearance Factor Pass - 2M -31-2M-31-210-31 1,700.00 215.73 1,700.00 202.71 1,800.00 16.567 Centre Distance Pass - 2M -31-210-31-2M-31 1,786.88 216.80 1,786.88 201.29 1,900.00 13.973 Ellipse Separation Pass - 2M -31- 2M-31- 2M-31 8,935.17 1,348.83 8,935.17 1,059.61 9,100.00 4.664 Clearance Factor Pass- 2M -32-2M-32-210-32 191.58 156.95 191.58 155.29 200.00 94.292 Ellipse Separation Pass - 2M -32-210-32-2M-32 4,334.58 2,217.71 4,334.58 2,135.74 4,400.00 27.057 Clearance Factor Pass - 2M -32 -2M -321-1-2M-3211 191.58 156.95 191.58 155.29 200.00 94.292 Ellipse Separation Pass - 2M -32 -2M -32L1 -2M-321-1 4,334.58 2,217.71 4,334.58 2,135.74 4,400.00 27.057 Clearance Factor Pass - 2M -32-210-3211-01-2M-3211-01 191.58 156.95 191.58 155.29 200.00 94.292 Ellipse Separation Pass - 2M -32 -2M -321-1-01-2M-3211-01 4,334.58 2,217.71 4,334.58 2,135.74 4,400.00 27.057 Clearance Factor Pass - 16 APNI, 2019 - 8:33 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-40 - 2M-40wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-40 - Plan: 2M40.2M40wp13 Scan Range: 0.00 to 21,242.01 usft. Measured Depth. Scan Radius is 2,320.51 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk W.Sak 16 April. 2019 - 8.33 Page 4 of COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2M -32 -2M -32L1 P131 -2M -32L1 P61 191.58 156.95 191.58 155.29 200.00 94.292 Ellipse Separation Pass - 2M -32-2M-321_1 PB1-2M-32L1 PB1 4,334.58 2,217.71 4,334.58 2,135.74 4,400.00 27.057 Clearance Factor Pass - 2M-32-2M-32Li PB2-2M-32L1 PB2 191.58 156.95 191.58 155.29 200.00 94.292 Ellipse Separation Pass - 2M -32 -2M -32L1 PB2-2M-32L1 PB2 4,334.56 2,217.71 4,334.58 2,135.74 4,400.00 27.057 Clearance Factor Pass - 2M -33 -2M -33-2M-33 1,137.01 223.29 1,137.01 212.50 1,200.00 20.700 Ellipse Separation Pass - 2M -33 -2M -33-2M-33 20,417.15 1,579.83 20,417.15 1,150.43 16,340.00 3.679 Clearance Factor Pass - 2M -36- 2M-36- 2M-36 799.88 74.26 799.88 69.81 800.00 16.667 Ellipse Separation Pass - 2M -36- 2M-36- 2M-36 4,371.22 920.62 4,371.22 850.33 4,600.00 13.097 Clearance Factor Pass - 2M -36- 2M-36PB1- 2M-36PB1 799.88 74.26 799.88 69.68 800.00 16.193 Ellipse Separation Pass - 2M -36- 2M-36PB1- 2M-36PB1 4,364.47 932.45 4,364.47 864.19 4,600.00 13.662 Clearance Factor Pass - 2M -37 -2M -37-2M-37 107.87 173.82 107.87 171.31 100.00 69.141 Ellipse Separation Pass - 2M -37 -2M -37-2M-37 12,300.00 2,272.86 12,300.00 2,038.40 12,600.00 9.694 Clearance Factor Pass- 2M -38 -2M -38-2M-38 11,744.58 389.12 11,744.58 191.10 12,400.00 1.965 Clearance Factor Pass - 2M -38 -2M -38-2M-38 13,014.57 254.89 13,014.57 183.93 13,600.00 3.592 Centre Distance Pass - 2M -38 -2M -38-2M-38 13,159.29 272.15 13,159.29 155.11 13,800.00 2.325 Ellipse Separation Pass - Plan: 2M -39 -Plan: 2M-39-2M-39wp16 1,191.50 49.91 1,191.50 42.62 1,200.00 6.842 Ellipse Separation Pass - Plan :2M -39 -Plan : 2M-39-2M-39wp16 7,954.58 314.67 7,954.58 194.63 8,100.00 2.622 Clearance Factor Pass - Kuparuk W.Sak 16 April. 2019 - 8.33 Page 4 of COMPASS ConocoPhillips Anticollision Report for Plan: 2M-40 - 2M-40wp13 Survey tool program ConocoPhillips Alaska Inc_Kuparuk From To Survey/Plan Survey Tool (usft) (usft) 36.90 1,500.00 2M-40wp13 GYD-GC-SS 1,500.00 2,500.00 2M-40wp13 MWD 1,500.00 2,992.58 2M-40Wp13 MWD+IFR-AK-CAZSC 2,992.58 4,492.58 2M40wp13 MWD 2,992.58 13,173.26 2M40Wp13 MWD+IFR-AK-CAZSC 13,173.26 14,215.20 2M40Wp13 MWD 13,173.26 14,215.20 2M40wp13 MWD+IFR-AK-CAZSC 14,215.20 18,680.00 2M-40wp13 MWD 14,215.20 21,241.08 2M-40wpl3 MWD+IFR-AK-CAZSC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Kuparuk River Unit -2 16 April, 2019 - 8,33 Page 5 of 7 COMPASS 8," dl 16 2019 2M-40wp13 Ladder View a C? 300 n Imo_ ` m _ I J YI M a� y 150 N U v it W Equivalent Magnetic Distance 0 n 0 850 1700 2550 3400 4250 5100 5950 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 36.90 1500.00 2M-40wp13 (Plan: 2M-40) GYD-GC-SS 2637.90 2992.58 13-3/8 x 16 1500.00 2500.00 2M-40wp13 (Plan: 2M-40) MWD 5777.9013173.26 9-5/8 x 12-1/4 1500.00 2992.58 2M-40wp13 (Plan: 2M-40) MWD+IFR-AK-CAZ-SC 6035.6014215.29 x 8-1/2 by 9-7/8" 2992.58 4492.58 2M-40wp13 (Plan: 2M-40) MWD 6110.271241.08 4-1/2 x 6-1/8 2992.5813173.26 2M-40wp13 (Plan: 2M-40) MWD+IFR-AK-CAZ-SC 13173.2614215.20 2M-40wp13 (Plan: 2M-40) MWD 14215.2018680.00 2M-40wp13 (Plan: 2M-40) MWD 14215.2021241.08 2M-40wp13 (Plan: 2M-40) MWD+IFR-AK-CAZ-SC b 0 C 0 30 � o t0 � o C Ol U 4 Equivalent Magnetic Dista e m m 0 U 350 700 1050 1400 1750 Partial Measured Depth 2M-40wp13 From To Tool 36.90 1500.00 GYD-GC-SS 1500.00 2500.00 MWD 1500.00 2992.58 MWD+IFR-AK-CAZ-SC 2992.58 4492.58 MWD 2992.593173.26 MWD+IFR-AK-CAZ-SC 13173.294215.20 MWD 13173.294215.20 MWD+IFR-AK-CAZ-SC 14215.208680.00 MWD 14215.2@1241.08 MWD+IFR-AK-CAZ-SC TVD MD Name 2637.902992.58 13-3/8 x 16 5777.903173.26 9-5/8 x 12-1/4 6035.604215.70 x 8-1/2 by 9-7/8" 6110.221241.08 4-1/2 x 6-1/8 MD Inc Azi TVD 36.90 0.00 0.00 36.90 300.00 0.00 0.00 300.00 500.00 3.00 290.00 499.91 1000.00 3.00 290.00 999.22 1434.00 13.85 290.00 1427.90 1537.00 13.85 290.00 1527.90 2992.58 63.10 263.35 2637.90 3012.58 63.10 263.35 2646.95 3312.58 72.50 260.00 2760.20 12212.58 72.50 260.00 5436.48 13477.17 68.01 206.20 5893.48 13527.02 68.01 206.20 5912.15 14015.22 86.00 198.38 6021.65 14215.22 86.00 198.38 6035.60 14235.22 86.00 198.38 6037.00 14329.73 88.84 198.38 6041.25 15162.43 88.84 198.38 6058.18 15608.99 88.56 189.45 6068.33 16007.39 88.56 189.45 6078.31 16142.36 90.00 191.74 6080.00 16224.39 91.64 191.74 6078.83 16596.20 91.64 191.74 6068.18 16639.57 90.78 191.63 6067.26 17221.22 90.78 191.63 6059.36 17260.20 90.00 191.66 6059.09 17362.56 87.95 191.66 6060.92 17998.70 87.95 191.66 6083.64 18090.13 89.78 191.67 6085.45 18806.25 89.78 191.67 6088.18 18831.15 89.28 191.69 6088.38 19687.98 89.28 191.69 6099.09 19732.94 88.39 191.63 6100.00 20251.93 88.39 191.63 6114.61 20332.73 90.00 191.72 6115.75 TC View Dleg TFace Target 0.00 0.00 0.00 0.00 1.50 290.00 0.00 0.00 2.50 0.00 0.00 0.00 3.50 -31.00 0.00 0.00 3.30 -18.95 0.00 0.00 4.00 -104.43 0.00 0.00 4.00 -23.98 0.00 0.00 2M-40 T01 020818 JM 0.00 0.00 3.00 0.00 0.00 0.00 2M-40 T02 020818 JM 2.00 -91.83 0.00 0.00 2.00 57.90 2M-40 T03 020818 JM 2.00 0.00 0.00 0.00 2M40 T04 020818 JM 2.00 -173.30 0.00 0.00 2.00 177.94 2W40 T05 020818 JM 2.00 -179.99 0.00 0.00 2.00 0.26 2M-40 T06 020818 JM 0.00 0.00 2M-40 T07 020818 JM 2.00 178.00 0.00 0.00 2M-40 T08 020818 JM 2.00 -176.05 0.00 0.00 2.00 3.44 2W40 T09 020818 JM Annotation KOP: Start -0.73°/100' DLS, 1.5° TF, for 200' Start Build 1.50 Stan 500.00 hold at 500.00 MD Stan Build 2.50 Start 179.74'/100' DLS, 3.5° TF, for 1455.58' Start 185.44°/100' DLS, 0° TF, for 20' Start 282.04°/100' DLS, 3.3° TF, for 300' Start 3461.73°/100' DLS, 0° TF, for 8900' Stan 4311.94°/100' DLS, 4° TF, for 1264.59' Stan 4356.76°/100' DLS, 0° TF, for 49.85' Stan 4822.69'/100' DLS, 4- TF, for 488.2' Start 5020.96°/100' DLS, 0° TF, for 200' Stan 5040.79'/100' DLS, 0' TF, for 20' Start 5134.61.1100' DLS, 3° TF, for 94.51' Stan 5961.98°/100' DLS, 0° TF, for 832.7' Start 6407.73°/100' DLS, 2° TF, for 446.5T Start 6805.61 °/100' DLS, 0° TF, for 398.39' Start 6940.51 °/100' DLS, 2" TF, for 134.97' Start 7022.53°/100' DLS, 2° TF, for 82.03' Stan 7394.19°/100' DLS, 0° TF, for 371.81' Start 7437.55°/100' DLS, 2° TF, for 43.37 Start 8019.13°1100' DLS, 0° TF, for 581.65' Start 8058.11'/100' DLS, 2- TF, for 38.98' Start 8160.45°/100' DLS, 2° TF, for 102.36' Start 8796.17°1100' DLS, 0° TF, for 636.14' Start 8887.58.1100' DLS, 2- TF, for 91.44' Start 9603.68°/100' DLS, 0° TF, for 716.12' Stan 9628.57°/100' DLS, 2- TF, for 24.89' Stan 10485.33°/100' DLS, 0° TF, for 856.84' Start 10530.28°/100' DLS, 2° TF, for 44.96' Start 11049.05.1100' DLS, 0° TF, for 518.99 Start 11129.84°/100' DLS, 2° TF, for 80.8' Start 11147.22"1100' DLS, 2" TF, for 17.39' Start 12038.16°/100' DLS, 0° TF, for 890.9T 08 37 298 298 -488 488 -668 668-858 3228 858 - 1038 1038- 1228 1 1228 - 1408 1 1408 - 1598 1598 - 2408 2408 3228 3228 - 4038 Q�kk>Qf:II>• 4848 - 5658 1 5658 - 6468 6468 - 7288 7288 - 8098 8098 - 9738 9738 - 11388 11388 13028 13028 - 14668 14668 - 16318 16318 17958 17958 - 19598 19598 - 212421 i 0 o� Q m o p W o M o o O p M O O •- aJ NO O Cp0 r� O6 p ol Ob 0 QS QO�S O Po o � N N •Q N CN o o M M O N yo N N N o Lp r _... 0 g c O M M N M og N M 6 O N (0 w a g N v N (O 6 3 IM M r Q. O N F p (uy4sn 000£) 6wyljoN N ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 2M Pad Plan: 2M-40 50103xxxxx00 Plan: 2M-40 Plan: 2M-40wp13 Error Ellipse Survey Report 16 April, 2019 Company: ConocoPhillips Alaska lnc_Kupawk Project: Kupamk River Unit _2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M-40 Design: 2M-40wp13 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-40 As Built 36.9+100.7 D19 @ 137.e0usft (D19) As Built 36.9+100.7 019 @ 137.60usft (D19) 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 Kupamk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10, well Plan: 2M-40 Well Position +NIS 0.00 usft Northing: Latitude: Version: +EAW 0.00 usft Easting: Longitude: Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: Ground Level: 100.70 usft Wellbore Plan: 2M-40 Magnetics Model Name Sample. Date Declination Dip Angle Field Strength (1) 0 (nn BGGM2018 5/1/2019 16.49 80.79 57,404 Design 2M-40wp13 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.90 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction (usft) (usft) (usft) 36.90 0.00 0 00 92.2. 00 ' Survey Tool Program Date 4/18/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 36.90 1,500.00 2M-40wp13 (Pian. 2M40) GYD-GC-SS Gyrodata gyro single shots 1,500.00 2,500.00 2M-40wp13(Plan: 2M-40) MWD MWD - Standard 1,500.00 2,992.58 2M-40wp13(Plan: 2M40) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2,992.58 4,492.58 2M-40wp13(Plan: 2M-40) MWD MWD -Standard 2,992.58 13,173.26 2M-40wp13(Plan: 2M40) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 13,173.26 14,215.20 2M-4Uwp13(Plan: 2M-40) MWD MWD - Standard 13,173.26 14,215.20 2M40wp13(Plan: 2M-40) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 14,215.20 18,680.00 2M-40wp13(Plan: 2M-40) MWD MWD -Standard 14,215.20 21,241.08 2M40wp13(Plan: 2M-40) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/16/2019 8.49:34AM Page 2 COMPASS 5000.14 Build 85D Company: Con=Phillips Alaska lnc_Kupamk Project Kuparuk River Unit -2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M40 Design: 2M40wp13 Plan Survey Tool Program Date 4/16/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 36.90 1,500.00 2M-40wpl3 (Plan, 2M-40) 2 1,500.00 2,500.00 2M-40Wp13 (Plan: 2M-40) 3 1,500.00 2,992.58 2M-40wpl 3 (Plan: 2M-00) 4 2,992.58 4,492.58 2M-40wpl3 (Plan: 2M40) 5 2,992.58 13,173.26 2M40wpl3 (Plan: 2M-40) 6 13,173.26 14,215.20 2M40wp13(Plan: 2M40) 7 13,173.26 14,215.20 2M40wpl3 (Plan: 2M40) 8 14,215.20 18,680.00 2M40wpl 3(Plan: 2M40) 9 14,215.20 21,241.08 2M-40wpl3 (Plan: 2M-00) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MVJD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 2M-40 As Built 36.9+100.7 D79 @ 137.60usft (D79) As Built 36.9+100.7 D79 @ 137.60usft (D79) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inclination A imwh Vertical NI90slde Labral Vertical Magneude 3eml+rw)or Samlmmw Depth Depth E. Bias Error Bias Enor Biu orales Error Evor Aa,.0 Tod (usft) 1') (1) (usft) (ltsftl (usft) (.11) (usft) (.n) (usft) (use) (..ft) Nsft) (9 3690 000 0.00 36.90 0.00 000 000 000 000 0.00 0.00 0.00 0.00 0.00 UNDEFINED 10000 0.00 0.00 100.00 0.00 000 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 20000 000 0.00 200.00 0.14 0.00 0.14 0.00 2.30 0.00 0.00 0.14 0.14 0.00 GYD-GC-W(1, 1) 300.00 0.00 0.00 300.00 0.43 0.00 0.43 0.00 2.30 0.00 0.00 043 0.43 0.00 GYD.GGSS D. 1) 400,0 1.50 290.00 399.99 0.69 0.00 0.69 0.00 2.30 0.01 0.01 0.69 0.69 45.00 GYD-GGSS (1, 1) 50000 300 280.00 499.91 0.94 0.00 0.93 0.00 2.30 0.02 0.02 0.94 0.93 19.52 GYD-GCSS(1. 1) 600.00 3.00 290.00 59sn 1.20 0.00 1.20 0.00 2.30 0.03 0.03 1.21 1.20 MCI GYD-GGSS(1. 1) 700.00 3.00 290.00 699.63 1.48 0.00 1.49 0.00 2.31 0.04 0.% 1.49 1.48 111.69 GYD-GC-W(1, 1) 800.00 3.00 290.00 799.50 1.76 0.00 1.77 0.00 2.32 0.06 0.00 1.77 1J6 110.69 GYD-GG55(1. 1) 900,0 3.00 290.00 899.35 2.% 0.00 2.08 0.00 2.32 0.08 0.00 2.06 2.05 110.,16 GYD.GGSS(1, 1) 1,000.00 100 290.00 999.22 2.33 0.00 2.35 0.00 2.33 0.10 0.10 2.35 2.33 110.35 GyD.GOSS(1. 1) 11100.00 5.50 290.00 1,098.% 2.61 -0.01 2.85 0.00 2.34 0.12 0.12 2.65 2.62 110.33 GYD.GGSS(1, 1) 1.200.00 8.00 280.00 1.198.24 2.90 .0.01 2.96 0.00 2.34 0.15 0.15 2.98 2.92 110.35 GYD-GC-W(1, 1) 1.300.00 10.50 290.00 1,296.93 3.19 -0.02 3.28 0.00 2.34 0.18 0.18 3.28 3.23 110.36 GYD-GGSS n. 1) 1,400.00 13.00 290.00 1,394.83 3.47 -0.03 3.63 0.00 2.34 0.21 0.21 3.63 3.53 110.& GYD4C.SS(1, 1) 1,434.00 13.85 290.00 1,427.90 3.57 .0.03 3.75 0.00 2.34 0.22 0.22 3.75 3.65 110.34 GYD-G(>SS(1. 1) 1,500.00 13.85 290.00 1,491.90 3.78 -0.03 3.89 0.00 2.35 0.25 0.25 3.89 3.85 110.30 GYD.GGSS n. 1) 1,537.00 13.85 290.00 1.527.90 3.83 .0.03 4.07 -0.01 2.35 0.26 am 4.07 3.91 110.28 MMM. 2) 4/18/2019 8:49:34AM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kupawk Project: Kupamk River Unit_2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M-40 Design: 2M-40wp13 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: 2M40 As Built 36.9+100.7 019 @ 137.60usft (D19) As Built 36.9+100.7 019 @ 137.60usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Measures Indma0nn Aa0nutb him"l Ki9bs,d. Wand Venlcat Magnitude Semima7or Semi+ninar Depth Oeptn Error Bias Emr Bias Ertl alas of Blas Error E., Aa9nuM TDM loan) r) 11) (usm loan) loan) lush) Nan) (ass) (usn) (ush) 01an1 (iso) (1) 1,600.00 15,78 28582 1,58081 3.62 -0.04 4.11 -0.03 2.35 028 029 4.11 992 11009 MWD(1, 2) 1,700.00 18,88 280,94 1.604,24 3.81 -0.05 4.36 -0.07 2.34 0.32 0.33 4.36 3.96 107,23 IAM (1. 2) 1,000.00 22.24 277.43 1,777.83 3.82 -0,08 4.07 .0.14 2.33 0.36 0.39 4.88 4.04 103.73 MM (1. 2) 1,900.00 25.57 274.79 1,889.24 3,08 -0.08 5.68 -0.23 2.32 0.40 0,47 5,70 4.15 100.87 MWD (1, 2) 2,000.00 28,94 272.72 1,958.13 3.93 -0.10 6.80 -0.34 2132 0,44 0.57 6.82 4.30 98,62 MWD (1, 2) 2,100,00 32.34 27106 2,0a4.15 4.04 4.11 8.19 -0.49 2.35 0.48 0.70 8,22 4.47 %.00 mm (1. 2) 2,20000 35.75 269.68 2,12700 4.20 -0.13 9.83 -0.65 2.40 0.52 0.86 9.07 4.67 95.29 MM (1. 2) 2,300,00 39.18 268,51 2,206.30 4.40 4.15 11,70 -0.85 2.50 a% 1.05 11.75 4.90 84.00 MM(1.2) 2.400.00 42.62 267.50 2,281.93 4.64 -0.18 13,78 -1.08 265 0.60 1.27 13.03 5.14 92.89 MWD (1, 2) 2,500.00 46.06 265.62 2,353.44 4.92 A21 16.03 -1.34 2.06 0.63 1.53 18.09 5.40 91.91 MWD(1, 2) 2,600.00 49.52 265,83 2.420.62 3.91 4.32 8.59 0,04 245 0.67 0.73 8.60 4.90 89,03 MM IFR-N(-CAZSC (2,2) 2.700.00 52.97 205.12 2,483.21 3.98 -0.36 9.52 0.04 2,55 030 0.77 9.54 5.03 80,31 MWD+IFR-AR-CAZSC (2, 2) 2,800.00 56,43 26447 2,510.90 4.08 -0.40 10.50 0.04 231 0.73 0.82 10.52 5.16 8269 MMAFR-AR-CA SC (2.2) 2.900.00 59.89 263.87 2,593.73 4.15 -0.45 11.52 0.05 2.00 0.76 0.06 11.53 5.28 87.16 MWD+IFR-AK-CAZ-SC (2, 2) 2,992.68 63.10 263.35 2,637.90 4.25 -0.49 12.48 0.05 3,06 0.78 0.90 12.49 5.38 W.72 MWD+IFR-AK-CAZSC(2,2) 3,000.00 63.10 263.35 2,641.26 4.26 -0.49 12.55 ON 2.93 0,78 0.91 12.57 5.54 86.82 MWD(2.3) 3,012.58 63,10 263.35 2,616.95 4.26 -0.49 12.68 -0.02 2.93 0.78 0.91 12.69 5.54 86,80 MM(2,3) 3,10000 65.03 262.33 2,684.63 4.17 -0,53 13.02 .0.30 2.98 0.80 1.02 13,85 5.57 86.46 MWD (2.3) 3,20000 68.97 261.21 2,723.05 4.17 -0.57 15.61 -O.n 3.15 0,82 1.29 15.66 5.62 85.77 FAM (2,3) 3,3013.00 72,10 260.13 2,756.37 4.29 -0.61 17.00 .1.27 3.44 0.84 1.65 17.85 5,88 04.94 MM (2.3) 3,312.58 72.50 260.00 2)60.20 4,31 -081 18.09 -1.32 3.48 0.84 1.69 10,15 530 84.84 FAM (2,3) 3.400.00 72.50 260.00 2,786.48 4,65 -0.61 20.20 -1.73 3,84 0.05 2.05 20.33 5.75 84.15 MM (2.3) 3.500.00 72.50 260.00 2,016.55 5,10 -0,61 22.95 -2.20 4.33 0.87 2.48 2299 5.01 03.51 MM (2,3) 3,6aaeo 72.50 260.00 2.046.63 5,60 -0,61 25.74 -2.67 4.85 0.88 2,92 25,76 5.08 83.00 FAM (2,3) 3,700.00 72.50 280.00 2,876]0 6A5 -0.61 20.62 .3.14 5.41 0,90 3.37 28.65 5.96 82.81 MM (2.3) 3,800.00 72,50 260.00 2,906]7 632 -0.81 31,56 .3.61 6.00 0.91 3.82 31,59 6.04 0229 IAM (2,3) 3,90000 72.50 260.00 2,936.84 7,31 -0,61 34.55 -4.08 6.59 0.93 4.28 34.57 6.13 82.03 MWD(2, 3) 4,00000 72,50 260.00 2,966al 7.93 -0,61 37.58 -4.55 7.21 0.95 435 37,60 au 01.02 MM (2. 3) 4,100.00 72.50 260.00 2,996.98 9,55 -0,61 40.63 -5.02 7.83 0.96 5.21 40.65 6.31 01.65 MWD (2.3) 4,20000 72,50 260.00 3,027.05 9.19 -0.61 43.70 -5.49 8.46 0.98 5.67 43.72 642 81.50 MWD (2.3) 4.300.00 72.50 260.00 3,057.12 9.84 -0,61 45.00 .5.95 9.09 1.00 6.14 46,01 6.52 01.37 MWD (2.3) 4,400.00 72.50 260.00 3,087.19 10,49 -0.81 49.90 -6.42 9.73 1.01 6.61 49.91 6.64 81.26 MM (2.3) 4.500.00 72.50 260.00 3,117.26 6.44 -0.82 23,88 0.08 5.76 1.03 1.58 23all 8,09 02.46 FAM+IFR-AK-CAZ-SC(3,3) 4.600.00 72.50 260.00 3,147.33 873 -0,82 24.00 ON 6.05 1.05 1.63 Use 6.14 82.20 MWD+IFR-AK-CA2-SC(3.3) 4,700.00 72.50 260.00 3,177.40 7.02 -0.62 25.91 0.08 6.35 1.06 1.69 25.92 6.19 82.11 MWD+IFR-AK-CP -SC (3.3) 4,800.00 72.50 200,00 3,207.47 7.32 -0.62 25.84 am 6.65 1.08 1.74 26,98 6.24 01.97 MMAFR-ML -SC (3,3) 4,900.00 72.50 260.00 3,237.54 7.63 -0.82 27.99 0.08 6.95 1.10 1.60 28.01 6.30 01.03 MWD+IFR-AK-CAZ-SC(3.3) 5,000.00 72.50 260.00 3,267.61 7.93 -0.62 29.05 a00 7.26 1.12 1.86 29.06 6.35 01,71 MWD+IFR-AK-0AZ-SC(3,3) 5,10000 72.50 260.00 3,297.68 8.25 -0.82 30.12 0.00 7.57 1.14 1.91 30,13 641 01.60 MWD+IFR-MC-SC (3,3) 6250.00 72.50 26000 3,327.75 6.58 .0.62 31.19 0.00 7.88 1.16 1.97 3110 6.47 81.49 MWD+IFR-AK-0AZ-8C(3,3) 5,300.00 72.50 280.00 3.457.93 8.80 -0.62 32.27 0.00 0.20 1.18 2.03 32.28 6.52 81,40 MWD+IFR-ML-SC (3,3) 5,400,00 72,50 260.00 3,387.90 9.20 -0.02 33.36 0.08 8.51 1.20 2.10 33,37 6.58 81.31 MWD+IFR-AR-CAZ-SC(3.3) 5,500.00 7250 Mae 3,417.97 9.52 -0.62 34.45 0.00 8.83 1.24 2.16 34.46 6,64 81,23 MMAFR-AK-CA2-SC(3,3) 5,600,00 72.50 260.00 3,448.04 a" .0.82 35.55 0.08 9.14 1,23 222 35.55 631 81.15 MWD+IFR-AR-CAZSC (3,3) 5,700.00 72.50 260.00 3.478,11 10.17 .0.62 36.65 0.08 a,16 1.25 2.29 WAS 6.77 81.08 MWD+IFR-MK CA 4C (3.3) 5,000.00 72.50 2 go 3,500.10 10.49 -0.82 37.75 0.08 938 118 2.35 3738 6.84 81,02 IAMAFR-AK-CAZ-SC (3,3) 51900,00 72,50 26000 3,530.25 10.82 .0.82 30.06 0.00 10.10 1.30 2.42 38,87 690 80.96 MWD+IFR-AR-CAZSC(3,3) 6,000.00 72.50 280.00 3,560.32 11.15 -0.62 39.97 0.00 10.43 1.32 2.48 39.98 6,97 80,90 MMAM-AK-CALSC(a3) 610000 72.50 280.00 3,590.39 11.48 -0.62 41.09 0.08 10.75 1.34 2.55 41,09 7.04 80.05 MWD+IFR-N(-CAZ-9C(3,3) 6200.00 72.50 260.00 3.62846 11.02 -0.62 42.21 0.00 11.07 1.36 2.62 42.21 7.11 Wal) MWD+IFR-AK-CAZSC(3.3) 6.300.00 72.50 280,00 3.650.53 12.15 -0.62 43,33 0.00 11.40 1.38 2.69 43.33 7,18 00.75 KIMAFR-AK-CAZ-SC (3.3) 6,400.00 72.50 260.00 3,680,60 12.48 -0.82 44.45 0.00 11.72 140 2.76 44+45 225 8031 MM+IFR-N(-CAZSC(3,3) 6,500.00 72.50 280.00 3,710.67 12.02 4.62 45.58 0.00 12.05 1,42 2.03 45.58 7,32 80,66 MWD+IFR-AK-CAZ-SC(3, 3) 6600.00 72.50 260.00 3,74834 13.16 4.62 4630 0.08 12.37 1.45 2.90 45,71 740 81 MM+IFR-AR-CAZSC(3, 3) 4/162019 8,49 34AM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kupawk Project: Kuparuk River Unit_2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M-40 Design: 2M-40wp13 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 emore are at Database: Well Plan: 210-40 As Built 36.9+100.7 D19 @ 137.60usft (D19) As Built 36.9+100.7 D19 @ 137.60usft (D79) True Minimum Curvature 2.00 sigma OAKEDMPI Measur Incim"On Azimmh Vem.1 Rigirsiae Lateral vent.) Magnit ft Semi+na)Or semiminor onan Depth Evor eka Error Bus Error 81a5 or Rias Eno, E., Azimuth Tool (.ft) (1 PI (oan) lush) tua) (.ftJ (am) IoM) (mft) (oan) (um) (use) PI 6.700,00 72,50 260.00 3,778.81 1349 -0.82 47.63 0.08 12.70 1.47 2.98 47.84 7.47 80.59 MW AFR-AK-CA2-3C(3. 3) 8.60000 72.50 280.00 3,808.80 13.03 -0.62 48.97 cW 13.03 1.49 3.05 48.97 7,55 80.55 MMAFR-AK-CAZSC(3, 3) 6,900.00 72.50 280.00 3,038.95 14.17 -0.62 50,10 0.08 13,35 1.51 3.13 50.10 7.62 80.52 MMAFR-M-GA-W(3, 3) 7,00090 72,50 260,00 3.869,03 14.51 -0.62 51.23 0.08 13.68 1.54 3.20 51.24 7.70 80.49 MWD+IFR-AK-CA-SC(3,3) 7,100.00 72.50 Mae 3,899.10 14.85 4.62 52.37 0.08 14.01 1.55 3.28 52.37 7.78 00.46 MM -IFR -AK -CA -SC (3, 3) 7,200.00 72.50 260.00 3,929.17 15.19 4).62 53.51 0,08 14.34 159 336 53.51 7.86 80.43 MM -IFR -AK -CA -SG (3, 3) 7,300.00 72.50 260.00 3.959.24 15.53 -0.62 54.85 0,08 14.66 161 3,43 54.65 7.94 60.41 MMID+IFR MAK -SC (3,3) 7,400.00 72.50 26000 3,989,31 15.87 4.62 55]9 0.08 14.99 1.63 3.51 55.79 8.02 80,38 MWDHFR-AK-CA -SC (3,3) 7,500.00 72.50 260.00 4,019.38 16.21 4.62 56.93 0.08 15.32 1.86 3.59 56.93 8.10 80.36 MWWIFR-AK-CA-SC(3.3) 7,600.00 72.50 260.00 4.049.45 16,55 .0.62 58.07 0.08 15.65 1.68 3.67 50.07 8.18 80.34 MWWIFR-AK-0A2-SC(3,31 7,700.00 72.50 260.00 4,079.52 16.89 -0.82 59.21 0.00 15.98 1.71 3.76 5921 8.27 80.31 MWD+IFR-AK-CA-SC (3.3) 7,800.00 72.50 260.03 4,109.59 17.23 -0.62 60.36 0.08 16.31 1.73 3.81 00.36 8.35 80.29 MWD+IFR-AK-CA -SC (3, 3) 7,900.00 72.50 260.00 4,139.66 17.58 -082 81,50 0.08 16.64 1.76 3.92 61.50 0.43 80.27 MM+1FR-AK-CA -SC (3, 3) 8.000,00 72sO 280.00 4,169.73 17.02 -0.62 62.65 0.08 16.97 1.78 4.01 62.65 8.52 00.25 MWD+IFR-W-CA-SC(3,3) 8,10Oo0 72.50 260.00 4,199.80 18.26 -0.62 63,79 0,08 17,30 1.01 4.09 63.79 8.61 00.24 MM -IFR -M- -SC(3,3) 8,200.00 72,50 260.00 4.229.87 18.61 -062 64.94 0.08 17.63 1.84 4.18 64.94 8,69 00.22 MWD+IFR-M-0A 40(3,3) 8,300.00 72,50 280.00 4,259.94 18.95 4).62 66.09 0.08 17.96 1.85 4.26 0.09 &78 80.20 MMAFR-MC -SC (3,3) 4400.00 72.50 260.00 4,29091 19.29 4).62 67.24 0.08 18129 1.89 4.35 67.24 &87 80.19 MM+IFR-AK-CAZSC(3,3) 8.500.00 72.50 260,00 1,320.08 19,64 4.62 60.39 0.08 18.62 1.92 4.44 68.39 8.95 60.17 MMAFR-AK4SC(43) 4eM,00 72.50 260.00 4,350.15 1998 4).62 69.54 0.08 18.98 1.94 4,53 69.54 9.00 WAS MWD+IFR-AK-CA-SC(3,3) 8,70090 72.50 260.00 4.380.23 20.33 4.62 70.69 0.08 19.29 1.97 4.62 70.69 9.13 80.14 MWD+IFR-AK-CAZ C(3.3) 8,800.00 72.50 28000 4,410,30 20.67 4).62 71.84 008 19.62 2.00 4.71 71,84 9.22 6013 MM+IFR4K-CA 4;C(3,3) 490(1,00 72.W 280.00 4,440.37 21.02 4.62 72.99 0.08 19.95 2,03 4.80 72,99 9.31 80.11 MM iAFR-AK-CA-SC(3,3) 9,000.00 72.0 260.00 4,470.44 21.36 4.62 74.15 0.08 20.28 2,05 4.90 74.15 9.40 80.10 MWD+IFR-AK-CA2-SC(3,3) 9,100.00 72.50 2W,00 4,50,51 21.71 4.62 75.30 0.08 20.61 2.08 4.99 75.30 9.50 80.09 MWD+IFR-AK-CA-SC (3,3) 9,200.00 72.W 260.00 4,530.50 22.05 -0.62 76.45 0.08 20.94 2.11 5.08 76.45 9.59 80.00 MW IFR -M -C -SC (3,3) 9,300.00 72.0 2W.00 4,560.65 22.40 .0.62 2..61 0.08 21.28 2.14 5.18 77.61 9.68 80.W MWD+)FR-AK-CA-SC (3,3) 9,400.00 72.W 2W.W 4,590.72 22.75 4.62 78.76 0.00 21.61 2.17 5.27 78.76 9.77 80.05 MW IFR -AK -CA -SC (3,3) 9,500.00 72.50 260.00 4,620.79 23,09 -0.82 79.91 cW 21.94 2.20 5.37 79.91 9.87 80.04 MWWIFR-AK-CA2-SC(3,3) 9,600.00 72.W 260.00 4,650.88 23.44 -0.62 81.07 0.08 22.27 2.23 5.47 81.07 aw 80.03 MMAFR-AK-CA-SC (3,3) 9,700.00 72.W 260.00 4.680.93 23.79 -0.62 62.23 0,08 22.80 2.28 5.57 82.23 10.06 80.02 MM IFR -AK -CA -SC (3,3) 9,800.00 72.511 2W.00 4.711.00 24,13 .0.62 83,38 0.00 22.94 2.29 5.67 83.30 10.15 80.01 MW IFR -AK -CA -SC (3.3) 9,900.00 72,W 260.00 4,741.07 24.48 -0.62 84.54 0.08 2127 2.32 5.77 84.54 10.25 80.00 MW IFR -AK -CA -SC (3,3) 10000.00 72.W 260.00 4.771.14 24.83 .0.62 Ilsso 0.08 23.60 2.35 5.07 85.69 10.34 79.99 MWDHFR-AK-CA-SC (3,3) 10,100.50 72.W 20,00 4.801.21 25.17 .0.62 8695 0.00 23.93 2.38 5.50 86.85 1444 7sW MW IFR -AK -CA -SC (3,3) 10,200.00 72.0 260.00 4,831.20 25.52 -0.62 88.01 cm 24,27 2,41 6.07 66.01 10.53 79.98 MM IFR -AK -CA -SC (3,3) 10,300.00 72.W 260.00 4.861.35 25.87 -0.62 89.17 0.08 24.60 2.14 6.18 89.17 10.63 79.97 MWWIFR-AK-CA-SC(3,3) 10,600.00 72.0 20,00 4891.42 26.21 .0.62 90.32 0.00 24.93 2.47 6.28 9032 10.73 7986 MW IFR -AK -CA -SC (3,3) 10,500.0 72.W 260.00 4,921.50 26.0 4).62 91.48 0.06 25.27 2.50 8.30 91.40 10.82 79.95 MM IFR -AK -CA -SC (3.3) 10,600.0 72.W 20.00 4851.57 Men .0.62 92.64 0.08 25.60 2.56 6.49 92.64 1092 79.0 MWD+IFR-AK-CA-SC (3.3) 10,700.0 72.W 2W,00 4,981.64 27.26 4.62 93.80 0.08 25.93 2.57 6.60 93.W 11.02 79.94 MW IFR -AK -CA -SC (3,3) 10,80,0 72.0 2WA0 5,011.71 27.60 2..62 94.96 cm 26.26 2.60 6.70 94.96 11.12 79.93 MWWIFR-AK-CA-SC(3.3) 10,900.00 72.50 250.00 5841.78 27,95 .0.62 96.12 0.08 26.60 2.63 6.81 98.12 1132 79.92 MWD+IFR-AK-CA -SC (3,3) 11,000100 72.0 20.00 5,071.05 28.30 4.62 97.27 0100 26.93 2.50 6.92 97.27 11.31 79.92 MW IFR -AK -CA -W(3.3) 11.100.00 72.50 20.00 5,101.92 28,65 .0.62 98.43 0.00 27.26 2.70 7.03 98.43 11.41 78.91 MMAMAK-CA -SC (3,3) 11,200.00 72.50 2Mae 5,131.99 28.99 -0.62 99.59 0.00 27.80 2.73 7.14 99.59 11.51 79.90 MM IFR -AK -CA -SC (3,3) 11,300.00 72,50 2W.00 5,162.06 29.34 -0.62 100.7$ 0.08 27,93 2.77 7.25 100.75 11.61 79.0 MW IFR-AK-CA2-SC(3,3) 11,400.00 72.50 2wao 5,192.13 29,69 .0.62 101.91 0.08 28.26 2.80 7.37 101.91 11.71 79.89 MWD+IFR-AK-CA-SC(3,3) 11,500.00 72.W 20.00 5,222.20 30.04 -0.62 103.07 0108 28.50 2.81 7.48 103.07 11.81 79.89 MW IFR -AK -CA -SG (3,3) 11,600.00 72.50 26.00 5.252.27 30,39 .0.82 104.23 0.00 28.93 2.87 7.59 104.23 11.91 79.88 MW IFR -AK -CA -SC (3, 3) 11.700.00 72.50 2WAO 5,282.34 30.74 -0.62 105.39 0.08 29.26 2.90 7.71 105.39 12.01 79.87 MM IFR -AK -CA -SC (3, 3) 11,800.00 72.% 2611.00 5,312.41 31,08 -0.62 106.55 0.05 29.60 2.94 7.82 106.55 12.12 79.87 MW IFR -AK -CA -SC (3,3) 11,900.00 72.50 2W,00 5.342.48 31.43 4.82 107.72 am 29.93 2.97 7.94 107.72 12.22 79.86 MW0HFR-AK-CA-SC(3, 3) 12,OW,00 72,50 260.00 5,372.55 3138 -0.62 10888 0.(18 30,26 3.01 8.06 108.86 12.32 79.86 MW IFR-AK-CA2-SC(3, 3) 4/152019 8.49:34AM - Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit_2 Site: Kuparuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M-40 Design: 2M40wp13 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: 24440 TVD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) MD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: OAKEDMP1 Position uncertainty and bias at survey station Measured Imlinatian Azimuth Verewl KlghsMe Lateral Venlcal Ma9nimile 8emirna)or 6emiminm Depth Depth Error Bias Error Blas E.r Blas or Blas Error ERor Aamluth Tool (-ft) 1°) 1°) (uaft) lusty lueftl 0,11) 1ueft1 lusft) (uen) lush) (waft) lum) M 12,100.00 72.50 260.00 6.402.62 32.13 -0.62 110e4 0.08 30.60 3.05 8.18 11004 12.42 79.85 MWD*1FR-AK-CA-SD(3,3) 12,200.00 72.50 260.00 5,432.70 32.48 -0.62 111.20 0.08 30.93 3.08 8.30 111.20 12.52 79.85 MV/D+IFR-AK-CA-SC(3.3) 12.212.50 72.50 260.00 5,435.48 32.52 -0.62 111.34 0.08 3097 3.09 8.31 111.35 12.53 79.85 MM,IFR-AK-CA-SC(3,3) 12.300.00 71.88 258,43 5.463.38 32.68 -0.51 11203 0.57 31.28 3.12 862 112.22 12.62 79.83 MV,DNFR-AK-CA-&C(3,3) 12,400.00 70.78 252.31 5,495.59 33.02 -0.40 11211 1.13 31.59 3.16 8.54 113.05 1273 79.79 MwD+IFR-AK-CA2-SC (3,3) 12,500.0 70.00 240.15 5,529.16 33.59 -0.32 111.56 1.70 31.91 320 8.67 113.84 12.83 79.72 MMAFR-AK-CA -SC (3,3) 12,600.00 69.31 243.94 5,563.94 34.42 -0.27 110.38 228 32,23 3.25 8.79 114.59 12.93 79.62 MWD+IFR-AK-C-SC(3,3) 12,700.00 68.73 239.70 5,599.75 35.50 -0.25 108.56 2.86 32.55 3.29 8.92 115,29 13.04 79.51 MWD+1FR-AK-077-SC(3,3) 12,800.00 68.25 235.44 5,636.43 36.83 -0.26 106.09 3.43 32.87 3.34 9.05 115.93 1316 79.37 MWD+1FR-AK-CALSC(3,3) 12,900.00 67.89 231.14 5.673.79 38.34 -0.31 102.98 4.00 33.18 3.40 9.17 116.52 13.28 79.22 MV,D+1FR-AK-CA-&C(3,3) 13,000.00 67A3 226.83 5,71165 39.98 -0.40 99.27 4.56 33.50 3.45 830 117.05 13.42 79.013 MWD+1FR-M-CA-SC(3.3) 13.100.00 67.49 222.50 5,749.84 41.67 -0.52 94.95 5.11 33.81 3.50 9.42 117.52 13.57 78.90 MV IFR-AK4-SG (3,3) 13,200.00 67.47 218.17 5.788.15 43.21 -0.06 90.41 5.54 33.99 3.56 9.48 118.34 13.22 78.66 MM (3,4) 13,300.00 67.56 213.85 5,826.41 44.56 .0.85 85.77 5.88 34,40 3.81 8.49 119.29 13.37 7833 MM (3,4) 13,400.00 67.77 209.53 5,064.42 45.79 -1.05 80.74 6.23 34.02 3.67 9.52 120.20 13.76 77.75 MM (3. 4) 13,477.17 88.01 20620 5,893.48 46.61 -1.22 76.65 6.51 34.05 3.71 9.55 120.88 14.22 77.34 MV,V(3, 4) 13,500.00 68.01 208.20 5,902.03 46.61 -1.22 76.98 6.49 34.0!1 3.72 9.57 121.07 14.35 77.22 MWD(3. 4) 13,527.02 68.01 206.20 5,912.15 46.62 -1.22 77.36 6.47 34.07 3.74 9.58 121.30 14.48 77.06 MWD (3, 4) 13,800.00 70.88 204,95 5,937.89 44.40 -1.59 76.42 6.54 34.11 3.77 9.61 121.93 14.99 76.69 MWD(3,4) 13,700.00 74.35 203.29 5,967.93 41.41 -2.08 75.32 6.64 34.17 3.81 9.66 122.82 15.95 76.10 MM (3,4) 13,800.00 78.04 201.69 5,991.79 38.85 -2.55 74.39 6.75 34.25 3.84 930 123.72 17.14 75.48 MM (3,4) 13,900.00 81.74 200.14 6,009.34 36.40 -299 73.61 6.86 34.34 3.86 9.75 124.83 18.50 74.82 MWD(3,4) 14,000.00 85.44 198.61 6,020.51 34.93 -3A1 7297 6.99 31.45 3.87 9.79 125.55 20.01 74.13 MVID(3.4) 14,015.22 86.00 198.38 6,021.65 34.80 3.47 72.88 7.01 34.47 3.87 9.79 125.69 20.25 74.02 MWD(3,4) 14,100.00 WAO 198.38 6.027.56 34.91 -3.47 74.58 6.99 34,58 3.88 9.83 Issas 21.51 73.42 M44D(Q4) 14,200,40 08.00 198.39 8,034.54 35.05 -3.47 76.57 6.97 34.72 3.80 9.07 127.42 22.92 7232 MWD(3,4) 14,21522 86.00 198.38 6,035.60 34.47 -3.48 64.01 794 34.14 3.88 10.38 120.58 15.22 77.05 MM (4, 5) 14,235.22 86.00 198.38 6,037.00 34.47 -3.48 64,30 7.74 34.14 3.89 10.37 120.73 15.31 7694 MM (4. 5) 14,300.00 87.94 190.38 8,040.42 34.15 -3.68 65.28 7.73 34.15 3.89 10.39 121.21 15.65 76.56 MWD (4.5) 14,329.73 88.84 198.38 6,041.25 34.11 3.77 65.74 7.72 34.15 3.89 10.40 121.44 Me$ 78.38 MM (4. 5) 14,400.00 88.84 198.38 6042.68 34.13 -3.77 65.87 7.71 34.17 389 10.42 121.98 16.40 75.94 MWD (4.5) 14,500.00 88.84 190.38 6,04411 34.16 41.77 68.55 7.69 34.21 3.89 10.46 122.77 17.37 75.31 MiM(4,5) 14,600.00 88.84 19630 6,046.75 34.22 4.77 70.30 7.67 3426 3.89 10.49 123.60 16.51 74.67 MWD (4, 5) 14,70.00 88.84 198.30 6,048.70 34.29 -0.77 72.14 7.65 34.33 3.90 1052 124.46 19.80 74.01 MWD (4, 5) 14,800.00 Best 198.38 6,050.81 34.37 -0.77 74.04 7.63 34.41 3.90 10.56 125.35 21.18 73.33 MWD(4, 5) 14,900.00 88.84 198.30 6,052.85 34A7 -3.77 76.01 7.61 34.51 3.90 10.60 12827 22.64 72.64 MWD(4, 5) 15,000.00 88.84 198.30 6654.08 34.59 -3.77 7804 7.59 3.63 190 10.63 127.23 24.14 71.93 MM (4, 5) 15,100.00 88.44 198.38 6,056.91 3432 -377 80.13 7.58 34.78 3.90 10.67 128.22 25.68 71.21 MM (4, 5) 15,162.43 88.84 198.30 6058.10 34.81 -3.77 81.45 7.56 34.85 3.90 10.69 128.86 26.66 70.75 MWD(4, 5) 15,20000 89.81 197.63 6058.95 34.86 -377 80.98 7.64 34,91 3.90 10.71 129.24 27.13 70.49 MM (4. 5) 15,300.00 88.75 195.63 6,061.00 35.01 -337 79.52 7.86 35.07 3.91 10.76 130.19 28.17 89.82 MMD (4, 5) 15,400.00 88.69 193.63 6.063.32 35.18 -3.77 78.10 8.09 35.24 3.91 10.62 131.12 29.32 69.13 MWD (4, 5) 15,500.00 88.83 191.63 6065,88 35.37 -3.77 76.72 8.34 35.43 3.91 10.09 132A5 30.55 68.41 1,111VU(4, 5) 15,600.00 88.57 189.63 6,060.11 35.56 -3.77 75.39 see 35.63 3.91 10.99 132.96 31.88 87.57 MWD (4, 5) 15,609.00 88.58 189.45 6,088.33 35.58 -377 75.27 8.62 3585 3.91 10.98 133.04 32.00 67.61 MM (4, 5) 15,700.00 88.56 189.45 6,070.61 35.78 -3.77 77.34 sail 35.85 3.91 11.06 133.89 33.37 88.90 MWD(4,5) 151800.00 88.56 188,45 6.073.12 35.01 -3.77 79.73 8.78 36.00 3.92 11.18 134.87 35.00 66.08 MM (4, 5) 15,900.00 98.56 189.45 6.75.62 36.26 -3.77 82.16 8.83 36.32 3.92 11.28 135.90 36.63 85.28 MWD(4. 5) 16.00.00 88.56 189.45 6,078.12 36.51 -3.77 84.62 0.90 3658 392 11,ad 136.96 38.25 64.42 MWD(4,5) 16,007.39 80.56 189.45 6,078.31 36.53 -3.77 84.80 0.90 36.60 3.92 11.39 137.04 30.37 64,36 MWD(4.5) 16,100.00 89.55 191.02 6079.83 Wall -3.87 89.57 0.79 Was 3.92 11.48 138.05 39.66 63.62 MM (4.5) 16,142.36 90.00 191.74 6.090.00 36.97 -3.92 91.69 0.74 Wel 3.92 11.51 138.52 40.17 63.29 MWD(4, 5) 16200.00 91.15 191.74 6,079.42 37.31 4.05 93.05 8.76 37.13 3.92 11.58 139.19 40.913 62.83 MWD (4, 5) 16324.39 91.64 191.74 6078.83 37.50 4.10 93.66 0.77 37.20 3.92 11.58 139.49 41.34 62.63 MVM (4. 5) 4/16/2019 8..49:34AM Page 6 COMPASS 5000.14 Build 850 Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit_2 Site: Kupafuk 2M Pad Well: Plan: 2M-40 Wellbore: Plan: 2M40 Design: 2M40wp13 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M40 As Built 36.9+100.7 D79 @ 137.60usft (D79) As Built 36.9+100.7 D19 @ 137.60usft (D19) True Minimum Curvature 2.00 sigma OAKEOMPI Measured Inclination A71mmh Vertical Rlghside Lafenl vertical Magnitude Semimajor Senlmin0r oaten Dale Error Bus Error a. Error Blas of Bias Error Erser AafmuM Tool (usft) V) (1) (.aft) (usft) (ura) (usftl (usft) (rift) (-Sit) (dsft) lawn) (tiaft) 7) 16,300.00 91.64 191.74 6.076.86 37.72 -4.10 95.55 e81 37.43 3.92 11.63 140.43 4248 61.89 MWD(4. 5) 18,400.00 91.64 191.74 6,073.W 38.02 -4.10 98.00 8.86 37.73 3.92 11.71 141.71 43.97 61.14 MM (4. 5) 16,500.00 ales 191.74 6,070.93 38.34 .4.10 100.63 8.91 38.05 3.92 11.79 143.03 45.44 60.28 MM (4. 5) 16,596.20 91.64 191.74 6.088.18 30.65 -4.10 103.10 8.95 38.37 3.91 use 144.35 46.82 59.46 MM (4. 5) 16,600.00 91.57 191.73 5008,07 38.65 -4.10 103.17 8.95 38.38 3.91 11.86 144.39 46.85 59.43 MND (4. 5) 16,639.57 90.78 191+63 6,057.26 38.62 -4.00 103.69 8.98 38.51 3.91 11.90 144.82 47.01 59.20 MWD (4, 5) 16.700.00 90.78 191.63 6,086.44 38,83 -4.00 104.99 9.01 38.72 3.91 11.94 145.50 47.56 50.77 MM (4, 5) 16,000.00 90.78 191.63 5065.08 39.10 4.00 107.58 9.06 39.07 3.91 12.02 147.01 48.93 57.91 MVUD (4, 5) 16,900.00 90.78 191.03 6,063.M 39.54 -CM 110.19 9.11 39.43 3.91 12.10 148.48 50.27 57.06 MM (4, 5) 17,000.00 90.78 191.63 6,062.36 39,91 -4.00 112.81 9.16 39.81 3.91 12.18 150.00 51.58 58.21 MM (4, 5) 17,100.00 90.78 191.63 61001.00 40.29 4.00 115.45 9.21 40.19 3.91 12.26 15L55 5285 55.37 MM (4. 5) 17,200.00 90.78 191.63 6,059.64 40.68 -4.00 118.10 9.26 40.58 3.91 12.35 153.16 54.09 54.52 MWD (4, 5) 17,221.22 90.78 191.63 6.059.36 40,76 -4.00 118.66 9.27 40.55 3.91 12.36 153.50 54.34 54.35 MM (4, 5) 17,280.20 90.00 191.86 6,059.09 40.82 -3.91 liam 9.28 40.82 3.91 12.39 154.06 54.63 54.08 MND(4, 5) 17,300.00 8920 191.86 6,059.37 40.93 -3.81 12011 9.30 40.98 3.91 12.43 154.54 54.73 5100 MMA(4, 5) 17.352.56 87.95 191.66 5060.92 41.21 -3.64 121.28 9.33 41.24 3.91 12.48 155.31 54.91 53.56 MWD (4, 5) 17,400.00 87.95 191.86 6,002.26 41.36 -3.64 122.09 9.35 41.39 3.91 12.51 155.85 55.18 53.31 MWD (4, 5) 17,500.40 87.95 191.08 6,055.83 41.78 -3.64 124.75 9.10 41Al 3.91 12.60 157.54 Ss.32 52.50 MWD(4, 5) 17,600.00 07.95 191.56 6,069.40 42.21 -3.64 127.42 9.45 42.24 3.92 12.69 15927 57.43 51.69 MWD (4, 5) 17,700.00 87.95 191.66 6,072.97 42.64 -3.64 130.10 9.50 42.67 3.92 12.78 161.04 58,51 50.90 MM (4, 5) 17,800.40 87.95 191.66 6,076.54 43,09 -3.64 132.60 9.54 43.11 3.92 12.87 162.85 59.55 50.11 MM (4, 5) 17,900.00 87.95 191.66 5000.12 43.54 -3.64 135.50 9.59 4157 3.93 12.96 164.69 60.56 49.34 MWD(4, 5) 17,998.70 87.95 191.06 6,083.07 43.99 -3.64 138.17 964 44.02 3.93 13.05 165.55 61.52 48.59 MM (4, 5) 18,000.00 87.98 191.66 6,083.69 44.00 -3.65 138.21 9.81 44.02 3.93 13.05 166.58 61.53 48.58 MMA (4, 5) 18.090.14 09.78 191.67 6,085,45 44.43 -3.90 140.67 9.68 44.44 3.93 13.13 168.30 62.39 47.91 MWD (4, 5) 18,100.00 89.78 191.67 6,085.49 44.47 -3.90 14094 9.89 44.49 3.93 13.14 168.50 62.48 47.83 MM (4. 5) 18,2W.W 89]0 191.67 6.085.87 44.95 -3.90 143.87 9.74 44.97 3.83 13.22 170.45 63.39 47.10 MM (4, 5) 10,3W.W 89.78 19167 6,086.25 45.43 .3.W 146.41 9.79 45.45 3.93 13.31 172.44 64.27 46.38 MM (4. 5) 18,4W.W 89.78 191.67 6.086.63 45.92 -3.07 149.15 9.83 45.93 3.93 13.39 174.46 65.12 4567 MM (4.5) 155Wp0 89.78 191.67 6.087.01 46.41 -3.90 151.91 9.88 46.43 3.07 13.48 176.52 65.94 4498 MM (4.5) 15600.00 89.78 191.67 6,087,39 46.91 -3.W 154.66 9.93 40.93 3.93 13.56 178.61 66.74 44.30 MM (4. 5) 18.700.00 89.78 191.67 6.087]8 37.72 -3.07 82.03 8.45 37.74 3.93 12.55 131.93 38.90 W.72 MM -IFR -AK -CZ (S. 5) 158110.00 89.78 191.67 6,068.16 37.88 -3,W 82.93 0.45 37.W 3.07 12.60 132.28 39.62 66.41 MM+IFR-A-CA-6C(5, 5) 15W6.25 89.78 191.67 5,088.10 37.89 -3.W B2.99 8.45 37.91 3.93 12.W 132.31 39.66 66.39 MWD+IFR-AK-CP-SC(5, 5) 18,83115 89.28 191.69 6.008.38 37,89 -3.83 83.15 8.44 37.95 3.93 12.62 132.37 39.72 68.34 M4YD+IFR-MH- -SC (5, 5) 18,900.00 09.20 191.89 5089.24 saw -3.83 83.53 a." 3807 3.93 12.56 132.56 39.88 66.W MMAFR-MRA -SC (5. 5) 19,000.00 8928 191.69 5090.49 36.16 -3.83 84.43 0.46 38.22 3.93 12.71 132.92 40.60 65.89 MWD+IFR-MK-0 -SC (5, 5) 19.100.00 09.28 191.69 5071]4 38.33 -3.03 85.35 844 30.30 193 12.77 113.29 41.31 65.50 MM+IFR-M(-C -SC (5, 5) 19,200.00 89.28 191.69 5092.99 30.49 -3.83 06.26 S." 30.51 394 12.83 133.66 42.02 65.26 MWD+IFR-MRA -SC (5, 5) 19,3W.00 89.28 191.69 5094.24 3560 -3.83 07.19 8.0 30.71 3.94 12.09 134.01 42.73 64.95 MWD+IFR-Al(CASC(6, 5) 194W.00 89.28 191.68 5095.49 38.83 -3.83 08.12 8.44 38.88 3.94 12.94 134.42 43.44 64.62 MVID+IFR-AK-CA4C(5, 5) 19,507.00 89.28 191.69 6,096.74 39.00 -3.83 89.05 &44 39.05 3.94 13.00 134.01 44.14 64.30 MVA+1FR-AK-CA -SC (5, 5) 19,607.00 89.28 191.69 8.097.07 39.18 -3.83 89.99 8.44 39.23 3.94 13.06 135.21 44.84 63.97 MV IFR -AK -CA SC(5,5) 19,887.98 69.28 191.69 5099.09 39.33 -3.83 90.82 8.44 39.39 3.94 13.11 135.58 45.45 63.69 MP IFR-AK-CAZ C(5,5) 19,700.00 89.04 191.67 6,099.27 39.35 -3.79 90.86 8.45 39.41 3.94 13.12 135.60 45.48 6365 MND+IFRdK-CA SC (5, 5) 19,732.94 80.39 191.63 5107.00 39.41 -3 B8 90,84 8.45 39.47 3.94 13.14 135.65 45.38 63.63 MV IFR -AK -CA -$C (5, 5) 19,070.00 80.39 191.63 6,101.09 39.53 -3e8 91.21 8.45 39.59 3.94 13.18 135.80 45.52 63.50 MVVD+IFR-AK-CA-S (5, 5) 19,900.00 98.39 191.63 81104]1 3971 -3.68 92.18 8.45 39.77 395 13.24 135.27 46.21 03.17 MM+1FR-AK-CA-SC(5, 5) 20,000.00 88.39 191.83 5107.52 39.0 .380 93.11 8.45 39.95 3.95 13.11 138.69 46.89 62.83 MND+IFR-AK-CA -B (S. 6) 20,107.00 88.39 191+63 6.110.34 40,09 - Ail 94.07 8.45 40.14 3.95 13.37 137.11 47.57 82.50 MM+IFR-AK-CA -S IS. 5) 20,200.00 00.39 191.63 6,113.15 40.28 -3.60 95.03 8.45 40.33 3.95 13.43 137.54 48.24 62.16 MM+)FR-ARCA -W(5, 5) 20,251.93 88.39 191.63 5114.61 40.38 -3.68 95.53 0.45 40.43 3.95 13.47 137.77 48.59 61.98 MW4)+IFR-AK-CA -S (5, 5) 20,3W.W 89.35 191.68 6.115150 40.48 -3.84 07.00 8.45 40.52 3.% 13.50 137.98 48.91 61.82 MWD+IFR-ARCA-W(5, 5) 20,332.73 90.00 191.72 6,115.75 40.59 -3.07 98.45 8.44 40.59 3.% 11.52 138.13 49.13 61.71 MWD+IFR-u(-CA2-SC(5, 5) 41162019 8:49:34AM Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit _2 Site: Kuparuk 2M Pad Well: Plan: 2M40 Wellbore: Plan: 2M-40 Design: 2M4Owpi3 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-40 As Built 36.9+100.7 D19 Q 137.60usft (D19) As Built 36.9+100.7 D79 @ 137.60usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station - Circle (radius 1,320.00) Measunw In<nnmion Mmu Vertical Ri9hsi4e Lu..I -3,735.16 vomcal Ma9nit Seml+naftr Semimimr Oepm Depth Error Blas Eno, Blas Evor Bias of Sias Emr E., AZ vffi Tod (usnl CI 111 (use) lust) (uafr) lust) lust) (UA) lusnl (ura) lural luanl PI 20,350.11 90.35 191.72 6,115.70 40.66 -4.01 %.62 8.44 40.62 3.% 13.53 138.20 49.24 61.65 MW WR.AKLR.SC(5, 5) 20,400.00 90.35 191.72 6,115.39 40.76 -4.01 97.10 8.44 40.72 3.96 13.55 138.42 49.57 61.48 MWWIFR-AK-CP -SC (5, 5) 20,500.00 90.35 191.72 6.114.79 40.95 -4.01 98.07 8.44 40.91 3.95 Mal 138.88 50.23 61.14 Mw IFR -AK -CA .SC (5, 5) 20,600.00 90.35 191.72 6.114.18 41.15 4.01 99.05 8.44 41.11 3.95 13.07 139.33 50.86 60.79 MVM -IFR -M- .SC (S. 5) 20.700.00 90.35 191.72 6,113.57 41.35 -4.01 100.03 8.44 41.31 3.95 13.73 139.80 51.52 60.44 MWWIFR-AK-CP-SC (5,5) 20,800.00 90.35 191.72 6.112.97 41.55 1.01 101.01 8.44 4t52 3.95 13.78 140.27 52.16 60.09 MWD+IFR-AK-CA-SC(5, 5) 2090.00 90.35 191.72 8.112.36 41.76 1.01 102.00 8.44 41]2 3.95 13.84 140]5 52.60 59]4 MW IFR-AKCA -SC (S. 5) 21,00010 90.35 191.72 6,111.75 41.97 4.01 102.99 8.44 41.93 3.95 13.90 14134 53.43 59.39 MWD+IFR-AK-CP-SC (5.5) 21,100.00 90.35 191.72 6.111.15 42.17 -4.01 10.98 8.44 42.14 3.95 13.96 141.73 54.05 59.03 MM+IFR-M-CA-SC(5, 5) 21.200.00 90.35 191.72 6.110.54 4288 1.01 104.98 8.44 42.35 3.95 14.02 142.23 54.67 58.68 MWD+IFR-AK-CA-SO(5, 5) 21,241.00 90.35 191.72 6,110.29 42.47 1.01 105.39 8A4 42.44 3.95 14.04 142.44 54.92 55.53 MWD+1FR-M-0A-SC (5,5) Design Targets Target Name . hitimiss target Dip Angle Dip Dir. TVD -NIS +E/ -W Northing Easting -Shape V) (1) lush) (usft) (usft) lust[) (usft) 2M-40 TO 020818 JM 0.00 0.00 6,035.60 -2,836.57 -10,804.47 - plan hits target center - Circle (radius 1,320.00) 2M-40 T02020818 JM 0.00 0.00 6,058.18 -3,735.16 -11,103.01 - plan hits target center - Circle (radius 100.00) 2M40 T05 020818 JM 0.00 0.00 6,059.09 -5,788.07 -11,526.65 - plan hits target center - Circle (radius 100.00) 2M40 704020818 JM 0.00 0.00 6,068.18 -5,137.78 -11,392.71 - plan hits target center - Circle (radius 100.00) 2M40 T03 020818 JM 0.00 0.00 6,080.00 -4,693.58 -11,300.44 - plan hits target center - Circle (radius 100.00) 210-40 T06020818 JM 0.00 0.00 6,085.45 -6,600.43 -11,694.32 - plan hits target center -Circle (radius 100.00) 2M-40 T07 020818 JM 0.00 0.00 6,088.18 -7,301.74 -11,839.16 - plan hits target center - Circle (radius 100.00) 2M-40 T08020818 JM 0.00 0.00 6,099.09 -8,165.13 -12,017.75 - plan hits target center - Circle (radius 100.00) 2M40 T10020818 JM 0.00 0.00 6,110.29 -9,685.80 -12,332.26 - plan hits target center - Circle (radius 1,320.00) 2M-40 T09 020818 JM 0.00 0.00 6,115.75 -8,796.40 -12,147.72 - plan hits target center - Circle (radius 100.00) Latitude Longitude 4/16/2019 8:49:34AM Page 8 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kupamk Project: Kupawk River Unit -2 Site: Kupawk 2M Pad Well: Plan: 210-40 Wellbore: Plan: 2M40 Design'. 2M-40wp13 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-40 As Built 36.9+100.7 D190 137.60usft (D79) As Built 36.9+100.7 D19 (Q 137.60usft (Dig) True Minimum Curvature 2.00 sigma OAKEDMPI Casing Points Measured Measured Vertical Dip Casing Hale Depth Depth (usft) Diameter Diameter (usft) (usft) Name (in) (in) 2,992.58 21637.90 13-3/8 x 16 13.375 16.000 13,173.26 5,777.90 9-5/8 x12-1/4 9.625 12.250 14,215.20 6,035.60 7" x &1/2 by 9-7/8" 7.000 9.875 21,241.08 6,110.29 4-1/2x6-1/8 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lfthology (1) (�) 450.64 450.60 T-3 0.00 579.80 579.60 K-15 0.00 1,485.19 1,477.60 Base Penn 0.00 2,061.74 2,011.60 W Sak D 0.00 2,919.89 2,603.60 Base WS D 0.00 4,032.23 2,976.60 Camp SS 0.00 8,019.52 4,175.60 C-50 0.00 9,672.30 4,672 60 C-37 / Top Iceberg 0.00 12,036.73 5,383.60 C-35 0.00 13,167.25 5,775.60 THRZ 0.00 13,544.50 5,918.60 BHRZ/TKLB 0.00 13,713.83 5,971.60 K-1 0.00 14,215.22 6,035.60 Top Kuparuk 0.00 4/162019 6 49:34AM Page 9 COMPASS 5000. 14 Build 85D ConocoPhillips Error Ellipse Report Company: ConomPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 2M-40 Project: Kuparuk River Unit -2 TVD Reference: As Built 36.9+100.7 Of 9 @ 137.60usft (D19) Site: Kuparuk 2M Pad MD Reference: As Built 36.9+100.7 D19 @ 137.60usft (D19) Well: Plan: 2M-40 North Reference: True Wellbore: Plan: 2M40 Survey Calculation Method: Minimum Curvature Design: 2M40wpl3 Output errors are at 2.00 sigma KOP. Stan -0.73°/100' OLS, 1.5° TF, for 200' 300.00 Database: OAKEDMPI Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft( (usft) Comment 36.90 36.90 0.00 0.00 KOP. Stan -0.73°/100' OLS, 1.5° TF, for 200' 300.00 300.00 0.00 0.00 Start Build 1.50 500.00 499.91 1.79 -4.92 Start 500.00 hold at 500.00 MD 1,000.00 999.22 10.74 -29.51 Start Build 2.50 1,434.00 1,427.90 32.46 -89.17 Start 179.74.1100' DLS, 3.5° TF, for 1455.58' 1,537.00 1,527.90 40.89 -112.34 Start 185.44°/100' DLS, 0° TF, for20' 2,992.58 2,637.90 24.25 -978.59 Start 282.04°/100' DLS, 3.3° TF, for 300' 3,012.58 2,646.95 22.19 -996.30 Start 3461.73°/100' DLS, 0° TF, for 8900' 3,312.58 2,760.20 -18.24 -1,270.74 Start 4311.94°/100' DLS, 4° TF, for 1264.59' 12,212.58 5,436.48 -1,492.17 -9,629.87 Start 4356.76°/100' DLS, 0° TF, for 49.85' 13,477.17 5,893.48 -2,167.35 -10,542.71 Start 4822.69°/100'DLS, 4"TF, for 488.2' 13,527.02 5,912.15 -2,208.83 -10,563.12 Start 5020.96'1100' DLS, 0* TF, for 200' 14,015.22 6,021.65 -2,647.24 -10,741.57 Start 5040.79°/100' DLS, 0° TF, for 20' 14,215.22 6,035.60 -2,836.57 -10,804.47 Start 5134.61°/100' DLS, 3" TF, for 94.51' 14,235.22 6,037.00 -2,855.51 -10,810.76 Start 5961.98°/100' DLS, 0' TF, for 832.7' 14,329.73 6,041.25 -2,945.09 -10,840.52 Start 6407.73°/100' DLS, 2' TF, for 446.57' 15,162.43 6,058.18 -3,735.16 -11,103.01 Start 6805.61°/100' DLS, T TF, for 398.39' 15,609.00 6,068.33 -4,168.07 -11,210.25 Start 6940.51°/100'DLS, 2* TF, for 134.97' 16,007.39 6,078.31 -4,560.94 -11,275.64 Start 7022.53°/100' DLS, 2° TF, for 82.03' 16,142.36 6,080.00 -4,693.58 -11,300.44 Start 7394.19°/100' DLS, 0° TF, for 371.81' 16,224.39 6,078.83 4,773.89 -11,317.12 Start 7437.55°/100' DLS, 2° TF, for 43.37' 16,596.20 6,068.18 -5,137.78 -11,392.71 Start 8019.13'/100' DLS, 0° TF, for 581.65' 16,639.57 6,067.26 -5,180.25 -11,401.49 Start 8058.11°/100'DLS, 2* TF, for 38.98' 17,221.22 6,059.36 -5,749.89 -11,518.78 Start 8160.45°/100' DLS, 2° TF, for 102.36' 17,260.20 6,059.09 -5,788.07 -11,526.65 Start 8796.17°/100'OILS, 0* TF, for 636.14' 17,362.56 6,060.92 -5,888.29 -11,547.33 Start 8887.58°/100' DLS, 2° TF, for 91.44' 17,998.70 6,083.64 -6,510.90 -11,675.83 Start 9603.68"/100' DLS, 0° TF, for 716.12' 18,090.14 6,085.45 -6,600.43 -11,694.32 Start 9628.57°/100' DLS, 2° TF, for 24.89' 18,806.25 6,088.18 -7,301.74 -11,839.16 Start 10485.33°/100' DLS, 0° TF, for 856.84' 18,831.15 6,088.38 -7,326.12 -11,844.20 Start 10530.28°/100' DLS, 2° TF, for 44.96' 19,687.98 6,099.09 -8,165.13 -12,017.75 Start 11049.05°/100' DLS, 0° TF, for 518.99' 19,732.94 6,100.00 -8,209.15 -12,026.84 Start 11129.84°/100' DLS, 2° TF, for 80.8' 20,251.93 6,114.61 -8,717.29 -12,131.37 Start 11147.22°/100' DLS, 2' TF, for 17.39' 20,332.73 6,115.75 -8,796.40 -12,147.72 Start 12038.16°/100' DLS, 0* TF, for 890.97' 20,350.11 6,115.70 -8,813.43 -12,151.25 TD: 21241.08'MD, 6110.29'TVD 21,241.08 6,110.29 -9,685.80 -12,332.26 TO at 21241.08 Checked By: Approved By: Date: 4/16/2019 8:49:34AM Page 10 COMPASS 5000.14 Build 85D 0 0 LO m 0 c`) f 0 8" dd3dd . mmS88arcrc"$ u �� F c'rvNav o m — baoo `. m M 00909}5�� to £ d9 ssa ory �� o ti md, iOOQ oaazsf$as '-�hrF3�3gg oo '.M �V iti 20 0 `0•�Z 0 h O 9L 0 Y H Ln O r 1 O 3 3a O n � M > �e•wr s-wz_ N Q d 3= 1...--- 0 0 o — Ln - --- _ - -- r c - N � o _> C O O U o N � Q N a O O O O O O O � O O O O LO LO O Ln O .d c7 M O (ui/4sn OOS£) (+)gIJON/(-)4lnoS r wbP w�' 6a< nryo 8a>rz gggAggqyA L7bEI iD00 .QQ � -. 'o J „R88888888R �y ® h m L N �mmmw�mmUY 0 e` N oM1n�n�wgg-mm q Zem�$$SS mmm OOb a Q 0026£ pp F N O NO -- - In mmmmmm ro m M ppg, ppg Sr BoU4 9£' OOP x'3000 P '�F di w g g O 200 0 10'W, N 7 ILD O � I ti� 6 N tT•31 oa O + ry O i W - a O M«Wz c-wz- f 1 N CL O O 0 N m O C o � � N o O In 14- c O O O O O o CL O O O O O U') LO o U') O M M I` O V (ui/)}sn 0090 (+)4IJoN/(-)4lnoS m y Is � S � � N V Led9£-we a Sxo ssaeaesss ..000000000 � C888888882 Ln 3 co N h uUUUUUUU�U SCC.......... CL F W EgS iyiI]3 $$E 9yS yy4S ppE pZ Qi (B O m y Is � S � � N V Led9£-we N O 0009 9£-GY2 O Ln 3 co N Mze CL 4) Qi (B O N m 0 CY W U) s Q N O i O Ln co N 0009 0009 I Ne O CD 0 O O LO 0 (ui[}sn 0090 (+)4IJoN/(- )ulnoS O O O r GZ•pZ Em O O VJ 1 0 O Ln O 0 O 0 0 0 LO r _.c.) 0 0 0 O O CD 1 0 O NT N 2M-31 I �IL MIR m I 2L 3 Surface M CPAI Coordinate Converter From: Datum: NAD83 Region: alaska . r Latitude/Longdude IDecimalDegrees * UTM Zone: F— r South G State Plane Zone:Units: ,as.ft C Legal Desaiption (NAD27 only) Datum: NAD27 Reim: alaske r Latitude/Longitude IDecimalDegreet f UTM Zone: True r— South * State Plane Zone: I' �,] Units: rus ft r Legal Description (NAD27 only) Starting Coordinates:-- Ending Coordinates: X'. 1627932.08 X: 1487899.197943113 Y. f5948735.36 Y. 5948985.27584091 2M-40 wp13 Surface M CPAI Coordinate Converter Datum: NAD83 Region: alaska C Latitude/Longitude IDedmalDegrew f UTM Zone: r— r South * State Plane Zone: Unitz usft r Legal Description (N.AD27 only) Starting Coordinates; X: 11627932.08 Y. 5948735.36 Quit He � ro - ❑ x Datum: NAD27 Region: alaska !' Latitude/Longitude IDecimalDegfees—� C UTM Zone: True r South f state Plane Zone: F--::] Urds us4t G Legal Desorption (NAD27 or*) Twmshp: 011 [WD, Range: 006 IE:,:] Meridian I� Section: FNL . 5166.7076 FEL 5221.1024 ,_-------- ....... _..' Quit Help 2M-40 wp13 Production Horizon M CPA[ Coordinate Converter Datum NADB3 Region: alaska ] C' Latitudekongitude IDecimaiDegrees * UTM Zone:I — r South G State Plane Zone: F ---D Units: usat C' Legal Description (NAD27 o*) - ❑ x Datum ryAD27 Region alaska C' Latitude/Lmgihde jDecirrailDegnees C' UTM Zone: True r South ' G State Plane Zone: Iq --�-] Units: urft C' Legal Description (NAD27 a*) Starting Coordinates: F Ending Coordinates: X 1617724.00 X. 477090.676279213 Y: 5945917.00 L Y: 5946167.15913779 2M-40 wp13 Production Horizon Q CPAI Coordinate Converter Datum NAD93 . Region: alaska C' Latitudekongitude IDecirnalDegrees C' UTM Zone: F— r- South F State Plane Zone: I' -�-] Units: unit C' LsgalD�mripEon I1dd.D27only] Starting Coordinates: K: 11617124.00 Y: 5945917.00 ('Tmnslam J Quit Help ......... ................ - ❑ x Datum:D27 , Region: alaska r Latitude/Longitude IDecinialDegrees, —� r UTM Zone: True r South C' State Plane Zone:1' J Units: urft . * Legal Description (NAD27 only) Township: 011 [R':,:] Range :I11O i` -' Meridian I" -7J Sectiom 31 / J FNL 2730.2273 FEL 191.93277 TransF«m _ Quk Help 12M-40 wp13 TD M CPAI Coordinate Converter Datum: NAD83 Region: alaska . C Latitude/Longotude IDecimalDegrees r- UTM Zone:I — r South G State Plane Zone: F---3 Units: urfl f Legal Description (NAD27 only) - ❑ X To ._ Datum:NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees * UTM Zone True r South R State Plane Zane: F -�-:) Units: w{t r- Legal Description (NAD27 o*) Starling Coordinates: Ending Coordinates: K: 11615585.00 X 475551.714548517 Y. 5939071.00 Y' 5939321.30115476 2M-40 wp13 TD M CPAI Coordinate Comrerter Datum: NAD83 Region: alaska r Latdude/Longitude IDecimalDegrees * UTM Zone: F— r South * State Plane Zone: F----] Units: usdt C Legal Dexcription INA.D27 only] Slatting Coordnatez X: 11615585.00 Y: 5939071.00 Tmnslam - quit Help - ❑ X Datum NAD27 Region: alaska C Latitude/Longitude IDecimal Degrees r UTM Zone: True r South r State Plane Zone: F--:-:1 Units: uslt r Legal Description (NAD27 only) Legal Township: oto I"J Range: IV1° F:-:1 j Meridian: F':-] 4301.5882 FEL 1734.5932 quit I Help REV DATE BY CK APP DESCRIPTION REV DAZE BY CK APP DESCRIPTION 3 8/19/1 LGM JLS AB 37 & 38 Per K160005ACS 4 9/25/1 LGM I JLS I lRevised Per K180005ACS ASP GRID Z' rI10F 16 15 14 13 2A 26 • 25 • 24 • 23 21 22 4—CORNI RS 4 38623 22 • PROJECT 21• LOCATION 20 • 410 28 25 27 26 18 2H 34 X $M 17 • 33 • 16 • VICINITY MAP 35 o 14 • 1"= 1 MILE 13 • NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2M MONUMENTAT10N PER'LOUNSBURY & ASSOC. DS2M 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 12• 3. ELEVATIONS ARE B.P.M.S.L. 11 • 10 • 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED 39 *9 SECTIONS 27 & 28, TOWNSHIP 11 NORTH, 869A RANGE 8 EAST, UMIAT MERIDIAN, ALASKA 8A 5. DATES OF MOST RECENT SURVEY:9/23/2018 6 : BK: L18-36 PG: 18-22. 4465 6. ALL DISTANCES SHOWN ARE GROUND 2 6A LEGEND 1 5A 27 34 O AS—BUILT CONDUCTOR LOCATION T • EXISTING CONDUCTOR LOCATION 28@36 • 28 33 • 3XPLUGGED & ABANDON CONDUCTOR LOCATION 29 • 30 2A GRAPHIC SCALE g 0 50 100 200 32 1 1 37499 1 inch = 100 ft. LOUNSBURY & AS Cures, INC. SEE SHEET 2, 3 & 4 FOR LOCATION INFORMATION SV"" MG" S P"NM AREA: 2M MODULE: XXXX UNIT: D2 ConocoPhilli S DS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6213D29 1/13/07 CEA-D2MX-6213D29 1 of 4 4 13 18/19/1N LGM I JLS I IAB 37 & 38 Per K160005AGS 1 4 19/24/181 LGM I JLS I (Revised Per K180005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 27, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X Lot. Long. F.S.L. F.W.L. O.G. PAD 21 5,948,985.88 488,319.18 N 70' 16' 18.585" W 150' 05' 40.098" 114' 479' 99.7' 105.3' 22 5,948,985.77 488,344.40 N 70' 16' 18.585" W 150' 05' 39.364" 114' 504' 99.7' 105.0' *23 5,948,985.83 488,368.91 N 70' 16' 18.586" W 150' 05' 38.650" 114' 529' 99.6' 104.9' 24 5,948,985.75 488,394.29 N 70' 16' 18.585" W 150' 05' 37.911" 114' 554' 99.5' 104.9' 25 5,948,985.79 488,419.22 N 70' 16' 18.586" W 150' 05' 37.186" 114' 579' 99.4' 104.9' 26 5,948,985.92 488,434.76 N 70' 16' 18.588" W 150' 05' 36.733" 115' 594' 99.4' 104.9' 27 5,948,985.97 487,844.42 N 70' 16' 18.579" W 150* 05' 53.921" 114' 4' 100.9' 105.5' 31 5,948,985.64 488,156.27 N 70' 16' 18.581" W 150' 05' 44.841" 114' 316' 100.2' 104.7' 33 5,948,985.93 488,206.85 N 70' 16' 18.584" W 150' 05' 43.369" 114' 367' 100.0' 104.7' 34 59948,985.32 488,232.32 N 70' 16' 18.579" W 150' 05' 42.627" 114' 392' 99.9' 104.6' 35 5,948,986.23 488,256.36 N 70' 16' 18.588" W 150' 05' 41.928" 115' 416' 99.9' 104.7' 38 5,948,986.00 488,364.41 N 70' 16' 18.591" W 150' 05' 38.781" 115' 524' 101.0' 101.3' *39 5,948,985.25 487,969.82 N 70' 16' 18.574" W 150' 05' 50.270" 113' 129' 100.7' 100.7' *40 5,948,985.28 487,899.20 N 70' 16' 18.573" W 150' 05' 52.326" 113' 59' 100.8' 100.7' *41 5,948,985.35 488,281.25 N 70' 16' 18.580" W 150' 05' 41.203" 114' 441' 99.9' 100.5' * CONDUCTOR ASBUILT THIS SURVEY ** PLUGGED AND ABANDONED WELLS LOUNSBURY & ASSOCIATES, INC. TOftS &YGINBE65 PYNNERS AREA: 2M MODULE: XXXX UNIT: 12 ConocoPhilli s DS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30' of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6 iia a ..i.... ConocoPhillips ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations 2M-40 grilling Hazards SL.nmary 16" Surface Section - 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Reduced pump rate and low mud temperatures. Additions of ScreenKleen. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced severe mud loss and 2M - Lost Circulation Moderate 38 had minor losses. Ensure enough lost circulation material on location. Reduce drilling ROP and trip speed Lost Circulation Moderate when necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip sheets), pump out of hole if necessary. Hole swabbing on trips Moderate Monitor real time surveys closely, run gyro survey to Anti -Collision Low eliminate magnetic interference from nearby wells when needed. Washouts / Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize circulating time when possible 12-1/4" INTRM 1 Section - 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD via PWD and torque/drag real time The Iceberg formation pressure is estimated to be 10.1 Abnormal Reservoir Pressure Moderate ppg. Weight up mud to 10.3 ppg before drill into Iceberg formation. Monitor ECD to below expected formation fracture Lost Circulation Moderate gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Perform OH FIT if necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip sheets), purnp out of hole if necessary. 2M-40 Drilling Hazards Summary.dou 4/1712019 8:5738 AM 8-1/2"x9-7/8" INTRM2 Section -7" Liner Hazard Risk Level Mitigation Strategy Keep good hole cleaning practices, monitor ECD and Stuck Pipe Low torque/drag real time. Maintain constant bottom hole ressure with MPD. The intermediate II section is penetrating into the Stuck Pipe Low reservoir of Kuparuk C, which is estimated to be up to 10.5 Abnormal Reservoir Pressure Moderate ppg. Utilize MPD for shale stability and pore pressure Lost Circulation Moderate management. Shut in nearby injectors to prevent pore pressure rise. Differential Sticking Low Monitor real time equivalent circulating density (ECD) to Lost Circulation Moderate below expected formation fracture gradient. Prepare enough lost circulation material on location. Reduce Hole swabbing on trips Moderate drillin ROP and trip seed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip sheets), pump out of hole if necessary 6-1/8" Production Section - 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy The reservoir pore pressure of Kuparuk C is estimated to Abnormal Reservoir Pressure Moderate be 6.5-10.5 ppg. Utilize MPD to manage and ensure wellbore overbalance. Shut in nearby injectors to prevent ore pressure rise. Stuck Pipe Low Keep good hole cleaning practices, use PWD tools monitoring, stabilized BHA Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program, control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly clean hole rior to pulling out of hole to run liner. Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use of tri sheets , umping or backrearning out if necessary 2M-40 Drilling Hazards Summarydocx 4/17/2019 8:57:38 AM Well: I KRU 2M-40 <== Data Inpnt Name: V Loepp ==Data Input Mud Weight (ppg) 12.00 <== Data Input Weak point or LOT - Measured depth (ft) 2,993' <== Data Input Weak point or LOT True vertical depth (ft) 2,636' <=- Data Input Weak point or LOT - Hole angle (deg) 63.00 <== Data Input Weak point or LOT - Hole size (in) 13, 75" <== Data Input .._,.., Weak point pressure or LOT -EMW (ppg) r_= Data Input Zone of interest - Measured depth (ft) 2,973' <== Data n Zone of interest - True vertical depth (ft) 5, <== Data Input _ Zone of interest - Hole angle (deg) 67.80 <== Data Input Zone of interest - Hole size (in) 9.625" <== 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) 0.0278 _ DP annular vol. @ zone of interest (bbl/ft) 0.0606 DP annular vol. @ weak point bbl/ft 0.1444 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi): PI0 1,783 psi Weak point pressure -Safety margin: Pmax 1,783 psi Pmax EMW 13.00 pp Max anticipated formation pressure (psi): Pf 3,706 psi Weak Pt to Zone of Interest distance (TVD ft): OH (TVD) Weak Pt to Zone of Interest distance (MD ft): OH (MD) Maximum influx height at the bit (TVD ft): H (TVD) Abb/ Maximum influx height at the bit (MD ft): H {MD) _ Calc. volume of (H) around BHA: Vlbha -Calc. volume of (H) around drill pipe: V1dp - Calc. volume that H equals @ initial shut in: V1 -1.6 bbl Calc. vol. that H equals @ weak point (MD ft): VWp -6.7 bbi Calc. volume of Vwp @ initial shut in: V2 -3 bbl Kick Tolerance: V2 -3.2 bbl NOTE: PF Weak point or LOT True vertical depth (ft) 2,638' <_= Data Input Weak point or LOT - Hole angle (deg) 63.0° <_= Data Input Weak point or LOT - Hole size (in) <== Data Input Weak point pressure or LOT -EMW (ppg) r 13.50 <_= Data Input Zone of interest - Measured depth (ft) <== Data Input Zone of interest - True vertical depth (ft) 5,701' <== Data Input Zone of interest - Hole angle (deg) 67.80 <== Data input Zone of interest - Hole size (in) 9.625" <== Data Input Zone of interest -Pore pressure EMW (ppg) 12.50 <== Data Input Gas gradient (psit t) 0.10 c== 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) 0.0278 DP annular vol. @ zone of interest (bblttt) 0.0606 - - - DP annular vol. @ weak point bbl/ft 0.1444 Additional safety margin (psi) 0.00 <_= Data Input Weak point pressure (psi): PIO 1,852 si Weak point pressure - Safety margin: Pmax 1,852 psi Pmax EMW 13.50 pp Max anticipated formation pressure (psi): Pf 3,706 psi Weak Pt to Zone of Interest distance (ND ft): OH D 3,063' Weak Pt to Zone of Interest distance (MD ft): OH MD 9,980' - Maximum influx height at the bit (ND ft): H D 110' Maximum influx height at the bit (MD ft): H (MD) 291' Calc. volume of (H) around BHA: V1bha 5.6 bbl Calc. volume of (H) around drill pipe: V1dp 5.5 bbl Calc. volume that H equals @ initial shut in: V1 11.1 bbl Calc. vol. that H equals @ weak point (MD ft): V Wp 34.9 bbl _ Calc. volume of Vwp @ initial shut in: V2 Kick Tolerance: V1 11.1 bbi gNOTE- D 1 Transform Points j X Source coordinate system CO arget coordinate system State Plane 1927 - Alaska Zone 4 bers Equal Area (-150) WAD 1927 - North America Datum of 1927 (Mean] a M_ µO NAD 1927 - North America Datum of 1927 (Mean) F-4 Typevalues into the spreadsheet or copy and Paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to copy and Ctd+V to 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 l k ct a M— If -0 / PTD: ( l — ac' -3 v Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: K u�y u fes, i Ve k— POOL: KU rJ tr Ls k R3 Ve-y- V f' 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 PTD#:2190630 Company CONO_COPHILLIPS ALASKA INC Initial Class/rype Well Name: KUPARUK RIV UNIT 2M40 Program DEV Well bore seg ❑ DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 11 Permit. fee attached . . . ........ . . . . . . . ..... . . . . . . . . ...... . . . . . . NA - 2 Lease number appropriate. . ... ... ..................... Yes ... 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ ....... _ _ 4 Well located in a. defined pool . ...... . . . . . . . . .... . . . . . ....... . . . Yes 5 Well located proper distance from drilling unit -boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 6 Well lgcated proper distance from other wells . . . . . . . . ..... . .. . ...... . . . . Yes . 7 Sufficient acreage available in drilling unit. . ......... . . . . .... . . . . . . .. Yes 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . Directional_ plan view Twejlbore-profile erlclosed. 9 Operator only affected party- ... Yes 10 Operator has.appropriate bond in force______________________ Yes___.......________....______ 11 Permit on be issued without conservation order . . . . . . . . . .... . . . ....... . . Yes _ _ .... Appr Date 12 Permit can be issued without administrative approval _ _ __ _ _ ___ _ _ _ _ _ _ ____ _ _ _ _ _ Yes DLB 4/23/2019 13 Can permit be approved before 15 -day wait_ _ _ _ _ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ _ Yes .. 14 Well located within area and strata authorized by. Injection Order # (put 10# in comments).(For INA 15 All wells_within 1/4. mile area of review identified (For service well only) .... . .. . . . . . .. NA 16 Pre -produced injector; duration of pre -production less than 3 months (For service well only) . _ NA 17 18 Niprigonven. gas conforms to AS31,05,03QQ•1.A),(f2.A-D) _ _ _ _____ _ _ _ _ _ _____ _ _ _ _ Conductor string. provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. NA_ Yes . _ _ _ 139'_ conductor driven Engineering 19 Surface casing_ pJotects all known USDWs _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Surface casing set to 2993' MD 20 CMT. vol. adequate to circulate on.conductor & surf og _ ____ _ _ _ _ _ _ _ _ .... Yes _ _ _ _ 178%. excess cement planned 21 CMT vol adequate to tie-inlong 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 A. permafrost _ _ _ _ _ _ _ _ _ _ Yes .... 24 Adequate tankage or reserve. pit _ _ _ _ _ _ _ _ _ ____ _ _ _ _____ _ _ _ Yes .. _ Rig has steel tanks; all waste to approved disposal wells. 25 If a_re-drill, has.a 10-403 for abandonment been approved .... . . . . ... . . _ NA 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ _______ _ _ _ _ _ _ _ _ Yes ... Anticollision analysis complete; no major risk failures 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes .... _ Diverter sizeand route meet regulations _ _ _ _ ....... Appr Date 28 Drilling fluid program schematic & equip Jist adequate____ _ _ _ _ _ _ _ _ _ _ _ Yes ... _ _ Max formation pressure is 3670 psig(11.7 ppg EMW ); will drill w/ 8.8-12:2. 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 3066 psig; will test BOPs to 35QO.psig _ . _ _ _ _ ......... 31 Choke manifold complies w/API RP -53 (May 84)... _ _ _ _ _ .. _ _ _ _ _ Yes _ _ _____ 32 Work will occur without operation shutdown_ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ________ _ _ Yes 33 Js presence of H2$ gas probable____ _ _ _ _ _ _ _ _ ________ _ _ _ _ _ ___ _ _ _ _ _ _ ___ Yes .... _ 1-12S measures required_ _ . 34 Mechanical -condition of wells within AOR verified (For service well only) . . ....... . . . . . NA. 35 Permit can be issued w/o hydrogen sulfide measures ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No.. _ _ Wells on 2M_ -Pad are H2S-bearing. 1-12S measures required. Geology 36 Datapresented on potential overpressure zones _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas zones. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA... _ _ _ _ _ _ _ DLB 4/23/2019 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