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Home My WebLink About220-002ORIGINATED TRANSMITTAL DATE:6/12/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:03172020 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3026 RHEA-1 50-103-20823-00 CBL-Final Field 3/17/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown-Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 06/12/2020 Abby Bell Abby Bell 06/12/2020 PTD: 2200020 E-Set: 33360 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _____________________ Service Stratigraphic Test 2.Operator Name:6.Date Comp., Susp., or 14.Permit to Drill Number / Sundry: Aband.: 3. Address: 7.Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:48.6 17. Field / Pool(s): GL: 7.5 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13.Water Depth, if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20 112 103/4 L-80 2352 7 5/8 L-80 7189 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press.24-Hour Rate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAG ConocoPhillips Alaska, Inc.4/11/2020 220-002/320-100 P.O. Box 100360 Anchorage, AK 99510-0360 2/4/2020 50-103-20823-00-00 4621' FNL, 2535' FEL, Sec 13, T12N, R4E, UM 2/18/2020 CRU RHEA 1 4074' FNL, 3963' FEL, Sec 13, T12N, R4E, UM Colville River Unit/Fiord Oil Pool 4054' FNL, 4001' FEL, Sec 13, T12N, R4E, UM 6761/6497 ADL 25526 376281 5992781 7345/7037 LONS 19-007 374862 5993351 374824 5993372 N/A 1376/1377 N/A List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary CASING, LINER AND CEMENTING RECORD CASING WT. PER FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLEDTOP BOTTOM TOP 94 40 112 40 42 543sx 11.2ppg, Class G 254sx 13.0ppg, Class G 10 yds 45.5 39 2352 39 13.5 905 sx 11.0ppg, Class G 288 sx 15.8ppg, ClassG 29.7 37 7189 37 9.875x11 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 1/2 39.5 N/A Perfs cemented Off@: 150-1850 MD and 150-1850….....4/5/2020 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information surface -6695 217bbls 15.8ppg cement 6695-7345 MD 157 sx 17.0ppg, Class G PRODUCTION TEST N/A PLUGGED & ABANDONED Choke Size: Gas-Oil Ratio: Oil-Bbl:Water-Bbl: Date of Test: Oil-Bbl: Water-Bbl: Sr Pet Eng Sr Pet Geo Sr Res Eng Flow Tubing WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 4:45 pm, May 11, 2020 Abandon Date 4/11/2020 HEW RBDMS HEW 5/13/2020 xG DSR-5/13/2020SFD 5/13/2020VTL 8/12/20 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1376 1377 Top of Productive Interval 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chip Alvord Contact Name:Steve Drake Drilling Manager Contact Email:Steve.G.Drake@cop.com Authorized Contact Phone:263-4062 Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name: Authorized Title: Signature w/Date: Formation at total depth: If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Permafrost - Base Formation @ TPI - Kuparuk C Daily Operations Summary, Definitive Survey, Cement Report, Schematic 28. CORE DATA Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29.GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS NAME Well tested? Yes No Permafrost - Top NoSidewall Cores:Yes NoNoSidewall Cores: No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.05.11 16:23:58 -08'00' ,JOHBL DTTM START JOBTYP SUMMARYOPS 4/5/20 DRILLING SUPPORT - CAPITAL RIH WITH BDJSN, TAG ICE AT 677', COME ONLINE WITH DIESEL DOWN COIL, GOT THROUGH ICE AT 720', CRIH TO TAG AT 4668' RKB, PJSM WITH HES WHILE SOCIAL DISTANCING. COME ONLINE WITH HES CEMENTERS DOWN COIL WITH 5 BBLS FW FOLLOWED BY 217 BBLS 15.8 PPG CEMENT, WHILE POOH LAYING IN 1:1 AT 50' FROM SURFACE WE GAINED COMMUNICATION WITH THE OA. STOPPED MOVING PIPE, SHUT CHOKE AND OPENED UP TO TAKE RETURNS OFF OF OA. 5 BBL AWAY GOT GOOD CEMENT OUT THE OA. SHUT IN OA POOH TO 14', PRESSURE UP TO 2500 PSI ON WHP AND OA. MONITOR PRESSURES FOR 10 MIN, LOST 80 PSI, SHUT WELL IN CLEAN ACROSS TREE AND BOP'S. (READY FOR WELL INTEGRITY IN 72HRS.) 4/8/20 DRILLING SUPPORT - CAPITAL (P&A) T,IA & OA DDT (PASSED) 4/9/20 DRILLING SUPPORT - CAPITAL (P&A) REMOVE FLUID AND TREE FROM WELL 4/10/20 DRILLING SUPPORT - CAPITAL (P&A) REMOVE WELL HOUSE AND CUT WELL OFF AT 4.5' BELOW TUNDRA 4/11/20 DRILLING SUPPORT - CAPITAL (P&A) STATE WITNESS CEMENT AND MARKER PLATE WELD PLATE AND BURY RHEA 1 PLUG & ABANDON Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG: CEMENT - Witnessed by AOGCC, Austin McCLeod 6,695.0 2/22/2020 RHEA 1 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Cement to surface and marker plate + 4'6" below tuntra 4/11/2020 RHEA 1 pproven Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 46.2 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 94.00 Grade Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 46.0 Set Depth (ftKB) 2,352.2 Set Depth (TVD) … 2,352.1 Wt/Len (l… 45.50 Grade L-80 Top Thread TXP-M Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 48.5 Set Depth (ftKB) 7,189.2 Set Depth (TVD) … 6,892.9 Wt/Len (l… 29.70 Grade L80 Top Thread TXPM Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 44.2 44.2 0.00 MARKER PLATE Stateman Adam Earl witness cement to surface and marker plate + 4'6" below tuntra (he waived site clearance).- Weld marker plate 4/11/2020 0.000 4,666.0 4,573.1 23.67 Bridge Plug - Permanent Baker Cast Iron Bridge Plug 2/22/2020 0.000 10376 5201 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 150.0 152.0 150.0 152.0 3/27/2020 4.0 IPERF TITAN CIR-2107-4C501 200.0 202.0 200.0 202.0 3/25/2020 4.0 IPERF PAC-1562-457 500.0 502.0 500.0 502.0 3/17/2020 4.0 IPERF PAC-1562-457 1,208.0 1,210.0 1,208.0 1,210.0 3/16/2020 4.0 IPERF PAC-1562-457 1,605.0 1,610.0 1,604.9 1,609.9 3/10/2020 4.0 IPERF SLB 5' X 1.56" PUNCHER 1,808.0 1,810.0 1,807.9 1,809.9 3/9/2020 4.0 IPERF TITAN CIR-2107-4C501 1,848.0 1,850.0 1,847.9 1,849.9 3/8/2020 4.0 IPERF TITAN CIR-2107-4C501 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 6,695.0 7,345.0 6,436.5 7,037.1 Cement Plug 2/21/2020 Pumped balanced cement plug 7,345'MD-6,761'MD with 20 joint 3 1/2" EUE stinger. Tagged firm cement at 6,696'MD with 10K down and pressure tested to 1,750psi after WOC 11+ hours with AOGCC witness. 44.2 152.0 44.2 152.0 CEMENT PERFS 4/5/2020 15.8 ppg - 217 barrels 44.2 4,666.0 44.2 4,573.1 CEMENT TO SURFACE 4/5/2020 15.8 ppg - 217 barrels 44.2 46.2 44.2 46.2 P&A Cement 4/10/2020 Trim up all annulus cuts - 8'6" void in IA - filled with 8 gals cement. Notes: General & Safety End Date Annotation 2/23/2020 NOTE: Test adapter flange void and hanger seals to 250/5000psi 10mins each, good, witnessed by CPAI. 2/22/2020 NOTE: Tag firm cement at 6,695'MD 2/22/2020 NOTE: Observed differential pressure spike. Witnessed by AOGCC, Austin McCLeod RHEA 1, 5/11/2020 3:21:14 PM Vertical schematic (actual) INTERMEDIATE; 48.5-7,189.2 Intermediate Casing Cement; 6,478.0 ftKB Cement Plug; 6,639.0 ftKB Bridge Plug - Permanent; 4,666.0 Intermediate Casing Cement; 2,000.0 ftKB SURFACE; 46.0-2,352.2 IPERF; 1,848.0-1,850.0 IPERF; 1,808.0-1,810.0 IPERF; 1,605.0-1,610.0 IPERF; 1,208.0-1,210.0 Surface Casing Cement; 44.2 ftKB IPERF; 500.0-502.0 IPERF; 200.0-202.0 IPERF; 150.0-152.0 CONDUCTOR; 46.2-112.0 CEMENT PERFS; 44.2 ftKB MARKER PLATE; 44.2 CEMENT TO SURFACE; 44.2 ftKB P&A Cement; 44.2 ftKB WNS PROD KB-Grd (ft) 39.69 Rig Release Date 2/24/2020 RHEA 1 ... TD Act Btm (ftKB) 7,345.0 Well Attributes Field Name FIORD WEST KUPARUK Wellbore API/UWI 501032082300 Wellbore Status PROD Max Angle & MD Incl (°) 24.02 MD (ftKB) 4,265.26 WELLNAME WELLBORERHEA 1 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NONE DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:Mud log/GM/RES/NEU DEN/TEMP/SONIC COMP/SONIC Shear/FORM TEST/Rotary Sidewall Core/AZUM RES IMGNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/11/20203730 1634 Electronic Data Set, Filename: (3018) RHEA-1, Tubing Punch, 3-8-20, Field Log (correlation pass).las32134EDDigital DataC3/11/20202107 1575 Electronic Data Set, Filename: (3018) RHEA-1, Tubing Punch, 3-8-20, Field Log (shooting pass).las32134EDDigital DataC3/11/2020 Electronic File: (3018) RHEA-1, Tubing Punch, 3-8-20 (Field Log).pdf32134EDDigital DataC3/11/2020 Electronic File: (3018) RHEA-1, Tubing Punch, 3-8-20, Field Ticket & WSR.pdf32134EDDigital Data0 0 2200020 COLVILLE RIV UNIT RHEA 1 LOG HEADERS32134LogLog Header ScansC4/3/20202128 2 Electronic Data Set, Filename: (3026) RHEA-1, CBL-Punch, 3-17-20, Field Log.las32387EDDigital DataC4/3/2020 Electronic File: (3026) RHEA-1, CBL-Punch, 3-17-20, Field Log.pdf32387EDDigital Data0 0 2200020 COLVILLE RIV UNIT RHEA 1 LOG HEADERS32387LogLog Header ScansDF5/6/20206994 7341 Electronic Data Set, Filename: ConocoPhillips_Rhea_1_XMAC_DTC_DTS.las32986EDDigital DataDF5/6/20207140 7341 Electronic Data Set, Filename: RHEA-1_GR_XMAC_BHP_7150_7335_MD.las32986EDDigital DataDF5/6/20206696 7035 Electronic Data Set, Filename: RHEA-1_GR_XMAC_BHP_7150_7335_TVD.las32986EDDigital DataDF5/6/20207110 7336 Electronic Data Set, Filename: RHEA-1_GR_ZDL_CN_7150_7335_MD.las32986EDDigital DataTuesday, July 7, 2020AOGCCPage 1 of 10Supplied by OPSupplied by OP DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/20206821 7030 Electronic Data Set, Filename: RHEA-1_GR_ZDL_CN_7150_7335_TVD.las32986EDDigital DataDF5/6/20201760 7197 Electronic Data Set, Filename: RHEA-1_SBT_GR_1760_7190_MD.las32986EDDigital DataDF5/6/2020 Electronic File: ConocoPhillips_Rhea_1_XMAC_DTC_DTS.dlis32986EDDigital DataDF5/6/2020 Electronic File: ConocoPhillips_Rhea_1_XMAC_DTC_DTS.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_BHP_3D_7150_7335_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_BHP_3D_7150_7335_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_PCOR_5IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_PCOR_5IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_SBT_1760_7190_5IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_SBT_1760_7190_5IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_1IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_1IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_1IN_TVD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_1IN_TVD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_5IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_5IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_5IN_TVD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_7150_7335_5IN_TVD.PDF32986EDDigital DataTuesday, July 7, 2020AOGCCPage 2 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: RHEA-1_GR_XMAC_BHP_7150_7335_MD.dlis32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_1IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_1IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_1IN_TVD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_1IN_TVD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_5IN_MD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_5IN_MD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_5IN_TVD.meta32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_5IN_TVD.PDF32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_GR_ZDL_CN_7150_7335_MD.dlis32986EDDigital DataDF5/6/2020 Electronic File: RHEA-1_SBT_GR_1760_7190_MD.dlis32986EDDigital Data0 0 2200020 COLVILLE RIV UNIT RHEA 1 LOG HEADERS. E-sets 32992-32999 also on this transmittal32986LogLog Header ScansC7/7/2020 Electronic File: Rhea-1_RCAL_19-Jun-2020.xlsx32992EDDigital DataDF5/6/2020 Electronic File: 1a_7227.30.jpg32992EDDigital DataDF5/6/2020 Electronic File: 1b_7242.00.jpg32992EDDigital DataDF5/6/2020 Electronic File: 2__7241.50.jpg32992EDDigital DataDF5/6/2020115 7345 Electronic Data Set, Filename: RHEA-1_Mud Log_Raw Data_115-7345ft.LAS32993EDDigital DataDF5/6/2020 Electronic File: RHEA 1_GEOLOG_Final Well Report_Final.doc32993EDDigital DataDF5/6/2020 Electronic File: RHEA 1_GEOLOG_Final Well Report_Final.pdf32993EDDigital DataTuesday, July 7, 2020AOGCCPage 3 of 10RHEA-1_Mud,Log_Raw Data_115-7345ft.LAS DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: RHEA-1_Drilling Log_1 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Drilling Log_1 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Drilling Log_2 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Drilling Log_2 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Drilling Log_5 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Drilling Log_5 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_1 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_1 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_2 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_2 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_5 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Gas Ratio Log_5 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_1 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_1 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_2 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_2 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_5 inch.pdf32993EDDigital DataDF5/6/2020 Electronic File: RHEA-1_Mud Log_5 inch.tif32993EDDigital DataDF5/6/2020 Electronic File: Rhea 1 End of Well Summary_Waters Petroleum.doc32994EDDigital DataDF5/6/2020 Electronic File: Rhea 1 Geo Morning Report_Waters Petroleum.xlsx32994EDDigital DataDF5/6/20202223 7192 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD002_RM.las32995EDDigital DataDF5/6/202016 7344 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_RM.las32995EDDigital DataDF5/6/202022 2362 Electronic Data Set, Filename: CPAI_RHEA-1_VISION_Service_LWD001_RM.las32995EDDigital DataTuesday, July 7, 2020AOGCCPage 4 of 10CPAI_RHEA-,1_Scope_Service_RM.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/20206997 7344 Electronic Data Set, Filename: CPAI_RHEA-1_VISION_Service_LWD003_RM.las32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_Partner_FINAL_EOW.zip32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD001_RM.dlis32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD002_RM_Drilling.dlis32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD002_RM_ReamDown1.dlis32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD003_RM.dlis32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_Composite_RM.dlis32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_MicroScope_RM_30MD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_2MD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_2TVD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_5MD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_5TVD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_SonicScope_RM_5MD.Pdf32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD27 EOW Compass Surveys [Canvas].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD27 EOW Compass Surveys [Macro].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD27 EOW Compass Surveys [Petrel].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD27 EOW Compass Surveys [Survey].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD27 EOW Compass Surveys.pdf32995EDDigital DataTuesday, July 7, 2020AOGCCPage 5 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: Rhea 1 NAD83 EOW Compass Surveys [Canvas].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD83 EOW Compass Surveys [Macro].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD83 EOW Compass Surveys [Petrel].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD83 EOW Compass Surveys [Survey].txt32995EDDigital DataDF5/6/2020 Electronic File: Rhea 1 NAD83 EOW Compass Surveys.pdf32995EDDigital DataDF5/6/20202299 7100 Electronic Data Set, Filename: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_DTCO_2299-7100ft.las32996EDDigital DataDF5/6/20202299 7100 Electronic Data Set, Filename: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_QP_2299-7100ft.las32996EDDigital DataDF5/6/20207090 7225 Electronic Data Set, Filename: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_MP_7090-7225ft.las32996EDDigital DataDF5/6/20207090 7225 Electronic Data Set, Filename: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_QP_7090-7225ft.las32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_Processed_SonicScope_2299-7225ft.zip32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_DTCO_2299-7100ft.dlis32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_DTCO_2299-7100ft.pdf32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_QP_2299-7100ft.dlis32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R2_9.875in_SonicScope675_Drill_QP_2299-7100ft.pdf32996EDDigital DataTuesday, July 7, 2020AOGCCPage 6 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_MP_7090-7225ft.dlis32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_MP_7090-7225ft.pdf32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_QP_7090-7225ft.dlis32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R3_6.25in_SonicScope475_Drill_QP_7090-7225ft.pdf32996EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_R3_6.5in_PROCESSED_StethoScope.zip32997EDDigital DataDF5/6/2020 Electronic File: CPAI_Rhea-1_6.5in_Run 3_STETHOSCOPE_RM_Report.pdf32997EDDigital DataDF5/6/2020 Electronic File: CPAI_Rhea-1_Run3_StethoScope_RT_Report.pdf32997EDDigital DataDF5/6/2020 Electronic File: CPAI_Rhea-1_6.5in_Run 3_StethoScope_TPT_RM.xlsx32997EDDigital DataDF5/6/2020 Electronic File: CPAI_Rhea-1_StethoScope_RT_TestPointTable.xlsx32997EDDigital DataDF5/6/20201452 1908 Electronic Data Set, Filename: CPAI_RHEA-1_Puncher_10MAR2020_Correlation_ConCu_R01_L002Up_PUNCHER_CCL.las32998EDDigital DataDF5/6/20201424 1710 Electronic Data Set, Filename: CPAI_RHEA-1_Puncher_10MAR2020_Shooting_ConCu_R01_L003Up_PUNCHER_CCL.las32998EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA_1_TUBING_PUNCH_10Mar20.zip32998EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Puncher_10MAR2020_Correlation_ConCu_R01_L002Up_PUNCHER_CCL.dlis32998EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Puncher_10MAR2020_Shooting_ConCu_R01_L003Up_PUNCHER_CCL.dlis32998EDDigital DataTuesday, July 7, 2020AOGCCPage 7 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: CPAI_RHEA_5in_Tubing_Punch_10Mar20.Pdf32998EDDigital DataDF5/6/202039 7345 Electronic Data Set, Filename: CPAI_RHEA-1_Drilling_Mechanics_Depth.las32999EDDigital DataDF5/6/202016 7344 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_Composite_RT.las32999EDDigital DataDF5/6/202016 2362 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD001_RT.las32999EDDigital DataDF5/6/20202272 7192 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD002_RT.las32999EDDigital DataDF5/6/20207072 7344 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD003_RT.las32999EDDigital DataDF5/6/202016 7344 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_Composite_RM.las32999EDDigital DataDF5/6/202022 2362 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD001_RM.las32999EDDigital DataDF5/6/20202223 7192 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD002_RM.las32999EDDigital DataDF5/6/20206997 7344 Electronic Data Set, Filename: CPAI_RHEA-1_Scope_Service_LWD003_RM.las32999EDDigital DataDF5/6/202043863 43866 Electronic Data Set, Filename: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD001.las32999EDDigital DataDF5/6/202043871 43875 Electronic Data Set, Filename: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD002.las32999EDDigital DataDF5/6/202043878 43881 Electronic Data Set, Filename: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD003.las32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Final Deliverables.zip32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_Composite_RM.dlis32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD001_RM.dlis32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD002_RM_Drilling.dlis32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD002_RM_TripIn1.dlis32999EDDigital DataTuesday, July 7, 2020AOGCCPage 8 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_LWD003_RM.dlis32999EDDigital DataDF5/6/2020 Electronic File: RHEA-1 EOW Letter.doc32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Drilling_Mechanics_Depth.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RT_2MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RT_2TVD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RT_5MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RT_5TVD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_MicroScope_RM_30MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_2MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_2TVD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_5MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Scope_Service_RM_5TVD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_SonicScope_RM_5MD.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD001.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD002.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Drilling_Mechanics_Time_LWD003.Pdf32999EDDigital DataDF5/6/2020 Electronic File: CPAI_RHEA-1_Surveys.csv32999EDDigital DataC6/12/20202128 2 Electronic Data Set, Filename: (3026) RHEA-1, CBL-Punch, 3-17-20, Field Log.las33360EDDigital DataC6/12/2020 Electronic File: (3026) RHEA-1, CBL-Punch, 3-17-20, Field Log.pdf33360EDDigital DataTuesday, July 7, 2020AOGCCPage 9 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20823-00-00Well Name/No. COLVILLE RIV UNIT RHEA 1Completion Status1-OILCompletion Date2/25/2020Permit to Drill2200020Operator ConocoPhillips Alaska, Inc.MD7345TVD7037Current StatusP&A7/7/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:2/25/2020Release Date: 1/27/20200 0 2200020 COLVILLE RIV UNIT RHEA 1 LOG HEADERS33360LogLog Header ScansC6/17/2020506 182 Electronic Data Set, Filename: (3030) RHEA 1, Punch, 3-25-2020, Field Logs.las33382EDDigital DataC6/17/2020 Electronic File: (3030) RHEA 1, Punch, 3-25-2020, Field Logs.pdf33382EDDigital Data0 0 2200020 COLVILLE RIV UNIT RHEA 1 LOG HEADERS33382LogLog Header Scans3/17/2020100 70391741CuttingsTuesday, July 7, 2020AOGCCPage 10 of 10M Guhl 7/7/2020 TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Rhea 1 DATE: 07/09/2020 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP Photos – 13.3 MB RCAL – 247 KB Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: Rhea 1- e-transmittal well folder Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 By Meredith Guhl at 1:27 pm, Jul 07, 2020 220-002 T32992 M. Guhl 7/7/2020 -added to T32992 -received 5/6/2020 ORIGINATED TRANSMITTAL DATE:6/16/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:03252020 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3030 RHEA 1 50-103-20823-00 CCL-Final Field 3/25/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown-Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 06/17/2020 PTD: 2200020 E-Set: 33382 Abby Bell Abby Bell 06/17/2020 ORIGINATED TRANSMITTAL DATE:6/12/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:03172020 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3026 RHEA-1 50-103-20823-00 CBL-Final Field 3/17/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown-Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 06/12/2020 Abby Bell Abby Bell 06/12/2020 PTD: 2200020 E-Set: 33360 TT RR AA NN SS MM II TT TT AA LL FROM: Sandra D. Lemke, ATO-704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Rhea 1 DATE: 05/05/2020 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: Rhea 1- e-transmittal well folder Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 Received by the AOGCC on 05/06/2020 PTD: 2200020 E-Set: 32986 Abby Bell 05/06/2020 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� 511 ��` DATE: April 16, 2020 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector CRU RHEA -1 ConocoPhillips Alaska Inc. PTD 2200020; Sundry 320-100 4/11/2020: 1 traveled out to Alpine West to witness the surface abandonment of CRU RHEA -1. The well was cut off at 50 inches below tundra grade. It had cement to surface in the tubing and annular voids. It looked as if the tubing cement had settled a half inch or so. I took a bar and hammered down on all voids. Cement was good and solid. I verified the numbers on the marker plate. The general well area looked good and clean with no debris. No issues Attachments: Photos (2) - 2020-0411_Surface_Abandon_CRU_RHEA-1_ae.docx Page 1 of 2 O N O O O N N J,Ir l_e k4hir s t 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _____________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:48.6 17. Field / Pool(s): GL: 7.5 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20 112 103/4 L-80 2352 7 5/8 L-80 7189 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press. 24-Hour Rate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAG ConocoPhillips Alaska, Inc.2/25/2020 220-002 P.O. Box 100360 Anchorage, AK 99510-0360 2/4/2020 50-103-20823-00-00 4621' FNL, 2535' FEL, Sec 13, T12N, R4E, UM 2/18/2020 CRU RHEA 1 4074' FNL, 3963' FEL, Sec 13, T12N, R4E, UM 4954' FNL, 4001' FEL, Sec 13, TX12N, R4E, UM 6761/6497 ADL 25526 376281 5992781 7345/7037 LONS 19-007 374862 5993351 374824 5993372 N/A 1376/1377 N/A List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary CASING, LINER AND CEMENTING RECORD Mud Log/GM/Res/Neutron Density/Temperature/Sonic Compression/Sonic Shear/Formation Tester/ Rotary Sidewall Core/Azumuthal Resistivity Image CASING WT. PER FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLEDTOP BOTTOM TOP 94 40 112 40 42 10 yds 45.5 39 2352 39 13.5 905 sx 11.0ppg, Class G 288 sx 15.8ppg, ClassG 29.7 37 7189 37 9.875x11 543sx 11.2ppg, Class G 254sx 13.0ppg, Class G TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 1/2 39.5 N/A CEMENTED IN PREPARATION FOR ABANDONMENT ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information 6761-7345 MD 157 sx 17.0ppg, Class G PRODUCTION TEST N/A TO BE PLUGGED & ABANDONED Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Sr Pet Eng Sr Pet Geo Sr Res Eng Colville River Unit/Fiord Oil Pool Flow Tubing Oil-Bbl:Water-Bbl: WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 8:35 am, Apr 06, 2020 RBDMS HEW 4/14/2020 Completion Date 2/25/2020 HEW SFD 4/6/2020 4054 4954 DSR-4/6/2020VTL 5/5/20 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1376 1377 Top of Productive Interval 7230 6931 2453 2453 3052 3051 3879 3852 K2 4079 4036 Albian 96 6161 5945 6577 6328 7245 6944 Alpine C 7264 6962 UJU 7266 6964 TD 7345 7037 Kingak E 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chip Alvord Contact Name:Tom Polasek Drilling Manager Contact Email:tom.g.polasek@cop.com Authorized Contact Phone:263-3740 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Daily Operations Summary, Definitive Survey, Cement Report, Schematic 28. CORE DATA Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS NAME Well tested? Yes No 7242' MD/6942' TVD Sandstone Oil Presence Permafrost - Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Permafrost - Base Formation @ TPI - Kuparuk C C30 7232' MD to 7243' MD C10 K3 HRZ Miluveach Formation at total depth: Fluid Density 0.83g/cc Pressure Gradient 0.36psi/ft Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name: Authorized Title: Signature w/Date: 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. 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). NoSidewall Cores:Yes NoNoSidewallCores: No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment G. L. Alvord Digitally signed by G. L. Alvord Date: 2020.04.03 15:26:24 -08'00' 6.5" Open Hole TD ~7339' MD 20" Conductor to 120' Kuparuk C Sand Top ~7229' MD / ~6931' TVD Rhea 1, FWK Pilot – Slant Completed with No Kill String Proposed Schematic updated 2/18/20, D25, RKB 39.7 ft 13.5" Open Hole with 10.75" 45.5 ppf L-80 TXP 2,352' MD / 2,352' TVD Kalubik Nechelik Top ~7450' MD 9-7/8" X 11" Underreamed Openhole with Top Set Casing 7 5/8" 29.7 ppf L-80 TXP 7189' MD / 6894' TVD @ 22.7° HES Stage Cementer 6579' MD / 6___' TVD LCU ~7239' MD / ~6942' TVD Qannik Sand Top 4079' MD / 4063' TVD Qannik Sand Base 4182' MD / 4134' TVD C30 Sand Top 2480' MD / 2480' TVD HRZ Top 6577' MD / 6333' TVD Cement Plug Top 300 ft Inside Casing 15.8 ppg Cement TOC at Stage Cementer 11.2 ppg Cement TOC ~ 2000' MD / 2000' TVD (will confirm with CBL) CIBP Baker CIBP ~4668' MD / ~4582' TVD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG: CEMENT - Witnessed by AOGCC, Austin McCLeod 6,695.0 2/22/2020 RHEA 1 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Prep for P&A RHEA 1 claytg Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 39.7 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 94.00 Grade Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 39.5 Set Depth (ftKB) 2,352.2 Set Depth (TVD) … 2,352.1 Wt/Len (l… 45.50 Grade L-80 Top Thread TXP-M Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 37.0 Set Depth (ftKB) 7,189.2 Set Depth (TVD) … 6,892.9 Wt/Len (l… 29.70 Grade L80 Top Thread TXPM Tubing Strings Tubing Description TUBING GUIDE STRING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 34.8 Set Depth (ft… 39.5 Set Depth (TVD) (… 39.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.8 34.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril HYD 563 3.958 38.2 38.2 0.00 MULE SHOE WLEG 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 4,666.0 4,573.1 23.67 Bridge Plug - Permanent Baker Cast Iron Bridge Plug 2/22/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 150.0 152.0 150.0 152.0 3/27/2020 4.0 IPERF TITAN CIR-2107-4C501 200.0 202.0 200.0 202.0 3/25/2020 4.0 IPERF PAC-1562-457 500.0 502.0 500.0 502.0 3/17/2020 4.0 IPERF PAC-1562-457 1,208.0 1,210.0 1,208.0 1,210.0 3/16/2020 4.0 IPERF PAC-1562-457 1,605.0 1,610.0 1,604.9 1,609.9 3/10/2020 4.0 IPERF SLB 5' X 1.56" PUNCHER 1,808.0 1,810.0 1,807.9 1,809.9 3/9/2020 4.0 IPERF TITAN CIR-2107-4C501 1,848.0 1,850.0 1,847.9 1,849.9 3/8/2020 4.0 IPERF TITAN CIR-2107-4C501 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 6,695.0 7,345.0 6,436.5 7,037.1 Cement Plug 2/21/2020 Pumped balanced cement plug 7,345'MD-6,761'MD with 20 joint 3 1/2" EUE stinger. Tagged firm cement at 6,696'MD with 10K down and pressure tested to 1,750psi after WOC 11+ hours with AOGCC witness. Notes: General & Safety End Date Annotation NOTE: RHEA 1, 3/30/2020 6:33:26 AM Vertical schematic (actual) INTERMEDIATE; 37.0-7,189.2 Cement Plug; 6,639.0 ftKB Bridge Plug - Permanent; 4,666.0 SURFACE; 39.5-2,352.2 IPERF; 1,848.0-1,850.0 IPERF; 1,808.0-1,810.0 IPERF; 1,605.0-1,610.0 IPERF; 1,208.0-1,210.0 IPERF; 500.0-502.0 IPERF; 200.0-202.0 IPERF; 150.0-152.0 CONDUCTOR; 39.7-112.0 MULE SHOE; 38.2 HANGER; 34.8 WNS PROD KB-Grd (ft) 39.69 Rig Release Date 2/24/2020 RHEA 1 ... TD Act Btm (ftKB) 7,345.0 Well Attributes Field Name FIORD WEST KUPARUK Wellbore API/UWI 501032082300 Wellbore Status PROD Max Angle & MD Incl (°) 24.02 MD (ftKB) 4,265.26 WELLNAME WELLBORERHEA 1 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NONE Page 1/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2020 00:00 1/28/2020 06:00 6.00 MIRU MOVE RURD P Fuel for moving. Blowed down steam. Lowered cattle chute. Raised C- Section and pin. Lower derrick rams and pin in place. 0.0 0.0 1/28/2020 06:00 1/28/2020 08:00 2.00 MIRU MOVE RURD P Skidded rig floor. Stomped casing shed out of way and onto suspension. 0.0 0.0 1/28/2020 08:00 1/28/2020 09:30 1.50 MIRU MOVE RURD P Lowered derrick. Stomped and moved motor complex. 0.0 0.0 1/28/2020 09:30 1/28/2020 12:00 2.50 MIRU MOVE RURD P PJSM w/ Peak. Staged casing module to end of pad. Moved ball mill out of the way. Unpinned pipe shed f/ sub. 0.0 0.0 1/28/2020 12:00 1/28/2020 18:00 6.00 MIRU MOVE RURD P Raised sub. Stomped pipe shed out from under sub. Hooked up truck. Swapped out hydraulic moving system pump on motor complex. 0.0 0.0 1/28/2020 18:00 1/29/2020 00:00 6.00 MIRU MOVE RURD P Staged pipeshed at entrance of pad w/ casing shed. Stomped motor and pump complexes away f/ modules and on suspensions for trucks. 0.0 0.0 1/29/2020 00:00 1/29/2020 06:00 6.00 MIRU MOVE MOB P Moved hydraulics unites on modules.and kept warm. rebuilt hydraulics pump on pit module. 0.0 0.0 1/29/2020 06:00 1/29/2020 12:00 6.00 MIRU MOVE MOB P Continued to rebuild/replace pump on pits moving hydraulics. Laid Herculite down at Rhea pad and laid mats. Installed hydraulic pin on sub. Stomped away f/ sub module. SIMOPS: Installed teflon bearings on agitators in mud pits. 0.0 0.0 1/29/2020 12:00 1/29/2020 18:00 6.00 MIRU MOVE MOB P Stomped sub off of the CD5-96. Oriented towards entrance of the pad. Installed and pinned transport jeep onto sub. SIMOPS: Installed diverter line onto diverter Tee on Rhea 1. 0.0 0.0 1/29/2020 18:00 1/30/2020 00:00 6.00 MIRU MOVE MOB P Installed Herculite around sub suspension/moving system to warm up w/ air heaters. All modules staged in series at pad entrance.Preparing for rig move. Tire pressure dropped due to sub zero temperatures. Inflating tires on casing and pipeshde modules prior to move. 0.0 0.0 1/30/2020 00:00 1/30/2020 06:00 6.00 MIRU MOVE MOB P Moved off CD-5 w/ pipeshed and casing complexes. SIMOPS: Continued to prep and check tires on sub for move. 0.0 0.0 1/30/2020 06:00 1/30/2020 10:00 4.00 MIRU MOVE MOB P Continued to move pipeshed and casing complexes to Rhea 1 and stage on location SIMOPS: Installed diverter on starter head. 0.0 0.0 1/30/2020 10:00 1/30/2020 12:00 2.00 MIRU MOVE MOB P Moved off CD5 w/ sub module to Rhea 1. 0.0 0.0 1/30/2020 12:00 1/30/2020 18:00 6.00 MIRU MOVE MOB P Arrive w/ sub module at Rhea 1. 0.0 0.0 1/30/2020 18:00 1/30/2020 20:30 2.50 MIRU MOVE MOB P Unhooked trucks and cats from sub and removed jeep. 0.0 0.0 1/30/2020 20:30 1/30/2020 22:00 1.50 MIRU MOVE MOB P Stomped sub over well. SIMOPS: Peak to head back and grab other complexes. 0.0 0.0 1/30/2020 22:00 1/31/2020 00:00 2.00 MIRU MOVE MOB P Staged pit, pump, and motor complexes at end of CD5 to move to Rhea 1. SIMOPS: Rolled out Herculite and laid mats as per plan on Rhea 1. 0.0 0.0 Rig: PW AKE-305 - Priority Page 2/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/31/2020 00:00 1/31/2020 02:00 2.00 MIRU MOVE MOB P Left CD5 w/ pits, pump, and power complexes. SIMOPS: Continued to lay mats and herculite per plan on Rhea 1. 0.0 0.0 1/31/2020 02:00 1/31/2020 07:30 5.50 MIRU MOVE MOB P Staged pits, pump, and power modules at Rhea pad. 0.0 0.0 1/31/2020 07:30 1/31/2020 12:00 4.50 MIRU MOVE MOB P Spotted pipe shed w/ trucks. Stomped and pinned to sub. Spotted pits and pump room on matts. 0.0 0.0 1/31/2020 12:00 1/31/2020 15:00 3.00 MIRU MOVE MOB P Continued to spot pipe shed and pin to sub base. Mobilized shop and parts houses f/ CD5 to move to CD-2. 0.0 0.0 1/31/2020 15:00 1/31/2020 18:00 3.00 MIRU MOVE MOB P Continued to spot pipe shed and pin to sub base. Laid Herculite and mats for motor complex. Moving shop and parts houses f/ CD5 to CD2. 0.0 0.0 1/31/2020 18:00 2/1/2020 00:00 6.00 MIRU MOVE MOB P Continued to spot pipe shed and pin to sub base. Moved motor complex into position. Moving shop and parts houses f/ CD5 to CD2. 0.0 0.0 2/1/2020 00:00 2/1/2020 06:00 6.00 MIRU MOVE RURD P Shimmed pipe shed and pinned to the sub base. Spotted casing shed with truck and stomped to pipe shed. Stomped and spotted pits to sub complex. Lowered cellar walls. 0.0 0.0 2/1/2020 06:00 2/1/2020 10:30 4.50 MIRU MOVE RURD P Stomped ans spotted casing shed. SIMOPS: Continued to stomp and spot pit complex. Put Tioga heaters on hydraulic stompers on all complexes. Hooched and Heated derrick. Raised cylinders. C/O hydraulic clamp and o- ring on pit complex. 0.0 0.0 2/1/2020 10:30 2/1/2020 12:00 1.50 MIRU MOVE RURD P Stomped and spotted pump and power complexes. SIMOPS: Plugged in casing and pit complexes. 0.0 0.0 2/1/2020 12:00 2/1/2020 15:00 3.00 MIRU MOVE RURD P Stomped spotted, and shimmed power complex. SIMOPS: Plugged in pump comlex, Chinked up cellar and ran Tioga heaters. Filled sub HPU w/ hydraulic oil. 0.0 0.0 2/1/2020 15:00 2/1/2020 16:00 1.00 MIRU MOVE RURD P Raised derrick. SIMOPS: Worked on interconnects, laid Herculite and mats for ball mill. 0.0 0.0 2/1/2020 16:00 2/1/2020 18:00 2.00 MIRU MOVE RURD P Skidded rig floor. SIMOPS: Plugged in rig floor. Continued working on interconnects, and steamed the rig floor. 0.0 0.0 2/1/2020 18:00 2/1/2020 21:00 3.00 MIRU MOVE RURD P Lowered C-Section. Continued to steam the rig floor. 0.0 0.0 2/1/2020 21:00 2/2/2020 00:00 3.00 MIRU MOVE RURD P Raised cattle chute. Installed roof covers and chink rig floor. Started hooking up interconnects in pits. Cleared rig floor for scoping the derrick. 0.0 0.0 2/2/2020 00:00 2/2/2020 04:00 4.00 MIRU MOVE RURD P R/U to scope up derrick. Scoped derrick and set saddles. Hooked up derrick lights and rigged down scoping equipment. Finished pits interconnect lines. Geolog ran umbilical cord and lines to pit room. 0.0 0.0 Rig: PW AKE-305 - Priority Page 3/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/2/2020 04:00 2/2/2020 05:00 1.00 MIRU MOVE RURD P Turned on steam to the BOP deck. Hooked up rig floor cement hose, and kelly hose. Secured kill line valve. Chinked up well house. Geolog continued to run umbilical cord and lines to pit room. 0.0 0.0 2/2/2020 05:00 2/2/2020 06:00 1.00 MIRU MOVE RURD P Gathered RKB's. Picked up riser and cleaned ring grooves. Brought in SLB DD tools for BHA #1 into the pipe shed. 0.0 0.0 2/2/2020 06:00 2/2/2020 11:30 5.50 MIRU MOVE NUND P N/U surface riser, annular, flow box, and flow line. 0.0 0.0 2/2/2020 11:30 2/2/2020 12:00 0.50 MIRU MOVE RURD P Got heater on surface annular and Koomey unit. 0.0 0.0 2/2/2020 12:00 2/2/2020 13:30 1.50 MIRU MOVE RURD P Continued to heat surface annular and Koomey Unit. SIMOPS: P/U 5" handling equipment and M/U 1 stand of 5" DP. 0.0 0.0 2/2/2020 13:30 2/2/2020 14:00 0.50 MIRU MOVE BOPE P Functioned annular and knife valve. 0.0 0.0 2/2/2020 14:00 2/2/2020 15:00 1.00 MIRU MOVE BOPE P Tested diverter system and performed Koomey drawdown. ACC = 3000 psi, Manifold = 1500 psi, ACC = 2050 psi after all functions on bottles 10 sec for 200 psi build w/ 2 electric pumps. 46 sec to build full system pressure w/ 2 electric pumps and 2 air pumps.Annular closing time = 28 sec. Knife valve open time = 21 sec. 6 Bottles N2 Avg = 1800 psi. Tested LEL and H2S gas alarms. Witnessed by AOGCC rep Austin McCleod. 0.0 0.0 2/2/2020 15:00 2/2/2020 16:00 1.00 MIRU MOVE RURD P Centered surface equipment and attempted to install low pressure riser. 0.0 0.0 2/2/2020 16:00 2/2/2020 18:00 2.00 MIRU MOVE RURD P Moved BHA and processed 5" DP to pick up. 0.0 0.0 2/2/2020 18:00 2/2/2020 22:00 4.00 MIRU MOVE RURD P Continued to process 5" DP in pipe shed. SIMOPS: P/U BHA #1 subs to rig floor. Serviced top drive. Added oil to gear box and topped off hydraulics. 0.0 0.0 2/2/2020 22:00 2/3/2020 00:00 2.00 MIRU MOVE BHAH T Pipe skate contacted cattle chute door when preparing to pick up drill pipe. Safety stand down was held w/ Field Drilling Supervisor. Prepped to lay down the cattle chute door. 0.0 0.0 2/3/2020 00:00 2/3/2020 02:00 2.00 MIRU MOVE RGRP T L/D cattle chute door. Cleaned and cleared rigging. 0.0 0.0 2/3/2020 02:00 2/3/2020 03:00 1.00 MIRU MOVE RURD P P/U mouse hole for building stands of 5" DP. 0.0 0.0 2/3/2020 03:00 2/3/2020 06:00 3.00 MIRU MOVE PULD P P/U 5" DP f/ pipe shed and racked back in derrick. 0.0 0.0 2/3/2020 06:00 2/3/2020 07:00 1.00 MIRU MOVE PULD P Continued to P/U 5" DP f/ pipe shed w/ mousehole and rack back in derrick. 0.0 0.0 2/3/2020 07:00 2/3/2020 09:30 2.50 MIRU MOVE RGRP T Removed cattle chute raising cylinder hydraulic lines and clamps. Plugged/capped cylinders and hoses. Inspected pipe skate and chain. Held a safety stand down. 0.0 0.0 2/3/2020 09:30 2/3/2020 12:00 2.50 MIRU MOVE PULD P Continued to P/U 5" DP f/ pipe shed and rack back in derrick. 0.0 0.0 2/3/2020 12:00 2/3/2020 16:30 4.50 MIRU MOVE PULD P Continued to P/U 5" DP f/ pipe shed and rack back in derrick. Total of 55 stands. 0.0 0.0 Rig: PW AKE-305 - Priority Page 4/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/3/2020 16:30 2/3/2020 17:30 1.00 MIRU MOVE RURD P Swapped out and installed low pressure riser. 0.0 0.0 2/3/2020 17:30 2/3/2020 18:00 0.50 MIRU MOVE PULD P Continued to P/U 5" HWDP. 0.0 0.0 2/3/2020 18:00 2/3/2020 20:30 2.50 MIRU MOVE BHAH P Finished P/U 5" HWDP and jars. Racked back in the derrick. L/D rotary mouse hole and built 7" drill collar stand. Racked back in derrick. 0.0 0.0 2/3/2020 20:30 2/3/2020 21:30 1.00 MIRU MOVE OTHR P PJSM on hanging cattle chute door. Hung door and prepped for picking up BHA #1. 0.0 0.0 2/3/2020 21:30 2/3/2020 22:15 0.75 MIRU MOVE PRTS P Flood lines and pressure test surface lines. Blow down. Function test annular preventor. 0.0 0.0 2/3/2020 22:15 2/4/2020 00:00 1.75 MIRU MOVE BHAH P P/U and scribed BHA #1. 0.0 0.0 2/4/2020 00:00 2/4/2020 00:45 0.75 MIRU MOVE SFTY P Prespud meeting. 0.0 0.0 2/4/2020 00:45 2/4/2020 01:30 0.75 MIRU MOVE TRIP P RIH. Filled conductor. Pumped 30 bbls to fill. Function tested MWD. Tagged bottom at 112' MD. 0.0 112.0 2/4/2020 01:30 2/4/2020 04:00 2.50 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 112' MD to 212' MD (212' TVD). 4klbs, 475 gpm, SPP on/off = 530psi/N/A, 50rpm, Torq on/off = 2kftlbs/2klftlbs, 65% FO, PU/SO/RTW = 65klbs/65klbs/65klbs. 112.0 212.0 2/4/2020 04:00 2/4/2020 05:00 1.00 SURFAC DRILL EQRP T Low pressure riser slipped out of air boot. Racked back one stand. Blew down Top drive. Drained stand. Pulled the master bushings, inspected and reinstalled low pressure riser. 212.0 212.0 2/4/2020 05:00 2/4/2020 06:00 1.00 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 212' MD to 237' MD (237' TVD). 8klbs, 525 gpm, SPP on/off = 640psi/740psi, 40rpm, Torq on/off = 4kftlbs/0klftlbs, 65% FO, PU/SO/RTW = 67klbs/67klbs/67klbs. AST/ART/ADT/ Total bit Hours = 0hrs/2.36hrs/2.36hrs/2.36hrs. 212.0 237.0 2/4/2020 06:00 2/4/2020 12:00 6.00 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 237' MD to 1,034' MD (1,034' TVD). 4klbs, 544 gpm, SPP on/off = 1080psi/1009psi, 60rpm, Torq on/off = 4kftlbs/1klftlbs, 80% FO, PU/SO/RTW = 69klbs/90klbs/83klbs. AST/ART/ADT/Total bit Hrs/Total Jar Hrs=0.22hrs/2.42hrs/2.64hrs/6.11hrs/1 05.8hrs. 237.0 1,034.0 2/4/2020 12:00 2/4/2020 16:30 4.50 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 1,034' MD to 1,600' MD (1,600' TVD). 5klbs, 625 gpm, SPP on/off = 1450psi/1241psi, 80rpm, Torq on/off = 4kftlbs/1klftlbs, 82% FO, PU/SO/RTW = 78klbs/94klbs/84klbs. 1,034.0 1,738.0 2/4/2020 16:30 2/4/2020 17:15 0.75 SURFAC DRILL RGRP T Change out O-Ring on mud line between rig module and pit module. 1,600.0 1,600.0 Rig: PW AKE-305 - Priority Page 5/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/4/2020 17:15 2/4/2020 18:00 0.75 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 1,600' MD to 1,738' MD (1,738' TVD). 5klbs, 625 gpm, SPP on/off = 1450psi/1241psi, 80rpm, Torq on/off = 4kftlbs/1klftlbs, 82% FO, PU/SO/RTW = 78klbs/94klbs/84klbs. AST/ART/ADT/Total bit Hrs/Total Jar Hrs=0.46hrs/8.34hrs/2.91hrs/9.02hrs/1 08.7hrs. 1,034.0 1,738.0 2/4/2020 18:00 2/5/2020 00:00 6.00 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 1,738' MD to 2,340' MD (2,340' TVD). 11klbs, 700 gpm, SPP on/off = 1865psi/1775psi, 80rpm, Torq on/off = 4.5kftlbs/1.5klftlbs, 73% FO, ECD = 11.65 ppg, PU/SO/RTW = 127klbs/115klbs/110klbs. AST/ART/ADT/Total bit Hrs/Total Jar Hrs=0hrs/12.97hrs/4.63hrs/13.65hrs/1 13.4hrs 1,738.0 2,340.0 2/5/2020 00:00 2/5/2020 00:30 0.50 SURFAC DRILL DRLG P Drilled 13 1/2" surface hole f/ 2,340' MD-2,363'MD (2,363' TVD) final surface TD. 11klbs WOB, 700 gpm, SPP on/off = 1870psi/1792psi, 80rpm, Torq on/off = 4.5kftlbs/1.5klftlbs, 73% FO, ECD = 11.68 ppg, PU/SO/RTW = 127klbs/115klbs/110klbs. BHA#1, TST=0.68, TRT=13.16, ADT=13.84,Total Jar Hrs=113.84hrs 1,738.0 2,363.0 2/5/2020 00:30 2/5/2020 04:30 4.00 SURFAC CASING CIRC P Circulate, rotate and reciprocate at 2,363'MD, 704gpm, 1785psi, 74% FO, 60rpm, 1.5k TQ, 11.48ppg ECD, PU/SO/RTW=115k/104k/96k, total strokes pumped 22,700, racking back one stand each bottoms up, and pumped 40bbl weighted Nut Plug sweep after each stand. OWFF @ 2,074' while rotating at 5rpm for 30min, static. SIMOPS=Pick-up PS-21 slips and casing tools. 2,363.0 2,074.0 2/5/2020 04:30 2/5/2020 06:00 1.50 SURFAC CASING PMPO P Rig-up hole fill line, get mark on trip tank. POOH from 2,074'-952', racking back 5" in DP. PU/SO/=106k/98K, monitor displacement on trip tank #3. 2,074.0 952.0 2/5/2020 06:00 2/5/2020 07:30 1.50 SURFAC CASING TRIP P Continue POOH from 952' to 123', PU/SO=80K/75K 952.0 123.0 2/5/2020 07:30 2/5/2020 09:30 2.00 SURFAC CASING BHAH P LD BHA as per Schlum DD. 123.0 0.0 2/5/2020 09:30 2/5/2020 10:30 1.00 SURFAC CASING BHAH P Clean and clear floor. 0.0 0.0 2/5/2020 10:30 2/5/2020 11:30 1.00 SURFAC CASING PULD P Rig up to run Surface casing, hold PJSM. 0.0 0.0 2/5/2020 11:30 2/5/2020 12:00 0.50 SURFAC CASING SVRG P Service rig and recalibrate Amphion Screens 0.0 0.0 2/5/2020 12:00 2/5/2020 13:30 1.50 SURFAC CASING PULD P RIH with 10 3/4", 45.5ppf, L-80 TXP casing installing centralizers as per detail. Baker-Lok shoe track joints. Pump through shoe and check floats. 0.0 800.0 2/5/2020 13:30 2/5/2020 14:00 0.50 SURFAC CASING EQRP T Blow down top drive and rig down Volant tool. Re-spooled drilling line onto draw works drum as 3 wraps jumped due to cold inclement weather. 800.0 800.0 Rig: PW AKE-305 - Priority Page 6/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2020 14:00 2/5/2020 15:00 1.00 SURFAC CASING EQRP T Trouble shoot pipe skate kicker. 800.0 800.0 2/5/2020 15:00 2/5/2020 20:00 5.00 SURFAC CASING PULD P Continue to RIH with 10 3/4", 45.5ppf, L-80 TXP casing installing centralizers as per detail from 800' to 1376'. PU/SO=87K/90K 800.0 1,376.0 2/5/2020 20:00 2/5/2020 21:00 1.00 SURFAC CASING CIRC P Circulate bottoms up+ below permafrost. Staged up in 0.5bbl/min stages to 8 bbls/min. 1bpm=110psi, 2bpm=115psi, 3bpm=130psi, 4bpm=135psi, 5bpm=140psi, 6bpm=155psi, 7bpm=165psi, 8bpm=190psi after pumping 2450strokes. 1,376.0 1,376.0 2/5/2020 21:00 2/6/2020 00:00 3.00 SURFAC CASING PULD P Continue to RIH with 10 3/4", 45.5ppf, L-80 TXP casing installing centralizers as per detail from 1376'-2,020'. At 1,800', Lost string weight to 58k so stage circulated up to 6bpm. Regained string weight to 96k lbs.Continue running casing. 1,376.0 2,020.0 2/6/2020 00:00 2/6/2020 03:00 3.00 SURFAC CASING CIRC P Continue to RIH with 10 3/4", 45.5ppf, L-80 TXP casing installing centralizers as per detail from 2,020'-2,352'. PU/SO=112K/106K while landing hanger. Made up XO joint and hanger and land hanger on ring. Pick-up and slowly try to establish circulation. 2,020.0 2,352.0 2/6/2020 03:00 2/6/2020 06:00 3.00 SURFAC CEMENT CIRC T Attempt to establish circulation reciprocating from 2,352'-2,297', pumping at 1/2bpm on the down stroke and staging up to 2 1/2bpm on the upstroke but losses continued. Pump 0.5-2.5bpm, 190-235psi, 0-2% Flow out. PU/SO=112K/108K 2,352.0 2,352.0 2/6/2020 06:00 2/6/2020 12:00 6.00 SURFAC CEMENT CIRC T Continue pumping to establish circulation reciprocating from 2,352'- 2,297', pumping at 1/2bpm on the down stroke. Staged up to 2 1/2bpm on the upstroke but losses continued. 190-235psi, 0-2% Flow out. PU/SO=112K/108K Total Losses for tour= 395bbls 2,352.0 2,352.0 2/6/2020 12:00 2/6/2020 12:30 0.50 SURFAC CEMENT CIRC T Continue pumping to establish circulation reciprocating from 2,352'- 2,297', pumping at 1/2bpm on the down stroke. Staged up to 2 1/2bpm on the upstroke but losses continued. 190-235psi, 0-2% Flow out. PU/SO=112K/108K 2,352.0 2,352.0 2/6/2020 12:30 2/6/2020 13:00 0.50 SURFAC CEMENT CIRC T Blow down top drive and rig up to pull and LD 10 3/4" casing until circulation can be regained. 2,352.0 2,352.0 2/6/2020 13:00 2/6/2020 13:30 0.50 SURFAC CEMENT CIRC T POOH. LD landing joint, hanger and XO joint as per FMC and Doyon casing rep. 2,352.0 2,234.0 2/6/2020 13:30 2/6/2020 19:30 6.00 SURFAC CEMENT CIRC T Pump out of hole w/ 10 3/4" casing, laying down joints and attempt to establish circulation at the top of each joint. Pulled total of 8 joints from 2,234'-1,960', 1/2-1bpm, 250psi, 1-6% FO, PU/SO=111K/106K, total pumped 1260 stokes. 2,234.0 1,960.0 Rig: PW AKE-305 - Priority Page 7/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/6/2020 19:30 2/6/2020 22:00 2.50 SURFAC CEMENT CIRC T Established returns at 1960' with 8 joints pulled. Staged up pump rate to 8bpm in 1/2bbl/min increments. 175psi at 6BPM with 50% FO. 126psi at 6.5bpm with 20% flow out 160psi at 7bpm PU/SO=115K/129k 1,960.0 1,960.0 2/6/2020 22:00 2/7/2020 00:00 2.00 SURFAC CEMENT CIRC T Re-run 10 3/4" casing from 1,960' to 2,079' with new seal rings and re-used centralizers. Wash down each joint with 6-8bpm, ensuring 8bpm lowering each joint down and 15 minutes circulating after each joint down. Mud Loss per tour=170bbls. Extreme cold requires Cold Weather Variances and reduced loads for trucks. 1,960.0 2,079.0 2/7/2020 00:00 2/7/2020 06:00 6.00 SURFAC CEMENT CIRC T Re-run pulled 10 3/4" casing with new seal rings and re-use bow spring centralizers. Wash casing down from 2,079' to 2,356'. Tagged bottom, circulate bottoms up @8bpm, 187psi, 20% FO, PU/SO Wt=148K/137K, minimal losses. 2,079.0 2,356.0 2/7/2020 06:00 2/7/2020 07:30 1.50 SURFAC CEMENT CIRC T Pump out and lay down 3 extra landing joints from 2,356'-2,271'. 2,356.0 2,271.0 2/7/2020 07:30 2/7/2020 08:30 1.00 SURFAC CEMENT CIRC T Clean threads on Joint #59, and make -up cross-over joint, pup jt and hanger and landing joint as per FMC and Doyon Casing. 2,271.0 2,352.0 2/7/2020 08:30 2/7/2020 12:00 3.50 SURFAC CEMENT CIRC T Establish circulation through Volant tool in 1bbl/min increments to 4bpm. Work pipe staying inside riser, landing out casing on the ring every 8th stroke. PU/SO=147K/138K, 87psi at 4bpm, 40psi at 2bpm, 160psi at 8bpm. Tour mud losses=25bbls. Circulating due to extreme cold exposure limitations. Working on tarping, insulating, heat application on outside cementing lines, valves. 2,352.0 2,352.0 2/7/2020 12:00 2/7/2020 18:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 4bpm, work pipe inside riser, landing out every 8th stroke. PU/SO=136K/146K, 84psi at 2bpm Circulating due to extreme cold exposure limitations. Working on tarping, insulating, heat application on outside cementing lines, valves. 2,352.0 2,352.0 Rig: PW AKE-305 - Priority Page 8/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/7/2020 18:00 2/8/2020 00:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 4bpm, work pipe inside riser, landing out every 8th stroke. PU/SO=136K/146K, 84psi at 2bpm. SIMOPS - making up 5" DP stands in 30 ft mousehole. Circulating due to extreme cold exposure limitations. Working on tarping, insulating, heat application on outside cementing lines, valves. Tour mud losses=17bbls 2,352.0 2,352.0 2/8/2020 00:00 2/8/2020 06:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 2bpm at 91psi, work pipe inside riser, landing out every 5th stroke and pumping to 8bpm every hour at 185psi. . PU/SO=134K/143K. Circulating due to extreme cold exposure limitations, heat application on outside cementing lines, valves. 2,352.0 2,352.0 2/8/2020 06:00 2/8/2020 12:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 2bpm at 91psi, work pipe inside riser, landing out every 5th stroke and pumping to 8bpm every hour at 185psi. . PU/SO=134K/143K. Circulating due to extreme cold exposure limitations, heat application on outside cementing lines, valves. 2,352.0 2,352.0 2/8/2020 12:00 2/8/2020 18:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 2bpm at 91psi, work pipe inside riser, landing out every 5th stroke and pumping to 8bpm every hour at 185psi. . PU/SO=134K/146K. Circulating due to extreme cold exposure limitations, heat application on outside cementing lines, valves. 2,352.0 2,352.0 2/8/2020 18:00 2/9/2020 00:00 6.00 SURFAC CEMENT CIRC T Continue circulating through Volant tool @ 2bpm at 91psi, work pipe inside riser, landing out every 5th stroke and pumping to 8bpm every hour at 185psi. . PU/SO=132K/144K. Preparing For Cementing Operations, warmed to -37 by midnight. 2,352.0 2,352.0 2/9/2020 00:00 2/9/2020 02:30 2.50 SURFAC CEMENT CIRC P Continue circulating through Volant tool @ 2bpm at 94psi, work pipe inside riser, landing out every 5th stroke and pumping to 8bpm every hour at 192psi. . PU/SO=132K/144K. Rig down and rig up to circulate through the cementing hose. Blow down top drive, 2,352.0 2,352.0 Rig: PW AKE-305 - Priority Page 9/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/9/2020 02:30 2/9/2020 07:00 4.50 SURFAC CEMENT CMNT P Conduct PJSM with Schlum and all involved support personnel while pumping and reciprocating thru cement hose. Blow air back to cementers to verify clear. Flood lines and Pressure test cement lines. Pump 75bbls 10.5ppg Mud Push II, drop bottom plug, pump 308bbls 11ppg lead cement, followed by 60 bbls 15.8ppg tail cement, drop top plug and displace with 20 bbls water by Schlumberger and rig with189bbls 10 ppg Drilplex mud. PU/SO=137K/146K. Displaced at 8bpm, FCP 363psi, bumped plug to 1246psi and held for 5 minutes. Floats held. 191bbls good cement returns observed to surface. 2,352.0 2,352.0 2/9/2020 07:00 2/9/2020 07:30 0.50 SURFAC CEMENT RURD P Rig down cementing and casing equipment 0.0 0.0 2/9/2020 07:30 2/9/2020 08:30 1.00 SURFAC CEMENT CLEN P Clean and clear floor of non-essential tools. 0.0 0.0 2/9/2020 08:30 2/9/2020 11:00 2.50 SURFAC WHDBOP NUND P Hold PJSM, N/D diverter and surface equipment. 0.0 0.0 2/9/2020 11:00 2/9/2020 12:00 1.00 SURFAC WHDBOP WWSP P Hold PJSM, install wellhead as per FMC. Pressure tested seals to 1000psi, 10min, witnessed by CPAI rep. 0.0 0.0 2/9/2020 12:00 2/9/2020 18:00 6.00 SURFAC WHDBOP NUND P Hold PJSM, nipple up wellhead as per FMC, N/U BOPE and MPD head. 0.0 0.0 2/9/2020 18:00 2/9/2020 21:30 3.50 SURFAC WHDBOP NUND P Continue N/U BOP's and install flowline. 0.0 0.0 2/9/2020 21:30 2/9/2020 22:30 1.00 SURFAC WHDBOP BOPE P Install FMC test plug and fill BOP stack, install MPD test cap and perform 250/1200 psi shell test, charted. Pull test cap and install trip nipple. install 5" test joint and fill with water. working air out of system. 0.0 0.0 2/9/2020 22:30 2/10/2020 00:00 1.50 SURFAC WHDBOP BOPE P Tested BOPE all tests 250psi low, 3800psi high for 5 min charted with exception of manual and Super chokes tested to 500/2000psi 5 minutes charted. With 5" test joint, test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, test choke valves 1-15. Witness waived by AOGCC rep Jeff Jones @20:24 02/09/2020. Continued test on next report. 0.0 0.0 Rig: PW AKE-305 - Priority Page 10/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2020 00:00 2/10/2020 03:30 3.50 SURFAC WHDBOP BOPE P Continue testing BOPE. All tests to 250psi low, 3800psi high charted for 5 min minimum with exception of manual operated and super choke tested to 250psi low and 2000psi high for 5 charted minutes, With both 3 1/2" and 5" test joints test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, With 3 1/2" test joint tested 2 7/8" x 5 1/2"UPR, and 2 7/8" x 5 1/2" LPR, test choke valves 1-15, manual operated and super choke, choke and kill manuals, and HCR's, 4" valve on kill line, 5" FOSV, 5" dart valve, upper and lower IBOP, tested Blind/Shear rams, performKoomey drawdown, ACC=3000psi, Manifold=1550psi. After all functions on just bottles, ACC=1600psi, Built to200psi in 15secs with two electric pumps, built to full system pressure in 87secs with 2 electric and 2 air pumps. Closing times for annular=23secs, UPR=18secs, blind/shear rams=16secs, LPR=16secs, choke HCR=2secs, kill HCR=2secs, test PVT gain/loss and flowout alarms. Test LEL and H2S alarms. Witness waived by Jeff Jones, @20:24hrs 02/09/2020. 0.0 0.0 2/10/2020 03:30 2/10/2020 04:00 0.50 SURFAC WHDBOP BOPE P Rig down and blow down test equipment. Pull FMC test plug and install 9.93" wear ring, run in two LDS on wear ring, install 1502 flanges to I.A. and O.A. valves. 0.0 0.0 2/10/2020 04:00 2/10/2020 06:00 2.00 SURFAC DRILLOUT BHAH P Hold PJSM on picking up BHA, Clear rig floor and pick-up Schlum DD tools for building BHA #2 as per Schlum rep 0.0 0.0 2/10/2020 06:00 2/10/2020 08:00 2.00 SURFAC DRILLOUT BHAH P Crew change, hold PJSM, continue picking up BHA as per Schlum rep from surface to 623'. PU/SO wt=68/72K. Monitor displacement via hole fill on trip tank. 0.0 623.0 2/10/2020 08:00 2/10/2020 11:00 3.00 SURFAC DRILLOUT PULD P PJSM, RIH from 623'-2,123', with 5" DP singled in from pipe shed. PU/SO=100k/112k, monitor displacement on trip tank. 623.0 2,123.0 2/10/2020 11:00 2/10/2020 11:30 0.50 SURFAC DRILLOUT CIRC P Circulate and condition mud for casing pressure test. 2,123.0 2,123.0 2/10/2020 11:30 2/10/2020 12:00 0.50 SURFAC DRILLOUT PRTS P PJSM, RU to test casing. 2,123.0 2,123.0 2/10/2020 12:00 2/10/2020 13:00 1.00 SURFAC DRILLOUT PRTS P Test casing to 2,900psi for 30 charted minutes 2,123.0 2,123.0 2/10/2020 13:00 2/10/2020 13:30 0.50 SURFAC DRILLOUT PRTS P R/D casing testing equipment 2,123.0 2,123.0 2/10/2020 13:30 2/10/2020 14:30 1.00 SURFAC DRILLOUT COCF P Wash down from 2,123' to 2,260' at 650gpm, 1504psi, 30rpm, 2k torque, PU/SO=101k/114k lbs 2,123.0 2,260.0 2/10/2020 14:30 2/10/2020 18:00 3.50 SURFAC DRILLOUT DRLG P Drill plugs and shoe track from 2,260' to 2271', 640gpm, 1384psi, 60rpm, TQ=1-6k, WOB=5-20klbs, PU/SO=99k/115k. 2,260.0 2,271.0 Rig: PW AKE-305 - Priority Page 11/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2020 18:00 2/10/2020 21:45 3.75 SURFAC DRILLOUT DRLG P Wash and drill cement from 2271' - 2347', tag the shoe at 2347'. Drill thru the shoe assembly at 635gpm, 1465psi, 70rpm, 7.5k WOB, 2.5k TQ, 26% FO, Continue to wash down rathole from 2352' 2363'MD/TVD. and drill new hole to 2383'MD/TVD. SPR's at 2,315'MD/2,315'TVD, 10ppg MW, 21:30hrs #1MP=160psi/30spm, 200psi/40spm #2MP=160psi/30spm, 200psi/40spm 2,271.0 2,383.0 2/10/2020 21:45 2/10/2020 23:00 1.25 SURFAC DRILLOUT CIRC P Displace to new 10ppg LSND drilling mud, pump 40bbl HI vis sweep, rotating and reciprocating 2,383'- 2,316', with 700gpm, 1275psi, 28% FO, 60rpm, 1.5k TQ, 10.6ppg ECD, PU/SO=101K/117K, Rtg Wt=105k, total pumped 4220 strokes. SPR's at 2,383'MD/2,383'TVD, 10ppg MW, 22:50hrs #1MP=120psi/30spm, 150psi/40spm #2MP=120psi/30spm, 150psi/40spm OWFF for 10mins Blow down top drive and install headpin for F.I.T. 2,383.0 2,383.0 2/10/2020 23:00 2/10/2020 23:45 0.75 SURFAC DRILLOUT FIT P Flood lines, circulate air out of system for F.I.T test. Conduct F.I.T. with 13 strokes to 19ppg with 1100psi applied surface pressure. (target was 17.5ppg, 917psi). Shut-in, monitored for 10 mins, good. Opened up and bled back 1.5bbls. Open well and blow down testing equipment. 2,383.0 2,383.0 2/10/2020 23:45 2/11/2020 00:00 0.25 INTRM1 DRILL UREM P Wash/ream back to bottom 2,316'- 2,383'MD at 700gpm, 1275psi, 60rpm, 1.5k TQ, PU/SO/RTG=101K/117K/105K 2,383.0 2,383.0 2/11/2020 00:00 2/11/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 2,383'MD- 2,788'MD/2,788'TVD. 8K WOB, 820gpm, 1420psi/1395psi on/off bottom, 120rpm, 3-8K/2.5K on/off bottom torque, 38% Flow Out, 10.86ppg ECD, PU/SO/RTG wt 104k/126k/122k, Dropped ball as per DD @ 2,508'MD and opened reamer @ 2,495'MD Collected parameters and conduct ledge pull test that confirmed UR is open. ADT=3.37, Total Bit Hrs=3.66, total Jar hrs=117.21 2,383.0 2,788.0 Rig: PW AKE-305 - Priority Page 12/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/11/2020 06:00 2/11/2020 12:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 2,788'MD- 3,543'MD/3,532'TVD. 10K WOB, 875gpm, 1730psi/1395psi on/off bottom, 160rpm, 4-6K/2K on/off bottom torque, 36% Flow Out, 11.09ppg ECD, PU/SO/RTG wt 124k/148k/124k, ADT=3.90, Total Bit Hrs=7.56, total Jar hrs=121.11 SPR's@2,882'MD/2,882'TVD, 06:49hrs, 9.9ppg MW #1MP - 120psi/30spm, 140psi1/40spm #2MP - 120psi/30spm, 140psi1/40spm 2,788.0 3,543.0 2/11/2020 12:00 2/11/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 3,543'MD- 4,202'MD/4,150'TVD. 7K WOB, 875gpm, 2,077psi/2,107psi on/off bottom, 160rpm, 6K/2K on/off bottom torque, 74% Flow Out, 10.28ppg ECD, PU/SO/RTG wt 124k/148k/134k, ADT=4.16, Total Bit Hrs=11.72, total Jar hrs=125.27 SPR's@3,820'MD/3,797'TVD, 14:18hrs, 9.9ppg MW #1MP - 180psi/30spm, 200psi/40spm #2MP - 160psi/30spm, 200psi/40spm 3,543.0 4,202.0 2/11/2020 18:00 2/12/2020 00:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 4,202'MD- 5,021'MD/4,906''TVD. 22K WOB, 875gpm, 2,296psi/2,288psi on/off bottom, 160rpm, 13K/3K on/off bottom torque, 41% Flow Out, 11.07ppg ECD, PU/SO/RTG wt 150k/167k/149k, ADT=4.42, Total Bit Hrs=16.14, total Jar hrs=129.69 SPR's@4,861'MD/4,747'TVD, 23:00hrs, 10.1ppg MW #1MP - 150psi/0spm, 200psi/40spm #2MP - 160psi/30spm, 200psi/40spm Tour Losses=Nil 4,202.0 5,021.0 2/12/2020 00:00 2/12/2020 06:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 5,021'MD- 5,765'MD/5,581'TVD. 20K WOB, 875gpm, 2,355psi/2,345psi on/off bottom, 160rpm, 11K/3K on/off bottom torque, 38% Flow Out, 10.76ppg ECD, PU/SO/RTG wt 148k/173k/156k, Pumped 20bbl Nut Plug sweep at 5,055', 5,333', 5,616'MD ADT=3.42, Total Bit Hrs=19.56, total Jar hrs=133.11 5,021.0 5,765.0 Rig: PW AKE-305 - Priority Page 13/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2020 06:00 2/12/2020 08:30 2.50 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 5,765'MD-6,081'MD. 21K WOB, 850gpm, 2,462psi/2,393psi on/off bottom, 160rpm, 13K/3K on/off bottom torque, 58% Flow Out, 11.56ppg ECD, PU/SO/RTG wt 155k/173k/163k, SPR's@5,795'MD/5,804'TVD, 06:30hrs, 10.1ppg MW #1MP - 150psi/30spm, 180psi/40spm #2MP - 150psi/30spm, 180psi/40spm ADT=2.62, Total Bit Hrs=22.18, total Jar hrs=135.73 5,765.0 6,081.0 2/12/2020 08:30 2/12/2020 09:00 0.50 INTRM1 DRILL CIRC P Circulate 1 Bottoms up, rotate and reciprocate 90'. @ 875gpm, 100rpm, 2371psi, 4K torque, PU/SO/TRG=154K/178K/162K 6,081.0 6,081.0 2/12/2020 09:00 2/12/2020 10:30 1.50 INTRM1 DRILL MPDA P PJSM, OWFF, (static), remove trip nipple and install RCD bearing 6,081.0 6,081.0 2/12/2020 10:30 2/12/2020 12:00 1.50 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 6,081'MD- 6,235'MD/5,966'TVD. 21K WOB, 850gpm, 2,462psi/2,393psi on/off bottom, 160rpm, 13K/3K on/off bottom torque, 57% Flow Out, 11.56ppg ECD, PU/SO/RTF=157K/180K/164K, MPD Back Pressure=300psi, ADT=2.62, Total Bit Hrs=22.18, total Jar hrs=135.73 6,081.0 6,235.0 2/12/2020 12:00 2/12/2020 18:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 6,235'MD- 6,595'MD/6,350'TVD. 16.5K WOB, 850gpm, 2,496psi/2,440psi on/off bottom, 135rpm, 8K/3K on/off bottom torque, 50% Flow Out, 11.40ppg ECD, No torque and drag parameters recorded due to shale's. ADT=4.52, Total Bit Hrs=26.7, total Jar hrs=140.25 6,235.0 6,595.0 Rig: PW AKE-305 - Priority Page 14/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2020 18:00 2/13/2020 00:00 6.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 6,595'- 7,059'MD/6,780'TVD. 21K WOB, 830gpm, 2,550psi/2,485 psi on/off bottom, 140rpm, 12K/4K on/off bottom torque, 51% Flow Out, 11.40ppg ECD, Started Dump and dilute at 6,938'MD 135bbls. SPR's@6,837'MD/6'569'TVD, 21:15hrs, 10.3ppg MW #1MP - 420/237 psi/30spm, 460/210psi/40spm #2MP - 420/221psi/30spm, 480/217psi/40spm Tour losses= nil ADT=4.57, Total Bit Hrs=31.27, total Jar hrs=144.82 6,595.0 7,059.0 2/13/2020 00:00 2/13/2020 02:00 2.00 INTRM1 DRILL DDRL P Drill 9 7/8" hole with Rhino UR and Power Drive from 7,059'MD- 7,192'MD/6,897'TVD, FINAL INT TD, 16K WOB, 850gpm, 2,563psi/2,550psi on/off bottom, 140rpm, 18K/4.5K on/off bottom torque, 52% Flow Out, 11.56ppg ECD, RTG wt 192 lbs, 285psi MPD BP FINAL - ADT=1.47, Total Bit Hrs=32.74, total Jar hrs=146.29 7,059.0 7,192.0 2/13/2020 02:00 2/13/2020 04:30 2.50 INTRM1 CASING CIRC P Rotate and reciprocate 7,192'- 7,096'MD, 800gpm, 2335psi, 52% Flow Out, 110rpm, 4.5K torque, 11.5ppg ECD, PU/SO/RTG=190K/190K/195K Weight up to 10.8ppg with 13ppg spike fluid, total 2,027strokes pumped (3 bottoms up) 7,192.0 7,096.0 2/13/2020 04:30 2/13/2020 06:00 1.50 INTRM1 CASING OWFF P Close Rhino Undereamer @7,117'MD as per Schlum DD. Confirmed UR closed with pressure parameters. Blow down top drive and rig up to Strip out of hole. Observe Well For Flow via MPD port, well static. 7,117.0 7,096.0 2/13/2020 06:00 2/13/2020 12:00 6.00 INTRM1 CASING SMPD P Strip Out Of Hole 7,096'-1,470', with 170 gpm on injection line with mud pump #2. 180psi/220psi in/out of slips MPD pressure., 4% flow out, PU/SO=187K/189K lbs. 7,096.0 1,470.0 2/13/2020 12:00 2/13/2020 13:00 1.00 INTRM1 CASING SMPD P Strip Out Of Hole 1470'-717', with 170 gpm on injection line with mud pump #2. 180psi/220psi in/out of slips MPD pressure., 4% flow out, PU/SO=90K/95K lbs. 1,470.0 717.0 2/13/2020 13:00 2/13/2020 14:30 1.50 INTRM1 CASING MPDA P OWFF. Remove MPD bearing, install trip nipple as per MPD rep. Monitor hole w/hole fill from pit #3. 717.0 717.0 2/13/2020 14:30 2/13/2020 18:00 3.50 INTRM1 CASING BHAH P Lay down 5" HWDP, L/D BHA #2 and unload radioactice source as per Schlum reps. Monitor hole fill on pit #3. 717.0 0.0 Rig: PW AKE-305 - Priority Page 15/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/13/2020 18:00 2/13/2020 20:00 2.00 INTRM1 CASING BHAH P Continue Laying down BHA as per Sclum DD to the pipe shed and down the beaver slide. Clear and clean rig floor. 0.0 0.0 2/13/2020 20:00 2/13/2020 20:30 0.50 INTRM1 CASING WWWH P Johnny Whack the BOP stack at 7bpm for 10mins, rinsing the wellhead and BOP stack. Pull wear ring and install upper test plug as per FMC rep. Make -up 7 5/8" test joint. 0.0 0.0 2/13/2020 20:30 2/13/2020 21:30 1.00 INTRM1 CASING BOPE P Close blind rams and bleed down Koomey. Open doors and change out upper VBR rams for 7 5/8" solid body rams. Energize Koomey and rig-up to pressure test rams. 0.0 0.0 2/13/2020 21:30 2/13/2020 22:00 0.50 INTRM1 CASING BOPE P Fill BOP stack with water and install 7 5/8" test joint, work air out of system and rig up testing equipment. 0.0 0.0 2/13/2020 22:00 2/13/2020 23:30 1.50 INTRM1 CASING BOPE P Pressure test annular to 2500psi/5mins and 7 5/8" rams to 3,800psi/5mins. Rig down testing equipment and pull FMC test plug. Clean and clear drill floor. 0.0 0.0 2/13/2020 23:30 2/14/2020 00:00 0.50 INTRM1 CASING PULD P Rig up Doyon Casing Equipment. M/U Volant tool and swivel sub to top drive with 36,000ft-lbs torque. 0.0 0.0 2/14/2020 00:00 2/14/2020 06:00 6.00 INTRM1 CASING PULD P Continue rigging up to run 7 5/8", 29.7ppf, L-80 TXP casing. Make up shoe as per detail. Reamer shoe, jt, 2 jts, float shoe, 1 jt, Baffle adapter, all Baker Loked. TQ casing to 21,300ft- lbs with Run and Seal thread compound. Pump thru shoe trac to confirm floats clear. Run casing from 129' to 930', filling pipe on the fly and topping off every 10th joint. Hydroform centralizers installed on each of 15 bottom joint and then every 2nd joint Jt #105. Strap pit every 10th joint. PU/SO=62K/74K 0.0 930.0 2/14/2020 06:00 2/14/2020 12:00 6.00 INTRM1 CASING PULD P Continue running 7 5/8", 29.7ppf, L-80 TXP casing. TQ casing to 21,300ft-lbs with Run and Seal thread compound. Run casing from 930'-3,218'MD. Fill pipe on the fly and topping off every 10th joint. Strap pit every 10th joint. PU/SO=117K/126K 930.0 3,218.0 2/14/2020 12:00 2/14/2020 14:00 2.00 INTRM1 CASING PULD P Continue running 7 5/8", 29.7ppf, L-80 TXP casing. TQ casing to 21,300ft-lbs with Run and Seal thread compound. Run casing from 3,218'MD-3,985'MD. Fill pipe on the fly and topping off every 10th joint. Strap pit every 10th joint. 3,218.0 3,985.0 2/14/2020 14:00 2/14/2020 15:30 1.50 INTRM1 CASING CIRC P CBU above the top of the Qannik @ 4,000'. Break circulation with 2bpm, staging up to 5bpm. 236psi@2bpm, 245psi@3bpm, 260psi@4bpm, 280psi@5bpm. FCP=160psi@210gpm. Pumped total 3800strokes. PU/SO=135K/153K 3,985.0 3,985.0 Rig: PW AKE-305 - Priority Page 16/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/14/2020 15:30 2/14/2020 18:00 2.50 INTRM1 CASING PULD P Continue running 7 5/8", 29.7ppf, L-80 TXP casing. TQ casing to 21,300ft-lbs with Run and Seal thread compound. Run casing from 3,985'MD-5,135'MD. Fill pipe on the fly and topping off every 10th joint. Strap pit every 10th joint. SO weight=161K. 3,985.0 5,135.0 2/14/2020 18:00 2/15/2020 00:00 6.00 INTRM1 CASING PULD P Continue running 7 5/8", 29.7ppf, L-80 TXP casing. TQ casing to 21,300ft-lbs with Run and Seal thread compound. Run casing from 5,135'MD-7,080'. Fill pipe on the fly and topping off every 10th joint. Strap pit every 10th joint. SO weight=178K. Top 5 Centek Bowspring centralizers located within surface casing as per detail. 5,135.0 7,080.0 2/15/2020 00:00 2/15/2020 01:30 1.50 INTRM1 CASING WASH P Continue running 7 5/8", 29.7ppf, L-80 TXP casing. TQ casing to 21,300ft-lbs with Run and Seal thread compound. Run casing from 7,080'-7,193'MD. Circulate and rotate slowly from 7,080'MD-7,195'MD, tag bottom. 10 rpm, 7-10K torque, PU/SO wt to 215K/205K with pumps on. Pressured up to 1250psi at 7,140'MD (Fill). Total strokes pumped,Final circulating pressure 180spi@5bpm. SO weight=178K. 7,080.0 7,193.0 2/15/2020 01:30 2/15/2020 03:30 2.00 INTRM1 CASING PULD P Pull out and laydown 3 joints 7,193'- 7,089', 22K overpull noted at 7,130'. 7,193.0 7,089.0 2/15/2020 03:30 2/15/2020 05:00 1.50 INTRM1 CASING PULD P PU pup, Cross-over and landing joint as per FMC rep. 7,089.0 7,189.0 2/15/2020 05:00 2/15/2020 07:00 2.00 INTRM1 CEMENT CIRC P Land out casing, reciprocate 7,173'- 7,188'MD, circ at 7bpm, 480-350psi, flow out 12%, PU/SO=203K/195K, total strokes to circulate and condition mud surface to suface 7,252strokes. 7,189.0 7,189.0 2/15/2020 07:00 2/15/2020 07:30 0.50 INTRM1 CEMENT CIRC P Blowdown top drive, rig up cement line and reestablish circulation through Volant swivel staging from 1-6bpm, 345psi, 8% Flow out. 7,189.0 7,189.0 2/15/2020 07:30 2/15/2020 10:30 3.00 INTRM1 CEMENT CMNT P Stage 1 cementing. Hold PJSM, test lines to 4,000psi, Pump 60bbls of 13ppg mud push, drop bottom bypass plug, Mix and pump 51.8bbls of 15.8ppg class G cement. Drop top shut-off plug, displace with 20bbls water with Schlumberger, and 307bbls with rig pumps at 8bpm. Bump plug @3045strokes to 500psi over FCP. Floats held good. Pressure up to 3,356psi to open stage tool. 7,189.0 7,189.0 2/15/2020 10:30 2/15/2020 12:00 1.50 INTRM1 CEMENT CIRC P Circulate thru ES stage cementer at 2bpm, 420psi. 7,189.0 7,189.0 Rig: PW AKE-305 - Priority Page 17/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/15/2020 12:00 2/15/2020 14:00 2.00 INTRM1 CEMENT CIRC P Continue circulating through ES cementer staging up to 7bpm. 150psi@2bpm, 225psi@3bpm, 320psi@4bpm, 380psi@5bpm, 460psi@6bpm, 555psi@7bpm, 6,757strokes total pumped. 7,189.0 7,189.0 2/15/2020 14:00 2/15/2020 16:45 2.75 INTRM1 CEMENT CMNT P Stage 2 cementing. PJSM, pump water. Pressure test to 4,000psi. Mix and pump 60bbls of 10.8ppg Mudpush, mix and pump 178.1bbls of 11.2ppg lead cement, 90bbls of 13ppg tail cement. Drop closing plug, pump 20 bbls water with Schlumberger, and 281.1bbls mud with rig pump. Bumped plug at 2818strokes, ES cementer closed at 1,479psi. Cement in place (C.I.P.) at 16:33hrs 02/15/2020, Bled off, stage collar closed and holding. Closed stage collar is located at 6,578'MD. 7,189.0 6,578.0 2/15/2020 16:45 2/15/2020 18:30 1.75 INTRM1 CEMENT CLEN P OWFF, laydown landing joint, rig down Volant tool, elevators and bales. Clear and clean rig floor. 0.0 0.0 2/15/2020 18:30 2/15/2020 21:00 2.50 INTRM1 CEMENT WWSP P Drain stack, pull slip inserts, PU test to set pack-off, RIH to set lock down screws, test to 5K/10mins witnessed by CPAI rep. Simops-Rig up for annular leak-off test. Set wear bushing. 0.0 0.0 2/15/2020 21:00 2/15/2020 22:30 1.50 INTRM1 DRILLOUT LOT P RU injection line to Outer Annulus. Pressured up to 1800psi, no leak-off observed (cement higher than 10 3/4" shoe likely). 0.0 0.0 2/15/2020 22:30 2/16/2020 00:00 1.50 INTRM1 DRILLOUT BOPE P Remove 7 5/8" rams, install 2 7/8" x 5 1/2" VBR rams. Change out saver sub to 4" XT-39. Simops = processing 225jts of 4" DP in pipeshed. 0.0 0.0 2/16/2020 00:00 2/16/2020 01:00 1.00 INTRM1 DRILLOUT BOPE P PU test jt, MU test plug and fill stack 0.0 0.0 2/16/2020 01:00 2/16/2020 02:00 1.00 INTRM1 DRILLOUT BOPE P Drain stack, c/o upper ram door seal, fill stack 0.0 0.0 2/16/2020 02:00 2/16/2020 03:30 1.50 INTRM1 DRILLOUT BOPE P Test 2 7/8" x 5 1/2" with both 3 1/2" and 4" test joints. Test 4" dart and 4" TIW all tests to 250psi/3800psi for 5 charted minutes 0.0 0.0 2/16/2020 03:30 2/16/2020 04:30 1.00 INTRM1 DRILLOUT BOPE P L/D test joint, pull test plug, install wear ring I.D.=6 7/8", OD=10 3/4", Run in L/D screws 0.0 0.0 2/16/2020 04:30 2/16/2020 05:00 0.50 INTRM1 DRILLOUT SVRG P Service top drive. blocks, slips and ST -80 0.0 0.0 2/16/2020 05:00 2/16/2020 10:00 5.00 INTRM1 DRILLOUT PULD P M/U mule shoe and RIH with 4", 15.7ppf DP singles from pipe shed from surface to 3,873' 0.0 3,873.0 2/16/2020 10:00 2/16/2020 10:30 0.50 INTRM1 DRILLOUT CIRC P CBU at 3,783'MD, 610psi@7 bpm, 16% flowout, 30rpm, 1K torque, 1,337 total strokes 3,873.0 3,873.0 2/16/2020 10:30 2/16/2020 12:00 1.50 INTRM1 DRILLOUT PULD P Continue RIH with DP singles from 3,873'-4,921'MD, drifted to 2.75, torqued to 27.5K ft-lbs, monitor displacement, PU/SO=119K/119K 3,873.0 4,921.0 2/16/2020 12:00 2/16/2020 13:30 1.50 INTRM1 DRILLOUT PULD P Continue RIH with DP singles from 4,921'-6,000'MD, drifted to 2.75, torqued to 27.5K ft-lbs, monitor displacement, PU/SO=128K/128K 4,921.0 6,000.0 Rig: PW AKE-305 - Priority Page 18/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2020 13:30 2/16/2020 14:15 0.75 INTRM1 DRILLOUT CIRC P Circulate and Condition mud at 870psi/7bpm, 12% FO, 30rpm, 2K torque 6,000.0 6,000.0 2/16/2020 14:15 2/16/2020 16:15 2.00 INTRM1 DRILLOUT TRIP T POOH from 6,000'-to 4,000'MD, racking stands in derrick. RU on O/A to attempt annular leak-off test. Pressured up to 1,200psi/5 strokes. 6,000.0 4,000.0 2/16/2020 16:15 2/16/2020 18:00 1.75 INTRM1 DRILLOUT CIRC T Circulate to warm up annulus, monitor pressure on O/A, ICP=850psi, FCP=700psi, mud temp initial 60deg, final 70 deg. Circ 530psi/7bpm, 10% flowout, 1K torque, 30rpm, 4,955 strokes. 4,000.0 4,000.0 2/16/2020 18:00 2/16/2020 20:00 2.00 INTRM1 DRILLOUT TRIP T POOH from 4,000 to surface w/ 4" DP sta ds rack back in derrick. Monitor displacement on trip tank. 4,000.0 0.0 2/16/2020 20:00 2/16/2020 20:30 0.50 INTRM1 DRILLOUT BHAH P Clear and clean rig floor. 0.0 0.0 2/16/2020 20:30 2/16/2020 22:00 1.50 INTRM1 DRILLOUT BHAH P PJSM P/U BHA #3 as per Schlumberger DD rep. 0.0 0.0 2/16/2020 22:00 2/16/2020 23:00 1.00 INTRM1 DRILLOUT BHAH P PJSM install source as per Schlum LWD, DD 0.0 100.0 2/16/2020 23:00 2/16/2020 23:30 0.50 INTRM1 DRILLOUT BHAH P Continue to M/U BHA #3 100.0 374.0 2/16/2020 23:30 2/17/2020 00:00 0.50 INTRM1 DRILLOUT PULD P Change out slip inserts, RIH with BHA #3, singling in 4" DP from 374' to 753' 374.0 753.0 2/17/2020 00:00 2/17/2020 01:00 1.00 INTRM1 DRILLOUT TRIP P TIH from 756'-1,517'MD, w/4" from pipe shed, PU/SO=50K/56K monitor on trip pit. 753.0 1,517.0 2/17/2020 01:00 2/17/2020 01:30 0.50 INTRM1 DRILLOUT TRIP P TIH from 1,517'MD-2,278'MD, w/4" from pipe shed, PU/SO=68K/75K monitor on trip pit. 1,517.0 2,278.0 2/17/2020 01:30 2/17/2020 02:00 0.50 INTRM1 DRILLOUT CIRC P Circulate to shallow test MWD, good, 1180psi/220gpm, 10% Flow Out 2,278.0 2,278.0 2/17/2020 02:00 2/17/2020 05:30 3.50 INTRM1 DRILLOUT TRIP P TIH from 2,278'MD-6,540'MD-, w/4" from derrick, PU/SO=68K/75K monitor on trip pit. 2,278.0 6,540.0 2/17/2020 05:30 2/17/2020 06:00 0.50 INTRM1 DRILLOUT COCF P Tag cement stringers at 6,540', drill cement down from 6,540'-6,578'MD. 2K WOB, 250gpm, 1950psi, 40rpm, 4K torque, 14% flow out, PU/SO/RTG=141K/133K/131K 6,540.0 6,578.0 2/17/2020 06:00 2/17/2020 08:30 2.50 INTRM1 DRILLOUT DRLG P Tag stage collar @6,578'MD, drill out as per Halliburton/Plan Forward recommendations from 6,578'- 6,607'MD at 180-240gpm, 970psi, 5% flow out, 40-60rpm, 3-6K torque. PU/SO/RTG=141K/133K/131K as per DD. 6,578.0 6,607.0 2/17/2020 08:30 2/17/2020 12:00 3.50 INTRM1 DRILLOUT COCF P Wash and ream, drilling cement from 6,607'-7,011'MD, 267gpm, 2060psi, 10% flow out, 80rpm, 3-5K torque, PU/SO/RTG=148K/143K/148K 6,607.0 7,011.0 2/17/2020 12:00 2/17/2020 13:00 1.00 INTRM1 DRILLOUT COCF P Wash and ream, drilling cement from 7,011'-7,038'MD, 267gpm, 2060psi, 10% flow out, 40rpm, 3-5K torque, PU/SO/RTG=148K/143K/148K 7,011.0 7,038.0 2/17/2020 13:00 2/17/2020 14:00 1.00 INTRM1 DRILLOUT PRTS P Shut down, rig up and test casing to 3,500psi for 30mins charted. Bled back 3.5bbls to trip tank. Test good. 7,038.0 7,038.0 Rig: PW AKE-305 - Priority Page 19/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/17/2020 14:00 2/17/2020 14:45 0.75 INTRM1 DRILLOUT COCF P Wash and ream, drilling cement from 7,038'MD-7,057'MD, 267gpm, 2190psi, 9% flow out, 50rpm, 5K torque, PU/SO/RTG=148K/143K/148K 7,038.0 7,057.0 2/17/2020 14:45 2/17/2020 16:00 1.25 INTRM1 DRILLOUT DRLG P Tag and drill baffle collar and shut-off plug from 7,057'-7,065'MD, 168gpm, 860psi, 4% flow out, 3-6k WOB, 40- 60rpm, 5-8K TQ. SIMOPS- Rig up and pressure up the OA with test-pump, monitor on chart. 7,057.0 7,065.0 2/17/2020 16:00 2/17/2020 16:30 0.50 INTRM1 DRILLOUT COCF P Wash and ream cement from 7,065'MD-7,100'MD, 253gpm, 1990psi, 9% FO, 60rpm, 5K TQ, PU/SO=143K/148K 7,065.0 7,100.0 2/17/2020 16:30 2/17/2020 17:00 0.50 INTRM1 DRILLOUT DRLG P Tag and drill float collar and plug @ 7,100'MD-7,104'MD, 170gpm, 880psi, 4% FO, 3-6K WOB, 40-60rpm, 5-8K TQ. 7,100.0 7,104.0 2/17/2020 17:00 2/17/2020 18:30 1.50 INTRM1 DRILLOUT COCF P Wash and ream drillling cement from 7,104'MD-7,185'MD, 253gpm, 2,005psi, 9% FO, 60rpm, 5K TQ, 4 WOB 7,104.0 7,185.0 2/17/2020 18:30 2/17/2020 20:30 2.00 INTRM1 DRILLOUT DRLG P Tag reamer float shoe at 7,185'MD- 7,189', drill at 220-250gpm, 1,850- 2,005psi, 8-9% FO, 40-60rpm, 5-9K TQ, 2-9K wob, Drill to 7,192'MD 7,185.0 7,189.0 2/17/2020 20:30 2/17/2020 23:00 2.50 INTRM1 DRILLOUT CIRC P Circulate, rotate and reciprocate from 7,192'-7,162'MD, 250gpm, 1950psi, 9% FO, 60rpm, 5K TQ, PU/SO/RTG=145K/147K/148K, 4603 strokes total pumped to cleanup drilled debris. 7,189.0 7,162.0 2/17/2020 23:00 2/18/2020 00:00 1.00 INTRM1 DRILLOUT MPDA P Rack back stand, blow down top drive, OWFF well, static, blow down hole fill line, pull PS-21 slips, remove trip nipple, install RCD bearing in RCD as per MPD rep. 7,162.0 7,065.0 2/18/2020 00:00 2/18/2020 01:30 1.50 INTRM1 DRILLOUT CIRC P Line up MPD test lines, begin displacement to 10.3ppg Flopro mud, rotate and reciprocate 7,124'- 7,065'MD, 250gpm, 1775-2040psi, 11% FO, 50rpm, 5K TQ, PU/SO/RTG=154K/138K/144K, pumped 3530strokes 7,065.0 7,065.0 2/18/2020 01:30 2/18/2020 06:00 4.50 INTRM1 DRILLOUT DDRL P Drill 6 1/2" production hole from 7,192'MD-7,212'MD (6,913'TVD) for required 20' of open hole for F.I.T., 6- 10K wob, 249gpm, 1800psi, 40- 80rpm, TQ on/off=5-8/5K, 115 FO, 10.69ppg ECD, PU/SO/RTG=154K/138K/144K, ADT=2.02, Total Bit Hrs=2.02 7,192.0 7,212.0 2/18/2020 06:00 2/18/2020 07:00 1.00 INTRM1 DRILLOUT FIT P Rack back stand in derrick, blow down top drive, RU and F.I.T. test to 1,200psi for 13.5ppg F.I.T. test. 7,212.0 7,212.0 2/18/2020 07:00 2/18/2020 08:00 1.00 PROD1 DRILL DDRL P Pick up single from pipe shed, drill 6 1/2" production hole from 7,212MD- 7,240'MD, 4K wob, 261gpm, 1930psi, 125rpm, TQ on/off=4-7K/5K, 7% FO 7,212.0 7,240.0 Rig: PW AKE-305 - Priority Page 20/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/18/2020 08:00 2/18/2020 12:00 4.00 PROD1 DRILL CIRC P Observe increase in flow out in conjunction with gamma spike (gamma 6.54' above bit), space out tool joint. Increase MPD back pressure to 500psi, (1.4ppf MWE). Took returns to mud gas separator. Begin weight up system from 10.1+ppg to 10.3+ppg, rotate ands reciprocate from 7,228'MD-7,200'MD. initial 40-30rpm, 5K TQ, 261gpm, 2,400psi, 12ppg ECD, 6,241 max Total Gas units 7,240.0 7,240.0 2/18/2020 12:00 2/18/2020 14:30 2.50 PROD1 DRILL CIRC P Continued to weight up from 10.3+ppg to 10.8ppg with MPD holding 440psi back pressure. Rotate and reciprocate 7,228' to 7,195'MD. 261gpm, 2,360psi, 30rpm, 5K TQ, 7% FO, 12ppg ECD 7,240.0 7,240.0 2/18/2020 14:30 2/18/2020 18:00 3.50 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 7,240'MD-7,345' MD, 7,041.35' TVD, FINAL TD called to avoid drilling into Miluveach shale below with high mud weight.6K wob, 261gpm, 2,280psi, 125rpm, 5-7k/5k on/off TQ, 7% FO, 12ppg ECD, 220psi MPD while drilling/circulating, 7,240.0 7,345.0 2/18/2020 18:00 2/18/2020 18:30 0.50 PROD1 CASING CIRC P Send downlink for final survey 7,345.0 7,345.0 2/18/2020 18:30 2/18/2020 19:30 1.00 PROD1 CASING CIRC P Circulate, rotate and reciprocate from 7,343'MD-7,260'MD, 261gpm, 2,300psi, 6% FO, 50rpm, 5K TQ, 12.05ppg ECD, PU/SO/RTG=154K/126K/136K, 3,969 strokes (1 1/2 bottoms up) 7,345.0 7,345.0 2/18/2020 19:30 2/18/2020 20:00 0.50 PROD1 CASING DLOG P Log up slowly at 120fph, no rotation, from 7,333'MD-7,316'MD, pumping 261gpm, 6% FO, 2,330psi, 260psi MPD back pressure, 12.0ppg ECD 7,345.0 7,345.0 2/18/2020 20:00 2/19/2020 00:00 4.00 PROD1 CASING DLOG P Conduct differential stick test at 7,316', good after 15 minutes, pumping at 261gpm, 2,324psi, 6% FO, Conducted 10 Stethoscope sets, from bit depths 7,316'MD to 7,279'MD, prelim #'s indicate 11.9+ppg at approx. 6937'TVD. Maintaining 12ppg EMW while circulating or if ever in slips not circulating. 7,345.0 7,345.0 2/19/2020 00:00 2/19/2020 05:00 5.00 PROD1 DRILLOUT CIRC P Circulate, rotate and reciprocate 7343'MD-7260'MD, 251gpm, 2170psi, 6% FO, 50rpm, 4-5K TQ, 12.05ppg MWE, PU/SO/RTG=154K/126K/136K, 17,840 total strokes with 10.8 LSND mud 7,343.0 2/19/2020 05:00 2/19/2020 07:00 2.00 PROD1 DRILLOUT CIRC P PJSM, displace well to 12.3ppg Kill Weight NaBromide clear brine, rotate and reciprocate 7343'MD-7260'MD, 251gpm, 1800-2170psi, 6% FO,50rpm, 4-5K TQ, 12.05-12.2ppg ECD, PU/SO/RTG=150K/138K/145K, 4K TQ at 3bpm, 4978 strokes pumped (surface to surface 2,870stokes. 7,343.0 7,343.0 Rig: PW AKE-305 - Priority Page 21/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/19/2020 07:00 2/19/2020 08:15 1.25 PROD1 DRILLOUT OWFF P Obtain SPR's, lay down single joint 4" DP, Blow down top drive, OWFF for 30min at 5rpm, well static. Drop Gyrodata gyro and wait for it to land out as per Gyrodata. SPR's @ 7,324'MD/7,037'TVD, MW=12.3+, time=07:00, MPD chokes open #1 MP - 20spm/270psi, 30spm/540psi #2 MP - 20spm/280psi, 30spm/540psi 7,324.0 7,324.0 2/19/2020 08:15 2/19/2020 11:15 3.00 PROD1 DRILLOUT SMPD P Strip OOH from 7,324'MD-3,896'MD, with 4" DP racking back into derrick. PU/SO=153K/135K, monitor displacement, MPD back pressure 110psi/70psi out/in slips at 126gpm through MPD chokes. Taking gyro survey stops as per Gyrodata rep. 7,324.0 3,896.0 2/19/2020 11:15 2/19/2020 12:00 0.75 PROD1 DRILLOUT MPDA P OWFF, remove RCD bearing and install trip nipple as per MPD rep. 3,896.0 3,896.0 2/19/2020 12:00 2/19/2020 15:30 3.50 PROD1 DRILLOUT TRIP P Install hole fill line, POOH from 3,896'MD-374'MD with 4" DP, rack in derrick, PU/SO=100K/92K, monitor displacement, 3,896.0 374.0 2/19/2020 15:30 2/19/2020 19:00 3.50 PROD1 DRILLOUT BHAH P LD HWDP, jars and BHA#3 as per DD and MWD reps, floor cleared of unnecessary personnel to unload radioactive source. Break off bit and Lay down tools. 374.0 0.0 2/19/2020 19:00 2/19/2020 20:00 1.00 PROD1 EVALFM BHAH P Clear and clean rig floor, Blow down MPD equipment. 0.0 0.0 2/19/2020 20:00 2/19/2020 22:00 2.00 PROD1 EVALFM ELOG P PJSM, PU Baker wireline sheaves and equipment and make up. 0.0 0.0 2/19/2020 22:00 2/19/2020 23:00 1.00 PROD1 EVALFM ELOG P MU Wireline BHA run #1. 0.0 0.0 2/19/2020 23:00 2/20/2020 00:00 1.00 PROD1 EVALFM ELOG P Load source and RIH Run #1, Neutron Density, monitor hole fill. 0 Losses for tour. 0.0 0.0 2/20/2020 00:00 2/20/2020 03:30 3.50 PROD1 EVALFM ELOG P Continue Logging Run #1, Neutron- Density with constant hole fill. Offline-Inventory Safety Equip, work orders on Mud Pump, drawworks, air compressors. 0.0 0.0 2/20/2020 03:30 2/20/2020 07:15 3.75 PROD1 EVALFM ELOG P Begin wireline Run #2-Acoustic run. 0.0 0.0 2/20/2020 07:15 2/20/2020 10:15 3.00 PROD1 EVALFM ELOG P Acoustic tool back to surface, rig down acoustic tool, MU Run #3 -Rotary Sidewall Coring (RSWC), 0.0 0.0 2/20/2020 10:15 2/20/2020 12:45 2.50 PROD1 EVALFM ELOG P Run in hole, tie-in and cut one core with Run #3-RSWC 0.0 0.0 2/20/2020 12:45 2/20/2020 14:00 1.25 PROD1 EVALFM ELOG T Attempted to push core in while in casing, re-attempt coring. 0.0 0.0 2/20/2020 14:00 2/20/2020 16:00 2.00 PROD1 EVALFM ELOG P POOH slowly, logging gamma-ray 0.0 0.0 2/20/2020 16:00 2/20/2020 17:45 1.75 PROD1 EVALFM ELOG T Swap out RSWC tools, surface function test 0.0 0.0 2/20/2020 17:45 2/20/2020 18:45 1.00 PROD1 EVALFM ELOG T Run in hole #4 RSWC 0.0 0.0 2/20/2020 18:45 2/20/2020 20:15 1.50 PROD1 EVALFM ELOG P Tie in, cut two cores 0.0 0.0 Rig: PW AKE-305 - Priority Page 22/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2020 20:15 2/20/2020 21:45 1.50 PROD1 EVALFM ELOG T POOH for RSWC tool failure and lay out RSWC tools 0.0 0.0 2/20/2020 21:45 2/21/2020 00:00 2.25 PROD1 EVALFM ELOG P PU, Makeup and RIH with Run #5 - Cement Bond Log (CBL) 0.0 0.0 2/21/2020 00:00 2/21/2020 04:00 4.00 PROD1 EVALWB ELOG P Continue Run #5 Cement Bond Log, contune PM's on rig. 0.0 0.0 2/21/2020 04:00 2/21/2020 04:30 0.50 PROD1 EVALFM ELOG P R/D wireline 0.0 0.0 2/21/2020 04:30 2/21/2020 05:30 1.00 PROD1 PLUG CMNT P PJSM, R/U and run 3 1/2" tubing string to 644'. MU Xover to 4" XT-39, swap out 3 1/2" tools to 4" running tools 0.0 644.0 2/21/2020 05:30 2/21/2020 10:15 4.75 PROD1 PLUG CMNT P Run 3 1/2" EUE stinger on 4" DP from 644' to 7,312'MD, PU/SO=140K/127K 644.0 7,312.0 2/21/2020 10:15 2/21/2020 11:00 0.75 PROD1 PLUG CMNT P Wash to bottom 7,312' to 7,345'MD, circulate bottoms up at 254gpm, 700psi,10% FO, 2,338 strokes 7,312.0 7,345.0 2/21/2020 11:00 2/21/2020 12:00 1.00 PROD1 PLUG CMNT P Rack back stand, blow down top drive, PU single 4" DP, R/U pump in sub and cement hose and break circulation. 7,343.0 7,343.0 2/21/2020 12:00 2/21/2020 13:30 1.50 PROD1 PLUG CMNT P Hold PJSM with Shlumberger on cement job. Pump 5 bbl fresh water, shutdown and pressure test to 3,000psi, good. Mix and pump 30.1bbls of 13.5ppg Mud Push II, shutdown, drop foam ball, mix and pump 28bbls 17.0ppg cement @ 4BPM,. Mix and follow with 9.9bbls 13.5ppg Mud Push II and 1 bbl of water. Shutdown and swap to rig pumps and displace with 53bbls of 12.3ppg brine. 7,343.0 7,343.0 2/21/2020 13:30 2/21/2020 14:30 1.00 PROD1 PLUG CMNT P POOH, LD 4" single, pull real slow from 7,343' to 6,645'MD, PU/SO=128K/118K 7,343.0 6,645.0 2/21/2020 14:30 2/21/2020 15:30 1.00 PROD1 PLUG CMNT P Drop top foam ball, circulate surface to surface, reciprocate, ICP=730psi @ 209gpm, 4% FO, FCP=340psi@209gpm, 5% FO. 6,640.0 6,640.0 2/21/2020 15:30 2/22/2020 00:00 8.50 PROD1 PLUG CMNT P Wait On Cement until 500psi compressive strength is developed (11hrs) for pressure testing. Circulate at 45psi@2bpm. AOGCC to be here to witness after 01:30hrs from CDR-3. 6,640.0 6,640.0 2/22/2020 00:00 2/22/2020 01:00 1.00 PROD1 PLUG WOC P Continue WOC until 500psi compressive strength is developed circulating @6,639'MD, 120psi@84gpm, 13% FO, PU/SO=124K/126K, 1,134 strokes 6,639.0 6,639.0 2/22/2020 01:00 2/22/2020 07:00 6.00 PROD1 PLUG WAIT T Continue WOC until 500psi compressive strength is developed monitor constant hole fill on trip tank. (11hrs WOC for compressive strength now OK, AOGCC rep tied up on CDR- 3). 6,639.0 6,639.0 2/22/2020 07:00 2/22/2020 07:30 0.50 PROD1 PLUG WAIT T Wash down to locate top of cement from 6,639'MD to 6,695'MD at 1 bpm/25 psi, PU/SO=129K/125K. Still waiting on AOGCC. 6,639.0 6,695.0 Rig: PW AKE-305 - Priority Page 23/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2020 07:30 2/22/2020 11:00 3.50 PROD1 PLUG WAIT T Monitor well on hole fill from pits #4 & 5. (11hrs WOC for compressive strength now OK, AOGCC rep tied up on CDR- 3). 6,639.0 6,639.0 2/22/2020 11:00 2/22/2020 11:30 0.50 PROD1 PLUG CMNT P Wash down at 25psi/1bpm to tag firm cement at 6,695'MD, set down 10K WOB. Observed differential pressure spike. Witnessed by AOGCC, Austin McCLeod. Rack back stand to 6,639'MD. 6,639.0 6,695.0 2/22/2020 11:30 2/22/2020 12:00 0.50 PROD1 PLUG PRTS P Blowdown top drive, rig-up and pressure tested cement plug to 1,975psi/30minutes as per AGOCC witness. 6,695.0 6,695.0 2/22/2020 12:00 2/22/2020 12:45 0.75 PROD1 PLUG PRTS P Continue 30 min pressure test on cement plug to 1,975psi, charted for 30 mins. Rig down test equipment, witnessed by AOGCC. 6,695.0 6,695.0 2/22/2020 12:45 2/22/2020 15:45 3.00 PROD1 PLUG TRIP P POOH from 6,639'MD-644'MD, racking DP in derrick. Monitor displacement. 6,695.0 644.0 2/22/2020 15:45 2/22/2020 17:00 1.25 PROD1 PLUG PULD P OWFF, rig down 4" handling equipment, R/U 3 1/2" equipment and power tongs. Laydown 3 1/2" EUE stinger to the pipeshed from 644' to surface. 644.0 0.0 2/22/2020 17:00 2/22/2020 17:30 0.50 PROD1 PLUG MPSP P Rig down and swap out 3 1/2" to 4" tools. M/U Baker Cast Iron Bridge Plug. 0.0 0.0 2/22/2020 17:30 2/22/2020 20:30 3.00 PROD1 PLUG MPSP P TIH from surface to 4,668'MD with stands of 4" DP. Rotate string 2 precautionary turns to left every 10 stands. RIH at 90fpm, monitor displacement, PU/SO=105K/109K. 0.0 4,668.0 2/22/2020 20:30 2/22/2020 21:00 0.50 PROD1 PLUG MPSP P Rotate 10 turns to right to set slips, PU/SO 3 times to 140K/74K to expand element and confirm set. 4,668.0 4,668.0 2/22/2020 21:00 2/22/2020 21:30 0.50 PROD1 PLUG PRTS P R/U and pressure test to 2,700psi/10 charted minutes, witnessed by CPAI rep, Bled down kill line and rotate 10 turns to the right to shear off. Observed weight drop from 110K to 103K on the 5th turn. Continue to pick- up to confirm release. 4,668.0 4,668.0 2/22/2020 21:30 2/23/2020 00:00 2.50 PROD1 PLUG FRZP P Circulate @4,660'MD, cutting brine density from 12.3ppg to 11.7ppg to lower crystalization point from 19F to - 19F. Pumped at 350psi/210gpm, 3% FO. 4,668.0 4,660.0 2/23/2020 00:00 2/23/2020 05:00 5.00 PROD1 PLUG PULD P POOH from 4,660'MD to surface with 4'DP, laying down singles to the pipeshed., L/D Baker running tools. 4,660.0 0.0 2/23/2020 05:00 2/23/2020 06:30 1.50 PROD1 PLUG TRIP P M/U MULE SHOE AND RIH T/ 2,470‘ MD, W/ 4” DP, P/U WT = 71K, S/O WT = 81K; MONITOR DISP. ON TRIP PIT 4. MU mule shoe on 4" DP and run in stands to 2,470'MD 0.0 2,470.0 2/23/2020 06:30 2/23/2020 10:00 3.50 PROD1 PLUG PULD P POOH from 2,470', laying down 4" singles to the pipeshed. Turn off hole from 1,500' to create void for top fill diesel freeze protect. 2,470.0 0.0 Rig: PW AKE-305 - Priority Page 24/24 RHEA 1 Report Printed: 3/31/2020 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/23/2020 10:00 2/23/2020 12:00 2.00 PROD1 PLUG THGR P RU and pull wear bushing. PU tubing hanger with WLEG and preinstalled and tested HP-BPV. Land hanger @11:15 and RILDS as per FMC. Lay down landing joint and R/U stack washer and flush rider and BOP stack with water. 0.0 0.0 2/23/2020 12:00 2/23/2020 14:30 2.50 PROD1 MOVE WWWH P Continue to wash and flush riser and BOP stack, clean rig floor and surface equipment. 0.0 0.0 2/23/2020 14:30 2/23/2020 18:00 3.50 PROD1 MOVE NUND P Nipple down BOPE and MPDE, L/D riser and adapter spool. 0.0 0.0 2/23/2020 18:00 2/23/2020 20:30 2.50 PROD1 MOVE WWWH P Warm up tree, install and torque up as per FMC 0.0 0.0 2/23/2020 20:30 2/24/2020 00:00 3.50 PROD1 MOVE PRTS P Test adapter flange void and hanger seals to 250/5000psi 10mins each, good, witnessed by CPAI. 0.0 0.0 2/24/2020 00:00 2/24/2020 00:30 0.50 PROD1 MOVE PULD P R/U to L/D 5" DP via rotary mousehole on top of PS-21 slips in rotary table. 0.0 0.0 2/24/2020 00:30 2/24/2020 09:15 8.75 PROD1 MOVE PULD P Break down (72 stands in derrick) and lay down singles to the pipe shed. 0.0 0.0 2/24/2020 09:15 2/24/2020 10:00 0.75 PROD1 MOVE FRZP P R/U to fill 7 5/8" casing with diesel through dry hole tree. Got in 100gals due to foaming issues. Install BPV and tree cap with gauge. 0.0 0.0 2/24/2020 10:00 2/24/2020 12:00 2.00 PROD1 MOVE PULD P Break-out and lay down 5" DP singles. SIM-OPS: welder installing splash guards on mud tanks, electrician swapping lights to L.E.D.. Working on moving system tires. 0.0 0.0 2/24/2020 12:00 2/24/2020 14:00 2.00 PROD1 MOVE PULD P L/D 5" DP, steaming connections for easier break-out. 0.0 0.0 2/24/2020 14:00 2/24/2020 16:00 2.00 PROD1 MOVE SVRG P Mechanic change out shot pin assembly on the top drive. Electrician maintenance on monkey board collision warning system. 0.0 0.0 2/24/2020 16:00 2/24/2020 17:00 1.00 PROD1 MOVE SVRG P Hang blocks and top drive to cut and slip drilling line. Cut 107'. 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Yes Vol Cement … 191.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 5 Q Pump Final (bbl/… 8 Q Pump Avg (bbl/… 5 P Pump Final (psi) 363.0 P Plug Bump (psi) 1,246.0 Recip? Yes Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 191bbls Good Cement Returns to surface observed. Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 75.0 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/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) 39.5 Est Btm (ftKB) 1,852.0 Amount (sacks) 905 Class G Volume Pumped (bbl) 308.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sa… 6.65 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 214.0 Thickening Time (hr) 5.57 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,852.0 Est Btm (ftKB) 2,352.0 Amount (sacks) 288 Class G Volume Pumped (bbl) 60.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sa… 5.02 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 131.9 Thickening Time (hr) 3.13 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/28/2020 00:00 Page 1/1 RHEA 1 Report Printed: 5/5/2020 Cement Detail Report Cement Details Description Intermediate Casing Cement Cementing Start Date 2/15/2020 18:00 Cementing End Date 2/15/2020 16:33 Wellbore Name RHEA 1 Comment Cold Mitigation-All fresh water for mixing was delivered warm from the rig tank Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Isolate 7 5/8" up to stage collar at 6578'MD Top Depth (ftKB) 6,478.0 Bottom Depth (ftKB) 7,189.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 4 Q Pump Avg (bbl/… 4 P Pump Final (psi) 33.0 P Plug Bump (psi) 1,000.0 Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 2,000.0 Est Btm (ftKB) 5,118.0 Amount (sacks) Class G Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Intermediate Casing Cement Objective Isolate from stage tool to cover Qannik to 3000ft Top Depth (ftKB) 2,000.0 Bottom Depth (ftKB) 6,478.0 Full Return? No Vol Cement … 0.0 Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/… 5 P Pump Final (psi) 104.0 P Plug Bump (psi) 909.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 2,000.0 Est Btm (ftKB) 5,118.0 Amount (sacks) 543 Class G Volume Pumped (bbl) 178.1 Yield (ft³/sack) 1.84 Mix H20 Ratio (gal/sa… 6.45 Free Water (%) Density (lb/gal) 11.20 Plastic Viscosity (cP) 120.3 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 5,118.0 Est Btm (ftKB) 6,589.0 Amount (sacks) 254 Class G Volume Pumped (bbl) 90.0 Yield (ft³/sack) 1.99 Mix H20 Ratio (gal/sa… 10.96 Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) 48.5 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/28/2020 00:00 Page 1/1 RHEA 1 Report Printed: 3/31/2020 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 2/21/2020 12:00 Cementing End Date 2/21/2020 13:30 Wellbore Name RHEA 1 Comment Pumped balanced cement plug 7,345'MD-6,761'MD with 20 joint 3 1/2" EUE stinger. Tagged firm cement at 6,696'MD with 10K down and pressure tested to 1,750psi after WOC 11+ hours with AOGCC witness. Cement Stages Stage # 1 Description Cement Plug Objective P&A open hole back into interrmedaiate shoe. Top Depth (ftKB) 6,695.0 Bottom Depth (ftKB) 7,345.0 Full Return? Yes Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 4 Q Pump Avg (bbl/… 4 P Pump Final (psi) 31.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 6,639.0 Tag Method Tubing Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Abandonment Cement Fluid Description Estimated Top (ftKB) 6,761.0 Est Btm (ftKB) 7,345.0 Amount (sacks) 157 Class G Volume Pumped (bbl) 28.0 Yield (ft³/sack) 1.00 Mix H20 Ratio (gal/sa… 5.00 Free Water (%) Density (lb/gal) 17.00 Plastic Viscosity (cP) 171.0 Thickening Time (hr) 11.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: DRILLING ORIGINAL, 1/28/2020 00:00 ORIGINATED ALASKA E—LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TRANSMITTAL DATE: TRANSMITTAL #: 220002 BP North Slope 1 0 0 1 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. RE CE D1 F D 1 0 0 Attn: NSK-69 APR 0 3 2020 700 G Street A� r !� Anchorage, Alaska 99501 V l✓ AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 0 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - F Please return via e-mail a copy to both Alaska E -Line Services and CorWo Phillips Alaska: Fa MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Section: 13 Township: 12N Drilling Rig: X Rig Elevation: 39.69 ft Operator Rep: Rob Reinhardt Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ Surface: 10-3/4" 0. D. Shoe@ Intermediate: 7-5/8" 0. D. Shoe@ Production: NA 0. D. Shoe@ Liner: NA 0. D. Shoe@ Tubing: NA 0. D. Tail@ Plugging Data: Test Data DATE: February 22, 2020 SUBJECT: Well Bore Plug & Abandonment Colville River Unit Rhea 1 - CPAI PTD 2200020 ' Range: 4E Meridian: Umiat 'dotal Depth: 7345 ft MD - Lease No.: ADL025526 110 - Feet 2455 Feet 7225 Feet NA Feet NA Feet NA Feet Suspend: NA P&A: X Depth To MW Above Casing Removal: Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Tbg Cut@ NA Feet T pe Plug Founded on Depth Btm Depth To MW Above Verified Fullbore - Bottom 7345 ft MD 6695 ft MD ' 12.3 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing NA NA NA P IA 1935 1842 1806 - OA 0 0 0 Remarks: I traveled to Doyon Rig 25, Well CRU Rhea 1, to witness the tag and pressure test of a cement plug placed in the small open hole section and extending up into the 7-5/8" casing. The cement was in place approximatley twelve hours prior to the tag. They used a 3.5 -inch muleshoe to tag with a downweight of 123k lbs and found the top of the plug at 6695 ft MD (530 feet inside casing) with 10k lbs set down. Tag was higher than anitcipated. Pumping down the drillpipe and kill line they then completed a 30 minute passing test against the plug. There was some discrepancies when I showed up in regards to paperwork that had/had not been approved. I did see the operators procedure for the P&A but the Permit to Drill stated that the P&A would be on a Sundry. There was no sundry and because of that both the operator and I had no idea what pressure to test the plug to so we used the ✓ generic MIT criteria for calcualtions on the plug top/shoe depth. Post me leaving location AOGCC's Victoria Loepp contacted me via email and said the bottom plug was approved on the Permit to Drill. Attachments: none rev. 11-28-18 2020-0222_Plug_Verification_CRU_Rhea-1 _am Pro o? -70 - a 02- Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Tuesday, March 17, 2020 5:41 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Rhea-1 (PTD 220-002, Sundry 320-100) P&A Change Approval Attachments: Rhea 1 CBL 3-17-2020.pdf; RHEA-1_GR_SBT_1760_7190_51N_MD.PDF Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached is the Pollard CBL we ran today as well as the Baker log that was run on rig. If you look at the depths where both logs were run over the same depth the data lines up pretty well. Looking at the Pollard log you can see what look like several stringers well above the original TOC pick depth of 1860. Now, I say cement stringers but I guess there is some possibility that they could be frozen fluids? My only concern right now is that we may have to shoot at 220' or higher. It looks like we might have clear pipe above 220' MD. Please let me know if you have any other questions. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 17, 2020 8:42 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]Rhea-1 (PTD 220-002, Sundry 320-100) P&A Change Approval Hi Steve, Approval is granted to shoot at 500' MD and pump 10.7 ppg lite crete on the backside if necessary. Please pass on the result of the 7-5/8 x 10-3/4 CBL when it becomes available. (AOGCC is working both from home and in the office; changing hourly) Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(d)alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepu �aias'ra�y, Rhea 1 C's El 0 L From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Tuesday, March 17, 2020 8:21 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]Re: Rhea -1 P&A Hi Victoria, Was wondering if you got what you needed for Rhea and if we are ok to shoot at 500 feet if necessary? (Is AOGCC still working from the office this week?) Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, March 16, 2020 7:22 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]Re: Rhea -1 P&A Steve, Please send me the plugging WBS and procedure. I don't have copies with me. Thx, Victoria Sent from my iPhone On Mar 16, 2020, at 7:12 AM, Drake, Steve G <Steve.G.Drake @conocophillips.com> wrote: Hi Victoria, I wanted to bring you up today on the Rhea -1 P&A and possibly get a verbal from you to change up scope if needed. Currently we've been having trouble establishing circulation between the 7 5/8" pipe and the 10 W surface casing. We have shot a couple of tubing punches and have attempted a couple of backside thaw jobs, thinking that there might be an ice lens on the backside, but have yet to be able to establish communication. Today, we are going to try one last attempt at shooting a tubing punch at a decent depth, 1200' MD, before coming up and attempting to shoot at 500' MD. The thought process in shooting up at 500' is that hopefully we'll be above anything that might be giving us issues. IF, it is determined that we need to shoot high, we have decided on a 10.7 ppg lite crete cement that we will pump on the backside. This cement should stay on top of the 11.7 ppg brine that is on the backside and prevent them from swapping out. Please let me know if you are OK with this potential change to procedure. We should have ELINE on the well later today to make the tubing punch at 1200' MD. Thanks, Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake(o)conocophillips.com Office: (907) 263-4062 Mobile: (907) 223-1166 SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7TH SUITE 100 ANCH. AK. 99501 2791433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: RHEA 1 DATE: March 17, 2020 AIR BILL: N/A CPAI: 2020031701 CHARGE CODE: N/A NAME: RHEA 1 NUMBER OF BOXES: 7 Box Qo -(DO Z t Ty I 100-7039 SENT BY: M. McCRACKEN UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO -380 ANCHORAGE, AK. 99510 ATTN: MIKE McCRACKEN Mike.mccracken@conocophillips.com RECEIVED: f 3(t -4l zv TL5DtA5 RECEIVED MAR 17 2020 AOGCC ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 2200 aZ TRAIWITTAL DATE: • TRANSMITTAL #: FIELD • - BP North Slope 1 0 1 0 1 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. KtCEIV0 0 Attn: NSK-69 MAR 1 1 2020 700 G Street Anchoraee, Alaska 99501 A r) r-, r-•►� AOGCC 1 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 1 0 1 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Pint Name Signature Date Please return via e-mail a copy to both Alaska E -Line Services and Conoc(e-lrilne.com ips Alaska: tom.osterkamDC@conocoohillios.com recentionna prD '7'�0 -002 Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Friday, March 6, 2020 10:54 AM To: Loepp, Victoria T (CED) Subject: Re: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Approved Follow Up Flag: Follow up Flag Status: Flagged Thank youth Get Outlook for iOS From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, March 6, 2020 10:48:20 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]Rhea 1(PTD 220-002) Reservoir Plug Approved Approved yesterday, couriered this morning From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Friday, March 6, 2020 7:29 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Re: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Hi Victoria, Was wondering if you have everything you need for the 403? We were hoping to begin work this weekend on the Rhea P&A. Thanks, Steve Get Outlook for iOS From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 4, 2020 3:44:38 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: RE: [EXTERNAL)Rhea 1 (PTD 220-002) Reservoir Plug This is good From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, March 4, 2020 3:41 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: RE: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug 1 Victoria, The only information in the sundry regarding the plug is on the schematic. I've taken what information I have about the plug and included it below. Please let me know if you need any other information or if there is anything I can do to help. Thanks for taking the time to expedite this sundry. A balanced cement plug was pumped from a depth of 7345' MD up to 6761' MD. The rig tagged firm cement at 6696' MD with IOK down and pressure tested it to 1750 psi after waiting on cement for 11+ hours. The pressure test was witnessed by the AOGCC. The cement plug is approximately 550' up inside of the intermediate casing shoe. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 4, 2020 3:15 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Steve, I will track the sundry down and try to expedite. I would like, as outlined below, this sundry to include the first reservoir plug that has already been completed. If the sundry does not include this information, please forward this information to me to include in the Sundry. Thanx, Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, March 4, 2020 12:03 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Re: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Victoria, 10-403 for the Rhea P&A was submitted this morning. We'd like to start the work as early as this Friday so was wondering if you had time to look it over the next day or two? Thanks, Steve Get Outlook for SGS From: Polasek, Tom G <Tom.G.Polasek@conocophiliips.com> Sent: Wednesday, March 4, 2020 10:30:29 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Drake, Steve G <Steve.G.Drake conocoffillips.com> Subject: RE: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Hi Victoria, Thanks for the heads up. Steve Drake is the Well Engineer that will submit the final P&A Sundry for Rhea. Steve is cc'd on this reply. Steve, do you have an update on timing of final P&A Sundry submittal? Thanks Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 04, 2020 10:22 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Tom, What engineer will be preparing the final P&A sundry? We need to have the reservoir plug covered in a sundry; it can be added to the sundry for the remainder of the P&A or more likely, we need a separate sundry, for the reservoir plug pumped, although the work has been completed. Let me know the timing for preparation of the final P&A sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aaaiaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loerpp4alaska.aov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 9:19 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: RE: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Victoria, The Sundry for P&A will be submitted in near future. The P&A will be performed by our Wells Group using coil tubing. The cement and work we are currently performing with the drilling rig is to set the Well's Group up for the P&A, after the rig moves off. Between the drilling rig moving off the well and the P&A, Conoco will perform a VSP log in the well, using wireline and vibe trucks. Please let me know if you have any other questions or concerns and I will answer them or get you in contact with the appropriate Well engineer that can answer them. Thanks tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, February 21, 2020 9:06 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Tom, I haven't seen a sundry for P&A? Victoria From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 8:50 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov> Subject: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Hi Victoria, Please find the attached Cement Bond Log for Rhea 1, 7-5/8" Intermediate Casing Cement Job. BakerHughes wireline found top of cement to be 1860' MD We are currently running in hole to pump our Cement Abandonment Plug. z M (n M 0 C13 <-< m 0 ;a 0 M 0 CE) m cM-nx&xr-QqCCMMMM-u-.q-0-u;Oz-j Z 0 ;u M M ;u M Z M r- OOMOMMZ OOOE00-4 > m M M M M Z M r, jc > - M 0 0 0 M z 0 Z > r- r- 0 G) M M 0 r, > M C M :c 0 r- > --iM _0 z :E M r- M > 0 M ;0 M 0 a M M . 0 0 M < M r- 0 > F- 0 0 M Z W � M 0 M -n r- S; 0 0 r- M o M X > --4 0 M 5 M M Z — C/) X M 0 ic -4 > M --j M 0 --i 0 r - 00 a 6) M 0 z --1 < > Eu 0 --I M r- 0 0 M;0;0;0— 0 2 -q M ;o < > a M --q == r- 0 0 0 M o M --i 0 ;a r- r- M ca M < 5 M 0 ;0 0 m c p > M 0 n -Dim 0 z --f > 4. N) 0 0 > 7, z -0 M C) :[ X 0 0 Q -n CSD OD aco , �) o NJ 0 X M M r- Z M cp M G) (A -n Z CJJ M G) M 0 0 -n -n --- I —4�6 j 0 Doan 0 M -u C) * OD c", 0 0 cy) A > 0 G) M -n --4 CD cr 0 IQ i 0 0 Z > r - > (n 0 Thanks tom Tom Polasek Drilling Engineer 5 0 M F M 0 X F r -- -In r- 0 0 ;u r- 0 M Cl) c M M 0 -n M 0 M 0 n :1 M M ;u ic z M z --i 0 C r. M r - M Oz 00 �O -n --A r - 0 z G) --4 c 0 0 M G) C C.4 ConocoPhillips Alaska Uttice: 9u7-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com THE STATE Steve Drake °'ALASKA GOVERNOR MIKE DUNLEAVY Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU RHEA 1 Permit to Drill Number: 220-002 Sundry Number: 320-100 Dear Mr. Drake: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov 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, Vre Price DATED this 15 day of March, 2020. 113DM$,it�? MAR 0 6 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAR 4 2020 AOGCC 1. Type of Request: Abandon E ' 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: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilll s Alaska Inc. Exploratory ❑ Development 0 - Stratigraphic El Service ❑ 220-002 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20823-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU RHEA 1 Will planned perforations require a spacing exception? Yes 11 No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25526 Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,345' 7,037' 7345 7037 2500psi 4666, 6695 N/A Casing Length Size MD TVD Burst Collapse Conductor 72' 20" 112' 112' Surface 2,313' 11" 2,352'2,352' 6,893' Intermediate 7,152' 8" 7,189'nTb, Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:ng Grade: Tubing MD (ft): N/A N/A 4.500" L-80 40' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic Development g p ❑ p ❑ Service ❑ 14. Estimated Date for 3 G 2DZ� 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ GAS ❑ WAG ❑ GSTOR ❑ Suspended ❑ 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. Authorized Name: Steve Drake Steve Drake Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Steve.G.Drake@cop.com Contact Phone: (907) 263-4062 Authorized Signature: � �- Date: 7,� Z v i' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: t �`}� _/C V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Cq Other: �f"D�G'C �✓� 1`ru55 Cts<n� � Svrt�'cc C�i�f-z' rah p L u �! %�%o to c6o ��--►��e 5� Post Initial Injection MIT Req'd? Yes E]No C5" - � MAR 0 6 2020 � 2 ��T Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: v �D , / APPROVED BY 2 13 � %/ Y Approved by: , COMMISSIONER - THE COMMISSION Date: ��i�//// d t vv U U �'X 3,5,,73i��o 0 R - IGINAL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. ,Ile 3 Submit Form and Attachments in Duplicate Ge ral Well Work Request Form Well: Rhea -1 Date of Request: Request SPOC: Well Type: Producer Req. Written by: Job Scope: Drilling Support Shut -In Reason Code: Budget Category: I Plug&Abandon Well Shut in Date (if SI): Prioritization Category: Network: Job / SAP Comment: 3/3/2020 Aipine PE x4934 Steve Drake, 263-4062 700 Regulatory/Compliance/Surveillance Other Rig 10419650 Well Work Justification & Objectives (and date required if appropriate): Rhea -1 is a single vertical well designed and implemented to investigate reservoir pressure and sand thickness to support the upcoming ERD project on CD2. The well was drilled and completed in late February 2020. The well was left with the reservoir cememted off up to 300' inside the 7 5/8" casing (TOC @ 6695' MD) and a cast iron bridge plug @ 4468' MD for secure. A couple of days of off -rig logging will occur prior to P&A operations. This procedure will outline the steps necessary to P&A Rhea -1. Current estimated start date for this procedure is March 6-7, 2020. Risk/Job Concerns: Well will have a Gen 5 wellhead with a dry hole tree. (see wellhead tab(s) for diagram) Rig brought cement cement up in annulus (between surface casing and intermediate casing) to 1860' MD - SEE CBL TAB Abandonment plug placed with top @ 6695' MD. Tested with AOGCC witness. ,,111 Cast iron bridge plug placed at 4668' MD and tested/charted to 2700 psi. for 10 minutes. Brine below CIBP is 12.2 ppg NaBr. Brine above CIBP is 11.7 ppg NaBr up to 175' MD. TCT of 11.7 NaBr is -19 F Diesel from 175' MD to surface. Min ID of 3.958" at tubing hanger @ 34.8' MD. A balanced cement plug was pumped from a depth of 7345' MD up to 6761' MD. The rig tagged firm cement at 6696' MD with 10K down and pressure tested it to 1750 psi after waiting on cement for 11+ hours. The pressure test was witnessed by the AO&CC. The cement plug is approximately 550' up inside of the intermediate casing shoe. of SLB EL & LRS (Tubing punch/circ out backside with 60/40 methanol) 1. MIRU EL unit and associated support equipment. 2. MU and RIH with 2' of tubing punch, magnets for decentralization and bowspring eccentralizer. 3. Shoot tubing punch at 1850' MD. No significant gamma signature to tie into on CBL. 4. POOH. 5. Utilizing LRS pump truck, circulate 158 barrels of 60/40 methanol down tubing, taking returns off of IA to estabilsh injection rate for upcoming cement job. Perform SRIT at 0.5 barrel increments up to 2500 psi WHP. A. If circulation cannot be attained consider one more tubing punch @ 1840' MD. B. If after the second punch there is no circulation, hand well off to coil to perform a backside thaw due to possible frozen fluids between 7 5/8" pipe and surface casing. 7. RDMO SLB Coil Tubing & Halliburton Cement (Place cement plug in 7 5/8") 1. Contact Alpine wells support to ensure typical coil rig up is available. Well should already have a flow cross from VSP operations. 2. Contact Mark Dean (303-506-8462) with Halliburton cement to ensure product and crew are available for cement job. 3. MIRU CT unit and associated support equipment. 4. MU and RIH with cement nozzle pumping seawater at minimum rates, taking returns off the tubing to tanks. Rhea -1 PA 03-03-20 SGD V4 Printed 3/5/2020 Well Work is not justified via increased production Preventive Maintenance Program Request Current Well Data After Well Work Data Current Oil Rate (BOPD) 0 Post -Job Oil Rate (BOPD) 0 Risked NOB (BOPD) Enter Rates Last SBHP 4464 psi Last Tag 4,668'md H2S (PPM): NA SBHP Date 2/21/2020 Tag Date 2/22/2020 Any Fluid Restriction on Well? No SBHP Datum (TVD/SS?) 7037 TVD Max Inclin. 24° Max Dogleg 6° / 100' and Min. LD (at/above work) 3.958" Max Incl. Depth 4,206'md Max Dogleg Depth 7,246'md Well Work Justification & Objectives (and date required if appropriate): Rhea -1 is a single vertical well designed and implemented to investigate reservoir pressure and sand thickness to support the upcoming ERD project on CD2. The well was drilled and completed in late February 2020. The well was left with the reservoir cememted off up to 300' inside the 7 5/8" casing (TOC @ 6695' MD) and a cast iron bridge plug @ 4468' MD for secure. A couple of days of off -rig logging will occur prior to P&A operations. This procedure will outline the steps necessary to P&A Rhea -1. Current estimated start date for this procedure is March 6-7, 2020. Risk/Job Concerns: Well will have a Gen 5 wellhead with a dry hole tree. (see wellhead tab(s) for diagram) Rig brought cement cement up in annulus (between surface casing and intermediate casing) to 1860' MD - SEE CBL TAB Abandonment plug placed with top @ 6695' MD. Tested with AOGCC witness. ,,111 Cast iron bridge plug placed at 4668' MD and tested/charted to 2700 psi. for 10 minutes. Brine below CIBP is 12.2 ppg NaBr. Brine above CIBP is 11.7 ppg NaBr up to 175' MD. TCT of 11.7 NaBr is -19 F Diesel from 175' MD to surface. Min ID of 3.958" at tubing hanger @ 34.8' MD. A balanced cement plug was pumped from a depth of 7345' MD up to 6761' MD. The rig tagged firm cement at 6696' MD with 10K down and pressure tested it to 1750 psi after waiting on cement for 11+ hours. The pressure test was witnessed by the AO&CC. The cement plug is approximately 550' up inside of the intermediate casing shoe. of SLB EL & LRS (Tubing punch/circ out backside with 60/40 methanol) 1. MIRU EL unit and associated support equipment. 2. MU and RIH with 2' of tubing punch, magnets for decentralization and bowspring eccentralizer. 3. Shoot tubing punch at 1850' MD. No significant gamma signature to tie into on CBL. 4. POOH. 5. Utilizing LRS pump truck, circulate 158 barrels of 60/40 methanol down tubing, taking returns off of IA to estabilsh injection rate for upcoming cement job. Perform SRIT at 0.5 barrel increments up to 2500 psi WHP. A. If circulation cannot be attained consider one more tubing punch @ 1840' MD. B. If after the second punch there is no circulation, hand well off to coil to perform a backside thaw due to possible frozen fluids between 7 5/8" pipe and surface casing. 7. RDMO SLB Coil Tubing & Halliburton Cement (Place cement plug in 7 5/8") 1. Contact Alpine wells support to ensure typical coil rig up is available. Well should already have a flow cross from VSP operations. 2. Contact Mark Dean (303-506-8462) with Halliburton cement to ensure product and crew are available for cement job. 3. MIRU CT unit and associated support equipment. 4. MU and RIH with cement nozzle pumping seawater at minimum rates, taking returns off the tubing to tanks. Rhea -1 PA 03-03-20 SGD V4 Printed 3/5/2020 Page 2 Well: Rhea -1 Date of Request: 3/3/2020 Request SPOC: Alpine PE x4934 Steps Continued (list service type): 5. While RIH, batch up and prepare 129 barrels of 15.8 ppg Class G cement. This batch will be the deep blend, designed for 80 deg. Volume of 7 5/8" tubing from CIBP @ 4668' MD to 1860' MD (TOC between 7 5/8" and surface casing) is 2808'. 2808'x 0.0459 = 128.89 barrels. 6. Lightly tag CIBP at approximately 4668' RKB. 7. Pump 5 bbls fresh water spacer followed by 15.8 ppg Class G deep blend cement. Allow 3 barrels of cement to get up around coil before POOH and laying in cement. 8. POOH laying in cement from CIBP to 1860' MD. 9. While laying in 129 bbls. of deep blend, begin batching up 158 bbls. of 15.8 ppg. Class G cement designed for 60 deg. This batch will be the shallow blend. 10. Once nozzle depth reaches approximately 1850' MD, shut in tubing, open IA and begin pushing cement through tubing punches and displacing out IA. Lead IA volume with 5 bbls. FW spacer followed by the 92 barrels of IA cement. Volume of IA from 1850 to surface approximately ii proximately 73 barrels. 92 barrels is the equivalent of 25% excess. 11. Monitor tanks for returns. Once good cement returns are seen, shut in gate valve at IA and open up tubing. 12. Lay in remaining shallow blend, approximate y 5 arrels, from 1850' to surface. 13. RDMO. Allow 72 hours for cement to cure before commencing surface P&A portion of procedure. Well Integrity (Remove wellhead) 1. DHD to perform drawdown test on tubing and IA. 2. Remove well house. 3. Bleed off T/I/O to ensure all pressure is bled off the system. 4. Remove production tree in preparation for excavation and casing cut. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off wellhead and all casing strings at 4 feet below original ground level. 6. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required.Q� C 7. Send the casingng head with stub to materials shop. Photo document. 8. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips Rhea -1 PTD #: 220-002 API #: 50-103-20823-00 9. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed. Rhea -1 PA 03-03-20 SGD V4 Printed 3/5/2020 Rhea 1, FWK Pilot — P&A Schematic 71 Proposed Schematic updated 3/4/20, RKB 39.7 ft 0 W r9 y �,)V -7 C30 Sand Top 2480' MD / 2480' TVD Qannik Sand Top 4079' MD / 4063' TVID Qannik Sand Base 4182' MD 4134' TVID HRZ Top 6577' MD 6333' TVID -00 Kalubik Kuparuk C Sand Top Top. 7229' MD -6931' TVID 3.00 A: n0o: 10a ihg LCU --7239' MD -6942' TVD Nechelik Top -7450' MD 20" Conductor to 120' Cement Plug #3 0' MID to 1860' in tubing Cement Plug #2 0' MID to 1860' in A 11.2 ppg Cement TOC 1869 MID 1869 TVID 13.5" Open Hole with 10.75" 45.5 ppf L-80 TXP 2,352' MD / 2,352' TVD Cement Plug #1 1850' MD to 4669 MID in tubing Baker CIBP -4668' MD / -4582' TVID HES Stage Cementer 6579' MD 6 TVID 15.8 ppg Cement TOC at Stage Cementer 9-7/8" X 11" Underreamed Openhole with Top Set Casing 7 5/8" 29.7 ppf L-80 TXP 7189' MD / 6894' TVD @ 22.7- 6.5" Open Hole TD -7339' MD WNS II WELLNAME RHEA 1 WELLBORE RHEA 1 �OnOCo`RllillipsIQ Well Attribm Max AngIL 0 TD Fieltl Name WellboreAPI/UWI Wellbore Status I cl V) MD (ftKB) Act Btm (ftKB)Alaska, Inc.FIOR. WEST KI IPARI IK Sn1n,,nR27On Pnnr) 402 d 2R5 26 7 i11 (1 Release Date NONE I I ILAST WO' RHEA 1, 314120206:33:59 AM Last Tag Venial schematic (actual) Annotation Depth (ftKB) I End Date Wellbore Last Mod Ey LAST TAG: CEMENT - Witnessed by AOGCC, Austin 6,695.0 2/22/2020 RHEA 1 pproven McCLeod 1 ...................... .....__ _ _.._ ............................ Last Rev Reason HANGER, 34.8- Annotation I End Date Wellbore 1 Last Mod By REV REASON: New Well 131312020 1 RHEA 1 1jennalt Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread """"""'."` ............."........................'""""' CONDUCTOR 20 19.12 39.7 112.0 112.0 94.00 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grad e Top Thread SURFACE 103/4 9.95 39.5 2,352.2 2,352.1 45.50 L-80 TXP-M Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (1... Grade Top Thread INTERMEDIATE 75/8 6.88 37.0 7,189.2 6,892.9 29.70 L80 TXPM I Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (IbKt) Gratle Top Connection MULE SHOE, 38.2 TUBING GUIDE STRING 41/2 3.96 34.8 39.5 39.5 12.60 L-80 Hyd563 Completion Details op (TVD) Topincl Nominal Top (ftKB) (ftKB) (') Item Des Com ID (in) ............................................................. ............. •........... 34.8 34.8 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril HYD 563 3.958 38.2 38.2 0.00 MULE SHOE JWLEG 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TVD) Top Incl Top (ftKB) (ftKB) I. Des Com Run Date ID (in) 34.8 34.8 0.00 Barrier - Back 2/24/2020 0.000 Pressure Valve „H„ 4,666.0 4,573.1 23.67 Bridge Plug - Baker Cast Iran Bridge Plug 2/22/2020 0.000 Permanent Cement Squeezes Top (TVD) Btm (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Des Start Date Com 6,695.0 7,345.0 6,436.5 7,037.1 Cement Plug 2/21/2020 Pumped balanced cement plug 7,345'MD-6,761'MD with 20 joint 3 1/2" EUE stinger. Tagged firm cement at 6,696'MD with 10K down and pressure tested to 1,750psi after WOC 11+ hours with AOGCC witness. Notes: General & Safety CONDUCTOR; 39.7-1120 End Date Annotation NOTE: SURFACE, 39.5-2,352.2 Bndge Plug- Permanent; 4Wo Cement Plug, 6,639.0 ftKB INTERMEDIATE, 37 0-7,1892 G gyral Well Work Request Form Well: Rhea-1 Date of Request: 3/3/2020 Request SPOC: Alpine PE x4934 Well Type: Producer Req. Written by: Steve Drake, 263-4062 Job Scope: Drilling Support Shut-In Reason Code: 700 Regulatory/Compliance/Surveillance Other Well Shut in Date (if SI): Prioritization Category: Rig Budget Category: Plug&Abandon Network: 10419650 Job / SAP Comment: Well Work is not justified via increased production Preventive Maintenance Program Request Current Well Data i After Well Work Data Current Oil Rate (BOPD) 0 Post-Job Oil Rate (BOPD) 0 Risked NOB (BOPD) Enter Rates Last SBHP 4464 psi Last Tag 4,668'md H2S (PPM): NA SBHP Date 2/21/2020 Tag Date 2/22/2020 Any Fluid Restriction on Well? No SBHP Datum (TVD/SS?) 7037 TVD Max Inclin. 24° Max Dogleg 6° / 100' and Min. LD (at/above work) 3.958" Max Incl. Depth 4,206'md Max Dogleg depth 7,246'md Well Work Justification & Objectives (and date required if appropriate):./ Rhea -1 is a single vertical well designed and implemented to investigate reservoir pressure and sand thickness to support the upcoming ERD project on CD2. The well was drilled and completed in late February 2020. The well was left with the reservoir cememted off up to 300' inside the 7 5/8" casing (TOC @ 6695' MD) and a cast iron bridge plug @ 4468' MD for secure. A couple of days of off -rig logging will occur prior to P&A operations. This procedure will outline the steps necessary to P&A Rhea -1. Current estimated start date for this procedure is March 6-7, 2020. Risk/Job Concerns: Well will have a Gen 5 wellhead with a dry hole tree. (see wellhead tab(s) for diagram) Rig brought cement cement up in annulus (between surface casing and intermediate casing) to 1860' MD - SEE CBL TAB Abandonment plug placed with top @ 6695' MD. Tested with AOGCC witness. Cast iron bridge plug placed at 4668' MD and tested/charted to 2700 psi. for 10 minutes. Brine below CIBP is 12.2 ppg NaBr. Brine above CIBP is 11.7 ppg NaBr up to 175' MD. TCT of 11.7 NaBr is -19 F C Diesel from 175' MD to surface. �►� /l/ Min ID of 3.958" at tubing hanger @ 34.8' MD. J Steps: SLB EL & LRS (Tubing punch/circ out backside with 60/40 methanol) 1. MIRU EL unit and associated support equipment. 2. MU and RIH with 2' of tubing punch, magnets for decentralization and bowspring eccentralizer. 3. Shoot tubing punch at 1850' MD. No significant gamma signature to tie into on CBL. 4. POOH. 5. Utilizing LRS pump truck, circulate 158 barrels of 60/40 methanol down tubing, taking returns off of IA to estabilsh injection rate for upcoming cement job. Perform SRIT at 0.5 barrel increments up to 2500 psi WHP. A. If circulation cannot be attained consider one more tubing punch @ 1840' MD. B. If after the second punch there is no circulation, hand well off to coil to perform a backside thaw due to possible frozen fluids between 7 5/8" pipe and surface casing. 7. RDMO SLB Coil Tubing & Halliburton Cement (Place cement plug in 7 5/8") 1. Contact Alpine wells support to ensure typical coil rig up is available. Well should already have a flow cross from VSP operations. 2. Contact Mark Dean (303-506-8462) with Halliburton cement to ensure product and crew are available for cement job. 3. MIRU CT unit and associated support equipment. 4. MU and RIH with cement nozzle faking returns off the tubing to tanks. ************* PRO EDURE CONTINUED ON NEXT PAGE ************************** Rhea -1 PA 03-03-20 SGD V3.xlsm Printed 3/3/2020 Page 2 Well: Rhea -1 Date of Request: 3/3/2020 Request SPOC: Alpine PE x4934 Steps Continued (list service type): 5. While RI H, batch up and prepare 129 barrels of 15.8 ppg Class G cement. This batch will be the deeper blend, designed for 80 deg. Volume of 7 5/8" tubing from CIBP @ 4668' MD to 1860' MD (TOC between 7 5/8" and surface casing) is 2808'. 2808'x 0.0459= 128.89 barrels. 6. Lightly tag CIBP at approximately 4668' RKB. 7. Begin pumping cement, displacing KWF out of hole. Allow 3 barrels of cement to get up around coil before POOH and laying in cement. 8. POOH laying in cement from CIBP to 1860' MD. 9. While laying in 129 bbls. of deep blend, begin batching up 158 bbls. of 15.8 ppg. Class G cement designed for 60 deg. This batch will be the shallow blend. 10. Once nozzle depth reaches approximately 1850' MD, shut in tubing, open IA and begin pushing cement through tubing punches and displacing out IA. Volume of IA from 1850 to surface is approximately 85 barrels. 11. Monitor tanks for returns. Once good cement returns are seen, shut in gate valve at IA and open up tubing. 12. Lay in remaining shallow blend, approximately 85 barrels, from 1850' to surface. 13. RDMO. Allow 72 hours for cement to cure before commencing surface P&A portion of procedure. Well Integrity (Remove wellhead) ESTIMATED SCHEDULE OF EVENTS BELOW 1. MIRU equipment (crane, excavator, loader, heater, air compressor, light plant) 1-2 days 2. Excavate. 1-2 days 3. Cut wellhead and top with cement if needed. 1-2 days 4. AOGCC witness top of cement and welding of marker plate. 1 day 5. RDMO equipment. 1 day 6. Pull shoring and backfill 1 day Rhea -1 PA 03-03-20 SGD V3.xlsm Printed 3/3/2020 c2c/ 8h7fa� Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, March 4, 2020 4:39 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL] Example P&A Sundry_319-309_070319.pdf Attachments: Rhea -1 P&A 03-03-20 SGD V4.xlsm; Rhea P&A Schematic.pdf Victoria, Thank you for looking over this for me. I've attached an updated procedure with all the information requested below. Also attached is a schematic of the well showing cement placement and planned depths. I've labeled them according to the order we are going to pump them per the procedure. I've also added a note about the information on the reservoir plug in the procedure. Please let me know if there is anything else. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 4, 2020 3:44 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL] Example P&A Sundry_319-309_070319.pdf Steve, Need the following information for this sundry: 1. See attached example; specifically the info that will be bead welded on the marker plate. 2. Need WBS schematic showing cement placement and planned depths. 3. See 20 AAC 25.120 and 20 AAC 25.170(a)(1) 4. Info on reservoir plug Thanx, V Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophiIli ps.com> Sent: Wednesday, March 4, 2020 3:41 PM To: Loepp, Victoria T (CED) Cc: Polasek, Tom G Subject: RE: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Victoria, The only information in the sundry regarding the plug is on the schematic. I've taken what information I have about the plug and included it below. Please let me know if you need any other information or if there is anything I can do to help. Thanks for taking the time to expedite this sundry. A balanced cement plug was pumped from a depth of 7345' MD up to 6761' MD. The rig tagged firm cement at 6696' MD with 10K down and pressure tested it to 1750 psi after waiting on cement for 11+ hours. The pressure test was witnessed by the AOGCC. The cement plug is approximately 550' up inside of the intermediate casing shoe. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 4, 2020 3:15 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Steve, I will track the sundry down and try to expedite. I would like, as outlined below, this sundry to include the first reservoir plug that has already been completed. If the sundry does not include this information, please forward this information to me to include in the Sundry. Thanx, Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, March 4, 202012:03 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Re: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Victoria, 10-403 for the Rhea P&A was submitted this morning. 31/ We'd like to start the work as early as this Friday so was wondering if you had time to look it over the next day or two? Thanks, Steve Get Outlook for iOS From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, March 4, 2020 10:30:29 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: RE: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Hi Victoria, Thanks for the heads up. Steve Drake is the Well Engineer that will submit the final P&A Sundry for Rhea. Steve is cc'd on this reply. Steve, do you have an update on timing of final P&A Sundry submittal? Thanks Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 04, 2020 10:22 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]Rhea 1 (PTD 220-002) Reservoir Plug Tom, What engineer will be preparing the final P&A sundry? We need to have the reservoir plug covered in a sundry; it can be added to the sundry for the remainder of the P&A or more likely, we need a separate sundry, for the reservoir plug pumped, although the work has been completed. Let me know the timing for preparation of the final P&A sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 9:19 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: RE: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Victoria, The Sundry for P&A will be submitted in near future. The P&A will be performed by our Wells Group using coil tubing. The cement and work we are currently performing with the drilling rig is to set the Well's Group up for the P&A, after the rig moves off. Between the drilling rig moving off the well and the P&A, Conoco will perform a VSP log in the well, using wireline and vibe trucks. Please let me know if you have any other questions or concerns and I will answer them or get you in contact with the appropriate Well engineer that can answer them. Thanks tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, February 21, 2020 9:06 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Tom, I haven't seen a sundry for P&A? Victoria From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 8:50 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Hi Victoria, Please find the attached Cement Bond Log for Rhea 1, 7-5/8" Intermediate Casing Cement Job. BakerHughes wireline found top of cement to be 1860' MD We are currently running in hole to pump our Cement Abandonment Plug. elsely sdllll4do:)ouoD iaaulgu3 BuIlIPCI laselod uaol wol slueyl uioa•s ! I J! 4d ODOUOD@ ilaselo •uao} t7ZSZ-OZ6-09L :I1a0 OVL£-E9Z-L06 :a:)!JIO pi D ;�,2-a-cc) Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 9:19 AM To: Loepp, Victoria T (CED) Cc: Drake, Steve G Subject: RE: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Follow Up Flag: Follow up Flag Status: Flagged Victoria, The Sundry for P&A will be submitted in near future. The P&A will be performed by our Wells Group using coil tubing. The cement and work we are currently performing with the drilling rig is to set the Well's Group up for the P&A, after the rig moves off. Between the drilling rig moving off the well and the P&A, Conoco will perform a VSP log in the well, using wireline and vibe trucks. Please let me know if you have any other questions or concerns and I will answer them or get you in contact with the appropriate Well engineer that can answer them. Thanks tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, February 21, 2020 9:06 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]RE: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Tom, I haven't seen a sundry for P&A? Victoria From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 21, 2020 8:50 AM To: Loepp, Victoria T (CED) <vctoria.io poalaska•�o_v> Subject: Rhea 1, PTD 220-002, Intermediate Casing Cement Bond Log Hi Victoria, 1 Please find the attached Cement Bond Log for Rhea 1, 7-5/8" Intermediate Casing Cement Job. BakerHughes wireline found top of cement to be 1860' MID We are currently running in hole to pump our Cement Abandonment Plug. z M (n U) M 0 a) < x M 0 0 ;6 0 M 0 M 0 C Z OzzOr-C>O<r-zMO—(j)m0r-OMO M M 'n M ;U M M 00 0 0 > -4 M M M -n M M M M r- M M > X M M M o M 0 -4 M C 70 z 0> ic > 0 G) G) 2 G) (1) M M M icM >C C x 0 M 0 > _ z 0 M r- x m 0 M M 0 (n q ;a M 0 G) M o M . M z -4 --I 0 V r, 0 M M r- r- V > -n r- q 0 M M 0 -n 0 r- M 0 M M > -4 M M ic M j C M z X M j C© M > --I M 0 0 M 0 2 M M < > 0 0 C 0 0 0 M 0 — z --i M < > M r- M M 0 r- r- M M M ;U 0 M C z > M 0 > 0 z > > 0 T 0 (D a) tD CO -n m Yr " C) G) ;U M r- Z M (31 M G) -n Cn z N) (A) 0 M C) 'D (1) cc a) C) -n --j 4�6 CD 00 Co ;a (I) t,.) b. IQ -4 0) -n CO -n Z 0 > 0 0 W -n 0 X W -n M 0 Z > 0 > 0 N • • I Thanks tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Loepp, Victoria T (CED) From: McLeod, Austin (CED) Sent: Monday, February 24, 2020 1:15 PM To: Loepp, Victoria T (CED) Subject: Re: Rhea 1 Follow Up Flag: Follow up Flag Status: Flagged Not a problem. Btw, I suppose one of these days I should meet you so I can put a face to the name. Next time I head north I'll make a lap around the "track" and introduce myself to the folks I haven't met yet. Thank you Austin McLeod Petroleum Inspector AOGCC 907-715-0880 cell > On Feb 24, 2020, at 1:10 PM, Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> wrote: > Austin, > Thanx for witnessing the tag/PT. This was an unusual well with a P&A planned post rig. All your comments are noted and appreciated. Sorry for the confusion and the lack of direction with the tag. > Thanx again, > Victoria > Sent from my iPhone >> On Feb 23, 2020, at 9:06 AM, McLeod, Austin (CED) <austin.mcleod@alaska.gov> wrote: >> Morning, thank you for getting back to me soon. Being the bottom plug (reservoir isolating) sure seemed like there was minimal info provided. Contradicting info on their application and ptd. If there are any other P&A plugs or the like that are done on part of the PTD (first I've seen), a simple Cc would be much appreciated. Easy enough to calculate test pressure needed off of ND's, but the co man had no emails from you to his engineer, no idea what to test it to, no idea how long to hold the test so on so on. All these co men and operator reps for misc jobs all tell me the same thing; " We all think you guys are in the loop on our tests/jobs before we even submit for them". Which of course is not the case ... all is well but maybe next time we could avoid the confusion. >> Thank you mam >> -----Original Message----- » From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >> Sent: Saturday, February 22, 2020 1:27 PM >> To: McLeod, Austin (CED) <austin.mcleod@alaska.gov> >> Cc: Regg, James B (CED) <jim.regg@alaska.gov> >> Subject: Re: Rhea 1 >> Austin, >> Yes, the engineer has been in touch with me. They set this plug as a part of the PTD. We asked for a P&A sundry for post rig P&A but did not ask for one for this plug. The tag and pressure test you witnessed sound good. It is approved for them to set the CIBP. >> Please call if you have any other questions. Victoria 907-242-9156. >> Victoria >> Sent from my iPhone »» On Feb 22, 2020, at 12:41 PM, McLeod, Austin (CED) <austin.mcleod@alaska.gov> wrote: >>> Hello and sorry to bug on the weekend. I'm just leaving Doyon 25 after I witnessed a tag on the cement plug from bottom, 7345', up into the 7-5/8". Tagged at 6695'. Shoe is at 7225'. Plenty of overlap. TVD of shoe is 6934'. Pressure tested to a target of 1750psi. >>> There is no approval paperwork or even an approved Sundry. Only thing I saw was that this was supposed to be a post rig P&A. Company man informed me that his Engineer has been in touch with you Victoria about this??? Please call/contact me about this because they will be setting a CIBP later this afternoon ... I tried calling both of you. Thanks >>> Austin McLeod >>> Petroleum Inspector AOGCC >>> 907-715-0880 cell 2 PTD 2ao-002 Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, February 18, 2020 12:28 PM To: Loepp, Victoria T (CED) Subject: Rhea 1, PTD 220-002, Completion with CIBP Attachments: FWK Ice Road Pilot Completion Schematic- Slant w_Plug 2-18-20.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, We are going to run a CIBP on rig after we pump the abandonment plug across the reservoir. Our wells group that will perform the P&A for Rhea requested the rig install a CIBP before moving off the well with the drilling rig to set them up for the P&A and not leave a kill string in the well because it can make the post rig VSP log and P&A work more difficult to perform. Due to the CIBP being run on rig, we would prefer to not wait for the abandonment plug to harden and tag it. We prefer to immediately pull out of hole after pumping the abandonment plug, run the CIBP and tag and pressure test the CIBP for our barrier. Does this require a Sundry for Approval to not tag the abandonment cement plug and instead tag and pressure test the CIBP? Please see updated schematic to reflect the new completion with CIBP. The abandonment cement plug is forecasted to take place on Thursday or Friday and the CIBP is forecasted to be run and set Friday afternoon or evening. Thanks Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Rhea 1, FWK Pilot — Slant Completed with No Kill String Proposed Schematic updated 2/18/20, D25, RKB 39.7 ft C30 Sand Top 2480' MD / 2480' TVD i i i i 1 i Qannik Sand Top f 4079' MD / 4063' TVD i R ii Qannik Sand Base 4182' MD / 4134' TVD HRZ Top 6577' MD / 6333' TVD 20" Conductor to 120' 11.2 ppg Cement TOC — 2000' MD / 2000' TVD 13.5" Open Hole with (Will confirm with CBL) 10.75" 45.5 ppf L-80 TXP 2,352' MD / 2,352' TVD Baker CIBP 4668' MD / —4582' TVD HES Stage Cementer 7 6579' MD / 6 TVD 15.8 ppg Cement TOC at Stage Cementer Kalubik 9-7/8" X 11" Underreamed Openhole with Top Set Casing ' 7 5/8" 29.7 ppf L-80 TXP W. P14u 7189' MD / 6894' TVD @ 22.7° Kuparuk C Sand Top —7229' MD / —6931' TVD LCU --7239' MD / —6942' TVD j t:. 3 j 6.5" Open Hole TD Nechelik Top V —7339' MD 7450' MD "` Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, February 18, 2020 9:37 AM To: Loepp, Victoria T (CED) Subject: FW: Rhea 1, PTD 220-002, Intermediate Casing Test and FIT Results Attachments: Rhea -1 Intermediate casing - FIT 2-18-20.pdf, Rhea -1 Intermediate casing - FIT.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, We performed the Rhea 1 Intermediate FIT this morning. Test went well with an FIT EMW of 13.5 ppg. Please see attached test data and charts. Thanks, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com 1 J O N O N CO N m E U) X N X t LL C .0 (B U N (Q N E L au N G- O m 06 N H LL vi 1- O J W >Y> ca O L N .Q g sz O En QU 06 C L O C 0 U Z cn OO Ln•Lntn LL7t17 000 O 0000000000 _ O O ICD O ti r r ti r• e r r- r r` r` r- r- tl- r- r• U N �+ C _ C r .- r c- r r r .- P r .- - d Em ~ OL')00 OOOO OOO O 0000000000 p -0 L co C ONLOO U') CD LOO IqOLn -q- -- O Lo LnOU.)OQ-)O in LnOLnO > m 000 .- NNM co OOr r00000(D E m G1 3 d W?C y DL() 000Ln CD CD pVo .N r• L!') 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O) N 0O 'L N Ln o 0 MOM 3 co !� w en N ~ O 1� cD Z rn G G! r.+ O) a- > CO v Cl) N N A N O Nl F- 0 U K L: y O N _0 d cn C) a N SLI O N y o ~ H O iLL v- H o ff c6 , O 0 2 c o E zCL m+ o EN U U) W J o 0 0 0 0 0 N 0 O 0 N V ii rr ? (7 N N z _ m 3bnss3bd E O L O O o x w U O N O N CO N m E U) X N X t LL C .0 (B U N (Q N E L au N G- O m 06 N H LL vi 1- O J W >Y> ca O L N .Q g sz O En QU 06 C L O C 0 U Z cn Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, February 17, 2020 7:50 AM To: Loepp, Victoria T (CED) Subject: Rhea 1, PTD 220-002, Intermediate Casing Cement Job Report Attachments: RHEA 1 Stage 1 Int Treatment Report.pdf, RHEA 1 2 Stage Int Treatment Report.pdf; Reporting - Cement Detail Report - RHEA 1 - 2020-02-17 07.47.44.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria. We performed the Intermediate cement job on Rhea 1. Both the intermediate first and second stage cement jobs went as planned with good pump pressures and no losses. TOC is estimated to be —2000' MD. We are currently in hole with our Production section drilling BHA and should be drilling out our shoe track in a few hours. Please find cement pumping reports attached. Thanks, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Cement Detail Report RHEA 1 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/28/2020 00:00 Cement Details Description Intermediate Casing Cement Cementing Start Date 2/15/2020 18:00 Cementing End Date 2/15/2020 16:33 Wellbore Name RHEA 1 Comment Cold Mitigation-All fresh water for mixing was delivered warm from the rig tank Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Isolate 7 5/8" up to stage collar at 6578'MD Top Depth (ftKB) 6,578.0 Bottom Depth (ftKB) 7,189.0 Full Return? No Vol Cement R' 0.0 Top Plug? Yes Bottom Plug? Yes Q Pump Init (bbl/min) 4 Q Pump Final (bbl/mh 4 iQ Pump Avg (bbl/min 4 P Pump Final (psi) 33.0 P Plug Bump (psi) 1,000.0 Recip? 1 Yes15.00 Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 2,000.0 Est Btm (ftKB) 5,118.0 Amount (sacks) Class Volume G Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sack) Free Water I%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration I Conc Unit label Stage # 2 Description Intermediate Casing Cement Objective Isolate from stage tool to cover Qannik to 3000ft Top Depth (ftKB) 2,000,0 Bottom Depth (ftKB) 6,578.0 1 Full Return? No Vol Cement R 0.0 'Top Plug? Yes Bottom Plug? No Q Pump Init (bbl/min) 6 Q Pump Final (bbl/mi 5 Q Pump Avg (bbl/min 5 P Pump 104.0 Final (psi) P Plug Bump (psi) 909.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 2,000.0 Est Btm (ftKB) 5,118.0 Amount (sacks) 543 Class Volume G 178.1 Pumped (bbl) Yield (ft'/sack) 1.84 Mix H2O Ratio (gal/sack) 6.45 Free Water I%) Density (Ib/gal) 11.20 Plastic Viscosity (cP) 120.3 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 5,118.0 Est Btm (ftKB) 6,589.0 Amount (sacks) 254 Class Volume G 90.0 Pumped (bbl) Yield (Wisack) 1.99 Mix H2O Ratio (gal/sack) 10.96 Free Water (%) Density (Iblgal) 13.00 Plastic Viscosity (cP) 48.5 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/17/2020 Schlumbugep Cementing ]oL iteport CemCATv1.6 Well RHEA 1 - Rate Client ConocoPhillips Field Alpine 13:42:16 SIR No. Engineer Lance Kalivas lob Type Stage 2 Int Country United States Job Date 02-15-2020 Time pressure - Rate Density WHP Messages 13:42:16 PISM Done Blow air down hardline 13:57:00 Fluid Pack Hard Line Low Pressure Test Trips Tripped High Pressure Test High Pressuer Test Good 14:12:00 Reset Total, Vol = 5.08 bbl Reset Total, Vol = 0.00 bbl Start batching mudpush MudPush scaled 10.8 heavy 14:27:00 End Mud Push Reset Total, Vol = 59.98 bbl Start batching Lead 14:42:00 14:57:00 15:12:00 End Lead cement Batch up Tail cement Reset Total, Vol = 190.27 bbl 15:27:00 15:42:00 End Tall Cement Drop closing Plug Reset Total, Vol = 90.05 bbl Reset Total, Vol = 0.00 bbl Fresh water behind Swap to rig to displace Blow air down nhard line 15:57:00 16:12:00 16:27:00 Bumped the plug 16:42:00 No Flow 16:58:36 Reset Total, Vol = 49.73 bbl hh:mm:ss o.00 2000 9000 WOO 9000 loom OW 2.0 4.0 6.0 BA 10.0 1.0 SOA Is.o 20A 25.0 OW IWO 2000 3000 4000 WOO oznmzo a:�.�a _ PSI —-- B/M - LB/G PSI uc/lD/cucu li.uc. is Sc hiumbepUep Cementing Service Report Page 1 of 5 Customer ConocoPhillips lob Number Well RHEA i Location (legal) Schlumberger Location Prudhoe Other lob Start Feb/15/2020 Field Alpine Formation Name/Type Deviation deg Bit Size 11.0 in Well MD 6578.0 k Well TVD 6578.0 k County State/Province Alaska BHPBLAST psi 154 degF BHCT 95 degF Pore Press. Gradient Ib/gal Well Master API/DWI Rig Name Doyon 25 Drilled For Oil Service Via Land Casing/Liner Depth, ft Size, in Weight, Ib/ft Grade Thread Offshore Zone Well Class New Well Type Exploration 6578.0 7.6 29.7 0.0 0.0 0.0 Drilling Fluid Type Max. Density Ib/gal Plastic Viscosity CP Tubing/ Drill Pipe T/D Depth, ft Size, in Weight, lb/ft Grade Thread Service Line Cementing lob Type Stage 2 Int Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection 2" 1502 Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval Service Instructions ft ft ft ft ft Diameter in ft ft Treat Down Casing Displacement Packer Type 301.9 bbl Packer Depth k Tubing Vol. bbl Casing Vol. Annular Vol. 301.9 bbl bbl Openhole Vol. bbl Casing/Tubing Secured 1 -Hole Vol. Circulated prior to Cement Casing Tools Squeeze lob Lift Pressure psi Shoe Type Squeeze Type Pipe Rotated EIPipe Reciprocated Fj Shoe Depth 6578.0 ft Tool Type No. Centralizers Top Plugs 1 Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Feb/15/2020 Arrived on Location Feb/15/2020 Leave Location Feb/15/2020 Collar Type Tail Pipe Depth ft Collar Depth ft Sq.. Total Vol. bbl Date Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LS/G WHP Stage PSI Volume BBL Total Message Vol BBL 02/15/2020 13:42:16 72 0.0 7.38 586 0.0 0.0 Started Acquisition 02/15/2020 13:42:26 68 0.0 7.38 575 0.0 0.0 PJSM Done 02/15/2020 13:42:46 12 0.0 7.38 593 0.0 0.0 Blow air down hardline 02/15/2020 13:43:31 25 0.0 7.38 584 0.0 0.0 02/15/2020 13:44:46 48 0.0 7.38 595 0.0 0.0 02/15/2020 13:46:01 80 0.0 7.39 587 0.0 0.0 02/15/2020 13:47:16 29 0.0 7.38 658 0.0 0.0 02/15/2020 13:48:31 26 0.0 7.38 660 0.0 0.0 02/15/2020 13:49:46 25 0.0 7.38 661 0.0 0.0 02/15/2020 13:51:01 i8 0.0 7.38 651 0.0 0.0 02/15/2020 13:52:16 23 0.0 7.38 663 0.0 0.0 02/15/2020 13:53:31 19 0.0 7.38 670 0.0 0.0 02/15/2020 13:54:46 23 0.0 7.38 675 0.0 0.0 02/15/2020 13:56:01 19 0.0 7.38 97 0.0 0.0 02/15/2020 13:57:16 16 0.0 7.38 97 0.0 0.0 02/15/2020 13:58:31 17 0.0 7.38 97 0.0 0.0 02/15/2020 13:59:46 76 0.0 7.38 100 0.0 0.0 Fluid Padc Hard Line 02/15/2020 14:01:01 139 1.9 7.38 145 1.2 1.2 02/15/2020 14:02:16 338 2.0 7.39 335 3.6 3.6 02/15/2020 14:03:31 145 0.0 7.38 200 5.0 5.0 02/15/2020 14:03:55 143 0.0 1 7.38 1 200 5.0 1 5.0 1 Low Pressure Test Page 1 of 5 Well RHEA 1 Field Alpine Job Start Feb/15/2020 Customer Conoco Phillips )ob Number Date Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LB/6 WHIR PSI Stage Total Volume Vol BBL BBL Message 02/15/2020 14:04:30 1353 0.0 7.38 1387 5.0 5.0 High Pressure Test 02/15/2020 14:04:46 1348 0.1 7.39 1409 5.1 5.1 02/15/2020 14:06:01 3980 0.0 7.38 3991 5.1 5.1 02/15/2020 14:06:39 3965 0.0 7.38 3978 5.1 S.1 High PressuerTest Good 02/15/2020 14:07:16 66 0.0 7.37 107 5.1 5.1 02/15/2020 14:07:47 138 0.0 7.94 147 5.1 5.1 Reset Total, Vol = 5.08 bbl 02/15/2020 14:08:04 142 0.0 8.30 149 0.0 5.1 Start batching mudpush 02/15/2020 14:08:31 141 0.0 8.45 151 0.0 5.1 02/15/2020 14:09:46 142 0.0 9.48 151 1 0.0 5.1 02/15/2020 14:11:01 110 0.0 10.49 149 0.0 5.1 02/15/2020 14:12:16 115 0.0 10.83 150 0.0 5.1 02/15/2020 14:12:59 112 0.0 10.82 155 0.0 5.1 Mud Push scaled 10.8 heavy 02/15/2020 14:13:31 110 0.0 10.81 167 0.0 5.1 02/15/2020 14:14:46 446 3.2 10.96 406 2.9 8.0 02/15/2020 14:16:01 456 1 3.2 10.98 403 6.9 12.0 02/15/2020 14:17:16 430 3.0 10.87 384 10.7 15.8 02/15/2020 14:18:31 425 2.9 10.79 382 14.4 19.5 02/15/2020 14:19:46 460 3.5 10.72 405 18.4 23.5 02/15/2020 14:21:01 454 3.5 10.91 395 22.8 27.9 02/15/2020 14:22:16 479 3.5 10.79 406 27.2 32.3 02/15/2020 14:23:31 494 3.6 10.75 415 31.6 36.7 02/15/2020 14:24:46 485 3.6 10.81 405 36.2 41.2 02/15/2020 14:26:01 469 3.6 10.92 399 40.7 45.8 02/15/2020 14:27:16 445 3.3 10.71 387 45.0 50.0 02/15/2020 14:28:31 453 3.3 10.83 390 49.1 54.1 02/15/2020 14:29:46 436 3.3 10.77 391 53.1 58.2 02/15/2020 14:31:01 422 3.3 10.96 382 57.2 62.3 02/15/2020 14:32:00 166 0.3 10.77 213 59.9 65.0 End MudPush 02/15/2020 14:32:10 154 0.0 10.75 199 60.0 1 65.1 Reset Total, Vol = 59.98 bbl 02/15/2020 14:32:16 150 0.0 10.75 197 0.0 65.1 02/15/2020 14:33:31 125 0.0 10.34 179 0.0 65.1 02/15/2020 14:34:46 122 0.0 7.91 175 0.0 65.1 02/15/2020 14:35:45 118 0.0 8.42 174 0.0 65.1 Start batching Lead 02/15/2020 14:36:01 119 0.0 8.45 174 0.0 65.1 02/15/2020 14:37:16 118 0.0 10.56 174 0.0 65.1 02/15/2020 14:38:31 122 0.0 10.98 171 0.0 65.1 02/15/2020 14:39:46 592 3.7 10.96 454 1.2 66.3 02/15/2020 1 14:41:01 865 5.0 10.85 551 6.2 71.3 02/15/2020 14:42:16 897 5.1 11.10 551 12.6 77.7 02/15/2020 14:43:31 983 5.4 11.14 596 19.1 84.2 02/15/2020 14:44:46 1038 5.5 11.10 604 25.9 91.0 02/15/2020 14:46:01 1039 S.S 11.09 591 32.8 97.8 02/15/2020 14:47:16 978 5.4 11.07 588 39.6 104.6 02/15/2020 14:48:31 1004 5.3 11.11 574 46.3 111.4 02/15/2020 14:49:46 990 5.3 11.12 577 52.9 118.0 02/15/2020 14:51:01 984 5.3 11.09 562 59.5 124.6 02/15/2020 14:52:16 1004 5.3 11.14 563 66.2 131.2 02/15/2020 14:53:31 1076 5.3 11.16 581 72.8 137.8 02/15/2020 14:54:46 1054 5.3 11.18 577 79.4 144.5 02/15/2020 14:56:01 1009 5.4 11.14 561 86.1 151.2 02/15/2020 14:57:16 1042 5.4 11.19 567 92.8 157.9 02/15/2020 14:58:31 1002 5.4 11.15 561 99.5 164.6 02/15/2020 14:59:46 968 5.4 11.14 541 106.2 171.3 02/15/2020 15:01:01 934 5.2 1 11.19 524 112.9 177.9 Page 2 of 5 Well RHEA 1 Field Alpine Job Start Feb/15/2020 Customer ConccoPhillips Job Number Date Time 24-br clock Treating Pressure PSI Flow Rate B/M Density 1-8/6 WNP PSI Stage Total Volume Vol 881. BBL Message 02/15/2020 15:03:31 925 5.2 11.14 516 125.9 190.9 02/15/2020 1 15:04:46 967 5.3 11.08 536 132.4 197.5 02/15/2020 15:06:01 988 5.5 11.11 542 139.2 204.2 02/15/2020 15:07:16 954 5.5 11.10 535 146.0 211.1 02/15/2020 15:08:31 955 5.5 11.16 533 152.9 218.0 02/15/2020 15:09:46 1000 5.5 11.12 551 159.8 224.8 02/15/2020 15:11:01 991 5.5 11.13 541 166.7 231.7 02/15/2020 15:12:16 978 5.5 11.09 529 173.5 238.6 02/15/2020 15:13:28 106 1.5 11.12 176 178.1 243.1 End Lead cement 02/15/2020 15:13:31 85 0.0 11.08 143 178.1 243.1 02/15/2020 15:14:46 47 0.0 10.19 112 178.1 243.1 02/15/2020 15:16:01 46 0.0 9.97 108 178.1 243.1 02/15/2020 15:16:34 45 0.0 8.67 110 178.1 243.1 Batch up Tail cement 02/15/2020 15:17:16 46 0.0 10.31 110 178.1 243.1 02/15/2020 15:18:31 46 0.0 13.44 108 178.1 243.1 02/15/2020 15:19:46 50 0.0 1 13.04 109 178.1 243.1 02/15/2020 15:21:01 569 3.8 13.31 356 182.8 247.9 02/15/2020 15:22:16 715 4.7 13.08 411 187.9 253.0 02/15/2020 15:22:43 862 5.3 13.05 465 190.3 255.3 Reset Total, Vol = 190.27 bbi 02/15/2020 15:23:31 952 5.5 13.02 495 4.3 259.7 02/15/2020 15:24:46 932 5.5 13.06 465 11.2 266.5 02/15/2020 15:26:01 808 5.2 13.01 409 18.0 273.3 02/15/2020 15:27:16 745 5.1 13.04 384 24.5 279.8 02/15/2020 15:28:31 674 4.7 13.11 353 30.5 285.8 02/15/2020 15:29:46 545 4.3 13.04 290 35.9 291.3 02/15/2020 15:31:01 604 4.6 12.99 297 41.6 296.9 02/15/2020 15:32:16 622 4.8 13.09 294 47.4 302.7 02/15/2020 15:33:31 576 4.7 13.06 272 53.3 308.7 02/15/2020 15:34:46 576 4.8 13.00 269 59.3 314.6 02/15/2020 15:36:01 614 4.8 13.04 283 65.2 320.6 02/15/2020 15:37:16 614 4.8 13.11 287 71.2 326.5 02/15/2020 15:38:31 589 4.7 13.12 271 77.1 332.5 02/15/2020 15:39:46 549 4.6 13.09 248 83.0 338.3 02/15/2020 15:41:01 394 3.9 13.12 185 88.6 344.0 02/15/2020 15:41:49 49 0.0 13.20 104 90.0 345.4 End Tail Cement 02/15/2020 15:42:07 50 0.0 13.17 101 90.0 345.4 Drop dosing Plug 02/15/2020 15:42:16 53 0.0 13.16 102 90.0 345.4 02/15/2020 15:43:31 66 0.0 13.13 100 90.0 345.4 02/15/2020 15:43:56 95 0.0 13.13 102 90.0 345.4 Reset Total, Vol = 90.05 bbl 02/15/2020 15:44:46 74 0.0 13.13 102 0.0 345.4 02/15/2020 15:46:01 51 0.0 13.14 102 0.0 345.4 02/15/2020 15:47:00 49 0.0 13.14 98 0.0 345.4 Fresh water behind 02/15/2020 15:47:16 466 4.5 13.20 196 0.5 345.9 02/15/2020 15:48:31 507 6.0 13.22 180 7.9 353.2 02/15/2020 15:49:46 664 5.9 12.03 365 15.3 360.7 02/15/2020 15:50:53 73 0.0 11.93 105 20.0 365.3 Swap to rig to displace 02/15/2020 15:51:01 59 0.0 11.92 97 20.0 365.3 02/15/2020 15:52:16 40 0.0 11.90 92 20.0 365.3 02/15/2020 15:53:31 41 0.0 11.88 99 20.0 365.3 02/15/2020 15:54:04 40 0.0 11.88 128 20.0 365.3 Blow air down nhard line 02/15/2020 15:54:46 44 0.0 11.87 434 20.0 365.3 02/15/2020 15:56:01 51 0.0 11.87 560 20.0 365.3 02/15/2020 15:57:16 105 0.0 11.87 567 20.0 365.3 02/15/2020 15:58:31 23 0.0 11.86 571 20.0 365.3 Page 3 of 5 Well RHEA 1 Field Alpine Job Start Feb/15/2020 Customer ConocoPhiilips Job Number Date Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LS/G WHP PSI Stage Total Message Volume Vol BBL BBL 02/15/2020 16:01:01 23 0.0 12.64 605 20.0 365.3 02/15/2020 16:02:16 19 0.0 11.53 617 20.0 365.3 02/15/2020 16:03:31 19 0.0 9.09 670 20.0 365.3 02/15/2020 16:04:46 25 0.0 11.40 695 20.0 365.3 02/15/2020 16:06:01 27 0.0 11.79 725 20.0 365.3 02/15/2020 16:07:16 20 0.0 11.82 774 20.0 365.3 02/15/2020 16:08:31 21 0.0 12.11 810 20.0 365.3 02/15/2020 16:09:46 20 0.0 11.94 849 20.0 365.3 02/15/2020 16:11:01 20 0.0 11.94 878 20.0 365.3 02/15/2020 16:12:16 24 0.0 11.93 898 20.0 365.3 02/15/2020 16:13:31 26 0.0 11.25 944 20.0 365.3 02/15/2020 16:14:46 26 0.0 10.27 958 20.0 365.3 02/15/2020 16:16:01 25 0.0A8.58 365.3 02/15/2020 16:17:16 26 0.0 365.3 02/15/2020 16:18:31 27 0.0 V1.92201.00 365.3 02/15/2020 16:19:46 29 0.0 365.3 02/15/2020 16:21:01 27 0.0 365.3 02/15/2020 16:22:16 27 0.0 365.3 02/15/2020 16:23:31 28 0.0 8.50 1118 20.0 365.3 02/15/2020 16:24:46 26 0.0 6.49 1149 20.0 365.3 02/15/2020 16:26:01 29 0.0 8.33 1185 20.0 365.3 02/15/2020 16:27:16 27 0.0 8.32 1220 20.0 365.3 02/15/2020 16:28:31 27 0.0 8.32 1261 20.0 365.3 02/15/2020 16:29:46 26 0.0 8.32 1280 20.0 365.3 02/15/2020 16:31:01 27 0.0 8.32 1176 20.0 365.3 02/15/2020 16:32:16 26 0.0 8.32 1178 20.0 365.3 02/15/2020 16:33:31 27 0.0 8.34 894 20.0 365.4 02/15/2020 16:34:46 33 0.0 7.71 895 20.0 365.4 02/15/2020 16:36:01 29 0.4 8.31 896 20.2 365.6 02/15/2020 16:37:16 30 0.4 8.31 909 20.6 366.0 02/15/2020 16:38:13 28 0.3 8.26 1538 20.9 366.2 Bumped the plug 02/15/2020 16:38:31 24 0.3 8.30 1582 21.0 366.3 02/15/2020 16:39:46 29 0.0 8.10 1560 21.3 366.7 02/15/2020 16:41:01 32 0.8 7.30 2076 21.4 366.8 02/15/2020 16:42:16 104 4.0 8.04 2062 24.7 370.0 02/15/2020 16:43:31 135 3.9 8.01 720 29.6 375.0 02/15/2020 16:44:46 75 2.8 7.40 85 32.5 377.9 02/15/2020 16:46:01 48 0.0 7.26 86 35.1 380.5 02/15/2020 16:47:16 28 0.0 7.44 86 35.1 380.5 02/15/2020 16:48:31 85 3.0 8.02 85 38.1 383.5 02/15/2020 16:49:46 127 3.0 8.06 125 41.9 387.2 02/15/2020 16:51:01 113 5.6 8.09 114 47.1 392.4 02/15/2020 16:52:16 32 0.1 7.45 110 49.7 395.1 02/15/2020 16:53:31 24 0.0 6.93 86 49.7 395.1 02/15/2020 16:54:46 21 0.0 6.88 88 49.7 395.1 02/15/2020 16:56:01 23 0.0 6.85 -3667 49.7 395.1 02/15/2020 16:57:16 19 0.0 6.81 -3665 49.7 395.1 02/15/2020 16:58:27 18 0.0 6.79 -3670 49.7 395.1 No Flow 02/15/2020 16:58:31 20 0.0 6.79 -3666 49.7 395.1 Page 4 of 5 yyeg Field Job Start Customer Job Number RHEA 1 Alpine Feb/15/2020 Conoco Phillips Mud Post Job Summary Page 5 of 5 Average Pump Rates, bbi/min Volume of Fluid Injected, bbl Slurry 4.1 N2 Mud Maximum Rate 6.0 Total Slurry 268.0 Mud 0.0 Spacer 60.0 N2 Treating Pressure Summary, psi Breakdown Fluid Maximum 4021 Final 23 Average 369 Bump Plug to Breakdown Type Volume bbl Density Ib/gal Avg. N2 Percent % Designed Slurry Volume 268.0 bbl Displacement 301.9 bbl Mix Water Temp de IF Cement Circulated to Surface? El volume bbl Washed Thru Perp El To ft Customer or Authorized Rob Reinhardt Representative Schlumberger Supervisor Lance Kalivas Circulation Lost El Job Completed l Page 5 of 5 Schlumberger Cementing JoL _teport CemCATv1.6 Well RHEA 1 Rate Client Conocolphillips Field Alpine 07:15:42 SIR No. Engineer Lance Kalivas Job Type Stage 1 Intermediate Country United States Job Date 02-15-2020 Time Pressure Rate Density -WHP Messages 07:15:42 PISM 07:31:00 07:46:00 08:01:00 Front head rate chech Rate Check good Reset Total, Vol = 3.12 bbl Rear head Rate Check Rate Check good Blow Air Down Hard Line D8:16:OD Reset Total, Vol = 3.09 bbl Fluid pack hard line Low Pressure Test Trips Trips tripped High Pressure Test Pressure Test Good 08:31:00 Start Batching Mud Push Reset Total, Vol = 4.25 bbl MudPush Scaled 13.2 08:46:00 Shut down drop bottom plug Reset Total, Vol = 60.04 bbl 09:01:00 Start bayching cement Cement Scaled 15.7 09:16:00 Shut down drop top plug Reset Total, Vol = 51.77 bbl Reset Total, Vol = 0.00 bbl Fresh water behind Shut down swap to rig to displace 09:31:00 Reset Total, Vol = 20.06 bbl Reset Total, Vol = 0.00 bbl Blow air down hard line 09:46:00 10:01:00 Bumped the plug 10:16:00 Check Floats 10:21:57 Floats Held hh:mm:ss ono mao soon s000 soon 10000 a.00 2.0 4.0 6.0 8.0 0.0 5.0 10.0 15.0 20.0 25.0 0.00 1000 moa 3000 4000 WN av,vo,a:n:n PSI -- - B/M LB/G PSI 02/15/2020 17:23:22 Schlumberger Cementing Service Report Page 1 of 5 [Customer ConocoPhillips lob Number Well RHEA 1 Location (legal) Schlumberger Location PRUDHOE OTHER lob Start Feb/15/2020 Field Alpine Formation Name/Type Deviation deg Bit Size 11.0 in Well MD 7189.0 ft Well TVD 6616.0 ft County State/Province Alaska BNPBNST psi 141 degF BHCi 90 degF Pore Press. Gradient Ib/gal Well Master API/UWI Rig Name Doyon 25 Drilled For Oil Service Via Land Casing/Liner Depth, ft Size, in Weight, Ib/ft Grade Thread Offshore Zone Well Gass New Well Type Exploration 7189.0 7.6 29.7 0.0 0.0 0.0 Drilling Fluid Type Max. Density Ib/gal Plastic Viscosity cP Tubing/Drill Pipe T/D Depth, it Size, in Weight, lb/ft Grade Thread Service Line Cementing lob Type Stage 1 Intermediate Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection 2 " 1502 Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval Service Instructions ft ft ft ft ft Diameter in ft ft Treat Down Casing Displacement Packer Type 324.0 bbi Packer Depth ft Tubing Vol. bbl Casing Vol. Annular Vol. 330.0 bbl bbl Openhole Vol. bbl Casing/Tubing Secured EIT1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze lob Lift Pressure psi Shoe Type Float Squeeze Type Pipe Rotated 0 Pipe Reciprocated Shoe Depth 7189.0 ft Tool Type No. Centralizers Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tall Pipe Size in Job Scheduled For Feb/15/2020 Arrived on Location Feb/15/2020 Leave Location Feb/15/2020 Collar Type Float Tail Pipe Depth ft Collar Depth 7060.0 ft Sqz. Total Vol. bbl Date Time 24 -hr clock Treating Flow Pressure Rate PSI BIM Density LB/G WHP Stage PSI Volume BBL Total Message Vol BBL 02/15/2020 07:15:42 43 0.0 6.64 158 0.0 0.0 Started Acquisition 02/15/2020 07:15:50 46 0.0 6.63 160 0.0 0.0 PISM 02/15/2020 07:16:57 38 0.0 6.62 128 0.0 0.0 02/15/2020 07:18:12 35 0.0 6.61 120 0.0 0.0 02/15/2020 07:19:27 45 0.0 6.60 113 0.0 0.0 02/15/2020 07:20:42 54 0.0 6.59 118 0.0 0.0 02/15/2020 07:21:57 47 0.0 6.59 127 0.0 0.0 02/15/2020 07:23:12 49 0.0 6.58 288 0.0 0.0 02/15/2020 07:24:27 45 0.0 6.58 342 0.0 0.0 02/15/2020 07:25:42 46 0.0 6.57 337 0.0 0.0 02/15/2020 07:26:57 46 0.0 6.56 394 0.0 0.0 02/15/2020 07:28:12 75 0.0 6.56 364 0.0 0.0 02/15/2020 07:29:27 72 0.0 6.55 397 0.0 0.0 02/15/2020 07:30:42 65 0.0 6.55 411 0.0 0.0 02/15/2020 07:31:57 62 0.0 6.55 464 0.0 0.0 02/15/2020 07:33:12 69 0.0 6.54 470 0.0 0.0 02/15/2020 07:34:27 65 0.0 6.54 451 0.0 0.0 02/15/2020 07:35:42 65 0.0 6.53 456 0.0 0.0 02/15/2020 07:36:57 63 0.0 6.53 529 0.0 0.0 02/15/2020 07:38:12 59 0.0 6.53 521 0.0 0.0 02/15/2020 07:39:27 61 0.0 6.53 545 0.0 0.0 Page 1 of 5 WellJob RHEA 1 Field Alpine Start Feb/15/2020 Customer ConocoPhillips Job Number Date Time 24 -hr Mock Treating Pressure PSI Flow Rate B/M Density LB/6 WHP PSI Stage Total Volume Vol BBL BBL Message 02/15/2020 07:41:57 63 0.0 6.52 574 0.0 0.0 02/15/2020 1 07:43:12 56 0.0 6.52 557 0.0 0.0 02/15/2020 07:44:27 55 0.0 6.52 542 0.0 0.0 02/15/2020 07:45:42 53 0.0 6.52 512 0.0 0.0 02/15/2020 07:46:57 59 0.0 6.52 509 0.0 0.0 02/15/2020 07:48:12 51 0.0 6.52 513 0.0 0.0 02/15/2020 07:49:27 52 0.0 6.51 504 0.0 0.0 02/15/2020 07:50:42 1 53 0.0 6.51 510 0.0 0.0 02/15/2020 07:51:57 57 0.0 6.51 500 0.0 0.0 02/15/2020 07:53:12 59 0.0 6.51 489 0.0 0.0 02/15/2020 07:54:27 57 0.0 6.51 482 0.0 0.0 02/15/2020 07:55:42 58 0.0 6.51 491 0.0 0.0 02/15/2020 07:56:57 42 0.0 6.51 498 0.0 0.0 02/15/2020 07:58:12 53 0.0 6.51 476 0.0 0.0 02/15/2020 07:59:27 58 0.0 6.51 472 0.0 0.0 02/15/2020 08:00:42 54 0.0 6.50 492 0.0 0.0 02/15/2020 08:01:57 52 0.0 6.50 502 0.0 0.0 02/15/2020 08:03:12 55 0.0 6.50 500 0.0 0.0 02/15/2020 08:03:49 73 2.3 6.48 480 0.0 0.0 Front head rate chech 02/15/2020 08:04:27 157 3.0 6.43 475 1.8 1.8 02/15/2020 08:05:36 117 0.0 6.37 479 3.1 3.1 Rate Check good 02/15/2020 08:05:42 144 0.0 6.36 474 3.1 3.1 Reset Total, Vol = 3.12 bbl 02/15/2020 08:06:10 156 3.0 6.33 482 0.8 3.9 Rear head Rate Check 02/15/2020 08:06:57 149 0.0 6.32 504 3.1 6.2 02/15/2020 08:07:12 104 0.0 6.53 509 3.1 6.2 Rate Check good 02/15/2020 08:08:12 176 0.0 7.59 510 3.1 6.2 02/15/2020 08:09:27 97 0.0 6.53 483 3.1 6.2 02/15/2020 1 08:10:42 84 0.0 6.48 478 3.1 6.2 02/15/2020 08:11:11 81 0.0 6.47 482 3.1 6.2 Blow Air Down Hard Line 02/15/2020 08:11:57 66 0.0 6.46 484 3.1 6.2 02/15/2020 08:13:12 89 0.0 6.48 468 3.1 6.2 02/15/2020 08:14:27 74 0.0 6.46 464 3.1 6.2 02/15/2020 1 08:15:42 44 0.0 6.44 130 3.1 6.2 02/15/2020 08:15:54 49 0.0 6.44 128 3.1 6.2 Reset Total, Vol = 3.09 bbl 02/15/2020 08:16:57 47 0.0 6.43 5 0.0 0.0 02/15/2020 08:17:51 51 0.0 6.48 0 1 0.0 0.0 Fluid pack hardline 02/15/2020 08:18:12 51 0.1 6.94 1 0.0 0.0 02/15/2020 08:19:27 272 1.6 7.12 178 1.3 1.3 02/15/2020 08:20:42 261 1.7 7.12 163 3.3 3.3 02/15/2020 08:21:57 134 0.0 6.41 71 4.2 4.2 02/15/2020 08:23:12 121 0.0 6.40 56 4.2 4.2 02/15/2020 08:23:31 126 0.0 6.39 54 4.2 4.2 Low Pressure Test 02/15/2020 08:23:59 1080 0.3 6.96 1020 4.2 4.2 Trips Trips tripped 02/15/2020 08:24:10 1361 0.0 6.93 1264 4.2 4.2 High Pressure Test 02/15/2020 08:24:27 2921 0.1 6.93 2826 4.2 4.2 02/15/2020 08:25:42 4091 0.0 6.40 3975 4.2 4.2 02/15/2020 08:26:41 3628 0.0 6.39 3512 4.2 4.2 Pressure Test Good 02/15/2020 08:26:57 220 0.0 6.38 169 4.2 4.2 02/15/2020 08:27:46 131 0.0 7.85 33 4.2 4.2 Start Batching MudPush 02/15/2020 08:28:12 136 0.0 8.30 34 4.2 4.2 02/15/2020 08:28:24 130 0.0 9.02 36 4.2 4.2 Reset Total, Vol = 4.25 bbl 02/15/2020 08:29:27 132 0.0 11.62 32 0.0 4.2 02/15/2020 08:30:42 147 0.0 13.25 33 0.0 4.2 02/15/2020 08:31:26 142 0.0 13.21 34 0.0 4.2 MucIPush Soled 13.2 Page 2 of 5 WellField RHEA 1 Field" Alpine Start Feb/15/2020 Customer ConocoPhillips Sob Number onto Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LB/B WHIP PSI Stage Total Volume Vol BBL BBL Message 02/15/2020 08:33:12 143 0.0 13.21 0.0 4.2 02/15/2020 08:34:27 170 0.9 13.20 0.1 4.4 02/15/2020 08:35:42 393 3.0 13.05 ]209 3.4 7.7 02/15/2020 08:36:57 444 3.5 13.01 7.3 11.5 02/15/2020 08:38:12 438 3.5 13.00 198 11.6 15.9 02/15/2020 08:39:27 446 3.4 12.99 211 1 16.1 20.3 02/15/2020 08:40:42 404 3.2 12.98 192 20.2 24.4 02/15/2020 08:41:57 357 3.1 13.00 158 24.2 28.4 02/15/2020 08:43:12 342 3.1 12.85 138 28.1 32.3 02/15/2020 08:44:27 342 3.2 12.97 140 32.0 36.2 02/15/2020 08:45:42 358 3.2 13.04 160 35.9 40.2 02/15/2020 08:46:57 333 3.2 12.77 144 39.9 44.1 02/15/2020 08:48:12 224 2.4 12.92 96 43.4 47.7 02/15/2020 08:49:27 85 0.0 13.44 36 45.3 49.6 02/15/2020 08:50:42 129 0.0 13.26 53 45.3 49.6 02/15/2020 08:51:57 160 1.6 13.62 75 45.9 50.1 02/15/2020 08:53:12 283 3.1 13.14 116 49.6 53.8 02/15/2020 08:54:27 261 3.1 12.98 98 53.4 57.6 02/15/2020 08:55:42 241 3.1 12.47 87 57.2 61.5 02/15/2020 08:56:54 91 1.1 12.49 14 60.0 64.2 Shut down drop bottom plug 02/15/2020 08:56:57 60 0.8 12.47 13 60.0 64.3 02/15/2020 08:56:59 59 0.2 12.43 12 60.0 64.3 Reset Total, Vol = 60.04 bbl 02/15/2020 08:58:12 112 0.0 12.48 14 0.0 64.3 02/15/2020 08:59:27 118 0.0 8.92 15 0.0 64.3 02/15/2020 09:00:42 124 0.0 8.48 18 0.0 64.3 02/15/2020 1 09:01:54 108 0.0 8.49 21 0.0 64.3 Start bayching cement 02/15/2020 09:01:57 103 0.0 8.49 19 0.0 64.3 02/15/2020 09:03:12 159 1 0.0 15.60 22 0.0 64.3 02/15/2020 09:04:27 158 0.0 15.70 27 0.0 64.3 02/15/2020 09:05:21 159 0.0 15.73 28 0.0 64.3 Cement Scaled 15.7 02/15/2020 09:05:42 139 1.7 15.73 34 0.1 64.4 02/15/2020 09:06:57 511 3.7 15.85 173 4.7 69.0 02/15/2020 09:08:12 501 3.8 15.78 142 9.4 73.7 02/15/2020 09:09:27 494 3.7 15.84 125 14.1 78.3 02/15/2020 09:10:42 416 3.7 15.83 100 18.7 83.0 02/15/2020 09:11:57 439 3.7 15.73 118 23.4 87.7 02/15/2020 09:13:12 362 3.7 15.85 85 28.1 92.4 02/15/2020 09:14:27 419 3.7 15.85 98 32.7 97.0 02/15/2020 09:15:42 421 3.7 15.83 103 37.4 101.7 02/15/2020 09:16:57 452 3.7 15.84 106 42.1 106.4 02/15/2020 09:18:12 352 3.5 15.80 89 46.4 110.7 02/15/2020 09:19:27 158 1.8 16.25 50 49.9 114.2 02/15/2020 09:20:42 32 0.0 16.25 35 51.8 116.0 02/15/2020 09:20:49 19 0.0 16.24 33 51.8 116.0 Shut down drop top plug 02/15/2020 09:21:02 20 0.0 16.23 35 51.8 116.0 Reset Total, Vol = 51.77 bbl 02/15/2020 09:21:57 32 0.0 16.23 35 0.0 116.0 02/15/2020 09:23:12 58 0.0 16.23 33 0.0 116.0 02/15/2020 09:24:15 45 0.0 16.24 34 0.0 116.1 Fresh water behind 02/15/2020 09:24:27 37 0.0 12.48 35 0.0 116.1 02/15/2020 09:25:42 524 6.0 8.93 98 6.7 122.8 02/15/2020 09:26:57 488 6.0 8.54 100 14.2 130.2 02/15/2020 09:28:12 73 0.0 8.47 22 20.1 136.1 02/15/2020 09:28:37 63 0.0 8.45 19 20.1 136.1 Shut down swap to rig to displace 02/15/2020 09:29:27 52 1 0.0 8.42 57 20.1 136.1 Page 3 of 5 Page 4 of 5 Field Alpine Job Start Feb/15/2020 Customer ConocoPhillips Job Number Well RHEA 1 Date Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LB/6 WHP PSI Stage Total Volume Vol BBL BBL Message 02/15/2020 09:30:42 39 0.0 8.37 202 0.0 136.1 02/15/2020 09:31:57 41 0.0 8.34 190 0.0 136.1 02/15/2020 09:32:47 39 0.0 8.40 187 0.0 136.1 Blow air down hard line 02/15/2020 09:33:12 103 0.0 7.60 185 0.0 136.1 02/15/2020 09:34:27 141 0.0 6.43 192 0.0 136.1 02/15/2020 09:35:42 66 0.0 6.35 190 0.0 136.1 02/15/2020 09:36:57 61 0.0 6.82 189 0.0 136.1 02/15/2020 09:38:12 61 0.0 8.36 185 0.0 136.1 02/15/2020 09:39:27 57 0.0 8.37 179 0.0 136.1 02/15/2020 09:40:42 62 0.0 8.39 179 0.0 136.1 02/15/2020 09:41:57 67 0.0 8.38 187 0.0 136.1 02/15/2020 09:43:12 66 0.0 8.39 186 0.0 136.1 02/15/2020 09:44:27 56 0.0 8.39 182 0.0 136.1 02/15/2020 09:45:42 61 0.0 8.39 189 0.0 136.1 02/15/2020 09:46:57 67 0.0 7.60 182 0.0 136.1 02/15/2020 09:48:12 65 0.0 6.53 187 0.0 136.1 02/15/2020 09:49:27 59 0.0 6.39 206 0.0 136.1 02/15/2020 09:50:42 59 0.0 6.38 202 0.0 136.1 02/15/2020 09:51:57 53 0.0 8.33 218 0.0 136.1 02/15/2020 09:53:12 35 0.0 6.98 251 0.0 136.1 02/15/2020 09:54:27 37 0.0 8.33 212 0.0 136.1 02/15/2020 09:55:42 205 0.0 8.22 234 0.0 136.1 02/15/2020 09:56:57 192 0.0 7.45 273 0.0 136.1 02/15/2020 09:58:12 199 0.0 7.69 302 0.0 136.1 02/15/2020 09:59:27 195 0.0 7.68 313 0.0 136.1 02/15/2020 10:00:42 141 0.0 7.68 343 0.0 136.1 02/15/2020 10:01:57 137 0.0 7.67 361 0.0 136.1 02/15/2020 10:03:12 123 0.0 7.67 365 0.0 136.1 02/15/2020 10:04:27 127 0.0 7.66 453 0.0 136.1 02/15/2020 10:05:42 38 0.0 7.65 564 0.0 136.1 02/15/2020 10:06:57 55 0.0 7.65 546 0.0 136.1 02/15/2020 10:08:12 33 0.0 7.64 624 0.0 136.1 02/15/2020 10:09:27 31 0.0 7.63P534 0.0 136.1 02/15/2020 10:10:42 31 0.0 7.63 0.0 136.1 02/15/2020 10:11:57 32 0.0 7.63 0.0 136.1 02/15/2020 10:13:12 31 0.0 7.62 0.0 136.1 02/15/2020 10:13:59 27 0.0 7.62 1000 0.0 136.1 Bumped the plug 02/15/2020 10:14:27 27 0.0 7.62 1115 0.0 136.1 02/15/2020 10:15:42 29 0.0 7.62 1106 0.0 136.1 02/15/2020 10:16:57 29 0.0 7.62 1100 0.0 136.1 02/15/2020 10:18:08 26 0.0 7.61 263 0.0 136.1 Check floats 02/15/2020 10:18:12 27 0.0 7.61 132 0.0 136.1 02/15/2020 10:19:27 27 0.0 7.61 -15 0.0 136.1 02/15/2020 10:20:42 27 0.0 7.61 -16 0.0 136.1 02/15/2020 10:21:42 26 0.0 7.60 -15 0.0 136.1 Floats Held Page 4 of 5 Well Field Job StagCustomer lob Number RHEA 1 Alpine Feb/15/2020 ConocoPhillips N2 Post Job Summary Page 5 of Average Pump Rates, bbl/min Volume of Fluid Injected, bbl Slurry 3.1 N2 Mud Maximum Rate 6.4 Total Slurry 52.0 Mud 0.0 Spacer 60.0 N2 Treating Pressure Summary, psi Breakdown Fluid Maximum 4156 Final 23 Average 195 Bump Plug to Breakdown Type Volume bbl Density Ib/gal Avg. N2 Percent %T Designed Slurry Volume 47.0 bbl Displacement 0.0 bbl Mix Water Temp degF Cement Circulated to Surface? Volume bbl Washed Thru Peri To ft Customer or Authorized Rob Reindhardt Representative Schlumberger Supervisor Lance Kalivas Circulation Lost lob Completed �X Page 5 of RTD 220 -ooZ, Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, February 11, 2020 9:35 AM To: Loepp, Victoria T (CED) Subject: Rhea 1, PTD 220-002, Surface Casing Test and FIT Results Attachments: Rhea -1 Surface casing - FIT.pdf, 10.75 surface casing test chart.pdf, Rhea -1, F.I.T. 2352ft, 10ppg, 1100psi, 19.Oppg Chart.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, We performed the Rhea 1 Surface FIT early this morning. Test went well with an FIT EMW of 19.0 ppg. Please see attached test data and charts. Thanks, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com 1 d 4 Q T cu d r�1 v `d. W k6��rd4� y�bd C O N O N vi 7 (0 E E a X X f - LL a) C cu U a) U CO OM Q - O O O 000 N J O O y N E R mm d d ~ l a Co LO 0 0 0 0 0 0 O O O 0 0 0 0 0 0 0 0 0 0 0 0 m a' E cn o oN�no �o�no �no�n o �o�c,U? ono > CL OOO� �-NNM co V V Lo O O CO I` I-- co co O O O m E m () � a LL r+ O O O O 0) N y O m :0Mtt r - MCD -� NC Q C d Q = 7 E a 7� ON�CO 000NM p O ' Y � .N OO 00 co O 00 O co O co O co 00 O i Y V1 aL+ Y m in d � a 0000 0) 0') 00 000 O 000 U -coo . "I CN! CV N N(\1NN NNN N NNN m 0(� O �, C) - N CO 'q LO (D i- C0 0 0 LO O N CO N o CO 7 -p O > p O y U)C y > r m O 0 0 0 0 0 0 0 0 O O O 7 to v) COO N O ONLO '�tgv a0 0 00 C. C , m aN � -ttt1- O— M� CO 000 N N LOt- N N O N N d Q O VN Ouj N NM O > O F' Q / W , 't� y m ai w J C .0 a II a ca- O O _ V" N � N `r 0 L.L. V Y 0)7 (ntn o a N a o C Q N to ` U Lna ^ to z LL yr QJ JJ as H 'i y" N o O O O 1- I- L.L i2 £ N W �Q moo oor-� a -0 � ._� .o ` CL _� '� O o o � .o - w a F- _ J d _ `� o o _ _ CO _Y - LL m Z rnv o o O Ct W= m o _ _ _in t N 0 w O 7 C M ` '� '� H J0 0 N V a s N NSE W -)1-`O o - CL c a U) Z a �o r- N ca W N a a a�� 4-- Q"a 4' 4- c O o Q > 0 0 0 C.4 Ln p - a , F- a' N N .Q OT O LL V F- Y Q W C ~ u) O O co O x II a y o a0 m r r IIIIIIIIHI LL Ln IIIIII LLp c `v l# cz IN c a 3 p v w LL R W o w LOW M 0) m o V 11H O O y' HIM 11 N N v cu H a J CL -j J m C O O O Oo N LLL m N isCNJ OOC-N � J w 4.i 0OG Ln W VO N NU) LL N H N (D 0, o m r m C t N �t �N Q IC z U a V Cl) '� O N (� ,� .- 1� !Oq > U Y C U�' != V) �� c ayi x 0) J L N N ) -a rn�4- tiN W o An fA 2.: NiaQ+O+ a 0 c t6 0 O E 3 N a N m m V N W J o 0 0 0 0 0 0 0 'n o u) � z = F- in U ami r N �, m 3bnss3ad E 75 � D 2 W U O N O N vi 7 (0 E E a X X f - LL a) C cu U a) U CO P7TD 2 29 r 1 02 Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, February 10, 2020 9:45 AM To: Loepp, Victoria T (CED) Subject: Rhea 1 Surface Cement Job Report Attachments: Rhea 1 Surface TRT Report.pdf, Reporting - Cement Detail Report - RHEA 1 - 2020-02-10 09.37.22.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Rhea 1 pumped it's surface cement job yesterday 2-9-20. The cement job went well with full returns during the cement job and —190 bbl. of cement was seen back to surface. Please see attached reports. We are forecasted to start drilling out —6:00 pm tonight and performing our FIT —8:00 pm tonight. Thanks, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com 1 Cement Detail Report RHEA 1 String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/28/2020 00:00 Cement Details Description Surface Casing Cement Cementing Start Date 2/9/2020 02:00 Cementing End Date 219/2020 06:10 Wellbore Name RHEA 1 Comment Cement Stages Stage # <Stage Number?> Description Surface Casing Cement Objective Isolate Surface Casing Shoe and Install BOP's Top Depth (ftKB) 39.1 Bottom Depth (ftKB) 2,352.0 Full Return? Yes Vol Cement R 191.0 'Top Plug? Yes Bottom Plug? Yes Q Pump Init (bbl/min) 5 Q Pump Final (bbl/mi 8 Q Pump Avg (bbl/min 5 P Pump 363.0 Final (psi) P Plug Bump (psi) 1,246.0 Recip? Yes I Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) Est Btm (ftKB) 1 Amount (sacks) 1 Class Volume 75.0 Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sack) Free Water (%) Density (Ib/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.5 Est Btm (ftKB) 1,852.0 Amount (sacks) 905 Class Volume G 308.0 Pumped (bbl) Yield (ft'/sack) 1.91 Mix H2O Ratio (gal/sack) 6.65 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cP) 214.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,852.0 Est Btm (ftKB) 2,352.0 Amount (sacks) 288 Class Volume G 60.0 Pumped (bbl) Yield (W/sack) 1.17 Mix H2O Ratio (gal/sack) 5.02 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) 131.9 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 2/10/2020 Schlumberger Cementing JoL Aeport CemCATv1.6 Well RHEA 1 Client ConocoPhillips Field Alpine SIR No. Engineer Lance Kalivas Job Type Surface Country United States Job Date 02-09-2020 Time Wos/1az0 o:os.te pressure Rate Density WHP Messages 01:09:18 Rate Checks Good Reset Total, Vol = 6.08 bbl 01:34:00 01:59:00 02:24:00 02:49:00 Blow air down hard line Fluid pack hard line Low Pressure Test Trips Tripped High Pressure Test 03:14:00 PT Good Start Batching Mud Push Reset Total, Vol = 6.13 bbl Mudpush scaled 10.5 Shut down drop bottom plug Reset Total, Vol = 75.05 bbl 03:39:00 Reset Total, Vol = 0.00 bbl Start batching lead cmt Lead Scaled 10.8 heavy 04:04:00 04:29:00 MudPush to surface 04:54:00 End lead ant Reset Total, Vol = 307.87 bbl Start batchino tail Cement scaled 15.8 heavy 05:19:00 Shut down Drop Top Plug Reset Total, Vol = 60.65 bbl Fresh water behind Shut down swap to rig to displace Blow air down hard line 05:44:00 Reset Total, Vol = 20.21 bbl Reset Total, Vol = 0.00 bbl Reset Total, Vol = 0.00 bbl 06:09:00 Bumped the plug Check floats 06:21:47 Floats Held hh:mm:ss 0.00 2000 4000 6000 8000 10000 0.00 2A 4.0 6.0 8.0 10.0 5.0 10.0 15.0 20Z 25.o 0.00 1000 2000 3000 4000 5000 0:/09/2o:o 4, PSI - _ - -- _ B/M LB/G PSI UL/UV/LULU U/:421:UU Schlumberger Cementing Service Report Page 1 of 5 [Customer ConomPhillips lob Number WellLocation RHEA 1 (legal) Exploration Schlumberger Location PRUDHOE OTHER lob Start Feb/09/2020 Field Alpine Formation Name/Type Deviation deg Bit Size 13.5 in Well MD 2352.0 ft Well TVD 2352.0 ft County State/Province Alaska BNP psi BHST 56 degF BHCT 72 degF Pore Press. Gradient Ib/gal Well Master API/uWI Rig Name Drilled For Oil Service Via Land Casing/Liner Depth, ft Size, in Weight, Ib/ft Grade Thread Offshore Zone well Class New Well Type Exploration 2352.0 10.0 45.5 N80 0.0 0.0 0.0 Drilling Fluid Type Max. Density ib/gal Plastic Viscosity CP Tubing/Drill Pipe T/D Depth, ft Size, in Weight, Ib/ft Grade Thread Service Line Cementing lob Type Surface Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection 2" 1502 Perforations/Open Hole Top, ft Bottom, ft shot/ft No. of Shots Total Interval Service Instructions ft ft ft ft ft Diameter in ft ft Treat Down Displacement Packer Type 218.4 bbl Packer Depth ft Tubing Vol. bbl Casing Vol. Annular Vol. 226.3 bbi bbl Openhole Vol. bbl Casing/Tubing Secured 1 Hole Vol. Circulated prior to Cement Casing Tools Squeeze lob Lift Pressure psi Shoe Type Float Squeeze Type Pipe Rotated Pipe Reciprocated ❑ Shoe Depth 2352.0 ft Tool Type No. Centralizers Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Feb/09/2020 Arrived on Location Feb/09/2020 Leave Location Feb/09/2020 Collar Type Float Tail Pipe Depth ft Collar Depth 2270.0 ft Sq.. Total Vol. bbl Date Time 24 -hr clock Treating Pressure PSI Flow Rate B/M Density LB/G WHP CMT__STGVOL CMT TOT_SLOR Message PSI BBL BBL 02/09/2020 01:09:18 47 0.0 6.97 24 0.0 0.0 Started Acquisition 02/09/2020 1 01:10:58 64 0.0 7.78 28 0.0 0.0 02/09/2020 01:12:38 55 0.0 7.02 29 0.0 0.0 02/09/2020 01:14:18 80 3.0 6.89 40 2.0 2.0 02/09/2020 01:15:58 1 68 0.0 6.86 43 3.1 3.1 02/09/2020 01:17:38 84 0.0 6.82 53 6.1 6.1 02/09/2020 01:18:39 44 0.0 6.55 50 6.1 6.1 Rate Checks Good 02/09/2020 01:18:43 48 0.0 6.55 48 6.1 6.1 Reset Total, Vol = 6.08 bbl 02/09/2020 01:19:18 40 1 0.0 6.54 52 0.0 0.0 02/09/2020 01:20:58 37 0.0 6.50 48 0.0 0.0 02/09/2020 01:22:38 40 0.0 6.49 50 0.0 0.0 02/09/2020 01:24:18 41 0.0 6.48 46 0.0 0.0 02/09/2020 01:25:58 43 0.0 6.47 36 0.0 0.0 02/09/2020 01:27:38 41 0.0 6.46 34 0.0 0.0 02/09/2020 01:29:18 26 0.0 6.46 25 0.0 0.0 02/09/2020 01:30:58 37 0.0 6.45 22 0.0 0.0 02/09/2020 01:32:38 26 0.0 6.45 25 0.0 0.0 02/09/2020 01:34:18 21 0.0 6.45 27 0.0 0.0 02/09/2020 01:35:58 21 0.0 6.44 26 0.0 0.0 02/09/2020 01:37:38 j 21 j 0.0 6.44 18 0.0 0.0 02/09/2020 01:39:18 18 0.0 6.44 18 0.0 0.0 Page 1 of 5 Well RHEA 1 Pield Alpine Job Start Feb/09/2020 Customer ConocoPhillips yob Number Date TlmeTreating ..hr Clock Pressure PSI Flow Rate B/M Density LB/G WHIP PSI CNT_STG_VOL CMT TOT_SLOR 8111. BBL Message 02/09/2020 01:42:38 21 0.0 6.43 17 0.0 0.0 02/09/2020 01:44:18 18 0.0 6.43 78 0.0 0.0 02/09/2020 01:45:58 23 j 0.0 6.43 102 0.0 0.0 02/09/2020 01:47:38 32 0.0 6.43 92 0.0 0.0 02/09/2020 01:49:18 31 0.0 6.43 87 0.0 0.0 02/09/2020 01:50:58 30 0.0 6.42 115 j 0.0 0.0 02/09/2020 01:52:38 34 0.0 6.42 31 0.0 0.0 02/09/2020 01:54:18 19 0.0 6.42 18 0.0 0.0 02/09/2020 1 01:55:58 24 0.0 6.42 60 0.0 0.0 02/09/2020 01:57:38 33 0.0 6.42 200 0.0 0.0 02/09/2020 01:59:18 40 0.0 6.42 284 0.0 0.0 02/09/2020 02:00:58 40 0.0 6.42 365 1 0.0 0.0 02/09/2020 02:02:38 33 0.0 6.41 251 0.0 0.0 02/09/2020 02:04:18 36 0.0 6.41 114 0.0 0.0 02/09/2020 02:05:58 36 0.0 6.41 115 0.0 0.0 02/09/2020 02:07:38 38 0.0 6.41 115 0.0 0.0 02/09/2020 02:09:18 41 0.0 6.41 115 0.0 0.0 02/09/2020 02:10:58 39 0.0 6.41 114 0.0 0.0 02/09/2020 02:12:38 39 0.0 6.41 112 0.0 0.0 02/09/2020 02:14:18 37 0.0 6.41 113 0.0 0.0 02/09/2020 02:15:58 41 0.0 6.41 114 0.0 0.0 02/09/2020 02:17:38 22 0.0 6.41 112 0.0 0.0 02/09/2020 02:19:18 23 0.0 6.41 115 0.0 0.0 02/09/2020 02:20:58 35 0.0 6.40 116 0.0 0.0 02/09/2020 02:22:38 41 0.0 6.40 113 0.0 0.0 02/09/2020 02:24:18 36 0.0 6.40 114 0.0 0.0 02/09/2020 02:25:58 39 0.0 6.40 115 0.0 0.0 02/09/2020 02:27:38 37 0.0 6.40 113 0.0 0.0 02/09/2020 02:29:18 37 0.0 6.40 113 0.0 0.0 02/09/2020 02:30:58 25 0.0 6.40 116 0.0 0.0 02/09/2020 02:32:38 27 0.0 6.40 116 0.0 0.0 02/09/2020 02:34:18 39 0.0 6.40 114 0.0 0.0 02/09/2020 02:35:58 39 0.0 6.40 116 0.0 0.0 02/09/2020 02:37:38 39 0.0 6.40 114 0.0 0.0 02/09/2020 02:39:18 39 0.0 6.39 113 0.0 0.0 02/09/2020 02:40:58 38 0.0 6.39 112 0.0 0.0 02/09/2020 02:42:38 43 0.0 6.39 114 0.0 0.0 02/09/2020 02:44:18 41 0.0 6.39 118 0.0 0.0 02/09/2020 02:45:58 37 0.0 6.39 116 0.0 0.0 02/09/2020 02:47:38 33 0.0 6.39 116 0.0 0.0 02/09/2020 02:49:18 39 0.0 6.39 114 0.0 0.0 02/09/2020 02:50:58 39 0.0 6.39 119 0.0 0.0 02/09/2020 02:52:38 19 0.0 6.39 117 0.0 0.0 Blow air down hard line 02/09/2020 02:54:18 20 0.0 6.39 120 0.0 0.0 02/09/2020 02:55:58 21 0.0 6.39 79 0.0 0.0 02/09/2020 02:57:38 22 0.0 6.30 9 0.0 0.0 02/09/2020 02:58:33 20 0.1 6.30 7 0.0 0.0 Fluid pack hard line 02/09/2020 02:59:18 37 1.2 6.28 12 0.6 0.6 02/09/2020 03:00:58 187 2.0 6.34 112 3.8 3.8 02/09/2020 03:02:38 98 0.0 6.34 70 6.1 6.1 02/09/2020 03:04:04 93 0.0 6.34 66 6.1 6.1 Low pressure Test 02/09/2020 03:04:18 307 0.6 6.34 316 6.1 6.1 02/09/2020 03:04:50 1508 0.0 1 6.34 1 1483 1 6.1 6.1 Trips Tripped 02/09/2020 03:05:03 1609 0.0 1 6.34 1 1572 6.1 6.1 High Pressure Test Page 2 of 5 Well RHEA 1 RHEA Alpine Job Start Feb/09/2020 Customer ConocoPhillips Job Number Deft Time 24 -hr clock Treating Pressure PSI Flow Rate S/M Density LS/6 WHIP PSI MT STG VOL BBL CMT_T07 SLUR BBL Message 02/09/2020 03:06:54 2740 0.0 6.34 2678 6.1 6.1 PT Good 02/09/2020 03:07:38 36 0.0 6.34 32 6.1 6.1 02/09/2020 03:09:18 148 0.0 8.32 21 6.1 6.1 02/09/2020 03:09:20 151 0.0 8.32 23 6.1 6.1 Start Batching MudPush 02/09/2020 03:09:33 149 0.0 8.32 22 6.1 6.1 Reset Total, Vol = 6.13 bbl 02/09/2020 03:10:58 147 0.0 9.81 22 0.0 6.1 02/09/2020 03:12:38 104 0.0 10.67 19 0.0 6.1 02/09/2020 03:14:16 99 0.0 10.66 18 0.0 6.1 Mudpush scaled 10.5 02/09/2020 03:14:18 100 0.0 10.66 19 0.0 6.1 02/09/2020 03:15:58 258 3.0 10.35 132 3.2 9.4 02/09/2020 03:17:38 267 3.0 10.47 126 j 8.2 14.4 02/09/2020 03:19:18 297 3.7 10.34 144 13.3 19.4 02/09/2020 03:20:58 418 4.6 11.00 160 20.1 26.2 02/09/2020 03:22:38 397 4.7 10.62 149 27.8 33.9 02/09/2020 03:24:18 483 5.4 10.48 165 36.1 42.3 02/09/2020 03:25:58 474 5.4 10.47 159 45.1 51.2 02/09/2020 03:27:38 481 5.4 10.52 157 54.1 60.2 02/09/2020 03:29:18 486 5.4 10.40 156 63.1 69.2 02/09/2020 03:30:58 389 5.0 10.27 126 71.6 77.7 02/09/2020 03:32:16 74 0.0 9.69 27 75.0 81.2 Shut down drop bottom plug 02/09/2020 03:32:24 74 0.0 9.66 27 75.0 81.2 Reset Total, Vol = 75.05 bbl 02/09/2020 03:32:38 71 0.0 9.60 29 0.0 81.2 02/09/2020 03:34:18 113 0.0 9.27 12 0.0 81.2 02/09/2020 03:35:58 116 0.0 8.81 15 0.0 81.2 02/09/2020 03:37:38 91 0.0 6.09 39 0.0 81.2 02/09/2020 03:39:18 131 0.0 4.56 38 0.0 81.2 02/09/2020 03:40:58 97 0.0 9.13 36 0.0 81.2 02/09/2020 03:41:58 134 0.0 10.19 33 0.0 81.2 Start batching lead curt 02/09/2020 03:42:38 161 0.0 10.63 33 0.0 81.2 02/09/2020 03:44:18 166 0.0 10.83 33 0.0 81.2 02/09/2020 03:45:05 166 0.0 10.83 30 0.0 81.2 Lead Scaled 10.8 heavy 02/09/2020 03:45:58 423 3.7 10.82 121 1.7 82.9 02/09/2020 03:47:38 635 4.8 10.82 191 9.3 90.5 02/09/2020 1 03:49:18 804 1 5.8 10.84 247 18.8 100.0 02/09/2020 03:50:58 745 5.5 10.93 240 28.3 109.4 02/09/2020 03:52:38 378 3.5 10.97 117 35.8 116.9 02/09/2020 03:54:18 726 5.5 10.82 221 43.9 125.1 02/09/2020 03:55:58 722 5.4 10.86 222 53.0 134.2 02/09/2020 03:57:38 583 4.8 10.84 178 61.3 142.5 02/09/2020 03:59:18 700 1 5.4 10.88 212 69.8 151.0 02/09/2020 04:00:58 691 5.3 10.89 207 78.8 160.0 02/09/2020 04:02:38 692 5.3 10.93 200 87.7 168.8 02/09/2020 04:04:18 665 5.3 10.89 194 96.5 177.7 02/09/2020 04:05:58 673 5.3 10.89 198 105.4 186.6 02/09/2020 04:07:38 698 5.4 10.91 198 114.3 195.5 02/09/2020 04:09:18 699 5.4 10.93 198 123.2 204.4 02/09/2020 04:10:58 676 5.4 10.93 194 132.2 213.3 02/09/2020 04:12:38 707 5.4 10.94 213 141.1 222.3 02/09/2020 04:14:18 708 5.4 10.90 216 150.1 231.2 02/09/2020 04:15:58 697 5.2 10.91 207 158.8 240.0 02/09/2020 04:17:38 648 5.1 10.92 189 167.4 248.6 02/09/2020 04:19:18 566 4.7 10.88 162 175.7 256.9 02/09/2020 04:20:58 118 0.7 10.81 34 181.3 262.5 02/09/2020 04:22:38 414 3.7 10.99 110 184.2 265.4 Page 3 of 5 Well RHEA 1 Field Alpine Jab Start Feb/09/2020 Customer ConocoPhillips Sob Number Date TimeTreating 24 -hr clock Pressure PSI Flow Rate B/M Density LB/6 WHP PSI CMT STG VOL BBL CMIT_TOT SLUR BBL Message 02/09/2020 04:25:58 495 4.5 10.90 137 199.3 280.4 02/09/2020 04:27:38 433 4.2 10.89 115 206.4 287.5 02/09/2020 04:29:18 388 4.0 10.78 99 213.0 294.2 02/09/2020 04:30:58 426 4.1 10.92 110 219.8 301.0 02/09/2020 04:32:38 963 4.0 10.90 655 226.5 307.7 02/09/2020 04:34:18 392 4.1 10.85 96 233.3 314.5 02/09/2020 04:35:58 435 4.1 10.83 117 240.0 321.2 02/09/2020 04:37:38 524 4.3 10.94 165 247.1 328.3 02/09/2020 04:39:18 445 4.1 10.85 147 254.3 335.5 02/09/2020 04:40:58 462 4.0 10.85 154 261.0 342.2 02/09/2020 04:42:38 491 4.0 10.89 167 267.6 348.8 02/09/2020 04:44:18 518 4.1 10.92 189 274.3 355.5 02/09/2020 04:45:58 564 4.2 10.91 217 281.2 362.4 02/09/2020 04:47:38 548 4.2 10.92 217 288.2 369.4 02/09/2020 04:49:18 594 4.2 10.94 225 295.2 376.4 02/09/2020 04:49:57 619 4.2 10.94 254 297.9 379.1 MudPushto surfaoe 02/09/2020 04:50:58 630 4.2 10.93 262 302.2 383.3 02/09/2020 04:52:38 140 0.6 11.02 59 307.6 388.8 02/09/2020 04:53:28 58 0.0 10.98 17 307.9 389.0 End lead ant 02/09/2020 04:53:39 58 0.0 10.97 13 307.9 389.0 Reset Total, Vol = 307.87 bbl 02/09/2020 04:54:18 105 0.0 8.97 14 0.0 389.0 02/09/2020 04:55:58 96 0.0 8.04 15 0.0 389.0 02/09/2020 04:57:38 95 0.0 7.98 14 0.0 389.0 02/09/2020 04:59:18 93 0.0 7.31 14 0.0 389.0 02/09/2020 05:00:58 94 0.0 7.23 15 0.0 389.0 02/09/2020 05:02:38 91 0.0 7.21 14 0.0 389.0 02/09/2020 05:04:18 102 0.0 9.08 14 0.0 389.0 02/09/2020 05:04:51 117 0.0 10.91 16 0.0 389.0 Start batching tail 02/09/2020 05:05:58 148 0.0 14.80 18 0.0 389.0 02/09/2020 05:07:38 152 0.0 15.84 17 0.0 389.0 02/09/2020 05:07:57 156 0.0 15.84 17 0.0 389.0 Cement scaled 15.8 heavy 02/09/2020 05:09:18 607 3.7 16.29 242 3.5 392.6 02/09/2020 05:10:58 609 3.8 15.90 249 9.8 398.8 02/09/2020 05:12:38 586 3.7 15.80 231 16.0 405.0 02/09/2020 05:14:18 528 3.7 15.80 193 22.2 411.3 02/09/2020 05:15:58 537 3.8 15.77 187 28.4 417.5 02/09/2020 05:17:38 525 3.7 15.82 183 34.7 423.7 02/09/2020 05:19:18 511 3.8 15.81 164 40.9 430.0 02/09/2020 05:20:58 471 3.6 15.80 147 47.1 436.1 02/09/2020 05:22:38 376 3.2 15.91 97 52.7 441.8 02/09/2020 05:24:18 356 3.2 16.30 96 58.0 447.1 02/09/2020 05:25:42 40 0.0 16.27 23 60.7 449.7 Shutdown Drop Top Plug 02/09/2020 05:25:58 53 0.0 16.26 28 60.7 449.7 02/09/2020 05:27:04 54 0.0 16.26 27 60.7 449.7 Reset Total, Vol = 60.65 bbl 02/09/2020 05:27:38 58 0.0 16.26 28 0.0 449.7 02/09/2020 05:29:18 53 0.0 16.26 27 0.0 449.7 02/09/2020 05:30:54 52 0.0 16.26 29 0.0 449.7 Fresh water behind 02/09/2020 05:30:58 50 0.0 16.33 25 0.0 449.7 02/09/2020 05:32:38 376 5.2 8.93 78 6.9 456.6 02/09/2020 05:34:18 356 5.2 8.52 86 15.5 465.2 02/09/2020 05:35:13 41 2.2 8.45 32 20.2 469.9 Shut down swap to rig to displace 02/09/2020 05:35:58 45 0.0 8.28 12 20.2 469.9 02/09/2020 05:37:38 32 0.0 7.99 40 20.2 469.9 02/09/2020 05:39:18 33 0.0 7.65 44 20.2 469.9 Page 4 of 5 Well RHEA 1 Field Alpine Job Start Feb/09/2020 Customer ConocoPhillips Job Number Date TimeTreating 20 -hr clock Total Slurry 368.0 Pressure PSI Flow Rate B/M Density LB/G WHP PSI MT_SiG VOL CMT_TOT SLUR BBL BBL Message 02/09/2020 05:40:58 114 0.0 7.37 46 20.2 469.9 Bump Plug to 02/09/2020 05:42:38 31 0.0 7.23 46 20.2 469.9 Designed Slurry Volume 433.0 bbi 02/09/2020 05:44:18 Mix Water Temp de 35 0.0 8.14 47 20.2 469.9 02/09/2020 05:45:58 29 0.0 8.71 44 20.2 469.9 02/09/2020 05:47:10 30 0.0 8.72 48 20.2 469.9 Reset Total, Vol = 20.21 bbl 02/09/2020 05:47:11 29 0.0 1 8.72 49 0.0 469.9 Reset Total, Vol = 0.00 bbl 02/09/2020 05:47:38 28 0.0 8.99 60 0.0 469.9 02/09/2020 05:49:18 30 0.0 9.04 190 0.0 469.9 02/09/2020 05:50:58 30 0.0 0.00 359 0.0 469.9 02/09/2020 05:52:38 30 0.0 8.45 404 0.0 469.9 02/09/2020 05:54:18 29 0.0 8.45 448 0.0 469.9 02/09/2020 05:55:58 28 0.0 8.47 463 0.0 469.9 02/09/2020 05:57:38 26 0.0 8.49 492 0.0 469.9 02/09/2020 05:59:18 24 0.0 8.46 517 0.0 469.9 02/09/2020 06:00:58 54 0.0 8.34 544 0.0 469.9 02/09/2020 06:02:38 28 0.0 8.34 576 0.0 469.9 02/09/2020 06:04:18 26 0.0 8.35 613 0.0 469.9 02/09/2020 06:05:58 23 0.0 8.34 654 0.0 469.9 02/09/2020 06:07:21 26 0.0 8.34 649 0.0 469.9 Reset Total, Vol = 0.00 bbi 02/09/2020 06:07:38 27 0.0 8.34 656 0.0 0.0 02/09/2020 06:09:18 28 0.0 8.35 658 0.0 0.0 02/09/2020 06:10:58 23 0.0 7.36 1246 0.0 0.0 02/09/2020 06:11:09 21 0.0 7.24 1246 0.0 0.0 Bumped the plug 02/09/2020 06:12:38 24 0.0 7.23 1236 0.0 0.0 02/09/2020 06:14:18 21 0.0 7.39 1235 0.0 0.0 02/09/2020 06:15:58 31 0.0 8.34 1235 0.0 0.0 02/09/2020 06:17:38 59 0.0 8.34 1177 0.0 0.0 02/09/2020 06:19:18 42 0.0 8.33 7 0.0 0.0 02/09/2020 06:19:59 112 0.0 8.33 4 0.0 0.0 Check floats 02/09/2020 06:20:58 135 0.0 8.21 6 0.0 0.0 Post Job Summary Page 5 of 5 Average Pump Rates, bbl/min Volume of Fluid Injected, bbl Slurry 4.2 N2 Mud Maximum Rate 6.1 Total Slurry 368.0 Mud 0.0 Spacer 75.0 112 Treating Pressure Summary, psi Breakdown Fluid Maximum 3556 Final 150 Average 232 Bump Plug to Breakdown Type Volume bbi Density Ib/gal Avg. N2 Percent Designed Slurry Volume 433.0 bbi Displacement 218.0 bbi Mix Water Temp de Cement Circulated to Surface? volume 191.0 bbl Washed Thru Perfs To ft Customer or Authorized Representative Garet Schlumberger Supervisor Lance Kalivas Circulation Lost Job Completed EX Page 5 of 5 PTD dao - Do Z- Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 7, 2020 3:55 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CPAI: Rhea 1(PTD 220-002) CBL Intermediate Cement Follow Up Flag: Follow up Flag Status: Flagged Victoria, Email received and I will include it with the approved PTD. Thanks and have a good weekend, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, February 07, 2020 3:08 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]CPAI: Rhea 1(PTD 220-002) CBL Intermediate Cement Tom, The Sonic log of the intermediate cement is not required. However, the entire intermediate section should be logged with the CBL. No sundry is required. Approval is granted for these changes. Please include this approval with your approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp &alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@aiaska.aov Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, February 7, 2020 3:08 PM To: Polasek, Tom G Subject: CPAI: Rhea 1(PTD 220-002) CBL Intermediate Cement Follow Up Flag: Follow up Flag Status: Flagged Tom, The Sonic log of the intermediate cement is not required. However, the entire intermediate section should be logged with the CBL. No sundry is required. Approval is granted for these changes. Please include this approval with your approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.aov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, February 7, 2020 2:59 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Conoco, Rhea 1, PTD 220-002, Cement Top Evaluation? Hi Victoria, For Rhea 1 well PTD Conditions of Approval it states we can use LWD Sonic for top of cement evaluation. The main purpose of our sonic tool in our Production BHA is for formation evaluation in our production section. Because we are running a post rig VSP log we need to run a wireline Cement Bond Log of our intermediate cement job to use in our analysis of the VSP data. The wireline CBL will be run post Production section drilling and pre cement abandonment plug operations (during line 25, pg. 8 of 15, PTD). Is it acceptable for Conoco to not log intermediate cement while running in hole with the Sonic tool and only submit the CBL for cement evaluation? If yes, 1) do I need to submit a sundry to forego the sonic cement top evaluation, and 2) does AOGCC need the entire intermediate cement job logged with the CBL or will a CBL from 4500' MD to above cement top be acceptable? Thank You Victoria and please let me know if you have any questions, Tom 22. Drill 6-3/4" hole to section TD (LWD Program: GR/RES /Son MIA DN/N4icroScope/Stcthoscopehmud logging,). 23. Circulate to clean the hole., pull up to location of Stethoscope test, perform "Sticky test" prior to prefonning Stethoscope test, if sticky test is good indicating low chance of differential sticking, perform stethoscope formation pore pressure test. 24. Pull out of hole with drilling BHA. Review cement job details and smeie 4 6 wilh AOGCC after download and process recorded data. 25. Rig up wireline and perform open 1101e logging (rotary sidewall dire, possibli : fomintiot► pressure test) L 4 L 26. [UH with —2000' of 4.5" tubing on drill pipe to "1'D 27. Place --500 ft cenient plug across reservoir and up into casing, With AOGCC witness, wait on cement run in and tag'l'OC to confirm abandrnmlcnt plug. 28. POOI I to —2000' MD CRU Rhea 1(PTD 220-002) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well CRU Rhea 1 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. LWD 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. S. 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. AW.caflo n for Plermil to j-01, WM I CRU RHEA 1 Saved- 2 -Jan -20 Attachment I — Cement Summary RHEA -1 wV05 Cenl(I'llille Program; Rhea 1, FWK pilot= Slant Completed with Kill String PioDmd Schematic updated 12113119, D25, RXB 50.8 ft CW Sand Tqo [A 2475'M012475' TV0 (,YkW ab 19 M err, IMM! A Gannik Sand Tap 4105' M014055' M 20" GoDduclor to 120' , 4.5'Tubing MI String 2000' MD 12400' TVD 13.5" Open Hole with 10.75" 45.3 ppf L-80 TXP 2.455WD/2,455'TVD 11.2 ppg Cenbent TOC 34o0' mD 13004' TVD jt 0annik Sand Balm 4210' MD 14152' TVD 20" GoDduclor to 120' , 4.5'Tubing MI String 2000' MD 12400' TVD 13.5" Open Hole with 10.75" 45.3 ppf L-80 TXP 2.455WD/2,455'TVD 11.2 ppg Cenbent TOC 34o0' mD 13004' TVD Kuoa—fUk G Sand Top 7246 PAO 169W TVD LCU 725r MD 16964' TVD Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 3 rd, al HRZ Top GSW IAD /6347 TVD CDD HIES Stage Cementer 5548' MR 16347' TVD 15.P, Ppq cefflani I. TOG at Stage Cent iler i,; 9-7j8" X 41" Underreafned Opeiihole with Kalubik Top Set Casing 7 W" 29.7 ppf L-80 UP T 722V MD 16934VD @ 22.7- - Kuoa—fUk G Sand Top 7246 PAO 169W TVD LCU 725r MD 16964' TVD Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 3 P7 -D z 20 -0OZ Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, January 28, 2020 11:52 AM To: Loepp, Victoria T (CED) Subject: Rhea 1, PTD: 220-002, Mud Logging in Surface Section Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Due to logistics problems with our mud logging equipment, it will not be delivered to the wellsite and ready for operations until —2-3 days after the rig is ready to spud Rhea 1 well. We have decided to forgo the data collection in the surface hole section and start the mud log in the intermediate section. The Rhea 1 permit does not require a mud log, but because mud logging is listed in section 13, line 4 of the PTD drilling program attachment, as one of the LWD logs in the surface section, I wanted to make you aware we are not planning to run it. Thank You and please let me know if you have any questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Tuesday, January 28, 2020 2:09 PM To: Polasek, Tom G Cc: Loepp, Victoria T (CED) Subject: Rhea 1, PTD: 220-002, Mud Logging in Surface Section Tom, Sorry to hear about the equipment delay. You are correct: the Permit to Drill for Rhea 1 did not require a mud log because the Nechelik 1 exploratory well—located about 1 mile east—was mud logged and sampled from 90' to TD at 10,018' MD / TVD. However, if a mud log is recorded in Rhea 1, Regulation 20 AAC 25.071 requires CPAI to submit electronic image and digital data files to the AOGCC for the public record. Thanks and good luck with the well, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or s! eve ci •ci- ri I:a,grr✓. From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, January 28, 2020 11:52 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Rhea 1, PTD: 220-002, Mud Logging in Surface Section Hi Victoria, Due to logistics problems with our mud logging equipment, it will not be delivered to the wellsite and ready for operations until –2-3 days after the rig is ready to spud Rhea 1 well. We have decided to forgo the data collection in the surface hole section and start the mud log in the intermediate section. The Rhea 1 permit does not require a mud log, but because mud logging is listed in section 13, line 4 of the PTD drilling program attachment, as one of the LWD logs in the surface section, I wanted to make you aware we are not planning to run it. Thank You and please let me know if you have any questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Re: Colville River Field, Fiord Oil Pool, CRU Rhea 1 ConocoPhillips Alaska, Inc. Permit to Drill: 220-002 Surface Location: 4621' FNL, 2535' FEL, SEC. 13, T12N, R4E, UM Bottomhole Location: 4054' FNL, 4064' FEL, SEC. 13, T12N, R4E, 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, VY rice DATED this aday January, of Janua , 2020. STATE OF ALASKA AL. :A OIL AND GAS CONSERVATION COMMI, ON PERMIT TO DRILL 20 AAC 25.005 JAN 0 2 21M 1 a. Type of Work: 1b__ Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑1 e, Spgcify, if well is proposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ElSingle Zone ❑� • C4oa6etf' qS' ,,,Qas Hydrates El Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 CRU -Rhea 1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 7500 TVD: 7188 Colville River Unit Fiord Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 4621' FNL, 2535' FEL, Sec. 13, T12N, R4E, UM ADL025526 Top of Productive Horizon: 8. DNR Approval Number: 13. Approxim S ud Date: 4087' FNL, 3973' FEL, Sec. 13, T12N, R4E, UM LONS 19-007(Pending) 2/ /2020 3O/Z0 rrL Total Depth: 9. Acres in Property: 14. D stance to Nearest Property: 4054' FNL, 4064' FEL, Sec. 13, T12N, R4E, UM 2287 1216' to ADL288901 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 50.8 15. Distance to Nearest Well Open Surface: x- 376281 y- 5992781 • Zone- 4 GL / BF Elevation above MSL (ft): 10 to Same Pool: 5643' CD3 -127 16. Deviated wells: Kickoff depth: 2620 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 23 degrees Downhole: 4400 Surface: 3681 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" 78.6 B Welded 110 10 10 120 120 10 yds 13.5" 10.75" 45.5 L-80 TXP 2445 10 10 2455 2455 1060 sx 11.0ppg, 271 sx 15.8ppg G 9.875x11" 7.625" 29.7 L-80 TXP 7215 10 10 7225 6934 1st: 225sx 15.8 G,2nd: 829sx 11.2 G 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No ❑✓ 20. Attachments: Property Plat BOP Sketch Diverter Sketch Drilling Program ® Seabed Report H Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and roce re approved herein will not be deviated from without prior written approval. � Contact Name: Tom Polasek Authorized Name: Chip Alvord � ' Contact Email: tom. olasek co .com Authorized Title: Drilling Manager ��1��4�C% Contact Phone: 907-263-3740 Authorized Signature: Date: Commission Use Only Permit to Drill.2 '�i API Number: Permit Approval See cover letter for other Number. r 50- fL. 3 - 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: E] i Other.,30P f,,-SJ� f0 _Teh0 P45-"7 c, Samples req'd: Yes ❑ Nolo Mud log req'd: Yes ❑ No[� {/fir tom' SvO��✓ d /fit' "tllctr `j /CVch �S z H2S measures: Yes No❑ Directional svy req'd: Yes [/No❑ sv,bm/?-'5LI-Fa« a 51� La71�17 Spacing exception req'd: Yes ElNo❑ Inclination -only svy req'd: Yes E] Nod tc ll e6 r,- wh_ en a va.-11 /q b / e . Post initial injection MIT req'd: Yes ❑ Nom 5-- Cf ��t7ypro ✓cc wee �! I GlC�7 CU Coh o» u r-� fc �►,�d �ccl '�-� �' r l2os i - r-, APPROVED BY I I Approved by: COMMISSIONER THE COMMISSION Date Submit Form and Form -4 ised 2017 This ermit is valid for 4 e of approval per 20 AAC 25.005(g) Attachments in Duplicate CRU Rhea 1(PTD 220-002) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well CRU Rhea 1 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. LWD 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. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 2" d, 2020 Alaska Oil and Gas Conservation Commission 333 West 711, Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill FWK Rhea 1 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Kuparuk C Sand well from an ice pad with rig Doyon 25. The intended spud date for this well is 2/5/2020. FWK Rhea 1 is planned to be a Kuparuk C Sand pilot well. The 13-1/2" surface hole will TD above the C-30 sand. The surface hole will then be cased with 10-3/4" casing and cemented to surface. The intermediate section will be drilled with a 9-7/8" x 11" underreamer BHA and Managed Pressure Drilling technology and will TD above the Kuparuk C sand. This hole will be subsequently cased with a 7-5/8" casing string to surface and cemente to 250' TVD above the uppermost hydrocarbon bearing interval. The 6-3/4" production section will then be drilled through the Kuparuk C sand and TD within the Kingak shales. A logging run will be performed to evaluate the reservoir. The production hole will be colleted with cement plugs across the reservoir — sec ion an a 4.5" kill string. A post rig P&A, prior to end of ice pad season, will be performed. ✓ Please find attached the information required by 20 AAC 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 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 AAC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 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 Tom Polasek at 263-3740 (Tom.G.Polasek@conocophillips.com) or Chip Alvord at 265-6120. Sincer cc: Rhea l Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Tom Polasek Jennifer Hoyt ATO 1760 Drilling Engineer Lanston Chin Kuukpik Corp Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Rhea 1 Application for Permit to Drill Document K � Co1ocoPhillips - Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (1))............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 3 Requirements of 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) .........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c) (5)).......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))...........5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) .......................... 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) ....................................6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ..........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) .........................7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................9 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 9 15. Attachments................................................................................................................9 Attachment I Cement Summary .................................................................................................................. 9 RHEA 1 APD Page 1 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Attachment 2 Drilling Hazards Summary.................................................................................................... 9 .Attachment 3 Completion Schematic........................................................................................................... 9 Attachment 4 Directional Plan................................................................................................................... 9 RHEA 1 APD Page 2 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 1. Well Name (Requirements of 20 AAC 25.005 (fl) The well for which this application is submitted will be designated as FWK Rhea 1 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 4621' FNL, 2535' FEL, Sec. 13, T12N, R4E, UM NAD 1927 RKB Elevation 50.8' AMSL Northings: 5,992,781 Total VerticalDe th, RKB: 7,188' Eastings: 376,281 Pad Elevation 10' AMSL Top of Productive Horizon Heel 4087' FNL, 3973 FEL, Sec. 13, T12N, R4E, UM NAD 1927 Measured Depth, RKB: 7,249' Northings: 5,993,338 Total Vertical Depth, RKB: 6,956' Eastings: 374,852 Total Vertical De th, SS: 6,905' Total Depth Toe 4054' FNL, 4064' FEL, Sec. 13, T12N, R3E, UM NAD 1927 Northings: 5,993,373 Eastings: 374,761 Measured Depth, RKB: 7,500' Total VerticalDe th, RKB: 7,188' Total Vertical Depth, SS: 7,137' Requirements of 20 AA 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.00S(c)(3)) Please reference BOP and diverter schematics on file for Doyon 25.' RHEA 1 APD Page 3 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 120/ 120 10.9 51 56 10.75 2,455 / 2,455 14.5 1111 1606 7.625 7,225 / 6,934 15.5 3138 3681 Open Hole 7500/7,188 15.8 4400 - n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) y ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from ]b./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1 ] D _ [(10.9 x 0.052) - 0.1] x 120 = 56 psi OR ASP = FPP - (0.1 x D) = 1111 - (0.1 x 2455') = 866 psi 2. Drilling below 10-3/4" surface casing ASP = [(FG x 0.052) - 0.1 ] D = [(14.5 x 0.052) - 0.1] x 2455' = 1606 psi OR ASP = FPP - (0.1 x D) = 3138 - (0.1 x 6934') = 2445 psi 3. Drilling below 7-5/8" intermediate casing -7 ASP = [(FG x 0.052) - 0.1 ] D = [(15.5 x 0.052) - 0.1 ] x 6934 = 4895 psi 1 OR p�' �P ASP = FPP - (0.1 x D) ,VP = 4400- (0.1 x 7188') = 3681 psi - 4400 psi - Highest possible pore pressure due to offset injection RHEA 1 APD Page 4 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing,, Program Csg/Tbg Hole ane Weight Grade Conn. Length Top MDlND Btm MD/TVD Cement Program OD (in) (Ibfft) (ft) (fl,) (ft,) 20 42 156 X-56 Welded 80 10/10 120/ 120 10 yards Cement to Surface with 10.75 13.5 45.5 L-80 TXP 2,445 10/ 10 2,455 / 2,455 1060 sx DeepCrete Lead 11.0 ppg, 271 sx Class G Tail Slurry 15.8 ppg 7.625 9.875 29.7 L-80 TXP 7,215 10/10 7,225 / 6,934 Stage 1: 225 sx of Class G at 15.8 ppg X11 Stage 2: 829 sx of Class G at 11.2 ppg Open - 6.75 N/A N/A n/A 275 7225/ 6934 7500/ 7188 Production Hole Abandonment Plug Hole 149 sx of Class G 15.8 ppg 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). RHEA 1 APD Page 5 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 8. Drilling Fluid Program(Requirementsof20AAC25.005(c)(8)) Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation in the Qannik formation. Maintain mud weight between 9.6 ppg and 10.5 ppg. Be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 — 11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate r shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (F1oPro) weighted to 9.0 — 11.8 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. ✓ Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. RHEA 1 APD Page 6 of 15 Printed: 2 -Jan -20 Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 Casing Size in. 10.75 7.625 4.5 Density PPG 10.0 9.6— 10.8 - 9.0-11.8 PV CP 30-80 10 10 YP Ib./100 ft2 100-200 20-28 10-15 Funnel Viscosity s/qt. 300 50-60 40-50 Initial Gels Ib./100 ft2 50 10 6 10 Minute Gels Ib./100 ft2 60 15 8 API Fluid Loss cc/30 min. N.C. — 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0-12.0 10.0 pH 11.0 9.5-10.0 9.0-9.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation in the Qannik formation. Maintain mud weight between 9.6 ppg and 10.5 ppg. Be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 — 11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate r shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (F1oPro) weighted to 9.0 — 11.8 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. ✓ Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. RHEA 1 APD Page 6 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 9. Abnormally Pressured Formation Information (Requirements of20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. Set conductor and install cellar box 2. MIRU Doyon 25 onto Rhea 1. 3. Rig up Diverter and diverter line, test diverter, dewater cellar as needed. 4. Drill 13.5" hole to the surface casing point as per the directional plan (LWD Program: GR,/Res/ Mud Logging). 5. Run and cement 10-3/4" surface casing to surface. 6. Install BOPE and MPD equipment. Yr V 7. Test BOPE to 250 psi low / 3 psi high (24 hr. AOGCC notice). ✓ 8. Pick up and run in hole with 9-7/8" x 11" drilling BHA to drill the intermediate hole section. 9. Chart casing pressure test to 2900 psi for 30 minutes. 10. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 11. Drill 9-7/8" x 11" hole to section TD, using Managed Pressure Drilling to maintain near constant bottom hole pressure on connections in shale formation (LWD Program: GR/RES/Sonic/Mud Logging). 12. Change out upper pipe rams to 7-5/8" solid bodies and test same to 3,500 psi. 13. Run 7-5/8" casing and cement first stage to 500' MD above the hydrocarbon bearing zones (cementing schematic attached). 14. Shift Stage cementer open and circulate at 1- 3 BPM while waiting on first stage to reach 500 lbf/100ft^2 gel strength (-4.5 hrs) 15. Pump second stage cement to 1000 ft above Qannik top (cement job for VSP Log post rig) 16. Change upper pipe rams to 3-1/2" x 6" VBRs. 17. Test BOPE to 250 psi low / 3,500 psi high (24 hr. AOGCC notice). 18. Pick up and run in hole with 6-3/4" drilling BHA. 19. Chart casing pressure test to 3500 psi for 30 minutes. RHEA 1 APD Page 7 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 20. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 15.5 ppg. Minimum required leak -off value is 12.0 ppg EMW. 21. Install MPD and Displace to 10.3 ppg F1oPro WBM. 22. Drill 6-3/4" hole to section TD (LWD Program: GR/RES/Sonic/ADN/MicroScope/Stethoscope/mud logging,). 23. Circulate to clean the hole, pull up to location of Stethoscope test, perform "Sticky test" prior to preforming Stethoscope test, if sticky test is good indicating low chance of differential sticking, perform stethoscope formation pore pressure test. 24. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC with AOGCC after download f and process recorded data. 25. Rig up wireline and perform open hole logging (rotary sidewall core, possible formation pressure test) 26. RIH with 2000' of 4.5" tubing on drill pipe to TD 27. Place —500 ft cement plug across reservoir and up into casing. With AOGCC witness, wait on cement run in ✓ and tag TOC to confirm abandonment plug. 28. POOH to 2000' MD 29. Space out and land tubing hanger. 30. Pressure test hanger seals to 5000 psi. 31. Pressure test casing to 3500 psi and chart test 32. Install HP-BPV and test to 2,500 psi. 33. Nipple down BOP. 34. Install tubing head adapter assembly. N/U tree and test tree to 5000 psi/10 minutes. 35. Freeze protection tubing and annulus. 36. Secure well. RDMO. RHEA 1 APD Page 8 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well RHEA 1 will be injected into dedicated Class 1 disposal well CD 1-O l A on CDL Rhea 1 will be plugged and abandoned shortly after completion. There is no consideration for using Rhea I for annular disposal. 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Haards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan RHEA 1 APD Page 9 of 15 Printed. 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Attachment 1 — Cement Summary RHEA 1 Wp05 Cementing Program: Rhea 1, FWK Pilot — Slant Completed with Kill String Proposed Schematic updated 12J13119. D25, RKB 50.8 ft 9-718" X 11" Underrearned Openhote with Kalut>ik Top Set Casing 7 518'° 29.7 ppf L-80 TXP Oji ! cti 7225 MD 16934' TVD ( 223- Kuparuk Sandop ' # , LY 7'24& MD 16956' TVD� 0y1t- 4 i � r Ye N. 11 LCU 725T MD 16964' TVD r C 0 I` ,� ai d r a ri f ` S5 6.75" Open Hote TD Miuveach ~7500 MD 1 7188' TVD C55 RHEA 1 APD Page 10 of 15 Printed: 2 -Jan -20 20" Conductor to 12(Y 4.5" Tubing 191 String 2000' MD 12000' TVD 13.5" Open Hole with C30 Sand Tap 10.75" 45.5 ppf L-80 TXP 2475' MD / 2475' TVD 2,455' MD 12,459 TV© i y 19.2 ppg Cement ' I: TOC 3000' MD 13000' TVD oannik Sand Top 4105' MD 14056 TVD P y Qanrtik Sand Base 4210' MtD i 4152' TVD li I it r: 1. 1 � f �`) HRZ To 6585' MD 1634T TVD (�HLESStage Cementer 0 0 O:i Mil? 16347' TVD 15.8 ppg Cement i TOC at Stage Cementer 9-718" X 11" Underrearned Openhote with Kalut>ik Top Set Casing 7 518'° 29.7 ppf L-80 TXP Oji ! cti 7225 MD 16934' TVD ( 223- Kuparuk Sandop ' # , LY 7'24& MD 16956' TVD� 0y1t- 4 i � r Ye N. 11 LCU 725T MD 16964' TVD r C 0 I` ,� ai d r a ri f ` S5 6.75" Open Hote TD Miuveach ~7500 MD 1 7188' TVD C55 RHEA 1 APD Page 10 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 10.75" Surface Casing run to 2,484' MD / 2,484' TVD Cement from 2455' MD to 1955'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1955' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1350' MD), zero excess in 20" conductor. Lead slurry from 1,955' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (120'- 10') X 1.364 ft3/ft X 1.0 (0% excess) = 150 ft3 Permafrost to Conductor (1,350'- 120') X 0.3637 ft3/ft X 3.5 (250% excess) = 1,565 ft3 Top of Tail to Permafrost (1,955 - 1,350') X 0.3637 ft3/ft X 1.5 (50% excess) = 330 ft3 Total Volume = 150 + 1,565 + 330 = 2,045 ft3 => 1060 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,455' MD to 1,955' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,455'-1,955') X 0.3637 ft3/ft X 1.50 (50% excess) = 273 ft3 Shoe Joint (80� X 0.5400 ft3/ft X 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 7.625" Intermediate Casins run to 7,225' MD / 6,934' TVD Top of slurry I" stage is designed to be at 6,588' MD, which is more than 500' MD above the prognosis ' shallowest hydrocarbon bearing zone Kuparuk C. Assume 20% excess annular volume. Top of slurry of 2nd stage is designed to be at 3000' MD, which is more than 500' MD above Qannik Zone and will aid in acquiring good ✓ data quality during post rig VSP log. * 11" Under reamer is 140' above the 9-7/8" bit. Tail slurry from 7,225' MD to 6,588' MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8" Hole (7225'- 7085) X 0.2148 ft3/ft X 1.20 (20% excess) = 36 ft3 11" Hole to to Top of Cement (7085'- 6588') X 0.3428 ft3/ft X 1.20 (20% excess) = 204 ft3 Shoe Joint (80� X 0.2578 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 36+ 204 + 21 = 261 ft3 => 225 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk RHEA 1 APD Page 11 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Second Stage 6,588' MD to 3,000' MD with 11.2 ppg Class G + additives Stage Cementer to 3000' MD (6588'— 3000') X 0.3428 ft3/ft X 1.20 (20% excess) = 1475 ft3 Total Volume = 1475 ft3 => 829 sx of 11.2 ppg Class G + 0.2% D167 Fluid Loss Addictive, @ 1.78 ft3/a Abandonment Plug, Production hole drilled to 7,500' MD / 7,188' TVD Top of slurry is designed to be at 6,925' MD, which is 300' MD inside intermediate casing and 324' MD above the Kuparuk C hydrocarbon bearing zone. Assume 40% excess hole volume. Tail slurry from 7,500' MD to 6,925' MD with 15.8 ppg Class G + additives TD to Casing Shoe (7500'— 7225') X 0.2485 ft3/ft X 1.40 (40% excess) = 96 ft3 Casing Shoe to 300' MD inside (7225'— 6925') X 0.2578 ft3/ft X 1.00 (0% excess) = 77 ft3 casing Total Volume = 96 + 77 = 173 ft3 => 149 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk RHEA 1 APD Page 12 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level I Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision None circulating density (ECD) monitoring, mud rheology, lost circulation Abnormal Reservoir Pressure Medium - Monitor well at base of permafrost, increased mud weight, decreased Gas Hydrates Low mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Abnormal Reservoir Pressure Low Maintain planned mud parameters, Increase mud weight, use Running Sands and Gravel Low across the path of the planned wellbore. weighted sweeps. Hydrogen Sulfide gas Low Reduced pump rates, mud rheology, lost circulation material, use of Lost Circulation Low mud scavengers low density cement slurries 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level I Mitigation Strategy Lost circulation Medium Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low circulating density (ECD) monitoring, mud rheology, lost circulation Abnormal Reservoir Pressure Medium - material Hole swabbing on tris Low Annular pressure applied by managed pressure drilling equipment. Well control drills, increased mud weight. No mapped faults occur Abnormal Reservoir Pressure Low across the path of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers 6-3/4" Open Hole Production Interval Event Risk Level Mitigation Strategy Lost circulation Medium Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on tris Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Medium - Well control drills, increased mud weight. Hydrogen Sulfide gas Low HS drills, detection systems, alarms, standard well control practices, mud scavengers RHEA 1 APD Page 13 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: r Reservoir Pressure: Offset injection has the potential to increase the reservoir pressure. Appropriate mud weights, MPD and kick detection monitoring will be implemented. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach and instability in the intermediate interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. RHEA 1 APD Page 14 of 15 Printed: 2 -Jan -20 Application for Permit to Drill, Well CRU RHEA 1 Saved: 2 -Jan -20 Attachment 3 — Completion Schematic Rhea 1, FWK Pilot — Slant Completed with Kill String Proposed Schematic updated 1211 3119, D25, RI(B 50.8 ft 20" Conductor to 120` - 4-5' Tubing f0l String 2000'MD12DOO'TVD C30 Sand Top 13.5" Open Hole with 10.75" 45.5 ppf L-80 TXP 2475`MD12475' TVD 2,455' MD 12,455 TVD r}sr men Qannik Sand Top A 4105 MD 14056' TVD Qannik Sand Base 4210" MID 14152' TVD KRZ Top 5588' MD 1634T TVD Kalubik Kuparuk C Sand Top 7249 MID 16956` TVD LCU 72ST MDI 6964' TVD HES Stage Cementer 6588' MD 16347' TVD 11-2 ppg Gement TOG 3000' MD 13000' TVD 15.8 ppg Cement TOG at Stage Cementer 9-718" X I V Underrearned Openhole with Top Set Casing 7 &W 29.7 ppf L-80 TXP 7225 MID 16934' TVD @ 22-7- 6.75" Open Hole TD Miurveach —750T MD 1-7188'TVD RHEA I APD Page 15 of 15 Printed: 2 -Jan -20 gW 4A U) :3 p 8 ID U) 0 CL > ct 0 0 Z 0) 0 0 0 0 i T E u LL a) a < 'E - :3 .? = - M 2 R p 2 EL o �5 a- CL Q- m a_ a- IL of 0 z z m a 0 r - m U-1 s�v0 FZ InO, f5 Ln NX.VZAL N..O.ZZ.OZ N..O.OZ.OL N.A9 l.OL [i] d U 4 GD3�3"117 ADL025526 M Rhea 7 Rhea 1 Ice Pad '4 N L��O, CIO V, 02 0.4 0.6 U Miles ms's :S 1 Rhea 1 Ice Pad Well Trajectory Open interval Active Well Plugged and Abandoned CPAI Lease Conoco Phillips Alaska Rhea 1 PTD Plat 12/19/2019 11:29, December 03 2.019 1 D D III Accepted by: Rhea 1 (D) wp05 4.963 plan Summary S. DeLapp V Osara J. Ryan 5 > a2 103/4. m 7 5/8 x 9 7/8 by 1 0 3v 0 0 001 0 1500 3000 4500 6000 7500 0000 Measured Depth 0 1000 Plan: 40.8+10 @ 50.80usft (D25) 00 00010 n 3/4 x 13-1/ ` p j X3000 ApD� i ' 7 5/8 x 9 7/8 by 11 6 3/4 O �� oo �OpO 0 0 250 500 750 1000 1250 1500 330 30 Horizontal Departure c ° 300 N 60 a1 loon 1000 - 2000 15 2000 �.a.,. 3000 030 27090 3oao -- a000 P150 a0006000soon sono 6000 7500 0 0 200 400 600 800 1000 1200 1400 240 0Measured SURVEY PROGRAM Qegjl2_ epth FromDepth To Survey/Plan Tool 210 40.80 2450.00 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG 2450.00 2550.00 Rhea 1 (D) wp05 (Rhea 1) INC+TREND 180 2550.00 7240.00 7240.00 7350.00 Rhea (D) wpD 05 (Rhea 1) MWOWSG Rh1 ea 1 (D) wp05 (Rhea 1) MWD-INC_ONLY (INC>10') TVID MID 2454 SO 2454 80 10 3/4 xa1'T 7350.00 7600.00 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG 6933.80 7224.69 7 5/8 x 9 7/8 by 11 Magnetic Model & Date: BGGM2018 31-Dec-19 7187.75 7500.00 6 3/4 OH Magnetic North is 15.890 East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.770 57365nT Lithology Column Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotaton 10298 1 40.80 0.00 0.00 40.80 0.00 0.00 0.00 0.00 0.00 Base Frozen Sand 2 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 Start 2500.00 told at 100.00 MD 141.8 3 2600.00 0.00 0.00 2600.00 0.00 0.00 0.00 0.00 0.00 Stat 20.00 hold at 2600.00 M7 4 2620.00 0.00 0.00 2620.00 0.00 0.00 0.00 0.00 0.00 Stat Build 1.00 Base Perm 5 2820.00 2.00 291.29 2819.96 1.27 -3.25 1.00 291.29 3.49 Stat OLS 2.00 TFO 0.00 6 3855.85 22.72 291.29 3826.30 81.32 -208.70 2.00 0.00 223.98 Start 3404.22 hold at 3855.85 MJ 7 7260.06 22.72 291.29 6966.43 558.65 -1433.62 0.00 0.00 1538.62 Rhea-D T01 100419 Stat 239.94 hold at 7250.06 MJ 21- 8 7500.00 22.72 291.29 718775 592.29 -1519.95 0.00 0.00 1631.28 TD at 7500.00 C-30 8088 - C-20 3092 8 C-10 44?1--2- (Qannik) K-2 (Qannik Base Permit Pack saos e Allo 97 61 .'2Ib 96 HRZ I I Wy4tls1 �+ sult By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all Standard jj[approve ` Surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack l it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a ' 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: S. DeLapp V Osara J. Ryan CoP DE O CL OOOM%% a r m W s OC ■ O O CL OOOM%% a r m W s OC O O O O s o m �' U a. m a Q o , .� O Z MY O z o O O c M -�5 LO O O O m �' U a. m a Q o , .� O Z MY O z o O c M -�5 CD N co c r c_� rnco Q N 0 c� d Q O N Y Y O rn O LO C? Y O o O� Cn T V J N O00 C15 OOd U O O O O Z O O o p T T N O m CL O O00 U p _0 CAIt O N E O O 0\0 CO CO co T N U O LO U r (� O O x O O rC) y <, Sc _ x CY) p a ' o T o Op N ■ p C C O 1 C St, Q p o C) IM Q9 T y.. IQ 42) cz W O O A S s, o `. OO Q] C L y o O Cn oyCL TO ' yr 00—\ C -. 0 o `/ T a �ayb Q �U CID o S a o x ZL�00 0 0 co 0 0 0 0 0 o co 0 0 0 00 CD �+)PONA-)uln0% C� L .CL U) C) O Y W 0 RT LO O Q w Zw r s OC (uin}sn 009/) bulglJON Q 3 O NN 3 V ❑� UN N AE, rn 40 N ❑d -Q U _ N ❑7ot m U M 3 `O J roi j ❑ N Qo v 3 U U N N ❑ U W O co V ❑ cU N U ❑ a ❑ N V N ❑ U ❑ U o a rn U U U U M N ❑ U U o co ❑ N V U U 3 �o C) v 0 M O O CL LO U o r M N (uin}sn 009/) bulglJON ConocoPhillips Alaska Inc_WNS Western North Slope (CD2) Rhea 1 Plan: Rhea 1 50103xxxxx00 Rhea 1 Plan: Rhea 1 (D) wp05 Standard Proposal Report 12 December, 2019 �f ConocoPhillips ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: Rhea 1 TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) MD Reference: Plan: 40.8+10 @ 50.8usft (D25) North Reference: Grid Survey Calculation Method; Minimum Curvature Project Western North Slope (CD2), CD2, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Wellbore Rhea 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) BGGM2018 12/31/2019 15.89 80.77 57,364.71155168 Design Rhea 1 (D) wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 40.8 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) (°) 40.8 0.0 0.0 291.29 Site Site Position: From: Position Uncertainty: Rhea 1 Map 0.0 usft Depth From Depth To Well Well Position Position Uncertainty Plan: Rhea 1 +N/ -S +E/ -W 0.0 usft 0.0 usft 0.0 usft Ground Level: 10.0 usft Survey (Wellbore) Tool Name Remarks 1 40.8 2,450.0 Wellbore Rhea 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°) (nT) BGGM2018 12/31/2019 15.89 80.77 57,364.71155168 Design Rhea 1 (D) wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 40.8 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) (°) 40.8 0.0 0.0 291.29 12/12/2019 9:34:51AM Page 2 COMPASS 5000.14 Build 85H Plan Survey Tool Program Date 12/3/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 40.8 2,450.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG OWSG MWD - Standard 2 2,450.0 2,550.0 Rhea 1 (D) wp05 (Rhea 1) INC+TREND Inclinometer + known azi trend 3 2,550.0 7,240.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG OWSG MWD - Standard 4 7,240.0 7,350.0 Rhea 1 (D) wp05 (Rhea 1) MWD-INC—ONLY (INC>10°) MWD-INC—ONLY—FILLER (IN 5 7,350.0 7,500.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG OWSG MWD - Standard 12/12/2019 9:34:51AM Page 2 COMPASS 5000.14 Build 85H b V. ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 Plan Sections Build Turn Measured +N/ -S +E/ -W Depth Inclination Azimuth (usft) (°) (°) 40.8 0.00 0.00 100.0 0.00 0.00 2,600.0 0.00 0.00 2,620.0 0.00 0.00 2,820.0 2.00 291.29 3,855.8 22.72 291.29 7,260.1 22.72 291.29 7,500.0 22.72 291.29 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Vertical Build Turn Depth +N/ -S +E/ -W (usft) (usft) (usft) 40.8 0.0 0.0 100.0 0.0 0.0 2,600.0 0.0 0.0 2,620.0 0.0 0.0 2,820.0 1.3 -3.3 3,826.3 81.3 -208.7 6,966.4 558.6 -1,433.6 7,187.8 592.3 -1,520.0 ConocoPhillips Standard Proposal Report Well Plan: Rhea 1 Plan: 40.8+10 @ 50.8usft (D25) Plan: 40.8+10 @ 50.8usft (D25) Grid Minimum Curvature Dogleg Build Turn Rate Rate Rate (°/100usft) (°I10ousft) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 0.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 0.00 0.00 291.29 0.00 0.00 Rhea -D T01 100419 0.00 12/12/2019 9:34:51AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips p ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: EDT 14 Alaska Production ConocoPhillips Alaska Inc_WNS Western North Slope (CD2) Rhea 1 Plan: Rhea 1 Rhea 1 Rhea 1 (D) wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: Rhea 1 Plan: 40.8+10 @ 50.8usft (D25) Plan: 40.8+10 @ 50.8usft (D25) Grid Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +El -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°h100usft) (°/100usft) (°1100usft) 40.8 0.00 0.00 40.8 0.0 0.0 0.0 0.00 0.00 0.00 100.0 0.00 0.00 100.0 0.0 0.0 0.0 0.00 0.00 0.00 Start 2500.00 hold at 100.00 MD 200.0 0.00 0.00 200.0 0.0 0.0 0.0 0.00 0.00 0.00 300.0 0.00 0.00 300.0 0.0 0.0 0.0 0.00 0.00 0.00 400.0 0.00 0.00 400.0 0.0 0.0 0.0 0.00 0.00 0.00 500.0 0.00 0.00 500.0 0.0 0.0 0.0 0.00 0.00 0.00 600.0 0.00 0.00 600.0 0.0 0.0 0.0 0.00 0.00 0.00 700.0 0.00 0.00 700.0 0.0 0.0 0.0 0.00 0.00 0.00 800.0 0.00 0.00 800.0 0.0 0.0 0.0 0.00 0.00 0.00 900.0 0.00 0.00 900.0 0.0 0.0 0.0 0.00 0.00 0.00 1,000.0 0.00 0.00 1,000.0 0.0 0.0 0.0 0.00 0.00 0.00 1,029.8 0.00 0.00 1,029.8 0.0 0.0 0.0 0.00 0.00 0.00 Base Frozen Sand 1,100.0 0.00 0.00 1,100.0 0.0 0.0 0.0 0.00 0.00 0.00 1,200.0 0.00 0.00 1,200.0 0.0 0.0 0.0 0.00 0.00 0.00 1,300.0 0.00 0.00 1,300.0 0.0 0.0 0.0 0.00 0.00 0.00 1,341.8 0.00 0.00 1,341.8 0.0 0.0 0.0 0.00 0.00 0.00 Base Perm 1,400.0 0.00 0.00 1,400.0 0.0 0.0 0.0 0.00 0.00 0.00 1,500.0 0.00 0.00 1,500.0 0.0 0.0 0.0 0.00 0.00 0.00 1,600.0 0.00 0.00 1,600.0 0.0 0.0 0.0 0.00 0.00 0.00 1,700.0 0.00 0.00 1,700.0 0.0 0.0 0.0 0.00 0.00 0.00 1,800.0 0.00 0.00 1,800.0 0.0 0.0 0.0 0.00 0.00 0.00 1,900.0 0.00 0.00 1,900.0 0.0 0.0 0.0 0.00 0.00 0.00 2,000.0 0.00 0.00 2,000.0 0.0 0.0 0.0 0.00 0.00 0.00 2,100.0 0.00 0.00 2,100.0 0.0 0.0 0.0 0.00 0.00 0.00 2,200.0 0.00 0.00 2,200.0 0.0 0.0 0.0 0.00 0.00 0.00 2,300.0 0.00 0.00 2,300.0 0.0 0.0 0.0 0.00 0.00 0.00 2,400.0 0.00 0.00 2,400.0 0.0 0.0 0.0 0.00 0.00 0.00 1 2,454.8 0.00 0.00 2,454.8 0.0 0.0 0.0 0.00 0.00 0.00 10 314 x 13-112 2,474.8 0.00 0.00 2,474.8 0.0 0.0 0.0 0.00 0.00 0.00 C-30 2,500.0 0.00 0.00 2,500.0 0.0 0.0 0.0 0.00 0.00 0.00 2,600.0 0.00 0.00 2,600.0 0.0 0.0 0.0 0.00 0.00 0.00 Start 20.00 hold at 2600.00 MD 2,620.0 0.00 0.00 2,620.0 0.0 0.0 0.0 0.00 0.00 0.00 Start Build 1.00 2,700.0 0.80 291.29 2,700.0 0.2 -0.5 0.6 1.00 1.00 0.00 2,800.0 1.80 291.29 2,800.0 1.0 -2.6 2.8 1.00 1.00 0.00 2,808.8 1.89 291.29 2,808.8 1.1 -2.9 3.1 1.00 1.00 0.00 C-20 2,820.0 2.00 291.29 2,820.0 1.3 -3.3 3.5 1.00 1.00 0.00 Start DLS 2.00 TFO 0.00 2,900.0 3.60 291.29 2,899.9 2.7 -6.9 7.4 2.00 2.00 0.00 3,000.0 5.60 291.29 2,999.5 5.6 -14.4 15.4 2.00 2.00 0.00 3,093.9 7.48 291.29 3,092.8 9.5 -24.3 26.1 2.00 2.00 0.00 C-10 3,100.0 7.60 291.29 3,098.9 9.8 -25.1 26.9 2.00 2.00 0.00 3,200.0 9.60 291.29 3,197.7 15.2 -39.0 41.9 2.00 2.00 0.00 3,300.0 11.60 291.29 3,296.0 21.9 -56.1 60.3 2.00 2.00 0.00 3,400.0 13.60 291.29 3,393.6 29.8 -76.5 82.1 2.00 2.00 0.00 12/12/2019 9:34.51AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: Rhea 1 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) Project: Western North Slope (CD2) MD Reference: Plan: 40.8+10 @ 50.8usft (D25) Site: Rhea 1 North Reference: Grid Well: Plan: Rhea 1 Survey Calculation Method: Minimum Curvature Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) 3,500.0 15.60 291.29 3,490.4 39.0 -100.0 107.3 2.00 2.00 0.00 3,600.0 17.60 291.29 3,586.2 49.3 -126.6 135.8 2.00 2.00 0.00 3,700.0 19.60 291.29 3,681.0 609 -156.3 167.7 2.00 2.00 0.00 3,800.0 21.60 291.29 3,774.6 737 -189.1 202.9 2.00 2.00 0.00 3,833.7 22.27 291.29 3,805.8 78.2 -200.8 215.5 2.00 2.00 0.00 K-3 3,855.8 22.72 291.29 3,826.3 81.3 -208.7 224.0 2.00 2.00 0.00 Start 3404.22 hold at 3865.86 MD 3,900.0 22.72 291.29 3,867.0 87.5 -224.6 241.0 0.00 0.00 0.00 4,000.0 22.72 291.29 3,959.3 101.5 -260.6 279.7 000 0.00 0.00 4,100.0 22.72 291.29 4,051.5 115.6 -296.6 318.3 0.00 0.00 0.00 4,104.6 22.72 291.29 4,055.8 116.2 -298.2 320.1 0.00 0.00 0.00 K-2 (Qannik) 4,200.0 22.72 291.29 4,143.8 129.6 -332.5 356.9 0.00 0.00 0.00 / 4,209.8 22.72 291.29 4,152.8 131.0 -336.1 360.7 0.00 0.00 0.00 ✓ K-2 (Qannik Base) 4,300.0 22.72 291.29 4,236.0 143.6 -368.5 395.5 0.00 0.00 0.00 4,400.0 22.72 291.29 4,328.2 157.6 -404.5 434.1 0.00 0.00 0.00 4,500.0 22.72 291.29 4,420.5 171.6 -440.5 472.7 0.00 0.00 0.00 4,600.0 22.72 291.29 4,512.7 185.7 -476.5 511.4 0.00 0.00 0.00 4,700.0 22.72 291.29 4,605.0 199.7 -512.4 550.0 0.00 0.00 0.00 4,800.0 22.72 291.29 4,697.2 213.7 -548.4 588.6 0.00 0.00 0.00 4,900.0 22.72 291.29 4,789.5 227.7 -584.4 627.2 0.00 0.00 0.00 5,000.0 22.72 291.29 4,881.7 241.8 -620.4 665.8 0.00 0.00 0.00 5,100.0 22.72 291.29 4,973.9 255.8 -656.4 704.4 0.00 0.00 0.00 5,200.0 22.72 291.29 5,066.2 269.8 -692.4 743.1 0.00 0.00 0.00 5,300.0 22.72 291.29 5,158.4 283.8 -728.3 781.7 0.00 0.00 0.00 5,400.0 22.72 291.29 5,250.7 297.8 -764.3 820.3 0.00 0.00 0.00 5,500.0 22.72 291.29 5,342.9 311.9 -800.3 858.9 0.00 0.00 0.00 5,568.2 22.72 291.29 5,405.8 321.4 -824.8 885.3 0.00 0.00 0.00 Alb 97 5,600.0 22.72 291.29 5,435.1 325.9 -836.3 897.5 0.00 0.00 0.00 5,700.0 22.72 291.29 5,527.4 339.9 -872.3 936.2 0.00 0.00 0.00 5,800.0 22.72 291.29 5,619.6 353.9 -908.3 974.8 0.00 0.00 0.00 5,900.0 22.72 291.29 5,711.9 367.9 -944.2 1,013.4 0.00 0.00 0.00 6,000.0 22.72 291.29 5,804.1 382.0 -980.2 1,052.0 0.00 0.00 0.00 6,100.0 22.72 291.29 5,896.4 396.0 -1,016.2 1,090.6 0.00 0.00 0.00 6,200.0 22.72 291.29 5,988.6 410.0 -1,052.2 1,129.2 0.00 0.00 0.00 6,300.0 22.72 291.29 6,080.8 424.0 -1,088.2 1,167.9 0.00 0.00 0.00 6,340.1 22.72 291.29 6,117.8 429.6 -1,102.6 1,183.3 0.00 0.00 0.00 Alb 96 6,400.0 22.72 291.29 6,173.1 438.1 -1,124.1 1,206.5 0.00 0.00 0.00 6,500.0 22.72 291.29 6,265.3 452.1 -1,160.1 1,245.1 0.00 0.00 0.00 6,588.3 22.72 291.29 6,346.8 464.5 -1,191.9 1,279.2 0.00 0.00 0.00 HRZ 6,600.0 22.72 291.29 6,357.6 466.1 -1,196.1 1,283.7 0.00 0.00 0.00 6,700.0 22.72 291.29 6,449.8 480.1 -1,232.1 1,322.3 0.00 0.00 0.00 6,800.0 22.72 291.29 6,542.1 494.1 -1,268.1 1,361.0 0.00 0.00 0.00 6,900.0 22.72 291.29 6,634.3 508.2 -1,304.1 1,399.6 0.00 0.00 0.00 7,000.0 22.72 291.29 6,726.5 522.2 -1,340.0 1,438.2 0.00 0.00 0.00 7,100.0 22.72 291.29 6,818.8 536.2 -1,376.0 1,476.8 0.00 0.00 0.00 7,142.3 22.72 291.29 6,857.8 542.1 -1,391.2 1,493.1 0.00 0.00 0.00 Upper Kalubik 12/12/2019 9:34:51AM Page 5 COMPASS 5000.14 Build 85H left onocoPhilll s ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: Rhea 1 Vertical Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Depth Plan: 40.8+10 @ 50.8usft (D25) (usft) Project. Western North Slope (CD2) (") (") MD Reference: 2,454.8 10 3/4 x 13-1/2 Plan: 40.8+10 @ 50.8usft (D25) 7,224.7 Site: Rhea 1 7-5/8 11 North Reference: 7,187.8 6 3/4 OH Grid Well: Plan: Rhea 1 Survey Calculation Method: Minimum Curvature Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 7,181.3 22.72 291.29 6,893.8 547.6 -1,405.3 1,508.2 0.00 0.00 0.00 Lower Kalubik / K-1 7,200.0 22.72 291.29 6,911.0 550.2 -1,412.0 1,515.4 0.00 0.00 0.00 7,224.7 22.72 291.29 6,933.8 553.7 -1,420.9 1,525.0 0.00 0.00 0.00 7 5/8 x 9 7/8 by 11 7,248.5 22.72 291.29 6,955.8 557.0 -1,429.5 1,534.2 0.00 0.00 0.00 Kup C 7,257.2 22.72 291.29 6,963.8 558.2 -1,432.6 1,537.5 0.00 0.00 0.00 LCU 7,260.1 22.72 291.29 6,966.4 558.6 -1,433.6 1,538.6 0.00 0.00 0.00 Start 239.94 hold at 7260.06 MD 7,300.0 22.72 291.29 7,003.3 564.2 -1,448.0 1,554.0 0.00 0.00 0.00 7,400.0 22.72 291.29 7,095.5 578.3 -1,484.0 1,592.7 0.00 0.00 0.00 7,411.2 22.72 291.29 7,105.8 579.8 -1,488.0 1,597.0 0.00 0.00 0.00 Nuigsuit 7,500.0 22.72 291.29 7,187.8 592.3 -1,520.0 1,631.3 0.00 0.00 0.00 TD at 7500.00 - 6 3/4 OH Design Targets Target Name hit/misstarget Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape (°) (°) (usft) (usft) (usft) Rhea -D T01 100419 0.00 360.00 6,966.4 558.6 -1,433.6 plan hits target center Circle (radius 100.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,454.8 2,454.8 10 3/4 x 13-1/2 10-3/4 13-1/2 7,224.7 6,933.8 7 5/8 x 9 7/8 by ll 7-5/8 11 7,500.0 7,187.8 6 3/4 OH 0 6-3/4 12/1212019 9:34:51AM Page 6 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaskalnc_WNS Project: Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 Formations Measured Depth (usft) 1,029.8 1,341.8 2,474.8 2,808.8 3,093.9 3,833.7 4,104.6 4,209.8 5,568.2 6,340.1 6,588.3 7,142.3 7,181.3 7,248.5 7,257.2 7,411.2 Vertical Depth Vertical (usft) Name 1,029.8 Base Frozen Sand 1,341.8 Base Perm 2,474.8 C-30 2,808.8 C-20 3,092.8 C-10 3,805.8 K-3 4,055.8 K-2 (Qannik) 4,152.8 K-2 (Qannik Base) 5,405.8 Alb 97 6,117.8 Alb 96 6,346.8 HRZ 6,857.8 Upper Kalubik 6,893.8 Lower Kalubik / K-1 6,955.8 Kup C 6,963.8 LCU 7,105.8 Nuiqsuit Plan Annotations Measured Vertical Depth Depth (usft) (usft) 100.0 100.0 2,600.0 2,600.0 2,620.0 2,620.0 2,820.0 2,820.0 3,855.8 3,826.3 7,260.1 6,966.4 7,500.0 7,187.8 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: Rhea 1 TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) MD Reference: Plan: 40.8+10 @ 50.8usft (D25) North Reference: Grid Survey Calculation Method: Minimum Curvature Dip Dip Direction Lithology Local Coordinates +Nl-S +E/ -W (usft) (usft) Comment 0.0 0.0 Start 2500.00 hold at 100.00 MD 0.0 0.0 Start 20.00 hold at 2600.00 MD 0.0 0.0 Start Build 1.00 1.3 -3.3 Start DLS 2.00 TFO 0.00 81.3 -208.7 Start 3404.22 hold at 3855.85 MD 558.6 -1,433.6 Start 239.94 hold at 7260.06 MD 592.3 -1,520.0 TD at 7500.00 12/12/2019 9:34:51AM Page 7 COMPASS 5000. 14 Build 85H 0 CL a. V 0 M Z V i d JT L O 0 3 �o U _ I C Q' � a a LO 0^ a r O 0 0 CL 3 O Q C N O = s V x� O Zo N E � M - }, c d V a��a V V Q N r F � 0 CL a. V 0 M MW C R 0 CL d N c O a N E N N N N N N al a7 a5 o O O 0 0 0 O o 0 � ro rn N N N N N N V V V OR r� O r- r- r- N Ul 00 V V V LI? M 1� u) aO OOO O O a) d � Y> N >Y> >Y >> > C 7 N N N Q t d U U M M M V O N d O o 0 0 a a m C 6 (0 N C m N c 2 -° U U U cc LL d d O tN,o d 3 NNN R' d C o d M M M d d C I C d U j ❑ ❑ ❑ ad a N U O N U U U � U d N i d L m L 3 a C m Q N 'C Lo ~ N 3 0 M N d d W d 1- 0 N Q N a °' U C as LL LL LL 4 •c 0 N G 3 d o 0 0 D7 O 7 ❑ c r M N N 'jA O N d yO. N N N O ui ani d N d « O d LL U C OU CO I O C U °y N a3 d N N _ U0 0 dE Q o �lum r c y U U a a o- d u n it N M O O O O O N N N N N L L L L L 0 0 0 0 0 O O O O O .O N R N O F NV N N M LQ N N r- rl- r - OO O O O O 00000 't In N 'I In V .O N M O 0 N N r- r-: LL a 0 U V O N d O a C 6 (0 N C N c CL W -° U d d L_ d O CL C d 3 ad 3 m d d C N U j d a7 N N U O N ❑ C N N Q O N O d C N i d L m L 3 d d U tT C a Q N N 3 0 M N d d W d U l0 0 N Q N a °' U C as N d o 0 N G N y N C U U ❑ d U ani d N d « O d LL U C OU CO Q N O C U °y N a3 d N N _ U0 0 U Q CA N z 3 ME YI O CL 3 0 W r Q m a L O wCL W C N O V C Q 0 z W W Q 0 v Q CL I � '.,. O co O ' i 0 0 m i f i j I LL c O f � m Q I d � � 3 i oM L I t i I I o CL Cl) (IU .p O 0 a _ __. ._ —-—_ ._._Oc o m � o � E � y a o z L) F co LL O ci O N O O N O N N O O to N O O f0 a (u!/ OS'Z) aoloej uoileaedeS _d U Q 0 v Q CL 9:40, Decembel 12 2019 Rhea 1 (D) wp05 Ladder View 300 0 0 a� U m X150 U o m U 0 0 1500 3000 4500 6000 7500 Measured Depth SURVEY PROGRAM CASING DETAILS From Depth To Survey/Plan Tool TWD MD Nam 40.8 2450.0 Rhea 1 (D) wp05 (Rhea 1) M" D OVA SG 2454.8 2454.8 10 3/4 x 13-1/2 2450.0 2550.0 Rhea 1 (D) wp05 (Rhea 1) INC+TREND 6933.8 7224.77 5/8 x 9 7/8 by 11 2550.0 7240.0 Rhea 1 (D) wp05 (Rhea 1) M" D OVA SG 7187.8 7500.0 6 3/4 OH 7240.0 7350.0 Rhea 1 (D) wp05 (Rhea 1) MVD-INC_ONLY (INC>10°) 7350.0 7500.0 Rhea 1 (D) wp05 (Rhea 1) M\A D 0" SG 60 i n cn0 m I � 30 ....... ... - U I o I c 0 ' i U I 0 0 1500 3000 4500 6000 7500 Partial Measured Depth Rhea 1 (L) wp05 From To Tool 40.8 2450.0 WAD OVA SG 2450.0 2550.0 INC+TREND 2550.0 7240.0 MVA DOV\ SG 7240.0 7350.0 M\AD- INC _ONLY (INC>10°) 7350.0 7500.0 MVD OV�SG TVD 2454.8 6933.8 7187.8 270 MD Name 2454.8 10 3/4 x 13-1/2 7224.77 5/8 x 9 7/8 by 11 7500.0 6 3/4 OH MD Inc Azi TVD 40.8 0.00 0.00 40.8 100.0 0.00 0.00 100.0 2600.0 0.00 0.00 2600.0 2620.0 0.00 0.00 2620.0 2820.0 2.00 291.29 2820.0 3855.8 22.72 291.29 3826.3 7260.1 22.72 291.29 6966.4 7500.0 22.72 291.29 7187.8 W rc View Dleg TFace Target 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 291.29 2.00 0.00 0.00 0.00 Rhea -D T01 100419 0.00 0.00 Annotation Start 2500.00 hold at 100.00 MD Start 20.00 hold at 2600.00 MD Start Build 1.00 Start DLS 2.00 TFO 0.00 Start 3404.22 hold at 3855.85 MD Start 239.94 hold at 7260.06 MD TD at 7500.00 41 1000 1000 2000 90 2000 3000 3000 4000 4000 5000 5000 6000 6000 7500 V AL W CL � V / 0 0 �n 0 3 p 0 r m vDC h CIDoo CD c ■ 3 in 0 O "' Y 0 h o N � C C? 0 U 5 W LO O OOOM\ %%MOO r� W s OC Y� (ui/llsn 009b) buiylJON ConocoPhillips Alaska Inc WNS Western North Slope (CD2) Rhea 1 Plan: Rhea 1 50103xxxxx00 Rhea 1 Plan: Rhea 1 (D) wp05 Error Ellipse Survey Report 12 December, 2019 Company: ConocoPhillips Alaska Inc —WNS Project Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan. Rhea 1 TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) MD Reference: Plan: 40.8+10 @ 50.8usft (D25) North Reference: Grid Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: EDT 14 Alaska Production Project Western North Slope (CD2), CD2, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: NorthAmerican Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Rhea 1 Site Position: From: Map Position Uncertainty: 0.0 usft Well Plan: Rhea 1 Well Position +NI -S 0.0 usft +E/ -W 0.0 usft Position Uncertainty 0.0 usft Ground Level: 10.0 usft ore Rhea 1 ietics Model Name Sample Date Declination Dip Angle Field Strength (°1 (°) (nT) BGGM2018 12/31/2019 15.89 80.77 57,364.71155168 Design Rhea 1 (D) wp05 Audit Notes: Version: Vertical Section: Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 40.8 0.0 Survey Tool Program Date 12/3/2019 From To (usft) (usft) Survey (Wellbore) 40.8 2,450.0 Rhea 1 (D) wp05 (Rhea 1) 2,450.0 2,550.0 Rhea 1 (D) wp05 (Rhea 1) 2,550.0 7,240.0 Rhea 1 (D) wp05 (Rhea 1) 7,240.0 7,350.0 Rhea 1 (D) wp05 (Rhea 1) 7,350.0 7,500.0 Rhea 1 (D) wp05 (Rhea 1) Tie On Depth: 40.8 +E/ -W Direction (usft) (°) 0.0 291.29 Tool Name Description MWD OWSG OWSG MWD - Standard INC+TREND Inclinometer + known azi trend MWD OWSG OWSG MWD - Standard MWD-INC_ONLY (INC>100) MWD-INC_ONLY_FILLER ( INC>10°) MWD OWSG OWSG MWD - Standard 12/1212019 9:45:28AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc _WNS Local Co-ordinate Reference: Well Plan: Rhea 1 Project: Western North Slope (CD2) TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) Site: Rhea 1 MD Reference: Plan: 40.8+10 @ 50.8usft (D25) Well: Plan: Rhea 1 North Reference: Grid Wellbore: Rhea 1 Survey Calculation Method: Minimum Curvature Design: Rhea 1 (D) wp05 Output errors are at 2.00 sigma Database: EDT 14 Alaska Production Plan Survey Tool Program Date 12/3/2019 Depth Error Depth From Depth To Bias Error (usft) (usft) Survey (Wellbore) Tool Name Remarks Error 1 40.8 2,450.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG (°) (°) (usft) OWSG MWD - Standard (usft) 2 2,450.0 2,550.0 Rhea 1 (D) wp05 (Rhea 1) INC+TREND (usft) (usft) (usft) Inclinometer + known azi trent O 3 2,550.0 7,240.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG 0.00 40.8 0.0 OWSG MWD - Standard 0.0 4 7,240.0 7,350.0 Rhea 1 (D) wp05 (Rhea 1) MWD -INC -ONLY (INC>10°) 0.0 0.0 0.0 MWD -INC -ONLY -FILLER (It UNDEFINED 5 7,350.0 7,500.0 Rhea 1 (D) wp05 (Rhea 1) MWD OWSG 100.0 0.1 0.0 OWSG MWD - Standard 0.0 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) O 40.8 0.00 0.00 40.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.00 UNDEFINED 100.0 0.00 0.00 100.0 0.1 0.0 0.1 0.0 2.3 0.0 0.0 0.1 0.1 0.00 MWD OWSG(1) 200.0 0.00 0.00 200.0 0.5 0.0 0.5 0.0 2.3 0.0 0.0 0.5 0.5 0.00 MWD OWSG(1) 300.0 0.00 0.00 300.0 0.8 0.0 0.8 0.0 2.3 0.0 0.0 0.8 0.8 0.00 MWD OWSG (1) 400.0 0.00 0.00 400.0 1.2 0.0 1.2 0.0 2.3 0.0 0.0 1.2 1.2 0.00 MWD OWSG (1) 500.0 0.00 0.00 500.0 1.5 0.0 1.5 0.0 2.4 0.0 0.0 1.5 1.5 0.00 MWD OWSG(1) 600.0 0.00 0.00 600.0 1.9 0.0 1.9 0.0 2.4 0.0 0.0 1.9 1.9 0.00 MWD OWSG (1) 700.0 0.00 0.00 700.0 2.3 0.0 2.3 0.0 2.4 0.0 0.0 2.3 2.3 0.00 MWD OWSG (1) 800.0 0.00 0.00 800.0 2.6 0.0 2.6 0.0 2.4 0.0 0.0 2.6 2.6 0.00 MWD OWSG (1) 900.0 0.00 0.00 900.0 3.0 0.0 3.0 0.0 2.5 0.0 0.0 3.0 3.0 0.00 MWD OWSG (1) 1,000.0 0.00 0.00 1,000.0 3.3 0.0 3.3 0.0 2.5 0.0 0.0 3.3 3.3 0.00 MWD OWSG (1) 1,029.8 0.00 0.00 1,029.8 3.7 0.0 3.7 0.0 2.6 0.0 0.0 3.7 3.7 0.00 MWD OWSG (1) 1,100.0 0.00 0.00 1,100.0 3.7 0.0 3.7 0.0 2.6 0.0 0.0 3.7 3.7 0.00 MWD OWSG (1) 1,200.0 0.00 0.00 1,200.0 4.0 0.0 4.0 0.0 2.6 0.0 0.0 4.0 4.0 0.00 MWD OWSG(1) 1,300.0 0.00 0.00 1,300.0 4.4 0.0 4.4 0.0 2.7 0.0 0.0 4.4 4.4 0.00 MWD OWSG (1) 1,341.8 0.00 0.00 1,341.8 4.8 0.0 4.8 0.0 2.8 0.0 0.0 4.8 4.8 0.00 MWD OWSG(1) 1,400.0 0.00 0.00 1,400.0 4.8 0.0 4.8 0.0 2.8 0.0 0.0 4.8 4.8 0.00 MWD OWSG(1) 1,500.0 0.00 0.00 1,500.0 5.1 0.0 5.1 0.0 2.8 0.0 0.0 5.1 5.1 0.00 MWD OWSG (1) 1,600.0 0.00 0.00 1,600.0 5.5 0.0 5.5 0.0 2.9 0.0 0.0 5.5 5.5 0.00 MWD OWSG (1) 1,700.0 0.00 0.00 1,700.0 5.8 0.0 5.8 0.0 3.0 0.0 0.0 5.8 5.8 0.00 MWD OWSG (1) 1,800.0 0.00 0.00 1,800.0 6.2 0.0 6.2 0.0 3.1 0.0 0.0 6.2 6.2 0.00 MWD OWSG (1) 1,900.0 0.00 0.00 1,900.0 6.6 0.0 6.6 0.0 3.1 0.0 0.0 6.6 6.6 0.00 MWD OWSG (1) 2,000.0 0.00 0.00 2,000.0 6.9 0.0 6.9 0.0 3.2 0.0 0.0 6.9 6.9 0.00 MWD OWSG (1) 2,100.0 0.00 0.00 2,100.0 7.3 0.0 7.3 0.0 3.3 0.0 0.0 7.3 7.3 0.00 MWD OWSG (1) 2,200.0 0.00 0.00 2,200.0 7.6 0.0 7.6 0.0 3.4 0.0 0.0 7.6 7.6 0.00 MWD OWSG (1) 2,300.0 0.00 0.00 2,300.0 8.0 0.0 8.0 0.0 3.5 0.0 0.0 8.0 8.0 0.00 MWD OWSG (1) 2,400.0 0.00 0.00 2,400.0 8.4 0.0 8.4 0.0 3.6 0.0 0.0 8.4 8.4 0.00 MWD OWSG(1) 2,454.8 0.00 0.00 2,454.8 8.6 0.0 8.6 0.0 2.6 0.8 0.8 8.6 8.6 0.00 INC -TREND (2) 2,474.8 0.00 0.00 2,474.8 8.6 0.0 8.6 0.0 2.6 0.8 0.8 8.6 8.6 0.00 INC+TREND (2) 2,500.0 0.00 0.00 2,500.0 8.6 0.0 8.6 0.0 2.6 0.8 0.8 8.6 8.6 0.00 INC+TREND (2) 2,600.0 0.00 0.00 2,600.0 8.9 0.0 8.9 0.0 3.8 0.0 0.0 8.9 8.9 0.00 MWD OWSG (3) 12/12/2019 9:45:28AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc _WNS Local Co-ordinate Reference: Well Plan: Rhea 1 Project: Western North Slope (CD2) TVD Reference: Plan: 40.8+10 @ 50.8usft (D25) Site: Rhea 1 MD Reference: Plan: 40.8+10 @ 50.8usft (D25) Well: Plan: Rhea 1 North Reference: Grid Wellbore: Rhea 1 Survey Calculation Method: Minimum Curvature Design: Rhea 1 (D) wp05 Output errors are at 2.00 sigma of Bias Error Database: EDT 14 Alaska Production Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (') (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 2,620.0 0.00 0.00 2,620.0 8.9 0.0 8.9 0.0 3.8 0.0 0.0 8.9 8.9 0.00 MWD OWSG (3) 2,700.0 0.80 291.29 2,700.0 8.9 0.0 8.9 0.0 3.9 0.0 0.0 8.9 8.9 45.00 MWD OWSG (3) 2,800.0 1.80 291.29 2,800.0 8.9 0.0 8.9 0.0 4.0 0.0 0.0 8.9 8.9 89.50 MWD OWSG (3) 2,808.8 1.89 291.29 2,808.8 8.9 0.0 8.9 0.0 4.0 0.0 0.0 8.9 8.9 84.99 MWD OWSG (3) 2,820.0 2.00 291.29 2,820.0 8.9 0.0 8.9 0.0 4.0 0.0 0.0 8.9 8.9 84.99 MWD OWSG (3) 2,900.0 3.60 291.29 2,899.9 8.9 0.0 8.9 0.0 4.1 0.0 0.0 8.9 8.9 97.41 MWD OWSG (3) 3,000.0 5.60 291.29 2,999.5 9.0 0.0 9.0 0.0 4.2 0.0 0.0 9.0 9.0 102.74 MWD OWSG (3) 3,093.9 7.48 291.29 3,092.8 9.0 0.0 9.1 0.0 4.3 0.0 0.0 9.1 9.1 105.40 MWD OWSG (3) 3,100.0 7.60 291.29 3,098.9 9.0 0.0 9.1 0.0 4.3 0.0 0.0 9.1 9.1 105.40 MWD OWSG (3) 3,200.0 9.60 291.29 3,197.7 9.0 0.0 9.2 0.0 4.5 0.0 0.0 9.2 9.2 106.89 MWD OWSG (3) 3,300.0 11.60 291.29 3,296.0 9.1 0.0 9.4 0.0 4.6 0.0 0.0 9.4 9.3 107.81 MWD OWSG (3) 3,400.0 13.60 291.29 3,393.6 9.2 0.0 9.7 0.0 4.7 0.0 0.0 9.7 9.4 108.44 MWD OWSG (3) 3,500.0 15.60 291.29 3,490.4 9.2 0.0 10.0 0.0 4.8 0.0 0.0 10.0 9.5 108.89 MWD OWSG (3) 3,600.0 17.60 291.29 3,586.2 9.3 0.0 10.5 0.0 4.9 0.0 0.0 10.5 9.7 109.23 MWD OWSG (3) 3,700.0 19.60 291.29 3,681.0 9.4 0.0 11.0 0.0 5.1 0.0 0.0 11.0 9.8 109.50 MWD OWSG (3) 3,800.0 21.60 291.29 3,774.6 9.5 0.0 11.7 0.0 5.2 0.0 0.0 11.7 10.0 109.72 MWD OWSG (3) 3,833.7 22.27 291.29 3,805.8 9.6 0.0 12.2 0.0 5.3 0.0 0.0 12.2 10.1 109.82 MWD OWSG (3) 3,855.8 22.72 291.29 3,826.3 9.6 0.0 12.2 0.0 5.3 0.0 0.0 12.2 10.1 109.82 MWD OWSG (3) 3,900.0 22.72 291.29 3,867.0 9.7 0.0 12.6 0.0 5.3 0.0 0.0 12.6 10.2 109.89 MWD OWSG (3) 4,000.0 22.72 291.29 3,959.3 9.9 0.0 13.6 0.0 5.5 0.0 0.0 13.6 10.4 110.01 MWD OWSG (3) 4,100.0 22.72 291.29 4,051.5 10.1 0.0 14.6 0.0 5.7 0.0 0.0 14.6 10.6 110.10 MWD OWSG (3) 4,104.6 22.72 291.29 4,055.8 10.4 0.0 15.7 0.0 5.8 0.0 0.0 15.7 10.8 110.17 MWD OWSG(3) 4,200.0 22.72 291.29 4,143.8 10.4 0.0 15.7 0.0 5.8 0.0 0.0 15.7 10.8 110.17 MWD OWSG (3) 4,209.8 22.72 291.29 4,152.8 10.6 0.0 16.9 0.0 6.0 0.0 0.0 16.9 11.1 110.23 MWD OWSG (3) 4,300.0 22.72 291.29 4,236.0 10.6 0.0 16.9 0.0 6.0 0.0 0.0 16.9 11.1 110.23 MWD OWSG (3) 4,400.0 22.72 291.29 4,328.2 10.9 0.0 18.0 0.0 6.2 0.0 0.0 18.0 11.3 110.27 MWD OWSG (3) 4,500.0 22.72 291.29 4,420.5 11.2 0.0 19.2 0.0 6.4 0.0 0.0 19.2 11.6 110.30 MWD OWSG (3) 4,600.0 22.72 291.29 4,512.7 11.5 0.0 20.5 0.0 6.6 0.0 0.0 20.5 11.8 110.33 MWD OWSG (3) 4,700.0 22.72 291.29 4,605.0 11.8 0.0 21.7 0.0 6.8 0.0 0.0 21.7 12.1 110.36 MWD OWSG (3) 4,800.0 22.72 291.29 4,697.2 12.1 0.0 23.0 0.0 7.0 0.0 0.0 23.0 12.4 110.38 MWD OWSG (3) 4,900.0 22.72 291.29 4,789.5 12.5 0.0 24.2 0.0 7.2 0.0 0.0 24.2 12.7 110.40 MWD OWSG (3) 5,000.0 22.72 291.29 4,881.7 12.8 0.0 25.5 0.0 7.4 0.0 0.0 25.5 13.0 110.41 MWD OWSG (3) 5,100.0 22.72 291.29 4,973.9 13.1 0.0 26.8 0.0 7.6 0.0 0.0 26.8 13.3 110.43 MWD OWSG (3) 5,200.0 22.72 291.29 5,066.2 13.5 0.0 28.1 0.0 7.8 0.0 0.0 28.1 13.6 110.44 MWD OWSG (3) 5,300.0 22.72 291.29 5,158.4 13.8 0.0 29.5 0.0 8.0 0.0 0.0 29.5 13.9 110.45 MWD OWSG (3) 5,400.0 22.72 291.29 5,250.7 14.2 0.0 30.8 0.0 8.2 0.0 0.0 30.8 14.2 110.46 MWD OWSG (3) 5,500.0 22.72 291.29 5,342.9 14.6 0.0 32.1 0.0 8.4 0.0 0.0 32.1 14.5 110.47 MWD OWSG (3) 5,568.2 22.72 291.29 5,405.8 14.9 0.0 33.4 0.0 8.7 0.0 0.0 33.4 14.9 110.48 MWD OWSG (3) 5,600.0 22.72 291.29 5,435.1 14.9 0.0 33.4 0.0 8.7 0.0 0.0 33.4 14.9 110.48 MWD OWSG (3) 5,700.0 22.72 291.29 5,527.4 15.3 0.0 34.8 0.0 8.9 0.0 0.0 34.8 15.2 110.49 MWD OWSG (3) 5,800.0 22.72 291.29 5,619.6 15.7 0.0 36.1 0.0 9.1 0.0 0.0 36.1 15.5 110.49 MWD OWSG (3) 5,900.0 22.72 291.29 5,711.9 16.1 0.0 37.5 0.0 9.3 0.0 0.0 37.5 15.9 110.50 MWD OWSG (3) 6,000.0 22.72 291.29 5,804.1 16.5 0.0 38.8 0.0 9.6 0.0 0.0 38.8 16.2 110.51 MWD OWSG (3) 6,100.0 22.72 291.29 5,896.4 16.8 0.0 40.1 0.0 9.8 0.0 0.0 40.2 16.6 110.51 MWD OWSG(3) 6,200.0 22.72 291.29 5,988.6 17.2 0.0 41.5 0.0 10.1 0.0 0.0 41.5 16.9 110.52 MWD OWSG (3) 6,300.0 22.72 291.29 6,080.8 17.6 0.0 42.9 0.0 10.3 0.0 0.0 42.9 17.3 110.52 MWD OWSG (3) 6,340.1 22.72 291.29 6,117.8 18.0 0.0 44.2 0.0 10.5 0.0 0.0 44.2 17.7 110.53 MWD OWSG (3) 6,400.0 22.72 291.29 6,173.1 18.0 0.0 44.2 0.0 10.5 0.0 0.0 44.2 17.7 110.53 MWD OWSG (3) 6,500.0 22.72 291.29 6,265.3 18.4 0.0 45.6 0.0 10.8 0.0 0.0 45.6 18.0 110.53 MWD OWSG (3) 6,588.3 22.72 291.29 6,346.8 18.8 0.0 46.9 0.0 11.0 0.0 0.0 46.9 18.4 110.53 MWD OWSG (3) 6,600.0 22.72 291.29 6,357.6 18.8 0.0 46.9 0.0 11.0 0.0 0.0 46.9 18.4 110.53 MWD OWSG (3) 6,700.0 22.72 291.29 6,449.8 19.2 0.0 48.3 0.0 11.3 0.0 0.0 48.3 18.8 110.54 MWD OWSG (3) 6,800.0 22.72 291.29 6,542.1 19.6 0.0 49.7 0.0 11.5 0.0 0.0 49.7 19.1 110.54 MWD OWSG (3) 6,900.0 22.72 291.29 6,634.3 20.0 0.0 51.0 0.0 11.8 0.0 0.0 51.0 19.5 110.54 MWD OWSG (3) 12/12/2019 9:45:28AM Page 4 COMPASS 5000.14 Build 85H Company: ConocoPhillips Alaska Inc _WNS Project: Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: Rhea 1 Plan: 40.8+10 @ 50.8usft (D25) Plan: 40.8+10 @ 50.8usft (D25) Grid Minimum Curvature 2.00 sigma EDT 14 Alaska Production Position uncertainty and bias at survey station Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (11) 1"1 2,454.8 Measured Inclination Azimuth Vertical Highside 7,500.0 Lateral 0 6-3/4 Vertical Magnitude Semi -major Serm-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) C) 1°) (usft) (usft) (usft) (usft) lust!) (usft) (usft) (usft) (usft) (usft) (°) 7,000.0 22.72 291.29 6,726.5 20.5 0.0 52.4 0.0 12.0 0.0 0.0 52.4 19.9 110.55 MWD OWSG (3) 7,100.0 22.72 291.29 6,818.8 20.9 0.0 53.8 0.0 12.3 0.0 0.0 53.8 20.3 110.55 MWD OWSG (3) 7,142.3 22.72 291.29 6,857.8 21.3 0.0 55.1 0.0 12.6 0.0 0.0 55.1 20.7 110.55 MWD OWSG (3) 7,181.3 22.72 291.29 6,893.8 21.3 0.0 55.1 0.0 12.6 0.0 0.0 55.1 20.7 110.55 MWD OWSG (3) 7,200.0 22.72 291.29 6,911.0 21.3 0.0 55.1 0.0 12.6 0.0 0.0 55.1 20.7 110.55 MWD OWSG (3) 7,224.7 22.72 291.29 6,933.8 21.4 0.0 55.5 0.0 7.8 6.2 6.7 55.5 20.7 110.56 WD-INC_ONLY (INC>10°) (4) 7,248.5 22.72 291.29 6,955.8 21.4 0.0 55.5 0.0 7.8 6.2 6.7 55.5 20.7 110.56 WD-INC_ONLY (INC>10°) (4) 7,257.2 22.72 291.29 6,963.8 21.4 0.0 55.5 0.0 7.8 6.2 6.7 55.5 20.7 110.56 WD -INC -ONLY (INC>70°) (4) 7,260.1 22.72 291.29 6,966.4 21.4 0.0 55.5 0.0 7.8 6.2 6.7 55.5 20.7 110.56 WD -INC -ONLY (INC>10°) (4) 7,300.0 22.72 291.29 7,003.3 21.4 0.0 55.6 0.0 7.8 6.2 6.8 55.6 20.7 110.56 WD -INC -ONLY (INC>10°) (4) 7,400.0 22.72 291.29 7,095.5 21.4 0.0 56.1 0.0 12.8 0.0 0.0 56.1 21.0 110.57 MWD OWSG (5) 7,411.2 22.72 291.29 7,105.8 21.4 0.0 56.6 0.0 12.9 0.0 0.0 56.6 21.0 110.58 MWD OWSG (5) 7,500.0 22.72 291.29 7,187.8 21.4 0.0 56.6 0.0 12.9 0.0 0.0 56.6 21.0 110.58 MWD OWSG (5) Design Targets Target Name hittmiss target Dip Angle Dip Dir. TVD +N/ -S +EI -W Shape (°) (°) (usft) (usft) (usft) Rhea -D T01 100419 0.00 360.00 6,966.4 558.6 -1,433.6 plan hits target center Circle (radius 100.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (11) 1"1 2,454.8 2,454.8 10 3/4 x 13-1/2 10-3/4 13-1/2 7,224.7 6,933.8 7 5/8 x 9 7/8 by ll 7-5/8 11 7,500.0 7,187.8 6 3/4 OH 0 6-3/4 12/12/2019 9:45.28AM Page 5 COMPASS 5000.14 Build 85H Company: ConocoPhillips Alaska Inc _WNS Project: Western North Slope (CD2) Site: Rhea 1 Well: Plan: Rhea 1 Wellbore: Rhea 1 Design: Rhea 1 (D) wp05 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: Rhea 1 Plan: 40.8+10 @ 50.8usft (D25) Plan: 40.8+10 @ 50.8usft (D25) Grid Minimum Curvature 2.00 sigma EDT 14 Alaska Production Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology 1,029.8 1,029.8 Base Frozen Sand 0.00 1,341.8 1,341.8 Base Perm 0.00 2,474.8 2,474.8 C-30 0.00 2,808.8 2,808.8 C-20 0.00 3,093.9 3,092.8 C-10 0.00 3,833.7 3,805.8 K-3 0.00 4,104.6 4,055.8 K-2 (Qannik) 0.00 4,209.8 4,152.8 K-2 (Qannik Base) 0.00 5,568.2 5,405.8 Alb 97 0.00 6,340.1 6,117.8 Alb 96 0.00 6,588.3 6,346.8 HRZ 0.00 7,142.3 6,857.8 Upper Kalubik 0.00 7,181.3 6,893.8 Lower Kalubik / K-1 0.00 7,248.5 6,955.8 Kup C 0.00 7,257.2 6,963.8 LCU 0.00 7,411.2 7,105.8 Nuiqsuit 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 100.0 100.0 0.0 0.0 Start 2500.00 hold at 100.00 MD 2,600.0 2,600.0 0.0 0.0 Start 20.00 hold at 2600.00 MD 2,620.0 2,620.0 0.0 0.0 Start Build 1.00 2,820.0 2,820.0 1.3 -3.3 Start DLS 2.00 TFO 0.00 3,855.8 3,826.3 81.3 -208.7 Start 3404.22 hold at 3855.85 MD 7,260.1 6,966.4 558.6 -1,433.6 Start 239.94 hold at 7260.06 MD 7,500.0 7,187.8 592.3 -1,520.0 TD at 7500.00 Checked By: Approved By: Date: 12/12/2019 9:45:28AM Page 6 COMPASS 5000.14 Build 85H O O Ln cY) T omZ o O m a O a mCD v C) w `O O g O LO oQ Soati, 0 o �m E M, ea yb .. �� co � h O O -.. O Ln i I 1 Lo 0 OCU CD CL�= / s � VJ O cfICD �\ •',. 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Range 004 E ,. Meridian: Section: l8 FNL I f4620.7220 IFEL 2534.5604 Transform t ..................) Quit Help Rhea 1w 05 Surface Casing [M CPA[ Coordinate Converter — ❑ X From: Datum: NNAAD83 Region: alaska r LatitudelLongitude Decimal Degrees C UTM Zone: r- South ro State Plane Zone: q Units: us ft r Legal Description (NAD27 only) i- Starting Coordinates:---- X: oordinates:-- --- X: 11516313.5 Y: 15992527.4 i To: - ----- D atum: Datum: NAD27 Region: alaska C" Latitude/Longitude Decimal Degrees r UTM Zone: True r South t: Skate Plane Zone: q + Units: us -ft r Legal Description (NAD27 only) Ending Coordinates: - -- -- X: -X 376281.370364475 Y: 5992780.64135404 i ...................................... _ .................. Transformi Quit Help Rhea IwpO5 Surface Casing CS. CPAI Coordinate Converter — ❑ X r From: - -- — -- - -- i Datum: NAp83 Region: alaska f LatitudelLongitude Decimal Degrees + ! UTM Zone: I— F South i C� State Plane Zone: f_4 7____ -,-j Units: us -ft - Starting Coordinates: X: 1516313.5 Y: 5992527.4 f To: Datum: NAp27 _9Region: alaska 9 >" Latitude/Longitude Decimal Degrees C UTM Zone: True F South C State Plane Zone: q Units: us•ft t- Legal Description (NAD27 only) Legal Description - Township: 012 N + Range: 004 E + Meridian: I" Section:13 FNL 4620.7220 FEL 2534.5604 .Transform Quit Help Rhea lwp05 Top Kup C M CPAI Coordinate Converter - From: - — - -- - - - --- -- Datum: INAD83 Region: alaska • Latitude/Longitude Decimal Degrees +] • UTM Zone: f I- South !� State Plane Zone:q Units: us ft + r Legal Description (NAD27 only) Starting Coordinates:-- - X: 11515007.76 Y: 15993036.25 ❑ X To: - _ Datum: INAD27 Region: alaska + f" Latitude/Longitude Decimal Degrees t' UTM Zone: True r South State Plane Zone: q Units: us ft + C Legal Description (NAD27 only) i Ending Coordinates: X: 374975.663122217 Y: 15993289.54922751 ........................................................... Transform Quit Help .................................................. Rhea lwp05 Top Kup C I M CPA[ Coordinate Converter - ❑ X From: -.—. - - --- _— Datum: NAD83 Region: alaska C- Latitude/Longitude IDecimal Degrees + r UTM Zone: Fv f- South ro State Plane Zone:q + Units: Ps -ft-+ r Legal Description (NAD27 only) Starting Coordinates: -- X: 11515007.76 Y: 15993036.25 To: - - -- Datum: INAD27 Region: alaska + { Latitude/Longitude Decimal Degrees i UTM Zone: True (- South r State Plane Zone:q Units: us -ft + Legal Description (NAD27 only) - LegalDescription — - - Township: 012 N + Range: 004 E Meridian: JU I Section: 1 l3 FNL .,l 14133.5649 IFEL 3848.4511 r: ::.....:................................................. Transform Quit Help Rhea 1w 05 Intermediate Casing I CPA[ Cccrdinate Ccn erter — ❑ x From: Datum: NAD83 Region: alaska r Latitude/Longitude I Decimal Degrees r UTM Zone: 1 r South C•' State Plane Zone: f4 -------1 Units: us ft (" Legal Description (NAD27 only) Starting Coordinates: j X 11514892.73 Y: 5993081.04 Datum: 1UR7 Region: alaska (" Latitude/Longitude IDecimalDegrees r UTM Zone: True r South (% State Plane Zone: q Units: u7ft (` Legal Description (NAD27 only) Ending Coordinates: - - - X: 374860.63599564 Y: 5993334.34432086 i Transform Quit Help )Rhea lwp05 Intermediate Casing I M CPAI Coordinate Converter — ❑ x - From: — - - - - - Datum: NAD$3 Region: alaska Ii r Latitude/Longitude Decimal Degrees UTM Zone:` W` ;" South (� State Plane Zone:q _MjUnits: us fk C' Legal Description (NAD27 only) Starting Coordinates: X: 11514092.73 Y: 15993081.04 To: — - Datum: NpD2F Region:alaska Latitude/Longitude Decimal Degrees ( UTM Zone: True r South (" State Plane Zone: q Units: us ft (� Legal Description (NAD27 only) Legal Description Township: p12 N . Range: 004 E Meridian: Section: 113 FNL 4090.6965 FEL 15964.2001 Transform i Quik Help J Rhea 1 wp05 TD I M CPAI Coordinate Converter — ❑ X ,-From:-- Datum: rom:—Datum: N.AD83 Region: alaska + r Latitude/Longitude IDecimal Degrees �__j C UTM Zone: T_ South i I r State Plane Zone:4 Units: us ft + r Legal Description (NAD27 only) -To: — -- - -- Datum: NAD27 Region: alaska + f Latitude/Longitude Decimal Degrees +� i' UTM Zone: True I— South State Plane Zone: 4,ZJ Units: FT f T FT + r Legal Description (NAD27 only) Starting Coordinates: — - ---- Ending Coordinates: — -------____— �- X: 11514793.66 .. I X: 374761.568469016 Y: 15993119.62 Y: 5993372.92870689 s :........................................................... .Transform Quit Help Rhea 1 w 05 TD C,L CPA[ Coordinate Converter — ❑ X From: 1 Datum: jUD83 Region: alaska + C• Latitude/Longitude Decimal Degrees + r UTM Zone: r— South State Plane Zone: 4 Units: us Ft + 1 t Legal Description (NAD27 only) �- Starting Coordinates: X: 11514793.66 Y 5993119.62 L _ - - -- -- ___ _ _ -To: — Datum: NAD27 Region:alaska + Latitude/Longitude Decimal Degrees t' UTM Zone: ITrue South f• State Plane Zone: 4 Units: us -ft + l" Legal Description (NAD27 only) Ending Coordinates: X: 1374761.568469016 Y: 5993372.92870689 ........................................................... 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P 1000!33947 20'00 CSG _— 10 3/4-00 CSG 7 5/8' OD CSG —4 1/2'00 TBG OEM 6 WELLEMEQD OWS u 01 20 X 10 3/4 X 7 5/8 X 4 1/2 EIIIi49 PRIVATE AND CONFIDENTIAL AlE, oescalanoN All Br:0. Btil A11— _CK. A1L me�eFn w¢:eve¢��+C [vuL� SURFACE WELLHEAD LAYOUT, 1 Z.MAROUEZ 01-30-i7 GEN 5 WELLHEAD i�v BE4'' A=e KEl sizE "`'° ' 20 X 103/4 X 7 5/8 X 4 1/2 F. LARA 01-30-i7 NA AwJFeCTLAT. APPRBY4: 1 AtE: _CA ANNBEB Ev. coA�,�e, �.:�. eF Aare , sed a "' I.T ,�w<,Ak wr:al: ..�rA t 13763! 8 rca .� usE m sA� Br ue,erAcruxn a .r. a*:es rcnAw ' k�aovEn al: - --. A'E1 BDML BEA rFFT v�rxw: wiu4 fuv[sS m:nc� u:rroxirer,o. ei rxnwl+c- 1 G._COTT 10-IC-IH DMICC255482 1/3 corrnicnr ..�n:,mEex Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Tuesday, January 21, 2020 7:01 AM To: Loepp, Victoria T (CED) Subject: COP Rhea 1 & CD5-90 Schedule Update Hi Victoria, I wanted to update you on changes to our schedule since the email below was sent. CD5-96 is forecasted to release around midnight Friday the 24th. Our Rhea 1 ice pad is also now forecasted to be ready on Jan 24th. COP management has made the decision to move straight to Rhea 1 after CD5-96, instead of drilling surface section on CD5-90 as email below stated. This puts forecasted spud of Rhea 1 at a possible earliest spud date of Jan 30th. Most likely or probable spud date for Rhea 1 is February 11t or 2"d. After Rhea 1 (- Feb 21St) we will move to CD5-90. Thank You and please let me know if you have any questions regarding our planned schedule or Rhea 1, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Polasek, Tom G Sent: Monday, December 23, 2019 11:17 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-90(PTD 219-189) Hi Victoria, Rhea 1 is the Fiord West Kuparuk Pilot well that is planned to be drilled off of an Ice Pad off of the CD3 ice road. Attached is an overview map that will also be included with the PTD application. The permit for Rhea will be submitted shortly after Christmas. The ice pad for Rhea will not be ready until February 15Y. Spud for Rhea 1 is Scheduled for February 51h, if all goes according to plan. Original drilling schedule had CD5-96 releasing first to second week of February, and D25 would then move to Rhea 1. Because CD5-26 (well prior to CD5-96) TD'd short and released 2 weeks early it bumped the rig schedule up and CD5-96 is now forecast to release —Jan 22-26. In this instance we would like to move to C135-90 and drill the surface section prior to moving to Rhea 1. This would put spud of CD5-90 surface section — Jan 24 -27th at current forecast. Please let me know if have any other questions and have a good Holiday! Thanks Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, January 17, 2020 12:52 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CRU Rhea 1(PTD 220-002) Kick Tolerance Hi Victoria, For the intermediate section on Rhea 1 we are planning to TD (topset) in the shale above the Kuparuk C sand. The shale above the Kuparuk C sand is considered to be normally pressured. The planned TVD of the intermediate section is 6934' TVD. The calculation of Formation Pore Pressure (FPP) at the intermediate section depth, topset above the Kuparuk C sand, is 0.4525 * 6934 = 3138 psi.�� fS�o52 � � �pP�- At the formation pressure of 3138 psi, using 10.3 ppg drilling mud, and a 12.5 ppg EMW FIT/LOT of the surface shoe plus 100 psi safety margin, I calculate the surface casing shoe can withstand —77 bbl. kick, which is above ConocoPhillips recommended minimum tolerance. I do agree that if the intermediate section was to TD in the Kuparuk C sands, and the sands are over pressured to the max possible pore pressure of 4400 psi as stated on the PTD, the surface shoe FIT/LOT would need to be —14.5 ppg EMW. We do not plan to TD in the Kuparuk C Sand. Z_ o !v With the above calculations and assumptions, I calculate that a 12.5 ppg EMW FIT/LOT at the surface shoe is still adequate. Please let me know if you agree 12.5 ppg EMW FIT/LOT, with the above assumptions, is adequate for the PTD, and if not, please let me know if you still require an FIT/LOT of 14.5 ppg EMW or other value. Thanks Victoria, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, January 16, 2020 2:05 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]CRU Rhea 1(PTD 220-002) Kick Tolerance Tom, The minimum LOT required to drill ahead the intermediate section is closer to 14.5 ppg EMW vs the 12.5 ppg EMW in the PTD. Let me know if you disagree with this. Thanx, OL Q a 0 > 0 0 N 1D C � O � co 3 u m U W u L a � O f6 cc u Y u H C C \ ro � V a 'O u i a Y a � 3 U V ro w 3 � 0 0 ro � CU g ro � E W O N =o 'N L N V 00 a c Y (9 C V ro a aLa aL.+ •�= V Y O Y O u a 3 ro > a a a .% � i � C O vNi M N 3 3 3 � ro a a s c Y ro Y N "Jo C N y H L N C L O N m m a 0 u > YO L ro a F C 3 u Y ro ++O L r ro N d w cu C V d ` ro X a Y ` 0 o o a 0. Y ro m 3 0r ro cu m OL E Ea 3 ro - L N w aL+ 0 O Q p > Y N N N a a a 00 L CL V u V C C C Q w x a Ln 'A Ln P, o c m OD Ln n 00 a a ai 0 L W 'N 3 O N C O N E 0 0 = x a v a m Y x O OD Ln Y a c p 2 fa Y N Y a O ( � j w Q > 3 C °a' c "6 a s .� w o = n. Q N m p a � v a a O > L Y L Y L 'i"' 3 u u � -O 2 UO v \ O O p m >p c 3 ro ro v o a > ro �p 3 T 2 C G c C o 0 O O a C Y N N C C O Y Y a a a a C L Y Y v 3 rot v E E L S Y C 3 LM 7 N N m u m OD c Q Q CL n a 3 ro ro V O a U a ro ro f8 0 O ro L a L C C r Q Q a z a C c cro .O -0 •N N N v -0 a Q Q a) -0 -0 -0 V 1-I N V 00 r -I Ln '-g N al 0 N ;�, LO cY1 F-4 ` fV O O v o v 0 o m 00 w a O Q x a v V Y Q Y x O OD Ln c c p 2 fa O- to N Y a Z- O C m ( � j w Q > a C C °a' u �c "6 a s .� w 4- O O w- O 'Oa O Q N - a p a � a a a U Q\ U O a0 a O L 'i"' 3 u m a OD o== UO v 7 -C o 3 7 EL o; o 0 >p> >p v w l7 2 m .9 2 > ro > ro > a Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, January 17, 2020 12:55 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: CRU Rhea 1(PTD 220-002) Kick Tolerance Hi Victoria, responded to the first email in this chain, on a separate email. Thank you for pointing out the mistake in BOP test pressure. I will update my drilling procedure to reflect your change to 3800 psi and I will look for the correction on the PTD. Thanks again, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, January 16, 2020 2:08 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]RE: CRU Rhea 1(PTD 220-002) Kick Tolerance Also, the BOP test pressure needs to be above the MPSP of 3681 psig so I have changed the BOP test pressure to 3800 psig. From: Loepp, Victoria T (CED) Sent: Thursday, January 16, 2020 2:05 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: CRU Rhea 1(PTD 220-002) Kick Tolerance Tom, The minimum LOT required to drill ahead the intermediate section is closer to 14.5 ppg EMW vs the 12.5 ppg EMW in the PTD. Let me know if you disagree with this. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Loepp, Victoria T (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Monday, December 23, 2019 11:17 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CRU CD5-90(PTD 219-189) Attachments: 6. FWK_2019_20_Overview.pdf Follow Up Flag: Follow up Flag Status: Completed Hi Victoria, Rhea 1 is the Fiord West Kuparuk Pilot well that is planned to be drilled off of an Ice Pad off of the CD3 ice road. Attached is an overview map that will also be included with the PTD application. The permit for Rhea will be submitted shortly after Christmas. The ice pad for Rhea will not be ready until February 15Y. Spud for Rhea 1 is Scheduled for February 5th, if all goes according to plan. Original drilling schedule had CD5-96 releasing first to second week of February, and D25 would then move to Rhea 1. Because CD5-26 (well prior to CD5-96) TD'd short and released 2 weeks early it bumped the rig schedule up and CD5-96 is now forecast to release —Jan 22-26. In this instance we would like to move to CD5-90 and drill the surface section prior to moving to Rhea 1. This would put spud of CD5-90 surface section — Jan 24 -27th at current forecast. Please let me know if have any other questions and have a good Holiday! Thanks Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, December 23, 2019 8:34 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]CRU CD5-90(PTD 219-189) Tom, What is the approximate spud date for this well? The PTD indicates 1/22/2020 but the most recent rig schedule shows Rhea next for Doyon 25 followed by CD5-90 on 2/19/2020. I'm not familiar with Rhea. Has a PTD been submitted? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska CN - 0'. V I r' v L La a .. � 4 w N N.OZZ.OL N.O.OZ.OL N.02LOL 5E (A S rn cc U) o a aa) Q� a Z J N u af v v Q y > L> 3> v a ami a 6 Z Q O d d d m m IL¢ c7 Q Y �o 0 0 -_ � � _� � � o v LL n n n Q € d � m a CL ` a z z m -140 0 a` R y Of L) LL CN - 0'. V I r' v L La a .. � 4 w N N.OZZ.OL N.O.OZ.OL N.02LOL Davies, Stephen F (CED) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Friday, January 10, 2020 2:13 PM To: Davies, Stephen F (CED) Subject: RE: [EXTERNAL]Rhea 1 (PTD 220-002) - Questions Hi Steve, Please see my answers in RED, to your questions below. Thank You, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Thursday, January 09, 2020 9:23 AM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]Rhea 1 (PTD 220-002) - Questions Thank you Tom. Quick questions: I notice that the expected reservoir pressure in the Kuparuk is estimated to be about 11.8 ppg EWM. How was this abnormal pressure estimated? The 11.8 ppg EMW is estimated from the Char 1 exploration well we drilled in 2008 and subsequent testing. Char 1 encountered unexpectedly high pressure when drilling the well. Follow up testing of the Kuparuk sand in the Char 1 well calculated a BHP of 4300 psi. The abnormal pressure in the Char well is predicted to be coming from CD2 -02 Apine Injection well to the south of the Char 1 well. CD2 -02 is the farthest reaching north/northwest well, closest to Char 1, and CD2 -02 toed up at the toe of well. It is likely CD2 -02 penetrated Kuparuk C lag sands during the toe up and allowing for pressure communication to the Char 1 well. That being said, there are major faults between Char 1 well location and Rhea 1 location. Rhea 1 is roughly 22000 ft away from Char 1. It is unknown if the faults between Char 1 and Rhea 1 are baffling or not. There is a good chance we will see normally pressured sands at the Rhea 1 location, but in the instance the faults between Char 1 and Rhea 1 are not baffling and CD2 -02 injection charged up a large area of the Fiord West Kuparuk Sands, we are prepared for the abnormal pressure seen at the Char 1 well location. I don't have any information regarding H2S measurements for any of the pools in the Colville River Unit. Have any development wells in the vicinity of Rhea 1 been tested for H2S? If so, could you please provide those H2S measurements? CD3 -127 is the closest development well to Rhea 1 at little over 5000 ft away. It had an H2S test performed on 9/3/2018 with a reading of 80 ppm. As far as Doyon 25 H2S equipment in use during the Rhea1 well, we will have our standard H2S monitoring equipment on the rig, plus we will have full Mud logging from spud to TD of the well in all sections of the well, and all personnel on the rig are required to wear personal H2S monitors as a standard operating procedure on Doyon Rig 25 Every six months, the AOGCC receives a copy of the H2S measurements acquired for wells in the Kuparuk River Unit. Does CPAI regularly test wells for H2S within the CRU as they do in the Kuparuk River Unit? If so, could we please get a copy of the measurements from CRU wells? As a drilling engineer I am unfamiliar with the H2S testing regimen for Alpine wells. This question would be more appropriately answered by the Alpine Production Engineers. Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.aov.From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, January 8, 2020 4:20 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: Text Directional Plans for Rhea 1 PTD Application Hi Steve, I attached .txt file of the Rhea 1 directional plan to aid in review of the Rhea 1 PTD application. Please note the XY's on the .txt file are in State Plane NAD 83 coordinates. Thanks and let me know if there is anything else you need from me, tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com AOGCC PTD No. 220-002 Coordinate Check 9 January 2020 INPUT Geographic, NAD27 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Rhea 1 1/1 Latitude: 70 23 19.36785 Northing/Y: 5992780.642 Longitude: 151 00 22.93100 Easting/X: 376281.371 Convergence: -0 56 52.80930 Scale Factor: 0.999917387 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Z --Z- ._ ,w - Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional l FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. (If last two digits API No. 50 - Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs Pilot Hole acquired for the pilot hole must be clearly differentiated in both well name ( PIS 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. Spacing Exception Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no—greater- than 30' sample intervals from below the permafrost or from where sam les are fust caught and 10' sam le intervals throu target zones. Please note the following special condition of this permit: Non -Conventional Production or production testing of coal bed methane is not allowed for (name of well? until Well after (CompaAYName) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Compan Namemust contact the AOGCC to obtain advance a roval 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 i/ 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 da s after com letion, su rasion or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD OIL - 120120 -- Engineering Well Name: COLVILLE RIV UNIT RHEA 1 _ Program DEV - _ _ _ Well bore seg ❑ PTD#:2200020 Company ConocoPhillips Alaska_ Inc. _- _ - -_ Initial Class/Type DEV/PEND - GeoArea 890 _- Unit 50360 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well located in ADL 25526. - 3 Unique well name and number Yes - - - 4 Well located in a defined pool - Yes COLVILL_E- RIVER, -FIORD OIL_- 120120, governed by CO 569 5 Well located proper distance from drilling unitboundaryYes Conservation Order No. 569 contains no spacing restrictions except wellbore must be more than 500' 6 Well located proper distance from other wells Yes from an external property line -where -ownership or landownership changes. As planned, well 17 Sufficient acreage available indrillingunit Yes conforms to spacing requirements. - 8 If deviated, is wellbore plat included Yes Nearest well is Nechelik-1, which is 5000' ENE. 9 Operator only affected party Yes 10 Operator has appropriate_ bond in force Yes Ill Permit can be issued without conservation order Yes ----------------------- Appr Date12 Permit -can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 1/9/20, 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 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 Nonconven. gas conforms to AS31.05.0300A.A),0,2_.A-D) - - - - NA 18 Conductor string provided Yes 110'- conductor set - Engineering 19 Surface casing protects all -known USDWs Yes Surface casing set to 2455' MD 20 CMT vol adequate to circulate on conductor & surf csg Yes 166% excess cement planned - - - - - 21 CMT vol -adequate -to tie-in long string to surf csg No 22 CMT will cover -all knownproductivehorizons Yes well is pilot hole, will log C -sand and -then place reservoir plug; P&A planned post rig - - - - 23 Casing designs adequate for C, T, B & permafrost - - - Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If -a re -drill, has a 1-0-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations Yes Diverter route and size_ meet regulations - Appr Date 28 Drilling fluid program schematic & equip list adequate - - Yes Max formation pressure is -4400 psig(11.8 ppg EMW); will drill w/ 11.8 ppg EMW -utilizing -MPD - VTL 1/16/2020 29 BOPEs, do they meet regulation - - Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3681 psig; will test BOPS to 3800-psig - 31 Choke manifold complies w/API-RP-53 (May 84)- Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas- probable Yes 34 Mechanical condition of wells within AOR verified (Forservicewell only) NA 35 Permit can be issued w/o hydrogensulfidemeasures - No Measures required:_ CD3 -127 closest development well to Rhea 1 (_5000' away) measured 80 ppm 1-12S on 9/3/201 Geology !36 Data -presented on potential overpressure zones Yes Gradient of 0.45 psi/ft (-8.7 ppg EMW) expected down through HRZ. Target Kup C sands expected to -be Appr Date 37 Seismic analysis of shallow gas -zones - - NA 0.61 psi/ft (-11.8 ppg EMW) due to nearby injection in Fiord Oil Pool. PI_annedmud_program appears to -be - SFD 1/17/2020 38 Seabed condition survey -(if off -shore) NA_ sufficient to manage expected pressures._ MPD planned for intermediate and production hole 39 Contact name/phone for weekly progress reports [exploratory only] - Yes sections to manage pressure and maintain -wellbore stability. Tom Polasek 907-263-3740 - - Geologic Date: Engineering Public Atypical "development" well: vertical well that will be drilled from an ice pad to delineate a potential Kuparuk C Sand reservoir nCommissioner: _ 1, ( %� zC� Commissioner: �C lDate/ !/ 2 �r �� Commi io 1 1�D%ate near the SW edge of the Fiord Oil Pool. Rhea 1 will be drilled, logged, then plugged and abandoned prior to the end of the 2020 1 1 ice pad season. Classified as a development well because it is being drilled to a known, productive pool. (See 20 AAC 25.990(18).) SFD