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219-034
January 8, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Fourth Quarter, 2020 To whom it may concern: Please find attached the fourth quarter 2020 annular disposal reports for the Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2020. With no rig activity due to the COVID 19 pandemic until December 15, 2020, injectivity testing on current and expired annuli was the only activity to determine disposal options. Tests were on the wells closest to CD5-90. A test on CD5-98, with an active sundry failed. A test completed on CD5-92 to investigate a new sundry for disposal appeared promising but failed in the end. These injectivity tests conclusively determined that CD5-92 and CD5-98 are not suitable for disposal anymore. CD5-26 remains the only well that might be used in the future as the rig moves to CD5- 31 in March 2021. It was not tested recently as it is farthest from the current drilling operations on CD5-90. Successful results of a test on CD5-26 and a request for an extension of the AD sundry on this previously approved but since unused annulus will potentially follow. If the test proves the well will not take injectivity, the final correspondence for it will be a final 1Q report as the sundry expires in March 2021. Please call Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. S. Hobbs Regulatory Engineer G. S. Hobbs Regulatory Engineer Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Greg Hobbs DN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021-01-08 12:41:27 Foxit PhantomPDF Version: 10.0.0 Greg Hobbs 219-0347. Well Name:50-5a. Sundry Number:319-50110(h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls):Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):3000713711 09/22/19 09/22/19Initial Water Flush(300 bbl) and Freeze Protect Diesel (71 bbl)2020/Q16435.50976532.55 03/11/20 03/15/20 CD5-90 2020/Q20000 n/a n/an/a n/a - Pandemic shutdown2020/Q3001.91.91 09/21/20 09/21/20n/a - Injectivity test - Failed. Well will not be used for further disposal2020/Q4006.36.31 12/15/20 12/15/20n/a - Diesel injectivity test completed by the rig (CD5-90). Failed. New sundry not pursued.Total Ending Volume (bbls):6735.50176.26911.78Other (Explain) Printed Name:Title:Phone Number:(907) 263-4749Initial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJWINJWDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:I hereby certify that the foregoing is true and correct to the best of my knowledge.Regulatory EngineerSignature:Date:1/8/2021G. Hobbs12. Remarks and Approved SubstancesDescription(s):Diesel for Freeze Protection5b. Sundry approval date:11/22/2019Report is due on the 20thof the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter.11. Attach: Disposal Performance Data: Pressure vs. TimeStep Rate Test 9. Field:Colville River Unit3. (Check one box only)ConocoPhillips Alaska, Inc.2. Address:4b. Well Status: Oil Gas WAG 103-20800-00-00CD5-92PO Box 100360, Anchorage, AlaskaG StForm 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in DuplicateDigitally signed by Greg HobbsDN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2021-01-08 12:47:35Foxit PhantomPDF Version: 10.0.0Greg HobbsRBDMS HEW 1/25/2021 October 13, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Third Quarter, 2020 To whom it may concern: Please find attached the third quarter 2020 annular disposal reports for the Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the third quarter of 2020. With no rig activity due to the COVID 19 pandemic, the only activity on our three active Annular Disposal permits were injectivity tests. These injectivity tests determined that the only well that might be used in the future is CD5-26, a newly permitted well late in the first quarter, but not used to date. The first report is attached for this well noting this test. Please call Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. S. Hobbs Compliance and Regulatory Engineer G. S. Hobbs Compliance and Regulatory Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Greg Hobbs DN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-13 15:07:12 Foxit PhantomPDF Version: 10.0.0 Greg Hobbs 219-0347. Well Name:50-5a. Sundry Number:319-50110(h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls):Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):3000713711 09/22/19 09/22/19Initial Water Flush(300 bbl) and Freeze Protect Diesel (71 bbl)2020/Q16435.50976532.55 03/11/20 03/15/20 CD5-90 2020/Q20000 n/a n/an/a n/a - Pandemic shutdown2020/Q3001.91.91 09/21/20 09/21/20n/a - Injectivity test - Failed. Well will not be used for further disposalYYYY/Q#Total Ending Volume (bbls):6735.5169.96905.47Other (Explain) Printed Name:Title:Phone Number:(907) 263-4749ConocoPhillips Alaska, Inc.2. Address:4b. Well Status: Oil Gas WAG 103-20800-00-00CD5-92PO Box 100360, Anchorage, Alaska12. Remarks and Approved SubstancesDescription(s):Diesel for Freeze Protection5b. Sundry approval date:11/22/2019Report is due on the 20thof the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter.11. Attach: Disposal Performance Data: Pressure vs. TimeStep Rate Test 9. Field:Colville River Unit3. (Check one box only)I hereby certify that the foregoing is true and correct to the best of my knowledge.Compliance and Regulatory EngineerSignature:Date:10/13/2020G. HobbsInitial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJWINJWDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:G StForm 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in DuplicateDigitally signed by Greg HobbsDN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2020-10-13 15:18:39Foxit PhantomPDF Version: 10.0.0Greg HobbsRBDMS HEW 12/7/2020 July 1, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Second Quarter, 2020 To whom it may concern: Please find attached the second quarter 2020 annular disposal reports for the Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the second quarter of 2020. The disposal permit for CD5-24 expired in the second quarter of 2020. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. L. Alvord Alaska Drilling Manager G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 G. L. Alvord Digitally signed by G. L. Alvord Date: 2020.07.01 16:13:39 -08'00' 219-0347. Well Name:50-5a. Sundry Number:319-50110(h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls):Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):3000713711 09/22/19 09/22/19Initial Water Flush(300 bbl) and Freeze Protect Diesel (71 bbl)2020/Q16435.50976532.55 03/11/20 03/15/20 CD5-90 2020/Q20000 n/a n/an/a n/a - Pandemic shutdownYYYY/Q#YYYY/Q#Total Ending Volume (bbls):6735.51686903.56Other (Explain) Printed Name:Title:Phone Number:(907)265-6120ConocoPhillips Alaska, Inc.2. Address:4b. Well Status: Oil Gas WAG 103-20800-00-00CD5-92PO Box 100360, Anchorage, Alaska12. Remarks and Approved SubstancesDescription(s):Diesel for Freeze Protection5b. Sundry approval date:11/22/2019Report is due on the 20thof the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter.11. Attach: Disposal Performance Data: Pressure vs. Time Step Rate Test 9. Field:Colville River Unit3. (Check one box only)I hereby certify that the foregoing is true and correct to the best of my knowledge.Drilling ManagerSignature:Date:7/1/2020G.AlvordInitial DisposalContinuation Final4a. Well Class:StratigraphicService GINJWINJWDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6.Permit to Drill Number:8. API Number:1. Operator:G StForm 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDESubmit in DuplicateG. L. AlvordDigitally signed by G. L. Alvord Date: 2020.07.01 16:31:35 -08'00'RBDMS HEW 7/14/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20800-00-00Well Name/No. COLVILLE RIV UNIT CD5-92Completion Status1-OILCompletion Date10/9/2019Permit to Drill2190340Operator ConocoPhillips Alaska, Inc.MD28591TVD7317Current Status1-OIL5/28/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/Res/CBLNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC10/28/201943 2256 Electronic Data Set, Filename: CPAI_CD5-92_Scope_GammaRay_RM_LWD001.las31375EDDigital DataC10/28/201912241 28560 Electronic Data Set, Filename: CPAI_CD5-92_Scope_Resistivity_RM_LWD005.las31375EDDigital DataC10/28/20192216 2372 Electronic Data Set, Filename: CPAI_CD5-92_VISION_Resistivity_RM_LWD002.las31375EDDigital DataC10/28/20192066 2256 Electronic Data Set, Filename: CPAI_CD5-92_VISION_Resistivity_RM_LWD002_ReamDown 1.las31375EDDigital DataC10/28/20192316 11514 Electronic Data Set, Filename: CPAI_CD5-92_VISION_Resistivity_RM_LWD003.las31375EDDigital DataC10/28/201911447 12306 Electronic Data Set, Filename: CPAI_CD5-92_VISION_Resistivity_RM_LWD004.las31375EDDigital DataC10/28/201943 28590 Electronic Data Set, Filename: CPAI_CD5-92_Scope_Resistivity_RM.las31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Gamma_Ray_LWD001_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_LWD005_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_VISION_Resistivity_LWD002_ReamDown 1_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_VISION_Resistivity_LWD002_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_VISION_Resistivity_LWD003_RM.dlis31375EDDigital DataThursday, May 28, 2020AOGCCPage 1 of 3CPAI_CD5-,92_Scope_Resistivity_RM.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20800-00-00Well Name/No. COLVILLE RIV UNIT CD5-92Completion Status1-OILCompletion Date10/9/2019Permit to Drill2190340Operator ConocoPhillips Alaska, Inc.MD28591TVD7317Current Status1-OIL5/28/2020UICNoC10/28/2019 Electronic File: CD5-92_VISION_Resistivity_LWD004_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_RM.dlis31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_2MD_RM.Pdf31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_2TVD_RM.pdf31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_5MD_RM.pdf31375EDDigital DataC10/28/2019 Electronic File: CD5-92_Scope_Resistivity_5TVD_RM.Pdf31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD27 EOW Compass Surveys [Canvas].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD27 EOW Compass Surveys [Macro].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD27 EOW Compass Surveys [Petrel].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD27 EOW Compass Surveys [Survey].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD27 EOW Compass Surveys.pdf31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD83 EOW Compass Surveys [Canvas].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD83 EOW Compass Surveys [Macro].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD83 EOW Compass Surveys [Petrel].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD83 EOW Compass Surveys [Survey].txt31375EDDigital DataC10/28/2019 Electronic File: CD5-92 NAD83 EOW Compass Surveys.pdf31375EDDigital Data0 0 2190340 COLVILLE RIV UNIT CD5-92 LOG HEADERS31375LogLog Header ScansC11/13/2019 Electronic File: CONOCOPHILLIPS NORTH SLOPE - CD5_92_GWPC Post Job.pdf31435EDDigital DataThursday, May 28, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20800-00-00Well Name/No. COLVILLE RIV UNIT CD5-92Completion Status1-OILCompletion Date10/9/2019Permit to Drill2190340Operator ConocoPhillips Alaska, Inc.MD28591TVD7317Current Status1-OIL5/28/2020UICNoWell 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:10/9/2019Release Date: 2/28/20190 0 2190340 COLVILLE RIV UNIT CD5-92 LOG HEADERS31435LogLog Header ScansDF5/13/2020 Electronic File: ConocoPhillips_CD5-92_SonicScope_Top_of_Cement.pdf33030EDDigital Data0 0 2190340 COLVILLE RIV UNIT CD5-92 LOG HEADERS33030LogLog Header ScansDF5/27/20203750 12307 Electronic Data Set, Filename: CPAI_CD5-92_SonicScope_TOC_3750-12307ft.las33030EDDigital DataThursday, May 28, 2020AOGCCPage 3 of 3M. Guhl5/28/2020 Transmittal #1274 Detail Date: 5/13/2020 To (External Party):From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*:Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone Number:(907) 793-1235 Phone Number: (907) 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 West 7th Ave.Address: 700 G Street City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: FTP Tracking #: Justification: Data Detail Quantity*:Description*:Type*: 1 CD5-92 SonicScope Top of Cement PDF Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ Received by the AOGCC 05/13/2020 Abby Bell Abby Bell 05/13/2020 PTD: 2190340 E-Set: 33030 ConocoPhillips April 9, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, First Quarter, 2020 To whom it may concern: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 (2t - o3y Please find attached the first quarter 2020 annular disposal reports for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the first quarter of 2020. The MT6-05 annular disposal permit expired in the first quarter of 2020. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, Digitally signed by G. L. Alvod G. L. Alvord Dater 2020.040915:42:10 08'00' G. L. Alvord Alaska Drilling Manager SCANNEa 0 13 2020 I' U) J LL O Q U) 177-& N Ln r E 0 N O LL a O i6 m p N m cn p-0 O c N LL° y O O lB C N co Cl) >m cu Z3 CN rn w c ca O rn o p m `y N o ai c i6 N 'n O ZS p = a E W N C0 O O 0 a- LLz o M t°/ni D U o v o z Oi/i +�., w O N Ln m = ` N 0 E d N co N r O 0 O Z 7 Z a O .E O O -Q N O n •i U d Q U -m .,. O 6 r-� ao 16 ° m Q rn _ Ln o o CIJ ° o N ❑ N a; N L T O E v Lon U d U ❑ Q 16 7 '0 7 •O UO Z NJ > l° l° U) 0- o OL y M N M f0 � to 0 (O m C ❑ W a E ❑ 7 7 c L (� ❑ .6 N > _ n YO 00 a ❑� ° v ❑ W N v E o El N V A C N y y E 7 N.0 C L 7 0 N C f6 Z O y Q U E � Z M d `o n d O m > y Q N .O U) p� CL a ElO v V� Cd M ° Y y 3 E a E L U F N O ❑ 3Em LL y o a <g rn o (D 7 m .. C_ 3 LL N N Q d o v ❑ R W U d C LO IA M N C L]U y C @ d O C C_ __ >` O O M Lq Ln M ° — 7 :D f0 O CO frl-° y 7 n y c C N E C y N O C C 7 0 C O y d f0 j C Q ai o U Ea)Em °' 3 a x -o m Q 6 c rn m y O n E Z` W m o y uU a LO oc ° J c ° c EGO) Q °o Q Q x❑� E > Q m N .. LO coc U v 00 ;C @ IL O y O y O O Y n U y O) N .. t C m O O N N U y 7 .. Xk Xk ik y 0 CL X m r p o o y '> O O a 5 E E y O U 7 m E n O � 6 � m N d Z O O c 0 a 0a V @ E o a o o F c o m W> v Q" C rn r C� n. ri c N O U)U 177-& N Ln r E ConocoPhillips January 8, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Fourth Quarter, 2019 To whom it may concern: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 6D5_-92 (211 -0`5v) Please find attached the fourth quarter 2019 annular disposal reports for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2019. No annular disposal permits expired in the fourth quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. L. Alvord Alaska Drilling Manager JAN 10 2020 A®GCC ICANNED JAN 7 61010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 219-034 ConocoPhillips Alaska, Inc. Development 11 Exploratory ❑ 7. Well Name: CD5-92 2. Address: 4b. Well Status: Oil ❑✓ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20800-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑✓ or Continuation ❑ or Final ❑ 319-501 11/22/2019 Colville River Unit 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement -contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 0 0 0 0 0 N/A N/A N/A 2019/1st 0 0 0 0 0 N/A N/A N/A 2019 2nd 0 0 0 0 0 N/A N/A N/A 2019 / 3rd 0 0 0 0 0 N/A N/A N/A 2019 / 4th 0 0 0 0 0 N/A N/A N/A Total Ending Report is due on the 20th Volume o 0 0 0 o of the month following the final month of the quarter. Ex: (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): No Disposal Injection in 2019 1 hereby certify that the foregoing is true and correct to the best of my knowledge. pp Signature: A r /� Chip Alvord Date: L C�( (Z Za RBDM�--' �� N 14 7� l• Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate THE STATE ( 'ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD5-92 Permit to Drill Number: 219-034 Sundry Number: 319-501 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ti Price Chair DATED this day of November, 2019. IBDMS 41� NOV 2 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 RECEIVED NOV 0 5 2019 AOGCV 1. Operator 3. Permit to Drill Name: 219-034 ConocoPhillips Alaska 4. API Number: 50-103-20800-00-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD5-92 6. Field: Colville River Unit- Alpine Pool 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, Torok and Seabee formation, shale, siltstone and sandstone CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-313, CD5-314X, CD5-315, CD5-316, CD5-98, CD5-99 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,323' MD and 1,320' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2094 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. • Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 16. Estimated start date: 15 -Dec -19 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Cement Bond Log (if required) ❑ FIT Records w/LOT Graph 0 Surf. Casing Cementing Data El Other ❑' previous authorization for new product cleanup fluids for CD1 and CD2 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: - - Title: Drilling Manager Printed Phone Name: Chip Alvord Number: 265-6120 Date: Commission Use Only Conditions of approval: LOT review and approval: (" _ ✓� Subsequent form required: Approval number: 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: r .� // 1/1P6' a/� i Form 10-403A ev 6/ 4 IN R TI O E E S M16_R2 v Submit in Duplicate G� 1i 113/2Ul`i 1� II�ltlr� IG �NA� ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 5, 2019 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-98 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-92 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD5-92 approximately December 15, 2019 or earlier depending on permit approval status. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Plan View of Adjacent Wells 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job . 9. Formation LOT on 10-3/4" x 7-5/8" casing annulus 10. List of wells on CD5 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within 'Amile radius at AOGCC: CD5-01, CD5-02, CD5-03, CD5-04, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, C135-1 1, CD5-12, CD5-17, CD5-19, CD5-20, C135-2 1, CD5-22, CD5- 313, CD5-314X, CD5-315, C135-316, CD5-23, CD5-24, C135-25 12. Information regarding remaining wells within'/4 mile radius included in sundry package: CD5-98 13. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The annular LOT (14.6 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (18.6 ppg). Therefore, we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be more than the shoe FIT. If you have any questions or require further information, please contact Andrew Beat at 265-6341 or Chip Alvord can also be reached by calling 265-6120. Si erely, Andre at Drilling Engineer cc: C135-92 Well File Chip Alvord ATO -1570 Annulus Disposal Transmittal Form - Well CD5-92 AOGCC Regulations. 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD5-92 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1320' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443. March 15, 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be um ed is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2117 psi. See attached calculation calculations showing how this value was determined. page - 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anti ci ated ressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the The top of primary cement is 10,960' MD and top of depth to which the inner casing is cemented. secondary cement is estimated at 5,300' MD in the intermediate casing which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this depth 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD5-96, CD5-90, CD5-28, CD5-27 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com fiance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Well CD5-92 Date 11/5/2019 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 10 3/4" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi 2,189 TVD TOC Est. @ 5,300' MD 4,029' TVI IOC Est. @ 10,960' MD Version 3.0 - 1.n'18 Pburst85% — PHydrostatic + PApplied - PFormation 4,429 = ( 2,189 * 0.052 * M Wmax ) + 1500 ( 0.4337 * 2,189 ) MW„,ax = 34.1 ppg Surface Casing String MW... = 11.2 Size 10.75 in Weight 45.5 ppf Grade L 80 Weight rburstl00% 5,210 psi Pburst85% 4,429 psi Depth of Shoe 2,189 ft TJ h FIT/LOT @ Shoe 18.6 ppg or 2,117 psi FIT/LOT for Annulus 14.6 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Densitv avoid Collapse of 2nd Casiniz Strin Pcollapse85% — PHydrostatic + PApplied - PGasGradient - PHeader 4,072 =( 6,966- 0.052 - M Wmax ) + 1,500 ( 0,0700 * 6,966) - 1,000 MW... = 11.2 ppg 2nd Casing String Size 7.625 in Weight 29.7 ppf Grade L 80 rcollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 6,966 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable — Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable — ( 2,189 *.052 * 18.6 ) Pmax allowable — 2,117 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". N 0) N 1� u v O Co N O LO O T O O O O O O Ln O LO LO O T T (+)gIAON/(-)ulnoS r CD5-92, 10-3/4", Surface Casing Well: CD5-92 10-314" 45.5# L-80 TXP-M Casin ConocoFfi lipsRig: Alaska, Inc. FINAL Date: 9/8/2019 Doyon 25 Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws Doyon 25 RKB to top of Landing Ring 39.14 FMC 10-3/4" Casing Hanger .13 39.14 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X H563 Pin 2.54 39.27 Full length XO A 10-3/4", 45.5#, L-80, BTCM Pin X H563 Box 37.80 41.81 Jts 3 to 56 54 Jts 10-3/4", 45.5#, L-80, TXP-M Casing 2081.10 79.61 10-3/4" To co BTCM Float Collar 1.48 2160.71 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, TXP-M Casing 81.08 2162.19 10-3/4" To co BTCM Shoe 2.83 2243.27 2246.10 2246.10 2246.10 2246.10 2246.10 2246.10 10-3/4" Shoe at 2,246' MD 2,188' TVD 2246.10 13-1/2" TD at 2,256' MD, 2,197' TVD 10' rathole 2246.10 2246.10 2246.10 2246.10 2246.10 2246.10 1 Centek 10' up from shoe w/stop rings on Jt #1 2246.10 1 Centek 30' up from pin w/stop rings on Jt #2 2246.10 1 Centek 20' up from pin w/stop rings on Jt #3 2246.10 1 Centek centralizer every joint from #4 to #15 Floating 2246.10 1 To co bowspring every Jt from #16 to #55 over coupling 2246.10 2246.10 2246.10 2246.10 2246.10 Total Centralizers 2246.10 15 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2246.10 (40) Top -Co PN 300-273-434 10.75" x 13-5/8" bowsprings 2246.10 2246.10 2246.10 Remarks: Up Wt 130 K MU Tq with Volant -1-1563 Doped to 16,200 ft/lbs w/ Seal Guard ECF, TXP-M to 27,160 ft/lbs w/ Run N Seal Down Wt 125 K Bakerlocked to pin end of jt #4 Block Wt 43 K Drifted with 9.875" drift Rig Supervisors: K. Harding / P. Castro Cement Detail Report CD5-92 String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/4/2019 04:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/8/2019 20:00 9/9/2019 00:00 CD5-92 Comment PJSM Flooded lines from cementers and pressure tested 3,500 psi (good). Pumped 75 bbis mud push Staged up to 4 6 bpm (170 psi) Dropped top plug 11 0 ppg Lead Cement (Batched at 21:23 hr) Pumped a total of 285.5 bbls @ 4.6 bpm @ 500 psi Pumped 59 05 bbls of 15 8 ppg tail cement (Batched at 23 00 hr) Dropped top plug Swapped to rig pumps Pumped at5-8 bpm Reduced pump rate to 3 bpm (450 psi) and bump the plug at 1845 strokes with at a final pressure of 1,000 psi Held for 5 minutes Floats held. Cement returns to surface = 144 bbls. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement.., Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4" 45.5 L-80 39.1 2,246.0 Yes 1440 Yes Yes TXP Surface Casing Q Pump [nit (bblim.. Q Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 5 5 450.0 1,000.0 1 Yes I 30.00 No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment P.ISM Flooded lines from cementers and pressure tested 3,500 psi (good) Pumped 75 bbfs mud push Staged up to 4.6 bpm (170 psi). Dropped top plug. 11.0 ppg Lead Cement (Batched at 21 23 hr) Pumped a total of 285 5 bbis @ 4 6 bpm @ 500 psi. Pumped 59.05 bbls of 15 8 ppg tail cement (Batched at 23:00 hr). Dropped top plug. Swapped to rig pumps Pumped at5-8 bpm Reduced pump rate to 3 bpm (450 psi) and bump the plug at 1845 strokes with at a final pressure of 1,000 psi Held for 5 minutes Floats held Cement returns to surface = 144 bbls. Full returns 15 Centek Centralizers (10 3/4" x 13 1/2") 40 Top Co Centralizers (10 3/4" x 13 1/2") ND, perform Halliburton Conductor LockCem Top-up job in top 2' of conductor Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 00 1,455.1 385 DeepCrete 3850 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1 91 6.65 1080 211.1 4.04 Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,455 1 2,2460 285 G 285.0 Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.51 15.70 113.9 3.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/5/2019 L (6 E E n CO ► o 0 0 0 0 c o_ 0 0_ o_ o_ o_ o_ o_ c_ N O N O N O N O N O t'J N O cal, T�-`," O _o O _o O 0 0 0 0 0 0 _o 0 0 _o 0 0 Y N — cl- E M� M�M � •.. -6 'a W cu c >, a+ � Cn = O O LO N 0 Ln 0 O 0 LO 0 0 O LO 0 O O Ln O O O LO O O 0 LO 0 O 0 LO 0 O 0 LO 0 O 0 LO 0 O 0 LO 0 O> O LO (n N X CL O O O T N N co M q q Ln Ln (p (p f. r M M 0) O O m E m d C — p N 0 0 0 0 0 0 0 0 0 0 0 O O O O Cl O O O O O O Q O O Q O O O O .Q N(ONi� ONL)CO Ln 00 �rOMI- OMI� NLONON(OO N N O O TNN MMMM cr 1. Lo LOLO(o(0(0Il-rIMW COaOOOOmOO -a N TCDdm U Q E 7 = N V CO CO M O T N M V Ln O f� OJ O O r N M d' LO (p I-- M O O T N CO'1 U CL d T T �- N N N N N N N N N N M M CO CO M; Operations Summary (with Timelog Depths) CD5-92 r r •' Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/7/2019 9/7/2019 2.50 SURFAC DRILL DDRL P Drilled 13 112" surface hole from 2,030.0 2,256.0 12:00 14:30 2,030' MD to 2,256' MD (2,198' TVD). Parameters: Flow 775 gpm, SPP 2,150 psi, F/O 80%, Surface Rotary 60 rpm, Torque 3-12 kftlbs, WOB 12 klbs, AST = 0.45, ART = 1. 17, and ADT = 1.62. Total bit hours = 12.45, Total Jars = 9.93. P/U Wt = 105 klbs, S/O Wt = 106 klbs, and Rot Wt = 104 klbs. Pumped 40 bbl NP sweeps last two stands before TD.. 9/7/2019 91712019 0.75 SURFAC CASING SRVY P Took MWD survey at TD. P/U onee 2,256.0 2,256.0 1430 15:15 joint and dropped Gyrodata tool. 9/7/2019 9/7/2019 1.50 SURFAC CASING CIRC P CBU 4X w/ 40 bbl NP sweep. Stood 2,256.0 1,885.0 15:15 16:45 back one stand each. BROOH from 2,256' MD to 1,885' MD. 775 gpm, 2,245 psi, 50 rpm, and 2 kftlbs TQ, Took recorded gyro surveys at connections. 9/7/2019 9/7/2019 0.50 SURFAC CASING OWFF P OWFF for 30 minutes (Static). 11885.0 1,885.0 16:45 17:15 9/7/2019 917/2019 0.75 SURFAC CASING TRIP P POOH from 1,885' MD to 1,654' MD. 1,885.0 1,654.0 17:15 18:00 Monitored hole on pit#3. P/U Wt = 110 klbs, S/O Wt = 99 klbs 9/7/2019 9/7/2019 3.00 SURFAC CASING TRIP P POOH from 1,654' MD to 660' MD. 1,654.0 660.0 18:00 21:00 Monitored hole on pit#3. OWFF at BHA (Static) 9/7/2019 917/2019 2.00 SURFAC CASING BHAH P Racked back HWDP and Collars. 660.0 157.0 21:00 23:00 Removed gyro tool. 9/7/2019 9/8/2019 1.00 SURFAC CASING BHAH P UD BHA#1 as per Schlumberger 157.0 0.0 23:00 00:00 Rep. 9/8/2019 9/8/2019 0.50 SURFAC CASING BHAH P LD BHA per SLB DD/MWD. 0.0 0.0 00:00 00:30 9/8/2019 9/8/2019 1.00 SURFAC CASING BHAH P Clean/Clear floor, LD BHA. PU Casing 0.0 0.0 00:30 01:30 equipment. 9/8/2019 9/8/2019 1.00 SURFAC CASING RURD P RU Volant w/ swivel and casing 00 0.0 01:30 02:30 running equipment 9/8/2019 9/8/2019 3.50 SURFAC CASING PUTB P PJSM. Baker locked shoe 0.0 621.0 02:30 06:00 track,checked floats, ran 10 3/4" L-80 45.5 ppf as per plan from surface to 621' MD. Torqued every joint to 27 kftlbs. Filled every joint and topped off every 10th joint. 9/8/2019 9/8/2019 3.00 SURFAC CASING PUTB P Continued to run 10 3/4" L-80 45.5 ppf 621.0 1,480.0 06:00 09:00 casing as per plan from 621' MD to 1,480' MD. Torqued every joint to 27 kftlbs. Filled every joint and topped off every 10th joint. S/O Wit = 70 klbs. 9/8/2019 9/8/2019 1.00 SURFAC CASING CIRC P Circulated and conditioned mud below 1,480.0 1,480.0 09:00 10:00 the permafrost while reciprocating pipe from 1,480' MD to 1,439' MD. Staged up pumps to 8 bpm. ICP = 250 psi, 2 bpm = 140 psi, 4 bpm = 148 psi, 6 bpm = 160 psi, 8 bpm = 190 psi. P/U Wt = 96 klbs, and S/O Wt = 75 klbs. 9/8/2019 9/8/2019 2.00 SURFAC CASING PUTB P Continued to run 10 3/4" L-80 45.5 ppf 1,480.0 2,049.0 10:00 12:00 casing as per plan from 1,480' MD to 2,049' MD. Torqued every joint to 27 kftlbs. Filled every joint and topped off every 10th joint. S/0 Wit = 75 klbs. Page 3131 ReportPrinted: 11/5/2019 Operations Summary (with Timelog Depths) CD5-92 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/8/2019 9/8/2019 0.50 SURFAC CASING PUTB P Continued to run 10 3/4" L-80 45.5 ppf 21049.0 2,230.0 12:00 12:30 casing as per plan from 2,049' MD to 2,230' MD. Torqued every joint to 27 kftlbs. Filled every joint and topped off every 10th joint. S/O Wit = 80 klbs. 9/8/2019 9/8/2019 1.00 SURFAC CASING HOSO P WU Hanger and attempted tp M/U 2,230.0 22300 1230 1330 landing joint. Noticed bad O -Ring. LID and redressed. Circulated and reciprocated from 2,230' MD to 2,218' MD at 1 bpm and 415 psi. P/U Wt = 109 klbs, and S/O Wt = 78 klbs. 9/8/2019 9/8/2019 0.75 SURFAC CASING HOSO P M/U landing joint. Measured and 2230.0 2,246.0 1330 14 15 1 Panded hanger 2,246' MD. 9/8/2019 9/8/2019 3.00 SURFAC CEMENT CIRC P Established circulation and 2,2460 2,246.0 1415 17 15 reciprocated from 2,230' MD to 2,246' MD @ 3bpm (420 psi) on the up stroke, and no pumps on the down stroke until circulation was reestablished. P/U Wt = 123 klbs, and S/O Wt = 120 klbs. Circulation was reistablished at 15:30 hr. Staged up the pumps to 8 bpm. 9/8/2019 9/8/2019 2.75 SURFAC CEMENT CIRC P Shut down B/D top drive and swapped 2,2460 2.2460 17.15 2000 to cement lines. Reestablished circulation and staged up to 8 bpm. Reciprocated pipe from 2,230' MD to2,246' MD. 9/8/2019 9/9/2019 4.00 SURFAC CEMENT CMNT P PJSM. Flooded lines from cementers 2,2460 2,246.0 20:00 0000 and pressure tested 3,500 psi (good). Pumped 75 bbls mud push. Staged up to 4.6 bpm. (170 psi). Dropped top plug. 11.0 ppg Lead Cement. Pumped a total of 285.5 bbls @ 4.6 bpm @ 500 psi. Pumped 59.05 bbls of 15.8 ppg tail cement. Dropped top plug. Swapped to rig pumps. Pumped at5-8 bpm. Reduced pump rate to 3 bpm (450 psi) and bump the plug at 1845 strokes with at a final pressure of 1,000 psi. Held for 5 minutes. Floats held. Cement returns to surface = 144 bbls. Full returns. 9/9/2019 9/9/2019 6.00 SURFAC CEMENT WWWH P Flushed riser, bag, and flow line. 2.246.0 2,2460 0000 0600 Opened flow line hatches to clear cement. Cleared shakers/mud through and cuttings pit. RID Volant, LID landing joint. Cleaned cellar box. Flushed bag and hanger flutes. Cleaned flow box. RID surface bag, and Mouse Hole/Shrew Hole. Removed surface bag, and riser. Cleaned pits. 9/9/2019 9/9/2019 1.00 SURFAC CEMENT CLEN P Removed diverter tee and Slip -Lok 2,2460 2,246.0 06-00 07:00 adapter. Emptied cellar box. Continued to clean pits. 9/9/2019 9/9/2019 3.25 SURFAC CEMENT CMNT P Prepped cellar for Epoxy/cement cap 2,2460 2,246.0 07.00 10:15 job. Flushed and cleaned conductor x surf casing annulus and 4" conductor outlets.Waited on more dry cement W SIMOPS and performed EPDXY/cement cap as per Halliburton Rep. SIMOPS: LD riser equip from floor, M/U riser adapters, C/O air boots on flow lines, and continued to clean pits. (1.5 hrs for epoxy job) Page 4/31 Report Printed: 11/5/2019 CD5-92 7-5/8" Intermediate casing Well: CD5-92 7 5/8" 29.7# 39# L80 TXP Casing ConotoPhillips alaska,Innc. Date: Rig: 9/21/2019 Doyon 25 De pth Jt Number Joints i Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 36.87 FMC 7.625" fluted hanger .72 36.87 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.42 37.59 7-5/8" 29.7#, L80, H563 box x TXP pin XO 39.73 40.01 its 155 to 304 150 its 7-5/8", 29.7#, L-80 TXP Casing 5994.05 79.74 7-5/8", HES 2 Stage Cementer Sub97 Zone 6,015'- 6,047' 3.03 6073.79 its 25 to 154 130 its 7-5/8", 29.7#, L-80 TXP Casing 5218.65 6076.82 its 5 to 24 20 its 7-5/8", 39#, L-80 TXP Casing 830.57 11295.47 its 4 to 4 1 its 7-5/8", 39#, L-80 TXP Casing, Bakerlock Jt 42.28 12126.04 7-5/8" HES Baffle Collar 1.18 12168.32 its 3 to 3 1 its 7-5/8", 39#, L-80 TXP Casing, Bakerlock Jt 41.32 12169.50 7-5/8" HES Float Collar 1.22 12210.82 its 1 to 2 2 its 7-5/8", 39#, 1-80, TXP Casing, Bakerlock Jt 78.69 12212.04 7-5/8" HES Composite Concentric Phenolic Nose shoe 2.14 12290.73 12292.87 12292.87 12292.87 12292.87 12292.87 11" Under reamed hole 12,195' MD 12292.87 Intermediate TD 9-7/8" 12,306' MD / 7,471.34' TVD 12292.87 7-5/8" Shoe @ 12,293.25' MD ! 7,469.703' TVD 12292.87 12292.87 12292.87 12292.87 Total 78 Centeks 12292.87 Total 26 To co Bowsprings 12292.87 12292.87 12292.87 12292.87 12292.87 12292.87 12292.87 12292.87 12292.87 Remarks: Bakerlock to pin of it #5 Up Wt 375 K M/U Trq TXP 39#_26.1 k ft/lbs w/Run-N-Seal Pipe Dope Dn Wt 110K M/U Trq TXP 29.7#_21.3 k ft/lbs w/Run-N-Seal Pipe Dope Block Wt 43 K M/U Trq Hyd 563_ 10.3 k ft/lbs w/Seal Guard Pipe ECF Dope Rig Supervisors: R. Reinhardt / G. Madel) Cement Detail Report CD5-92 Job: String: Intermediate Casing Cement DRILLING ORIGINAL, 9/4/2019 04:30 Cement Details Description Intermediate Casing Cement Cementing Start Date 9/21/2019 10:00 Cementing End Date 9/21/2019 17:00 Wellbore Name CD5-92 Comment 2 Stage description from time log. Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Cement shoe and isolate KupC Top Depth (ftKB) 10,926.0 Bottom Depth (ftKB) 12,306.0 Full Return? Yes Vol Cement.. 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 4 Q Pump Final (bbl/... 2 Q Pump Avg (bbl/.. 8 P Pump Final (psi) 391.0 P Plug Dump (psi) 960.0 Recip? 1 Yes I Stroke (ft) 20.00 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 Interrnediate Cement Fluid Description Estimated Top (ftKB) 10,9260 Est Btm (ftKB) 12,306.0 Amount (sacks) 614 Class G Volume Pumped (bbl) 125.0 Yield (ft'/sack) 1.16 Mix H2O Ratio (gallsa... 5.05 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) 142.0 Thickening Time (hr) 705 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Intermediate Casing Cement Objective Qannik Isolation Top Depth (ftKB) 5,300.0 Bottom Depth (ftKB) 6,037.0 Full Return? Yes Vol Cement... Top Plug? Yes Btm Plug? No Q Pump ]nit (bbl/m.. 4 Q Pump Final (bbi/_. 2 Q Pump Avg (bbl/ . 8 P Pump Final (psi) 275.0 P Plug Bump (psi) 2,200.0 1 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 Intermediate Cement Fluid Description Estimated Top (ftKB) 5,300.0 Est Btm (ftKB) 6,037.0 Amount (sacks) 332 Class G Volume 66.2 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa.. 5.08 Free Water (%) Density (Ihlgal) 15.80 Plastic Viscosity (cP) 151.3 Thickening Time (hr) CmprStr 4.80 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 11/5/2019 .� O O O O In O O O to Ln Ln 0 0 In to Ln 0 0 0 0 n 6) V' 67 0) C) M O) M 0) Cl) 0) N O) N 0) N 0 N 0 r 0) 0) 0) 0 x 0) C:) 6) 0 0 0 6) 0 C) 0 0) 0 m 0 0) Y N N C Q d fL) 4+ ) 7 m m Lam,) O Ln 00 0000 000 0 0000000000 o a C O N LO O LO O LO O LO O Lo O LO O LO O Ln O LO O LO O > _O ' CL O O O r r N N co co V' V LO LO (D (O f-- ti co CO O M O m E d CLO CL C 0000 0000 000 O 00000 fl- MaoN MNOLn raoM O LnO4OLn N rN NMMd' LO Lr) (D � r 000007O d "� N - d i Q � � E y 01— N M V L) (O I- 00 O O N M LO CO O a >aCD O L Y �.+ O Lf) Lo In 0 0 0 Ln Ln Ln Ln O 0 0 0 CO CO M M M CO N N N N N N N N 4% .!QC Cl Ln Ln LO LO LO Ln Ln LO LO LO Ln Ln LO LO Ln d V Ei m - Cl) co co M co co Cl) co M co co Cl) co co co E m �+ Or NM V LOMr` 000)0 L[') OLOO a r` > O U),O r NNM d ; r m O � .�., •= O O LO V LO O LOM O (D Lo O Co h Q' M� LO Cf) N M co O Ln N r M CO O O V r- N Ln 07 LO V C Y � C U .- r .- r r N N" N Cl)Cl)d E Q E O V M N CO O V CO N (O O V 00 N 0 O V' co CN E D Y N N NM M V V 't LO Ln (0 (O (f) rl- ; 7 0 > Y o cn a- ri ' � U rn > �n a IT o M C NP I f� tl T I I I I I I N ILL y O V N ++ 7 N 0) a ' a C rO 'y d N W) 0 00 o C nE' a � � n a Q y QJ JJ Qa � 7 7 2_ p fn �- O O Ln N �_ C W a m O r O N CD r a Q _ _ O L Cl) O o_ .I J p C G i L�,v L M a W= ami 0 � c D ° N o Oa (D U) a aco S w o N OU E E n� a,;� 2 a:0) CD Cl)Z Lo N a� a C) r � 73 z + CL LLJ� O 0 a." 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C N N O r 0 UO W O N 6) tO 0 (O 'd' �O O i CY) m ANO (O(`')O(0 N Cl) IT �T NM LO 0000 y v fA Q N C Q Q a) m � U) O L LO N LO CO LO V LO LO LO (D LO r LO O LL � � O N M V �O CO I� � Q ! 07 L C Q Yy a1 U.0 U m E m m O N CO V' LO O r— M O O LO O (O O U) � � m C 0- 75 m > a o >I m _ W i O I ~ et O N E LL N 04 N oCD y N 0 O 7 C O U a, CL CJ f.._ O O._i L Lo a M ' a � CL 0 W C J (C I L 4+ ++ F s a W a 0 m Cry �`) ° O m 3M o y2)0 �d O` NSI L O Q W~ �, cl O E E N� U) Z d a U N W O N (L 2i 00 p V 0 ► �'! N E N __ N Q �LL m �W °' a aO a) O co m o o x II N w LL.fl u, co:J LO O ', C r— a j 0Nk s w a _ LL J m (Y p O a) L CL N_ U 0E m r N _ It o N P� L Qj V .0 0 0 ! C L f9 w N Q _ N r- O O tai N L LL m �E� Q 7 w @ "a (n O O a) O CL CD O� 0 '� QLo U) �_ ca N � LL (n O (� f C � = L 0 Q LL — -0 c co C O O -0 O > cn U U w Q = f6 C Q a) !! to = U N H y X @ "O 0 is d L 0) O O !i L N W Lo(n r0 W �(n � li y 0 a2i s O O y 0 CL a) S c U 75 cm .� m a) 0 a) E _N Y f6 0 0 d = Q N f6 U L U N n 2 O 0) (n UJ o o o n Z F- Y O O w _ M 3anss3ad E �$ 2 I I I Lu U E E co Operations Summary (with Timelog Depths) CD5-92 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/19/2019 9/19/2019 0.75 INTRM1 CASING BOPE P Rig up and test upper 7 5/8" pipe rams 00 0.0 1300 13:45 and annular with 7 5/8" test joint to 250psi low and 3500psi high for rams and 250psi low, 2500psi high on annular for 5 charted minutes each. 9/19/2019 9/19/2019 0.50 INTRM1 CASING BOPE P Blow down and rig down test 00 00 1345 14 15 equipment, pull test plug. 9/19/2019 9/19/2019 1.25 INTRM1 CASING RURD P Rig up to run 7 5/8" casing 00 00 14 15 1530 9!19/2019 9/19/2019 2.50 INTRM1 CASING PUTB P PJSM, run 7 5/8" casing as per detail 00 506.0 15.30 18:00 tally from surface to 506'MD monitoring displacement on pit #2. PU/SO=64k/60k, filling on the fly topping off fill every 10 joints. 9/19/2019 9/19/2019 2.00 INTRM1 CASING RURD P After 24 joint 7 5/8" x 39ppf, 5060 506.0 1800 20:00 changeout out Volant guide shoe and cup asembly for 29.7ppf as per DDI Casing rep. 9/19/2019 9/19/2019 0.25 INTRM1 CASING PUTB P PJSM, run 7 5/8" casing as per detail 5060 1 20:00 2015 tally from 506'MD-1,13VMD, monitoring displacement on pit #2. PU/SO=71 k/78k, filling on the fly topping off fill every 10 joints. 9/19/2019 9/19/2019 0.50 INTRM1 CASING PUTB P PJSM, run 7 5/8" casing as per detail 1,131 0 1,170.0 2015 20:45 tally from 1,131'MD to 1,170'MD, monitoring displacement on pit #2, filling on the fly topping off fill every 10 joints. 9/19/2019 9/19/2019 0.50 INTRM1 CASING PUTB P Lay down bad joint #26 and collar 1.170.0 1.170.0 20.45 21 15 from joint 25. Replace jt #25, 40.75' with spare jt 40.37'. MU to 21,300 tq and check torque. 9/19/2019 9/20/2019 2.75 INTRM1 CASING PUTB P PJSM, run 7 5/8" casing as per detail 1,1740 2,181 0 21 15 0000 tally from 1,170'MD-2181'MD, monitoring displacement on pit #2. PU/SO=103k/68k, filling on the fly topping off fill every 10 joints. 9/20/2019 9/20/201 6.00 INTRM1 CASING PUTB P Continue to run 7 5/8"" 29.7ppf, L-80 2,0800 4,691 0 00:00 06 OU TXP intermediate casing from 2,080'MD to 4,691' MD as per casing detail tally. Torque connections with Volant tool to 21,300ft-lbs. Monitor displacement on pit 2. SO/PU wt 150/137k, filled pipe on the fly, topping off every 10 joints. 9/20/2019 9/20/2019 1.25 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 4,691 0 5.2440 06:00 0715 TXP intermediate casing from 4,691'MD to 5,244' MD as per casing detail tally. Torque connections with Volant tool to 21,300ft-lbs. Monitor displacement on pit 2. PU/SO wt 150k/1 37k, filled pipe on the fly, topping off every 10 joints. 9/20/2019 9/20/2019 1.25 INTRM1 CASING CIRC P Circulate bottoms up at 5,244'MD Oust 5,2440 5,244.0 07 15 0830 above the Qannik/K2 at 5,363'MD). Stage pump at 1bpm/170psi, 2bpm/190psi, 3bpm/194psi, 4bpm/212psi, 5bpm/214psi, 6bpm/225psi, PU/SO=155k/139k. Total 2650strokes pumped. Page 15131 Report Printed: 11/5/2019 ' Operations Summary (with Timelog Depths) CD5-92 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/20/2019 9/20/2019 3.50 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 5,244.0 7,171.0 0830 12:00 TXP intermediate casing from 5,244'MD to 7,171' MD as per casing detail tally. Torque connections with Volant tool to 21,300ft-lbs. Baker Locked ES cementer and 4 connections above it. Monitor displacement on pit 2. PU/SO wt 172k/149k, filled pipe on the fly, topping off every 10 joints. 9/20/2019 9/20/2019 6.00 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 7,171 0 10,0390 12:00 18 00 TXP intermediate casing from 7,171'MD to 10,039' MD as per casing detail tally. Torque connections with Volant tool to 21,300ft-lbs. Monitor displacement on pit 2. SO wt 155k, filled pipe on the fly, topping off every 10 joints. 9/20/2019 9/20/2019 2.00 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 100390 11,000.0 18:00 20:00 TXP intermediate casing from 10,039' MD to 11,000' MD as per casing detail tally. Torque connections with Volant tool to 21,300ft-lbs. Monitor displacement on pit 2 with SO wt 155k, filled pipe on the fly, topping off every 10 joints. 9/20/2019 9/20/2019 2.75 INTRM1 CASING CIRC P Circulate bottoms up at 11,000'MD 11,0000 11.0000 20:00 22:45 (just above the HRZ at 11,291'MD). Stage up pump from 3bpm to 6bpm. Final circ press=328psi, PU/S0=280k/170k. Total 7200strokes pumped.(bottoms up 6900stks). 9/20/2019 9/21/2019 1.25 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 11,000.0 11.600.0 22:45 0000 TXP intermediate casing from 11,000' MD to 11,600'MD as per casing detail tally, running limit set to maximum 50 ft/min. Torque connections with Volant tool to 21,300ft-lbs. Monitor displacement on pit 2 with SO wt 155k, filled pipe on the fly, topping off every 10 joints. 9/21/2019 9/21/2019 2.00 INTRM1 CASING PUTB P Continue to run 7 5/8" 29.7ppf, L-80 11,6000 12,256.0 00:00 02.00 TXP intermediate casing from 11,600' MD to 12,256'MD as per casing detail tally, Torque connections with Volant tool to 21,300ft-lbs TXP, 10,300ft-lbs on Hyd 563 hanger and x-over. MU fluted FMC hanger to landing joint as per FMC rep. Monitor displacement on pit 2. Final SO wt 110k. 9/21/2019 9/21/2019 4.00 INTRM1 CEMENT CIRC P Slowly staged up pumps from 12.256.0 12,293.0 0200 0600 lbpm=320psi, 2bpm=350psi, 3bpm=380psi, 4bpm=428psi, 5bpm=570psi, 6bpm=500psi, 7bpm=561psi, 8bpm=605psi. Circulate and condition mud lowering weight to 10.6ppg, With pumps PU/S0=375k/110k, with pumps on PU/S0=330k/l63k at 8 BPM. 9/21/2019 9/21/2019 2.50 INTRM1 CEMENT CIRC P Circ and condition mud at 8bpm. at 12,2930 12,293.0 0600 08:30 430psi. Lowering mud weight to 10.6ppg. PU/S0=290k/168k 9/21/2019 9/21/2019 0.50 INTRM1 CEMENT RURD P Blow down top drive, RU cement line. 12,293.0 12.293.0 0830 09:U0 Page 16131 Report Printed: 11/5/2019 Operations Summary (with Timelog Depths) CD5-92 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/21/2019 9/21/2019 1.00 INTRMI CEMENT CIRC P Continue to circulate and condition 12,2930 12,293.0 0900 1000 mud for cement job at 8bpm, 530psi, FO=20%, SIMOPS-PJSM for cementing. 9/21/2019 9/21/2019 2.00 INTRM1 CEMENT CMNT P As per Schlum: pump 5 bbls mud, 12,293.0 12,293.0 10:00 1200 Pressure test to 4,000psi, pump 60.1 bbls 13.Oppf mud push at 3.2bpm/280psi, drop bottom bypass plug, pump 125bbls first stage cement at 15.8ppg, at 4bpm/150psi, drop top plug, Schlum pumped 20bbls displacement water, rig pumped LSND mud at 8bpm/250psi, reciprocating 15', UP/DN=303k/160k 9/21/2019 9/21/2019 1.25 INTRM1 CEMENT CMNT P Continue to displace with 10.6ppg 12,2930 12,2930 1200 13 15 mud at 8bpm. FCP=700psi, slow to 3bpm/400psi 10bbls from bumping, bump plug at 539.45 bbls pumped (5357stks), to 950psi, hold for 5 mins, check floats held, cement in place at 13:05, open stage collar as per HES rep to 3,000psi. 9/21/2019 9/21/2019 2.50 INTRM1 CEMENT CIRC P Circulate and condition mud through 1,074 0 6 074 0 13 15 1545 stage collar at 6,074'MD at 8bpm/370psi, FO=20%, reducing mud weight to 10.4ppg, SIMOPS-PJSM for second stage cement job. 9/21/2019 9/21/2019 1.75 INTRM1 CEMENT CMNT P Second Stage Cement Job: Schlum 6,074.0 6,0740 1545 17:30 pumped 41.9bbls Mud Push II at 3.lbpm/170psi, 66.2bbls 15.8ppg cement at 3.9bpm/155psi, dropped closing plug, pumped 20bbls water, rig chased with displacement 10.4ppg LSND mud at 8bpm/560psi, slowed to 2bpm and bumped top closing plug at 25bbls (2572strokes), no close confirmed, bleed off pressure, well static both sides for confirmation that stage collar is closed. Cement in place CIP=17:30hrs 9/21/2019 9/21/2019 0.50 INTRM1 CEMENT RURD P RO cement line, RD Volant tool and 610740 6,074.0 1730 1800 bale extensions as per FMC rep, LD Ldg jt. 9/21/2019 9/21/2019 0.50 INTRM1 CEMENT RURD P Lay down 7 5/8" landing joint. Clear 6.0740 5,074 0 18:00 1830 floor of old wear ring and test plug. Pull PS-21 inserts. 9/21/2019 9/21/2019 1.25 INTRM1 CEMENT WWSP P PJSM on setting the pack-off as per 6,u74 0 6,0740 18:30 19:45 FMC procedure. Picked up one stand of 5" HWDP and pack-off running tool. Installed pack-off, run in LDS and test pack-off for 10 min witnessed by CPAI rep. 9/21/2019 9/21/2019 0.75 INTRM1 CEMENT WWSP P LD pack-off running tool and HWDP 6,0740 6074.0 1945 20:30 stand. Installed FMC test plug as per FMC rep. 9/21/2019 9/21/2019 1.00 INTRM1 CEMENT BOPE P Change pipe rams to from 7 5/8" to 6,0740 6,074.0 2030 2130 2.875"x5.5" variables. SIMOPS- Pressure wash top drive, service wash pipe. 9/21/2019 9/22/2019 2.50 INTRM1 CEMENT PULD P Install rotary table center sock in PS- 6,0740 6,074.0 21 30 0000 21 slips, Start LD HWDP and jars from derrick. 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O ❑ o 3 U U U X N0 T c OJ U O (V O m N ca O" 00 O M U U U U U Coco ° U U ❑❑ N ❑ U N O } X uR U U U U M U C) U U a) a r m m m rn y O ❑ N - N O_ 0 C m a at ° m o N -O U V U C N E r U M O ' R V M N ro o) o) J >_ d M M In co co M C C 0 D Q m °c w L � m C N R h 0) O O N M U U R �- V M O U 0 O M Cl) O(D rn O_ r O N O O (O N O N (O O rn m rn O r N M M rn N N M U N N V' CO N rn N (D m N R ° 6(htbN(A 66 6L66(h6(h6 h(h6(hth6666hth(h(A(b(A(A a) rn ❑ ❑ ❑ ❑ O ❑ ❑ ❑ ❑ ❑ ❑ O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑.❑ O ❑ o U U U C) U U U U U U U UUUU U U U U U U U U U U U U U U U z CD5-92 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW Injection Pressure (psi) MW )(psi) Injection Pressure MW )(psi) Injection Pressure 6.8 1,393 8.8 1,166 10.8 938 6.9 11382 8.9 1,154 10.9 926 7.0 1,370 9.0 1,143 11.0 915 7.1 1,359 9.1 11131 11.1 904 7.2 11348 9.2 1,120 11.2 892 7.3 11336 9.3 1,109 11.3 881 7.4 1,325 9.4 1,097 11.4 870 7.5 11313 9.5 11086 11.5 858 7.6 1,302 9.6 19074 11.6 847 7.7 11291 9.7 1,063 11.7 835 7.8 11279 9.8 1,052 11.8 824 7.9 11268 9.9 1,040 11.9 813 8.0 1,257 10.0 1,029 12.0 801 8.1 1,245 10.1 11018 12.1 790 8.2 1,234 10.2 11006 12.2 778 8.3 11222 10.3 995 12.3 767 8.4 11211 10.4 983 12.4 756 8.5 1,200 10.5 972 12.5 744 8.6 1,188 10.6 961 12.6 733 8.7 1,177 10.7 949 12.7 722 Note to File CRU CD5-92 (PTD 219-034) November 6, 2019 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-92 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CRU CD5-92. Recommendation Approve ConocoPhillips' request. Conclusions 1. In CD5-92, the surface casing shoe is set at 2,246' measured depth (MD; equivalent to -2,115' true vertical depth subsea'), near the base of a 500 -foot thick shale-, claystone-, and siltstone-dominated interval that persists throughout the area. This interval will prevent upward migration of injected fluids. 2. There appears to be a sufficient volume of sandstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the disposal interval. 4. There are no potential USDWs in this area. There are no water wells within one mile of CD5-92. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The volume of sediments most strongly impacted by the proposed annular injection operation will likely lie within about 100' of the CD5-92 wellbore. 8. Injected fluids will likely reach one or more nearby wells that have open annuli beneath their surface casing shoes. However, if this occurs, surface casing, surface casing cement (to surface), and thick, laterally continuous confining layers of shale, claystone, and siltstone will ensure injected fluids remain within the disposal interval. Discussion ConocoPhillips' application was reviewed along with records from Colville River Unit CD5-92 (CD5-92), nearby development wells, and exploratory well Nuiqsut 1, which is located 1-1/2 miles to the northeast. The discussion that follows is based on information, well logs, and mud logs from these wells. An index map is provided in Figure 1, below. The proposed annular disposal injection interval in this well lies in the Torok and Seabee Formations within Section 7, TI IN, R4E, Umiat Meridian, which is about 2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoe of CD5-92 lies at -2,115', near the base of a 500 -foot thick I Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet, true vertical depth below mean sea level (mean low, low water). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. CD5-92 Annular Disposal Note to File November 6, 2019 Page 2 of 5 interval that is dominated by shale, claystone, and siltstone and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). In CD5-92, the annulus open to disposal extends downward from the surface casing shoe at -2,115' to the top of second -stage cement for the 7-5/8" casing string, which is estimated to lie at -4,033'. The portion of the open annulus that will most likely accept the injected waste is a 185 -foot thick interval that contains several 1- to 10 -foot thick beds of sandstone and sandy siltstone that lie below the surface casing shoe between about -2,250' and -2,435'. The aggregate thickness of these thin, potential receptor beds is about 40'. These beds are separated by thin claystone intervals. Beneath the disposal interval are several intervals of claystone that are continuous throughout the area and will provide lower confinement for any injected wastes. Top of Second -Stage Cement for 7-5/8„ CDS-92 Intermediate \ Open Annulus Casing c Os, Most Likely Surface Disposal Casing Interval Shoe for CD5-92 Surface Casing NORTH ♦ Shoe Locations A A 'A z 0s 500 feet ♦ e i Figure 1. CD5-92 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 2.) The index map above displays trajectories for all wells drilled from the Colville River Unit CD5 Drill Site. The locations of the surface casing shoes for all well bores are depicted with green -colored triangles. The calculated top of second -stage cement for the CD5-92 intermediate casing string (-3,956') is indicated by the orange -colored circle. Twenty eight wells are currently open to these same strata within the '/-mile radius area of review: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5- 25, CD5-98, CD5-99, CD5-313, CD5-314, CD5-314X, CD5-315, and CD5-316. CD5-92 Annular Disposal November 6, 2019 Note to File Page 3 of 5 Figure 2, below, presents a structural cross-section view of CD5-92 and nearby wells CD5-19 and C135-01, which were logged to the ground surface. Resistivity measurements indicate that the base of permafrost occurs at about -1,250' in the CD5 Drill Site area, which is about 865' above the CD5-92 surface casing shoe. Figure 2. CD5-92 Area: Structural Cross-section (Depth scale represents true vertical feet. Horizontal separation footages shown between wells are the approximate distances between the surface casing shoes.) Mud logs were recorded in only two wells drilled at the CD5 Drill Site, CD5-04 and C135-313, that were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). These mud logs suggest the shallow geologic section in the area contains predominantly methane gas, with minor amounts of ethane, propane, and butane. The shallowest SW 501032076000 501032080000 501032073600 NE 2171210 823, 2190340 565' 2160220 CRU CD5-19 CRU CD5-92 CRU CD5-01 0 0 1 :. t r Su rface { L• Ca sing -500_ p - Cement Surface ' Suace-500 �� Casing - Ca ing Cement f� Cement Q� 1 loon -Permafrost -1000 Ease at ,250' z�—, ;; .• u DSS o 1500 -1500 Upp r Con fining" v 5' Su face -2000 w Inte al m" .. — '{ Casing 2000 oe -- ost Likely - 'f _ry D sposal -2500 - '_ Irterval i -2500 i Open AnnulusLo wer E _ - - onfining 3000 _ 3000 Vers41 F -3500< - - 3500 Top of Second( Stage Cement 5,300' MD, -4000 # -3,956' TVDSS 4000 Figure 2. CD5-92 Area: Structural Cross-section (Depth scale represents true vertical feet. Horizontal separation footages shown between wells are the approximate distances between the surface casing shoes.) Mud logs were recorded in only two wells drilled at the CD5 Drill Site, CD5-04 and C135-313, that were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). These mud logs suggest the shallow geologic section in the area contains predominantly methane gas, with minor amounts of ethane, propane, and butane. The shallowest CD5-92 Annular Disposal Note to File November 6, 2019 Page 4of5 occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas—equivalent to 4,000 ppm—on the mud log) were about-1,850'and -2,000', respectively. So, the entire proposed annular disposal interval likely contains small, non-commercial amounts of methane gas. Unfortunately, oil shows are not recorded on the mud logs obtained in CD5-04 and CD5-313, likely due to the use of oil -base drilling mud. In ARCO's Nuiqsut 1 exploratory well, located about 1-1/2 miles to the northeast, the shallowest oil show was encountered at 3,990' MD (-3,930' TVDSS), with a second show encountered at 4,115' MD (-4,055' TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These oil shows indicate the presence of only trace to minor quantities of oil in the geologic strata that may be affected by annular disposal in CD5-92. These shows do not represent commercial quantities of oil. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order No. 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit. The Alaska Department of Natural Resources' Alaska Mapper web application, accessed November 6, 2019, confirms that there are no publicly recorded water wells within one mile of CD5-92. Injected Fluid vs Affected Area Surrounding CRU CD5-92 Wellbore (Assumptions: 30.0% porosity, 50% native fluid displacement, aggregate cylinder 40.0' high) 200 102' affected radius assuming 40.0' of injection interval aggegate thickness 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. CD5-92 Area Likely Affected by Annular Injection (Assuming uniform, piston -like, radial displacement of 50% of native formation fluids) The gamma ray well log curve recorded in CD5-92 indicates that an aggregate total of about 40 true vertical feet of sandstone and sandy siltstone are present within the most likely disposal interval. Inspection of CD5-92 Annular Disposal Note to File November 6, 2019 Page 5 of 5 density porosity logs from correlative strata in nearby wells suggests porosity averages about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected fluids lies within a radius of about 100' from the CD5-92 wellbore, assuming uniform, radial, piston -like displacement of half of the native formation fluids (Figure 3, above). The surface casing shoes of the two closest wells— CD5-08 and C135-12—are located between about 100' and 120' from the most likely disposal interval within CD5-92. However, surface casings in CD5-08 and C135-12 were cemented to surface with full returns. The surface casing shoes for the two other nearby wells—CD5-05 and CD541—lie between about 250' and 300' away from the most likely disposal interval in CD5-92. Their surface casing strings were also cemented to surface with full returns. If fluids injected into CD5-92 reach uncemented annuli within any of the four nearby wells, surface casing, surface casing cement, and thick, laterally continuous confining layers will ensure those fluids remain within the intended interval. Summary The limited volume of rock that will be affected by this proposed annular disposal operation is situated beneath 1,250' of permafrost and is bounded above and below by continuous confining layers of shale, claystone, and siltstone. The disposal interval lies inside the Colville River Unit, far from any external property lines, so correlative rights are not a concern. There are no freshwater aquifers present, and there are no water wells within one mile of CD5-92. The disposal interval does not include any potentially commercial hydrocarbon accumulations. Surface casing, surface -casing cement (to surface), and laterally continuous layers of shale, claystone, and siltstone will prevent injected fluids from migrating out of zone. I recommend approving the proposed annular disposal operations within CRU CD5-92 to the requested limit of 35,000 barrels. It Davies Senior Petroleum Geologist ell (Ol Vo Note to File CD5-92 (PTD 2190340, Sundry 319-501) Colville River Unit (Alpine Oil Pools) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD5-92). -- 10 3/4" Surface casing was cemented to surface successfully with no losses experienced. Cement report put excess cement to surface of 144 bbls with 385 bbl DeepCrete pumped. No problems reported. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 9/10/2019, the pressure slope rises smoothly with test stopping at 3.4 bbl pumped and 1020 psi to yield the desired 18.6 ppg EMW. The pressure declined slightly from 1020 to 1010 psi (18.52 ppg EMW) during the 10 minute shut in period with the 2.5 bbl being bled back. The initial FIT indicates that the surface casing shoe is well cemented. An open hole injectivity test was completed on 9/22/2019 prior to running and cementing the 7.625" casing with a depth of the casing shoe of 2246 ft MD/ 2188 ft TVD and an open hole to est 12306 ft MD yielding a 14.6 ppg EMW. The test showed pressure rising steadily with the slight tangent change at the 14.6 ppg EMW and a sharp break over point at approximately 14.96 ppg EMW. AOGCC geology staff have estimated the potential disposal zone as a 185 ft thick sand and silt beginning approx. 135 ft below the casing shoe -- The 7.625" casing was run and successfully cemented with a two stage job and shoe of 12326 ft. First stage cement was pumped and was estimated as 12326 to TOC 10960 ft MD. Cement tool at 6037 ft was opened and the 2nd stage pumped without problems with that TOC estimated at 5300 ft MD. A "Sonic Top of Cement" evaluation log processed on 10/03/2019 was run from 8700 ft MD to TD and shows a TOC of 10960 ft with improving cement to shoe. --There are multiple wells currently drilled or planned to be drilled within '/ mile radius of CD5- 92 and the CPAI application contains supporting cementing and LOT well information and mentions that well and cementing information is already on file with AOGCC. The surface shoe of CD5-12 is closest, about 55' distant. AD is already prolific on CD5 and it is expected to continue with additional CD5 wells. CPA[ is therefore constructing the CD5 wells to be compliant with AD regulations. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC November 13, 2019 F:Acdwa11ace\Documents\Annu1ar DisposalA 91113 CD5-92 note to file.doc STATE OF ALASKA ALASKH OIL AND GAS CONSERVATION COMMISSI�_ REPORT OF SUNDRY WELL OPERATIONS 0wk.awid NOV 0 7 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate E] Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development El Exploratory ❑ Stratigraphic❑ Service ❑ 219-034-0 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20800-00 7. Property Designation (Lease Number): 8. Well Name and Number: CRU CD5-92 ASRC-NPR4, ASRC-NPR2, ASRC-NPR3, ASRC-NPR1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): POST FRAC REPORT Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 28,503 feet Plugs measured None feet true vertical 7,325 feet Junk measured None feet Effective Depth measured 28,503 feet Packer measured 12,076 feet true vertical 7,325 feet true vertical 7,448 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 20 115' MD 1157VD SURFACE 2,207 feet 10 3/4 " 2,246' MD 2189' TVD INTERMEDIATE 12,256 feet 7 5/8 " 12,293' MD 7470' TVD 4 1/2" LINER 12,863 feet 4 1/2 " 24,993' MD 7346' TVD Perforation depth: Measured depth: 1 2723-1 961 8 feet True Vertical depth: 7471-7394 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 12,145' MD 7,458' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 12,076' MD 7,448' TVD PACKER - HRDE ZXP LINER TOP PKR 12,130' MD 7,456' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12,747-21,903 Treatment descriptions including volumes used and final pressure: Total Well -13 stages, 1,054,274 lbs placed .... See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 10 670 Subsequent to operation: 5192 2426 318 1870 588 14. Attachments (required Per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory El Development EZ Service ❑ Stratigraphic E]Copies of Logs and Surveys Run El�/ ktl l3l 11 16. Well Status after work: Oil Q Gas [-]WDSPL E]Printed and Electronic Fracture Stimulation Data Q GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-453 Contact Name: Adam Klem Authorized Name: Adam Klem contact Email: adam.klem@cop.com Authorized Title: Sr. Compl n Engineer Contact Phone: (907) 263-4529 Authorized Signature: `r`3 Date: / Form 10-404 Revised 4/2017 (-b1J j 1/ j X (/1� /7 R MS.I�w NOV 0 8 2ftmit Original Only WNS PF- 7 WELLNAME CD5-92 WELLBORE CD5-92 Conor hIllips Alaska, Inc. HORIZONTAL,CD5-92, 11/120197:52:49 AM Perforations& Slots Vertical scher-abc (actual) Shot Dens ............................................................................................ Top (TVD) Sim [TVD) (shots/ft HANGER, 31.5 Top (ftKB) at. (ftKB) (RIB) (ftKB) Linked Zone Date ) Type Com 15,010.7 15,013.1 7,459.4 7,459.4 10/5/2019 PERFP Baker Frac Sleeve #10 ....................._..__...._.._..._.................. ... ............... 2.215" OD Ball 15,770.7 15,773.1 7,458.0 7,457.9 10/5/2019 PERFP Baker Frac Sleeve #9 2.175" OD Ball 16,535.3 16,537.7 7,429.5 7,429.5 10/5/2019 PERFP Baker Frac Sleeve #8 2.135" OD Ball 17,302.8 17,305.1 7,428.1 7,428.1 10/5/2019 PERFP Baker Frac Sleeve #7 2.095" OD Ball CONDUCTOR; 35.0175.0 18,072.9 18,075.2 7,431.2 7,431.2 10/5/2019 PERFP Baker Frac Sleeve #6 X -NIPPLE; 1,979.2 2.055" OD Ball 18,846.3 18,848.6 7,418.3 7,418.1 10/5/2019 PERFP Baker Frac Sleeve #5 2.015" OD Ball 19,616.1 19,618.4 7,394.0 7,394.1 10/5/2019 PERFP Baker Frac leave #4 SURFACE; 39.0.2,248.0 1.975" OD Ball GAS LIFT; 4,309.2 20,391.1 20,393.4 7,393.3 7,393.3 1015/2019 PERFP Baker Frac Sleeve #3 1.935'. OD Ball 21,156.9 21,159.3 7,396.2 7,396.2 10/5/2019 PERFP Baker Frac Sleeve #2 1.895" OD Ball 21,913.5 21,915.8 7,380.3 7,380.1 10/5/2019 PERFP Baker Frac Sleeve#1 1.855" OD Ball GAS LIFT; 8,137.8 22,678.8 22,719.1 7,357.2 7,356.7 10/5/2019 PERFP Perfd Jill) 23,004.8 23,045.1 7,354.8 7,354.7 10/5/2019 PERFP Perfd Jt(1) 23,330.4 23,370.7 7,357.2 7,357.7 10/5/2019 PERFP Perfd Jt(1) GAS LIFT; 11,897.4 23,652.7 23,692.7 7,359.2 7,359.3 10/5/2019 PERFP Perfd Jt(1) 23,976.4 24,016.7 7,356.1 7,355.4 10/5/2019 PERFP Perfd Jt(1) SLB GAUGE; 12,018.7 24,287.3 24,327.6 7,350.7 7,350.2 10/5/2019 PERFP I Perfd Jt(1) 24,908.8 24,987.01 7,346.1 7,346.2 1 10/5/2019 PERFP I Perfd Jts(2) PACKER; 12,075.6 Frac Summary NIPPLE; 12,703.9 Start Date 10/11/2019 Proppant Designed (lb) 7,000.0 Proppanl In Formation (lb) 64,449.0 Stg # StartDate Top Depth (RKB) Etm (ftKB) 1 10/17/2019 21,900.0 21,903.0 Link to Fluid System Gelled Salt Water, 25# HydroG Vol Clean (bbl) Vol Slurry (bbl) 1,433.00 1,503.00 LOCATOR; 12,128.0 MULE SHOE; 12,144.8 Start Date 10/11/2019 1 Proppant Designed (lb) 7,000.0 Proppant In Formation (lb) 66,515.0 Stg # StartDate Top Depth (ftKB) Bim (RKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 2 10/17/2019 21,137.0 21,140.0 Gelled Salt Water, 25# HydroG 970.00 1,042.00 Start Date Proppant Designed (lb) Proppant In Formation (lb) 10/11/2019 I 7,000.0 68,782.0 Stg # Sfart Date Top Depth (ftKB) son (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 3 10/17/2019 20,374.0 20,377.0 Gelled Salt Water, 25# HydroG 986.00 1,061.00 Start Date Proppant Designed (lb) Proppant In Formation (lb) 10/11/2019 9,000.0 I 102,548.0 Sig # Start Date Top Depth (ftKB) Ban (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) INTERMEDIATE; 36.9-12,292.9 4 10/17/2019 19,612.0 19,614.0 Gelled Salt Water, 25# HydroG 1,013.00 1,124.00 Start Date Proppant Designed (Ib) Proppant In Formation (Ib) PERFP; 12,723.4-12,725.8 10/11/2019 9,000.0 97,569,0 Hydraulic Fracture; 12,747.0 ( Sig # Start Date Top Depth (ftKB) atm (ftKB) 5 10/17/2019 18,849.0 18,852.0 Link to Fluid System Gelled Salt Water, 25# HydroG Vol Clean (bbl)VOI Slurry (bbl) 957.00 1 1,062.00 PERFP; 13,493.4-73,495.7 Start Date- Ib ppant Designed( ) Pro ppant In Formation (lb) Hydreulb Fracture; 13,510.0 I 10111/2019 9,0B0.B 90,331.0 Stg # StartDate Top Depth (ftKB) Stan (KLink Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl)PERFP; 74,241.7-14,244.0 6 10/17/2019 18,086.0 I 1$,0$9.8 Gelled Salt Water, 25# HydroG 923.00 1,021.00 Hydraulic Fmctu.; 14,272.0 Start Date 10/11/2019 Proppant Designed (Ib)Proppant 9,000.0 In Formation (Ib) 98,332.0 Stg # Start Data Top Depth (RKB) Btm (RKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbp PERFP; 15,010.7-15,013.1 Hydraulic Fracture; 15,0350 7 10/17/2019 17,323.0 17,326.0 Gelled Salt Water, 25# HydroG 1,149.00 1,256.00 Start Date Proppant Designed (lb) Proppant In Formation (Ib) PERFP: 15,770.7-15,773.1 10/11/2019 9,000.0 I 83,669.0 Stg # Start Date Top Depth -131 Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbp Hyd..I. Fracture; 15,798.0 I 8 10/19/2019 16,561.0 16,563.0 Gelled Salt Water, 25# HydroG 1,063.00 1,153.00 Start Date 10/11/2019 Proppant Designed (Ib)Proppent 9,000.0 In Formation (Ib) $4,432.0 PERFP; 16,535.3-16,537.7 Hydreulb Fmcture; 16,561. I Stg # Start Date Top Depth (ftKB) St. (RKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) PERFP; 17,302.8-17,305.1 9 10/19/2019 15,798,0 15,801.0 Gelled Salt Water, 25# HydroG 913.00 1,005.00 Start Date Proppant Designed (lb) Proppant In Formation (lb) Hydraulic Frectum; 17,323,0 10/11/2019 I 9,000.0 90,247.0 PERFP; 78,072.9-18,075.2 Stg # Start Data Top Depth (ftKB) she (ftKB) 10 10/19/2019 15,035.0 15,038.0 Link to Fluid System Gelled Salt Water, 25# HydroG Vol Ckan (bbl) Vol Slurry (bbl) 942.00 1,040.00 Hydraulic Fracture; 18,086.0 Start Date Pioppani Designed (lb) Proppant In Formation (lb) PERFP; 18,846.3.18,848.8 10/11/2019 I 9,000.0 69,926.0 Stg # Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Hydraulic Fracture; 1e,e49.o 11 10/19/2019 14,272.0 14,275.0 Gelled Salt Water, 25# HydroG 905.00 981.00 Hydraulic Fracture; 19,612.0 Start Date 10/11/2019 Proppant Designed (Ib) 9,000.0 Proppant In Formation (lb) 102,369.0 PERFP; 19,616.1-19,618.4 Stg # Start Date Top Depth (RKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Hydreullo Fracture; 20,3740 12 10!192019 13,510.0 13,512.0 Gelled Salt Water, 25# HydroG 995.00 1,106.00 Start Date Proppant Designed (Ib) Proppant In Formation (lb) PERFP; 20,391.7-20,393.4 10/11/2019 I 9,000.0 I 127,238.0 Stg # Start Date Top Depth (ftKB) Btm (ftKB) 13 10/192019 12,747.0 12,750.0 Link to Fluid System Gelled Salt Water, 25# HydroG Vol Clean (bbl) Vol Slurry (bbl) 1,184.00 1,323.00 Hydraulic Freclure; 21,137.0 ( PERFP; 21,156.9-21,159.3 Mandrel Inserts Hydraulic Frecture; 21,900.0 ' St ati PERFP; 21,913.521,915.8 PERFP; 22,678.8-22,719.1 N Top (TVD) Top (RKB) (WB) Make Model Valve Latch Do (in) Sew Type Type PortSize TRORun (In) (psi) Run Date Com 1 4,309.2 3,516.8 Carrico KBMG 1 GAS LIFT GLV BK 0.188 1,905.0 10/23/2019 PERFP; 23,004.8-23,045.1 PERFP; 23,330.423,370.7 2 8,137.8 5,496.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,892.0 10/22/2019 PERFP; 23,652.7-23.692.7 3 11,897.4 7,407.5 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 10/21/2019 PERFP; 23,976.4-24,016.7 PERFP; 24,287.3-24,327.5 PERFP; 24,908.a-24,987.0 41/2' LINER; 72,130.2-24,993,0 WNS Pr' 17 WELLNAME CD5-92 WELLBORE CD5-92 ConocoPhillips Alaska. Inc. HORIZONTAL, CD5-92, 11/120197:52:49AM Notes: General & Safety Vertical wl amatic (acting End Date Annotation ............................................................................................ 10/10/2019 NOTE: View Schematic w/ Alaska Schematic10.0 4.5..HANGER; 34.5— .................................... I.......................... ......................... ............ .. ............ CONDUCTOR; 35.0-115.0 X -NIPPLE; 1,979.2 SURFACE; 39.0-2,246.0 GAS LIFT; 4,309.2 GAS LIFT; 8,137 e GAS LIFT; 11,897.4 SLB GAUGE; 12,018 .1 PACKER; 12,075.6 NIPPLE; 12,103.9 LOCATOR; 12,126.0 MULE SHOE; 12,144.8 INTERMEDIATE; 36.9-12,292.9 I PERFP; 12,723.4-12,725.8 Hydraulic Fra .; 12,747.0 PERFP; 13,493.4-13,495.7 Hydraulic Fracture; 13,510.0 PERFP; 14,241.7-14,244.0 Hydraulic Fr ni; 14,272.0 PERFP; 15,010.7-15,013.1 Hydraulic Fra .; 15,035.0 PERFP; 15,770.7-15,773.1 Hydraulic Fracture; 15,798.0 PERFP; 16,535.316,537.7 Hydraulic Fra tore; 16,561.0 PERFP; 17,302.8-17,305.1 Hydraulic Frature; 17,323.0 PERFP; 18,072.9-18,075.2 Hydraulic Fm—na, 18,086.0 PERFP; 18,846.318,848.6 Hydtsutic Fracture; 18,849.0 Hydraulic Fracture; 19,612.0 PERFP, 19,616.1-19,618.4 Hydraulic FracWra; 2D,374.0 PERFP; 20,391.1-20,393.4 Hydraulic FmMre; 21,137.0 PERFP; 21,156.9-21,159.3 Hydraulic Frature; 21,900.0 PERFP; 21,913.521,915.8 PERFP; 22,678.8-22,719.1 PERFP; 23,004.8-23,045.1 PERFP; 23,330.4-23,370.7 PERFP; 23,652.7-23,692.7 PERFP; 23,976.424,016.7 PERFP; 24,287.3-24,327.5 PERFP; 24,908.8-24,967.0 412" LINER; 12,130.2-24,993.0 CD5-92 FRAC STIMULATE DTTM JOBTYP SUMMARYOPS START 10/13/19 DRILLING RIH WITH XO TEST TOOL. SIT DOWN @ 12,104' RKB. ATTEMPT MITT SUPPORT- AND AT 2000 PSI ON THE TUBING, THE PLUG PUSHED THROUGH THE CAPITAL NIPPLE. AT SURFACE, TEST TOOL SHEARED AT SAFETY TOP SUB LEAVING XO TEST TOOL BODY IN HOLE. RIH AND SIT DOWN @ 3314' CTMD. XO TEST TOOL RECOVERED, MISSING 3" LONG, 1/4" STEEL RETAINER PIN. LAY DOWN FOR NIGHT TO DISCUSS PLAN FORWARD. JOB IN PROGRESS. 10/14/19 DRILLING RIH WITH XXN PLUG W/ BL BRUSH AND SAT DOWN @ 12,104' RKB. SUPPORT- PERFORM PASSING MITT TO 5230 PSI. ***NOTE, STEEL RETAINER PIN CAPITAL STILL IN HOLE*** JOB COMPLETE 10/17/19 DRILLING PUMPED SATGES 1 THRU 7 OF FRAC, TOTAL OF 590,000 LBS 20/40 SUPPORT- WANLI SAND AWAY. WELL IS FREEZE PROTECTED, RELOAD SAND AND CAPITAL WATER FOR FINAL STAGES. 10/19/19 DRILLING PUMPED SATGES 8 THRU 13 OF FRAC, TOTAL OF 557,881 LBS 20/40 SUPPORT - WANLI SAND AWAY. WELL IS FREEZE PROTECTED, FRAC COMPLETE. CAPITAL 10/20/19 DRILLING MOBILIZED EQUIP TO CD5 FOR JOB IN AM (FRAC STILL RIGGING SUPPORT - DOWN) IN PROGRESS. CAPITAL 10/21/19 DRILLING Sl BRUSHED & FLUSHED TBG (UNABLE TO PASS 12,036' SLM W/2.50" GAUGE RING). ATTEMPTED TO SET 2.81" XXN PLUG @ 12,104' RKB, UNSUCCESSFUL DUE TO FRAC SAND. BRUSHED & FLUSHED TBG W/ SLICK SEAWATER TO 12,104' RKB. SET 2.81" XXN PLUG @ 12,104' RKB. ATTMEMPT TO PT TBG, UNABLE TO PRESSURE TBG. PULLED PLUG. FLUSHED TBG W/ 300 BBLS SEAWATER & 2.60" SWAGE. ATTEMPT TO SET 2.81" XXN PLUG @ 12,104' RKB, AND PLUG PASSES THROUGH NIPPLE. SET 3 1/2" SLIPSTOP CATCHER @ 12,069' RKB. PULLED DV @ 11,898' RKB, SET 1/4" OV @ SAME. DDT IA 500 TO 200 PSI. PULLED DV @ 8138' RKB. SET 3 1/2" EVOTRIEVE PLUG @ 12,059' RKB. CMIT 2500 PSI (PASSED). 10/22/19 DRILLING (MISC) TxIA DDT (PASSED), SET & TEST 4" HP BPV TO 1208 PSI SUPPORT- (PASSED), T POT (PASSED), SWAP 1 OK FRAC TREE & THA (COMPLETE), CAPITAL T PPPOT (PASSED), TREE SHELL TEST TO 5K (PASSED). Hydraulic Fracturing Fluid Product Component Information Dis ,e Fracture Date 10/1912019 ata.: Alaska County: Hamson Ba API Number. 5010320800 O NORTH SLOPE - Operator Name: ESUS Well Name and Number. COS 92 Longitude: 151.22 Latitude: 70.31 Long/Lat Projection: NAD27 IndlardFederal: none production Type, OII True Vedkal Depth (TVD): 7 473 Total Water Volume a 555,254 Hydraulic Fradunng Fluid Composition. Chemical Maximum Abstract Maximum Ingredient Ingredient Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Ingredient Mass Comments Company First Name Last Name Email Phone Number (CAB (% by mass)" HF Fluid (A by lbs g) mass)" Sea Water Operator Base Flud Water 7732-165 6. 1 o 4552180 Densd =8.540 MICROBIOCIDE Hellbuton Bodo listed Belon IC listed Below 0 NA CL-22 VC Haliiburtm Crossiinker Listed Below Listed Be- 0 NA CHelLbuelau ton linker Listed B CROSSLiNKER Listed eebn 0 NA LOSURF-300D Hallbunon Non-ionic SurfactantListed Beton Listed Blow 0 NA MO -67 Hellbuton pH Control Additive Listed Beim Listed Beim 0 NA OPTIFLO411 DELAYED RELEASE Halliburton Breaker listed Beim Listed Below 0 NA BREAKER SP BREAKER Hallbuton Breaker Daed Beim listed Beim 0 NA WG -36 GELLING Hallbudon Gelling Agent Listed Below AGENT listed Beim 0 NA LVT-2110 I Penreco Freeze Protect Listed Belau Usted Bebe 0 NA WeMi Wanli 27/40 Proppent Additive Listed Belau Listed Belau 0 NA Cam Ingredieras Listed Above listed Abow 124 Triniethylibencene 95438 1.01. De 17 D, 42 2-Bromo-2aitm1,3 id 5251.7 100,008 0.001421 84 Denies Tuck, Halliburton, 3000 Donee.Tuck@ Acrylate polymer Propr.Wry l.DOa 1.D0 — 54 N. Sem Houston Pkwy E., Hopston, Hallbudon Dame Tuck Mallburton.co 281571-( Tx 77032,291- in 8715226 AmmoNun persulftile 7727-59-0 1nn,o09 -.oilr58 1101 D --...Tuck@ Borate salts Proprietary 3208 Hallbuton Denise Tuck Hallibudan.m 281-871-6226 in Corundum 1302-74.5 721760 Cr altars sfi-, quartz 1480660-7 30. Dog .DD5fi 64 336 DoneeTwk® Cued acrylic ram Proprietary -+D. Doe 9. DD: see 330 Kailbuton Dene. Tuck Hallbuton.co 281-871-6226 Enharol 64-17-5 2482 Guar gum 900630-0 12495 Heavy on, r1-na naptiffic 64742-345 -+D. D08 .02092, 1241 Hydratreated Distillate, f M 64742-47-B la D.908 .94—_ 5=1 MWRe 1302-938 95.009 8. 42 J__=15 499680 Naphthalene 91-043 S.Dos —13— 207 D-i.e.Tuck@ Oylated Plsnolic resin Proprietary 1655 HaObuton Dais, Tuck Hallibun..co 281-871-6226 Pdy(oxy-1,2ethasdiy0, alp11-(4- nonylphsayl)amegahydrmry-, 127087-97-0 S. onB O. oD.199F 207 Marched Pa—nn famine 596294^.000 fi5.ao8 J.D.4�5e 3208 Pat—lum mold, 13165&3 O. DDll11 106 Potassium mctaborate 137099495 D.Do9 D. o 2131£ 1264 Sodium cartaxymanyl 900432-0 1.Da8 J.00 D93e 54 Sodium chbndla 7647-145 4.009 3.l ooa of 189751 Sodium glycoliRts 283632-0 1.D08 D.Daa9�8 54 Sodiumhdro>ede 1310-732 30.008 D.D1015F 208 Sodium persulfate 7775.27-1 D..1 o. or rare 14 Sod.. suffate 7757-82- 1 Water 7732-165 o. 0E 41'18 4992 ' Total Water Volume sources may include fresh water, produced water, and/or recycled water _ I Mormation is based on the mindum potemial for concentration and thus the total may be over 1001/6 Note. For Feld Development Products (products that begin with FDP), MSDS Zeal only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be duetted to the supplier who provided it. The 0cwpa0onal Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Lew protects "proprietary", "trade secret', and "confidential business information" and the criteria for haw this Informatlon is re died on an MSDS is sub'ect to 29 CFR 1910.12 andAppendix D. Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: Job End Date: State: County: API Number: Operator Name: 10/17/2019 10/19/2019 Alaska Harrison Bay 50-103-20800-00-00 ConocoPhillips Company/Burlington Resources CD5-92 70.31378100 -151.22136400 NAD83 NO NO 7,317 555,254 0 Hydraulic Fracturing Fluid Composition: r-udv. Foas Chemical Disclosure Registry GROUNDWATER <Oil&Gas Well Name and Number: Latitude: Chemical Longitude: Maximum Datum: Federal Well: Indian Well: Abstract True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 10/17/2019 10/19/2019 Alaska Harrison Bay 50-103-20800-00-00 ConocoPhillips Company/Burlington Resources CD5-92 70.31378100 -151.22136400 NAD83 NO NO 7,317 555,254 0 Hydraulic Fracturing Fluid Composition: r-udv. Foas Chemical Disclosure Registry GROUNDWATER <Oil&Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)" (% by mass)" Sea Water Operator Base Fluid Water 7732-18-5 96.00000 76.76709 Density = 8.540 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.08417 LVT-200 Penreco Freeze Protect Listed Below CL-22 UC Halliburton Crosslinker Listed Below Wanli 20/40 Wanli Proppant Company Additive Listed Below CL-31 CROSSLINKER Halliburton Crosslinker Listed Below BE-6 MICROBIOCIDE Halliburton Biocide Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below MO-67 Halliburton pH Control Additive Listed Below SP BREAKERHalliburton Breaker Listed Below WG-36 GELLING Halliburton AGENT Gelling Agent Listed Below Corundum 1302-74-5 65.00000 12.17162 Mullite 1302-93-8 45.00000 8.42651 Sodium chloride 7647-14-5 4.00000 3.19989 Hydrotreated Distillate, 64742-47-8 100.00000 light 0.84657 Guar gum 9000-30-0 100.00000 0.21070 Borate salts Proprietary 60.00000 0.05409 Potassium formate 590-29-4 60.00000 0.05409 Ethanol 64-17-5 60.00000 0.04185 Oxylated phenolic resin Proprietary 30.00000 0.02790 Potassium metaborate 13709-94-9 60.00000 0.02131 Heavy aromatic 64742-94-5 30.00000 petroleum naphtha 0.02092 Ammonium persulfate 7727-54-0 100.00000 0.01855 Sodium hydroxide 1310-73-2 30.000001 0.01075 Crystalline silica, quartz 14808-60-7 30.00000 0.00566 Cured acrylic resin Proprietary 30.00000 0.00557 Naphthalene 91-20-3 5.00000 0.00349 Poly(oxy-1,2-ethanediyl), 127087-87-0 5.00000 alpha-(4-nonylphenyl)- omega-hydroxy-, branched 0.00349 Potassium hydroxide 1310-58-3 5.00000 0.00178 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 propanediol 0.00142 Sodium glycollate 2836-32-0 1.00000 0.00090 Sodium carboxymethyl 9004-32-4 1.00000 cellulose 0.00090 Acrylate polymer Proprietary 1.00000 0.00090 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00070 Sodium persulfate 7775-27-1 100.000001 0.00024 Sodium sulfate 7757-82-6 0.100001 0.00000 :Total Water Volume sources may include various types of water including freshwater, produced water, and recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100 ***If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) HALLIBURTON Sales Order# 0906024930 Conoco Phillips Alaska CD5-92 Intervals 1-13 A -Sand Formation Harrison Bay County, AK API: 50-103-20800 Prepared for: Adam Klem October 19, 2019 Stimulation Treatment Post Job Report 25# Hybor G Prepared By: Keegan Lambe Chad Burkett Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. HALLIBURTON Table of Contents Section Page(q) Executive Summary 3 Wellbore Information 4 Actual Design 5-6 Interval Summary 7-19 Fluid System-Proppant Summary 20 Interval 1 Plots 21-28 Interval 2 Plots 29-32 Interval 3 Plots 33-36 Interval 4 Plots 37-40 Interval 5 Plots 41-44 Interval 6 Plots 45-48 Interval 7 Plots 49-52 Interval 8 Plots 53-59 Interval 9 Plots 60-63 Interval 10 Plots 64-67 Interval 11 Plots 68-71 Interval 12 Plots 72-75 Interval 13 Plots 76-79 Appendix 80 Well Summary 81 Chemical Summary 82 Planned Design 83-84 Water Straps 85 Water Straps Day 2 86 Water Analysis Day 1 87 Water Analysis Day 2 88 Real -Time QC 89 Prejob Break Test Day 1 90 Prejob Break Test Day 2 91 Fann 15 Minute Zone 1 92 Fann 15 Minute Zone 2 93 Fann 15 Minute Zone 3 94 Fann 15 Minute Zone 4 95 Fann 15 Minute Zone 5 96 Fann 15 Minute Zone 6 97 Fann 15 Minute Zone 7 98 Fann 15 Minute Zone 8 99 Fann 15 Minute Zone 9 100 Fann 15 Minute Zone 10 101 Fann 15 Minute Zone 11 102 Fann 15 Minute Zone 12 103 Fann 15 Minute Zone 13 104 Event Log Day 1 105 Event Log Day 2 106 Lab Testing 107-108 Conoco Phillips Alaska - CD5-92 TOC Engineering Executive Summary On October 17, 2019 a stimulation treatment was performed in the A -Sand formation on the CD5-92 well in Harrison Bay County, AK. The CD5-92 was a 13 stage Horizontal Sleeve Design. The proposed treatment consisted of: 518,050 gallons of 25# HyborG 16,794 gallons of 25# WaterFrac G 2,520 gallons of Freeze Protect 1,110,000 pounds of Wanli 20/40 The actual treatment fully completed 12 of 13 stages. 0 stages were skipped, and 1 stage was cut short of design. The actual treatment consisted of: 536,957 gallons of 25# HyborG 18,297 gallons of 25# WaterFrac G 2,854 gallons of Freeze Protect 1,110,400 pounds of Wanli 20/40 A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: Prior to pumping interval 1, the growler tub was measured at a 150cP fluid due to an error with the computer mixing the gel. This fluid was pumped ahead of dropping the ball and used to displace the wellbore to assist in cleaning the wellbore out. Once the viscosity had returned to a more normal range the fluid was cross-linked. During the 5ppg stage of Interval 11, the gel would no longer crosslink on surface. Sand was cut and the next ball was dropped. Prior to dropping the ball crosslink had been re- established. Due to cutting Interval 11 short, the extra proppant was scheduled to be pumped in intervals 12 and 13. On the second day of pumping the castle weights were noted to be varying. Prior to pumping the screws were slowed down to ensure that there would be enough sand to finish the entire day of pumping and not short the final higher proppant stages in the last interval. All remaining proppant on location was pumped in the final 6ppg stage. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. In order to reduce the pipe friction the surface crosslinker was adjusted down after preforming field tests to ensure the crosslinker would provide enough viscosity on surface to carry proppant. The Buffer concentration was adjusted as needed to target a ph. Gel concentrations were adjusted to target a viscosity to help manage pipe friction. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Thank you, Keegan Lambe Technical Professional Halliburton Energy Services Conoco Phillips Alaska - CD5-92 Executive Summary o.. 1o,liafli9 W., Conoco Phillips Alaska - CID5-92 Wellbore Information Q W (wl nnu I W nnu (W enm W 1.i ..i slum 6Xleym ,v, Y 41111 —1 Liai 41T 1. —1 2.317 1.,>3-wi 7:1 1- 1�: 1.�441 — 0- 45. 1M Conoco Phillips Alaska - CID5-92 Wellbore Information Conoco Phillips Alaska - CD5-92 Actual Design aaa aaaa �®m®lll�ll���m aee m0�®e�lllllllle•�� aaa ®llllllE�71111111^ *J 111111! s lllllllE� lllll� lllllly Conoco Phillips Alaska - CDS-92 Actual Design Interval Summary CD5-92 - A -Sand - Interval 1 Interval Summary Start Date/Time: 10/17/19 12:32 End Date/Time: 10/17/19 13:55 Pump Time: 83 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,352 psi Initial BH Pressure (Breakdown). 7,665 psi Max Rate: 30.2 bpm Max Surface Pressure: 7,110 psi Max BH Pressure: 6,627 psi Average Rate: 21.5 bpm Average Missile Pressure: 4,944 psi Average Surface Pressure: 4,975 psi Average BH Pressure: 5,797 psi Average Missile HHP: 2,599 hhp Initial OA Pressure: 37 psi Max OA Pressure: 846 psi Max Proppant Concentration: 3.98 ppg Average Visc: 21.4 cP Average Temp: 91.78 F Average pH: 9.84 Proppant Summary Wanli 20/40 Pumped: 64,449 lbs Total Proppant Pumped" : 64,449 lbs Proppant in Formation: 64,449 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 25# HyborG Volume: 46,566 gal 25# WaterFrac G Volume: 7,580 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 12,706 gal Proppant Laden Fluid Volume: 31,654 gal Flush Volume: 0 gal Establish Stable Fluid Volume: 13,606 gal Ball Drop - 1.855 Volume: 1,157 gal Spacer and Ball Drop - 1.895 Volume: 1,049 gal Interval Status: Completed Comments: Issues with the ADP delayed pumping until the afternoon. The ADP then mixed a tub with a Visc o 150cP. This tub was pumped off as linear until viscosity readings became normal. Crosslink was then started. Van died after running out of fuel. Dropped the ball after establishing 20bbl of good crosslink. Dropped rate after 115bbl to 20bpm per design. After seating the ball, rate was adjusted as pressure allowed. 'Values foi Fi •opan! a'e taken m ,_ e (,arcula' . base:i u' iia=[i�,l_ viiiobies rcppant is baled cfl Of ..ahs`?f t ket vNLIrnes and tray vary shg fitly From this irnber 0 bbls 1,109 bbls 180 bbls 0 bbls 303 bbls 754 bbls 0 bbls 324 bb/s 28 bbls 25 bb/s tngineer: Keegan Lambe Treater. Josh Caprio Supervisor. Josh Caprio Customer Engineer: Sandeep Pedam Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 7 CD5-92 - A -Sand - Interval 2 Interval Summary Start Date/Time: 10/17/19 13:55 End Date/Time: 10/17/19 14:33 Pump Time: 38 min Initial Rate (Breakdown): 12.8 bpm Initial Surface Pressure (Breakdown): 5,742 psi Initial BH Pressure (Breakdown): 7,358 psi Max Rate: 32.0 bpm Max Surface Pressure: 7,104 psi Max BH Pressure: 6,378 psi Average Rate. 27.3 bpm Average Missile Pressure: 6,065 psi Average Surface Pressure: 6,064 psi Average BH Pressure: 6,053 psi Average Missile HHP: 4,063 hhp Initial OA Pressure: 821 psi Max OA Pressure: 822 psi Max Proppant Concentration: 4.05 PPg Average Visc: 18.2 cp Average Temp: 92.7 F Average pH: 9.75 Proppant Summary Wanli 20/40 Pumped: 66,515 lbs Total Proppant Pumped' : 66,515 Itis Proppant in Formation: 66,515 Itis Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 40,724 gal 970 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,643 gal 301 bbls Proppant Laden Fluid Volume: 27,226 gal 648 bbls Spacer and Ball Drop - 1.935 Volume: 855 gal 20 bbls Interval Status: Completed Comments: I ested the effect of dropping the surtace linker in the UG and once the surtace link was shown, Engineer: Keegan Lambe adjusted the crosslinker concentration along with the buffer. Adjusted the pumping schedule per Treater. Josh Caprio customer request. Supervisor: Josh Caprio �,Lca .r prcppc.nt are ia;! from oofr Ca Cdati�ns based or rru,t,pl :a'a_les Customer Engineer. Sandeep Pedam rcppanl is billed off "relght a bit vciunnes ar:i may v,. 9 sliq^,tli from this imber Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 8 CD5-92 - A -Sand - Interval 3 Interval Summary Start Date/Time: 10/17/19 14:33 End Date/Time: 10/17/19 15:12 68,782 Pump Time: 39 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,277 psi Initial BH Pressure (Breakdown): 7,391 psi Max Rate: 31.0 bpm Max Surface Pressure: 6,886 psi Max BH Pressure: 6,210 psi Average Rate: 27.1 bpm Average Missile Pressure: 5,483 psi Average Surface Pressure: 5,480 psi Average BH Pressure: 5,835 psi Average Missile HHP: 3,647 hhp Initial OA Pressure: 584 psi Max OA Pressure: 588 psi Max Proppant Concentration: 4.05 Ppg Average Visc: 16.3 cP Average Temp: 93.4 F Average pH: 9.82 Proppant Summary Wanli 20/40 Pumped: 68,782 lbs Total Proppant Pumped* : 68,782 lbs Proppant in Formation: 68,782 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 41,405 gal 986 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,602 gal 300 bbls Proppant Laden Fluid Volume: 27,917 gal 665 bbls Spacer and Ball Drop - 1.975 Volume: 886 gal 21 bbls Interval Status: Completed Comments Adjusted MO -67 set point to maintain a ph. Proppant placed to adjusted design. Engineer. Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio 'Values for prcppant aretaken from software cab,ulations based or, lrult,ple varSeFles Customer Engineer: Sandeep Pedam Proppant is billed oft of weight ticket volumes and may vary slightly from this number Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 9 CD5-92 - A -Sand - Interval 4 Interval Summary Start Date/Time: 10/17/19 15:12 End Date/Time: 10/17/19 15:53 Pump Time: 41 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,572 psi Initial BH Pressure (Breakdown): 7,682 psi Max Rate: 30.1 bpm Max Surface Pressure: 7,103 psi Max BH Pressure: 6,382 psi Average Rate: 26.7 bpm Average Missile Pressure: 5,817 psi Average Surface Pressure: 5,816 psi Average BH Pressure: 5,842 psi Average Missile HHP: 3,808 hhp Initial OA Pressure: 586 psi Max OA Pressure: 649 psi Max Proppant Concentration: 6.15 PP9 Average Visc: 18.1 cP Average Temp: 91.2 F Average pH: 9.87 Proppant Summary Wanli 20/40 Pumped: 102,548 lbs Total Proppant Pumped' : 102,548 Ibs Proppant in Formation: 102,548 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 25# HyborG Volume: 42,544 gal 25# WaterFrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 12,615 gal Proppant Laden Fluid Volume: 29,091 gal Spacer and Ball Drop - 2.015 Volume: 838 gal Interval Status: Completed Comments 0 bbls 1,013 bbls 0 bbls 0 bbls 300 bbls 693 bb/s 20 bbls Sample port was clogged during pad. Pad crosslink sample was not brought in. Lost proppant Engineer: Keegan Lambe concentration in 4ppg due to ice chunks in the hopper. Volume for stages was kept the same and Treater: Josh Caprio 6ppg was extended to make up the proppant concentration. Supervisor: Josh Caprio 'Values for proppant are taken from software calculations based on multiple variables. Customer Engineer.' Sandeep Pedam Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 10 CD5-92 - A -Sand - Interval 5 Interval Summary Start Date/Time: 10/17/19 15:53 End Date/Time: 10/17/19 16:32 Pump Time: 39 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,639 psi Initial BH Pressure (Breakdown): 7,451 psi Max Rate: 29.8 bpm Max Surface Pressure: 7,106 psi Max BH Pressure: 6,351 psi Average Rate: 27.0 bpm Average Missile Pressure: 6,077 psi Average Surface Pressure: 6,077 psi Average BH Pressure: 5,881 psi Average Missile HHP: 4,026 hhp Initial OA Pressure: 577 psi Max OA Pressure: 598 psi Max Proppant Concentration: 6.01 PPg Average Visc: 16.6 cp Average Temp: 91.4 F Average pH: 9.76 Proppant Summary Wanli 20/40 Pumped: 97,569 lbs Total Proppant Pumped' : 97,569 lbs Proppant in Formation: 97,569 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 25# HyborG Volume: 40,174 gal 25# WaterFrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 12,633 gal Proppant Laden Fluid Volume: 27,156 gal Spacer and Ball Drop - 2.055 Volume: 385 gal Interval Status: Completed Comments: Ice chunks in hopper during 6ppg lead to the concentration dipping. Cleaned up pumped proppant in 6ppg to clean the hopper up. /alu.s far p,o r., .t . takes, from a c , ,tul v, ,abies ?r p?art is billed off �)f w_ int ti ! � _t;d mai a , s n t.on, Irws 0 bbls 957 bbls 0 bbls 0 bbls 301 bbls 647 bbls 9 bbls Engineer: Keegan Lambe Treater. Josh Caprio Supervisor: Josh Caprio Customer Engineer. Sandeep Pedam Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 11 CD5-92 - A -Sand - Interval 6 Interval Summary Start Date/Time: 10/17/19 16:32 End Date/Time: 10/17/19 17:11 Pump Time: 39 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,590 psi Initial BH Pressure (Breakdown): 7,499 psi Max Rate: 31.1 bpm Max Surface Pressure: 6,938 psi Max BH Pressure: 5,978 psi Average Rate: 26.8 bpm Average Missile Pressure: 5,532 psi Average Surface Pressure: 5,525 psi Average BH Pressure: 5,657 psi Average Missile HHP: 3,634 hhp Initial OA Pressure: 581 psi Max OA Pressure: 585 psi Max Proppant Concentration: 6.26 Ppg Average Visc: 16 cp Average Temp: 89.8 F Average pH: 9.71 Proppant Summary Wanli 20/40 Pumped: 90,331 lbs Total Proppant Pumped` : 90,331 lbs Proppant in Formation: 90,331 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 38,758 gal 923 bbls 25# WaterFrac G Volume: 0 gal 0 bb/s Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,612 gal 300 bbls Proppant Laden Fluid Volume: 25,818 gal 615 bbls Spacer and Ball Drop - 2.095 Volume: 328 gal 8 bbls Interval Status: Completed Comments Proppant pumped to design. During 6ppg proppant one of the pumps had internal issues. The Engineer: Keegan Lambe pump passed the debris. After the pump cleared out of proppant the pump was brought offline and Treater: Josh Caprio a different pump was brought online. Supervisor: Josh Caprio Values for proppant are taken from sofl*are calculations based oc multiple variables Customer Engineer: Sandeep Pedam Pr000ant is bdied off of vveig'ht ticket volumes and may vary l,gh:ly from this number Customer Rep. Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 12 CD5-92 - A -Sand - Interval 7 Interval Summary Start Date/Time: 10/17/19 17:11 End Date/Time: 10/17/19 17:50 Pump Time: 39 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,785 psi Initial BH Pressure (Breakdown): 7,586 psi Max Rate: 32.2 bpm Max Surface Pressure: 6,384 psi Max BH Pressure: 6,048 psi Average Rate: 26.8 bpm Average Missile Pressure: 5,026 psi Average Surface Pressure: 5,015 psi Average BH Pressure: 5,596 psi Average Missile HHP: 3,295 hhp Initial OA Pressure: 554 psi Max OA Pressure: 619 psi Max Proppant Concentration: 6.22 PP9 Average Visc: 17.3 cp Average Temp: 91.3 F Average pH: 9.8 ISDP: 4960 psi Final Fracture Gradient: 0.667 psi/ft Proppant Summary Wanli 20/40 Pumped: 98,332 lbs Total Proppant Pumped' : 98,332 lbs Proppant in Formation: 98,332 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 39,928 gal 951 bbls 25# WaterFrac G Volume: 7,161 gal 171 bbls Freeze Protect Volume: 1,165 gal 28 bbls Fluid Summary (by stage description) Pad Volume: 12,625 gal 301 bbls Proppant Laden Fluid Volume: 27,303 gal 650 bbls Flush Volume: 7,161 gal 171 bbls Establish Stable Fluid Volume: 0 gal 0 bbls Freeze Protect Volume: 1,165 gal 28 bbls Interval Status: Completed Comments Lost a pump during the interval due to a hydraulic issue. Flushed the well using linear, seawater Engineer.' Keegan Lambe and LVT. LVT took a little longer than anticipated to get to the inline. Pumped the flush volume at Treater: Josh Caprio full rate then finished the freeze protect at 2bpm. Supervisor: Josh Caprin 'values Por proopant are taken from software calculations based on multiple variables Customer Engineer: Sandeep Pedam Proppant is killed off of weight ticket volumes and may vary shrj,-diy from this rr_nnber Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 13 CD5-92 - A -Sand - Interval 8 Interval Summary Start Date/Time: 10/19/19 10:23 End Date/Time: 10/19/19 11:20 Pump Time: 57 min Initial Rate (Breakdown): 11.2 bpm 300 bbls Initial Surface Pressure (Breakdown): 5,611 psi 587 bbls Initial BH Pressure (Breakdown): 6,786 psi 139 bbls Max Rate: 30.5 bpm 19 bbls Max Surface Pressure: 7,096 psi 18 bbls Max BH Pressure: 5,772 psi Average Rate: 24.2 bpm Average Missile Pressure: 4,578 psi Average Surface Pressure: 4,573 psi Average BH Pressure: 5,374 psi Average Missile HHP: 2,717 hhp Initial OA Pressure: 0 psi Max OA Pressure: 261 psi Max Proppant Concentration: 5.86 PP9 Average Visc: 18.9 cP Average Temp: 82.2 F Average pH: 9.82 Proppant Summary Wanli 20/40 Pumped: 83,669 lbs Total Proppant Pumped' : 83,669 lbs Proppant in Formation: 83,669 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 44,629 gal 1,063 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,589 gal 300 bbls Proppant Laden Fluid Volume: 24,647 gal 587 bbls Establish Stable Fluid Volume: 5,836 gal 139 bbls Spacer and Ball Drop - 2.135 Volume: 804 gal 19 bbls Spacer and Ball Drop - 2.175 Volume: 753 gal 18 bbls Interval Status: Completed Due to a castle scale having issues screws were adjusted as needed. Proppant placed to design. Engineer. Keegan Lambe Swapped a pump during the ball drop due to a packing issue. Treater: Josh Caprio Supervisor. Josh Capno 'Values for proppant are taken from software calculations based on multiple variables. Customer Engineer.' Sandeep Pedam Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Conoco Phillips Alaska - CDS-92 Interval Summary 14 CD5-92 - A -Sand - Interval 9 Interval Summary Start Date/Time: 10/19/19 11:20 End Date/Time: 10/19/19 11:58 Pump Time: 38 min Initial Rate (Breakdown): 11.3 bpm Initial Surface Pressure (Breakdown): 5,601 psi Initial BH Pressure (Breakdown): 7,248 psi Max Rate: 30.6 bpm Max Surface Pressure: 7,096 psi Max BH Pressure: 5,782 psi Average Rate: 26.8 bpm Average Missile Pressure: 5,506 psi Average Surface Pressure: 5,511 psi Average BH Pressure: 5,489 psi Average Missile HHP: 3,619 hhp Initial OA Pressure: 261 psi Max OA Pressure: 522 psi Max Proppant Concentration: 5.81 PPg Average Visc: 18.4 cp Average Temp: 86.2 F Average pH: 9.81 Proppant Summary Wanli 20/40 Pumped: 84,432 lbs Total Proppant Pumped' : 84,432 lbs Proppant in Formation: 84,432 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 38,361 gal 913 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,626 gal 301 bbls Proppant Laden Fluid Volume: 25,023 gal 596 bbls Spacer and Ball Drop - 2.215 Volume: 712 gal 17 bbls Interval Status: Completed Comments Interval pumped to design. Engineer: Keegan Lambe Treater. Josh Caprio Supervisor. Josh Caprio Values f-,,, proppant _ taker ficiii -cft��, caicu;a',�s bases an i,,w-pll-.vanc!es Customer Engineer Sandeep Pedam Proppant is oiled off o rat ti k.et voliumps and may vay slay i from, this rrber Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 15 CD5-92 - A -Sand - Interval 10 Interval Summary Start Date/Time: 10/19/19 11:58 End Date/Time: 10/19/19 12:37 Pump Time: 39 min Initial Rate (Breakdown): 11.7 bpm Initial Surface Pressure (Breakdown): 5,523 psi Initial BH Pressure (Breakdown): 7,302 psi Max Rate: 30.6 bpm Max Surface Pressure: 7,060 psi Max BH Pressure: 5,816 psi Average Rate: 26.8 bpm Average Missile Pressure: 5,565 psi Average Surface Pressure: 5,568 psi Average BH Pressure: 5,463 psi Average Missile HHP: 3,654 hhp Initial OA Pressure: 522 psi Max OA Pressure: 618 psi Max Proppant Concentration: 5.82 ppg Average Visc: 18.5 cP Average Temp: 84.1 F Average pH: 9.77 Proppant Summary Wanli 20/40 Pumped: 90,247 lbs Total Proppant Pumped' : 90,247 lbs Proppant in Formation: 90,247 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 39,546 gal 942 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,612 gal 300 bbls Proppant Laden Fluid Volume: 26,127 gal 622 bbls Spacer and Ball Drop - 2.255 Volume: 807 gal 19 bbls Interval Status: Completed After swapping castles, frozen chunks of sand fell out of the first castle. Drained the hopper at the Engineer.' Keegan Lambe end 6ppg to remove the ice out of the hopper. Treater: Josh Caprio Supervisor: Josh Capno aloes for proppa rt are taken frorr sof .,.are calculations based on multiple- wenabies Customer Engineer Sandeep Pedam ?roppant Is billed off of ve!gnt ticket volunnes and may vary sl,gh',ly from this namber Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 16 CD5-92 - A -Sand - Interval 11 Interval Summary Start Date/Time: 10/19/19 12:37 End Date/Time: 10/19/19 13:11 Pump Time: 34 min Initial Rate (Breakdown): 11.6 bpm Initial Surface Pressure (Breakdown): 5,660 psi Initial BH Pressure (Breakdown): 7,206 psi Max Rate: 30.8 bpm Max Surface Pressure: 6,111 psi Max BH Pressure: 5,203 psi Average Rate: 28,0 bpm Average Missile Pressure: 4,846 psi Average Surface Pressure: 4,842 psi Average BH Pressure: 5,061 psi Average Missile HHP: 3,320 hill Initial OA Pressure: 614 psi Max OA Pressure: 658 psi Max Proppant Concentration: 5.07 PP9 Average Visc: 18.4 cp Average Temp: 84.7 F Average pH: 9.71 Proppant Summary Wanli 20/40 Pumped: 69,926 lbs Total Proppant Pumped` : 69,926 lbs Proppant in Formation: 69,926 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 25# HyborG Volume: 38,023 gal 25# WaterFrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 12,621 gal Proppant Laden Fluid Volume: 24,898 gal Spacer and Ball Drop - 2.295 Volume: 504 gal Interval Status: Cut Short Comments 0 bbls 905 bbls 0 bbls 0 bbls 301 bbls 593 bbls 12 bbls During 5ppg noticed a decreasing pressure trend. Fluid would not lip, lost surface crosslink. The Engineer.' Keegan Lambe pH was still holding steady. Cut proppant and dropped the ball for the next stage. Treater: Josh Caprio Supervisor. Josh Caprio Values for proppant are taken from software calculations based on multiple variables Customer Engineer: Sandeep Pedam Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 17 CD5-92 - A -Sand - Interval 12 Interval Summary Start Date/Time: 10/19/19 13:11 End Date/Time: 10/19/19 13:51 102,369 Pump Time: 40 min Initial Rate (Breakdown): 13.1 bpm Initial Surface Pressure (Breakdown): 5,514 psi Initial BH Pressure (Breakdown): 6,522 psi Max Rate: 30.6 bpm Max Surface Pressure: 7,100 psi Max BH Pressure: 5,160 psi Average Rate: 27.7 bpm Average Missile Pressure: 5,571 psi Average Surface Pressure: 5,570 psi Average BH Pressure: 5,041 psi Average Missile HHP: 3,784 hhp Initial OA Pressure: 655 psi Max OA Pressure: 696 psi Max Proppant Concentration: 6.06 PPg Average Visc: 18.5 cp Average Temp: 86.3 F Average pH: 9.75 Proppant Summary Wanli 20/40 Pumped: 102,369 lbs Total Proppant Pumped' : 102,369 lbs Proppant in Formation: 102,369 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 25# HyborG Volume: 41,800 gal 995 bbls 25# WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,632 gal 301 bbls Proppant Laden Fluid Volume: 28,117 gal 669 bbls Spacer and Ball Drop - 2.335 Volume: 1,051 gal 25 bbls Interval Status: Completed Comments 6ppg proppant was extended due to proppant being cut from interval 11. Engineer.' Keegan Lambe Treater: Josh Caprio Supervisor. Josh Caprio _� ror r pliant t,k h fr.��; _ ��_:a ui,s bas=. _r r �It� l ,a�lables Customer Engineer. Sandeep Pedam or�n: is billed Off votui,.e, and may "ai, slid Jj fico- ! i � n_Irl?er Customer Rep: Paul Bessette Conoco Phillips Alaska - CD5-92 Interval Summary 18 CD5-92 - A -Sand - Interval 13 Interval Summary Start Date/Time: 10/19/19 13:51 End Date/Time: 10/19/19 14:35 Pump Time: 44 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,331 psi Initial BH Pressure (Breakdown): 6,735 psi Max Rate: 30.5 bpm Max Surface Pressure: 7,106 psi Max BH Pressure: 5,199 psi Average Rate: 27.4 bpm Average Missile Pressure: 5,543 psi Average Surface Pressure: 5,544 psi Average BH Pressure: 5,067 psi Average Missile HHP: 3,724 hhp Initial OA Pressure: 684 psi Max OA Pressure: 719 psi Max Proppant Concentration: 6.49 ppg Average Visc: 18.4 cP Average Temp: 83.7 F Average pH: 9.77 ISDP: 4926 psi Final Fracture Gradient: 0.660 psi/ft Proppant Summary Wanli 20/40 Pumped: 127,238 lbs Total Proppant Pumped` : 127,238 lbs Proppant in Formation: 127,238 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 25# HyborG Volume: 44,499 gal 25# WaterFrac G Volume: 3,556 gal Freeze Protect Volume: 1,689 gal Fluid Summary (by stage description) Pad Volume: 12,620 gal Proppant Laden Fluid Volume: 31,879 gal Flush Volume: 3,556 gal Freeze Protect Volume: 1,689 gal Interval Status: Completed Comments 0 bbls 1,060 bbls 85 bbls 40 bbls 300 bbls 759 bbls 85 bbls 40 bbls 6ppg proppant was extended due to proppant being cut from interval 11. Pumped all remaining Engineer: Keegan Lambe proppant at the end of 6ppg in the castle. During 6ppg proppant one of the hoses on a pump had a Treater: Josh Caprio leak. Shut that pump in and opened another. Supervisor.Josh Caprio Vaiues for proppant are iak.en from software caiculations based on rru!tip(e variacies Customer Engineer Sandeep Pedam �roppant is billed or o`,/.,eight ticket vciumes and ma✓ vary s!ighdy from ;his rr_imber Customer Rep: Paul Bessette Conoco Phillips Alaska - CDS-92 Interval Summary 19 Customer Conoco Phillips Alaska Formation A -Sand HALUBURTON or w mac+ I ErcRenceme... �. �. Lease CD5-92 570 API 50-103-20800 Date October 17, 2019 Well Summary Planned Recorded Fluids Fluids Proppants Interval Sea Water 2517 HyborG 2577 WaterFrac G Freeze Protect Total Fluid Wanli 20/40 TotalProppant lbs Total gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs 1 46,566 1,109 7,550 180 60,172 1,433 64,449 64,449 2 40,724 970 40,724 970 66,515 66,515 3 41,405 986 41,405 986 68,782 68,782 4 42,544 1,013 42,544 1,013 102.,548 102,548 5 40,174 957 40,174 957 97,569 97,569 638758 923 38,758 923 90,331 90,331 7 39,928 951 7,161 171 1,165 28 48,254 1,149 98,332 98,332 8 44,629 1,063 44,629 1,063 83,669 83,669 9 38,361 913 38,361 913 84,432 84,432 10 39,546 942 39,546 942 90,247 90,247 11 38,023 905 38,023 905 69,926 69,926 12 41,800 995 41,800 995 102,369 102,369 13 44,499 1,060 3,556 85 1,689 40 49,744 1,184 127,238 127,238 Minimum 38023 905 3556 SS 1165 28 38023 905 64449 64449 Average 41304 983 6099 145 1427 34 43395 1033 88185 88185 Maximum 46566 1109 7580 180 1689 40 60172 1433 127238 127238 Planned Recorded Fluids Proppants Sea Water 25# HyborG 25# WaterFrac G Freeze Protect Total Fluid Wanli 20/40 Total Proppant gal bbl gal bbl gal bbl galbbl gal bbl lbs Total 0 0 518,050 12,335 16,794 400 2,520 60 537,364 12,794 11110,000 1,110,000 0 0 536,957 12,785 18,297 436 2,854 68 564,134 13,432 1,1461407 1,146,407 Weight Tickets 1,110,400 1,110,400 IFS numbers for proppant are taken from software "• Proppant is billed from Weight Ticket volumes Conoco Phillips Alaska - CD5-92 Fluid System-Proppant Summary Pressure Test - Day 1 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 09:25 09:30 09:35 09:40 09:45 10/17/2019 10/17/2019 Time Global Event Log 77 Pressure Test 0925:17 ❑8 Pressure Test- Globals 09:31:04 ❑9 Pressure Test- Locals 09:31:381® Pressure Test- Max 09:44:52 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LIM 50-103-20800 Conoco Phillips Alaska - C05-92 Interval 1 Plots Nitrogen Pop -Off Test - Day 1 Treating Pressure (psi) — Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) �nnnn 10:04 10:05 10:06 10:07 10:08 10:09 10:10 10/17/2019 10/17/2019 Time Global Event Log N2 Pop @ 8432psi 10:05:59 N2 Pop @ 8554psi 10:08:48 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LAM: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 1 Plots Blender Chemical Plot - Bucket Tests Day 1 131 CL -31 Cone -LA1 (gal/Mgal) A B1 CL -22 UC Cone -LA2 (gal/Mgal) B1 M0-67 Cone -LA5 (gal/Mgal) B B1 Optiflo-III Cone -DA2 (Ib/Mgal) B 07:00 07:05 07:10 07:15 07:20 07:25 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LAM: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 1 Plots ADP Chemical Plot - Bucket Tests Day 1 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B n n 4^^ 07:27:30 07:28:00 07:28:30 07:29:00 07:29:30 07:30:00 07:30:30 10/17/2019 10/17/2019 Time Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska-CD5-92 Interval 1 Plots 24 A B 10000 1-- 9000- 8000- 7000- 6000- 5000- 4000- 3000- 2000- 1000- C 00080007000600050004000300020001000 Treatment Plot - Interval 01 -reating Pressure (psi) A Slurry Rate (bpm) — - E >lurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C nu owe- 1--;% n n,.--1 OLI T,-,- / ri _. . r C D 0 175 150 125 100 175 12:40 13:00 13:20 13:40 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 LNM: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 1 Plots 25 A 3.0 2.5 2.0 1.5 1.0 0.5 M64 Blender Chemical Plot - Interval 01 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Cone -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B 12:40 13:00 13:20 13:40 14:00 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 "" Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 1 Plots 26 12:40 13:00 13:20 13:40 14:00 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 "" Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 1 Plots 26 ADP Chemical Plot - Interval 01 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 12:50 13:00 13:10 13:20 13:30 13:40 13:50 10/17/2016 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-10320800 Conoco Phillips Alaska - CD5-92 Interval 1 Plots 27 Net Pressure Plot - Interval 01 Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B M Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LMA: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 1 Plots A B 100007 1 :111 3000 2000 1000 0 Treatment Plot - Interval 02 Treating Pressure (psi) -- A Slurry Rate (bpm) - - B Slurry Proppant Colic (lb/gal) C BH Proppant Conc (Ib/gal) C Gauge BH Pres (r)si) A Actual BH Tema ('F') D C D 0 175 150 125 100 75 13:50 14:00 14:10 14:20 14:30 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBIJS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 """ " Well Description: CD5 92 LMA: 50-10320800 Conoco Phillips Alaska-CD5-92 Interval2 Plots 29 A 3. 2. 2. M a Blender Chemical Plot - Interval 02 B1 CL -31 Conc -LA1 (gal/Mgal) - A 131 CL -22 UC Conc -LA2 (gal/Mgal) A 61 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 13:50 14:00 14:10 14:20 14:30 10/17/2019 10/17/2019 Time Custorrer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 2 Plots 30 ADP Chemical Plot - Interval 02 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) Ell B 1 1 1 0 0 0 0 0 13:50 14:00 14:10 14:20 14:30 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Jab Date: 17 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 LAM 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 2 Plots 31 Net Pressure Plot - Interval 02 - Net Gauge BH Pres (psi) A - BH Proppant Conc (Ib/gal) B 10 Time (min) Custolrer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 "� Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 2 Plots. A B 10000 1 9000- 8000- 7000- 6000- 5000- 1 0008000-700060005000 1 Treatment Plot- Interval 03 -reating Pressure (psi) A Slurry Rate (bpm) E (Ib/gait — C BH Proppant Conc (Ib/gal) — -- ---- C au ores ir�;� A _..... _. C D 0 [175 150 125 100 75 50 25 14:30 14:40 14:50 15:00 15:10 10/17/2019 Time 10/17/2019 Custorrer — CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVN: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 3 Plots 33 Blender Chemical Plot - Interval 03 B1 CL -31 Cone -LAI (gal/Mgal) A 131 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B 61 Optiflo-III Conc -DA2 (Ib/Mgal) B 14:30 14:40 14:50 15:00 15:10 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UM 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval Plots ADP Chemical Plot - Interval 03 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (ib/Mgal) BI B 14:30 14:40 14:50 15:00 15:10 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVN: 50-103-20800 Conoco Phillips Alaska-CD5-92 Int.Nal3 Plots 35 W Net Pressure Plot - Interval 03 Net Gauge BH Pres (psi) H BH Proppant Conc (Ib/gal) B 1U Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LAM 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 3 Plots A B 10000 1 9000- 8000- 7000- 6000- 5000- 4000 0008000700060005000 4000 3000 2000 1000 Treatment Plot - Interval 04 `reating Pressure (psi) A Slurry Rate (bpm) — E flurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A A —.— -1.1 r__.._ i r, r C D 0 175 150 125 100 75 15:10 15:20 15:30 15:40 15:50 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 IPM: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 4 Plots 37 Blender Chemical Plot - Interval 04 131 CL -31 Conc -LA1 (gal/Mgai) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-Ill Conc -DA2 (Ib/Mgal) B 15:10 15:20 15:30 15:40 15:50 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska -CD5-92 Interval Plots ADP Chemical Plot - Interval 04 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B U B 15:10 15:20 15:30 15:40 15:50 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phil l ips Alaska - CDS-92 Int—al4 Plots 39 Net Pressure Plot - Interval 04 - Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B 1U Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LMA: 50-10320800 Conoco Phillips Alaska - CDS-92 Interval 4 Plots A B 100007 1 7000 6000 5000 4000 3000 2000 1000 Treatment Plot- Interval 05 -reating Pressure (psi) A Slurry Rate (bpm) E >lurry Proppant Conc (Ib'<: - C BH Proppant Conc (Ib/gal) C C D 0 175 150 125 100 75 50 25 15:50 16:00 16:10 16:20 16:30 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order 4: 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phillips Alaska-CD5-92 Int—al5 Plots 41 Blender Chemical Plot - Interval 05 B1CL-31 Conc -LA1 (gal/Mgal) A 131 CL -22 UC Conic -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B 131 Optiflo-III Conc -DA2 (Ib/Mgal) B B 15:50 16:00 16:10 16:20 16:30 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UM 50-10320800 Conoco Phillips Alaska-CD5-92 Interval 5 Plots 42 ADP Chemical Plot - Interval 05 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B I� 15:50 16:00 16:10 16:20 16:30 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order M 0906024930 Well Description: CD5 92 UVM: 50-103-20800 Conoco Phillips Alaska-CD5-92 Intervals Plots Net Pressure Plot - Interval 05 - Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B 10 Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 - "a Well Description: CD5 92 LI M: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 5 Plots A 10000- 9000- 8000-- 7000- 6000 5000- 4000 3000 2000 1000 0j B 1 Treatment Plot - Interval 06 reating Pressure (psi) --- A Slurry Rate (bpm) E Jurry Proppant Conc (lb!gai) C BH Proppant Conc (Ib/gal) C C D 0 175 I --150 125 100 75 16:30 16:40 16:50 17:00 17:10 10/17/2019 Time 10/17/2019 Custo rer. CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: _ 50-103-20800— - d Conoco Phillips Alaska -CDS-92 I ntmal 6 Plots 45 Blender Chemical Plot - Interval 06 B1 CL -31 Conic -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A 131 MO -67 Conc -LA5 (gal/Mgal) B 61 Optiflo-III Conc -DA2 (Ib/Mgal) B B o n 16:30 16:40 16:50 17:00 17:10 10/17/2019 10/17/2019 Time Custoner: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska-CD5-92 Interval 6 Plots 46 ADP Chemical Plot - Interval 06 B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B 16:30 16:40 16:50 17:00 17:10 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 6 Plots Net Pressure Plot - Interval 06 Net Gauge BH Pres (psi) A BH Proppant Conc (Ib/gal) B Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 " Well Description: CD5 92 UW: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 6 Plots A B 100007 1 8000 7000 6000 5000 4000 3000 2000 1000 Treatment Plot- Interval 07 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C C D 0 —175 150 125 100 75 50 125 17:10 17:20 17:30 17:40 17:50 18:00 10/17/2019 Time 10/17/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 7 Plots 49 A Blender Chemical Plot - Interval 07 B1 CL -31 Conc -LAI (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A 61 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B1 SP breaker Conc -DA1 (Ib/Mgal) B B 17:10 17:20 17:30 17:40 17:50 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVN: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 7 Plots so ADP Chemical Plot - Interval 07 B2 Losurf-300D Conc -LA2 (gal/Mgal) — A B2 WG -36 Conc -DA1 (Ib/Mgal) B 17:10 17:20 17:30 17:40 17:50 10/17/2019 10/17/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval Plots Net Pressure Plot - Interval 07 Net Gauge BH Pres (psi) A BH Proppant Conc (ib/gal) B 10 Time (min) Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 7 Plots Pressure Test - Day 2 Treating Pressure (psi) _. Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi' �nnnn 10:10 10:12 10:14 10:16 10:18 10/19/2019 10/19/2019 Time Global Event Log [5 Pressure Test- Globals 10:08:39 [ Pressure Test- Locals 10:11:00 ❑7 Pressure Test- Max Pressure 10:17:52 N Pressure Test- Good Test Bleed Down 10:19:05 Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 8 Plots 53 Blender Chemical Plot - Bucket Tests Day 2 B1 CL -31 Conc -LAI (gal/Mgal) – A B1 CL -22 UC Conc -LA2 (gal/Mgal) - — A A 61 MO 67 Conc -LA5 (gal/Mgal) 8 61 Optiflo-III Conc -DA2 (Ib/Mgal) B 07:00 07:02 07:04 07:06 07:08 07:10 07:12 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 8 Plots 54 ADP Chemical Plot -Bucket Tests Day 2 B2 Losurf-300D Conc -LA2 (gal/Mgal) — A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 06:32 06:33 06:34 06:35 06:36 06:37 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska -CDS-92 InteNal8 Plots A B 10000 1-- 9000- 8000- 7000- 2000 00080007000 2000 1000 L Treatment Plot- Interval 08 -reating Pressure (psi) A Slurry Rate (bpm) E flurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C Du D-- f—;x A A——f ou r.... - nc r C D 0 175 150 125 100 75 10:30 10:40 10:50 11:00 11:10 11:20 10/19/2016 Time 10/19/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVN: 50-10320800 43 Conoco Phillips Alaska-CD5-92 Inteval8 Plots 56 A 3.0 2.E MO 1.5 1.0 0.5 OS Blender Chemical Plot - Interval 08 B1 CL -31 Conc -LA1 (gal/Mgal) — - A B1 CL -22 UC Conc -LA2 (gal/Mgal) A 61 MO -67 Conic -LA5 (gal/Mgal) B 61 Optiflo-III Conc -DA2 (Ib/Mgal) B w I 10:30 10:40 10:50 11:00 11:10 11:20 10/19/2019 Time 10/19/2019 Custorner: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 -- Well Description: CD5 92 LNM: 50-103-20800 3 5 I Conoco Phillips Alaska - CDS-92 Interval 8 Plots 57 ADP Chemical Plot - Interval 08 A B2 Losurf-300D Conc -LA2 (gal/Mgal) --- — A B2 WG -36 Conc -DA1 (Ib1Mgal) B 1 1 1 0 0 0 0 0 B 10:30 10:40 10:50 11:00 11:10 11:20 10/19/2019 10/19/2019 Time Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVA: 50-103-20800 Conoco Phillips Alaska -CDS -92 Interval Plots 58 Net Pressure Plot - Interval 08 Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 UVN: 50-103-20800 Conoco Phillips Alaska -CD5-92 Interval Plots Treating Pressure (ps Slurry Proppant Con A B Gauge BH Pres (psi) 100007 1 9000 8000 7000 6000 5000 4000 3000 2000 1000 Treatment Plot - Interval 09 i) A Slurry Rate (bpm) c (Ib/gal) C BH Proppant Conc (Ib/gal) A Actual BH Temp (°F) C D C D 0 175 r 150 125 100 75 11:20 11:30 11:40 11:50 12:00 Time 10/19/2019 10/19/2019 Custorrer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 U1N1: 50-103-20800 Conoco Phillips Alaska-CD5-92 Interval 9 Plots 60 Blender Chemical Plot - Interval 09 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B 11:20 11:30 11:40 11:50 12:00 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order M 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 9 Plots ADP Chemical Plot - Interval 09 A I B2 Losurf-3O0D Conc -LA2 (gal/Mgal) - — A B2 WG -36 Conc -DA1 (ib/Mgal) B I B 11:20 11:30 11:40 11:50 12:00 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 1 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 9 Plots 62 Net Pressure Plot - Interval 09 Net Gauge BH Pres (psi) i. BH Proppant Conc (Ib/gal) B I Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LMA: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 9 Plots Treatment Plot - Interval 10 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Cone (lb/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp ("F) -- 100007 1 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 C D C D 0 175 150 125 100 75 12:00 12:10 12:20 12:30 12:40 10/19/2019 Time 10/19/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 "'— Well Description: CD5 92 LAM 50-103-20800 Conoco Phillips Alaska -CDS-92 Interval 10 Plots 64 Blender Chemical Plot - Interval 10 A 3.0 2.5 2.0 1.5 UN 0.5 B1 CL -31 Conc -LAI (gal/Mgal) B1 MO -67 Conic -LA5 (gal/Mgal) A B B1 CL -22 UC Conc -LA2 (gal/Mgal) B1 Optiflo-III Conc -DA2 (Ib/Mgal) A B 0.0- 11:50 10/19/2019 12:00 12:10 12:20 12:30 Time Customer: CONOCOPHILLIPS NORTH SLOPE- ESUS I Job Date: 19 -Oct -2019 Sales Order k 0906024930 Well Description: CD5 92 UWI: 50-103-20800 0 12:40 10/19/2019 Conoco Phillips Alaska - CD5-92 Interval 10 Plots 65 ADP Chemical Plot - Interval 10 A 132 LosurF 3 M Cone -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 2.0 100 1. 1. 1. 1. 0. 0. 0.1 0.: 0.1 11:50 10/19/2019 12:00 12:10 12:20 12:30 12:40 Time 10/19/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LMA: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 10 Plots 66 ILI Net Pressure Plot -Interval 10 Net Gauge BH Pres (psi) A 1 BH Proppant Conc (Ib/gal) B 10 Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 10 Plots A B 100007 1 7000 5000 4000 3000 2000 1000 9 Treatment Plot - Interval 11 -reating Pressure (psi) A Slurry Rate (bpm) E u�r Prcr�,pant Conc (lb/gal) C BH Proppant Conc (Ib/gal) C C D 0 [175 150 -125 100 75 12:30 12:40 12:50 13:00 13:10 10/19/2019 Time 10/19/2019 Custorrer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 " Well Description: CD5 92 UWI: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 11 Plots 68 Blender Chemical Plot - Interval 11 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 12:30 12:35 12:40 12:45 12:50 12:55 13:00 13:05 13:10 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 LIM 50-103-20600 Conoco Phillips Alaska - CD5-92 Interval 11 Plots 69 ADP Chemical Plot - Interval 11 A B2 Losurf-30 Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B n n 12:30 12:40 12:50 13:00 13:10 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LW: 50-103-20800 Conoco Phillips Alaska-CD5-92 Interval 11 Plots 70 Net Pressure Plot - Interval 11 Net Gauge BH Pres (psi) A BH Proppant Conc (Ib/gal) B 10 Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LIM 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 11 Plots A B 10000 1^^ 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 Treatment Plot- Interval 12 'reating Pressure (psi) A Slurry Rate (bpm) E >lurry Proppan# Conc (Ib/gall C BH Proppant Conc (Ib/gal) C 3auge BH Pres (psi) A Actuai BH temp ("F) C C D '0 175 150 125 100 75 50 25 13:10 13:20 13:30 13:40 13:50 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UWI: 50-10320800 Conoco Phillips Alaska - CDS-92 Interval 12 Plots 72 Blender Chemical Plot - Interval 12 131 CL -31 Conc -LAI (gal/Mgal) A 61 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 13:10 13:20 13:30 13:40 13:50 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 1LMA: 50-103-20800 Conoco Phillips Alaska - CDS-92 Interval 12 Plots 73 ADP Chemical Plot - Interval 12 B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B 13:10 13:20 13:30 13:40 13:50 10N9/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBL1S Job Date: 19 -Oct -2019 Sales Order #: 0906024930 "� Well Description: CD5 92 LMA: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 12 Plots 10 Net Pressure Plot - Interval 12 Net Gauge BH Pres (psi) A BH Proppant Conc (Ib/gal) B 10 Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 UVN: 50-103-20800 Conoco Phillips Alaska - CD5-92 Interval 12 Plots Treatment Plot - Interval 13 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) A 6 Gauge BH Pres (psi) A Actual BH Temp ("'F) - 100007 1 9000 8000 7000 6000 5000 4000 3000 2000 1000 C D C D 0 175 150 125 100 75 13:50 14:00 14:10 14:20 14:30 14:40 10/19/2019 Time 10/19/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order k 0906024930 Well Description: CD5 92 UVA 50-103-20800 :] Conoco Phillips Alaska - CDS-92 Interval 13 Plots 76 A Blender Chemical Plot - Interval 13 131 CL -31 Conic -LA1 (gal/Mgai) A B1 CL -22 UC Conc -LA2 (gal/Mgai) A 61 MO -67 Conc -LA5 (gal/Mgal) B 131 Optiflo-III Conc -DA2 (Ib/Mgai) B 61 SP breaker Conc -DA1 (Ib/Mgai) B B 13:50 14:00 14:10 14:20 14:30 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order* 0906024930 Well Description: CD5 92 UM: 50-103-20800 Conoco Phillips Alaska -CDS-92 Interval 13 Plots 77 ADP Chemical Plot - Interval 13 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 13:50 14:00 14:10 14:20 14:30 10/19/2019 10/19/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LAM: 50-10320800 Conoco Phillips Alaska - CDS-92 Interval 13 Plots 78 Net Pressure Plot - Interval 13 - Net Gauge BH Pres (psi) A - BH Proppant Conc (Ib/gal) B 1U Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 19 -Oct -2019 Sales Order #: 0906024930 Well Description: CD5 92 LMA: 50-103-20800 Conoco Phillips Alaska-CD5-92 Interval 13 Plots HALLISURTON Sales rd r# 0906024930 Conoco Phillips Alaska - CD5-92 Conoco Phillips Alaska CD5-92 Intervals 1-13 A -Sand Formation Harrison Bay County, AK API: 50-103-20800 Prepared for: Adam Klem October 19, 2019 Stimulation Treatment Appendix - Well Summary - Chemical Summary - Planned Design - Water Straps - Water Analysis - Real -Time QC - Wellbore Information - Event Log - Field Break Test - Fann 15 Minute - Lab Testing Appendix 80 C135-92 Interval Highlights Interval Date Designed DesignProppaed (lbs) Proppant in Formation (Ibs) Vol Clean (bbl) Vol Slurry (bbl) Top Perf (ft) Bottom Perf (ft) Fluid System 1 10/17/2019 70000 64,449 1433 1,503 21,900 21,903 1 Hybor G 2 10/17/2019 70000 66,515 970 1,042 21,137 21,140 Hybor G 3 10/17/2019 70000 68,782 986 1061 20,374 20,377 HyborG 4 10/17/2019 90000 102,548 1013 1124 19,612 19,614 HyborG 5 10/17/2019 90000 97,569 957 1062 18,849 18,852 HyborG 6 10/17/2019 90000 90,331 923 1021 18,086 18,089 HyborG 7 10/17/2019 90000 98,332 1149 1256 17,323 17,326 1 HyborG 8 10/19/2019 90000 83,669 1063 1153 16,561 16,563 1 HyborG 9 10/19/2019 90000 84,432 913 1005 15,798 15,801 HyborG 10 10/19/2019 90000 90,247 942 1040 15,035 15,038 HyborG 11 10/19/2019 90000 69,926 905 981 14,272 14,275 HyborG 12 10/19/2019 90000 102,369 995 1106 13,510 13,512 HyborG 13 10/19/2019 90000 127,238 1184 1323 12,747 12,750 Hybor G Conoco Phillips Alaska - CDS-92 Well Summary Customer Conoco Phillips Alaska Formation A -Sand HAt_l.lE3tJi�TON ! o od aclon Enhcence3m¢+r�t Lease CD5-92 API 50-103-20800 Date 10/17/2019 Interval Summary - Chemicals Conoco Phillips Alaska - CD5-92 Chemical Summary Liquid Additives Dry Additives LoSurf-3001) MO -67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 Opti Flo -III SP Interval (gal) (gal) (gal) (gal) (gal) (lbs) (Ibs) (lbs) (Ibs) Prime Up 0 0 0 0 0 0 0 0 0 1 60 31 47 24 0 1666 9 120 0 2 41 18 37 14 0 870 6 81 0 3 41 14 37 14 0 865 6 83 0 4 43 15 38 15 0 856 6 85 0 5 40 14 36 14 0 797 6 80 0 6 39 14 35 14 0 857 6 78 0 7 51 18 39 10 3780 857 7 72 8 8 45 15 35 15 0 1178 7 89 0 9 38 13 30 13 0 843 6 77 0 10 40 14 31 14 0 882 6 79 0 it 38 13 29 13 0 801 6 76 0 12 42 15 30 19 0 956 6 84 0 13 33 5 30 13 3570 1066 7 95 6 Total 550 200 455 193 7350 12494 84 1100 14 w/o Prime Up 550 200 455 193 1 7350 12494 84 1100 14 Conoco Phillips Alaska - CD5-92 Chemical Summary Conoco Phillips Alaska - CD5-92 Planned Design ................. Conoco Phillips Alaska - CD5-92 Planned Design Conoco Phillips Alaska - CD5-92 Planned Design 84 m•ma.�m�v�mm� ��m•Ea�m��mz��m,���� ss�� �� mmrm•m.� ms m.�a� ®ma.�m� � m � am � m, � sm.mtmm•� �m•�� ®s�.��.�mm� gym• m ©lm �m �� � � �.�mf m•m•� mam• m� m• �� m*� mm� � m �� � ma � � � m mt m• m• � � m• m � ®maea���� ®Emae���®m m �mam,� ��m•m,mm•��m•�� m ®mm©m ��m•mtm•m•�msm.�� ®�a��m-��� mmmmm_m m��mmtmm•��m•m� ®�a.��.^��mm m•�.��r�mm�®m �mt�m�� ��m•mtm.m•�msm•�� �mt0� ®� �� m•mtm•m•�m,m.mm• ®ma;��r�mm�®m ��m®®�1�� m•mtm.m•� m,m•m•m• Conoco Phillips Alaska - CD5-92 Planned Design 84 Customer: Conoco Phillips Alaska Well: CD5-92 Date: 10/17/2019 Formation: A -Sand SO#: 0906024930 Conoco Phillips Alaska - CD5-92 Water Straps General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels 1 Atigan CDS 106 20,142 480 106 9 1,444 34 2 Atigan CD5 106 20,142 480 106 9 1,444 34 3 Atigan CD5 105 19,949 475 108 9 1,444 34 4 Atigan CD5 104 19,7SS 470 106 9 1,444 34 S Atigan CD5 105 19,949 475 105 9 1,444 34 6 Atigan CDS 105 19,949 475 105 9 1,444 34 7 Atigan CD5 100 18,981 452 109 9 1,444 34 8 Atigan CDS 104 19,755 470 109 9 1,444 34 9 Atigan CDS 100 18,981 4S2 107 9 1,444 34 10 Atigan CD5 103 19,562 466 109 59 10,992 262 11 Atigan CD5 106 20,142 480 107 98 18,595 443 12 Atigan CDS 104 19,755 470 112 100 18,981 452 13 Atigan CD5 106 20,142 480 110 61 11,408 272 14 Atigan CD5 105 19,949 475 110 9 1,444 34 15 Atigan CDS 105 19,949 475 110 9 1,444 34 16 Atigan CD5 105 19,949 475 109 9 1,444 34 17 Atigan CD5 107 20,336 484 109 9 1,444 34 18 Atigan CD5 103 19,562 466 109 9 1,444 34 19 Atigan CD5 104 19,755 470 108 9 1,444 1 34 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 376,702 8,969 81,642 1,944 295,061 7,025 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 472 0 472 0 472 0 472 Conoco Phillips Alaska - CD5-92 Water Straps Customer: Conoco Phillips Alaska Well: CD5-92 Date: 10/17/2019 Formation: A -Sand SO#: 0906024930 Conoco Phillips Alaska - CD5-92 Water Straps Day 2 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels 1 Atigan CD5 9 1,444 34 NA 9 1,444 34 2 Atigan CD5 9 1,444 34 NA 9 1,444 34 3 Atigan CD5 9 1,444 34 NA 9 1,444 34 4 Atigan CD5 15 2,540 60 NA 9 1,444 34 5 Atigan CD5 91 17,241 410 98 9 1,444 34 6 Atigan CD5 104 19,755 470 103 9 1,444 34 7 Atigan CD5 88 16,660 397 100 9 1,444 34 8 Atigan CD5 104 19,755 470 94 9 1,444 34 9 Atigan CD5 97 18,401 438 96 9 1,444 34 10 Atigan CD5 104 19,755 470 98 9 1,444 34 11 Atigan CD5 105 19,949 475 98 9 1,444 34 12 Atigan CD5 99 18,788 447 100 89 16,854 401 13 Atigan CD5 99 18,788 447 97 92 17,434 415 14 Atigan CD5 103 19,562 466 98 10 1,627 39 15 Atigan CD5 104 19,755 470 98 9 1,444 34 16 Atigan CD5 104 19,755 470 99 9 1,444 34 17 Atigan CD5 104 19,755 470 98 9 1,444 34 18 Atigan CD5 103 19,562 466 98 9 1,444 34 19 Atigan CD5 100 18,981 452 98 9 1,444 34 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 293,334 6,984 59,025 1,405 234,310 5,579 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 466 0 0 466 466 0 466 Conoco Phillips Alaska - CD5-92 Water Straps Day 2 Company: HALLISURTON Alaska District Field QC Prejob Water Analysis on Location Conoco Phillips Well Name: CD5-92 Water Source: CD5 Specific Gravity Testing Temperature Dissolved Iron Fe's Chloride CI Sulfate Calcium Magnesium Total Linear SO �. Ca'. Mg,., r.Hardness Viscosity Water H Gel PH Post-Crosslink PH Crosslink Bacteria -F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) BQValue Tank Hydrometer Digital Thermometer StripStrip P Strip Titration Total Hardness Titration FANN-35 P Minus Calcium Probe Probe Probe - M ycometer 11,016 80.1 0 14,810 800 800 1,600 2,400 19 7.05 7.31 9.89 y 21,987 2 1.014 82.5 0 14,810 800 600 1,200 1,800 19 6.91 7.15 9.92 Y 30,501 3 1.016 80.1 0 16,010 800 720 1,480 2,200 18 6.94 7.05 9.85 Y 9,321 4 1.016 73.8 0 16,010 800 760 1,240 2,000 18 6.95 7.11 9.82 Y 7,341 5 1.014 74.5 5 14,810 1,200 720 1,280 2,000 18 6.75 7.12 9.85 Y 3,917 6 1.016 82.9 5 13,700 800 760 1,040 1,800 19 6.72 7.08 9.87 Y 3,327 7 1.014 85.9 0 14,810 1,200 720 1,280 2,000 19 6.81 7.11 1 9.89 Y 11,306 8 1.014 84.4 0 13,700 800 840 1,560 2,400 18 6.75 7.08 9.84 Y 7,026 91,014 85.7 5 13,700 800 680 1,520 2,200 17 6.78 7.10 9.80 Y 11,160 10 1.014 86.7 0 14,810 800 720 1,080 1,800 18 6.77 7.05 9.83 Y 9,133 11 1 1.016 87.1 0 16,010 800 1 640 1,560 2,200 18 6.82 7.10 9.79 Y 5,617 12 1.012 84.6 0 14,810 800 560 1,640 2,200 17 6.85 7.04 9.82 Y 5,572 13 1.014 83.6 5 13,700 11200 600 1,200 1,800 18 6.70 7.02 9.83 Y 439 14 1.016 85.6 0 16,010 11200 680 1,120 1,800 18 6.72 7.05 9.85 Y 421 15 1.014 87.3 0 13,700 800 640 1,760 2,400 17 6.80 7.04 9.81 Y 672 16 1.016 88.1 0 14,810 800 560 1,640 2,200 18 6.78 7.05 9.80 Y 1,342 17 1.012 87.2 0 13,700 800 600 1,200 1,800 17 6.85 7.01 9.82 Y 851 18 1.012 87.1 5 14,810 1,200 680 1,720 2,400 19 6.87 7.05 9.87 Y 1,417 19 1 1.016 86.4 0 14,810 1 800 1 600 1,800 2,400 17 6.83 7.12 9.75 Y 785 Average 1.015 83.9 1 11181 905 515 1077 1592 18 6.82 7.09 9.84 6954.5 Maximum 1.016 88.1 516,010 1,200 840 1,800 2,400 19 7.05 7.31 9.92 30,501 Minimum 1.012 73.8 0 0 800 o 0 0 17 6.70 7.01 9.75 421 Range 0.004 14.3 5 16,010 400 840 1,800 2,400 2 0.35 0.30 0.17 30,080 Como PNII, Nas W -Cps-92 Company: HALLISURTON Alaska District Field QC Prejob Water Analysis on Location Conoco Phillips Well Name: CD5-92. Intervals 8-13 Water Source: CD5 Specific GravityTemperature Testing Dissolved Iron Fee' Chloride CF(SO,'-) Sulfate Calcium Magnesium Total Linear Cala (ME,*) Hardness Viscosity Water H Gel PH Post-Crosslink PH Crosslink Bacteria -F mg/L mg/L mg/L mg/L mg/L mg/L CP (V/N) BC, Value Tank N Hydrometer y Digital Thermometer Strip StripStrip Titration Total Hardness Titration FANN-35 p Minus Calcium Probe Probe Probe - M ycometer 5 1.016 81.5 0 13,700 800 800 1,000 1,800 18 6.85 7.12 9.79 y 1,131 1L014 79.8 0 13,700 800 560 1,040 1,600 19 6.95 7.15 9.85 Y 1,558 7 1.016 78.5 0 13,730 800 480 1,320 1,800 18 1.01 7.14 9.78 Y 642 8 1.014 75.5 5 13,730 1,200 400 1,440 1,840 18 7.10 7.20 9.84 V 764 9 1.016 72.6 5 11,300 800 440 1,240 1,680 17 7.10 7.22 9.88 V 589 10 1.016 73.4 0 14,840 800 600 880 1,480 18 7.04 7.19 9.84 V 1,025 11 1.016 87.1 0 16,010 800 640 1,560 2,200 18 6.82 7.10 9.79 y 5,617 12 1.012 84.6 0 14,810 800 560 1,640 2,200 17 6.85 7.04 9.82 y 5,572 13 1.014 83.6 5 13,700 1,200 600 1,200 1,800 18 6.70 7.02 9.83 y 439 14 1.016 85.6 0 16,010 1,200 680 1,120 1,800 18 6.72 7.05 9.85 y 421 15 1.016 78.6 0 14,840 1 800 800 680 1,480 17 7.03 7.12 9.83 Y 455 16 1.016 75.6 0 13,730 800 760 840 1,600 18 7.05 7.15 9.85 y 766 17 1.018 77.2 5 13,730 1,200 800 1,160 1,960 19 7.04 7.20 9.84 y 688 18 1.016 73.4 0 14,840 800 600 1,080 1,680 18 7.02 7.19 9.78 y 788 19 1.016 74,6 0 144840 800 800 800 1,600 19 7.04 7.24 9.83 V 686 Average1,015 78.8 1 11237 907 501 895 1396 18 6.95 7.14 9.83 1409.4 Maximum 1.018 87.1 5 16,010 1,200 Soo 1,640 2,200 19 7.10 7.24 9.88 5,617 Minimum 1.012 72.6 0 0 8000 0 0 17 6.70 7.02 9.78 421 Range 0.006 14.5 5 16,010 400 800 1,640 2,200 2 0.40 0.22 0.10 5,196 Como PNII, Nas W -Cps-92 1- ALLIBURTON Customer ConocoPhAps Alaska, In<. Wellrlame&#: CD5-92 Date: October 17, 2019 ®�®�ffiWi>•� ��®��� �mm®mom �mm®mom HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 10/15/2019 Company: ConocoPhillips Project No: Well Name: CDS-92 Stage(s): Break Test BHST (eF): 156 Water Source: CD5 Depth: Water pH: 6.85 Formation: Hydration pH: 7.10 Analyst: XLaw6e Hydration Visc: 17 cp @ 87 Fluid is broken at 200cp Prejob Crosslink Break Tests -Break Test 1 2500 2000 a v 1500 :y u 1000 N_ i 500 0 0000 0200 0400 1000 2000 30.00 100 30'.00 00:00 3000 Time (mm.sec) All chemical concentrations below are in gallons per thousand / pounds per thousand Tempel' PH LOSURF300D CL -22 UC CL -31 MO -67 OptiOo-III Break Test 87 9.84 1.00 0.90 0.45 0.40 2.00 Conoco Phillips Alaska - 05-92 Prejob Break Test Day 1 90 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 10/19/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): Break Test BHST (IF): 156 Water Source: CD5 Depth: Water pH: 6.97 Formation: Hydration pH: 7.14 Analyst: XLam6a HydrationVisc: 18 cp@ 82 Fluid is broken at 200cp Prejob Crosslink Break Tests -Break Test 1 laoo 00:00 02:00 0400 1000 2000. 3000 1 00 Time (min:sec) 1200 1000 a 800 T p 600 N_ > 400 200 0 All chemical concentrations below are In gallons per thousand I pounds per thousand Temp°F PH LOSURFJOOD CL -22 UC CL -31 M087 Optitloall Break Test 80 9.81 1.00 0.90 0.35 0.35 2.00 30.00 00:00 3000 00:00 Conoco Phillips Alaska - CD5-92 Prejob ereak Test Day 2 91 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/17/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 1 BHST (eF): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: WardnAgu(as Hydration Visc: cp@ Lot Number-- Fluidisbroken at200cp Zone 1 Crosslink Tests -Pad -1 ppb -2 pp9 -3 PP9 -4 PP9 -5 PP9 4000 3500 3000 2500 T 2000 0 O a 1500 > 1000 500 0 0000 01:00 0200. 03.00 0400 05.00 0600 07:00 08:00 09:00 1000 1100 1200. 1300 14:00 15001 Time (min:sec) All chemical concentrations below are in gallons per thousand / pounds per thousand Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zone 1 92 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/17/21 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 2 BHST (eF): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: 51dartix)4ufar Hydration Visc: cp Fluid is broken at200cp Z 2 C 1' k T t one ross In es s -Pad -1 PP9 -2 PP9 -3 pP9 -4 PP9 -5 PP9 6000 5000 a 4000 3000 a 0 U W 21)1)1) 1000 0 i . i 00:00 01:00 02:00 03:00 04:00 05:00 06100 07'.00 06:00 09:00 400 11:00 12:00 400 400 400 Time (min:sec( All chemical concentrations below are in gallons per thousand I pounds per thousand Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zone 2 93 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid is broken of 200cp Zone 3 t- 1: Tests Pad -1 ppg -2 pp9 -3 PP9 -4 PP9 -5 pp9 000i00 01:00 02:00 03:00 04:00 05'.00 08:00 0700 1 0800 1 09:00 1 10:00 1 11'00 1 12:00 1 13'.00 1400 1500 Time (min:sec) Conoco Phillips Alaska - C05-92 Fenn 15 Minute Zone 3 94 3500 Fluid System: Date: 10/17/2019 3000 Company: ConocoPhillips Project No: 2500 Well Name: CD5-92 Stage(s): 3 2000 BHST (°F): 155 Water Source: CD5 p 1500 Depth: Water pH: y Formation: Asand Hydration pH: > 1000 Analyst: %ardn ggufar Hydration Visc: CP @ 500 000i00 01:00 02:00 03:00 04:00 05'.00 08:00 0700 1 0800 1 09:00 1 10:00 1 11'00 1 12:00 1 13'.00 1400 1500 Time (min:sec) Conoco Phillips Alaska - C05-92 Fenn 15 Minute Zone 3 94 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/17/2( Company: ConocoPhillips Project No: Well Name: C135-92 Stage(s): 4 BHST ('F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: WartinXgufar Hydration Visc: cp @ Fluid is broken at 200cp Zone 4 Crosslink Tests -Pad -1 pp9 —2 ppy —3 ppg —4 PPg —5 PP9 4500 4000 3500 a 3000 u 2500 0 2000 U m 1500 1000 500 0 0000 01:00 0200 03:00 0400 0500 0600 07:00 08:00 0900 1000 11:00 1200 1300 1400 1500 Time (min:sec) Conoco Phillips Alaska - C05-92 Fann 15 Minute Zone 4 95 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/17/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 5 BHST (°F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: Wartin lyufas Hydration Visc: cp @ Fluid is broken at 200cp Zone 5 Crosslink Tests -Pad -1 PP9 -2 ppg -3 Ppb -4 ppg -5 ppg 4500 4000 3500 n 3000 a 2500 0 2000 u 1500 1000 500 0 0000 0100 0200 0300 04:00 05.00 0600 07:00 0800 0900 1000 1100 1200 1300 14:00 1500 Time(min:sec) Conoco Phillips Alaska - CDS-92 Fann 15 Minute Zone 5 96 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid is broken at 200cp Zone A f' 1; 11 Tests -Pad -1 PP9 —2 PP9 —3 1p9 —4 PP9 —5 PP9 4000 3500 3000 'a 2500 2_ 2000 N O m 1500 1000 500 0 00:00 01:00 02.00 0300 04:00 05'.00 0600 0700 0800 09:00 10.00 11.00 1200 1300 14:00 15:00 I Time (min:sec) Conoco Phillips Alaska - CDS-92 Fann 15 Minute Zone 6 97 Fluid System: Date: 10/17/2( Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 6 BHST ('F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: MartinAgurar Hydration Vise: CP @ Fluid is broken at 200cp Zone A f' 1; 11 Tests -Pad -1 PP9 —2 PP9 —3 1p9 —4 PP9 —5 PP9 4000 3500 3000 'a 2500 2_ 2000 N O m 1500 1000 500 0 00:00 01:00 02.00 0300 04:00 05'.00 0600 0700 0800 09:00 10.00 11.00 1200 1300 14:00 15:00 I Time (min:sec) Conoco Phillips Alaska - CDS-92 Fann 15 Minute Zone 6 97 Fluid is broken at 200ep Zone 7 f, 1. Tests -Pad -1 ppg -2 PW -3 PW -4 ppg -5 ppg 4000 3500 3000 2500 ZG 2000 .y O w 1500 1000 500 0 0000 01 00 0200 0300 0400 0500 06:00 07:00 0800 0900 1000 11:00 12:00 1300 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - C05-92 Fann 15 Minute Zone 7 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/17/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 7 BHST (eF): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: WardnAgufar Hydration Visc: CP@ Fluid is broken at 200ep Zone 7 f, 1. Tests -Pad -1 ppg -2 PW -3 PW -4 ppg -5 ppg 4000 3500 3000 2500 ZG 2000 .y O w 1500 1000 500 0 0000 01 00 0200 0300 0400 0500 06:00 07:00 0800 0900 1000 11:00 12:00 1300 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - C05-92 Fann 15 Minute Zone 7 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 10/19/2019 Company: ConocoPhillips Project No: Well Name: CDS-92 Stage(s): 8 BHST (°F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: Wartaflgurar Hydration Vise: cp@ Fluid is broken at 200cp Z 7 C I' k 1r 4, one ross In es s Pad -1 PW -2 pP9 -3 Pp9 -4 pp9 -5 pp9 3500 3000 2500 a 2000 T p 1500 m > 1000 500 0 0000 01:00 02:00 0300 0400 05000 08:00 07:00 08:00 09:00 10000 11:00 12:00 1300 1400 15:00 Time (min:—) Conoco Phillips Alaska- 05.92 F.- 15 Minute Zone 8 99 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/19/2019 Company: ConocoPhillips Project No: Well Name: CDS-92 Stage(s): 9 BHST (oF): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: WartinAp&r Hydration Visc: cP@ Fluid is broken at 200cp Z 7 one rossllnk Tests -Pad -1 PP9 -2 PP9 -3 PP9 -4 PP9 -5 PP9 2500 a 2000 Z' 1500 O 1000 500 00:00 1 0190 1 02:00 1 03:00 04:00 05:00 06:00 07:00 08:00 i 0990 i 10.00 1100 1200 1300 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - C05-92 Penn 15 Minute Zone 9 100 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/19/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 10 BHST (°F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: ;KarNx 4gular Hydration Visc: cp @ Fluid is broken at 200cp Zone 7 Crosslink Tests Ped - 1 PP9 -2 PP9 -3 PP9 -4 PP9 -5 PP9 %1.1-H: 3000 2500 a 2000 T p 1500 > 1000 500 0 00:00 01'.00 02:00 03:00 04:00 05:00 06'.00 0700 1 08'.00 1 09:00 1 10600 1100 1200 1300 1400 15:00 Time (min:—) Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zone 10 101 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 10/19/2019 Company: ConocoPhillips Project No: Well Name: CD5-92 Stage(s): 11 BHST (°F): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: Wanix)4vfar Hydration Visc: cp@ Fluid is broken at WOOF Zone 7 f, 1: Tests Pad —1 PP9 —2 PP9 —3 PP9 -4 pP9 -5 Pp9 4000 3500 3000 2500 .y 2000 O N 1500 1000 500 0 0000 01:00 0200 0300 0400 0500 08:00 0700 0800 0900 1000 1100 1200 1300 1400 1500 Time (min:—) Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zane 11 102 Fluid is broken at 200cp Z 71, 1' k T 4. one Iwoo in es s —Pad —1 PP9 —2 PP9 —3 PP9 —4 PP9 —5 Pp9 0000 01:00 02'.00 0300 0400 0500 0800 0700 0800 0900 10:00 1100 1200 1300 1400 15:00 Time (min sec) Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zone 12 103 ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report 4000 Fluid System: 3500 Date: 10/19/2019 Company: ConocoPhillips Project No: 3000 Well Name: CDS-92 Stage(s): 12 n 2500 BHST (°F): 155 Water Source: CD5 2000 N Depth: Water pH: O a 1500 Formation: Asand Hydration pH: 1000 Analyst: WartinAgular Hydration Visc: cp @ 500 0 one Iwoo in es s —Pad —1 PP9 —2 PP9 —3 PP9 —4 PP9 —5 Pp9 0000 01:00 02'.00 0300 0400 0500 0800 0700 0800 0900 10:00 1100 1200 1300 1400 15:00 Time (min sec) Conoco Phillips Alaska - CD5-92 Fann 15 Minute Zone 12 103 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 10/1912019 Company: ConocoPhillips Project No: Well Name: CDS-92 Stage(s): 13 BHST (eF): 155 Water Source: CD5 Depth: Water pH: Formation: Asand Hydration pH: Analyst: Warcin ggufar Hydration Visc: cp @ Fluid Is broken of 200cp Z 7 C 1' k 'r- one ross In ests -Pad - 1 PP9 -2 PP9 -3 PP9 -4 PP9 -5 PP9 3500 3500 3000 2500 a 2000 ' 1500 v a 1000 500 0 00:00 0100 0200 0300 1 04:00 05:00 06000 07:00 Oat 09:00 1000 1100 12:00 13:00 14:00 15:00 Time (mm;-) Conoco Phillips Alaska - CDS-92 Fann 15 Minute Zone 13 104 Conoco Phillips Alaska -CDS-92 Event Log Day 1 105 Conoco Phillips Alaska - CD5-92 Event Log Day 2 106 Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2069820 Customer: ConocoPhillips Well Name & Number: CD5-92 Fluid System: Hybor G Date: October 8, 2019 10 minutes at 511 1 /sec 10 minutes the shear rate was decreased to 100 1/sec Seawater SL#1281 Technician(s) Performing Testing: Jason Doyle Reviewed & Approved By: DLB 04/17/2020 Customer: Well Name: Date: ConocoPhillips CD5-92 October 8, 2019 Fluid System: Water Source: BHST (°F): Hybor G Seawater 155 Bob Type: B5 Shear Rate (I /see): 511 /100 Lab Project ID: 2069820 Test No: 1 2 FLUID DESIGN 5 Lot# Chemical Units Chemical Concentrations BE -6 ppt 0.15 0.15 0.15 0.15 LOSUrf 300D WG -36 gpt ppt 1.00 25.00 1.00 25.00 1.00 25.00 1.00 25.00 MO -67 gpt 0.25 0.25 0.25 0.25 CL -22 ppt 0.90 0.90 0.90 0.90 CL31 ppt 0.45 0.45 0.45 1 0.45 Optiflo III ppt 2.00 2.00 2.00 SP Breaker ppt 0.25 0.50 *calculated values r SChlufflobopgep Drilling & Measurements Product Delivery 219034 3 13 75 Transmittal #: 21OCT19-SP03 Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resource Tech Well Name: CD5-92 Date Dispatched: 21 -Oct -19 Service Order #: 19AKA0086 Dispatched By: Stephanie Pacillo Product Desc LWD Recorded Mode Prints: Scope* Resistivity F5" MD / TVD MD / TVD Digital Data - R CD DLIS / LAS Data N/ RIEqEIVED 4OCT 282019 N/A Directional Survey Nad27 Directional Survey Nad83 Data: DLIS/ LAS Graphics: PDF Surveys: PDF/TXT N/A 1 CD _Digital Co Contents on x x L;ontents on CD x Contents on CD x x Contents on CD x x x Please sign and email a copy to - Tom. Osterkamp(c�conocoohillips com Please sign and email a copy to: Alaska PTSPrintCenter(aDslb com Attn: Tom Osterkamp Attn: Stephanie Pacillo ReceivedI f / By: i . Logginq Date 3 -Oct 19 THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-92 Permit to Drill Number: 219-034 Sundry Number: 319-453 Dear Mr. Klem: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J , rice Chair DATED this day of October, 2019. RBDMs.N OCT 14 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS v7S 10111) 17 20 AAC 1. 1 ype of Pequest: Abandon LJ 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: ConocoPhillips Exploratory ❑ Development EJ Stratigraphic ❑ Service ❑ 219-034 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20800-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU-CD5-92 Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation (Lease Number): ° 10. Field/Pool(s): ASRC-NPR4, ASRC-NPR2, ASRC-NPR3, ASRC-NPR1 Colville River Unit, Alpine 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): 28,503' 7,325' 28,503' 7,325' 6500 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 115' 115' Surface 2,149' 10-3/4" 2,246' 2,188' 5210 2470 Intermediate 12,254' 7-5/8" 12,293' 7,469 6890 4790 Production Liner 12,853' 4-1/2"1 25,000' 7,325' 7,780 6,350 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 112,147 Tubing MD (ft): none n/a 3.5" L80 est Packers and SSSV Type: Baker Premier, No SSSV Packers and SSSV MD (ft) and TVD (ft): 12,100'MD est, 7452' TVD est 12. Attachments: Proposal Summary ❑ Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 10/13/2019 15. Well Status after proposed work: Commencing Operations: OIL 2 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Adam Klem Contact Name: Adam Klem Authorized Title: Completion Engineer Contact Email: adamAlem conocO hull S.com 1 � Contact Phone: 907-263-4529 Authorized 'U 3 G Signature: Date: /') U/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: q-uG3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity ❑ g y Test ❑ Location Clearance Other: iBDMS1V44OCT 1 41019 Post Initial Injection MIT Req'd? Yes F1No [Vr Spacing Exception Required? Yes ❑ No E/ Subsequent Form Required: IQ — 4-0 - . APPROVED BY Approved by. �1 ' ' \� COMMISSIONER THE COMMISSION Date: Jol } I h6l 09�li'TLGRIGINAL " Submit Form andForm 10-403 Revised 4/2017 Approved applim the date of proval. Attachments in Duplicate °,� 110/4 l 9 CD5 — 92 Alpine A Producer Schematic ■©= Cameo KBMG GLM 3 x1" SLB Downhole Gauge" 20" 94# H-40 :L Welded Conductor 10-3/4" 45.5# L-80 TXP/BTC Surface Casing 2.813" X Nipple 7-5/8" Stage Cementer Cameo KBMG GLM 3%"x1" 3-1/2" 9.3# EUE L-80 Production Tubing Camco KBMG GLM 3%"x1" 7 5/8" 29.7/39# L-80 BTCM Intermediate Casing Production Packer 2.813" XN Nipple Upper Completion: Length 1) 4-'/z" 12.6#/ft HYD563 Tubing (1 jts) XO to 3-%" EUE tubing 2) Shallow 2.813" X nipple profile 3)3-1/2" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4)3-1/2" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4)3-1/2" x 1" Camco KBMG GLM (xx°) w/DCK2 7' pinned for 2500 psi casing to tbg shear 5) BHP Gauge, Encapsulated I -Wire 1.5' w/cannon clamps on every joint 6) 3-'/2" x 7-5/8" Baker Premier Packer 7) XN nipple 2.812" ID 1.5' 8) WLEG Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-1/2" Hyd563 pin 10)41/2", 12.6#/ft, L-80 H563 Liner w/ 12 ball actuated frac ports to 21,700' MD O O O O O O O O •. •i •i •- •i ZXP Liner Top 4-'/2" 12.6# L-80 H563 Packer and Hanger Production Liner Section 1 -Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason C. Parker Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-92 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASt1li ) THIRD JUDICIAL DISTRICT ) Jason C. Parker, being first duly sworn, upon oath, deposes and states as follows: My name is Jason C. Parker. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am a Senior Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On October 1, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 15` day of October, 2019. Jacor) STATE OF ALASKA } THIRD JUDICIAL DISTRICT } This instrument was acknowledged before me this 151 day of October, 2019, by Jason C. Parker. Notary Public, State of Alaska My Commission Expires: E LAS KABLIC ENSEN Expires Auq. 27, 2020. x ConocoPhillips Alaska October 1, 2019 To: Operator and Owners (shown on Exhibit 2) ,son C. Parker ,:!nior Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 Office: 907-265-6297 Fax: 907-263-4966 jason.c.parker@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD5-92 Well AA -92344 (ASRC), ASRC-NPR1, ASRC-NPR2, ASRC-NPR3, and ASRC-NPR4 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-92 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about October 1, 2019. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases, ASRC- NPR1, ASRC-NPR2, ASRC-NPR3, and ASRC-NPR4 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Section Meridian Surface 246' 2287' Range T11 N R4E 18 Umiat Top Open Interval 4756' 3043' T11N R3E 1 Umiat Bottomhole 497' 487' TI 2N ,F4E- 27 Umiat R31E7 gu* t °(s hq Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, '` Jason . P r er Senior Landman Attachments: Exhibits 1 & 2 Exhibit 1 ADL388 63 • Frac Points Halt Mile Frac Port Buffer Half Mile Well Track Buffer -3 2;4 Wells within Track Buffer Well Track I -p —in- -a PAA... A- - Open Interval ------- ......... Alpine PA Unit Boundary ASRC-NPR1 CPAI Lease z z NIIPRB 1 T)LNR3E AS-RC,NPR2 \ C THNIRA T11NR,4E -NPR4 COI ASRC-N.P.R3 ASRC CD( 12 AA087888 AA092347 .................. ConocoPhillips Alaska C015-92 W' J z I N I Z //!: Lease Analysis - I 0 0,2 0.4 0.6 0.8 1 A=j Miles SRC.AA09 I- 234j Date: 9130/2019 T ,_ AS-RC,NPR2 112N4E T11NR,4E -NPR4 COI CD( Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Ooerator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: Misty Alexa, NS Development Manager Owner (Non-Ooerator): None Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attn: Teresa Imm, Executive VP, Regional and Resource Development Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attn: Joe Nukapigak, President Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles ADL388463 • Frac Points I j Q Half Mile Frac Port Buffer Half Mile Well Track Buffer j i 24 Wells within Track Buffer Well Track I Open Interval I „ - - - --------__- � � Alpine PA Unit Boundary _____ _____ j ASRC-NPR1 Co CPAI Lease 2• - n %u ^5 ziiry %SRC-NPR8 ! I I I �� � , I I I i 35 I I ,.-, ,,�- ____....------------ i T9 NR3 - -- , I •c _----- T11 NR3 ----- ----- q� — W ASRC-NPR3 ASRC-NI I � I iU I I i I I ! V 1 AA087888 I AA092347 I j i i cos2t I ( CD5 ConocoPhillips Alaska i w l LU -o C135-92 '� o Lease Analysis N 0 0.2 0.4 0.6 0.8 1 Miles }_= SRC-AA092344 Date: 9/30/20 19 ASRC-NPR2 T12NR4E T/ f NR4E 5 o U Q) J CD5-W c� ASRC'NPR4 c>_ 17 q Table 1: Wells within .5 miles API Well Name Well Type Status 501032073600 CD5-01 INJ ACTIVE 501032073700 CD5-02 SVC PA 501032073701 CD5-02A INJ ACTIVE 501032071800 CD5-03 PROD ACTIVE 501032071100 CD5-04 PROD ACTIVE 501032071200 CD5-05 PROD ACTIVE 501032074400 CD5-06 INJ ACTIVE 501032074460 CD5-06L1 INJ ACTIVE 501032073400 CD5-07 INJ ACTIVE 501032074100 CD5-08 INJ ACTIVE 501032072300 CD5-09 PROD ACTIVE 501032072400 CD5-10 PROD ACTIVE 501032072600 CD5-11 PROD ACTIVE 501032074200 CD5-12 INJ ACTIVE 501032075400 CD5-17 INJ ACTIVE 501032075460 CD5-171-1 INJ ACTIVE 501032075000 CD5-18 PROD ACTIVE 501032075060 CD5-18L1 PROD ACTIVE 501032076000 CD5-19 INJ ACTIVE 501032076060 CD5-191-1 INJ ACTIVE 501032075260 CD5-20L1 PROD ACTIVE 501032073800 CD5-21 PROD SUSP 501032075900 CD5-22 PROD ACTIVE 501032076100 CD5-23 INJ ACTIVE 501032079900 CD5-24 PROD ACTIVE 501032079960 CD5-241-1 PROD ACTIVE 501032079970 CD5-24L1PB1 EXPEND PA 501032076500 CD5-25 INJ ACTIVE 501032076560 C05 -25L1 INJ ACTIVE 501032071400 CD5-313 PROD ACTIVE 501032071470 CD5-313PB1 EXPEND PA 501032070700 CD5-314 PROD PA 501032075500 CD5-314X PROD ACTIVE 501032071600 CD5-315 INJ ACTIVE 501032071670 CD5-315PB1 EXPEND PA 501032075600 CD5-316 INJ ACTIVE 501032075670 CD5-316PB1 EXPEND PA 501032080300 CD5-98 PROD ACTIVE 501032080360 CD5-981-1 PROD ACTIVE 501032074800 CD5-99 PROD PA 501032074801 CD5-99A PROD ACTIVE 501032074861 CD5-99AL1 PROD INACTV SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 10 & %" casing cement pump report on 9/8/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCrete lead and 15.8ppg class G cement, displaced with mud. Full returns were seen throughout the job. The plug bumped at 1000 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 9/21/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G tail. Full returns were seen throughout the job. The plug bumped at 950 psi, and the floats were checked and they held. The second stage cement job was pumped with 15.8ppg Class G tail. Full returns were seen throughout the job. The stage tool was confirmed closed. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 9/10/2019 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 9/24/2019 the 7-5/8" casing was pressure tested to 3,500 psi for 30 mins. The 3.5" tubing will be pressure tested to 4,750 psi prior to frac'ing. The 7-5/8" casing will be pressure tested to 4,180 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,500 Annulus pressure during frac 3,800 Annulus PRV setpoint during frac 3,900 7 5/8" Annulus pressure test 4,180 3 1/2" Tubing pressure Test 4,750 Nitrogen PRV 8,550 Highest pump trip 8,050 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & %11 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi 3.5" 9.3 L-80 10,160 psi 10,535 psi Table 2: Wellbore pressure ratings Stimulation Surface Rig -Up } y Bleed t Tattle F Tale Ta. oii! • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3900 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV N C N N 0 H d v Xorul damd v Pop -Off Tank Pump Truck Pop -Off Tank Alpine 1 OK Frac Tree ;K J ._..n. W. 4 1,18 WK FRAC FEEL' 17 Td".FWC 454 t£x "I i WI-A—tfl P, Pf SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick at the heel of the lateral and thinned to approximately 20-25ft to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 12256' MD/ -7394' TVDSS in the CD5-92. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 300' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 11291'MD/ -7064' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The top of the Kingak shale interval ranges from — -7,424' TVDSS at the heel to — -7269' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-92 wellbore). SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: CD5-98: The 7 & 5/8" casing cement report on 6/23/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G tail. The plug bumped at 1600 psi, and the floats were checked and they held. Partial losses were observed during cement operations, however the cement was logged and TOC was determined to be at 12,850' MD. CD5-23: The 7-5/8" casing cement pump report on 1/7/2018. Full returns were seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 ppg WBM. The plug bumped at 1,100 psi and the floats held. N Ln 0 v m c iu a E m E d c V O `y - m a c a c o f c °0 E u w E n ti v N E v U `o x N v N W a 0 m ti N m m m 0 c o N Ql in � oZ o ,p op l0 V O N VO H � o Z K c v � c - a S N a o o a o n `o v c v O S v a 0 c m a E a m c o 0 - o v r°� o c a _ E N lV N 0 F- c a a 6 O F N C an°o O m o O a 0 r v c � vOi � 0 'lp0 m o a° m 6 10- O d C m V N n H F > > W Q N Off 3 o u SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPA[ has formed the opinion, based on seismic, well, and other subsurface information currently available that ten faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-92. The only fault the CD5-92 wellpath intersected occurred at 13880' MD and had a throw of 3'. This fault was not interpreted in seismic. There were several small natural fracture systems encountered in the CD5-92 wellpath which have no interpretable offset:16182' MD, 18087' MD, 18121' MD, 18993' MD, 19030' MD, 19102' MD, 24520' MD, 24700' MD. Small losses of drilling fluids were noted associated with the two fracture systems at 24520' MD and 24700' MD; these losses healed after –4 hours and are well beyond the final frac stage. There was one observed fault in the CD5-23 within the one half mile radius at 12,725' MD, with a throw of 6'. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval, and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Faults and Fractures observed in CD5-92 and CD5-23 Wellbores (Fractures identified by 0' vertical displacement): Well Name Depth MD (ft) Depth TVDSS (ft) Vertical ment Displace ace Loss (bbls/hr) CD5-92 13880 -7392 3' 0 CD5-92 16182 -7372 0' 0 —C135 -92 18087 -7360 0' 0 CD5-92 18121 -7360 0' 0 CD5-92 18993 -7338 0' 0 CD5-92 19030 -7336 0' 0 CD5-92 19102 -7333 0' 0 CD5-92 24520 -7278 0' 22* CD5-92 24700 -7277 0' 22* CD5-23 12725 -7423 6' 0 *Losses healed after –4hrs Plat 2: CD5-92 Fault Analysis ADL388463 • Frac Points i Half Mile Frac Port Buffer Half Mile Well Track Buffer _ r 23 24 Fault in Frac Port Buffer r Wells within Frac Port Buffer i !Alpine PA i Well Track i -- - —• —- •-----._.i --- — �_ { Open Interval iI wf ! '- i Alpine PA i ASRC-NPR1 ` i Unit Boundary 6 25 x N�N — CPAI Lease %SRC-NPR8 i r 34 L---- 35 i 3b 31 - i j ASRC-NPR2 i I 3 T12JF4E T11N 4E r= ASRC-NPR3 ASRC-NPR4 rU � i co� I r I 12 ii 7 8 AA087888 AA092347 ' ----------•-•-•--r I CD_5 i I i i i w I ` f_ lr ConocoPhillips z z ASRC-NPR4 Alaska ~ ~ CD5-92 3 N Fault Analysis I ASRC-AA092344 A 0 0.2 0.4 0.6 0.8 1 Miles E Date: 9/30/2019 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-92 was completed in 2019 as a horizontal producer in the Alpine A formation. The well was completed with 3.5" tubing. In the A sand is a 4.5" liner with ball actuated sliding sleeves and pre perforated joints. We will establish injection and drop a ball which will shift a sleeve to close off the perforated joint section of the lateral. We will then pump the 1st stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 12,694 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU HES Frac Equipment. 6. PT Surface lines to 9,500 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Bring up pumps and increase annulus pressure from 2,500 psi to 3,800 psi as the tubing pressures up. 9. Pump the Frac job by following attached HES schedule @ 25bpm with a maximum expected treating pressure of 6,500 psi. 10. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 11. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). S a f 0 N C OA .� a v c c a Hydraulic Fracturing Fluid Product Component Information Disclost, t Freed—Date 1011=19 audit: Ateria campy: Harris-Ba API Numbest. 6010320600 NORTH SLOPE Operator Name: EBUS WE41 Name and Number: COs 92 Length d. 451.22 larmlda: 70.31 Loogjlaf Projection: NAD27 IndfardFederatt Production TyW.mo011 True Vertical Depth trvDI: 7 437 Total Water Volume 637,1W Hydraulic Fracturing Fluid Composition' Chemical Maximum Abstract Maximum ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration In Ingredient Mass Comments Company First Name Last Name Email Phone Number (CAS I% by mass)'" HF Fluid I% by lbs A .Bell, Sea Water Dperstcr Base Fluitl Water 7732 18-5 4371078 Density = 8.540 BE-MIC IOCIOE ""baton Beside Listed Below Listed Below 0 NA CL-22 UC Haifiburtm Crmslinker Listed Below Dated Below CL-22 J 0 NA CL-31 "burinn Crossynker Listed Below Listed Below CROSSLINKER 0 NA LOSURF3WD Hallburbn Non ionic Surtactant Listed Below Listed Below 0 NA M047 Hallbuten pH control Add— Listed Below Listed Deb. 0 NA OPTIFLO-III DELAYED Halliburton Breaker Listed Below Listed Below RELEASE 0 NA BREAKER SP BREAKER Halburlon Breaker Listed Below Listed Below 0 NA WG-36 GELLI NG Habburlon Gelling Agent Uiled Below Listed Below AGENT 0 NA LVF-2110 Perveco Fiesta, Poo l Listed Bab. Listed Below 0 NA Well Moll 20140 Pmpieim Addyive Listed Below Listed Below 0 NA Com Ingredients Listed Above Listed Above 1,2,4 Tnirelh Ibemene 95.63.6 1.001 G. coos P6 40 2-Bmmoo2nkm,1,3 nedbl 52-51-7 10..601 0.011391 79 DZ enise Tice, lburton, 3000 Denise.Tuck@ Acrylate polymer Proprietary 1.609 J..oJ s, 55 N. SamH... ton Pkwy E., Houston, Halliburton Denise Tuck HaOibunon.co 281-8715226 T% 77032,281- in 8714i226 Ammolum Peoullate 7727.540 001 0. J1c391 1050 Denise.Tuck@ Borate salts Proprietary ooa o.,:,9?! 3255 Halliburton Denise Tuck 11.11burtone. 201-871-8226 in Corundun 1302-74.5 001 13.636.50 721500 crystalline allies, quartz 1480a.60.7 009 O. M5619 321 Den--sa.Tock@ Cured acrylic resin Proprietary o.l 0. ue552s 315 Halmurmn Osilse Took HaOloudon.co 281471-226 Ethanol 64175 15 ..101521 2371 Guar 900030-0 001 0.23006! 13136 Hea aromatic tmleum na ma 64742-945 0.020761 1186 H edDMlllate, Point 6474247-8 G06 o-io1441 17212 Muiliie 130293-8 005 9.716.31 N ldhalems 91-203 009 0.0.3464 198 J—o. Ogeled phenolb resin Proprietary G 0.02769! 1582 Hallrbunon Denise Tuck Hallibunon.m 2813713226 PolylosyA.2tdarroSry9. alpi aHrsmypiarry¢omege4hdmxy-, 127087-87-8 aanehedPotasslum 001 6.003469 195 fomale 590-294 oris 0.05693! 3255 Patasslum Nodde 131058-3 001 60..2306 128 Pomo—metoborate 13709-949 00! 0.026461 1511 sodurn mom I mnulose 9004524001 0.00.959 55 Sodiumchloride 7647-145 069 3.191218 182217 witun odete 283632-0 001 0.1.0951 55 Sodiumh doidde 1310-73-2 GJ1 0.117176 981 5odkrm rsulfeu 777527-t oo6 o.Joo211 12 Sodiumsulfte 7757-82-6 106 o. 010009 1 Water 7732-18-5 GJ1 J. 11_131 6407 ' Total Water Volume sources may include fresh water, produced water, and/or—ycled water _ . Information Is based an the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin Win FDP), MSDS level only information has been provided. Al component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided a The Occupational Safety and Health Administrations (OSHA) regulations govern the coterie for the disdcalim of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidenbei business information" and the criteria for how this information is re neo on an MSDS is subect to 29 CFR 1910.1200 and molt D. N %%NMOOO N 4 ._ � �' d' 00 00 00 00 00 00 00 00 c� S N N N N (N N $ O O O O O O O O O O O w �1 Q / O O O O O O O O O O O v M M M L � LL. . V 2 \/ o 0 0 0 0 0 0 0 0 0 0 s � o0 00 00 00 00 00 00 00 00 00 00 � C O O L- > > O x d' �-- 14-7 M IZr � m �D r\ r� r- O O O cm m cm m cm M M cm d - Q V O H O r-� N m x m N O m r\ 4-;t x N l0 F M r, m r -I M l0 x O m m r- O N C r -i r-1 O dl X Xr,- Q0 M M CI- O r14 N N F— O O O O O O O O O O O O N -• 0 0 0 0 0 0 0 0 0 0 0 m O O O O O O O O O O O O O O O O O O O O O O O re � � Ol Ol 01 Dl Ol Ol Ol Dl tio CD r -I N M LIl LO 00 01 r -I t� V 1 V) O 4 -Ln +� v � � � v v L., V C6 h0 M O O U C (p O O 41 V O Q O � o Q) Ln L � � O O O m U N t L v v -0 O O O co O Q U Q QE EL — Ln E Q� O U ._ — U, G O � O c� a E Q) O +, U O a� v v a� Ln v . oO t Q v- � L O E > D 4.J U L v N Ln Ln Ln v 0 O E v E O L 4- Z. - i. N N WR 4- Lo a� N � v v E — }, ca , N U U (B 4A � v i -- Ln aj O O O C_ V) O a1 L C U v 41 L C O � a-' Q O o N � � L � O C: C O �E n4-1 Q) o73- LnL� L _ � v O 40- 0 E OE E cu aj Ln -LZ cr c (ztN m C: co O Q iQE a)'nLn E—� EQ� -� � O � � 0 4- O 4- U O C) v cz LA L CD C) -Z- U., Q CL OJ o C L d -i � Q � L O 0 Ln C L Ln aj U t c N F- L CO Ln _4-1 N Qj Q� O E C) 4-1C C O 14L v a fB A U ti 0000 N 0000 N Q W � S Mo V � d1 m _ O r -I O rl LL m 4 bb CL a .. Gi O J O WW O a 0 CL -- o r r- � Or- � t C m N `o r W N •-• cn -0 O O O O O O O 0) Ol W bA N M m l� N WR 4- Lo a� N � v v E — }, ca , N U U (B 4A � v i -- Ln aj O O O C_ V) O a1 L C U v 41 L C O � a-' Q O o N � � L � O C: C O �E n4-1 Q) o73- LnL� L _ � v O 40- 0 E OE E cu aj Ln -LZ cr c (ztN m C: co O Q iQE a)'nLn E—� EQ� -� � O � � 0 4- O 4- U O C) v cz LA L CD C) -Z- U., Q CL OJ o C L d -i � Q � L O 0 Ln C L Ln aj U t c N F- L CO Ln _4-1 N Qj Q� O E C) 4-1C C O 14L v a fB A SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) Loepp. Victoria T (CED) From: Klem, Adam <Adam.Klem@conocophilIips.com> Sent: Thursday, October 10, 2019 3:01 PM To: Loepp, Victoria T (CED); Beat, Andrew T Cc: Boyer, David L (CED); Wallace, Chris D (CED); Davies, Stephen F (CED) Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Victoria, My apologies. We have gone away from putting depths on the schematic sent in with the sundry as those have to be manually entered for each change, and we are trying to remove duplication of depths in multiple areas to reduce any wrong information. The Baker premier production packer was set at 12,075.65' MD. Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 10, 2019 2:57 PM To: Klem, Adam <Adam.Klem@conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Adam, This WBS is very difficult to read. Your schematic provided with the frac sundry is great however it has no depths. Anyway, on the WBS you did provide I cannot locate the production packer. It is not listed under the completion details. Victoria From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, October 10, 2019 2:41 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david. boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Victoria, Attached is the WBS with depths. I'll look into your cement question. Thanks, Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 10, 2019 2:34 PM To: Klem, Adam <Adam.Klem @conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophi Ili ps.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.w...ace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Adam, I am reviewing this now specifically the intermediate cement job. The log shows poor cement from about 12000' MD likely to the shoe at 12292' MD; is that correct? Also, please send the final WBS annotated with depths Tha nx, Victoria From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, October 10, 2019 2:09 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Status of CD5-92 10-403 to frac Hello, We are looking to be ready to frac CD5-92, API# 50-103-20800-00-00, PTD# 219-034 this coming Sunday 13th. I have not received any questions or comments regarding this sundry application, so I wanted to check to see if it is processing and if there will be any issues getting it approved by tomorrow so we can start the stimulation on Sunday? Feel free to contact me via email or my cellphone. Thank you, Adam Klem Senior Completions Engineer Alpine ConocoPhillips Alaska 700 G St ATO 1712 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com Loepp. Victoria T (CED) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, October 4, 2019 3:31 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: CD5-92 Intermediate Cement Log (219-034) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Intermediate shoe depth is 12,292' MD. Top of the Alpine 11,872' MD. FIT was to 12.5 ppg EMW. We are actively running the liner now so we'll have an updated schematic once the completion is in place. If WBS didn't mean wellbore schematic then let me know. Thanks, Andrew (303) 378-8881 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, October 04, 2019 1:42 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]RE: CD5-92 Intermediate Cement Log (219-034) Andrew, Thanx for the log and cement job details. What is the depth of the intermediate shoe and the top of the Alpine? Do you have a current WBS? What was the FIT out of the shoe? 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.gov From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, October 4, 2019 11:27 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Klem, Adam <Adam.Klem@conocophillips.com> Subject: CD5-92 Intermediate Cement Log (219-034) Victoria, Please see the attachments for the intermediate cement job on CD5-92 (219-034). The job was pumped as planned with full returns and the plugs bumped/floats held. Cement top was logged at 10,960' MD. Please let me know if you have any questions. Thanks, Andrew (303)378-8881 'NNS PROD WELLNAME CD5-92 WFILBORE CD5-92 t__ _ _ o_nV!n.-_ Al Attributes lax Anaie & MD 1TD `vet rva.vr I um a- Alaska. Inc. Field Nam Wellltae APWWI Weiltrore Status IMIt°7 MO(ftK8) AM Sir"(RKB) PIN PROD 45,65 28.339.03 23,410.0 Comment H23(ppm) Date Armotation End Dat< Ke-Grd(it) I Rig Rateasa Data SSSV: NIPPLE LAST WO: 39.20 11W912019 I HORIZONTAL, CD5-92, 10110/2019 2:39:29 PM Last Tag Annotation Depth (WS) End Date Watlbore Last Mod By D LAST TAG CC15-92 jennalt (ft Vertical schematic (actual) Last Rev Reason KB Annotation End Date Wellbore Last Mod By REV REASON: 10!102019 C05-92 jennalt ......................... _.. _... _...................._.........................................,..... Casing Strings >•.�_ ,on.>m Casing Description OD (in) ID (int Top (ft)(81 Set Depth (RKB) Set Depth ITVD)... WVLen (L.. Grade Top Thread .. CONDUCTOR 20 19.25 35.0 115.0 115.0 94.00 H40 ............ .......... n, a.._.a .,a......_.._.............._.. Ceam 9 Descriptio. OD (in) to (In) Top (RKB) Set Depth (RKB) Sat Depth (TVO)... Will -en (I.., Grads Top Thread 10314"SURFACE 103/4 9.95 39.0 2,246.0 2.188.9 45.50 L-80 TXP-M Casing Description OD Iml 10 (in) Top (hK8) Set Depth (RKB) Set Depth (TVD)... Will." IL, Grade Top Thread 75/8"INTERMEOIATE 7518 6.88 36.9 12,292.9 7,469.6 29.70 Lao TXPM �m Casing Description Do 41.) to (in) TOp(ftKe) Set Depth (W]3) Set DepM(TVDi... Wt11Lert(I... Grade TW Thread 412"LINER 4112 3.96 12,1302 24,993.0 7,34&2 12.60 L-80 Hyd563 Liner Details Nominal to Top (R)(B) Top (TVD) (RKB) Top Incl (°) Ram Des Com (in) I ! 12,1302 7.4561 82.71 PACKER "HR -E" ZXP Liner Top Packer w111 A5'SBE for 39# 5.740 „. ,. ..n casing 12,150.1 7,458.4 83.48 PACKOFF "RS" Packoff Seal Nipple 4.250 12,152.4 7,458.7 83.57 HANGER 'DG"Flex-Lock Liner Hanger 4.800 12.161.9 7,459. .93 -XU-- XO. 5.5" H563 x 5" H521, bxb 4,390 REDUCING 12,7726 7,460.8 84.35 SSE SBE, 5" H521 x 4.5" H521, 80-40 4,000 12.190.9 7462.5 85.05 XO - XO Pup, 4.5" H521 x 4.5" H563 3.958 REDUCING 12,723.4 7.471.7 90.33 FRAC Baker frac sleeve #13, Hyd563 SN H809080389 2.335 SLEEVEIPORT 2,335" OD Ball 73.493.4 7,467.3 90.27 FRAC Baker frac sleeve #12, Hyd563 SN 1-1809086307 2.295 SLEEVEIPORT 2.295'00 Ball 14 241.7 7,465.0 90.44 FRAC Baker frac sleeve #11, Hyd563 SN H809080386 2.255 SLEEVEIPORT 2.255" OD Bali 15,010.7 7.4614 89.96 FRAC Baker frac sleeve #10, Hyd563 SN HBOW80385 2.215 SIEEVE/PORT 2.215"OD Ball �....tl,=„� s=� _ 15,770.7 7,460.0 91.54 FRAC Baker frac sleeve #9, Hyd563 SN H809080384 2.175 °'�°-•'_••"'_„•''•s'�=•°^_@ SLEEVEIPORT 2.175" OD Ball 16,535.3 7.431.6 90.95 FRAC Baker frac sleeve #8. Hyd563 SN H809080383 2.135 SLEEVEIPORT 2.135" OD Bail 17,302.8 7,430.1 89.79 FRAC Baker frac sleeve #7, Hyd563 SN H809080382 2.095 SLEEVEIPORT 2.095" OD Ball 7,433.2 89.98 FRAC Baker frac sleeve #6, Hyd563 SN H80908038 2,055 SLEEVEIPORT 2.055" OD Ball 18.846.3 7.420.3 94.01 FRAC Baker frac sleeve #5, Hyd563 SN H9595726 2.015 °^°�"-''_'-•�•=°'-.m SLEEVE/PORT 2.015* DO Bail .-.�•:,.. a,-..,.0=�.�, 19,616.1 7.396.1 89.41 FRAC SLEEVEIPORT Baker frac sleeve #4, Hyd563 SN H809080725 1.975" OD Ball 1.975 20,391.1 7.395.3 89.21 FRAC Baker frac sleeve #3. Hyd563 SN H809080724 1.935 SLEEVEIPORT 1.935"00 Ball 21,156.9 7,398.3 9041 FRAC Baker frac sleeve #2, Hyd563 SN H809080723 1,895 SLEEVE/PORT 1.895" OD Ball 21,97 7,382.3 93.13 FRAC Baker frac sleeve #1, Hyd563 SN H809080722 1.855 ""-•"`•," •�."°° SLEEVE/PORT 1.955"OD Ball -------- Tubing Strings Tubing DescriptionSin- Ma.. 10 (in) -[12D99 Top 1nKe1 Set Depth (R.- Set Dey::. r1 ..., i....°. ,„..... ........ TUBING 3112 2.99 0.0 12,745.8 7.458.0 9.30 L-80 EUE8rdh1 "-"'@'-° PRODUCTION Completion Details Tap (TVD) Top Incl Nominal fl Top (ftKB) (ftK8) (°) Rem Des Com ID (in) 34.6 34.6 0.00 HANGER FMC 4-1i2" Tubing Hanger H563 3.958 .a. �.-....�a.,.°.,.,.�=�..n.�.os 79.2 79.2 0.15 XO REDUCING CROSSOVERA 112" H563 X 3112"EUE,81w2.992 7,-,_°„ 1,979.2 1.947.1 22.06 IPPLE Landing Nipple, 3-112".X, 2.813", EUE-Sb (` 2,000' MD) 2.813 12.018.1 7437.3 7.94 GAUGEIPUMP SLB Gauge Carrier, 9.3# L-80 EUE PinxPin w/top coupling 2.913 .. ..,.-,- SENSOR 12,103.9 7452.5 81.68 NIPPLE NIPPLE,LANDING,3112".XN,2.813%FUF8RDM_ 2. 75 no -g. 2.7-10 w/Dual Flapper 12.1 6.0 7,455.5 8255 LOCATOR Mechanical locator, EUE (" OD locatorl 2.980 12.144.8 7,457.9 83.27 MULE SHOE Baker WLEG 2.990 Other in Hole (Wireline r: Top (TVD) Top Incl Date °°" $-" C8" '910'e° Top (RKB) (ftK8) (°) Des Com Run to (in) 34.6 ... 0.00 BARRI R BACK "H" type BPV 10798019 PRESSURE VALVE IS PROD WELLNAME CD5-92 WELLBORE CD5-92 ConocoPhillips Alaska, Inc. HORIZONTAL, CDS-92, 1Oil OJ20192:39:31 PM Mandrel Inserts D (ft KB Vertical schematic (actual) st ad N Top (TVD) Valve latch Pori Site TRO Run Top (ftKB) (ftKB) Make Model OD (In) Sery Type Type (in) (psi) Run Date Com T 4,309.2 3,516.8 Camco KBMG GLV 2 ,1378 5,496.5 Camco KBMG GL 3 11,897.4 7,407.5 Camw KBMG GLV Notes: General & Safety End Date Annotation ........ .. ......... eaanrymma�.._......... Ypiods..r9a*rm� 10/10/2019 NOTE: N s Ln V � 1 � M O •- p Z V Q. Q 3 ^t ice' • M V U. N V 75 Z M Q CL M N N Ln Lli N V Q � Q U N n• a► CL G U V N t CL m CL :o a`o ate. rn rn rn rn rn rn rn rn ci OI �-i O c -i O ci O N O r -I O c-1 O rl O Co N _I mN J m N J m N J� Co N J m N JPl m N J I J N \ O O O O O O O O O O O O 0 O O O O O O O O ri a -I c -I ci e--1 r -I e-1 e -i Q) N C co U N 'a � <a N cL6 v f 6 L1 C 1 N m C O O m _ M N O N 41 L Q 41 4L C L y C1 O OC C L= O O ++ - a (d N F- L O ++ H 3 m ai Z N ri � g v v _a � a; -o m vii v ►�- F c Q u 0 3 N a° 0 3 o a o 0 ~ O N O (U OV O (a O ++ N C N cC 3 N C M c6 0 a s- O Y O cn O E U 'a N pp i� _ N O 'i C N N Q Q w m w 10 CL C7 N +�_-+ o. 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Qe rJ 3� vti a vi a o c a a a`c a�A rn 0 N O rH O U IM O r-1 N OA m CL 4-+ N Ln t V I � O M • ._ O V 4-0Z •u CL c to ._ � M � O V m li N V •— O 3 Z M D >. a r M N co CA 0V N V Q V O N (-3 U a n_ r4 u ri v DO a � c Lo O i u l 3 A 1 1 zE ,u N T C ' pQ i m_,_ n v u ri v DO a PTO a 9 - 913 9- Loepp, Victoria T (CED) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, October 14, 2019 10:37 AM To: Loepp, Victoria T (CED) Cc: Regg, James B (CED) Subject: Re: [EXTERNAL]CD5-92 MITT Follow Up Flag: Follow up Flag Status: Flagged Victoria, The DFCV is a dual flapper check valve we ran at the end of the tubing to pressure test against. We just got it pulled and saw the equalizing sub on it had failed. We believe that is what caused the failure. We are proceeding with installing a new plug to test, just having some issues with it. Thanks, Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, October 14, 2019 10:32:30 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]CD5-92 MITT Adam, With the information presented, the tubing pressure test does not meet our criteria of <10% loss in 30 min. Based on this criteria a new plug should be set and the test repeated. We can take a closer look at the data to see if it affects our decision. We would need the MITT and MITIA submitted on the AOGCC test form and the pressure charts. That will take additional time. What is a DFCV? This is a producer, correct? Victoria Sent from my iPhone On Oct 14, 2019, at 9:07 AM, Klem, Adam <Adam.Klem @conocophillips.com> wrote: It fell off from 5050 psi to 4738 at 25 minutes, where we went to pressure it back up. At 4800psi it fell off pretty hard. And we started pumping slowly into it. Additionally we did have a 4000psi 30 min test on rig. So, we are very confident in the integrity of the tubing, and believe it was the flapper check valve that failed as we have had issues on the last two previous wells we drilled at CD5. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, October 14, 2019 8:36:47 AM To: Klem, Adam <Adam.Klem @co nocophillips.com> Subject: Re: [EXTERNAL]CD5-92 Approved and ready for PU How much pressure loss during the 2nd 15 minutes(tubing)? Sent from my iPhone On Oct 14, 2019, at 5:59 AM, Klem, Adam <Adam.Klem @conocophillips.com> wrote: Victoria, Over the weekend we went to pressure test the tubing to 5200 psi against the DFCV while holding 0 psi on the IA. The tubing lost 123 psi in the 1st 15 min and during the 2nd 15 min the pressure started to fall off. There was no pressure increase on the IA, which leads us to believe that the DFCV failed. We were able to pump 5 bbls down the tubing @ .5 bpm with our tubing pressure @ 2400 psi and slowly increasing with no change in IA. We also had a passing IA pressure test to 4200psi. My question is, do you accept this as a passing pressure test or do we need to run a new plug to pressure test the tubing? Thanks, Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, October 11, 2019 1:14:26 PM To: Klem, Adam <Adam.Klem @conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]CD5-92 Approved and ready for PU From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Friday, October 11, 2019 10:53 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: Re: [EXTERNAL]Status of CD5-92 10-403 to frac I would agree that the cement is ratty at the bottom below 12,000'. We did get a good FIT indicating we have good show integrity. Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, October 11, 2019 10:50:18 AM To: Klem, Adam <Adam.Klem@conocophillips.com>; Beat, Andrew T 2 <Andrew.T.Beat@conocophiIIips.com> Subject: [EXTERNAL]Status of CD5-92 10-403 to frac I have not heard back on the cement question. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, October 10, 2019 3:01 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Victoria, My apologies. We have gone away from putting depths on the schematic sent in with the sundry as those have to be manually entered for each change, and we are trying to remove duplication of depths in multiple areas to reduce any wrong information. The Baker premier production packer was set at 12,075.65' MD. Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 10, 2019 2:57 PM To: Klem, Adam <Adam.Klem @conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Adam, This WBS is very difficult to read. Your schematic provided with the frac sundry is great however it has no depths. Anyway, on the WBS you did provide I cannot locate the production packer. It is not listed under the completion details. Victoria From: Klem, Adam <Adam.Klem @conocophillips.com> Sent: Thursday, October 10, 2019 2:41 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.go_v>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@aiaska.gov> Subject: RE: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Victoria, Attached is the WBS with depths. I'll look into your cement question. Thanks, Adam From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 10, 2019 2:34 PM To: Klem, Adam <Adam.Klem@conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL]RE: Status of CD5-92 10-403 to frac Adam, I am reviewing this now specifically the intermediate cement job. The log shows poor cement from about 12000' MD likely to the shoe at 12292' MD; is that correct? Also, please send the final WBS annotated with depths Thanx, Victoria From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, October 10, 2019 2:09 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Status of CD5-92 10-403 to frac Hello, We are looking to be ready to frac CD5-92, API# 50-103-20800-00-00, PTD# 219-034 this coming Sunday 13th. 1 have not received any questions or comments regarding this sundry application, so I wanted to check to see if it is processing and if there will be any issues getting it approved by tomorrow so we can start the stimulation on Sunday? Feel free to contact me via email or my cellphone. Thank you, Adam Klem Senior Completions Engineer Alpine ConocoPhillips Alaska 700 G St ATO 1712 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com Loepp, Victoria T (CED) From: Regg, James B (CED) Sent: Monday, October 14, 2019 9:58 AM To: Loepp, Victoria T (CED) Subject: RE: CD5-92 Tubing Pressure Test Follow Up Flag: Follow up Flag Status: Flagged Producer or injector? What is a DFCV? Why a MITT to 5200psi - our requirement? Seems unusual to not have at least a couple hundred psi imposed on the backside (IA) to facilitate monitoring of the pressure during the tubing test. It is also unusual to have "no pressure increase" — not even any ballooning effects from a 5200psi differential tubing to IA? I don't see where the <10% pressure loss criteria has been demonstrated. It appears the tubing pressures at 30 minutes dropped to 2400psi (he said the plug failed during the 2nd 15minute monitoring period — 50% pressure loss). And, what were the pressures in the tubing and OA during the alleged passing MITIA? They should submit the MITT and MITIA on our test form so we have a more complete picture for a decision; it appears based on what was submitted that the intent of our requirements has not been met (even if we accept the rolling pressure test of the tubing after the alleged plug failure is a valid test procedure). My opinion. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITYNOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or jim.re @alaska.�ov. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, October 14, 2019 8:40 AM To: Regg, James B (CED) <jim.regg@alaska.gov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Subject: CD5-92 Tubing Pressure Test Since this is less than 10% loss in 30 min this would be a passing tubing pressure test. Correct? Sent from my iPhone Begin forwarded message: From: "Klem, Adam" <Adam.Klem@conocophillips.com> Date: October 14, 2019 at 5:59:48 AM AKDT To: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov> Subject: Re: [EXTERNAL]CDS-92 Approved and ready for PU Loepp, Victoria T (CED) From: Regg, James B (CED) Sent: Sunday, October 6, 2019 12:17 AM To: Loepp, Victoria T (CED) Subject: Re: CD5-92 BOP Test Extension Request Follow Up Flag: Follow up Flag Status: Flagged Test before running. They know we dont give extensions to 14 day BOPE test interval. Sent via the Samsung Galaxy S8 Active, an AT&T SG Evolution capable smartphone -------- Original message -------- From: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov> Date: 10/5/19 3:18 PM (GMT -09:00) To: "Regg, James B (CED)" <jim.regg@alaska.gov> Subject: Fwd: CD5-92 BOP Test Extension Request Any comments? Sent from my iPhone Begin forwarded message: From: "Beat, Andrew T" <Andrew.T.Beat@conocophillips.com> Date: October 5, 2019 at 1:55:47 PM AKDT To: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.gov> Cc: Doyon 25 Company Man <d25cm@conocophillips.com>, "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>, "Alexa, Kurt J" <Kurt.J.Alexa@conocophillips.com>, "Klem, Adam" <Adam.Klem@conocophillips.com>, "Njoku, Johnson" <Johnson.Nioku@conocophillips.com> Subject: CDS-92 BOP Test Extension Request Victoria, I would like to request a 24 hour BOP test extension for Doyon 25 on CD5-92. We are currently due for a test at midnight tomorrow (10/6). Currently, we are laying down drill pipe after setting our production liner. The liner hanger set successfully and the packer tested. We expect to begin running the upper completion tomorrow morning and should have the hangar landed and the well tested sometime Monday morning. Our original schedule had us completing the well before our next required test, however, our DP connections have been extremely tight which has drastically slowed down the lay down process and pushed our schedule past the deadline. We are planning on testing BOP equipment tomorrow morning unless an extension is granted. Loepp, Victoria T (CED) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, October 4, 2019 3:31 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: CD5-92 Intermediate Cement Log (219-034) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Intermediate shoe depth is 12,292' MD. Top of the Alpine 11,872' MD. FIT was to 12.5 ppg EMW. We are actively running the liner now so we'll have an updated schematic once the completion is in place. If WBS didn't mean wellbore schematic then let me know. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, October 04, 2019 1:42 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]RE: CD5-92 Intermediate Cement Log (219-034) Andrew, Thanx for the log and cement job details. What is the depth of the intermediate shoe and the top of the Alpine? Do you have a current WBS? What was the FIT out of the shoe? 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. LoeppCa_)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, October 4, 2019 11:27 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Klem, Adam <Adam.Klem@conocophillips.com> Subject: CD5-92 Intermediate Cement Log (219-034) Victoria, Please see the attachments for the intermediate cement job on CD5-92 (219-034). The job was pumped as planned with full returns and the plugs bumped/floats held. Cement top was logged at 10,960' MD. Please let me know if you have any questions. Thanks, Andrew (303)378-8881 FOLD HERE: The well name, location and borehole reference data were furnished by the customer. cov CD zr Any interpretation, research, analysis, data, results, estimates, or recommendation furnished with the services or otherwise communicated by Schlumberger to the customer at any time in connection with the services are opinions based on inferences from measurements, empirical relationships, and/or assumptions; which, inferences, empirical relationships and/or assumptions are not infallible and with respect to which professionals in the industry may differ. Accordingly, Schlumberger cannot and does not warrant the accuracy, correctness, or completeness of any such interpretation, research, analysis, data, results, estimates, or recommendation. The customer acknowledges that it is accepting the services "as is," that Schlumberger makes no representation or warranty, express or implied, of any kind or description in respect thereto, and that such services are delivered with the explicit understanding and agreement that any action taken based on the services received shall be at its own risk and responsibility, and no claim shall be made against Schlumberger as a consequence thereof. Svc. Order #: OP Vers: Processed by: Process Date: 10/03/2019 Location; I Techlog 2019 e-mail:jburt2@slb.com Top of Cement is identified on the logs at 10960' MD based on the decrease in sonic amplitude. COMPANY: ConocoPhillips Alaska LLC. n (J)C 79 C n WELL: CD5-92 D M 0 FIELD: Western North Slope STATE: Alaska z M !- COUNTRY: USA D z . Location �x D z m Q o n cn C O C D�C7C� Q DE57CD O 8 .-F1 CD N o � O O z 70 3. U) D o v -0 CD N 7 • 4A C7 FOLD HERE: The well name, location and borehole reference data were furnished by the customer. cov CD zr Any interpretation, research, analysis, data, results, estimates, or recommendation furnished with the services or otherwise communicated by Schlumberger to the customer at any time in connection with the services are opinions based on inferences from measurements, empirical relationships, and/or assumptions; which, inferences, empirical relationships and/or assumptions are not infallible and with respect to which professionals in the industry may differ. Accordingly, Schlumberger cannot and does not warrant the accuracy, correctness, or completeness of any such interpretation, research, analysis, data, results, estimates, or recommendation. The customer acknowledges that it is accepting the services "as is," that Schlumberger makes no representation or warranty, express or implied, of any kind or description in respect thereto, and that such services are delivered with the explicit understanding and agreement that any action taken based on the services received shall be at its own risk and responsibility, and no claim shall be made against Schlumberger as a consequence thereof. Svc. Order #: OP Vers: Processed by: Process Date: 10/03/2019 Location; I Techlog 2019 e-mail:jburt2@slb.com Top of Cement is identified on the logs at 10960' MD based on the decrease in sonic amplitude. Company: ConocoPhillips Alaska, Inc. Well: CD5-92 Field: Western North Slope State: Alaska Country: USA Schlu hepgep SonicScope Top of Cement Schlumberger Cementing Job .ceport CemCATv1.7 Well CD5-92 Client ConocoPhillips Field Apline SIR No. 84027 Engineer John Morrison Job Type Intermediate Casing Country United States Job Date 09-21-2019 Time -019 07.-53 pump pressure Rate Density Messages 09:30:37 10:01:00 Reset Total, Vol = 4.54 bbl water ahead High PT 10:31:00 Bleed Off Pressure batch up mudpush Reset Total, Vol = 2.28 bbl start pumping mudpush returns to pits cement wet 11:01:00 issues on rig floor cement going downhole, 15.8 scat Reset Total, Vol = 60.2 bbl 11:31:00 returns to floor 4 bbl cmt pumped before stagr res. Reset Total, Vol = 125.0 bbl 12:01:00 dropping plug 20 bbl water behind Returns at Surface Reset Total, Vol = 20.17 bbl Rig Pumps To Displace Reset Total. Vol = 0.00 bbl Reset Total, Vol = 2.02 bbl 12:31:00 13:01:00 landed stage 1 top plug 13:31:46 Pressuring up to open stage collar stage collar open, 3420 psi 5357 strokes to bump top plug 15:55:29 rely for stage 2 mudpush batched up start mudpush Returns at Surface 16:20:00 Reset Total. Vol = 41.91 bbl cement wet Start Cement Slurry Returns at Surface 16:45:00 _ Reset Total, Vol = 66.24 bbl 20 bbl water Tota Reset l, Vol = 20.19 bbl tum over to rig for displacement 17:10:00 slow rate for bump 17;35:00 land top plug attempting to close stage tool 2572 STKS to bump 17:59:43 tool "shut" Reset Total, Vol = 0.00 bbl hh:mm:ss °D0 '°°° 2000 5000 0m I6 33 Il GA U SA 14 11° 1]D 210 234 0m 101° 2000 3000 1000 s°°° .caves+vera PSI IV LB/G Psi 09/21/2019 20:07:23 Schlumberger Cementing Service Report Page 1 of 24 Customer Conoco Phillips lob Number 84027 Well CDS-92 Location (legal) Drill Site CDS Schlumberger Location PRUDHOE OTHER lob Start Sep/21/2019 Field Apline Formation Name/Type Clean -Sandstone Deviation 90 deg Bit Size 9.9 In Wali MD 12306.0 R Well TVD 7471.3 ft County North Slope Stat*/Province Alaska BHP psi BHST 168 degF BHCT 122 degF Pore Press. Gradient Ib/gal Well Master 0065860944 API/UWI 501032080000 Rig Name Doyon 25 Drilled For 011 Service Vla Land Casing/User Depth, ft Size, In Weight, lb/ft Grade Thread Offshore Zone Well Class New WOR Type Development 11295.8 7.6 29.7 L80 HYD563 12291.1 7.6 39.0 L80 TXP Drilling Fluid Type M. Danslty Ib/gal Plastic Viscosity CP Tubing/Drill Pipe T/D Depth, R Size, In Weight, ib/ft Grade Thread Service Line Cementing lob Type Intermediate Casing Max. Allowed Tub. Press psi Max. Allowed Ann. Press psi WH Connection 2"1502 Perforations/Open Mol* Top, R Bottom, R shot/ft No. of Shots Total Interval Service Instructions 361 pump skid 1 set triple silos 1 ABT 125 bbl cement and 60 bbl spacer for stage 1 66 bbl cement and 40 bbl spacer for stage 2 20 bbl water on top of each top plug (( ft R ft R Diameter in R ft Treat Down Casing Displacement Packer Type 561.3 bbl Packer Depth ft Tubing Vol. bbl Casing Vol. Annular Vol. 566.5 bbl 699.2 bel Openhole Vol. bbl Cuing/Tubing Secured ❑ 1 Hols Vol. Circulated prior to Cement x❑ Casing Tools Squeeze lob UR Pressure 550 psi Shoe Type Float Squeeze Type Pipe Rotated ❑ Pipe Redprocsted ❑ Shoe Depth 12291.1 ft Tool Type No. Centralizers 104 1 Top Plugs 2 Bottom Plugs 1 Stage Tool Type HES Tool Depth ft Cement Head Type Stage Tool Depth 6073.8 ft Tail Pips Shka in Job Scheduled For Sep/21/2019 Arrived on Location Sep/21/2019 Leave Location Sep/21/2019 Collar Type HM Tail Pipe Depth ft Collar Depth 12168.7 R Sgz.Total Vol. bbl Date Time 244ar dock PRESS DENS PSI LS/G RATE B/M Volume BBL WHP Massage PSI 09/21/2019 07:45:53 53 0.0 0.0 0.0 -3669 Started Acquisition 09/21/2019 07:46:08 50 0.0 0.0 0.0 -3668 On location @ 0700 09/21/2019 07:46:18 49 0.0 0.0 0.0 -3669 09/21/2019 07:46:43 44 0.0 0.0 0.0 -3670 09/21/2019 07:47:08 39 0.0 0.0 0.0 -3670 09/21/2019 07:47:33 40 0.0 0.0 0.0 -3667 09/21/2019 07:47:58 39 0.0 0.0 0.0 -3669 09/21/2019 07:48:23 40 0.0 0.0 0.0 -3668 09/21/2019 07:48:48 51 0.0 1 0.0 0.0 -3669 09/21/2019 07:49:13 48 0.0 0.0 0.0 -3669 09/21/2019 07:49:38 48 0.0 0.0 0.0 -3668 09/21/2019 07:50:03 51 0.0 0.0 0.0 -3670 09/21/2019 07:50:28 48 0.0 0.0 0.0 -3667 09/21/2019 07:50:53 47 0.0 0.0 0.0 -3669 09/21/2019 07:51:18 49 0.0 0.0 0.0 -3669 09/21/2019 07:51:43 39 0.0 0.0 0.0 -3668 09/21/2019 07:52:08 40 0.0 0.0 0.0 -3671 09/21/2019 07:52:33 41 0.0 0.0 0.0 -3667 09/21/2019 07:52:58 43 0.0 0.0 0.0 -3669 09/21/2019 07:53:23 46 0.0 0.0 0.0 -3669 09/21/2019 07:53:48 48 0.0 0.0 0.0 -3667 Page 1 of 24 Well CD5-92 Field Apline Iob Start Sep/21/2019 Customer ConocoPhillips lob Number 84027 Date Time 24-br clock PRESS PSI DENS LB/G RATE B/M Volume BBL WHIP Message PSI 09/21/2019 07:55:03 50 0.0 0.0 0.0 -3668 09/21/2019 07:55:28 50 0.0 0.0 0.0 -3669 09/21/2019 07:55:53 49 0.0 0.0 0.0 -3670 09/21/2019 07:56:18 40 0.0 0.0 0.0 -3669 09/21/2019 07:56:43 38 0.0 0.0 0.0 -3668 09/21/2019 07:57:08 41 0.0 0.0 0.0 -3669 09/21/2019 07:57:33 43 0.0 0.0 0.0 -3668 09/21/2019 07:57:58 48 0.0 0.0 0.0 -3670 09/21/2019 07:58:23 49 0.0 0.0 0.0 -3668 09/21/2019 07:58:48 51 0.0 0.0 0.0 -3669 09/21/2019 07:59:13 50 0.0 0.0 0.0 -3668 09/21/2019 07:59:38 51 0.0 0.0 0.0 -3669 09/21/2019 08:00:03 48 0.0 0.0 0.0 -3666 09/21/2019 08:00:28 48 0.0 0.0 0.0 -3671 09/21/2019 08:00:53 42 0.0 0.0 0.0 -3669 09/21/2019 08:01:18 42 0.0 0.0 0.0 -3670 09/21/2019 08:01:43 41 0.0 0.0 0.0 -3669 09/21/2019 08:02:08 42 0.0 0.0 0.0 -3670 09/21/2019 08:02:33 48 0.0 0.0 0.0 -3667 09/21/2019 08:02:58 48 0.0 0.0 0.0 -3669 09/21/2019 08:03:23 48 0.0 0.0 0.0 -3669 09/21/2019 08:03:48 49 0.0 0.0 0.0 -3670 09/21/2019 08:04:13 47 0.0 0.0 0.0 -3668 09/21/2019 08:04:38 48 0.0 0.0 0.0 -3668 09/21/2019 08:05:03 48 0.0 0.0 0.0 -3669 09/21/2019 08:05:28 41 0.0 0.0 0.0 -3667 09/21/2019 08:05:53 42 0.0 0.0 0.0 -3672 09/21/2019 08:06:18 41 0.0 0.0 0.0 -3667 09/21/2019 08:06:43 42 0.0 0.0 0.0 -3671 09/21/2019 08:07:08 43 0.0 0.0 0.0 -3670 09/21/2019 08:07:33 39 0.0 0.0 0.0 -3668 09/21/2019 08:07:58 36 0.0 0.0 0.0 -3668 09/21/2019 08:08:23 37 0.0 0.0 0.0 -3669 09/21/2019 08:08:48 42 0.0 0.0 0.0 -3667 09/21/2019 08:09:13 48 0.0 0.0 0.0 -3669 09/21/2019 08:09:38 49 0.0 0.0 0.0 -3669 09/21/2019 08:10:03 49 0.0 0.0 0.0 -3667 09/21/2019 08:10:28 50 0.0 0.0 0.0 -3671 09/21/2019 08:10:53 49 0.0 0.0 0.0 -3668 09/21/2019 08:11:18 47 0.0 0.0 0.0 -3669 09/21/2019 08:11:43 45 0.0 0.0 0.0 -3667 09/21/2019 08:12:08 42 0.0 0.0 0.0 -3671 09/21/2019 08:12:33 42 0.0 0.0 0.0 -3672 09/21/2019 08:12:58 40 0.0 0.0 0.0 -3668 09/21/2019 08:13:23 39 0.0 0.0 0.0 -3669 09/21/2019 08:13:48 48 0.0 0.0 0.0 -3670 09/21/2019 08:14:13 45 0.0 0.0 0.0 -3667 09/21/2019 08:14:38 47 0.0 0.0 0.0 -3669 09/21/2019 08:15:03 49 0.0 0.0 0.0 -3667 09/21/2019 08:15:28 49 0.0 0.0 0.0 -3668 09/21/2019 08:15:53 47 0.0 0.0 0.0 -3670 09/21/2019 08:16:18 48 0.0 0.0 0.0 -3669 09/21/2019 08:16:43 41 0.0 0.0 0.0 -3666 09/21/2019 08:17:08 41 0.0 0.0 0.0 -3669 Page 2 of 24 We" CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhillips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LS/6 RATE y/M Volume SOL WHP Message PSI 09/21/2019 08:17:58 41 0.0 0.0 0.0 -3671 09/21/2019 08:18:23 40 0.0 0.0 0.0 -3669 09/21/2019 08:18:48 51 0.0 0.0 0.0 -3668 09/21/2019 08:19:13 47 0.0 0.0 0.0 -3669 09/21/2019 08:19:38 49 0.0 0.0 0.0 -3667 09/21/2019 08:20:03 51 0.0 0.0 0.0 -3669 09/21/2019 08:20:28 51 0.0 0.0 0.0 -3667 09/21/2019 08:20:53 46 0.0 0.0 0.0 -3669 09/21/2019 08:21:18 48 0.0 0.0 0.0 -3668 09/21/2019 08:21:43 43 0.0 0.0 0.0 -3667 09/21/2019 08:22:08 42 0.0 0.0 0.0 -3669 09/21/2019 08:22:33 41 0.0 0.0 0.0 -3668 09/21/2019 08:22:58 42 0.0 0.0 0.0 -3667 09/21/2019 08:23:23 47 0.0 0.0 0.0 -3668 09/21/2019 08:23:48 51 0.0 0.0 0.0 -3673 09/21/2019 08:24:13 51 0.0 0.0 0.0 -3668 09/21/2019 08:24:38 51 0.0 0.0 0.0 -3668 09/21/2019 08:25:03 48 0.0 0.0 0.0 -3669 09/21/2019 08:25:28 48 0.0 0.0 0.0 -3668 09/21/2019 08:25:53 49 0.0 0.0 0.0 -3669 09/21/2019 08:26:18 40 0.0 0.0 0.0 -3667 09/21/2019 08:26:43 42 0.0 0.0 0.0 -3671 09/21/2019 08:27:08 42 0.0 0.0 0.0 -3669 09/21/2019 08:27:33 39 0.0 0.0 0.0 -3667 09/21/2019 08:27:58 36 0.0 0.0 0.0 -3669 09/21/2019 08:28:23 37 0.0 0.0 0.0 -3669 09/21/2019 08:28:48 34 0.0 0.0 0.0 -3669 09/21/2019 08:28:55 37 0.0 0.0 0.0 -3668 priming unIt 09/21/2019 08:29:13 73 0.0 0.0 0.0 -3669 09/21/2019 08:29:38 167 0.0 0.0 0.0 -3669 09/21/2019 08:30:03 151 0.0 0.0 0.0 -3669 09/21/2019 08:30:28 127 0.0 0.0 0.0 -3666 09/21/2019 08:30:53 187 0.0 0.0 0.0 -3671 09/21/2019 08:31:18 144 0.0 0.0 0.0 -3672 09/21/2019 08:31:43 70 0.0 0.0 0.0 -3670 09/21/2019 08:32:08 73 0.0 0.0 0.0 -3671 09/21/2019 08:32:33 86 0.0 0.0 0.0 -3669 09/21/2019 08:32:58 148 0.0 0.0 0.0 -3668 09/21/2019 08:33:23 65 0.0 0.0 0.0 -3667 09/21/2019 08:33:48 55 0.0 0.0 0.0 -3669 09/21/2019 08:34:13 51 0.0 0.0 0.0 -3668 09/21/2019 08:34:38 51 0.0 0.0 0.0 -3666 09/21/2019 08:35:03 53 0.0 0.0 0.0 -3668 09/21/2019 08:35:28 55 0.0 0.0 0.0 -3672 09/21/2019 08:35:53 59 0.0 0.0 0.0 -3669 09/21/2019 08:36:18 56 0.0 0.0 0.0 -3668 09/21/2019 08:36:43 54 0.0 0.0 0.0 -3668 09/21/2019 08:37:08 53 0.0 0.0 0.0 -3668 09/21/2019 08:37:33 52 0.0 0.0 0.0 -3669 09/21/2019 08:37:58 45 0.0 0.0 0.0 -3669 09/21/2019 08:38:23 47 0.0 0.0 0.0 -3669 09/21/2019 08:38:48 45 0.0 0.0 0.0 -3668 09/21/2019 08:39:13 43 0.0 0.0 0.0 -3668 09/21/2019 08:39:38 43 0.0 0.0 0.0 -3668 Paye 3 of 24 Well CD5-92 Field Apline Job Start Sep/21/2019 Customer ConocoPhillips Job Number 84027 Date Time .hr clock PRESS PSI DENS LB/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 08:40:28 49 0.0 0.0 0.0 -3670 09/21/2019 08:40:53 50 0.0 0.0 0.0 -3669 09/21/2019 08:41:43 52 0.0 0.0 0.0 -3667 09/21/2019 08:42:08 51 0.0 0.0 0.0 -3667 09/21/2019 08:42:33 51 0.0 0.0 0.0 -3669 09/21/2019 .08:42:58 41 0.0 0.0 0.0 -3668 09/21/2019 08:43:23 44 0.0 0.0 0.0 -3671 09/21/2019 08:43:48 130 0.0 0.0 0.0 -3667 09/21/2019 08:44:13 72 0.0 0.0 0.0 -3667 09/21/2019 08:44:38 97 0.0 0.0 0.0 -3669 09/21/2019 08:45:03 67 0.0 0.0 0.0 -3669 09/21/2019 08:45:28 63 0.0 0.0 0.0 -3670 09/21/2019 08:45:53 60 0.0 0.0 0.0 -3672 09/21/2019 08:46:18 59 0.0 0.0 0.0 -3668 09/21/2019 08:46:43 57 0.0 0.0 0.2 -3671 09/21/2019 08:47:08 56 0.0 0.0 0.7 -3667 09/21/2019 08:47:33 45 0.0 0.0 0.7 -3667 09/21/2019 08:47:58 50 0.0 0.0 0.8 -3667 09/21/2019 08:48:23 45 0.0 0.0 1.2 -3669 09/21/2019 08:48:48 49 0.0 0.0 1.6 -3668 09/21/2019 08:49:13 48 0.0 0.0 1.6 -3670 09/21/2019 08:49:38 53 0.0 0.0 1.6 -3670 09/21/2019 08:50:03 47 0.0 0.0 1.9 -3670 09/21/2019 08:50:28 55 0.0 0.0 2.3 -3670 09/21/2019 08:50:53 57 0.0 0.0 2.6 -3667 09/21/2019 08:51:18 60 0.0 0.0 2.6 -3668 09/21/2019 08:51:43 77 0.0 0.0 2.6 -3669 09/21/2019 08:52:08 76 0.0 0.0 2.6 -3668 09/21/2019 08:52:33 59 0.0 0.0 2.6 -3673 09/21/2019 08:52:58 57 0.0 0.0 2.8 -3667 09/21/2019 08:53:23 58 0.0 0.0 3.2 -3669 09/21/2019 08:53:48 45 0.0 0.0 3.5 -3669 09/21/2019 08:54:13 50 0.0 0.0 3.5 -3668 09/21/2019 08:54:38 50 0.0 0.0 3.6 -3669 09/21/2019 08:55:03 49 0.0 0.0 4.0 -3669 09/21/2019 08:55:28 49 0.0 0.0 4.5 -3669 09/21/2019 08:55:53 49 0.0 0.0 4.5 -3667 09/21/2019 08:56:18 41 0.0 0.0 4.5 -3669 09/21/2019 08:56:43 38 0.0 0.0 4.5 -3669 09/21/2019 08:57:08 43 0.0 0.0 4.5 -3667 09/21/2019 08:57:33 40 0.0 0.0 4.5 -3667 09/21/2019 08:57:58 38 0.0 0.0 4.5 -3668 09/21/2019 08:58:23 37 0.0 0.0 4.5 -3670 09/21/2019 08:58:48 36 0.0 0.0 4.5 -3669 09/21/2019 08:59:13 37 0.0 0.0 4.5 -3672 09/21/2019 08:59:38 37 0.0 0.0 4.5 -3671 09/21/2019 09:00:03 34 0.0 0.0 4.5 -3669 09/21/2019 09:00:28 37 0.0 0.0 4.5 -3668 09/21/2019 09:00:53 41 0.0 0.0 4.5 -3668 09/21/2019 09:01:18 36 0.0 0.0 4.5 -3670 09/21/2019 09:01:43 37 0.0 0.0 4.5 -3669 09/21/2019 09:02:08 34 0.0 0.0 4.5 -3669 09/21/2019 09:02:33 34 0.0 0.0 4.5 -3669 09/21/2019 09:02:58 37 0.0 0.0 4.5 -3666 Page 4 of 24 Well CD5-92 Field Apline Job Start Sep/21/2019 Customer Conoco Phillips Job Number 84027 Data Time 24 -hr clock PRESS PSI DENS LB/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 09:03:48 37 0.0 0.0 4.5 -3669 09/21/2019 09:04:13 35 0.0 0.0 4.5 -3670 09/21/2019 09:04:38 36 0.0 0.0 4.5 -3666 09/21/2019 09:05:03 42 0.0 0.0 4.5 -3670 09/21/2019 09:05:28 35 0.0 0.0 4.5 -3668 09/21/2019 09:05:53 34 0.0 0.0 4.5 -3670 09/21/2019 09:06:18 39 0.0 0.0 4.5 -3670 09/21/2019 09:06:43 34 0.0 0.0 4.5 -3667 09/21/2019 09:07:08 33 0.0 0.0 4.5 -3667 09/21/2019 09:07:33 33 0.0 0.0 4.5 -3670 09/21/2019 09:07:58 35 0.0 0.0 4.5 -3669 09/21/2019 09:08:23 32 0.0 0.0 4.5 -3669 09/21/2019 09:08:48 34 0.0 0.0 4.5 -3668 09/21/2019 09:09:13 35 0.0 0.0 4.5 -3666 09/21/2019 09:09:38 32 0.0 0.0 4.5 -3670 09/21/2019 09:10:03 37 0.0 0.0 4.5 -3669 09/21/2019 09:10:28 34 0.0 0.0 4.5 -3667 09/21/2019 09:10:53 33 0.0 0.0 4.5 -3667 09/21/2019 09:11:18 33 0.0 0.0 4.5 -3668 09/21/2019 09:11:43 34 0.0 0.0 4.5 -3671 09/21/2019 09:12:08 33 0.0 0.0 4.5 -3666 09/21/2019 09:12:33 31 0.0 0.0 4.5 -3667 09/21/2019 09:12:58 33 0.0 0.0 4.5 -3671 09/21/2019 09:13:23 31 0.0 0.0 4.5 -3668 09/21/2019 09:13:48 31 0.0 0.0 4.5 -3670 09/21/2019 09:14:13 32 0.0 0.0 4.5 -3669 09/21/2019 09:14:38 32 0.0 0.0 4.5 -3670 09/21/2019 09:15:03 34 0.0 0.0 4.5 -3670 09/21/2019 09:15:28 32 0.0 0.0 4.5 -3669 09/21/2019 09:15:53 34 0.0. 0.0 4.5 -3670 09/21/2019 09:16:18 33 0.0 0.0 4.5 -3668 09/21/2019 09:16:43 30 0.0 0.0 4.5 -3668 09/21/2019 09:17:08 31 0.0 0.0 4.5 -3671 09/21/2019 09:17:33 31 0.0 0.0 4.5 -3669 09/21/2019 09:17:58 30 0.0 0.0 4.5 -3668 09/21/2019 09:18:23 31 0.0 0.0 4.5 -3669 09/21/2019 09:18:48 29 0.0 0.0 4.5 -3670 09/21/2019 09:19:13 29 0.0 0.0 4.5 -3669 09/21/2019 09:19:38 27 0.0 0.0 4.5 -3669 09/21/2019 09:20:03 25 0.0 0.0 4.5 -3669 09/21/2019 09:20:28 27 0.0 0.0 4.5 -3667 09/21/2019 09:20:53 24 0.0 0.0 4.5 -3670 09/21/2019 09:21:18 25 0.0 0.0 4.5 -3667 09/21/2019 09:21:43 23 0.0 0.0 4.5 -3667 09/21/2019 09:22:08 26 0.0 0.0 4.5 -3669 09/21/2019 09:22:33 24 0.0 0.0 4.5 -3667 09/21/2019 09:22:58 26 0.0 0.0 4.5 -3671 09/21/2019 09:23:23 28 0.0 0.0 4.5 -3669 09/21/2019 09:23:48 29 0.0 0.0 4.5 -3667 09/21/2019 09:24:13 37 0.0 0.0 4.5 45 09/21/2019 09:24:38 40 0.0 0.0 4.5 48 09/21/2019 09:25:03 37 0.0 0.0 4.5 46 09/21/2019 09:25:28 35 0.0 0.0 4.5 46 09/21/2019 09:25:53 36 0.0 0.0 4.5 47 Page 5 of 24 C Well CD5-92 Field Apline ]ob Start Sep/21/2019 Customer ConocoPhillips Job Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 09:26:43 43 0.0 0.0 4.5 241 09/21/2019 09:27:08 41 0.0 0.0 4.5 317 09/21/2019 09:27:33 38 0.0 0.0 4.5 353 09/21/2019 09:27:58 58 0.0 0.0 4.5 411 09/21/2019 09:28:23 55 0.0 0.0 4.5 434 09/21/2019 09:28:48 58 0.0 0.0 4.5 452 09/21/2019 09:29:13 59 0.0 0.0 4.5 492 09/21/2019 09:29:38 57 0.0 0.0 4.5 500 09/21/2019 09:30:03 59 0.0 0.0 4.5 475 09/21/2019 09:30:28 55 0.0 0.0 4.5 507 09/21/2019 09:30:53 60 0.0 0.0 4.5 500 09/21/2019 09:31:18 61 0.0 0.0 4.5 543 09/21/2019 09:31:43 45 0.0 0.0 4.5 570 09/21/2019 09:32:08 48 0.0 0.0 4.5 584 09/21/2019 09:32:33 47 0.0 0.0 4.5 541 09/21/2019 09:32:58 45 0.0 0.0 4.5 582 09/21/2019 09:33:23 62 0.0 0.0 4.5 540 09/21/2019 09:33:48 64 0.0 0.0 4.5 565 09/21/2019 09:34:13 64 0.0 0.0 4.5 602 09/21/2019 09:34:38 65 0.0 0.0 4.5 606 09/21/2019 09:35:03 65 0.0 0.0 4.5 602 09/21/2019 09:35:28 67 0.0 0.0 4.5 605 09/21/2019 09:35:53 66 0.0 0.0 4.5 611 09/21/2019 09:36:18 45 0.0 0.0 4.5 615 09/21/2019 09:36:43 46 0.0 0.0 4.5 621 09/21/2019 09:37:08 44 0.0 0.0 4.5 637 09/21/2019 09:37:33 47 0.0 0.0 4.5 633 09/21/2019 09:37:58 46 0.0 0.0 4.5 637 09/21/2019 09:38:23 67 0.0 0.0 4.5 613 09/21/2019 09:38:48 65 0.0 0.0 4.5 613 09/21/2019 09:39:13 67 0.0 0.0 4.5 603 09/21/2019 09:39:38 65 0.0 0.0 4.5 605 09/21/2019 09:40:03 65 0.0 0.0 4.5 612 09/21/2019 09:40:28 67 0.0 0.0 4.5 602 09/21/2019 09:40:53 65 0.0 0.0 4.5 617 09/21/2019 09:41:18 46 0.0 0.0 4.5 618 09/21/2019 09:41:43 47 0.0 0.0 4.5 623 09/21/2019 09:42:08 44 0.0 0.0 4.5 643 09/21/2019 09:42:33 49 0.0 0.0 4.5 624 09/21/2019 09:42:58 62 0.0 0.0 4.5 611 09/21/2019 09:43:23 65 0.0 0.0 4.5 622 09/21/2019 09:43:48 66 0.0 0.0 4.5 609 09/21/2019 09:44:13 63 0.0 0.0 4.5 617 09/21/2019 09:44:38 65 0.0 0.0 4.5 587 09/21/2019 09:45:03 66 0.0 0.0 4.5. 601 09/21/2019 09:45:28 63 0.0 0.0 4.5 620 09/21/2019 09:45:53 48 0.0 0.0 4.5 608 09/21/2019 09:46:18 47 0.0 0.0 4.5 623 09/21/2019 09:46:43 47 0.0 0.0 4.5 614 09/21/2019 09:47:08 47 0.0 0.0 4.5 623 09/21/2019 09:47:33 63 0.0 0.0 4.5 627 09/21/2019 09:47:58 66 0.0 0.0 4.5 568 09/21/2019 09:48:23 65 0.0 0.0 4.5 579 09/21/2019 09:48:48 69 0.0 0.0 4.5 589 Page 6 of 24 Well CD5-92 Field Apline lob Start Sep/21/2019 Customer Conoco Phillips Iob Number 84027 Date Time 24 -hr dock PRESS PSI DENS t.B/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 09:49:38 65 0.0 0.0 4.5 589 09/21/2019 09:50:03 67 0.0 0.0 4.5 562 09/21/2019 09:50:28 49 0.0 0.0 4.5 593 09/21/2019 09:50:53 46 0.0 0.0 4.5 615 09/21/2019 09:51:18 47 0.0 0.0 4.5 584 09/21/2019 09:51:43 44 0.0 0.0 4.5 599 09/21/2019 09:52:08 64 0.0 0.0 4.5 603 09/21/2019 09:52:33 66 0.0 0.0 4.5 581 09/21/2019 09:52:58 62 0.0 0.0 4.5 584 09/21/2019 09:53:23 63 0.0 0.0 4.5 567 09/21/2019 09:53:48 66 0.0 0.0 4.5 577 09/21/2019 09:54:13 65 0.0 0.0 4.5 583 09/21/2019 09:54:38 65 0.0 0.0 4.5 559 09/21/2019 09:55:03 45 0.0 0.0 4.5 588 09/21/2019 09:55:28 46 0.0 0.0 4.5 586 09/21/2019 09:55:53 45 0.0 0.0 4.5 601 09/21/2019 09:56:18 47 0.0 0.0 4.5 604 09/21/2019 09:56:43 39 0.0 0.0 4.5 579 09/21/2019 09:57:08 51 0.0 0.0 4.5 599 09/21/2019 09:57:33 51 0.0 0.0 4.5 599 09/21/2019 09:57:58 49 0.0 0.0 4.5 582 09/21/2019 09:58:23 58 0.0 0.0 4.5 588 09/21/2019 09:58:48 61 0.0 0.0 4.5 577 09/21/2019 09:59:13 63 0.0 0.0 4.5 588 09/21/2019 09:59:38 64 0.0 0.0 4.5 573 09/21/2019 10:00:03 69 0.0 0.0 4.5 559 09/21/2019 10:00:28 68 0.0 0.0 4.5 575 09/21/2019 10:00:53 65 0.0 0.0 4.5 574 09/21/2019 10:01:18 65 0.0 0.0 4.5 572 09/21/2019 10:01:43 64 0.0 0.0 4.5 567 09/21/2019 10:02:08 64 0.0 0.0 4.5 558 09/21/2019 10:02:33 45 0.0 0.0 4.5 584 09/21/2019 10:02:58 44 0.0 0.0 4.5 588 09/21/2019 10:03:23 50 0.0 0.0 4.5 585 09/21/2019 10:03:48 50 0.0 0.0 4.5 602 09/21/2019 10:04:13 61 0.0 0.0 4.5 572 09/21/2019 10:04:38 67 0.0 0.0 4.5 572 09/21/2019 10:05:03 65 0.0 0.0 4.5 561 09/21/2019 10:05:28 67 0.0 0.0 4.5 551 09/21/2019 10:05:53 67 0.0 0.0 4.5 561 09/21/2019 10:06:18 68 0.0 0.0 4.5 561 09/21/2019 10:06:43 66 0.0 0.0 4.5 554 09/21/2019 10:07:08 43 0.0 0.0 4.5 576 09/21/2019 10:07:33 45 0.0 0.0 4.5 577 09/21/2019 10:07:58 45 0.0 0.0 4.5 585 09/21/2019 10:08:23 47 0.0 0.0 4.5 580 09/21/2019 10:08:48 59 0.0 0.0 4.5 570 09/21/2019 10:09:13 63 0.0 0.0 4.5 565 09/21/2019 10:09:38 65 0.0 0.0 4.5 558 09/21/2019 10:10:03 67 0.0 0.0 4.5 552 09/21/2019 10:10:28 64 0.0 0.0 4.5 550 09/21/2019 10:10:53 66 0.0 0.0 4.5 549 09/21/2019 10:11:18 80 0.0 0.0 4.5 549 09/21/2019 10:11:43 42 0.0 0.0 4.5 567 Page 7 of 24 Well CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhillips lob Number 84027 Date Time 24-hr dodo PRESS PSI DENS LB/6 RATE B/M Volume BBL WHP PSI Message 09/21/2019 10:12:33 44 0.0 0.0 4.5 578 09/21/2019 10:12:58 44 0.0 0.0 4.5 577 09/21/2019 10:13:23 57 0.0 0.0 4.5 563 09/21/2019 10:13:48 41 0.0 0.0 4.5 580 09/21/2019 10:14:13 41 0.0 0.0 4.5 561 09/21/2019 10:14:38 38 0.0 0.0 4.5 135 09/21/2019 10:15:03 33 0.0 0.0 4.5 97 09/21/2019 10:15:28 38 0.0 0.0 4.5 54 09/21/2019 10:15:53 34 0.0 0.0 4.5 54 09/21/2019 10:16:03 67 0.0 0.0 4.5 56 Reset Total, Vol = 4.54 bbl 09/21/2019 10:16:18 82 0.0 0.0 0.0 54 09/21/2019 10:16:27 83 0.0 0.0 0.0 54 water ahead 09/21/2019 10:16:43 86 0.0 0.0 0.0 55 09/21/2019 10:17:08 44 0.0 0.0 0.0 55 09/21/2019 10:17:33 111 0.0 0.0 0.0 68 09/21/2019 10:17:58 286 0.0 0.0 0.9 217 09/21/2019 10:18:23 342 0.0 0.0 1.9 271 09/21/2019 10:18:48 180 0.0 0.0 2.2 165 09/21/2019 10:19:13 172 0.0 0.0 2.2 166 09/21/2019 10:19:38 578 0.0 0.0 2.2 566 09/21/2019 10:20:03 556 0.0 0.0 2.2 548 09/21/2019 10:20:28 549 0.0 0.0 2.2 544 09/21/2019 10:20:53 3347 0.0 0.0 2.3 3343 09/21/2019 10:21:14 4071 0.0 0.0 2.3 4057 High PT 09/21/2019 10:21:18 4068 0.0 0.0 2.3 4054 09/21/2019 10:21:43 4061 0.0 0.0 2.3 4047 09/21/2019 10:22:08 4058 0.0 0.0 2.3 4043 09/21/2019 10:22:33 4057 0.0 0.0 2.3 4042 09/21/2019 10:22:58 4055 0.0 0.0 2.3 4041 09/21/2019 10:23:06 4055 0.0 0.0 2.3 4040 Bleed Off Pressure 09/21/2019 10:23:23 2547 0.0 0.0 2.3 2513 09/21/2019 10:23:48 67 0.0 0.0 2.3 66 09/21/2019 10:24:13 64 0.0 0.0 2.3 69 09/21/2019 10:24:38 52 0.0 0.0 2.3 69 09/21/2019 10:25:03 100 0.0 0.0 2.3 118 09/21/2019 10:25:28 100 0.0 0.0 2.3 118 09/21/2019 10:25:53 96 0.0 0.0 2.3 120 09/21/2019 10:26:15 97 0.0 0.0 2.3 118 batch up mudpush 09/21/2019 10:26:18 95 0.0 0.0 2.3 115 09/21/2019 10:26:43 93 0.0 0.0 2.3 117 09/21/2019 10:27:08 90 0.0 0.0 2.3 117 09/21/2019 10:27:33 90 0.0 0.0 2.3 119 09/21/2019 10:27:58 89 0.0 0.0 2.3 118 09/21/2019 10:28:23 87 0.0 0.0 2.3 116 09/21/2019 10:28:40 89 0.0 0.0 2.3 118 Reset Total, Vol = 2.28 bbl 09/21/2019 10:28:48 88 0.0 0.0 2.3 118 09/21/2019 10:29:13 125 0.0 0.0 2.3 137 09/21/2019 10:29:15 127 0.0 0.0 2.3 137 start pumping mudpush 09/21/2019 10:29:38 372 0.0 0.0 3.0 280 09/21/2019 10:29:50 473 0.0 0.0 3.6 331 returns to pits 09/21/2019 10:30:03 624 0.0 0.0 4.4 377 09/21/2019 10:30:28 471 0.0 0.0 6.0 308 09/21/2019 10:30:53 462 0.0 0.0 7.3 304 09/21/2019 10:31:18 453 0.0 0.0 8.7 299 Page 8 of 24 Well CDS-92 Fleld Apline lob Start Sep/21/2019 Customer Conoco Phillips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/G BATE 8/M Volume 881. WNP Message PSI 09/21/2019 10:32:08 457 0.0 0.0 11.4 294 09/21/2019 10:32:33 435 0.0 0.0 12.7 281 09/21/2019 10:32:58 429 0.0 0.0 14.0 279 09/21/2019 10:33:23 436 0.0 0.0 15.3 276 09/21/2019 10:33:48 413 0.0 0.0 16.7 274 09/21/2019 10:34:13 423 0.0 0.0 18.0 286 09/21/2019 10:34:38 432 0.0 0.0 19.3 285 09/21/2019 10:35:03 416 0.0 0.0 20.6 274 09/21/2019 10:35:28 409 0.0 0.0 21.9 261 09/21/2019 10:35:53 405 0.0 0.0 23.3 254 09/21/2019 10:36:18 417 0.0 0.0 24.6 252 09/21/2019 10:36:43 404 0.0 0.0 26.0 246 09/21/2019 10:37:08 397 0.0 0.0 27.3 245 09/21/2019 10:37:33 456 0.0 0.0 28.8 260 09/21/2019 10:37:58 447 0.0 0.0 30.3 248 09/21/2019 10:38:23 440 0.0 0.0 31.9 254 09/21/2019 10:38:48 446 0.0 0.0 33.4 252 09/21/2019 10:39:13 447 0.0 0.0 35.0 253 09/21/2019 10:39:38 435 0.0 0.0 36.6 250 09/21/2019 10:40:03 432 0.0 0.0 38.1 242 09/21/2019 10:40:28 428 0.0 0.0 39.7 221 09/21/2019 10:40:53 411 0.0 0.0 41.3 214 09/21/2019 10:41:18 419 0.0 0.0 42.8 211 09/21/2019 10:41:43 396 0.0 0.0 44.3 202 09/21/2019 10:42:08 393 0.0 0.0 45.8 199 09/21/2019 10:42:33 345 0.0 0.0 47.2 183 09/21/2019 10:42:58 342 0.0 0.0 48.5 184 09/21/2019 10:43:23 335 0.0 0.0 49.9 193 09/21/2019 10:43:48 342 0.0 0.0 51.2 193 09/21/2019 10:44:13 328 0.0 0.0 52.5 182 09/21/2019 10:44:38 322 0.0 0.0 53.9 173 09/21/2019 10:45:03 271 0.0 0.0 55.1 138 09/21/2019 10:45:28 273 0.0 0.0 56.3 140 09/21/2019 10:45:53 240 0.0 0.0 57.4 127 09/21/2019 10:46:18 233 0.0 0.0 58.5 128 09/21/2019 10:46:43 242 0.0 0.0 59.6 123 09/21/2019 10:47:08 243 0.0 0.0 60.6 141 09/21/2019 10:47:33 265 0.0 0.0 61.7 153 09/21/2019 10:47:58 82 0.0 0.0 62.4 68 09/21/2019 10:48:23 92 0.0 0.0 62.4 65 09/21/2019 10:48:48 80 0.0 0.0 62.4 63 09/21/2019 10:49:13 84 0.0 0.0 62.4 64 09/21/2019 10:49:38 89 0.0 0.0 62.4 64 09/21/2019 10:50:03 94 0.0 0.0 62.4 65 09/21/2019 10:50:28 92 0.0 0.0 62.4 68 09/21/2019 10:50:53 91 0.0 0.0 62.4 65 09/21/2019 10:51:18 93 0.0 0.0 62.4 66 09/21/2019 10:51:43 103 0.0 0.0 62.4 65 09/21/2019 10:52:08 91 0.0 0.0 62.4 64 09/21/2019 10:52:33 92 0.0 0.0 62.4 65 09/21/2019 10:52:58 93 0.0 0.0 62.4 66 09/21/2019 10:53:08 93 0.0 0.0 62.4 64 cement wet 09/21/2019 10:53:23 92 0.0 0.0 62.4 63 09/21/2019 10:53:48 94 0.0 0.0 62.4 66 Page 9 of 24 Well CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhlllips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/6 RATE B/M Volume BEL WHP Message PSI 09/21/2019 10:54:38 107 0.0 0.0 62.4 65 09/21/2019 10:55:03 96 0.0 0.0 62.4 67 09/21/2019 10:55:28 94 0.0 j 0.0 62.4 64 09/21/2019 10:55:53 93 0.0 0.0 62.4 65 09/21/2019 10:56:18 93 0.0 0.0 62.4 65 09/21/2019 10:56:43 95 0.0 0.0 62.4 66 09/21/2019 10:57:08 96 0.0 0.0 62.4 66 09/21/2019 10:57:33 98 0.0 0.0 62.4 66 09/21/2019 10:57:58 98 0.0 0.0 62.4 64 09/21/2019 10:58:23 92 0.0 j 0.0 62.4 62 09/21/2019 10:58:48 95 0.0 0.0 62.4 67 09/21/2019 10:59:13 93 0.0 0.0 62.4 64 09/21/2019 10:59:38 92 0.0 0.0 62.4 66 09/21/2019 11:00:03 93 0.0 0.0 62.4 65 09/21/2019 11:00:28 98 0.0 0.0 62.4 65 09/21/2019 11:00:53 96 0.0 0.0 62.4 64 09/21/2019 11:01:18 94 0.0 j 0.0 62.4 67 09/21/2019 11:01:43 97 0.0 0.0 62.4 64 09/21/2019 11:02:08 98 0.0 0.0 62.4 65 09/21/2019 11:02:33 97 0.0 0.0 62.4 64 09/21/2019 11:02:58 93 0.0 0.0 62.4 63 09/21/2019 11:03:18 95 0.0 1 0.0 62.4 65 Issues on rlg floor 09/21/2019 11:03:23 94 0.0 0.0 62.4 67 09/21/2019 11:03:48 93 0.0 0.0 62.4 66 09/21/2019 11:04:13 95 0.0 0.0 62.4 68 09/21/2019 11:04:38 93 0.0 0.0 62.4 64 09/21/2019 11:05:03 94 0.0 0.0 62.4 67 09/21/2019 11:05:28 97 0.0 0.0 62.4 64 09/21/2019 11:05:53 93 0.0 0.0 62.4 68 09/21/2019 11:06:18 94 0.0 0.0 62.4 63 09/21/2019 11:06:43 95 0.0 0.0 62.4 65 09/21/2019 11:07:08 94 0.0 0.0 62.4 68 09/21/2019 11:07:33- 98 0.0 0.0 62.4 66 09/21/2019 11:07:58 92 0.0 0.0 62.4 67 09/21/2019 11:08:23 95 0.0 0.0 62.4 64 09/21/2019 11:08:48 94 0.0 0.0 62.4 65 09/21/2019 11:09:13 96 0.0 0.0 62.4 65 09/21/2019 11:09:38 98 0.0 0.0 62.4 65 09/21/2019 11:10:03 93 0.0 0.0 62.4 65 09/21/2019 11:10:28 98 0.0 0.0 62.4 64 09/21/2019 11:10:53 95 0.0 0.0 62.4 64 09/21/2019 11:11:18 97 0.0 0.0 62.4 64 09/21/2019 11:11:43 99 0.0 0.0 62.4 65 09/21/2019 11:12:08 96 0.0 0.0 62.4 64 09/21/2019 11:12:33 96 0.0 0.0 62.4 64 09/21/2019 11:12:58 117 0.0 0.0 62.4 63 09/21/2019 11:13:23 94 0.0 0.0 62.4 65 09/21/2019 11:13:48 94 0.0 0.0 62.4 62 09/21/2019 11:14:13 101 0.0 0.0 62.4 64 09/21/2019 11:14:38 108 0.0 0.0 62.4 64 09/21/2019 11:15:03 102 0.0 0.0 62.4 65 09/21/2019 11:15:28 103 0.0 0.0 62.4 65 09/21/2019 11:15:53 106 0.0 0.0 62.4 64 09/21/2019 11:16:18 92 0.0 0.0 62.4 65 Page 10 of 24 Well CD5-92 Field Apline ]ob Start Sep/21/2019 Customer Conoco Phillips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/G RATE B/M Volume BBL WHP PSI Message 09/21/2019 11:17:08 93 0.0 0.0 62.4 66 09/21/2019 11:17:33 90 0.0 0.0 62.4 64 09/21/2019 11:17:58 92 0.0 0.0 62.4 64 09/21/2019 11:18:23 97 0.0 0.0 62.4 65 09/21/2019 11:18:48 178 0.0 0.0 62.4 66 09/21/2019 11:19:13 372 0.0 0.0 63.4 94 09/21/2019 11:19:27 286 0.0 0.0 64.1 84 cement going downhole, 15.8 sole 09/21/2019 11:19:38 314 0.0 0.0 64.6 101 09/21/2019 11:20:03 309 0.0 0.0 65.8 114 09/21/2019 11:20:16 318 0.0 1 0.0 66.4 123 Reset Total, Vol = 60.2 bbl 09/21/2019 11:20:28 326 0.0 0.0 66.9 130 09/21/2019 11:20:38 544 0.0 0.0 67.4 195 returns to floor 09/21/2019 11:20:53 595 0.0 0.0 68.4 243 4 bbl ant pumped before stagr reset 09/21/2019 11:21:18 434 0.0 0.0 70.1 231 09/21/2019 11:21:43 460 0.0 0.0 71.7 220 09/21/2019 11:22:08 233 0.0 0.0 73.2 122 09/21/2019 11:22:33 384 0.0 0.0 74.5 156 09/21/2019 11:22:58 336 0.0 0.0 75.8 113 09/21/2019 11:23:23 255 0.0 0.0 77.1 135 09/21/2019 11:23:48 434 0.0 0.0 78.4 140 09/21/2019 11:24:13 414 0.0 0.0 79.7 132 09/21/2019 11:24:38 308 0.0 0.0 81.0 108 09/21/2019 11:25:03 211 0.0 0.0 82.3 111 09/21/2019 11:25:28 199 0.0 0.0 83.7 96 09/21/2019 11:25:53 357 0.0 0.0 85.1 111 09/21/2019 11:26:18 198 0.0 0.0 86.1 91 09/21/2019 11:26:43 265 0.0 0.0 87.2 90 09/21/2019 11:27:08 220 0.0 0.0 88.2 82 09/21/2019 11:27:33 386 0.0 0.0 89.3 120 09/21/2019 11:27:58 177 0.0 0.0 90.3 82 09/21/2019 11:28:23 305 0.0 0.0 91.4 110 09/21/2019 11:28:48 299 0.0 0.0 92.5 107 09/21/2019 11:29:13 521 0.0 0.0 94.1 158 09/21/2019 11:29:38 505 0.0 0.0 95.7 159 09/21/2019 11:30:03 505 0.0 0.0 97.4 156 09/21/2019 11:30:28 496 0.0 0.0 99.0 153 09/21/2019 11:30:53 498 0.0 0.0 100.7 147 09/21/2019 11:31:18 510 0.0 0.0 102.3 146 09/21/2019 11:31:43 515 0.0 0.0 104.0 149 09/21/2019 11:32:08 518 0.0 0.0 105.6 148 09/21/2019 11:32:33 509 0.0 0.0 107.3 148 09/21/2019 11:32:58 513 0.0 0.0 109.0 155 09/21/2019 11:33:23 512 0.0 0.0 110.6 153 09/21/2019 11:33:48 516 0.0 0.0 112.3 155 09/21/2019 11:34:13 505 0.0 0.0 113.9 157 09/21/2019 11:34:38 499 0.0 0.0 115.6 151 09/21/2019 11:35:03 495 0.0 0.0 117.2 150 09/21/2019 11:35:28 488 0.0 0.0 118.9 145 09/21/2019 11:35:53 509 0.0 0.0 120.5 148 09/21/2019 11:36:18 512 0.0 0.0 122.2 146 09/21/2019 11:36:43 516 0.0 0.0 123.8 145 09/21/2019 11:37:08 517 0.0 0.0 125.5 153 09/21/2019 11:37:33 515 0.0 0.0 127.1 153 09/21/2019 11:37:58 518 0.0 0.0 128.8 153 Page 11 of 24 Well CD5-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhillips ]ob Number 84027 Date nme 24 -hr dock PRESS PSI DENS W/O RATE S/M Volume ML WNP PSI Message 09/21/2019 11:38:48 501 0.0 0.0 132.1 153 09/21/2019 11:39:13 721 0.0 0.0 133.9 183 09/21/2019 11:39:38 491 0.0 j 0.0 135.7 150 09/21/2019 11:40:03 489 0.0 0.0 137.3 146 09/21/2019 11:40:28 507 0.0 0.0 139.1 145 09/21/2019 11:40:53 501 0.0 0.0 141.1 145 09/21/2019 11:41:18 507 0.0 0.0 142.7 151 09/21/2019 11:41:43 505 0.0 0.0 144.4 149 09/21/2019 11:42:08 509 0.0 0.0 146.0 153 09/21/2019 11:42:33 501 0.0 0.0 147.7 152 09/21/2019 11:42:58 503 0.0 0.0 149.4 150 09/21/2019 11:43:23 505 0.0 0.0 151.0 152 09/21/2019 11:43:48 499 0.0 0.0 152.7 154 09/21/2019 11:44:13 502 0.0 0.0 154.3 153 09/21/2019 11:44:38 491 0.0 0.0 156.0 150 09/21/2019 11:45:03 488 0.0 0.0 157.6 143 09/21/2019 11:45:28 503 0.0 0.0 159.3 145 09/21/2019 11:4S:53 509 0.0 0.0 160.9 151 09/21/2019 11:46:18 509 0.0 0.0 162.6 149 09/21/2019 11:46:43 507 0.0 0.0 164.2 149 09/21/2019 11:47:08 509 0.0 0.0 165.9 150 09/21/2019 11:47:33 512 0.0 0.0 167.5 151 09/21/2019 11:47:58 513 0.0 0.0 169.2 155 09/21/2019 11:48:23 497 0.0 0.0 170.8 153 09/21/2019 11:48:48 495 0.0 0.0 172.5 153 09/21/2019 11:49:13 489 0.0 0.0 174.2 150 09/21/2019 11:49:38 489 0.0 0.0 175.8 149 09/21/2019 11:50:03 499 0.0 0.0 177.5 146 09/21/2019 11:50:28 501 0.0 0.0 179.1 145 09/21/2019 11:50:53 501 0.0 0.0 180.8 148 09/21/2019 11:51:18 505 0.0 0.0 182.4 152 09/21/2019 11:51:43 510 0.0 0.0 184.1 154 09/21/2019 11:52:08 506 0.0 0.0 185.7 147 09/21/2019 11:52:33 233 0.0 0.0 187.3 90 09/21/2019 11:52:58 86 0.0 0.0 187.4 63 09/21/2019 11:53:23 64 0.0 0.0 187.4 65 09/21/2019 11:53:34 56 0.0 0.0 187.4 66 Reset Total, Vol @ 125.0 bbl 09/21/2019 11:53:45 56 0.0 0.0 187.4 63 dropping plug 09/21/2019 11:53:48 54 0.0 0.0 187.4 66 09/21/2019 11:54:13 56 0.0 0.0 187.4 64 09/21/2019 11:54:38 63 0.0 0.0 187.4 63 09/21/2019 11:55:03 69 0.0 0.0 187.4 62 09/21/2019 11:55:28 60 0.0 0.0 187.4 62 09/21/2019 11:55:53 56 0.0 0.0 187.4 61 09/21/2019 11:56:18 55 0.0 0.0 187.4 64 09/21/2019 11:56:43 53 0.0 0.0 187.4 61 09/21/2019 11:56:59 151 0.0 0.0 187.4 62 20 bbl water behind 09/21/2019 11:57:08 344 0.0 0.0 187.7 120 09/21/2019 11:57:27 231 0.0 0.0 188.7 95 Returns at Surface 09/21/2019 11:57:33 156 0.0 0.0 189.0 94 09/21/2019 11:57:58 210 0.0 0.0 190.8 79 09/21/2019 11:58:23 323 0.0 0.0 192.6 108 09/21/2019 11:58:48 326 0.0 0.0 194.6 102 09/21/2019 11:59:13 335 0.0 0.0 196.6 100 Page 12 of 24 Well CD5-92 Fleur Apline lob Start Sep/21/2019 Customer Conoco Phillips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LS/6 RATE B/M Volume BBL WHP PSI Message 09/21/2019 12:00:03 325 0.0 0.0 200.6 102 09/21/2019 12:00:28 315 0.0 0.0 202.6 105 09/21/2019 12:00:53 330 0.0 0.0 204.6 105 09/21/2019 12:01:18 324 0.0 0.0 206.6 98 09/21/2019 12:01:43 51 0.0 0.0 207.6 58 09/21/2019 12:01:44 50 0.0 0.0 207.6 55 Reset Total, Vol = 20.17 bbl 09/21/2019 12:01:56 49 0.0 0.0 207.6 54 Rig Pumps To Displace 09/21/2019 12:01:59 49 0.0 0.0 207.6 55 Reset Total, Vol = 0.00 bbl 09/21/2019 12:02:08 53 0.0 0.0 0.0 51 09/21/2019 12:02:33 55 0.0 0.0 0.0 91 09/21/2019 12:02:58 59 0.0 0.0 0.0 96 09/21/2019 12:03:23 58 0.0 0.0 0.0 99 09/21/2019 12:03:48 61 0.0 0.0 0.0 110 09/21/2019 12:04:13 58 0.0 0.0 0.0 188 09/21/2019 12:04:38 79 0.0 0.0 0.0 245 09/21/2019 12:05:03 67 0.0 0.0 0.0 242 09/21/2019 12:05:28 77 0.0 0.0 0.0 237 09/21/2019 12:05:53 78 0.0 0.0 0.0 246 09/21/2019 12:06:18 77 0.0 0.0 0.0 242 09/21/2019 12:06:43 82 0.0 0.0 0.0 231 09/21/2019 12:07:08 76 0.0 0.0 0.0 232 09/21/2019 12:07:33 81 0.0 0.0 0.0 233 09/21/2019 12:07:58 78 0.0 0.0 0.0 242 09/21/2019 12:08:23 61 0.0 0.0 0.0 241 09/21/2019 12:08:48 63 0.0 0.0 0.0 230 09/21/2019 12:09:13 59 0.0 0.0 0.0 228 09/21/2019 12:09:38 62 0.0 0.0 0.0 234 09/21/2019 12:10:03 78 0.0 0.0 0.0 236 09/21/2019 12:10:28 79 0.0 0.0 0.0 237 09/21/2019 12:10:53 80 0.0 0.0 0.0 233 09/21/2019 12:11:18 77 0.0 0.0 0.0 226 09/21/2019 12:11:43 82 0.0 0.0 0.0 236 09/21/2019 12:12:08 79 0.0 0.0 0.0 231 09/21/2019 12:12:33 79 0.0 0.0 0.0 229 09/21/2019 12:12:56 63 0.0 0.0 0.0 224 09/21/2019 12:13:23 62 0.0 0.0 0.0 228 09/21/2019 12:13:46 65 0.0 0.0 0.0 227 09/21/2019 12:14:13 62 0.0 0.0 0.0 229 09/21/2019 12:14:38 77 0.0 0.0 0.0 237 09/21/2019 12:15:03 80 0.0 0.0 0.0 228 09/21/2019 12:15:28 81 0.0 0.0 0.0 234 09/21/2019 12:15:53 81 0.0 0.0 0.0 236 09/21/2019 12:16:16 83 0.0 0.0 0.0 239 09/21/2019 12:16:43 79 0.0 0.0 0.0 235 09/21/2019 12:17:08 80 0.0 0.0 0.0 225 09/21/2019 12:17:33 62 0.0 0.0 0.0 225 09/21/2019 12:17:58 64 0.0 0.0 0.0 230 09/21/2019 12:18:23 63 0.0 0.0 0.0 221 09/21/2019 12:18:48 62 0.0 0.0 0.0 222 09/21/2019 12:19:13 65 0.0 0.0 0.0 218 09/21/2019 12:19:38 79 0.0 0.0 0.0 225 09/21/2019 12:20:03 80 0.0 0.0 0.0 235 09/21/2019 12:20:28 80 0.0 0.0 0.0 238 09/21/2019 12:20:53 82 0.0 0.0 0.0 230 Page 13 of 24 Well CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhlllips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LR/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 12:21:43 79 0.0 0.0 0.0 242 09/21/2019 12:22:08 67 0.0 0.0 0.0 239 09/21/2019 12:22:33 49 0.0 0.0 0.0 234 09/21/2019 12:22:58 49 0.0 0.0 0.0 223 09/21/2019 12:23:23 51 0.0 0.0 0.0 221 09/21/2019 12:23:48 50 0.0 0.0 0.0 222 09/21/2019 12:24:13 68 0.0 0.0 0.0 217 09/21/2019 12:24:38 95 0.0 0.0 1.0 220 09/21/2019 12:25:02 91 0.0 0.0 2.0 228 Reset Total, Vol = 2.02 bbl 09/21/2019 12:25:03 91 0.0 0.0 0.0 224 09/21/2019 12:25:28 93 0.0 0.0 0.0 236 09/21/2019 12:25:53 185 0.0 0.0 0.0 234 09/21/2019 12:26:18 169 0.0 0.0 0.0 237 09/21/2019 12:26:43 159 0.0 0.0 0.0 243 09/21/2019 12:27:08 120 0.0 0.0 0.0 233 09/21/2019 12:27:33 57 0.0 0.0 0.0 224 09/21/2019 12:27:58 119 0.0 0.0 0.0 219 09/21/2019 12:28:23 117 0.0 0.0 0.0 220 09/21/2019 12:28:48 128 0.0 0.0 0.0 217 09/21/2019 12:29:13 87 0.0 0.0 0.0 220 09/21/2019 12:29:38 93 0.0 0.0 0.0 224 09/21/2019 12:30:03 65 0.0 0.0 0.0 234 09/21/2019 12:30:28 68 0.0 0.0 0.0 239 09/21/2019 12:30:53 67 0.0 0.0 0.0 242 09/21/2019 12:31:18 68 0.0 0.0 0.0 240 09/21/2019 12:31:43 50 0.0 0.0 0.0 238 09/21/2019 12:32:08 48 0.0 0.0 0.0 241 09/21/2019 12:32:33 52 0.0 0.0 0.0 236 09/21/2019 12:32:58 51 0.0 0.0 0.0 226 09/21/2019 12:33:23 61 0.0 0.0 0.0 220 09/21/2019 12:33:48 67 0.0 0.0 0.0 219 09/21/2019 12:34:13 74 0.0 0.0 0.0 227 09/21/2019 12:34:38 136 0.0 0.0 0.0 223 09/21/2019 12:35:03 125 0.0 0.0 0.0 225 09/21/2019 12:35:28 122 0.0 0.0 0.0 232 09/21/2019 12:35:53 67 0.0 0.0 0.0 239 09/21/2019 12:36:18 49 0.0 0.0 0.0 240 09/21/2019 12:36:43 49 0.0 0.0 0.0 239 09/21/2019 12:37:08 48 0.0 0.0 0.0 239 09/21/2019 12:37:33 49 0.0 0.0 0.0 239 09/21/2019 12:37:58 51 0.0 0.0 0.0 236 09/21/2019 12:38:23 73 0.0 0.0 0.0 230 09/21/2019 12:38:48 49 0.0 0.0 0.0 225 09/21/2019 12:39:13 60 0.0 0.0 0.0 216 09/21/2019 12:39:38 73 0.0 0.0 0.0 223 09/21/2019 12:40:03 67 0.0 0.0 0.0 227 09/21/2019 12:40:28 65 0.0 0.0 0.0 219 09/21/2019 12:40:53 66 0.0 0.0 0.0 222 09/21/2019 12:41:18 68 0.0 0.0 0.0 233 09/21/2019 12:41:43 63 0.0 0.0 0.0 239 09/21/2019 12:42:08 68 0.0 0.0 0.0 241 09/21/2019 12:42:33 67 0.0 0.0 0.0 246 09/21/2019 12:42:58 50 0.0 0.0 0.0 240 09/21/2019 12:43:23 50 0.0 0.0 0.0 243 Page 14 of 24 Well CDS-92 Field Apline ]ob Start Sep/21/2019 Customer Conoco Phillips lob Number 84027 Date Time 24 -hr clock PRESS PSI DENS LB/6 RATE B/M Volume 1181. WNP Message PSI 09/21/2019 12:44:13 48 0.0 0.0 0.0 235 09/21/2019 12:44:38 59 0.0 0.0 0.0 224 09/21/2019 12:45:03 67 0.0 0.0 0.0 223 09/21/2019 12:45:28 66 0.0 0.0 0.0 225 09/21/2019 12:45:53 51 0.0 0.0 0.0 229 09/21/2019 12:46:18 61 0.0 0.0 0.0 223 09/21/2019 12:46:43 63 0.0 0.0 0.0 234 09/21/2019 12:47:08 61 0.0 0.0 0.0 245 09/21/2019 12:47:33 63 0.0 0.0 0.0 245 09/21/2019 12:47:58 48 0.0 0.0 0.0 262 09/21/2019 12:48:23 45 0.0 0.0 0.0 257 09/21/2019 12:48:48 47 0.0 0.0 0.0 268 09/21/2019 12:49:13 45 0.0 0.0 0.0 274 09/21/2019 12:49:38 67 0.0 0.0 0.0 275 09/21/2019 12:50:03 51 0.0 0.0 0.0 262 09/21/2019 12:50:28 64 0.0 0.0 0.0 252 09/21/2019 12:50:53 64 0.0 0.0 0.0 253 09/21/2019 12:51:18 65 0.0 0.0 0.0 254 09/21/2019 12:51:43 63 0.0 0.0 0.0 265 09/21/2019 12:52:08 50 0.0 0.0 0.0 254 09/21/2019 12:52:33 48 0.0 0.0 0.0 276 09/21/2019 12:52:58 64 0.0 0.0 0.0 284 09/21/2019 12:53:23 61 0.0 0.0 0.0 292 09/21/2019 12:53:48 55 0.0 0.0 0.0 290 09/21/2019 12:54:13 81 0.0 0.0 0.0 299 09/21/2019 12:54:38 88 0.0 0.0 0.0 303 09/21/2019 12:55:03 87 0.0 0.0 0.0 308 09/21/2019 12:55:28 86 0.0 0.0 0.0 315 09/21/2019 12:55:53 87 0.0 0.0 0.0 343 09/21/2019 12:56:18 84 0.0 0.0 0.0 366 09/21/2019 12:56:43 87 0.0 0.0 0.0 372 09/21/2019 12:57:08 86 0.0 0.0 0.0 392 09/21/2019 12:57:33 99 0.0 0.0 0.0 405 09/21/2019 12:57:58 101 0.0 0.0 0.0 397 09/21/2019 12:58:23 102 0.0 0.0 0.0 413 09/21/2019 12:58:48 61 0.0 0.0 0.0 444 09/21/2019 12:59:13 97 0.0 0.0 0.0 452 09/21/2019 12:59:38 83 0.0 0.0 0.0 452 09/21/2019 13:00:03 58 0.0 0.0 0.0 469 09/21/2019 13:00:28 56 0.0 0.0 0.0 478 09/21/2019 13:00:53 45 0.0 0.0 0.0 508 09/21/2019 13:01:18 47 0.0 0.0 0.0 529 09/21/2019 13:01:43 58 0.0 0.0 0.0 535 09/21/2019 13:02:08 59 0.0 0.0 0.0 532 09/21/2019 13:02:33 55 0.0 0.0 0.0 531 09/21/2019 13:02:58 46 0.0 0.0 0.0 571 09/21/2019 13:03:23 42 0.0 0.0 0.0 601 09/21/2019 13:03:48 46 0.0 0.0 0.0 580 09/21/2019 13:04:13 39 0.0 0.0 0.0 601 09/21/2019 13:04:38 38 0.0 0.0 0.0 621 09/21/2019 13:05:03 41 0.0 0.0 0.0 639 09/21/2019 13:05:28 88 0.0 0.0 0.0 639 09/21/2019 13:05:53 80 0.0 0.0 0.0 647 09/21/2019 13:06:18 76 0.0 0.0 0.0 678 Page 15 of 24 Well CDS-92 7 Field Apline Jon Sart Sep/21/2019 Customer ConocoPhillips Job Number 84027 Dab Tim* 24 -hr dodo PRESS PSI DENS Ln/G RATE n/M Volume nnL WHIP Massage PSI 09/21/2019 13:07:08 79 0.0 0.0 0.0 707 09/21/2019 13:07:33 38 0.0 0.0 0.0 718 09/21/2019 13:07:58 39 0.0 0.0 0.0 731 09/21/2019 13:08:23 38 0.0 0.0 0.0 734 09/21/2019 13:08:48 35 0.0 0.0 0.0 600 09/21/2019 13:09:13 37 0.0 0.0 0.0 401 09/21/2019 13:09:38 41 0.0 0.0 0.0 439 09/21/2019 13:10:03 36 0.0 0.0 0.0 442 09/21/2019 13:10:28 37 0.0 0.0 0.0 445 09/21/2019 13:10:53 37 0.0 0.0 0.0 451 09/21/2019 13:11:18 38 0.0 0.0 0.0 451 09/21/2019 13:11:43 36 0.0 0.0 0.0 453 09/21/2019 13:12:08 37 0.0 0.0 0.0 455 09/21/2019 13:12:33 39 0.0 0.0 0.0 433 09/21/2019 13:12:58 33 0.0 0.0 0.0 1017 09/21/2019 13:13:23 31 0.0 0.0 0.0 1020 09/21/2019 13:13:48 31 0.0 0.0 0.0 1020 09/21/2019 13:14:13 27 0.0 0.0 0.0 1020 09/21/2019 13:14:38 26 0.0 0.0 0.0 1021 09/21/2019 13:15:03 27 0.0 0.0 0.0 1025 09/21/2019 13:15:28 25 0.0 0.0 0.0 1025 09/21/2019 13:15:53 24 0.0 0.0 0.0 1025 09/21/2019 13:16:18 24 0.0 0.0 0.0 1025 09/21/2019 13:16:43 25 0.0 0.0 0.0 1029 09/21/2019 13:17:08 25 0.0 0.0 0.0 1027 09/21/2019 13:17:33 23 0.0 0.0 0.0 1028 09/21/2019 13:17:58 23 0.0 0.0 0.0 1032 09/21/2019 13:18:23 74 0.0 0.0 0.0 1030 09/21/2019 13:18:48 71 0.0 0.0 0.0 1033 09/21/2019 13:19:13 75 0.0 0.0 0.0 1036 09/21/2019 13:19:38 78 0.0 0.0 0.0 1033 09/21/2019 13:20:03 77 0.0 0.0 0.0 1035 09/21/2019 13:20:28 70 0.0 0.0 0.0 1037 09/21/2019 13:20:53 74 0.0 0.0 0.0 1037 09/21/2019 13:21:18 70 0.0 0.0 0.0 1038 09/21/2019 13:21:43 72 0.0 0.0 0.0 820 09/21/2019 13:22:08 73 0.0 0.0 0.0 211 09/21/2019 13:22:33 72 0.0 0.0 0.0 67 09/21/2019 13:22:58 71 0.0 0.0 0.0 56 09/21/2019 13:23:23 73 0.0 0.0 0.0 56 09/21/2019 13:23:48 69 0.0 0.0 0.0 59 09/21/2019 13:24:13 69 0.0 0.0 0.0 57 09/21/2019 13:24:38 68 0.0 0.0 0.0 56 09/21/2019 13:25:03 66 0.0 0.0 0.0 54 09/21/2019 13:25:28 68 0.0 0.0 0.0 55 09/21/2019 13:25:53 67 0.0 0.0 0.0 54 09/21/2019 13:26:18 62 0.0 0.0 0.0 53 09/21/2019 13:26:43 59 0.0 0.0 0.0 325 09/21/2019 13:27:08 69 0.0 0.0 0.0 821 09/21/2019 13:27:16 68 0.0 0.0 0.0 912 landed stage stop plug 09/21/2019 13:27:32 68 0.0 0.0 0.0 1215 Pressuring up to open stage collar 09/21/2019 13:27:33 68 0.0 0.0 0.0 1155 09/21/2019 13:27:58 70 0.0 0.0 0.0 1624 09/21/2019 13:28:23 43 0.0 0.0 0.0 2071 Page 16 of 24 Well CD5-92 Field Apline Job Start Sep/21/2019 Customer ConocoPhillips Job Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 13:29:13 31 0.0 0.0 0.0 3015 09/21/2019 13:29:38 27 0.0 0.0 0.0 629 09/21/2019 13:30:03 27 0.0 0.0 0.0 125 09/21/2019 13:30:28 27 0.0 0.0 0.0 129 09/21/2019 13:30:48 27 0.0 0.0 0.0 135 stage collar open, 3420 psi 09/21/2019 13:30:53 29 0.0 0.0 0.0 134 09/21/2019 13:31:18 27 0.0 0.0 0.0 136 09/21/2019 13:31:40 28 0.0 0.0 0.0 145 5357 strokes to bump top plug 09/21/2019 13:31:43 29 0.0 0.0 0.0 145 09/21/2019 13:32:08 27 0.0 0.0 0.0 170 09/21/2019 13:32:33 25 0.0 0.0 0.0 167 09/21/2019 13:32:58 29 0.0 0.0 0.0 166 09/21/2019 13:33:23 28 0.0 0.0 0.0 197 09/21/2019 13:33:48 28 0.0 0.0 0.0 203 09/21/2019 13:34:13 27 0.0 0.0 0.0 232 09/21/2019 13:34:38 25 0.0 0.0 0.0 230 09/21/2019 13:35:03 25 0.0 0.0 0.0 236 09/21/2019 13:35:28 27 0.0 0.0 0.0 227 09/21/2019 13:35:53 27 0.0 0.0 0.0 282 09/21/2019 13:36:18 27 0.0 0.0 0.0 275 09/21/2019 13:36:43 27 0.0 0.0 0.0 324 09/21/2019 13:37:08 28 0.0 j 0.0 0.0 326 09/21/2019 13:37:33 27 0.0 0.0 0.0 383 09/21/2019 13:37:58 28 0.0 0.0 0.0 374 09/21/2019 13:38:23 28 0.0 0.0 0.0 385 09/21/2019 13:38:48 27 0.0 0.0 0.0 393 09/21/2019 13:39:13 28 0.0 0.0 0.0 383 09/21/2019 13:39:38 31 0.0 0.0 0.0 377 09/21/2019 13:40:03 31 0.0 0.0 0.0 387 09/21/2019 13:40:28 28 0.0 0.0 0.0 388 09/21/2019 13:40:53 29 0.0 0.0 0.0 389 09/21/2019 13:41:18 27 0.0 0.0 0.0 383 09/21/2019 13:41:43 31 0.0 0.0 0.0 373 09/21/2019 13:42:08 29 0.0 0.0 0.0 389 09/21/2019 13:42:33 30 0.0 0.0 0.0 386 09/21/2019 13:42:58 30 0.0 0.0 0.0 383 09/21/2019 13:43:23 26 0.0 0.0 0.0 373 09/21/2019 13:43:48 28 0.0 0.0 0.0 380 09/21/2019 13:44:13 27 0.0 0.0 0.0 387 09/21/2019 13:44:38 30 0.0 0.0 0.0 387 09/21/2019 13:45:03 31 0.0 0.0 0.0 379 09/21/2019 13:45:28 29 0.0 0.0 0.0 382 09/21/2019 13:45:53 28 0.0 0.0 0.0 387 09/21/2019 13:46:18 29 0.0 0.0 0.0 385 09/21/2019 13:46:43 29 0.0 0.0 0.0 388 09/21/2019 13:47:08 30 0.0 0.0 0.0 378 09/21/2019 13:47:33 30 0.0 0.0 0.0 372 09/21/2019 13:47:58 29 0.0 0.0 0.0 386 09/21/2019 13:48:23 29 0.0 0.0 0.0 385 09/21/2019 13:48:48 28 0.0 0.0 0.0 382 09/21/2019 13:49:13 29 0.0 0.0 0.0 378 09/21/2019 13:49:38 29 0.0 0.0 0.0 383 09/21/2019 13:50:03 28 0.0 0.0 0.0 391 09/21/2019 13:50:28 30 0.0 0.0 0.0 388 Page 17 of 24 Well CD5-92 Field Apline Job Start Sep/21/2019 Customer ConocoPhillips Job Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/O RATE B/H Volume BBL WHP PSI Message 09/21/2019 13:51:18 29 0.0 0.0 0.0 393 09/21/2019 13:51:43 32 0.0 0.0 0.0 389 09/21/2019 13:52:08 29 0.0 0.0 0.0 392 09/21/2019 13:52:33 29 0.0 0.0 0.0 390 09/21/2019 13:52:58 31 0.0 0.0 0.0 379 09/21/2019 13:53:23 30 0.0 0.0 0.0 380 09/21/2019 13:53:48 30 0.0 0.0 0.0 391 09/21/2019 13:54:13 30 0.0 0.0 0.0 387 09/21/2019 13:54:38 31 0.0 0.0 0.0 383 09/21/2019 13:55:03 29 1 0.0 0.0 0.0 389 09/21/2019 13:55:28 31 0.0 0.0 0.0 392 09/21/2019 13:55:53 30 0.0 0.0 0.0 393 09/21/2019 13:56:18 28 0.0 0.0 0.0 395 09/21/2019 13:56:43 30 0.0 0.0 0.0 389 09/21/2019 13:57:08 31 0.0 0.0 0.0 398 09/21/2019 13:57:33 29 0.0 0.0 0.0 393 09/21/2019 13:57:58 29 0.0 0.0 0.0 396 09/21/2019 13:58:23 29 0.0 0.0 0.0 390 09/21/2019 13:58:48 28 0.0 0.0 0.0 385 09/21/2019 13:59:13 29 0.0 0.0 0.0 391 09/21/2019 15:57:18 33 0.0 0.0 0.0 391 redyfor stage 2 09/21/2019 15:57:33 28 0.0 0.0 0.0 401 09/21/2019 15:57:58 31 0.0 0.0 0.0 408 09/21/2019 15:58:23 31 0.0 0.0 0.0 401 09/21/2019 15:58:48 32 0.0 0.0 0.0 404 09/21/2019 15:59:13 65 0.0 0.0 0.0 404 09/21/2019 15:59:38 60 0.0 0.0 0.0 407 09/21/2019 16:00:03 86 0.0 0.0 0.0 394 09/21/2019 16:00:28 82 0.0 0.0 0.0 391 09/21/2019 16:00:53 84 0.0 0.0 0.0 402 09/21/2019 16:01:18 85 0.0 0.0 0.0 402 09/21/2019 16:01:43 83 0.0 0.0 0.0 389 09/21/2019 16:02:08 81 0.0 0.0 0.0 389 09/21/2019 16:02:33 84 0.0 0.0 0.0 401 09/21/2019 16:02:58 82 0.0 0.0 0.0 404 09/21/2019 16:03:23 82 0.0 0.0 0.0 406 09/21/2019 16:03:48 83 0.0 0.0 0.0 398 09/21/2019 16:04:13 82 0.0 0.0 0.0 392 09/21/2019 16:04:38 84 0.0 0.0 0.0 400 09/21/2019 16:05:03 80 0.0 0.0 0.0 407 09/21/2019 16:05:28 84 0.0 0.0 0.0 394 09/21/2019 16:05:53 83 0.0 0.0 0.0 389 09/21/2019 16:06:18 83 0.0 0.0 0.0 398 09/21/2019 16:06:22 83 0.0 0.0 0.0 401 mudpush hatched up 09/21/2019 16:06:43 147 0.0 0.0 0.0 250 09/21/2019 16:07:08 132 0.0 0.0 0.0 86 09/21/2019 16:07:33 130 0.0 0.0 0.0 84 09/21/2019 16:07:58 131 0.0 0.0 0.0 80 09/21/2019 16:08:07 130 0.0 0.0 0.0 80 start mudpush 09/21/2019 16:08:23 120 0.0 0.0 0.0 120 09/21/2019 16:08:44 319 0.0 0.0 0.7 188 Retums at Surface 09/21/2019 16:08:48 312 0.0 0.0 1.0 188 09/21/2019 16:09:13 340 0.0 0.0 2.3 197 09/21/2019 16:09:38 324 0.0 0.0 3.7 193 Page 18 of 24 Well CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhillips ]ob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/6 RATE B/M Volume BBL WNP PSI Message 09/21/2019 16:10:28 290 0.0 0.0 6.4 173 09/21/2019 16:10:53 299 0.0 0.0 7.7 175 09/21/2019 16:11:18 287 0.0 j 0.0 9.0 171 09/21/2019 16:11:43 281 0.0 0.0 10.3 167 09/21/2019 16:12:08 274 0.0 0.0 11.6 157 09/21/2019 16:12:33 283 0.0 0.0 12.9 157 09/21/2019 16:12:58 281 0.0 0.0 14.2 155 09/21/2019 16:13:23 272 0.0 0.0 15.5 150 09/21/2019 16:13:48 265 0.0 0.0 16.8 145 09/21/2019 16:14:13 264 0.0 0.0 18.1 138 09/21/2019 16:14:38 257 0.0 0.0 19.4 135 09/21/2019 16:15:03 249 0.0 0.0 20.7 130 09/21/2019 16:15:28 253 0.0 0.0 22.0 128 09/21/2019 16:15:53 237 0.0 0.0 23.4 130 09/21/2019 16:16:18 242 0.0 0.0 24.7 127 09/21/2019 16:16:43 246 0.0 0.0 26.0 112 09/21/2019 16:17:08 229 0.0 0.0 27.3 118 09/21/2019 16:17:33 232 0.0 0.0 28.6 104 09/21/2019 16:17:58 223 0.0 0.0 29.9 106 09/21/2019 16:18:23 230 0.0 0.0 31.2 100 09/21/2019 16:18:48 196 0.0 0.0 32.5 90 09/21/2019 16:19:13 193 0.0 0.0 33.7 90 09/21/2019 16:19:38 184 0.0 0.0 34.9 84 09/21/2019 16:20:03 190 0.0 0.0 36.1 82 09/21/2019 16:20:28 178 0.0 0.0 37.3 76 09/21/2019 16:20:53 175 0.0 0.0 38.5 77 09/21/2019 16:21:18 171 0.0 0.0 39.6 76 09/21/2019 16:21:43 122 0.0 0.0 40.6 70 09/21/2019 16:22:08 155 0.0 0.0 41.6 77 09/21/2019 16:22:33 54 0.0 0.0 41.9 61 09/21/2019 16:22:39 51 0.0 0.0 41.9 62 Reset Total, Vol = 41.91 bbl 09/21/2019 16:22:58 54 0.0 0.0 41.9 62 09/21/2019 16:23:23 124 0.0 0.0 41.9 60 09/21/2019 16:23:48 126 0.0 0.0 41.9 59 09/21/2019 16:24:13 114 0.0 0.0 41.9 61 09/21/2019 16:24:38 114 0.0 0.0 41.9 61 09/21/2019 16:25:03 127 0.0 0.0 41.9 62 09/21/2019 16:25:28 120 0.0 0.0 41.9 60 09/21/2019 16:25:53 121 0.0 0.0 41.9 62 09/21/2019 16:26:18 123 0.0 0.0 41.9 60 09/21/2019 16:26:26 120 0.0 0.0 41.9 62 cement wet 09/21/2019 16:26:43 120 0.0 0.0 41.9 60 09/21/2019 16:27:08 117 0.0 0.0 41.9 59 09/21/2019 16:27:33 118 0.0 0.0 41.9 59 09/21/2019 16:27:58 119 0.0 0.0 41.9 62 09/21/2019 16:28:23 116 0.0 0.0 41.9 59 09/21/2019 16:28:48 166 0.0 0.0 41.9 59 09/21/2019 16:29:04 137 0.0 0.0 41.9 70 Start Cement Slurry 09/21/2019 16:29:13 203 0.0 0.0 42.0 85 09/21/2019 16:29:38 354 0.0 0.0 43.4 94 09/21/2019 16:29:54 429 0.0 0.0 44.4 141 Retums at Surface 09/21/2019 16:30:03 400 0.0 0.0 44.9 136 09/21/2019 16:30:28 402 0.0 0.0 46.3 141 09/21/2019 16:30:53 492 0.0 0.0 47.8 162 Page 19 of 24 Weil CDS-92 FlNd Apline ]ob Start Sep/21/2019 Customer ConocoPhillips ]ob Number 84027 Date Time 24-hr clock PRESS PSI DENS LB/G RATE B/M Volume BBL WNP Message PSI 09/21/2019 16:31:43 482 0.0 0.0 51.1 155 09/21/2019 16:32:08 497 0.0 0.0 52.7 153 09/21/2019 16:32:33 479 0.0 0.0 54.3 147 09/21/2019 16:32:58 501 0.0 0.0 55.9 153 09/21/2019 16:33:23 488 0.0 0.0 57.5 154 09/21/2019 16:33:48 489 0.0 0.0 59.2 149 09/21/2019 16:34:13 478 0.0 0.0 60.8 145 09/21/2019 16:34:38 471 0.0 0.0 62.4 145 09/21/2019 16:35:03 483 0.0 0.0 64.0 149 09/21/2019 16:35:28 471 0.0 0.0 65.6 147 09/21/2019 16:35:53 486 0.0 0.0 67.2 149 09/21/2019 16:36:18 470 0.0 0.0 68.9 147 09/21/2019 16:36:43 499 0.0 0.0 70.5 150 09/21/2019 16:37:08 482 0.0 0.0 72.1 149 09/21/2019 16:37:33 483 0.0 0.0 73.7 148 09/21/2019 16:37:58 481 0.0 0.0 75.3 146 09/21/2019 16:38:23 479 0.0 0.0 76.9 149 09/21/2019 16:38:48 488 0.0 0.0 78.6 151 09/21/2019 16:39:13 471 0.0 0.0 80.2 143 09/21/2019 16:39:38 485 0.0 0.0 81.8 148 09/21/2019 16:40:03 468 0.0 0.0 83.4 145 09/21/2019 16:40:28 494 0.0 0.0 85.0 151 09/21/2019 16:40:53 487 0.0 0.0 86.6 150 09/21/2019 16:41:18 489 0.0 0.0 88.3 148 09/21/2019 16:41:43 487 0.0 0.0 89.9 151 09/21/2019 16:42:08 469 0.0 0.0 91.5 147 09/21/2019 16:42:33 496 0.0 0.0 93.1 148 09/21/2019 16:42:58 476 0.0 0.0 94.7 143 09/21/2019 16:43:23 484 0.0 0.0 96.4 148 09/21/2019 16:43:48 488 0.0 0.0 98.0 153 09/21/2019 16:44:13 457 0.0 0.0 99.6 141 09/21/2019 16:44:38 498 0.0 0.0 101.2 149 09/21/2019 16:45:03 480 0.0 0.0 102.8 146 09/21/2019 16:45:28 494 0.0 0.0 104.4 150 09/21/2019 16:45:53 493 0.0 0.0 106.1 148 09/21/2019 16:46:18 470 0.0 0.0 107.7 143 09/21/2019 16:46:43 69 0.0 0.0 108.2 64 09/21/2019 16:47:08 65 0.0 0.0 108.2 63 09/21/2019 16:47:33 77 0.0 0.0 108.2 61 09/21/2019 16:47:58 71 0.0 0.0 108.2 63 09/21/2019 16:48:23 77 0.0 0.0 108.2 60 09/21/2019 16:48:48 80 0.0 0.0 108.2 58 09/21/2019 16:49:13 66 0.0 0.0 108.2 61 09/21/2019 16:49:38 66 0.0 0.0 108.2 61 09/21/2019 16:50:03 69 0.0 0.0 108.2 61 09/21/2019 16:50:28 71 0.0 0.0 108.2 60 09/21/2019 16:50:37 67 0.0 0.0 108.2 61 Reset Total, Vol = 66.24 bbl 09/21/2019 16:50:44 398 0.0 0.0 108.2 102 20 bbl water 09/21/2019 16:50:53 508 0.0 0.0 108.8 187 09/21/2019 16:51:18 344 0.0 0.0 110.5 125 09/21/2019 16:51:43 289 0.0 0.0 112.4 88 09/21/2019 16:52:08 288 0.0 0.0 114.3 89 09/21/2019 16:52:33 285 0.0 0.0 116.3 90 09/21/2019 16:52:58 299 0.0 0.0 118.2 102 Page 20 of 24 wen CDS-92 7 Field Apline lob Star[ Sep/21/2019 Customer ConocoPhillips Job Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/6 RATE B/M volume BBL WNP PSI Message 09/21/2019 16:53:48 292 0.0 0.0 122.1 100 09/21/2019 16:54:13 294 0.0 0.0 124.0 98 09/21/2019 16:54:38 299 0.0 0.0 126.0 101 09/21/2019 16:55:03 301 0.0 0.0 127.9 103 09/21/2019 16:55:16 38 0.0 0.0 128.3 56 Reset Total, Vol = 20.19 bbl 09/21/2019 16:55:28 39 0.0 0.0 128.3 51 09/21/2019 16:55:39 56 0.0 0.0 128.3 51 tum over to rig for displacement 09/21/2019 16:55:53 57 0.0 0.0 128.3 90 09/21/2019 16:56:18 54 0.0 0.0 128.3 95 09/21/2019 16:56:43 56 0.0 0.0 128.3 200 09/21/2019 16:57:08 55 0.0 0.0 128.3 214 09/21/2019 16:57:33 57 0.0 0.0 128.3 222 09/21/2019 16:57:58 55 0.0 0.0 128.3 233 09/21/2019 16:58:23 81 0.0 0.0 128.3 229 09/21/2019 16:58:48 128 0.0 0.0 128.3 237 09/21/2019 16:59:13 121 0.0 0.0 128.3 233 09/21/2019 16:59:38 113 0.0 0.0 128.3 221 09/21/2019 17:00:03 31 0.0 0.0 128.3 218 09/21/2019 17:00:28 31 0.0 0.0 128.3 229 09/21/2019 17:00:53 30 0.0 0.0 128.3 237 09/21/2019 17:01:18 31 0.0 0.0 128.3 235 09/21/2019 17:01:43 30 0.0 0.0 128.3 232 09/21/2019 17:02:08 33 0.0 0.0 128.3 225 09/21/2019 17:02:33 33 0.0 0.0 128.3 215 09/21/2019 17:02:58 30 0.0 0.0 128.3 225 09/21/2019 17:03:23 31 0.0 0.0 128.3 235 09/21/2019 17:03:48 32 0.0 0.0 128.3 229 09/21/2019 17:04:13 31 0.0 0.0 128.3 231 09/21/2019 17:04:38 31 0.0 0.0 128.3 225 09/21/2019 17:05:03 31 0.0 0.0 128.3 217 09/21/2019 17:05:28 33 0.0 0.0 128.3 223 09/21/2019 17:05:53 31 0.0 0.0 128.3 235 09/21/2019 17:06:18 31 0.0 0.0 128.3 230 09/21/2019 17:06:43 31 0.0 0.0 128.3 221 09/21/2019 17:07:08 34 0.0 0.0 128.3 227 09/21/2019 17:07:33 32 0.0 0.0 128.3 219 09/21/2019 17:07:58 33 0.0 0.0 128.3 220 09/21/2019 17:08:23 33 0.0 0.0 128.3 232 09/21/2019 17:08:48 32 0.0 0.0 128.3 231 09/21/2019 17:09:13 32 0.0 0.0 128.3 225 09/21/2019 17:09:38 31 0.0 0.0 128.3 215 09/21/2019 17:10:03 31 0.0 0.0 128.3 219 09/21/2019 17:10:28 34 0.0 0.0 128.3 215 09/21/2019 17:10:53 33 0.0 0.0 128.3 231 09/21/2019 17:11:18 33 0.0 0.0 128.3 227 09/21/2019 17:11:43 31 0.0 0.0 128.3 228 09/21/2019 17:12:08 31 0.0 0.0 128.3 219 09/21/2019 17:12:33 31 0.0 0.0 128.3 220 09/21/2019 17:12:58 31 0.0 0.0 128.3 217 09/21/2019 17:13:23 33 0.0 0.0 128.3 233 09/21/2019 17:13:48 31 0.0 0.0 128.3 243 09/21/2019 17:14:13 32 0.0 0.0 128.3 249 09/21/2019 17:14:38 30 0.0 0.0 128.3 253 09/21/2019 17:15:03 31 0.0 0.0 128.3 256 Page 21 of 24 Well CDS-92 Field Apline ]ob Start Sep/21/2019 Customer ConocoPhillips ]ob Number 84027 Date Time 24 -hr dock PRESS PSI DENS LB/G RATE S/N Volume BBL WHIP PSI Message 09/21/2019 17:15:53 30 0.0 0.0 128.3 292 09/21/2019 17:16:18 30 0.0 0.0 128.3 313 09/21/2019 17:16:43 34 0.0 0.0 128.3 328 09/21/2019 17:17:08 33 0.0 0.0 128.3 349 09/21/2019 17:17:33 33 0.0 0.0 128.3 347 09/21/2019 17:17:58 30 0.0 0.0 128.3 388 09/21/2019 17:18:23 33 0.0 0.0 128.3 399 09/21/2019 17:18:48 32 0.0 0.0 128.3 420 09/21/2019 17:19:13 30 0.0 0.0 128.3 424 09/21/2019 17:19:38 30 0.0 0.0 128.3 449 09/21/2019 17:20:03 33 0.0 0.0 128.3 446 09/21/2019 17:20:28 31 0.0 0.0 128.3 474 09/21/2019 17:20:53 31 0.0 0.0 128.3 492 09/21/2019 17:21:18 33 0.0 0.0 128.3 495 09/21/2019 17:21:43 32 0.0 0.0 128.3 504 09/21/2019 17:22:08 33 0.0 0.0 128.3 527 09/21/2019 17:22:33 33 0.0 0.0 128.3 525 09/21/2019 17:22:58 32 0.0 0.0 128.3 528 09/21/2019 17:23:23 30 0.0 0.0 128.3 565 09/21/2019 17:23:48 34 0.0 0.0 128.3 553 09/21/2019 17:24:13 33 0.0 0.0 128.3 577 09/21/2019 17:24:38 30 0.0 0.0 128.3 573 09/21/2019 17:25:03 33 0.0 0.0 128.3 589 09/21/2019 17:25:28 33 0.0 0.0 128.3 576 09/21/2019 17:25:53 31 0.0 0.0 128.3 597 09/21/2019 17:26:18 53 0.0 0.0 128.3 600 09/21/2019 17:26:43 30 0.0 0.0 128.3 607 09/21/2019 17:27:08 109 0.0 0.0 128.3 595 09/21/2019 17:27:25 99 0.0 0.0 128.3 357 slow rate for bump 09/21/2019 17:27:33 94 0.0 0.0 128.3 351 09/21/2019 17:27:58 96 0.0 0.0 128.3 342 09/21/2019 17:28:23 124 0.0 0.0 128.3 339 09/21/2019 17:28:48 121 0.0 0.0 128.3 363 09/21/2019 17:29:13 120 0.0 0.0 128.3 351 09/21/2019 17:29:38 94 0.0 0.0 128.3 344 09/21/2019 17:30:03 32 0.0 0.0 128.3 363 09/21/2019 17:30:28 91 0.0 0.0 128.3 345 09/21/2019 17:30:53 67 0.0 0.0 128.3 361 09/21/2019 17:31:18 33 0.0 0.0 128.3 360 09/21/2019 17:31:43 33 0.0 0.0 128.3 352 09/21/2019 17:32:08 34 0.0 0.0 128.3 743 09/21/2019 17:32:33 29 0.0 0.0 128.3 1351 09/21/2019 17:32:37 30 0.0 0.0 128.3 1454 land top plug 09/21/2019 17:32:58 33 0.0 0.0 128.3 2055 09/21/2019 17:33:23 30 0.0 0.0 128.3 2082 09/21/2019 17:33:48 33 0.0 0.0 128.3 1858 09/21/2019 17:34:13 55 0.0 0.0 128.3 1891 09/21/2019 17:34:25 118 0.0 0.0 128.3 2010 attempting to dose stage tool 09/21/2019 17:34:38 107 0.0 0.0 128.3 2155 09/21/2019 17:35:03 47 0.0 0.0 128.3 2007 09/21/2019 17:35:28 29 0.0 0.0 128.3 1942 09/21/2019 17:35:53 32 0.0 0.0 128.3 2098 09/21/2019 17:36:18 28 0.0 0.0 128.3 2167 09/21/2019 17:36:43 29 0.0 0.0 128.3 2121 Page 22 of 24 Well CDS-92 Field Apline lob Start Sep/21/2019 Customer ConocoPhillips lob Number 84027 Date Time 24 -hr dock PRESS PSI DENS L6/G RATE E/M Volume 6!L WHP Message PSI 09/21/2019 17:37:33 29 0.0 0.0 128.3 2249 09/21/2019 17:37:58 29 0.0 0.0 128.3 2229 09/21/2019 17:38:23 28 0.0 0.0 128.3 2215 09/21/2019 17:38:48 30 0.0 0.0 128.3 1998 09/21/2019 17:39:13 30 0.0 0.0 128.3 1255 09/21/2019 17:39:38 29 0.0 0.0 128.3 424 09/21/2019 17:40:03 30 0.0 0.0 128.3 97 09/21/2019 17:40:28 29 0.0 0.0 128.3 58 09/21/2019 17:40:38 29 0.0 0.0 128.3 54 2572 STKS to bump 09/21/2019 17:40:53 28 0.0 0.0 128.3 52 09/21/2019 17:41:18 28 0.0 0.0 128.3 50 09/21/2019 17:41:43 29 0.0 0.0 128.3 45 09/21/2019 17:42:08 27 0.0 0.0 128.3 5o 09/21/2019 17:42:33 27 0.0 0.0 128.3 48 09/21/2019 17:42:58 27 0.0 0.0 128.3 49 09/21/2019 17:43:23 31 0.0 0.0 128.3 48 09/21/2019 17:43:48 27 0.0 0.0 128.3 48 09/21/2019 17:44:13 28 0.0 0.0 128.3 48 09/21/2019 17:44:38 29 0.0 0.0 128.3 48 09/21/2019 17:45:03 28 0.0 0.0 128.3 50 09/21/2019 17:45:28 28 0.0 0.0 128.3 47 09/21/2019 17:45:53 29 0.0 0.0 128.3 46 09/21/2019 17:46:18 27 0.0 0.0 128.3 46 09/21/2019 17:46:43 27 0.0 0.0 128.3 50 09/21/2019 17:47:08 25 0.0 0.0 128.3 49 09/21/2019 17:47:33 23 0.0 0.0 128.3 50 09/21/2019 17:47:58 27 0.0 0.0 128.3 51 09/21/2019 17:48:23 26 0.0 0.0 128.3 52 09/21/2019 17:48:48 23 0.0 0.0 128.3 54 09/21/2019 17:49:13 23 0.0 0.0 128.3 53 09/21/2019 17:49:38 26 0.0 0.0 128.3 57 09/21/2019 17:50:03 26 0.0 0.0 128.3 60 09/21/2019 17:50:28 27 0.0 0.0 128.3 60 09/21/2019 17:50:53 25 0.0 0.0 128.3 58 09/21/2019 17:51:18 26 0.0 0.0 128.3 60 09/21/2019 17:51:43 27 0.0 0.0 128.3 62 09/21/2019 17:52:08 24 0.0 0.0 128.3 63 09/21/2019 17:52:33 27 0.0 0.0 128.3 65 09/21/2019 17:52:58 27 0.0 0.0 128.3 68 09/21/2019 17:53:23 29 0.0 0.0 128.3 68 09/21/2019 17:53:48 28 0.0 0.0 128.3 68 09/21/2019 17:54:13 27 0.0 0.0 128.3 70 09/21/2019 17:54:38 29 0.0 0.0 128.3 69 09/21/2019 17:55:03 26 0.0 0.0 128.3 74 09/21/2019 17:55:28 27 0.0 0.0 128.3 73 09/21/2019 17:55:53 25 0.0 0.0 128.3 76 09/21/2019 17:56:18 24 0.0 0.0 128.3 78 09/21/2019 17:56:43 25 0.0 0.0 128.3 77 09/21/2019 17:57:08 25 0.0 0.0 128.3 79 09/21/2019 17:57:33 26 0.0 0.0 128.3 79 09/21/2019 17:58:23 25 0.0 0.0 128.3 79 09/21/2019 17:58:48 25 0.0 0.0 128.3 79 09/21/2019 17:59:13 24 0.0 0.0 128.3 79 09/21/2019 17:59:33 25 0.0 0.0 128.3 79 tool"shut" Page 23 o/ 24 Well Field Job Start Customer lob Number CDS-92 Aphne Sep/21/2019 Conoco Phillips 84027 Post Job Summary Page 24 of 24 Average Pump Rates, bbl/min Volume of Fluid Injected, bbl Slurry 3.4 N2 Mud Maximum Rate 7.0 Total Slurry 191.2 Mud 0.0 Spacer 102.1 N2 Treating Pressure Summary, psi Breakdown Fluid Maximum 4084 Final 23 erage Av123 Bump Plug to 1100 Breakdown Type Volume bbl Density Ib/gal Avg. N2 Percent % Designed Slurry Volume 0.0 bbl Displacement 20.0 bbl Mix Water Temp 80 degF Cement Circulated to Surface? ❑ Volume bbl Washed Thru Paris To ft Customer or Authorized Representative Rob Reinhardt Schlumberger Supervisor John Morrison Circulation Lost Job Completed %❑ Page 24 of 24 PTD ;219 -03 ,�P Loepp, Victoria T (CED) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, June 25, 2019 10:13 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CRU CD5-92(PTD 219-034) Rig change to Doyon 25 Follow Up Flag: Follow up Flag Status: Flagged Victoria, Great! Thank you. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, June 25, 2019 9:39 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]CRU CD5-92(PTD 219-034) Rig change to Doyon 25 Andrew, This email will suffice. 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 Loeppna.alaska.aov 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. Loe .)alask�a,joy From: Beat, Andrew T <And rew.T. Beatconocophillips.com> Sent: Tuesday, lune 25, 2019 9:29 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Gre S.Hobbs c conocophillips.com> Subject: CD5-92 PTD Edit (219-034) Victoria, Back in February we received approval to drill CD5-92 (219-034) with Doyon 142. Our rig schedules were moved around and CD5-92 was pushed further back on the schedule and moved over to Doyon 25. The plan is for CDS-92 to be the next well drilled on Doyon 25 with an anticipated spud date around August 10. What is the best way for us to amend the current PTD to reflect the change to Doyon 25? All else will remain the same in the permit. Thanks, Andrew (303)378-8881 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 Re: Colville River Field, Alpine Oil Pool, CRD CD5-92 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-034 Surface Location: 246' FNL, 2286' FEL, SEC. 18, TI IN, R4E, UM Bottomhole Location: 497' FNL, 487' FEL, SEC. 27, T12N, R3E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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, Daniel T. Seamount, Jr. Commissioner DATED this Y February, _day Feb2019. Y� STATE OF ALASKA AL ..A OIL AND GAS CONSERVATION COMMI� .,ON PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 • CRU-CD5-92 ` 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 28738 TVD: 7375 Colville River Unit Alpine Pool 4a. Location of Well (Governmental Section): 7. Property Designation: - Surface: 246' FNL, 2286' FEL, Sec. 18, T11N, R4E, UM ASRC-NPR4, ASRC-NPR2, ASRC-NPR3, ASRC-N PRI Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4335' FNL, 3345' FEL, Sec. 1, T11 N, R3E, UM 932669000, 932128000, 932671000, 932126000 3/7/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 497' FNL, 487' FEL, Sec. 27, T12N, R3E, UM 1238, 6408, 2560, 6146 497' to ASCR-NPR1 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 73.3 15. Distance to Nearest Well Open Surface: x- 349693 y- 5965958 Zone -4 GL / BF Elevation above MSL (ft): 33.9 Ito Same Pool: 1442' CD5-23 16. Deviated wells: Kickoff depth: 800 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3200 - Surface: 2463 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 78.6 B Welded 76 39 39 115 115 10 yds 13.5" 10.75" 45.5 L-80 TXP 2228 39 39 2267 2207 984sx 11.0ppg, 271 sx 15.8ppg G 9.875x11" 7.625" 29.7 L-80 TXP 12420 39 39 12459 7493 650sx 15.8ppg Class G 6.5" 4.75" 1 12.2 L-80 T -Blue 16429 12309 7483 28738 73741 Lined with blank pipe and frac ports 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 0 No ❑ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program v. Depth Plot ❑ ❑ eFluid Shallow Hazard Analysis ❑✓ ❑ Divertter Sketch Seabed Report Drilling Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Andy Marushack Authorized Name: Chip Alvord Contact Email: and .0.marUShack c0 .com Authorized Title: Drilling Manager Contact Phone: 832-525-8923 A 11 Authorized Signature: It Date: atzy(2s',rct Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: <�, 1 I - 0 150- 10 3 20'300 - 00 - 0 0 1 Date: Z requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: OCR try t ,Ta 35-Ul'5., -r Samples req'd: Yes ❑ Nolvl" Mud log req'd: Yes E]No [ K 4,;-1 v1 ti / cT /- F1 Vivo r �5 �� � J (SCJ /�5 iH�3 measures: Yes ❑ No IVDirectional svy req'd: Yes [N/No ❑ j VC rffP- V'�-4 r/'n h C 15- 1-6? n n/ Spacing exception req'd: Yes ❑ No [� Inclination -only svy req'd: Yes ❑ No [[ P C'r 2 AAS S. L 5- /yl zl Post initial injection MIT req'd: Yes ❑ No I� APPROVED BY Approved by:4p/� COMMISSIONER THE COMMISSION Date: Z 2g //9 Submit Form and t<�f Form 10-401 Revised 5/2017 Thi. pefmit is valid for 24 mehR.JGIN r al per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 251h, 2019 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU CD5-92 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine A and Alpine C production well from the CD5 drilling pad with rig Doyon 142. The intended spud date for this well could be as early as 3/7/2019. CRU CD5-92 is planned to be an Alpine A production 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. This hole will be subsequently cased with a 7-5/8" casing string to surface and cemented to 250' TVD above the uppermost hydrocarbon bearing interval. The suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak -off test. The 6-1/2" production section will then be horizontally drilled and completed as producer in the Alpine A reservoir. Alpine A sand lateral will be lined with 4-3/4" liner, with the upper completion covered in the corresponding PTD application. 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 Greg Hobbs at 263-4749 (Greg.S.Hobbs@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, cc: C135-92 Well File / Ann Haggerty -Sherrod ATO 1530 a4A�� Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Andy Marushack Jennifer Hoyt ATO 1760 Drilling Engineer Lanston Chin Kuukpik Corp Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 CD5-92 Application for Permit to Drill Document f 31 Cono ocooPhillips'"� Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (fl)............................................................ 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............................................................................................................. 10 Attachment 1 Cement Summary............................................................................................................... 10 CD5-92 APD Page 1 of 15 Printed: 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 Attachment 2 Drilling Hazards Summary................................................................................................. 10 Attachment 3 Completion Schematic........................................................................................................ 10 Attachment4 Directional Plan................................................................................................................ 10 CD5-92 APD Page 2 of 15 Printed., 24 -Feb -19 Applica x Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 1. Well Name (Requirements of 20 AAC 25.005 (fl) The well for which this application is submitted will be designated as CRU CD5-92 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 246' FNL, 2286' FEL, Sec. 18, TI IN, R4E, UM NAD 1927 RKB Elevation 73.3' AMSL Northings: 5,965,958 Eastings: 349,693 Pad Elevation 33.7' AMSL Top of Productive Horizon eel 4335' FNL, 3345 FEL, Sec. 1, TI IN, RM, UM NAD 1927 Northings: 5,972,550 Eastings: 343,839 Measured Depth, RKB: 12,383' Total Vertical Depth, RKB: 7,489' Total Vertical Depth, SS: 7,416' Total Depth Toe 497' FNL, 487' FEL, Sec. 27, T12N, R3E, UM NAD 1927 Northings: 5,987,108 Eastings: 336,432 Measured Depth, RKB: 28,738' Total Vertical Depth, RKB: 7,374' Total Vertical Depth, SS: 7,300' 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 25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 142. CD5-92 APD Page 3 of 15 Printed: 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 4. Drilling Hazards Information (Requirements of20 AAC 25.005 (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 Pore pressure si ASP Drilling si 20 120/120 10.9 51 56 10.75 2,267 / 2,207 14.5 964 1,443 7.625 12,459 / 7,493 12.5 3,950--, 2463 4.75 28,738/ 7,375 12.5 3,200 n/a ASP is determined as the lesser of 1) surface pressure at breakdown of the fo ation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less ag 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 lb./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 1. 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) = 977 - (0.1 x 2190') = 745 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 2207' = 1443 psi OR ASP = FPP - (0.1 x D) = 3950 - (0.1 x 7495') = 3200 psi 3. Drilling below 7-5/8" intermediate casing ASP = [(FG x 0.052) - 0.1] D = [(12.5 x 0.052) - 0.1 ] x 7375 = 4056 psi OR ASP = FPP - (0.1 x D) = 3200- (0.1 x 7375') = 2463 psi _M' 1A_ h� �h PT " pry fv, f0c q.6 -las g- 35 FjT-°q,.5- 2ly�I\0\ CD5-92 APD Page 4 of 15 Printed: 24 -Feb -19 Applice or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 (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 of 20 AAC 25.005 (c)(s)) 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 Cementin 1, Program Csg7Tbg Hole Sne weight Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program OD (in) (Ib7ft) (ft) (ft) (ft) 20 42 94 H-40 Welded 76 39/39 115/115 10 yards Cement to Surface with 10.75 13.5 45.5 L-80 BTM 2,228 39/39 2,267 / 2,207 984 sx DeepCrete Lead 11.0 ppg, 271 sx Class G Tail Slurry 15.8 ppg 7.625 9.875 X11 29.7/ 39 L-80 TXP 12,420 39/39 12,459 / 7,493 650 sx of Class G at 15.8 ppg 4.75 6.5 12.2 L-80 Blue 16,429 12,209 / 7,483 28,738 / 7,374 No cement, Perforation Sub 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2) is granted. At CD5, more than ✓� twenty-four penetrations have been completed and there has not been a significant indication of shallowgas or gas hydrates above the C30 where casing will be set. CD5-92 APD Page 5 of 15 Printed. 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 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, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and 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 shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (FloPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-92 APD Page 6 of 15 Printed: 24 -Feb -19 Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.5 Casing Size in. 10.75 7.625 4.5 Density PPG 9.0-10.0 9.6-10.8 8.8-9.5 PV CP 30-80 10 10 YP Ib./100 ftz 100-200 20-28 10-15 Funnel Viscosity s/qt. 300 50-60 40-50 Initial Gels Ib./100 ftz 50 10 6 10 Minute Gels Ib./100 ftz 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, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and 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 shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (FloPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-92 APD Page 6 of 15 Printed: 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 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 of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis(Requirements of20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20AAC25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 142 onto C135-92. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 13.5" hole to the surface casing point as per the directional plan (LWD Program: GR). / 4. Run and cement 10-3/4" surface casing to surface. Notify Engineer and AOGCC if cement not to surface. ✓ 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 3500 psi high (24 hr. AOGCC notice). 7. Pick up and run in hole with 9-7/8" x 11" drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3500 psi for 30 minutes. 9. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. Submit LOT/FIT to AOGCC. 10. 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 (I "Program: GR/RES). 11. Change out upper pipe rams to 7-5/8" solid bodies and test same to 3,500 psi. 12. Run 7-5/8" casing and cement to 250' TVD above the hydrocarbon bearing zones (cementing schematic attached). j��Pp,-¢ /'Cg��tS �{ czr�f Job to tldC�cG ii-�c6ven/� 13. Change upper pipe rams to 3-1/2" x 6" VBRs. 14. Test BOPE to 250 psi low/ 3,500 psi high (24 hr. AOGCC notice). 15. Pick up and run in hole with 6-1/2" drilling BHA. Log top of cement on way down with Sonic tool in memory mode. 16. Chart casing pressure test to 3500 psi for 30 minutes. 17. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 16.0 ppg. Minimum required leak -off value is 11.0 ppg EMW. 18. Drill 6-1/2" hole to section TD (LWD Program: GR/RES). 19. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC with AOGCC after download and process recorded data. CD5-92 APD Page 7 of 15 Printed. 24 -Feb -19 Applicat or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 20. Run 4-3/4" liner, set liner hanger and packer. 21. RIH with 4.5" tubing with Baker Premier production packer. 22. Space out and land hanger. 23. Pressure test hanger seals to 5000 psi. 24. Drop ball and rod to set production packer, test tubing to 4,200 psi, chart test. 25. Bleed tubing pressure to 2,200 psi and test IA to 3,850 psi, chart test. 26. Install HP-BPV and test to 2,500 psi. 27. Nipple down BOP. 28. Install tubing head adapter assembly. N/U tree and test tree to 5000 psi/10 minutes. 29. Freeze protection tubing and annulus. 30. Secure well. RDMO. CD5-92 APD Page 8 of 15 Printed. 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 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 CD5-92 will be injected into a permitted surface casing x production casing annulus on CD5. The CD5-92 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. Significant hydrocarbon zones include only the Alpine and Kuparuk sand based on pre -drill interpretations. There will be 500' of cement placed above the top of the Kuparuk reservoir. Once CD5-92 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,207') + 1,500 psi = 2,877 psi Pore Pressure = 1,049 psi Therefore Differential = 2,877 — 1,049 = 1,828 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 10-3/4" 45.5 L-80 3 TXP/BTCM 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 TXP 4790 psi 4071 psi 6890 psi 5856 psi CD5-92 APD Page 9 of 15 Printed: 24 -Feb -19 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan Applica 'or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 CD5-92 APD Page 10 of 15 Printed: 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 Attachment 1 — Cement Summary CD5-92 wp04 Cementinjj Prolzram: CD5-92 wp05 Schematic 20" 94# H-40 Welded Conductor to 115' 13-1/2" Hole 9-7/8" x 11" Hole Albian 97 5,625' MD / 4,291' TVD Kuparuk C 11,388' MD / 7,291' TVD Alpine C 11,879' MD / 7,444' TVD 10-3/4" 45.5# L-80 TXP/BTCM 2,267' MD / 2,207' TVD @ 281 inc. Top of Cement 10,900' MD / 7,041 TVD 250' TVD above C 7-5/8" 29.7 L-80 TXP Casing 12,459' MD /'7,493 TVD @ 87- ......... ... Alpine A i 12,383' MD / 7,490' TVD i 6-1/2" Hole MD/ 7,373,@.90.5° CD5-92 APD Page 11 of 15 Printed: 24 -Feb -19 Applical or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 10.75" Surface Casing run to 2,267' MD / 2,207' TVD Cement from 2267' MD to 1767'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1767' 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 1,726' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (115'- 41� X 1.364 ft3/ft X 1.0 (0% excess) = 100 ft3 Permafrost to Conductor (1,350'- 125 X 0.3637 ft3/ft X 3.5 (250% excess) = 1,571 ft3 Top of Tail to Permafrost (1,767'- 1,350') X 0.3637 ft3/ft X 1.5 (50% excess) = 227 ft3 Total Volume = 100 + 1,571 + 227 = 1,900 ft3 => 984 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,267' MD to 1,726' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,267'-1,762) 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 Casing run to 12,459' MD / 7,493' TVD Top of slurry is designed to be at 10,900' MD, which is 250' TVD above the prognosis shallowest hydrocarbon bearing zone Kuparuk C. Assume 40% excess annular volume. * 1 1" Under reamer is 80' above the 9-7/8" bit. Tail slurry from 12,441' MD to 10,900' MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8" Hole (12,459'- 12,379 X 0.2148 ft3/ft X 1.40 (40% excess) = 24 ft3 11" Hole to to Top of Cement (12,379'- 10,900 X 0.3428 ft3/ft X 1.40 (40% excess) = 709 ft3 Shoe Joint (80') X 0.2578 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 24+ 709 + 21 = 754 ft3 => 650 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk CD5-92 APD Page 12 of 15 Printed: 24 -Feb -19 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 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 Miti ation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased Gas Hydrates Low mud viscosity, increased circulating times, controlled drilling rates, Abnormal Reservoir Pressure Low low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use Hydrogen Sulfide gas Low weighted sweeps. Reduced pump rates, mud rheology, lost circulation material, use of Lost Circulation Low low density cement slurries 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level I Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low 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 Low Well control drills, increased mud weight. No mapped faults occur Abnormal Reservoir Pressure Low H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low across the path of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers 6-1/4" Open Hole Production Interval Event Risk Level I Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low 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 Low Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers CD5-92 APD Page 13 of 15 Printed: 24 -Feb -19 Applicat )r Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 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: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. 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. CD5-92 APD Page 14 of 15 Printed: 24 -Feb -19 Attachment 3 — Completion Schematic CD5 — 92 Alpine A Producer Schematic Draft wp5 Applica or Permit to Drill, Well CRU CD5-92 Saved: 24 -Feb -19 Camco KBMG GLM, 3%"x1" Camco KBMG GLM, 3%"x1" 7 5/8" 29.7/39# L-80 BTCM Intermediate Casing 12,459' 3-'/2" 9.3# EUE L-80 Production Tubing 12,309' Production Packer above Alpine A sand 12,309 SLB Downhole Gauge o 2.813" XN Nipple ZXP Liner Top Packer and Hanger 12,309' MD 4-%" 12.6# L-80 Hyd563 Production Liner 28, 738' MD ------------------------------------! 6 1/2" Hole TD 28,738' MD CD5-92 APD Page 15 of 15 Printed: 24 -Feb -19 Upper Completion: Length 20" 94# H-40 Welded 1) 4-%" 12.6#/ft HYD563 Tubing (1 its) Ilk Conductor to 115' XO to V/2" EUE tubing 2) Shallow 2.813" X nipple profile 3) 3-Y�" x 1"Camco KBMG GLM (xx°) w/ DV 7' 4) 3-'/2" x 1"Camco KBMG GLM (xx°) w/ DV 7' 4) 3-'/2" x 1" Camco KBMG GLM (xx°) w/DCK2 7' 10-3/4" 45.5# L-80 pinned for 2500 psi casing to tbg shear TXP/BTC 5) BHP Gauge, Encapsulated I -Wire 1.5' Surface Casing w/cannon clamps on every joint cemented to surface 6) Baker Premier Packer 7) XN nipple 2.812" ID 1.5' 2.813" X Nipple 8) WLEG Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-%" Hyd563 pin 10) 4 ''/z", 12.6#/ft, L-80 Hyd563 Liner Camco KBMG GLM, w/ 12 ball actuated frac ports every until 21,700' MD 3'/:„ x 1" Camco KBMG GLM, 3%"x1" Camco KBMG GLM, 3%"x1" 7 5/8" 29.7/39# L-80 BTCM Intermediate Casing 12,459' 3-'/2" 9.3# EUE L-80 Production Tubing 12,309' Production Packer above Alpine A sand 12,309 SLB Downhole Gauge o 2.813" XN Nipple ZXP Liner Top Packer and Hanger 12,309' MD 4-%" 12.6# L-80 Hyd563 Production Liner 28, 738' MD ------------------------------------! 6 1/2" Hole TD 28,738' MD CD5-92 APD Page 15 of 15 Printed: 24 -Feb -19 15:59, February 22 2019 1 CD5-92 wp05 ermit Pack plan Summar, T 10 3/4 x 13-1/2 j 7-5/8 x 9-7/8 by 11 Q3 5 - 20 x 4,T-- m 4-1/2 x 6-3/4 .. o 0 0 5625 11250 16875 22500 28125 Measured Depth 20 x 42 hecked by o $. Plan: D142 39.4 + 33.9 @ 73.30usf S. Del -app CL Z��O o 10-3/4 x 13-1/2 J. Ryan o bo � a� 7-5/8 x 9-7/8 by 11 4-1/2 x 6-3/ � 0 6 $ WA W V u1 O N V 0 O O O D v4 (128 39 -750 0 3500 7000 10500 14000 17500 21000 24500 330 30 750 - 940 Horizontal Departure 940 - 1140 nao - 1330 330 - 1520 a D5 9 03 1wp01 v3 (F 7) - curr t 5-89wp FWK-6) -ane - 1720 300 6720 cD 05 1510 �55 CD5-95wp v r 1910 - 2100 2100 - 3210 l 3 3210 4330 2 '. 4330 5440 CD5-94P 5440 - 6550 028 Equivalent Magnetic Distance i 70 90 6550 - 7660 - , r ,,. ,_. _. _ `, '• - ,�._• FWK-7)-curre - 8770 CD5-93 9890 N - 9890 11000 U 11000 13220 Q 5-97 400 800 1200 1600 2000 2400 2800 240 -1220 13220 15430 15430 17650 17650 - 19870 Measured Depth D5-96 01 p ) 19870 - 22090 SURVEY PHCXiHAM Surface Location _ 22090 24300 Depth From Depth To Survey/Plan Tool North / Y: East / X: _ D5.95wpo1 A.) curve 24300 -"'- 26520 39.40 1000.00 CD5-92 wp05 (CD5-92) MWD OWSG 39.40 2240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS pad Elevation: 33.90 D 94 12A 1 01 v3 (13A 26520 28738 2240.00 3740.00 CD5-92 wp05 (CD5-92) MWD OWSG TVD MD Name 2240.0012450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 118.40 118.40 20 x 42 12450.0013950.00 CD5-92 wpO5 (CDS-92) MWD OWSG 12450.00 28738.16 CD5-92wp05(CDS92) MWD+IFR2+SAG+MS 3- 2188.30 2245.93 10-314 x 13-1 /2 Ma Magnetic Model &Date: BGGM2018 30 -Apr -19 7493.30 12459.687-5/8x9-7/8 11 Magnetic North is 16.161 East of True North (Magnetic Declination) 7373.30 28738.16 4-1/2 x 6-3/4 Magnetic Dip & Field Strength: 80.73° 57379nT Sec MD Inc Azi TVD +N/ -S +EI -W Dleg TFace VSect Target Annotation 1 39.40 0.00 0.00 39.40 0.00 0.00 0.00 0.00 0.00 Lithology, Column 2 750.00 0.00 0.00 750.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 330° TF, far 300' 3 1050.00 4.50 330.00 1049.69 10.20 -5.89 1.50 330.00 11.77 Start 2-/100' DLS, 0' TF, for 1195.93' 4 2245.93 28.42 330.00 2188.30 301.52 -174.08 2.00 0.00 347.95 Hold for 20' 5 2265.93 28.42 330.00 2205.89 309.76 -178.84 0.00 0.00 357.47 Start 2-/100' DLS, -24.7° TF, for 1571.09' i3za.a 6 3837.02 58.32 315.17 3337.79 1128.23 -854.12 2.00 -24.70 1397.15 Hold for 7318.22' 711155.24 58.32 315.17 7180.71 5544.86 -5245.21 0.00 0.00 7358.30 Start 3°I100' DLS, 19.86° TF, for 1004.45' Permafrost Ba: 812159.68 87.00 325.00 7477.60 6275.71 -5848.18 3.00 19.86 8286.68 Hold for 300' 912459.68 87.00 325.00 7493.30 6521.12 -6020.02 0.00 0.00 8584.04 CD5-92 (11 A) T01 Heel 121418 Adjust TF to 0°, for 20' 2sez.3 1012479.68 87.00 325.00 7494.35 6537.48 -6031.48 0.00 0.00 8603.86 Start 2°/100' DLS, 63.75° TF, for 390.58' 11 12870.26 90.47 332.00 7502.98 6870.18 -6235.32 2.00 63.75 8993.32 Hold for 15867.9' 1228738.16 90.47 332.00 7373.30 20880.52 -13684.07 0.00 0.0024860.69 CD5-92 (11 A) T02 Toe Update 0110fnH8738.16' MD, 7373.3' TVD C-30 3710 n . 3 395 . K-2 4291.3 Albian 97 Fails AC against CD5-91 and CD5-98 5231.3 TCR required Albian 96 3Q . C 189 By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.1 approve 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. repared by hecked by ccepted by Approved by: S. Del -app V. Osara I J. Ryan A. Donat 8:52 Jangary 16 2019 CD5-92 wp05 39.40 To 28738.16 Spider e p a ion emptation 1 CD5-92 wp05 CD5-23 CD2 -11 CD5-09 CD5-2 ?CD5- 2 CD5-02A CD5 3 C CD 7 O cm c CD5-02 t r Z 5-04 CD 10 Nuiqsut 1 CD4 -07 314 D5-21 D5- 9A ro CD5- Easting (5000 usft/in) CD5-92 wp05 _1 Plan Vmew While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 06. 22500 D5-92 (11A) T02 Toe Update JH y.9`LQ C 011019 C, 00 4-1/2 x 6-3/4 013 2g 000 2600ll 00 18000 260 0 20000 23 000 22 000 21 00 T3500 200 0 i �g0000 z �g0 00 ��00 .c 1600 0 9000 7E9000— U) 11N000 CD5-92 (11A) T01 Heel 1214 8 0 0 7-5/8 x 9-7/8 by 11_00000 0 NN O X00 00 4500 O0 000 0 0 �0p 00 X00 00 h0 00 �O 000 ®®® 0 10-3/4 x 13-1/2 20 x 42 -22500 -18000 -13500 -9000 -4500 0 4500 9000 West( -)/East(+) C D5-92 wp05 Section View -3500- Permafrost Base C-30 0 20 x 42 KOO KX3 Lian 97 a � ��0p00 Albian 96 o 10-3/4 o 13-1/2 5 0 _ x 0o b� H RZ 3500 �4 Kalubik 000 o LCU n 0 Kuparuk C Uju `?t' o0 0o o Alpine C CO ry 0O oo Q+ Alpine A a 0 7000 (OJT --------------------------- - -- O O O O O O C:) O ® O O �' O O - J' - CO' C6 - - O O -.4 - - - - O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O, O O O O 7-5/8 x 9-7/8 by 11 4-1/2 x 6-3/4 10500- 0 3500 7000 10500 14000 17500 21000 24500 Vertical Section at 332.00° ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: C135-92 - Slot 92 50103xxxxx00 CD5-92 Plan: C135-92 wp05 Standard Proposal Report 23 February, 2019 ConocoPhillips ConocoPhillips philli Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 0 TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD5 Alpine West Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: Well Plan: CD5-92 - Slot 92 Well Position +N/ -S 186.39 usft Northing: Latitude: +E/ -W 470.87 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: Wellbore CD5-92 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 4/30/2019 16.16 80.73 57,379 Design CD5-92 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.40 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.40 0.00 0.00 332.00 2123/2019 11:53:44AM Page 2 COMPASS 5000.14 Build 85D Plan Survey Tool Program Date 2/22/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.40 1,000.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard j 2 39.40 2,240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + � 3 2,240.00 3,740.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard 4 2,240.00 12,450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A 5 12,450.00 13,950.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard 6 12,450.00 28,738.16 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A 2123/2019 11:53:44AM Page 2 COMPASS 5000.14 Build 85D ConocoPhilli s p Database: OAKEDMP1 Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Project: Western North Slope MD Reference: Site: CD5 Alpine West Pad North Reference: Well: Plan: CD5-92 Survey Calculation Method: Wellbore: CD5-92 Turn Rate Rate Rate Design: CD5-92 wp05 0.00 0.00 0.00 Plan Sections 0.00 0.00 1.50 1.50 0.00 Measured 2.00 0.00 Vertical 0.00 0.00 Depth Inclination Azimuth Depth +N/ -S +E/ -W (usft) (°) (°) (usft) (usft) (usft) 39.40 0.00 0.00 39.40 0.00 0.00 750.00 0.00 0.00 750.00 0.00 0.00 1,050.00 4.50 330.00 1,049.69 10.20 -5.89 2,245.93 28.42 330.00 2,188.30 301.52 -174.08 2,265.93 28.42 330.00 2,205.89 309.76 -178.84 3,837.02 58.32 315.17 3,337.79 1,128.23 -854.12 11,155.24 58.32 315.17 7,180.71 5,544.86 -5,245.21 12,159.68 87.00 325.00 7,477.60 6,275.71 -5,848.18 12,459.68 87.00 325.00 7,493.30 6,521.12 -6,020.02 12,479.68 87.00 325.00 7,494.35 6,537.48 -6,031.48 12,870.26 90.47 332.00 7,502.98 6,870.18 -6,235.32 28,738.16 90.47 332.00 7,373.30 20,880.52 -13,684.07 ConocoPhillips Standard Proposal Report Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) Tru e Minimum Curvature Dogleg Build Turn Rate Rate Rate (°/100usft) (°/100usft) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 0.00 2.00 2.00 0.00 0.00 0.00 0.00 2.00 1.90 -0.94 0.00 0.00 0.00 3.00 2.85 0.98 0.00 0.00 0.00 0.00 0.00 0.00 2.00 0.89 1.79 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 330.00 0.00 0.00 -24.70 0.00 19.86 0.00 CD5-92 (11 A) T01 He 0.00 63.75 0.00 CD5-92 (11A) T02 Too 2/23/2019 11:53:44AM Page 3 COMPASS 5000.14 Build 85D i ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP1 ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 CD5-92 CD5-92 wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI -S +E/ -W Section Rate Rate Rate (usft) C) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (`/100usft) 39.40 0.00 0.00 39.40 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 750.00 0.00 0.00 750.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.75 330.00 800.00 0.28 -0.16 0.33 1.50 1.50 0.00 900.00 2.25 330.00 899.96 2.55 -1.47 2.94 1.50 1.50 0.00 1,000.00 3.75 330.00 999.82 7.08 -4.09 8.17 1.50 1.50 0.00 1,050.00 4.50 330.00 1,049.69 10.20 -5.89 11.77 1.50 1.50 0.00 1,100.00 5.50 330.00 1,099.50 13.97 -8.07 16.12 2.00 2.00 0.00 1,200.00 7.50 330.00 1,198.85 23.77 -13.73 27.44 2.00 2.00 0.00 1,300.00 9.50 330.00 1,297.75 36.57 -21.12 42.21 2.00 2.00 0.00 1,400.00 11.50 330.00 1,396.07 52.36 -30.23 60.42 2.00 2.00 0.00 1,500.00 13.50 330.00 1,493.69 71.10 -41.05 82.05 2.00 2.00 0.00 1,600.00 15.50 330.00 1,590.50 92.78 -53.57 107.07 2.00 2.00 0.00 1,700.00 17.50 330.00 1,686.38 117.38 -67.77 135.45 2.00 2.00 0.00 1,800.00 19.50 330.00 1,781.21 144.85 -83.63 167.16 2.00 2.00 0.00 1,900.00 21.50 330.00 1,874.87 175.18 -101.14 202.16 2.00 2.00 0.00 2,000.00 23.50 330.00 1,967.25 208.32 -120.27 240.40 2.00 2.00 0.00 2,100.00 25.50 330.00 2,058.25 244.23 -141.01 281.84 2.00 2.00 0.00 2,200.00 27.50 330.00 2,147.74 282.87 -163.32 326.43 2.00 2.00 0.00 2,245.93 28.42 330.00 2,188.30 301.52 -174.08 347.95 2.00 2.00 0.00 2,265.93 28.42 330.00 2,205.89 309.76 -178.84 357.47 0.00 0.00 0.00 2,300.00 29.04 329.41 2,235.77 323.90 -187.10 373.83 2.00 1.82 -1.72 2,400.00 30.87 327.82 2,322.41 366.52 -213.12 423.67 2.00 1.83 -1.60 2,500.00 32.73 326.38 2,407.40 410.75 -241.76 476.16 2.00 1.85 -1.43 2,600.00 34.59 325.09 2,490.63 456.54 -272.97 531.25 2.00 1.87 -1.30 2,700.00 36.47 323.91 2,572.01 503.84 -306.73 588.86 2.00 1.88 -1.18 2,800.00 38.36 322.83 2,651.43 552.58 -342.99 648.93 2.00 1.89 -1.08 2,900.00 40.26 321.84 2,728.80 602.72 -381.71 711.37 2.00 1.90 -0.99 3,000.00 42.17 320.92 2,804.02 654.19 -422.83 776.12 2.00 1.91 -0.92 3,100.00 44.08 320.07 2,877.01 706.92 -466.32 843.10 2.00 1.91 -0.85 3,200.00 46.00 319.27 2,947.67 760.86 -512.12 912.22 2.00 1.92 -0.79 3,300.00 47.92 318.53 3,015.91 815.93 -560.17 983.40 2.00 1.92 -0.74 3,400.00 49.85 317.83 3,081.66 872.07 -610.41 1,056.56 2.00 1.93 -0.70 3,500.00 51.79 317.17 3,144.84 929.21 -662.78 1,131.60 2.00 1.93 -0.66 3,600.00 53.72 316.54 3,205.36 987.28 -717.22 1,208.43 2.00 1.94 -0.63 3,700.00 55.66 315.94 3,263.16 1,046.21 -773.66 1,286.96 2.00 1.94 -0.60 3,800.00 57.60 315.37 3,318.15 1,105.94 -832.04 1,367.10 2.00 1.94 -0.57 3,837.02 58.32 315.17 3,337.79 1,128.23 -854.12 1,397.15 2.00 1.94 -0.55 3,900.00 58.32 315.17 3,370.86 1,166.24 -891.91 1,448.45 0.00 0.00 0.00 4,000.00 58.32 315.17 3,423.37 1,226.59 -951.91 1,529.91 0.00 0.00 0.00 4,100.00 58.32 315.17 3,475.89 1,286.94 -1,011.92 1,611.37 0.00 0.00 0.00 4,200.00 58.32 315.17 3,528.40 1,347.29 -1,071.92 1,692.82 0.00 0.00 0.00 4,300.00 58.32 315.17 3,580.91 1,407.64 -1,131.92 1,774.28 0.00 0.00 0.00 4,400.00 58.32 315.17 3,633.42 1,467.99 -1,191.92 1,855.74 0.00 0.00 0.00 4,500.00 58.32 315.17 3,685.93 1,528.35 -1,251.92 1,937.19 0.00 0.00 0.00 4,600.00 58.32 315.17 3,738.45 1,588.70 -1,311.93 2,018.65 0.00 0.00 0.00 4,700.00 58.32 315.17 3,790.96 1,649.05 -1,371.93 2,100.10 0.00 0.00 0.00 4,800.00 58.32 315.17 3,843.47 1,709.40 -1,431.93 2,181.56 0.00 0.00 0.00 2123/2019 11:53:44AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 4,900.00 5,000.00 5,100.00 5,200.00 5,300.00 5,400.00 5,500.00 5,600.00 5,700.00 5,800.00 5,900.00 6,000.00 6,100.00 6,200.00 6,300.00 6,400.00 6,500.00 6,600.00 6,700.00 6,800.00 6,900.00 7,000.00 7,100.00 7,200.00 7,300.00 7,400.00 7,500.00 7,600.00 7,700.00 7,800.00 7,900.00 8,000.00 8,100.00 8,200.00 8,300.00 8,400.00 8,500.00 8,600.00 8,700.00 8,800.00 8,900.00 9,000.00 9,100.00 9,200.00 9,300.00 9,400.00 9,500.00 9,600.00 9,700.00 9,800.00 9,900.00 10,000.00 10,100.00 OAKEDMPI ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 CD5-92 CD5-92 wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature Vertical Dogleg Vertical Turn Section Inclination Azimuth Depth +N/ -S +E/ -W (°) (°) (usft) (usft) (usft) 58.32 315.17 3,895.98 1,769.75 -1,491.93 58.32 315.17 3,948.49 1,830.10 -1,551.93 58.32 315.17 4,001.00 1,890.45 -1,611.94 58.32 315.17 4,053.52 1,950.80 -1,671.94 58.32 315.17 4,106.03 2,011.16 -1,731.94 58.32 315.17 4,158.54 2,071.51 -1,791.94 58.32 315.17 4,211.05 2,131.86 -1,851.94 58.32 315.17 4,263.56 2,192.21 -1,911.95 58.32 315.17 4,316.07 2,252.56 -1,971.95 58.32 315.17 4,368.59 2,312.91 -2,031.95 58.32 315.17 4,421.10 2,373.26 -2,091.95 58.32 315.17 4,473.61 2,433.61 -2,151.96 58.32 315.17 4,526.12 2,493.96 -2,211.96 58.32 315.17 4,578.63 2,554.32 -2,271.96 58.32 315.17 4,631.14 2,614.67 -2,331.96 58.32 315.17 4,683.66 2,675.02 -2,391.96 58.32 315.17 4,736.17 2,735.37 -2,451.97 58.32 315.17 4,788.68 2,795.72 -2,511.97 58.32 315.17 4,841.19 2,856.07 -2,571.97 58.32 315.17 4,893.70 2,916.42 -2,631.97 58.32 315.17 4,946.21 2,976.77 -2,691.97 58.32 315.17 4,998.73 3,037.13 -2,751.98 58.32 315.17 5,051.24 3,097.48 -2,811.98 58.32 315.17 5,103.75 3,157.83 -2,871.98 58.32 315.17 5,156.26 3,218.18 -2,931.98 58.32 315.17 5,208.77 3,278.53 -2,991.99 58.32 315.17 5,261.29 3,338.88 -3,051.99 58.32 315.17 5,313.80 3,399.23 -3,111.99 58.32 315.17 5,366.31 3,459.58 -3,171.99 58.32 315.17 5,418.82 3,519.93 -3,231.99 58.32 315.17 5,471.33 3,580.29 -3,292.00 58.32 315.17 5,523.84 3,640.64 -3,352.00 58.32 315.17 5,576.36 3,700.99 -3,412.00 58.32 315.17 5,628.87 3,761.34 -3,472.00 58.32 315.17 5,681.38 3,821.69 -3,532.00 58.32 315.17 5,733.89 3,882.04 -3,592.01 58.32 315.17 5,786.40 3,942.39 -3,652.01 58.32 315.17 5,838.91 4,002.74 -3,712.01 58.32 315.17 5,891.43 4,063.09 -3,772.01 58.32 315.17 5,943.94 4,123.45 -3,832.01 58.32 315.17 5,996.45 4,183.80 -3,892.02 58.32 315.17 6,048.96 4,244.15 -3,952.02 58.32 315.17 6,101.47 4,304.50 -4,012.02 58.32 315.17 6,153.98 4,364.85 -4,072.02 58.32 315.17 6,206.50 4,425.20 -4,132.03 58.32 315.17 6,259.01 4,485.55 -4,192.03 58.32 315.17 6,311.52 4,545.90 -4,252.03 58.32 315.17 6,364.03 4,606.26 -4,312.03 58.32 315.17 6,416.54 4,666.61 -4,372.03 58.32 315.17 6,469.06 4,726.96 -4,432.04 58.32 315.17 6,521.57 4,787.31 -4,492.04 58.32 315.17 6,574.08 4,847.66 -4,552.04 58.32 315.17 6,626.59 4,908.01 -4,612.04 58.32 315.17 6,679.10 4,968.36 -4,672.04 ConocoPhillips Standard Proposal Report Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature Vertical Dogleg Build Turn Section Rate Rate Rate (usft) (°/100usft) (°/100usft) (°/100usft) 2,263.02 0.00 0.00 0.00 2,344.47 0.00 0.00 0.00 2,425.93 0.00 0.00 0.00 2,507.39 0.00 0.00 0.00 2,588.84 0.00 0.00 0.00 2,670.30 0.00 0.00 0.00 2,751.75 0.00 0.00 0.00 2,833.21 0.00 0.00 0.00 2,914.67 0.00 0.00 0.00 2,996.12 0.00 0.00 0.00 3,077.58 0.00 0.00 0.00 3,159.03 0.00 0.00 0.00 3,240.49 0.00 0.00 0.00 3,321.95 0.00 0.00 0.00 3,403.40 0.00 0.00 0.00 3,484.86 0.00 0.00 0.00 3,566.32 0.00 0.00 0.00 3,647.77 0.00 0.00 0.00 3,729.23 0.00 0.00 0.00 3,810.68 0.00 0.00 0.00 3,892.14 0.00 0.00 0.00 3,973.60 0.00 0.00 0.00 4,055.05 0.00 0.00 0.00 4,136.51 0.00 0.00 0.00 4,217.97 0.00 0.00 0.00 4,299.42 0.00 0.00 0.00 4,380.88 0.00 0.00 0.00 4,462.33 0.00 0.00 0.00 4,543.79 0.00 0.00 0.00 4,625.25 0.00 0.00 0.00 4,706.70 0.00 0.00 0.00 4,788.16 0.00 0.00 0.00 4,869.62 0.00 0.00 0.00 4,951.07 0.00 0.00 0.00 5,032.53 0.00 0.00 0.00 5,113.98 0.00 0.00 0.00 5,195.44 0.00 0.00 0.00 5,276.90 0.00 0.00 0.00 5,358.35 0.00 0.00 0.00 5,439.81 0.00 0.00 0.00 5,521.26 0.00 0.00 0.00 5,602.72 0.00 0.00 0.00 5,684.18 0.00 0.00 0.00 5,765.63 0.00 0.00 0.00 5,847.09 0.00 0.00 0.00 5,928.55 0.00 0.00 0.00 6,010.00 0.00 0.00 0.00 6,091.46 0.00 0.00 0.00 6,172.91 0.00 0.00 0.00 6,254.37 0.00 0.00 0.00 6,335.83 0.00 0.00 0.00 6,417.28 0.00 0.00 0.00 6,498.74 0.00 0.00 0.00 6,580.20 0.00 0.00 0.00 2/23/2019 11:53:44AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 10,300.00 10,400.00 10,500.00 10,600.00 10,700.00 10,800.00 10,900.00 11, 000.00 11,100.00 11,155.24 11,200.00 11,300.00 11,400.00 11, 500.00 11,600.00 11,700.00 11,800.00 11, 900.00 12,000.00 12,100.00 12,159.68 12,200.00 12,300.00 12,400.00 12,459.68 12,479.68 12,500.00 12,600.00 12,700.00 12,800.00 12,870.26 12,900.00 13,000.00 13,100.00 13,200.00 13,300.00 13,400.00 13,500.00 13,600.00 13,700.00 13,800.00 13,900.00 14,000.00 14,100.00 14,200.00 14,300.00 14,400.00 14,500.00 14,600.00 14,700.00 14,800.00 14,900.00 15,000.00 15,100.00 2/23/2019 11:53:44AM OAKEDMPI ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 CD5-92 CD5-92 wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) North Reference: True Survey Calculation Method: Minimum Curvature Page 6 Vertical Dogleg Vertical Turn Section Inclination Azimuth Depth +N/ -S +E/ -W (°) (°) (usft) (usft) (usft) 58.32 315.17 6,731.61 5,028.71 -4,732.05 58.32 315.17 6,784.13 5,089.06 -4,792.05 58.32 315.17 6,836.64 5,149.42 -4,852.05 58.32 315.17 6,889.15 5,209.77 -4,912.05 58.32 315.17 6,941.66 5,270.12 -4,972.06 58.32 315.17 6,994.17 5,330.47 -5,032.06 58.32 315.17 7,046.68 5,390.82 -5,092.06 58.32 315.17 7,099.20 5,451.17 -5,152.06 58.32 315.17 7,151.71 5,511.52 -5,212.06 58.32 315.17 7,180.71 5,544.86 -5,245.21 59.59 315.70 7,203.80 5,572.18 -5,272.12 62.42 316.83 7,252.27 5,635.38 -5,332.57 65.26 317.91 7,296.36 5,701.41 -5,393.35 68.11 318.94 7,335.93 5,770.10 -5,454.28 70.96 319.92 7,370.90 5,841.26 -5,515.20 73.82 320.88 7,401.15 5,914.70 -5,575.94 76.68 321.81 7,426.61 5,990.21 -5,636.34 79.55 322.71 7,447.20 6,067.59 -5,696.22 82.42 323.60 7,462.87 6,146.62 -5,755.43 85.29 324.48 7,473.58 6,227.09 -5,813.81 87.00 325.00 7,477.60 6,275.71 -5,848.18 87.00 325.00 7,479.71 6,308.69 -5,871.28 87.00 325.00 7,484.94 6,390.50 -5,928.56 87.00 325.00 7,490.18 6,472.30 -5,985.83 87.00 325.00 7,493.30 6,521.12 -6,020.02 87.00 325.00 7,494.35 6,537.48 -6,031.48 87.18 325.36 7,495.38 6,554.14 -6,043.06 88.07 327.16 7,499.53 6,637.22 -6,098.55 88.95 328.95 7,502.13 6,722.05 -6,151.44 89.84 330.74 7,503.18 6,808.51 -6,201.66 90.47 332.00 7,502.98 6,870.18 -6,235.32 90.47 332.00 7,502.74 6,896.44 -6,249.28 90.47 332.00 7,501.92 6,984.73 -6,296.23 90.47 332.00 7,501.11 7,073.02 -6,343.17 90.47 332.00 7,500.29 7,161.32 -6,390.11 90.47 332.00 7,499.47 7,249.61 -6,437.05 90.47 332.00 7,498.66 7,337.90 -6,484.00 90.47 332.00 7,497.84 7,426.20 -6,530.94 90.47 332.00 7,497.02 7,514.49 -6,577.88 90.47 332.00 7,496.20 7,602.79 -6,624.82 90.47 332.00 7,495.39 7,691.08 -6,671.76 90.47 332.00 7,494.57 7,779.37 -6,718.71 90.47 332.00 7,493.75 7,867.67 -6,765.65 90.47 332.00 7,492.93 7,955.96 -6,812.59 90.47 332.00 7,492.12 8,044.25 -6,859.53 90.47 332.00 7,491.30 8,132.55 -6,906.48 90.47 332.00 7,490.48 8,220.84 -6,953.42 90.47 332.00 7,489.67 8,309.13 -7,000.36 90.47 332.00 7,488.85 8,397.43 -7,047.30 90.47 332.00 7,488.03 8,485.72 -7,094.24 90.47 332.00 7,487.21 8,574.01 -7,141.19 90.47 332.00 7,486.40 8,662.31 -7,188.13 90.47 332.00 7,485.58 8,750.60 -7,235.07 90.47 332.00 7,484.76 8,838.90 -7,282.01 Page 6 Vertical Dogleg Build Turn Section Rate Rate Rate (usft) (°1100usft) (°1100usft) (°1100usft) 6,661.65 0.00 0.00 0.00 6,743.11 0.00 0.00 0.00 6,824.56 0.00 0.00 0.00 6,906.02 0.00 0.00 0.00 6,987.48 0.00 0.00 0.00 7,068.93 0.00 0.00 0.00 7,150.39 0.00 0.00 0.00 7,231.85 0.00 0.00 0.00 7,313.30 0.00 0.00 0.00 7,358.30 0.00 0.00 0.00 7,395.05 3.00 2.82 1.18 7,479.23 3.00 2.83 1.13 7,566.07 3.00 2.84 1.08 7,655.33 3.00 2.85 1.03 7,746.76 3.00 2.85 0.99 7,840.12 3.00 2.86 0.96 7,935.14 3.00 2.86 0.93 8,031.58 3.00 2.87 0.91 8,129.16 3.00 2.87 0.89 8,227.61 3.00 2.87 0.88 8,286.68 3.00 2.87 0.87 8,326.64 0.00 0.00 0.00 8,425.76 0.00 0.00 0.00 8,524.88 0.00 0.00 0.00 8,584.04 0.00 0.00 0.00 8,603.86 0.00 0.00 0.00 8,624.01 2.00 0.88 1.80 8,723.42 2.00 0.89 1.79 8,823.14 2.00 0.89 1.79 8,923.06 2.00 0.89 1.79 8,993.32 2.00 0.89 1.79 9,023.05 0.00 0.00 0.00 9,123.05 0.00 0.00 0.00 9,223.05 0.00 0.00 0.00 9,323.04 0.00 0.00 0.00 9,423.04 0.00 0.00 0.00 9,523.04 0.00 0.00 0.00 9,623.03 0.00 0.00 0.00 9,723.03 0.00 0.00 0.00 9,823.03 0.00 0.00 0.00 9,923.02 0.00 0.00 0.00 10,023.02 0.00 0.00 0.00 10,123.02 0.00 0.00 0.00 10,223.01 0.00 0.00 0.00 10,323.01 0.00 0.00 0.00 10,423.01 0.00 0.00 0.00 10,523.00 0.00 0.00 0.00 10,623.00 0.00 0.00 0.00 10,723.00 0.00 0.00 0.00 10,822.99 0.00 0.00 0.00 10,922.99 0.00 0.00 0.00 11,022.99 0.00 0.00 0.00 11,122.98 0.00 0.00 0.00 11,222.98 0.00 0.00 0.00 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Project: Western North Slope MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-92 Survey Calculation Method: Minimum Curvature Wellbore: CD5-92 Azimuth Depth Design: CD5-92 wp05 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (1) (usft) (usft) (usft) (usft) (°/100usft) ('1100usft) (°/100usft) 15,200.00 90.47 332.00 7,483.94 8,927.19 -7,328.96 11,322.98 0.00 0.00 0.00 15,300.00 90.47 332.00 7,483.13 9,015.48 -7,375.90 11,422.97 0.00 0.00 0.00 15,400.00 90.47 332.00 7,482.31 9,103.78 -7,422.84 11,522.97 0.00 0.00 0.00 15,500.00 90.47 332.00 7,481.49 9,192.07 -7,469.78 11,622.97 0.00 0.00 0.00 15,600.00 90.47 332.00 7,480.68 9,280.36 -7,516.72 11,722.96 0.00 0.00 0.00 15,700.00 90.47 332.00 7,479.86 9,368.66 -7,563.67 11,822.96 0.00 0.00 0.00 15,800.00 90.47 332.00 7,479.04 9,456.95 -7,610.61 11,922.96 0.00 0.00 0.00 15,900.00 90.47 332.00 7,478.22 9,545.24 -7,657.55 12,022.95 0.00 0.00 0.00 16,000.00 90.47 332.00 7,477.41 9,633.54 -7,704.49 12,122.95 0.00 0.00 0.00 16,100.00 90.47 332.00 7,476.59 9,721.83 -7,751.44 12,222.95 0.00 0.00 0.00 16,200.00 90.47 332.00 7,475.77 9,810.13 -7,798.38 12,322.94 0.00 0.00 0.00 16,300.00 90.47 332.00 7,474.95 9,898.42 -7,845.32 12,422.94 0.00 0.00 0.00 16,400.00 90.47 332.00 7,474.14 9,986.71 -7,892.26 12,522.94 0.00 0.00 0.00 16,500.00 90.47 332.00 7,473.32 10,075.01 -7,939.20 12,622.93 0.00 0.00 0.00 16,600.00 90.47 332.00 7,472.50 10,163.30 -7,986.15 12,722.93 0.00 0.00 0.00 16,700.00 90.47 332.00 7,471.69 10,251.59 -8,033.09 12,822.93 0.00 0.00 0.00 16,800.00 90.47 332.00 7,470.87 10,339.89 -8,080.03 12,922.92 0.00 0.00 0.00 16,900.00 90.47 332.00 7,470.05 10,428.18 -8,126.97 13,022.92 0.00 0.00 0.00 17,000.00 90.47 332.00 7,469.23 10,516.47 -8,173.91 13,122.92 0.00 0.00 0.00 17,100.00 90.47 332.00 7,468.42 10,604.77 -8,220.86 13,222.91 0.00 0.00 0.00 17,200.00 90.47 332.00 7,467.60 10,693.06 -8,267.80 13,322.91 0.00 0.00 0.00 17,300.00 90.47 332.00 7,466.78 10,781.36 -8,314.74 13,422.91 0.00 0.00 0.00 17,400.00 90.47 332.00 7,465.96 10,869.65 -8,361.68 13,522.90 0.00 0.00 0.00 17,500.00 90.47 332.00 7,465.15 10,957.94 -8,408.63 13,622.90 0.00 0.00 0.00 17,600.00 90.47 332.00 7,464.33 11,046.24 -8,455.57 13,722.90 0.00 0.00 0.00 17,700.00 90.47 332.00 7,463.51 11,134.53 -8,502.51 13,822.89 0.00 0.00 0.00 17,800.00 90.47 332.00 7,462.70 11,222.82 -8,549.45 13,922.89 0.00 0.00 0.00 17,900.00 90.47 332.00 7,461.88 11,311.12 -8,596.39 14,022.89 0.00 0.00 0.00 18,000.00 90.47 332.00 7,461.06 11,399.41 -8,643.34 14,122.88 0.00 0.00 0.00 18,100.00 90.47 332.00 7,460.24 11,487.70 -8,690.28 14,222.88 0.00 0.00 0.00 18,200.00 90.47 332.00 7,459.43 11,576.00 -8,737.22 14,322.88 0.00 0.00 0.00 18,300.00 90.47 332.00 7,458.61 11,664.29 -8,784.16 14,422.87 0.00 0.00 0.00 18,400.00 90.47 332.00 7,457.79 11,752.58 -8,831.11 14,522.87 0.00 0.00 0.00 18,500.00 90.47 332.00 7,456.97 11,840.88 -8,878.05 14,622.87 0.00 0.00 0.00 18,600.00 90.47 332.00 7,456.16 11,929.17 -8,924.99 14,722.86 0.00 0.00 0.00 18,700.00 90.47 332.00 7,455.34 12,017.47 -8,971.93 14,822.86 0.00 0.00 0.00 18,800.00 90.47 332.00 7,454.52 12,105.76 -9,018.87 14,922.86 0.00 0.00 0.00 18,900.00 90.47 332.00 7,453.71 12,194.05 -9,065.82 15,022.85 0.00 0.00 0.00 19,000.00 90.47 332.00 7,452.89 12,282.35 -9,112.76 15,122.85 0.00 0.00 0.00 19,100.00 90.47 332.00 7,452.07 12,370.64 -9,159.70 15,222.85 0.00 0.00 0.00 19,200.00 90.47 332.00 7,451.25 12,458.93 -9,206.64 15,322.84 0.00 0.00 0.00 19,300.00 90.47 332.00 7,450.44 12,547.23 -9,253.59 15,422.84 0.00 0.00 0.00 19,400.00 90.47 332.00 7,449.62 12,635.52 -9,300.53 15,522.84 0.00 0.00 0.00 19,500.00 90.47 332.00 7,448.80 12,723.81 -9,347.47 15,622.83 0.00 0.00 0.00 19,600.00 90.47 332.00 7,447.98 12,812.11 -9,394.41 15,722.83 0.00 0.00 0.00 19,700.00 90.47 332.00 7,447.17 12,900.40 -9,441.35 15,822.83 0.00 0.00 0.00 19,800.00 90.47 332.00 7,446.35 12,988.70 -9,488.30 15,922.82 0.00 0.00 0.00 19,900.00 90.47 332.00 7,445.53 13,076.99 -9,535.24 16,022.82 0.00 0.00 0.00 20,000.00 90.47 332.00 7,444.72 13,165.28 -9,582.18 16,122.82 0.00 0.00 0.00 20,100.00 90.47 332.00 7,443.90 13,253.58 -9,629.12 16,222.81 0.00 0.00 0.00 20,200.00 90.47 332.00 7,443.08 13,341.87 -9,676.07 16,322.81 0.00 0.00 0.00 20,300.00 90.47 332.00 7,442.26 13,430.16 -9,723.01 16,422.81 0.00 0.00 0.00 20,400.00 90.47 332.00 7,441.45 13,518.46 -9,769.95 16,522.80 0.00 0.00 0.00 20,500.00 90.47 332.00 7,440.63 13,606.75 -9,816.89 16,622.80 0.00 0.00 0.00 2/23/2019 11:53:44AM Page 7 COMPASS 5000.14 Build 85D sConocoPhillip Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 20,600.00 20,700.00 20,800.00 20,900.00 21, 000.00 21,100.00 21,200.00 21, 300.00 21,400.00 21, 500.00 21,600.00 21,700.00 21,800.00 21, 900.00 22,000.00 22,100.00 22,200.00 22,300.00 22,400.00 22,500.00 22,600.00 22,700.00 22,800.00 22,900.00 23,000.00 23,100.00 23,200.00 23,300.00 23,400.00 23,500.00 23,600.00 23,700.00 23,800.00 23,900.00 24,000.00 24,100.00 24,200.00 24,300.00 24,400.00 24,500.00 24,600.00 24,700.00 24,800.00 24,900.00 25,000.00 25,100.00 25,200.00 25,300.00 25,400.00 25, 500.00 25,600.00 25,700.00 25,800.00 25,900.00 OAKEDMP1 ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 CD5-92 CD5-92 wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) North Reference: True Survey Calculation Method: Minimum Curvature 2123/2019 11:53:44AM Page 8 COMPASS 5000.14 Build 85D Vertical Vertical Dogleg Build Turn Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (1) V) (usft) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/100usft) 90.47 332.00 7,439.81 13,695.04 -9,863.83 16,722.80 0.00 0.00 0.00 90.47 332.00 7,438.99 13,783.34 -9,910.78 16,822.79 0.00 0.00 0.00 90.47 332.00 7,438.18 13,871.63 -9,957.72 16,922.79 0.00 0.00 0.00 90.47 332.00 7,437.36 13,959.93 -10,004.66 17,022.79 0.00 0.00 0.00 90.47 332.00 7,436.54 14,048.22 -10,051.60 17,122.78 0.00 0.00 0.00 90.47 332.00 7,435.73 14,136.51 -10,098.55 17,222.78 0.00 0.00 0.00 90.47 332.00 7,434.91 14,224.81 -10,145.49 17,322.78 0.00 0.00 0.00 90.47 332.00 7,434.09 14,313.10 -10,192.43 17,422.77 0.00 0.00 0.00 90.47 332.00 7,433.27 14,401.39 -10,239.37 17,522.77 0.00 0.00 0.00 90.47 332.00 7,432.46 14,489.69 -10,286.31 17,622.77 0.00 0.00 0.00 90.47 332.00 7,431.64 14,577.98 -10,333.26 17,722.76 0.00 0.00 0.00 90.47 332.00 7,430.82 14,666.27 -10,380.20 17,822.76 0.00 0.00 0.00 90.47 332.00 7,430.00 14,754.57 -10,427.14 17,922.76 0.00 0.00 0.00 90.47 332.00 7,429.19 14,842.86 -10,474.08 18,022.75 0.00 0.00 0.00 90.47 332.00 7,428.37 14,931.16 -10,521.03 18,122.75 0.00 0.00 0.00 90.47 332.00 7,427.55 15,019.45 -10,567.97 18,222.75 0.00 0.00 0.00 90.47 332.00 7,426.74 15,107.74 -10,614.91 18,322.74 0.00 0.00 0.00 90.47 332.00 7,425.92 15,196.04 -10,661.85 18,422.74 0.00 0.00 0.00 90.47 332.00 7,425.10 15,284.33 -10,708.79 18,522.74 0.00 0.00 0.00 90.47 332.00 7,424.28 15,372.62 -10,755.74 18,622.73 0.00 0.00 0.00 90.47 332.00 7,423.47 15,460.92 -10,802.68 18,722.73 0.00 0.00 0.00 90.47 332.00 7,422.65 15,549.21 -10,849.62 18,822.73 0.00 0.00 0.00 90.47 332.00 7,421.83 15,637.50 -10,896.56 18,922.72 0.00 0.00 0.00 90.47 332.00 7,421.01 15,725.80 -10,943.51 19,022.72 0.00 0.00 0.00 90.47 332.00 7,420.20 15,814.09 -10,990.45 19,122.72 0.00 0.00 0.00 90.47 332.00 7,419.38 15,902.38 -11,037.39 19,222.71 0.00 0.00 0.00 90.47 332.00 7,418.56 15,990.68 -11,084.33 19,322.71 0.00 0.00 0.00 90.47 332.00 7,417.75 16,078.97 -11,131.27 19,422.71 0.00 0.00 0.00 90.47 332.00 7,416.93 16,167.27 -11,178.22 19,522.70 0.00 0.00 0.00 90.47 332.00 7,416.11 16,255.56 -11,225.16 19,622.70 0.00 0.00 0.00 90.47 332.00 7,415.29 16,343.85 -11,272.10 19,722.70 0.00 0.00 0.00 90.47 332.00 7,414.48 16,432.15 -11,319.04 19,822.69 0.00 0.00 0.00 90.47 332.00 7,413.66 16,520.44 -11,365.98 19,922.69 0.00 0.00 0.00 90.47 332.00 7,412.84 16,608.73 -11,412.93 20,022.69 0.00 0.00 0.00 90.47 332.00 7,412.02 16,697.03 -11,459.87 20,122.68 0.00 0.00 0.00 90.47 332.00 7,411.21 16,785.32 -11,506.81 20,222.68 0.00 0.00 0.00 90.47 332.00 7,410.39 16,873.61 -11,553.75 20,322.68 0.00 0.00 0.00 90.47 332.00 7,409.57 16,961.91 -11,600.70 20,422.67 0.00 0.00 0.00 90.47 332.00 7,408.75 17,050.20 -11,647.64 20,522.67 0.00 0.00 0.00 90.47 332.00 7,407.94 17,138.50 -11,694.58 20,622.67 0.00 0.00 0.00 90.47 332.00 7,407.12 17,226.79 -11,741.52 20,722.66 0.00 0.00 0.00 90.47 332.00 7,406.30 17,315.08 -11,788.46 20,822.66 0.00 0.00 0.00 90.47 332.00 7,405.49 17,403.38 -11,835.41 20,922.66 0.00 0.00 0.00 90.47 332.00 7,404.67 17,491.67 -11,882.35 21,022.65 0.00 0.00 0.00 90.47 332.00 7,403.85 17,579.96 -11,929.29 21,122.65 0.00 0.00 0.00 90.47 332.00 7,403.03 17,668.26 -11,976.23 21,222.65 0.00 0.00 0.00 90.47 332.00 7,402.22 17,756.55 -12,023.18 21,322.64 0.00 0.00 0.00 90.47 332.00 7,401.40 17,844.84 -12,070.12 21,422.64 0.00 0.00 0.00 90.47 332.00 7,400.58 17,933.14 -12,117.06 21,522.64 0.00 0.00 0.00 90.47 332.00 7,399.76 18,021.43 -12,164.00 21,622.63 0.00 0.00 0.00 90.47 332.00 7,398.95 18,109.73 -12,210.94 21,722.63 0.00 0.00 0.00 90.47 332.00 7,398.13 18,198.02 -12,257.89 21,822.63 0.00 0.00 0.00 90.47 332.00 7,397.31 18,286.31 -12,304.83 21,922.62 0.00 0.00 0.00 90.47 332.00 7,396.50 18,374.61 -12,351.77 22,022.62 0.00 0.00 0.00 2123/2019 11:53:44AM Page 8 COMPASS 5000.14 Build 85D 2/23/2019 11:53:44AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Project: Western North Slope MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-92 Survey Calculation Method: Minimum Curvature Wellbore: CD5-92 Design: CD5-92 wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (1) (°) (usft) (usft) (usft) (usft) (°I100usft) (°I100usft) (°1100usft) 26,000.00 90.47 332.00 7,395.68 18,462.90 -12,398.71 22,122.62 0.00 0.00 0.00 26,100.00 90.47 332.00 7,394.86 18,551.19 -12,445.66 22,222.61 0.00 0.00 0.00 26,200.00 90.47 332.00 7,394.04 18,639.49 -12,492.60 22,322.61 0.00 0.00 0.00 26,300.00 90.47 332.00 7,393.23 18,727.78 -12,539.54 22,422.61 0.00 0.00 0.00 26,400.00 90.47 332.00 7,392.41 18,816.07 -12,586.48 22,522.60 0.00 0.00 0.00 26,500.00 90.47 332.00 7,391.59 18,904.37 -12,633.42 22,622.60 0.00 0.00 0.00 26,600.00 90.47 332.00 7,390.77 18,992.66 -12,680.37 22,722.60 0.00 0.00 0.00 26,700.00 90.47 332.00 7,389.96 19,080.95 -12,727.31 22,822.59 0.00 0.00 0.00 26,800.00 90.47 332.00 7,389.14 19,169.25 -12,774.25 22,922.59 0.00 0.00 0.00 26,900.00 90.47 332.00 7,388.32 19,257.54 -12,821.19 23,022.59 0.00 0.00 0.00 27,000.00 90.47 332.00 7,387.51 19,345.84 -12,868.14 23,122.58 0.00 0.00 0.00 27,100.00 90.47 332.00 7,386.69 19,434.13 -12,915.08 23,222.58 0.00 0.00 0.00 27,200.00 90.47 332.00 7,385.87 19,522.42 -12,962.02 23,322.58 0.00 0.00 0.00 27,300.00 90.47 332.00 7,385.05 19,610.72 -13,008.96 23,422.57 0.00 0.00 0.00 27,400.00 90.47 332.00 7,384.24 19,699.01 -13,055.90 23,522.57 0.00 0.00 0.00 27,500.00 90.47 332.00 7,383.42 19,787.30 -13,102.85 23,622.57 0.00 0.00 0.00 27,600.00 90.47 332.00 7,382.60 19,875.60 -13,149.79 23,722.56 0.00 0.00 0.00 27,700.00 90.47 332.00 7,381.78 19,963.89 -13,196.73 23,822.56 0.00 0.00 0.00 27,800.00 90.47 332.00 7,380.97 20,052.18 -13,243.67 23,922.56 0.00 0.00 0.00 27,900.00 90.47 332.00 7,380.15 20,140.48 -13,290.62 24,022.55 0.00 0.00 0.00 28,000.00 90.47 332.00 7,379.33 20,228.77 -13,337.56 24,122.55 0.00 0.00 0.00 28,100.00 90.47 332.00 7,378.52 20,317.07 -13,384.50 24,222.55 0.00 0.00 0.00 28,200.00 90.47 332.00 7,377.70 20,405.36 -13,431.44 24,322.54 0.00 0.00 0.00 28,300.00 90.47 332.00 7,376.88 20,493.65 -13,478.38 24,422.54 0.00 0.00 0.00 28,400.00 90.47 332.00 7,376.06 20,581.95 -13,525.33 24,522.54 0.00 0.00 0.00 28,500.00 90.47 332.00 7,375.25 20,670.24 -13,572.27 24,622.53 0.00 0.00 0.00 28,600.00 90.47 332.00 7,374.43 20,758.53 -13,619.21 24,722.53 0.00 0.00 0.00 28,700.00 90.47 332.00 7,373.61 20,846.83 -13,666.15 24,822.53 0.00 0.00 0.00 28,738.16 90.47 332.00 7,373.30 20,880.52 -13,684.07 24,860.69 0.00 0.00 0.00 2/23/2019 11:53:44AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips p Database: OAKEDMPI Company: ConocoPhillips Alaskalnc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape (1) (1) (usft) (usft) (usft) CD5-92 (11A) T02 Toe L 0.00 0.00 7,373.30 20,880.52 -13,684.07 plan hits target center Circle (radius 100.00) CD5-92 (11A) T01 Heel plan hits target center Circle (radius 100.00) CD5-92 (11A) T01 Heel plan hits target center Circle (radius 1,320.00) 0.00 0.00 7,493.30 6,521.12 -6,020.02 0.00 0.00 7,493.30 6,521.12 -6,020.02 ConocoPhillips Standard Proposal Report Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature Northing Easting (usft) (usft) Latitude Longitude Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 118.40 118.40 20 x 42 20.000 42.000 2,245.93 2,188.30 10-3/4 x 13-1/2 10.750 13.500 12,459.68 7,493.30 7-5/8 x 9-7/8 by 11 7.625 11.000 28,738.16 7,373.30 4-1/2 x 6-3/4 4.500 6.750 2/23/2019 11:53.44AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips p Database: OAKEDMP1 Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_WNS ND Reference: Project: Western North Slope MD Reference: Site: CD5 Alpine West Pad North Reference: Well: Plan: CD5-92 Survey Calculation Method: Wellbore: CD5-92 C-30 Design: CD5-92 wp05 K-3 ConocoPhillips Standard Proposal Report Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,325.93 1,323.30 Permafrost Base 2,336.18 2,267.30 C-30 4,552.12 3,713.30 K-3 5,005.35 3,951.30 K-2 5,652.82 4,291.30 Albian 97 7,442.90 5,231.30 Albian 96 10,964.02 7,080.30 HRZ 11,208.93 7,208.30 Kalubik 11,388.00 7,291.30 Kuparuk C 11,390.36 7,292.30 LCU 11,879.09 7,443.30 Alpine C 11,906.11 7,448.30 UJU 12,383.25 7,489.30 Alpine Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 750.00 750.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 330° TF, for 300' 1,050.00 1,049.69 10.20 -5.89 Start 2°/100' DLS, 00 TF, for 1195.93' 2,245.93 2,188.30 301.52 -174.08 Hold for 20' 2,265.93 2,205.89 309.76 -178.84 Start 2°/100' DLS, -24.7° TF, for 1571.09' 3,837.02 3,337.79 1,128.23 -854.12 Hold for 7318.22' 11,155.24 7,180.71 5,544.86 -5,245.21 Start W/100' DLS, 19.86° TF, for 1004.45' 12,159.68 7,477.60 6,275.71 -5,848.18 Hold for 300' 12,459.68 7,493.30 6,521.12 -6,020.02 Adjust TF to 0°, for 20' 12,479.68 7,494.35 6,537.48 -6,031.48 Start 2°/100' DLS, 63.75° TF, for 390.58' 12,870.26 7,502.98 6,870.18 -6,235.32 Hold for 15867.9' 28,738.16 7,373.30 20,880.52 -13,684.07 TD: 28738.16' MD, 7373.3' TVD 2/23/2019 11:53:44AM Page 11 COMPASS 5000.14 Build 85D ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 CD5-92 50103xxxxx00 C135-92 wp05 ConocoPhillips Clearance Summary Anticollision Report 23 February, 2019 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: CD5 Alpine West Pad - Plan: CD5-92 - CD5-92 - CD5-92 wp05 Well Coordinates: Datum Height: Plan: D142 39.4+33.9 @ 73.30usft (D142) Scan Range: 0.00 to 28,738.16 usft. Measured Depth. Scan Radius is 3,069.88 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85D Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: ConocoPhillips ConocoPhillips Anticollision Report for Plan: CD5-92 - CD5-92 wp05 ConocoPhillips Alaska Inc_WNS Westem North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: CDs Alpine West Pad - Plan: CDS-92 - CD5-92 - CDS-92 wp05 Scan Range: 0.00 to 28,738.16 usft. Measured Depth. Scan Radius is 3,069.88 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft CD5 Alpine West Pad CD5-01 - CD5-01 - CD5-01 CD5-01 - CD5-01 - CD5-01 CD5-02 - CD5-02 - CD5-02 CD5-02 - CD5-02 - CD5-02 CD5-02 - CD5-02A- CD5-02A CD5-02 - CD5-02A- CD5-02A CD5-03 - CD5-03 - CD5-03 CD5-03 - CD5-03 - CD5-03 CD5-03 - CD5-03 - CD5-03 CD5-04 - CD5-04 - CD5-04 CD5-04 - CD5-04 - CD5-04 CD5-05 - CD5-05 - CD5-05 CD5-06 - CD5-06 - CD5-06 CD5-06 - CD5-0611 - CD5-0611 CD5-07 - CD5-07 - CD5-07 CD5-08 - CD5-08 - CD5-08 CD5-09 - CD5-09 - CD5-09 CD5-09 - CD5-09 - CD5-09 CD5-10 - CD5-10 - CD5-10 CD5-10 - CD5-10 - CD5-10 CD5-11 - CD5-11 - CD5-11 CD5-12 - CD5-12 - CD5-12 CD5-19 - CDS-19 - CD5-19 CD5-19 - CD5-19 - CD5-19 CD5-19 - CD5-19 - CD5-19 CD5-19 - CD5-1911 - CD5-1911 CD5-19 - CD5-1911 - CD5-1911 C05-19 - CD5-1911 - CD5-1911 1,300.63 101.39 1,300.63 93.27 1,300.00 12.488 Centre Distance Pass - 1,397.96 101.66 1,397.96 92.98 1,400.00 11.713 Clearance Factor Pass - 1,609.23 123.22 1,609.23 113.49 1,600.00 12.670 Ellipse Separation Pass - 1,706.75 126.24 1,706.75 116.04 1,700.00 12.366 Clearance Factor Pass - 1,609.23 123.22 1,609.23 113.49 1,600.00 12.664 Ellipse Separation Pass - 1,706.75 126.24 1,706.75 116.03 1,700.00 12.360 Clearance Factor Pass - 102.37 199.90 102.37 197.11 100.00 71.631 Centre Distance Pass - 602.13 201.15 602.13 197.04 600.00 49.004 Ellipse Separation Pass - 1,831.62 235.63 1,831.62 224.81 1,800.00 21.777 Clearance Factor Pass - 1,096.21 212.02 1,096.21 205.26 1,100.00 31.370 Ellipse Separation Pass - 1,279.28 228.95 1,279.28 221.00 1,300.00 28.804 Clearance Factor Pass - 1,888.25 41.47 1,888.25 30.06 1,900.00 3.634 Clearance Factor Pass - 2,231.34 138.98 2,231.34 125.50 2,200.00 10.309 Clearance Factor Pass - 2,231.34 138.98 2,231.34 125.49 2,200.00 10.303 Clearance Factor Pass - 1,755.04 124.89 1,755.04 114.21 1,800.00 11.696 Clearance Factor Pass - 2,321.61 194.22 2,321.61 181.36 2,300.00 15.131 Clearance Factor Pass - 601.81 318.68 601.81 314.37 600.00 73.898 Ellipse Separation Pass - 3,666.66 838.96 3,666.66 794.03 3,600.00 18.673 Clearance Factor Pass - 1,538.44 319.63 1,538.44 310.18 1,600.00 33.824 Ellipse Separation Pass - 1,693.77 329.98 1,693.77 319.48 1,800.00 31.452 Clearance Factor Pass - 2,031.70 147.67 2,031.70 135.25 2,100.00 11.887 Clearance Factor Pass - 2,165.32 45.41 2,165.32 32.54 2,200.00 3.528 Clearance Factor Pass - 39.40 519.96 39.40 517.76 36.87 236.526 Centre Distance Pass - 102.53 519.99 102.53 517.49 100.00 208.081 Ellipse Separation Pass - 1,729.39 633.07 1,729.39 622.35 1,800.00 59.058 Clearance Factor Pass - 39.40 519.96 39.40 517.76 36.87 236.526 Centre Distance Pass - 102.53 519.99 102.53 517.49 100.00 208.081 Ellipse Separation Pass - 1,729.39 633.07 1,729.39 622.35 1,800.00 59.058 Clearance Factor Pass - 23 February, 2019 - 11:48 Page 2 of COMPASS ConocoPhillips Anticollision Report for Plan: CD5-92 - CD5-92 wp05 ConocoPhillips Alaska Inc_WNS Western North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: CD5 Alpine West Pad - Plan: CD5-92 - CD5-92 - CDS-92 wp05 Scan Range: 0.00 to 28,738.16 usft. Measured Depth. Scan Radius is 3,069.88 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft CD5-22 - CDS-22 - CD5-22 3,669.05 158.15 3,669.05 100.19 3,600.00 2.729 Clearance Factor Pass - CD5-22 - C05-22 - CD5-22 3,849.90 112.04 3,849.90 82.67 3,800.00 3.815 Ellipse Separation Pass - CD5-22 - CD5-22 - CD5-22 3,940.76 110.33 3,940.76 87.76 3,900.00 4.888 Centre Distance Pass - CD5-23 - CD5-23 - CD5-23 3,117.40 526.49 3,117.40 491.00 3,000.00 14.838 Centre Distance Pass - CD5-23- CD5-23 - CD5-23 3,211.66 526.61 3,211.66 490.16 3,100.00 13.747 Ellipse Separation Pass - CD5-23 - CD5-23 - CD5-23 26,171.72 1,558.40 26,171.72 1,024.65 27,430.00 2.920 Clearance Factor Pass - CD5-99 - C05-99 - CD5-99 302.85 139.46 302.85 137.00 300.00 56.831 Centre Distance Pass - CD5-99 - CD5-99 - CD5-99 402.83 139.93 402.83 136.86 400.00 45.618 Ellipse Separation Pass - CD5-99 - CD5-99 - CD5-99 1,090.91 164.81 1,090.91 158.01 1,100.00 24.237 Clearance Factor Pass - CD5-99 - CD5-99A - CD5-99A 302.85 139.46 302.85 137.00 300.00 56.831 Centre Distance Pass - CD5-99 - CD5-99A - CD5-99A 402.83 139.93 402.83 136.86 400.00 45.618 Ellipse Separation Pass - CD5-99 - CD5-99A - CD5-99A 1,090.91 164.81 1,090.91 158.01 1,100.00 24.237 Clearance Factor Pass - CD5-99 - CD5-99AL1 - CD5-99AL1 302.85 139.46 302.85 137.00 300.00 56.831 Centre Distance Pass - CD5-99 - CD5-99AL1 - CD5-99AL1 402.83 139.93 402.83 136.86 400.00 45.618 Ellipse Separation Pass - CD5-99 - CD5-99AL1 - CD5-99AL1 1,090.91 164.81 1,090.91 158.01 1,100.00 24.237 Clearance Factor Pass - CD5-99- For survey analysis _CD5-99A-CD5-99A_Gy 402.84 138.93 402.84 135.94 400.00 46.437 Ellipse Separation Pass - CD5-99- For survey analysis_CD5-99A-CD5-99A_Gy 1,091.21 164.64 1,091.21 157.46 1,100.00 22.943 Clearance Factor Pass - CD5-99 - For survey analysis_CD5-99A_Raw - CD5-99 39.40 140.07 39.40 137.87 36.55 63.718 Centre Distance Pass - CD5-99 - For survey analysis _CD5-99A_Raw - CD5-99 102.85 140.11 102.85 137.70 100.00 58.252 Ellipse Separation Pass - CD5-99- For survey analysis_CD5-99A_Raw-CD5-99 1,090.09 170.94 1,090.09 163.50 1,100.00 22.994 Clearance Factor Pass - Plan: CD5-90 (12B) - CD5-90 (12B) - CD5-90 wp02 v4 198.60 40.01 198.60 38.17 200.00 21.734 Centre Distance Pass - Plan: CD5-90 (12B) - CD5-90 (12B) - CD5-90 wp02 v4 398.56 40.21 398.56 37.09 400.00 12.872 Ellipse Separation Pass - Plan: CD5-90 (12B) - CD5-90 (12B) - CD5-90 wp02 v4 11,961.80 1,545.89 11,961.80 1,261.12 16,100.00 5.429 Clearance Factor Pass - Plan: CD5-93 (12A) - C05-93 - CD5-93 wp02 v3 (12A) 498.51 19.03 498.51 15.48 500.00 5.366 Centre Distance Pass - Plan: CD5-93 (12A) - CD5-93 - CD5-93 wp02 v3 (12A) 598.37 19.47 598.37 15.36 600.00 4.735 Ellipse Separation Pass - Plan: CD5-93 (12A) - CD5-93 - CD5-93 wp02 v3 (12A) 28,499.00 1,505.39 28,499.00 881.12 29,148.45 2.411 Clearance Factor Pass - Plan: CD5-94 (13A) - CD5-94 - CD5-94 wp03 v3 (13A) 998.84 38.96 998.84 32.17 1,000.00 5.740 Centre Distance Pass - Plan: CD5-94 (13A) - ODS -94 - CD5-94 wp03 v3 (13A) 1,098.43 39.56 1,098.43 32.13 1,100.00 5.330 Ellipse Separation Pass - Plan: CD5-94 (13A) - CD5-94 - CD5-94 wp03 v3 (13A) 28,717.09 2,988.57 28,717.09 2,364.14 29,600.00 4.786 Clearance Factor Pass - Plan: CD5-94 (13A) - CD5-94PH1 - CD5-94PH1 wp01 998.84 38.96 998.84 32.17 1,000.00 5.740 Centre Distance Pass - 23 February, 2019 - 11:48 Page 3 of 7 COMPASS IV-' ConocoPhillips ConocoPhillips Alaska Inc_WNS Western North Slope Anticollision Report for Plan: CD5-92 - CD5-92 wpO5 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: CD5 Alpine West Pad - Plan: CDS-92 - CD5-92 - CD5-92 wp05 Scan Range: 0.00 to 28,738.16 usft. Measured Depth. Scan Radius is 3,069.88 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan :CD5-94(13A)-CD5-94PH1-CD5-94PHi wp01 1,098.43 39.56 1,098.43 32.13 1,100.00 5.330 Ellipse Separation Pass - Plan: CD5-94 (13A) - CD5-94PH1 - CD5-94PH1 wp01 1,197.37 42.97 1,197.37 34.91 1,200.00 5.330 Clearance Factor Pass - Plan: CD5-98 (11 B) - CD5-98 (11 B -A) - CD5-98 (11 B -A 598.60 120.00 598.60 115.26 600.00 25.315 Centre Distance Pass - Plan: CD5-98 (11 B) - CD5-98 (11 B -A) - CD5-98 (11 B -A 11,413.91 311.64 11,413.91 60.29 13,400.00 1.240 Clearance Factor Pass - Plan: CD5-98 (11 B) - CD5-9811 - CD5-98L1 wp04 598.60 120.00 598.60 115.26 600.00 25.315 Centre Distance Pass - Plan: CD5-98 (11 B) - CD5-9811 - CD5-9811 wp04 11,413.91 311.64 11,413.91 60.42 13,400.00 1.241 Clearance Factor Pass - Prelim: CD5-89 (FWK6) - CD5-89 - CD5-89wp01 v3 (F 603.10 60.01 603.10 55.57 600.00 13.528 Centre Distance Pass - Prelim: CD5-89 (FWK6) - CD5-89 - CD5-89wp01 v3 (F 703.09 60.40 703.09 55.32 700.00 11.893 Ellipse Separation Pass - Prelim: CD5-89(FWK6)-CD5-89-CD5-89wp01 v3 (F 3,270.71 360.78 3,270.71 319.89 3,300.00 8.823 Clearance Factor Pass - Prelim: CD5-91 (FWK7) - CD5-91 - CD5-91wp01 0 (F 703.10 20.00 703.10 14.93 700.00 3.939 Centre Distance Pass - Prelim: CD5-91 (FWK7) - CD5-91 - CD5-91wp01 v3 (F 803.04 20.11 803.04 14.39 800.00 3.517 Ellipse Separation Pass - Prelim: CD5-91 (FWK7)- CD5-91 - CD5-91wp01 v3 (F 28,642.88 692.83 28,642.88 34.12 27,700.00 1.052 Clearance Factor Pass - Prelim: CD5-95 (14A) - CD5-95 - CD5-95wp01 v3 (14A 1,003.71 58.91 1,003.71 51.91 1,000.00 8.417 Centre Distance Pass - Prelim: CD5-95 (14A) - CD5-95 - CD5-95wp01 v3 (14A 1,103.76 58.93 1,103.76 51.43 1,100.00 7.858 Ellipse Separation Pass - Prelim: CD5-95 (14A) - CD5-95 - CD5-95wp01 v3 (14A 3,664.47 375.60 3,664.47 315.21 3,700.00 6.219 Clearance Factor Pass - Prelim: CD5-96 (15A) - CD5-96 - CD5-96wp01 v3 (15A 903.79 79.84 903.79 73.49 900.00 12.571 Centre Distance Pass - Prelim: CD5-96 (15A) - CD5-96 - CD5-96wp01 v3 (15A 1,004.19 80.22 1,004.19 73.24 1,000.00 11.501 Ellipse Separation Pass - Prelim: CD5-96 (15A) - CD5-96 - CD5-96wp01 v3 (15A 3,667.71 524.94 3,667.71 463.97 3,700.00 8.609 Clearance Factor Pass - Prelim: CD5-97 (16A) - C05-97 - CD5-97 wp01 v3 (16A 684.90 100.01 684.90 94.69 700.00 18.824 Ellipse Separation Pass - Prelim: CD5-97 (16A) - C05-97 - CD5-97 wp01 v3 (16A 985.67 110.68 985.67 103.78 1,000.00 16.028 Clearance Factor Pass - 23 February, 2019 - 11:48 Page 4 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: CD5-92 - CD5-92 wp05 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.40 1,000.00 CD5-92 wp05 MWD OWSG 39.40 2,240.00 CD5-92 wp05 MWD+IFR2+SAG+MS 2,240.00 3,740.00 CD5-92 wp05 MWD OWSG 2,240.00 12,450.00 CD5-92 wp05 MWD+IFR2+SAG+MS 12,450.00 13,950.00 CD5-92 wp05 MWD OWSG 12,450.00 28,738.16 CD5-92 wp05 MWD+IFR2+SAG+MS Ellipse error terms are correlated across survey tool lie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. ConocoPhillips Alaska Inc_WNS Western North Slope 23 February, 2019 - 11:48 Page 5 of 7 COMPASS -92 wp05 Q U Z � (a'I C m n 300- Ladder View 0-17 0 4000 8000 12000 16000 20000 24000 28000 Measured Depth SURVEY PROGRAM s a CASING DETAILS Depth From Depth To Survey/Plan i U Name 39.40 1000.00 CD5-92 wp05 (CD5-92) MWD OWSG 118.40 118.40 20 x 42 39.40 2240.00 U MWD+IFR2+SAG+MS 2188.30 2245.93 10-3/4 x 13-1/2 2240.00 3740.00 CD5-92 wp05 (CD5-92) MWD OWSG 7493.3012459.05/8 x 9-7/8 by 11 U CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 7373.308738.16 4-1/2 x 6-3/4 12450.0013950.00 CD5-92 wp05 (CD5-92) MWD OWSG i U 12450.0028738.16 I MWD+IFR2+SAG+MS c a I � N � I � � I m 5 U U ti Equivalent Magnetic Distance i j i 0-17 0 4000 8000 12000 16000 20000 24000 28000 Measured Depth 0 C o ( 0- U SURVEY PROGRAM s a CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.40 1000.00 CD5-92 wp05 (CD5-92) MWD OWSG 118.40 118.40 20 x 42 39.40 2240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 2188.30 2245.93 10-3/4 x 13-1/2 2240.00 3740.00 CD5-92 wp05 (CD5-92) MWD OWSG 7493.3012459.05/8 x 9-7/8 by 11 2240.0012450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 7373.308738.16 4-1/2 x 6-3/4 12450.0013950.00 CD5-92 wp05 (CD5-92) MWD OWSG 12450.0028738.16 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS N � m 5 0 C o ( 0- U m t U n s a m 30 _ ------ U o � m L Equivalent Magnetic c U 0 --r 0 450 ME 1350 Partial Measured Depth 1800 2250 12:31, February 23 2019 CD5-92 wp05 Ladder View 00 N N , L, 300 i I � I I c o �y E C ` n. U m I 150 - i I amici I U I Equivalent Magnetic Distance I 0 I 0 4000 8000 12000 16000 20000 24000 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.40 1000.00 CD5-92 wp05 (CD5-92) MWD OWSG 118.40 118.40 20 x 42 39.40 2240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 2188.30 2245.93 10-3/4 x 13-1/2 2240.00 3740.00 CD5-92 wp05 (CD5-92) MWD OWSG 7493.3012459.65/8 x 9-7/8 by 11 2240.0012450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 7373.3C28738.16 4-1/2 x 6-3/4 12450.0013950.00 CD5-92 wp05 (CD5-92) MWD OWSG 12450.0028738.16 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 60- - _ - .... — -- - ...... -- .................. i Equivalent Magnetic Distance O 75 L i Q vJ L a30- - - -- .._- -..----- ---- - - ......-.............. --------------------------- -------- -- - -- -- - - ----- - --..--.... -------------- --------------- U 0 � W I U j 0 0 450 900 1350 1800 2250 Partial Measured Depth ConocoPhillips Alaska Inc WNS Western North Slope CD5 Alpine West Pad Plan: CD5-92 50103xxxxx00 CD5-92 Plan: CD5-92 wp05 Error Ellipse Survey Report 23 February, 2019 Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: OAKE D M P 1 Project Western North Slope, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD5 Alpine West Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: Well Plan: CD5-92 - Slot 92 Well Position +N/ -S 0.00 usft Northing: Latitude: +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.90 usft Wellbore CD5-92 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 4/30/2019 16.16 80.73 57,379 Design CD5-92 wp05 Audit Notes: Version: Vertical Section: Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 39.40 0.00 Tie On Depth: 39.40 +EI -W Direction (usft) (I 0.00 332.00 Survey Tool Program Date 2/22/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.40 1,000.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard 39.40 2,240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 2,240.00 3,740.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard 2,240.00 12,450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 12,450.00 13,950.00 CD5-92 wp05 (CD5-92) MWD OWSG OWSG MWD - Standard 12,450.00 28,738.16 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 2/23/2019 11:54 49AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well Plan: CD5-92 - Slot 92 Project: Western North Slope TVD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Site: CD5 Alpine -West Pad MD Reference: Plan: D142 39.4+33.9 @ 73.30usft (D142) Well: Plan: CD5-92 North Reference: True Wellbore: CD5-92 Survey Calculation Method: Minimum Curvature Design: CD5-92 wp05 Output errors are at 2.00 sigma Database: OAKEDMPI Plan Survey Tool Program Date 2/22/2019 Inclination Azimuth Depth From Depth To Lateral (usft) (usft) Survey (Wellbore) Tool Name Remarks Magnitude 1 39.40 1,000.00 CD5-92 wp05 (CD5-92) MWD OWSG Depth OWSG MWD - Standard Depth 2 39.40 2,240.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS Bias Error Bias OWSG MWD + IFR2 + Sag + Error 3 2,240.00 3,740.00 CD5-92 wp05 (CD5-92) MWD OWSG (usft) I,) (°) OWSG MWD - Standard (usft) 4 2,240.00 12,450.00 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS (usft) (usft) (usft) OWSG MWD + IFR2+Sag + (usft) 5 12,450.00 13,950.00 CD5-92 wp05 (CD5-92) MWD OWSG 0.00 0.00 39.40 OWSG MWD - Standard 0.00 6 12,450.00 28,738 16 CD5-92 wp05 (CD5-92) MWD+IFR2+SAG+MS 0.00 0.00 0.00 OWSG MWD + IFR2 + Sag + 0.00 2/23/2019 11:54:49AM Page 3 COMPASS 500014 Build 85D 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) I,) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (') 39.40 0.00 0.00 39.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.00 0.00 0.00 100.00 0.11 0.00 0.11 0.00 2.30 0.00 0.00 0.11 0.11 0.00 MWD OWSG (1, 1) 200.00 0.00 0.00 200.00 0.47 0.00 0.47 0.00 2.30 0.00 0.00 0.47 0.47 0.00 MWD OWSG (1, 1) 300.00 0.00 0.00 300.00 0.83 0.00 0.83 0.00 2.31 0.00 0.00 0.83 0.83 0.00 MWD OWSG (1, 1) 400.00 0.00 0.00 400.00 1.18 0.00 1.18 0.00 2.33 0.00 0.00 1.18 1.18 0.00 MWD OWSG (1, 1) 500.00 0.00 0.00 500.00 1.54 0.00 1.54 0.00 2.35 0.00 0.00 1.54 1.54 0.00 MWD OWSG (1, 1) 600.00 0.00 0.00 600.00 1.90 0.00 1.90 0.00 2.37 0.00 0.00 1.90 1.90 0.00 MWD OWSG (1, 1) 700.00 0.00 0.00 700.00 2.26 0.00 2.26 0.00 2.40 0.00 0.00 2.26 2.26 0.00 MWD OWSG (1, 1) 750.00 0.00 0.00 750.00 2.44 0.00 2.44 0.00 2.42 0.00 0.00 2.44 2.44 0.00 MWD OWSG (1, 1) 800.00 0.75 330.00 800.00 2.62 0.00 2.62 0.00 2.44 0.00 0.00 2.62 2.62 135.00 MWD OWSG (1, 1) 900.00 2.25 330.00 899.96 2.97 0.00 2.97 0.00 2.48 0.00 0.00 2.98 2.97 99.18 MWD OWSG (1, 1) 1,000.00 3.75 330.00 999.82 3.33 0.00 3.34 0.00 2.52 0.00 0.00 3.34 3.33 112.75 MWD OWSG (1, 1) 1,050.00 4.50 330.00 1,049.69 3.50 0.00 3.51 0.00 2.54 0.00 0.00 3.52 3.50 91.22 MWD+IFR2+13AG+MS (2, 1) 1,100.00 5.50 330.00 1,099.50 3.68 0.00 3.68 0.00 2.57 0.00 0.00 3.70 3.68 92.77 MWD+IFR2+SAG+MS (2, 1) 1,200.00 7.50 330.00 1,198.85 4.02 0.00 4.04 0.00 2.62 0.00 0.00 4.06 4.03 98.03 MWD+IFR2+SAG+MS(2, 1) 1,300.00 9.50 330.00 1,297.75 4.36 0.00 4.40 0.00 2.67 0.00 0.00 4.43 4.38 103.55 MWD+IFR2+SAG+MS(2, 1) 1,400.00 11.50 330.00 1,396.07 4.70 0.00 4.77 0.00 2.72 0.00 0.00 4.80 4.74 110.52 MWD+IFR2+SAG+MS (2, 1) 1,500.00 13.50 330.00 1,493.69 5.03 0.00 5.15 0.00 2.78 0.00 0.00 5.18 5.09 117.76 MWD+IFR2+SAG+MS (2, 1) 1,600.00 15.50 330.00 1,590.50 5.35 0.00 5.55 0.00 2.85 0.00 0.00 5.57 5.44 124.16 MWD+IFR2+SAG+MS (2, 1) 1,700.00 17.50 330.00 1,686.38 5.67 0.00 5.96 0.00 2.92 0.00 0.00 5.98 5.79 129.26 MWD+IFR2+SAG+MS (2, 1) 1,800.00 19.50 330.00 1,781.21 5.98 0.00 6.39 0.00 2.99 0.00 0.00 6.42 6.13 133.14 MWD+IFR2+SAG+MS (2, 1) 1,900.00 21.50 330.00 1,874.87 6.29 0.00 6.86 0.00 3.08 0.00 0.00 6.88 6.47 136.06 MWD+IFR2+SAG+MS (2, 1) 2,000.00 23.50 330.00 1,967.25 6.58 0.00 7.35 0.00 3.17 0.00 0.00 7.37 6.81 138.28 MWD+IFR2+SAG+MS(2, 1) 2,100.00 25.50 330.00 2,058.25 6.88 0.00 7.88 0.00 3.28 0.00 0.00 7.90 7.14 140.01 MWD+IFR2+SAG+MS(2, 1) 2,200.00 27.50 330.00 2,147.74 7.16 0.00 8.45 0.00 3.39 0.00 0.00 8.47 7.47 141.36 MWD+IFR2+SAG+MS(2, 1) 2,245.93 28.42 330.00 2,188.30 7.21 0.00 8.66 0.00 3.28 0.00 0.00 8.68 7.66 141.37 MWD OWSG (2.2) 2,265.93 28.42 330.00 2,205.89 7.21 0.00 8.74 0.00 3.30 0.00 0.00 8.76 7.67 141.97 MWD OWSG (2,2) 2,300.00 29.04 329.41 2,235.77 7.18 0.00 8.90 0.00 3.32 0.00 0.00 8.92 7.68 142.98 MWD OWSG (2.2) 2/23/2019 11:54:49AM Page 3 COMPASS 500014 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi-mmor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) ("j (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 2,400.00 30.87 327.82 2,322.41 7.14 0.00 9.61 0.00 3.41 0.00 0.00 9.61 7.73 145.22 MWD OWSG (2,2) 2,500.00 32.73 326.38 2,407.40 7.13 0.00 10.63 0.00 3.51 0.00 0.00 10.63 7.81 146.21 MWD OWSG (2.2) 2,600.00 34.59 325.09 2,490.63 7.16 0.00 11.95 0.00 3.63 0.00 0.00 11.95 7.91 146.41 MWD OWSG (2.2) 2,700.00 36.47 323.91 2,572.01 7.22 0.00 13.54 0.00 3.79 0.00 0.00 13.55 8.04 146.21 MWD OWSG (2,2) 2,800.00 38.36 322.83 2,651.43 7.34 0.00 15.40 0.00 3.97 0.00 0.00 15.41 8.19 145.80 MWD OWSG (2,2) 2,900.00 40.26 321.84 2,728.80 7.49 0.00 17.48 0.00 4.18 0.00 0.00 17.51 8.36 145.29 MWD OWSG (2,2) 3,000.00 42.17 320.92 2,804.02 7.69 0.00 19.78 0.00 4.43 0.00 0.00 19.82 8.55 144.74 MWD OWSG (2.2) 3,100.00 44.08 320.07 2,877.01 7.94 0.00 22.29 0.00 4.71 0.00 0.00 22.34 8.76 144.17 MWD OWSG (2,2) 3,200.00 46.00 319.27 2,947.67 8.22 0.00 24.98 0.00 5.02 0.00 0.00 25.05 8.98 143.60 MWD OWSG (2,2) 3,300.00 47.92 318.53 3,015.91 8.54 0.00 27.86 0.00 5.36 0.00 0.00 27.94 9.22 143.05 MWD OWSG (2,2) 3,400.00 49.85 317.83 3,081.66 8.89 0.00 30.92 0.00 5.74 0.00 0.00 31.01 9.47 142.50 MWD OWSG (2,2) 3,500.00 51.79 317.17 3,144.84 9.27 0.00 34.14 0.00 6.14 0.00 0.00 34.26 9.73 141.97 MWD OWSG (2,2) 3,600.00 53.72 316.54 3,205.36 9.68 0.00 37.53 0.00 6.58 0.00 0.00 37.66 9.99 141.46 MWD OWSG (2,2) 3,700.00 55.66 315.94 3,263.16 10.11 0.00 41.07 0.00 7.05 0.00 0.00 41.22 10.25 140.97 MWD OWSG (2,2) 3,800.00 57.60 315.37 3,318.15 8.13 0.00 22.14 0.00 5.96 0.00 0.00 22.19 9.36 139.93 MWD+IFR2+SAG+MS (3,2) 3,837.02 58.32 315.17 3,337.79 8.20 0.00 22.73 0.00 6.06 0.00 0.00 22.79 9.41 139.77 MWD+IFR2+SAG+MS (3,2) 3,900.00 58.32 315.17 3,370.86 8.40 0.00 23.77 0.00 6.26 0.00 0.00 23.83 9.50 139.51 MWD+IFR2+SAG+MS (3,2) 4,000.00 58.32 315.17 3,423.37 8.73 0.00 25.44 0.00 6.57 0.00 0.00 25.49 9.65 139.14 MWD+IFR2+SAG+MS (3, 2) 4,100.00 58.32 315.17 3,475.89 9.07 0.00 27.12 0.00 6.89 0.00 0.00 27.17 9.80 138.82 MWD+IFR2+SAG+MS (3,2) 4,200.00 58.32 315.17 3,528.40 9.41 0.00 28.82 0.00 7.22 0.00 0.00 28.87 9.96 138.55 MWD+IFR2+SAG+MS (3,2) 4,300.00 58.32 315.17 3,580.91 9.77 0.00 30.53 0.00 7.55 0.00 0.00 30.57 10.12 138.30 MWD+IFR2+SAG+MS (3,2) 4,400.00 58.32 315.17 3,633.42 10.12 0.00 32.26 0.00 7.88 0.00 0.00 32.29 10.28 138.09 MWD+IFR2+SAG+MS (3,2) 4,500.00 58.32 315.17 3,685.93 10.49 0.00 33.99 0.00 8.22 0.00 0.00 34.02 10.45 137.90 MWD+IFR2+SAG+MS (3, 2) 4,600.00 58.32 315.17 3,738.45 10.86 0.00 35.73 0.00 8.57 0.00 0.00 35.76 10.62 137.73 MWD+IFR2+SAG+MS (3,2) 4,700.00 58.32 315.17 3,790.96 11.23 0.00 37.48 0.00 8.91 0.00 0.00 37.51 10.79 137.58 MWD+IFR2+SAG+MS (3,2) 4,800.00 58.32 315.17 3,843.47 11.61 0.00 39.23 0.00 9.26 0.00 0.00 39.26 10.97 137.44 MWD+IFR2+SAG+MS (3,2) 4,900.00 58,32 315.17 3,895.98 11.99 0.00 40.98 0.00 9.61 0.00 0.00 41.01 11.15 137.31 MWD+IFR2+SAG+MS (3,2) 5,000.00 58.32 315.17 3,948.49 12.38 0.00 42.75 0.00 9.96 0.00 0.00 42.77 11.34 137.20 MWD+IFR2+SAG+MS (3,2) 5,100.00 58.32 315.17 4,001.00 12.76 0.00 44.51 0.00 10.32 0.00 0.00 44.54 11.52 137.09 MWD+IFR2+SAG+MS(3,2) 5,200.00 58.32 315.17 4,053.52 13.16 0.00 46.28 0.00 10.68 0.00 0.00 46.30 11.72 136.99 MWD+IFR2+SAG+MS (3, 2) 5,300.00 58.32 315.17 4,106.03 13.55 0.00 48.05 0.00 11.03 0.00 0.00 48.07 11.91 136.90 MWD+IFR2+SAG+MS (3, 2) 5,400.00 58.32 315.17 4,158.54 13.95 0.00 49.83 0.00 11.39 0.00 0.00 49.85 12.11 136.82 MWD+IFR2+SAG+MS (3,2) 5,500.00 58.32 315.17 4,211.05 14.34 0.00 51.60 0.00 11.76 0.00 0.00 51.62 12.30 136.74 MWD+IFR2+SAG+MS (3,2) 5,600.00 58.32 315.17 4,263.56 14.75 0.00 53.38 0.00 12.12 0.00 0.00 53.40 12.51 136.67 MWD+IFR2+SAG+MS (3,2) 5,700.00 58.32 315.17 4,316.07 15.15 0.00 55.17 0.00 12.48 0.00 0.00 55.18 12.71 136.61 MWD+IFR2+SAG+MS (3, 2) 5,800.00 58.32 315.17 4,366.59 15.55 0.00 56.95 0.00 12.84 0.00 0.00 56.96 12.92 136.55 MWD+IFR2+SAG+MS (3,2) 5,900.00 58.32 315.17 4,421.10 15.96 0.00 58.73 0.00 13.21 0.00 0.00 58.75 13.13 136.49 MWD+IFR2+SAG+MS (3,2) 6,000.00 58.32 315.17 4,473.61 16.36 0.00 60.52 0.00 13.58 0.00 0.00 60.53 13.34 136.43 MWD+IFR2+SAG+MS (3,2) 6,100.00 58.32 315.17 4,526.12 16.77 0.00 62.31 0.00 13.94 0.00 0.00 62.32 13.55 136.38 MWD+IFR2+SAG+MS (3,2) 6,200.00 58.32 315.17 4,578.63 17.18 0.00 64.10 0.00 14.31 0.00 0.00 64.11 13.77 136.33 MWD+IFR2+SAG+MS (3,2) 6,300.00 58.32 315.17 4,631.14 17.59 0.00 65.89 0.00 14.68 0.00 0.00 65.90 13.98 136.29 MWD+IFR2+SAG+MS (3,2) 6,400.00 58.32 315.17 4,683.66 18.01 0.00 67.68 0.00 15.05 0.00 0.00 67.69 14.20 136.24 MWD+IFR2+SAG+MS (3,2) 6,500.00 58.32 315.17 4,736.17 18.42 0.00 69.47 0.00 15.42 0.00 0.00 69.48 14.43 136.20 MWD+IFR2+SAG+MS (3,2) 6,600.00 58.32 315.17 4,788.68 18.83 0.00 71.26 0.00 15.79 0.00 0.00 71.27 14.65 136.16 MWD+IFR2+SAG+MS (3,2) 6,700.00 58.32 315.17 4,841.19 19.25 0.00 73.06 0.00 16.16 0.00 0.00 73.07 14.87 136.13 MWD+IFR2+SAG+MS (3,2) 6,800.00 58.32 315.17 4,893.70 19.66 0.00 74.85 0.00 16.53 0.00 0.00 74.86 15.10 136.09 MWD+IFR2+SAG+MS (3,2) 6,900.00 58.32 315.17 4,946.21 20.08 0.00 76.65 0.00 16.90 0.00 0.00 76.66 15.33 136.06 MWD+IFR2+SAG+MS (3,2) 7,000.00 58.32 315.17 4,998.73 20.50 0.00 78.44 0.00 17.28 0.00 0.00 78.45 15.56 136.03 MWD+IFR2+SAG+MS (3,2) 7,100.00 58.32 315.17 5,051.24 20.91 0.00 80.24 0.00 17.65 0.00 0.00 80.25 15.79 136.00 MWD+IFR2+SAG+MS (3,2) 7,200.00 58.32 315.17 5,103.75 21.33 0.00 82.04 0.00 18.02 0.00 0.00 82.04 16.02 135.97 MWD+IFR2+SAG+MS (3,2) 7,300.00 58.32 315.17 5,156.26 21.75 0.00 83.83 0.00 18.40 0.00 0.00 83.84 16.26 135.94 MWD+IFR2+SAG+MS (3,2) 7,400.00 58.32 315.17 5,208.77 22.17 0.00 85.63 0.00 18.77 0.00 0.00 85.64 16.50 135.92 MWD+IFR2+SAG+MS (3, 2) 7,500.00 58.32 315.17 5,261.29 22.59 0.00 87.43 0.00 19.15 0.00 0.00 87.44 16.73 135.89 MWD+IFR2+SAG+MS (3, 2) 7,600.00 58.32 315.17 5,313.80 23.01 0.00 89.23 0.00 19.52 0.00 0.00 89.24 16.97 135.87 MWD+IFR2+SAG+MS (3, 2) 2/23/2019 11:54:49AM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMP1 Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) r) (") (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (`) 7,700.00 58.32 315.17 5,366.31 23.43 0.00 91.03 0.00 19.90 0.00 0.00 91.04 17.21 135.84 MWD+IFR2+SAG+MS (3,2) 7,800.00 58.32 315.17 5,418.82 23.86 0.00 92.83 0.00 20.27 0.00 0.00 92.84 17.46 135.82 MWD+IFR2+SAG+MS (3,2) 7,900.00 58.32 315.17 5,471.33 24.28 0.00 94.63 0.00 20.65 0.00 0.00 94.64 17.70 135.80 MWD+IFR2+SAG+MS (3,2) 8,000.00 58.32 315.17 5,523.84 24.70 0.00 96.43 0.00 21.03 0.00 0.00 96.44 17.94 135.78 MWD+IFR2+SAG+MS (3,2) 8,100.00 58.32 315.17 5,576.36 25.12 0.00 98.23 0.00 21.40 0.00 0.00 98.24 18.19 135.76 MWD+IFR2+SAG+MS (3, 2) 8,200.00 58.32 315.17 5,628.87 25.55 0.00 100.03 0.00 21.78 0.00 0.00 100.04 18.44 135.74 MWD+IFR2+SAG+MS (3,2) 8,300.00 58.32 315.17 5,681.38 25.97 0.00 101.84 0.00 22.16 0.00 0.00 101.84 18.68 135.72 MWD+IFR2+SAG+MS (3, 2) 8,400.00 58.32 315.17 5,733.89 26.39 0.00 103.64 0.00 22.54 0.00 0.00 103.64 18.93 135.70 MWD+IFR2+SAG+MS (3,2) 8,500.00 58.32 315.17 5,786.40 26.82 0.00 105.44 0.00 22.92 0.00 0.00 105.44 19.19 135.69 MWD+IFR2+SAG+MS (3,2) 8,600.00 58.32 315.17 5,838.91 27.24 0.00 107.24 0.00 23.29 0.00 0.00 107.25 19.44 135.67 MWD+IFR2+SAG+MS (3,2) 8,700.00 58.32 315.17 5,891.43 27.67 0.00 109.05 0.00 23.67 0.00 0.00 109.05 19.69 135.65 MWD+IFR2+SAG+MS (3,2) 8,800.00 58.32 315.17 5,943.94 28.09 0.00 110.85 0.00 24.05 0.00 0.00 110.85 19.94 135.64 MWD+IFR2+SAG+MS (3,2) 8,900.00 58.32 315.17 5,996.45 28.52 0.00 112.65 0.00 24.43 0.00 0.00 112.66 20.20 135.62 MWD+IFR2+SAG+MS (3,2) 9,000.00 58.32 315.17 6,048.96 28.94 0.00 114.46 0.00 24.81 0.00 0.00 114.46 20.46 135.61 MWD+IFR2+SAG+MS (3,2) 9,100.00 58.32 315.17 6,101.47 29.37 0.00 116.26 0.00 25.19 0.00 0.00 116.26 20.71 135.60 MWD+IFR2+SAG+MS(3,2) 9,200.00 58.32 315.17 6,153.98 29.80 0.00 118.06 0.00 25.57 0.00 0.00 118.07 20.97 135.58 MWD+IFR2+SAG+MS (3,2) 9,300.00 58.32 315.17 6,206.50 30.22 0.00 119.87 0.00 25.95 0.00 0.00 119.87 21.23 135.57 MWD+IFR2+SAG+MS (3,2) 9,400.00 58.32 315.17 6,259.01 30.65 0.00 121.67 0.00 26.33 0.00 0.00 121.67 21.49 135.56 MWD+IFR2+SAG+MS (3,2) 9,500.00 58.32 315.17 6,311.52 31.08 0.00 123.48 0.00 26.72 0.00 0.00 123.48 21.76 135.54 MWD+IFR2+SAG+MS (3,2) 9,600.00 58.32 315.17 6,364.03 31.50 0.00 125.28 0.00 27.10 0.00 0.00 125.28 22.02 135.53 MWD+IFR2+SAG+MS (3,2) 9,700.00 58.32 315.17 6,416.54 31.93 0.00 127.08 0.00 27.48 0.00 0.00 127.09 22.28 135.52 MWD+IFR2+SAG+MS (3,2) 9,800.00 58.32 315.17 6,469.06 32.36 0.00 128.89 0.00 27.86 0.00 0.00 128.89 22.55 135.51 MWD+IFR2+SAG+MS (3,2) 9,900.00 58.32 315.17 6,521.57 32.79 0.00 130.69 0.00 28.24 0.00 0.00 130.70 22.81 135.50 MWD+IFR2+SAG+MS (3,2) 10,000.00 58.32 315.17 6,574.08 33.21 0.00 132.50 0.00 28.63 0.00 0.00 132.50 23.08 135.49 MWD+IFR2+SAG+MS (3,2) 10,100.00 58.32 315.17 6,626.59 33.64 0.00 134.30 0.00 29.01 0.00 0.00 134.31 23.35 135.48 MWD+IFR2+SAG+MS (3,2) 10,200.00 58.32 315.17 6,679.10 34.07 0.00 136.11 0.00 29.39 0.00 0.00 136.11 23.62 135.47 MWD+IFR2+SAG+MS (3,2) 10,300.00 58.32 315.17 6,731.61 34.50 0.00 137.92 0.00 29.77 0.00 0.00 137.92 23.89 135.46 MWD+IFR2+SAG+MS (3,2) 10,400.00 58.32 315.17 6,784.13 34.93 0.00 139.72 0.00 30.16 0.00 0.00 139.72 24.16 135.45 MWD+IFR2+SAG+MS (3,2) 10,500.00 58.32 315.17 6,836.64 35.36 0.00 141.53 0.00 30.54 0.00 0.00 141.53 24.43 135.44 MWD+IFR2+SAG+MS (3,2) 10,600.00 58.32 315.17 6,889.15 35.78 0.00 143.33 0.00 30.93 0.00 0.00 143.33 24.70 135.43 MWD+IFR2+SAG+MS (3,2) 10,700.00 58.32 315.17 6,941.66 36.21 0.00 145.14 0.00 31.31 0.00 0.00 145.14 24.98 135.42 MWD+IFR2+SAG+MS (3,2) 10,800.00 58.32 315.17 6,994.17 36.64 0.00 146.95 0.00 31.69 0.00 0.00 146.95 25.25 135.41 MWD+IFR2+SAG+MS (3,2) 10,900.00 58.32 315.17 7,046.68 37.07 0.00 148.75 0.00 32.08 0.00 0.00 148.75 25.53 135.40 MWD+IFR2+SAG+MS (3,2) 11,000.00 58.32 315.17 7,099.20 37.50 0.00 150.56 0.00 32.46 0.00 0.00 150.56 25.80 135.40 MWD+IFR2+SAG+MS (3,2) 11,100.00 58.32 315.17 7,151.71 37.93 0.00 152.36 0.00 32.85 0.00 0.00 152.36 26.08 135.39 MWD+IFR2+SAG+MS (3,2) 11,155.24 58.32 315.17 7,180.71 38.17 0.00 153.36 0.00 33.06 0.00 0.00 153.36 26.23 135.38 MWD+IFR2+SAG+MS(3,2) 11,200.00 59.59 315.70 7,203.80 38.35 0.00 154.18 0.00 33.23 0.00 0.00 154.18 26.36 135.38 MWD+IFR2+SAG+MS (3,2) 11,300.00 62.42 316.83 7,252.27 38.74 0.00 155.99 0.00 33.63 0.00 0.00 156.04 26.63 135.39 MWD+IFR2+SAG+MS (3, 2) 11,400.00 65.26 317.91 7,296.36 39.07 0.00 157.81 0.00 34.02 0.00 0.00 157.95 26.88 135.41 MWD+IFR2+SAG+MS (3,2) 11,500.00 68.11 318.94 7,335.93 39.30 0.00 159.62 0.00 34.43 0.00 0.00 159.91 27.13 135.44 MWD+IFR2+SAG+MS (3,2) 11,600.00 70.96 319.92 7,370.90 39.43 0.00 161.43 0.00 34.84 0.00 0.00 161.90 27.35 135.49 MWD+IFR2+SAG+MS (3,2) 11,700.00 73.82 320.88 7,401.15 39.44 0.00 163.22 0.00 35.25 0.00 0.00 163.91 27.56 135.55 MWD+IFR2+SAG+MS (3,2) 11,800.00 76.68 321.81 7,426.61 39.34 0.00 164.99 0.00 35.66 0.00 0.00 165.93 27.74 135.62 MWD+IFR2+SAG+MS (3,2) 11,900.00 79.55 322.71 7,447.20 39.12 0.00 166.73 0.00 36.07 0.00 0.00 167.95 27.91 135.70 MWD+IFR2+SAG+MS (3,2) 12,000.00 82.42 323.60 7,462.87 38.79 0.00 168.43 0.00 36.47 0.00 0.00 169.96 28.07 135.79 MWD+IFR2+SAG+MS (3,2) 12,100.00 85.29 324.48 7,473.58 38.36 0.00 170.08 0.00 36.88 0.00 0.00 171.95 28.20 135.89 MWD+IFR2+SAG+MS(3,2) 12,159.68 87.00 325.00 7,477.60 38.08 0.00 171.04 0.00 37.11 0.00 0.00 173.13 28.27 135.95 MWD+IFR2+SAG+MS(3,2) 12,200.00 87.00 325.00 7,479.71 38.24 0.00 171.84 0.00 37.27 0.00 0.00 173.92 28.31 136.00 MWD+IFR2+SAG+MS (3,2) 12,300.00 87.00 325.00 7,484.94 38.63 0.00 173.83 0.00 37.67 0.00 0.00 175.89 28.43 136.10 MWD+IFR2+SAG+MS (3,2) 12,400.00 87.00 325.00 7,490.18 39.03 0.00 175.82 0.00 38.07 0.00 0.00 177.86 28.54 136.21 MWD+IFR2+SAG+MS (3,2) 12,459.68 87.00 325.00 7,493.30 39.15 0.00 176.66 0.00 38.05 0.00 0.00 178.70 30.02 136.19 MWD OWSG (3.3) 12,479.68 87.00 325.00 7,494.35 39.15 0.00 176.62 0.00 38.05 0.00 0.00 178.86 30.04 136.20 MWD OWSG (3,3) 12,500.00 87.18 325.36 7,495.38 39.10 0.00 176.82 0.00 38.05 0.00 0.00 179.03 30.07 136.21 MWD OWSG (3,3) 12,600.00 88.07 327.16 7,499.53 38.80 0.00 176.78 0.00 38.08 0.00 0.00 179.93 30.20 136.28 MWD OWSG (3,3) 2/23/2019 11:54 49AM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 12,700.00 88.95 328.95 7,502.13 38.51 0.00 176.70 0.00 38.11 0.00 0.00 180.92 30.37 136.36 MWD OWSG (3, 3) 12,800.00 89.84 330.74 7,503.18 38.22 0.00 176.55 0.00 38.16 0.00 0.00 182.01 30.57 136.47 MWD OWSG (3,3) 12,870.26 90.47 332.00 7,502.98 38.03 0.00 176.41 0.00 38.21 0.00 0.00 182.82 30.74 136.56 MWD OWSG (3,3) 12,900.00 90.47 332.00 7,502.74 38.05 0.00 176.79 0.00 38.23 0.00 0.00 183.18 30.82 136.60 MWD OWSG (3,3) 13,000.00 90.47 332.00 7,501.92 38.14 0.00 178.12 0.00 38.31 0.00 0.00 184.43 31.10 136.75 MWD OWSG (3, 3) 13,100.00 90.47 332.00 7,501.11 38.24 0.00 179.55 0.00 38.41 0.00 0.00 185.78 31.43 136.91 MWD OWSG (3.3) 13,200.00 90.47 332.00 7,500.29 38.35 0.00 181.08 0.00 38.53 0.00 0.00 187.21 31.78 137.08 MWD OWSG (3,3) 13,300.00 90.47 332.00 7,499.47 38.49 0.00 182.70 0.00 38.66 0.00 0.00 188.73 32.16 137.26 MWD OWSG (3,3) 13,400.00 90.47 332.00 7,498.66 38.63 0.00 164.42 0.00 38.81 0.00 0.00 190.34 32.56 137.45 MWD OWSG (3,3) 13,500.00 90.47 332.00 7,497.84 38.79 0.00 186.22 0.00 38.97 0.00 0.00 192.03 32.98 137.65 MWD OWSG (3.3) 13,600.00 90.47 332.00 7,497.02 38.97 0.00 188.10 0.00 39.14 0.00 0.00 193.80 33.42 137.86 MWD OWSG (3.3) 13,700.00 90.47 332.00 7,496.20 39.16 0.00 190.07 0.00 39.33 0.00 0.00 195.65 33.88 138.08 MWD OWSG (3,3) 13,800.00 90.47 332.00 7,495.39 39.37 0.00 192.13 0.00 39.54 0.00 0.00 197.58 34.34 138.30 MWD OWSG (3,3) 13,900.00 90.47 332.00 7,494.57 39.59 0.00 194.25 0.00 39.76 0.00 0.00 199.58 34.82 138.52 MWD OWSG (3,3) 14,000.00 90.47 332.00 7,493.75 38.54 0.00 178.51 0.00 38.71 0.00 0.00 184.69 32.48 136.89 MWD+IFR2+SAG+MS (4,3) 14,100.00 90.47 332.00 7,492.93 38.63 0.00 179.10 0.00 36.80 0.00 0.00 185.24 32.70 136.97 MWD+IFR2+SAG+MS (4,3) 14,200.00 90.47 332.00 7,492.12 38.72 0.00 179.71 0.00 38.89 0.00 0.00 185.81 32.93 137.04 MWD+IFR2+SAG+MS (4,3) 14,300.00 90.47 332.00 7,491.30 38.82 0.00 180.35 0.00 38.99 0.00 0.00 186.40 33.16 137.12 MWD+IFR2+SAG+MS (4,3) 14,400.00 90.47 332.00 7,490.48 38.92 0.00 181.00 0.00 39.09 0.00 0.00 187.01 33.39 137.19 MWD+IFR2+SAG+MS (4,3) 14,500.00 90.47 332.00 7,489.67 39.03 0.00 181.67 0.00 39.19 0.00 0.00 187.63 33.63 137.28 MWD+IFR2+SAG+MS (4,3) 14,600.00 90.47 332.00 7,488.85 39.14 0.00 182.36 0.00 39.31 0.00 0.00 188.28 33.88 137.36 MWD+IFR2+SAG+MS (4,3) 14,700.00 90.47 332.00 7,488.03 39.25 0.00 183.07 0.00 39.42 0.00 0.00 188.94 34.12 137.44 MWD+IFR2+SAG+MS (4,3) 14,800.00 90.47 332.00 7,487.21 39.38 0.00 183.80 0.00 39.54 0.00 0.00 189.61 34.38 137.53 MWD+IFR2+SAG+MS (4,3) 14,900.00 90.47 332.00 7,486.40 39.50 0.00 184.55 0.00 39.67 0.00 0.00 190.31 34.63 137.62 MWD+IFR2+SAG+MS (4,3) 15,000.00 90.47 332.00 7,485.58 39.63 0.00 185.31 0.00 39.80 0.00 0.00 191.02 34.89 137.71 MWD+IFR2+SAG+MS (4,3) 15,100.00 90.47 332.00 7,484.76 39.77 0.00 186.09 0.00 39.94 0.00 0.00 191.75 35.15 137.80 MWD+IFR2+SAG+MS(4,3) 15,200.00 90.47 332.00 7,483.94 39.91 0.00 186.89 0.00 40.08 0.00 0.00 192.49 35.42 137.90 MWD+IFR2+SAG+MS (4, 3) 15,300.00 90.47 332.00 7,483.13 40.06 0.00 187.71 0.00 40.22 0.00 0.00 193.26 35.68 137.99 MWD+IFR2+SAG+MS (4,3) 15,400.00 90.47 332.00 7,482.31 40.21 0.00 188.54 0.00 40.37 0.00 0.00 194.03 35.95 138.09 MWD+IFR2+SAG+MS (4,3) 15,500.00 90.47 332.00 7,481.49 40.36 0.00 189.39 0.00 40.52 0.00 0.00 194.83 36.22 138.19 MWD+IFR2+SAG+MS (4,3) 15,600.00 90.47 332.00 7,480.68 40.52 0.00 190.26 0.00 40.68 0.00 0.00 195.64 36.50 138.29 MWD+IFR2+SAG+MS (4,3) 15,700.00 90.47 332.00 7,479.86 40.69 0.00 191.14 0.00 40.85 0.00 0.00 196.47 36.77 138.39 MWD+IFR2+SAG+MS (4,3) 15,800.00 90.47 332.00 7,479.04 40.85 0.00 192.04 0.00 41.01 0.00 0.00 197.31 37.05 138.49 MWD+IFR2+SAG+MS (4, 3) 15,900.00 90.47 332.00 7,478.22 41.03 0.00 192.96 0.00 41.18 0.00 0.00 198.17 37.32 138.59 MWD+IFR2+SAG+MS (4, 3) 16,000.00 90.47 332.00 7,477.41 41.20 0.00 193.89 0.00 41.36 0.00 0.00 199.04 37.60 138.70 MWD+IFR2+SAG+MS (4,3) 16,100.00 90.47 332.00 7,476.59 41.38 0.00 194.84 0.00 41.54 0.00 0.00 199.93 37.88 138.80 MWD+IFR2+SAG+MS (4,3) 16,200.00 90.47 332.00 7,475.77 41.57 0.00 195.80 0.00 41.72 0.00 0.00 200.83 36.16 138.91 MWD+IFR2+SAG+MS (4,3) 16,300.00 90.47 332.00 7,474.95 41.76 0.00 196.78 0.00 41.91 0.00 0.00 201.75 38.44 139.01 MWD+IFR2+SAG+MS (4,3) 16,400.00 90.47 332.00 7,474.14 41.95 0.00 197.77 0.00 42.11 0.00 0.00 202.69 38.72 139.12 MWD+IFR2+SAG+MS (4,3) 16,500.00 90.47 332.00 7,473.32 42.15 0.00 198.78 0.00 42.30 0.00 0.00 203.64 39.00 139.23 MWD+IFR2+SAG+MS (4,3) 16,600.00 90.47 332.00 7,472.50 42.35 0.00 199.80 0.00 42.50 0.00 0.00 204.60 39.28 139.33 MWD+IFR2+SAG+MS (4,3) 16,700.00 90.47 332.00 7,471.69 42.56 0.00 200.84 0.00 42.71 0.00 0.00 205.57 39.56 139.44 MWD+IFR2+SAG+MS (4,3) 16,800.00 90.47 332.00 7,470.87 42.76 0.00 201.89 0.00 42.91 0.00 0.00 206.57 39.83 139.55 MWD+IFR2+SAG+MS (4,3) 16,900.00 90.47 332.00 7,470.05 42.98 0.00 202.95 0.00 43.13 0.00 0.00 207.57 40.11 139.66 MWD+IFR2+SAG+MS (4,3) 17,000.00 90.47 332.00 7,469.23 43.19 0.00 204.03 0.00 43.34 0.00 0.00 208.59 40.39 139.77 MWD+IFR2+SAG+MS (4,3) 17,100.00 90.47 332.00 7,468.42 43.41 0.00 205.12 0.00 43.56 0.00 0.00 209.62 40.67 139.87 MWD+IFR2+SAG+MS (4,3) 17,200.00 90.47 332.00 7,467.60 43.64 0.00 206.22 0.00 43.78 0.00 0.00 210.67 40.94 139.98 MWD+IFR2+SAG+MS (4,3) 17,300.00 90.47 332.00 7,466.78 43.87 0.00 207.34 0.00 44.01 0.00 0.00 211.73 41.22 140.09 MWD+IFR2+SAG+MS (4.3) 17,400.00 90.47 332.00 7,465.96 44.10 0.00 208.47 0.00 44.24 0.00 0.00 212.80 41.49 140.20 MWD+IFR2+SAG+MS (4,3) 17,500.00 90.47 332.00 7,465.15 44.33 0.00 209.61 0.00 44.47 0.00 0.00 213.88 41.77 140.31 MWD+IFR2+SAG+MS (4,3) 17,600.00 90.47 332.00 7,464.33 44.57 0.00 210.77 0.00 44.71 0.00 0.00 214.98 42.04 140.42 MWD+IFR2+SAG+MS (4,3) 17,700.00 90.47 332.00 7,463.51 44.81 0.00 211.93 0.00 44.95 0.00 0.00 216.09 42.31 140.52 MWD+IFR2+SAG+MS (4,3) 17,800.00 90.47 332.00 7,462.70 45.05 0.00 213.11 0.00 45.20 0.00 0.00 217.21 42.58 140.63 MWD+IFR2+SAG+MS (4,3) 17,900.00 90.47 332.00 7,461.88 45.30 0.00 214.30 0.00 45.44 0.00 0.00 218.34 42.85 140.74 MWD+IFR2+SAG+MS (4, 3) 212312019 11:54:49AM Page 6 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: C05-92 wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (Usft) (") (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) r) 18,000.00 90.47 332.00 7,461.06 45.55 0.00 215.50 0.00 45.69 0.00 0.00 219.49 43.11 140.85 MWD+IFR2+SAG+MS (4,3) 18,100.00 90.47 332.00 7,460.24 45.81 0.00 216.72 0.00 45.95 0.00 0.00 220.65 43.38 140.95 MWD+IFR2+SAG+MS (4,3) 18,200.00 90.47 332.00 7,459.43 46.06 0.00 217.94 0.00 46.20 0.00 0.00 221.82 43.64 141.06 MWD+IFR2+SAG+MS (4,3) 18,300.00 90.47 332.00 7,458.61 46.32 0.00 219.18 0.00 46.46 0.00 0.00 223.00 43.90 141.16 MWD+IFR2+SAG+MS (4,3) 18,400.00 90.47 332.00 7,457.79 46.59 0.00 220.42 0.00 46.72 0.00 0.00 224.19 44.17 141.27 MWD+IFR2+SAG+MS (4, 3) 18,500.00 90.47 332.00 7,456.97 46.85 0.00 221.68 0.00 46.99 0.00 0.00 225.39 44.42 141.37 MWD+IFR2+SAG+MS (4,3) 18,600.00 90.47 332.00 7,456.16 47.12 0.00 222.94 0.00 47.26 0.00 0.00 226.61 44.68 141.48 MWD+IFR2+SAG+MS (4,3) 18,700.00 90.47 332.00 7,455.34 47.39 0.00 224.22 0.00 47.53 0.00 0.00 227.83 44.94 141.58 MWD+IFR2+SAG+MS (4,3) 18,800.00 90.47 332.00 7,454.52 47.67 0.00 225.51 0.00 47.80 0.00 0.00 229.07 45.19 141.68 MWD+IFR2+SAG+MS (4,3) 18,900.00 90.47 332.00 7,453.71 47.95 0.00 226.80 0.00 48.08 0.00 0.00 230.31 45.44 141.79 MWD+IFR2+SAG+MS (4, 3) 19,000.00 90.47 332.00 7,452.89 48.23 0.00 228.11 0.00 48.36 0.00 0.00 231.57 45.70 141.89 MWD+IFR2+SAG+MS (4,3) 19,100.00 90.47 332.00 7,452.07 48.51 0.00 229.43 0.00 48.64 0.00 0.00 232.84 45.94 141.99 MWD+IFR2+SAG+MS (4,3) 19,200.00 90.47 332.00 7,451.25 48.79 0.00 230.75 0.00 48.92 0.00 0.00 234.11 46.19 142.09 MWD+IFR2+SAG+MS (4,3) 19,300.00 90.47 332.00 7,450.44 49.08 0.00 232.09 0.00 49.21 0.00 0.00 235.40 46.44 142.19 MWD+IFR2+SAG+MS (4,3) 19,400.00 90.47 332.00 7,449.62 49.37 0.00 233.43 0.00 49.50 0.00 0.00 236.69 46.68 142.28 MWD+IFR2+SAG+MS (4, 3) 19,500.00 90.47 332.00 7,448.80 49.66 0.00 234.78 0.00 49.79 0.00 0.00 238.00 46.92 142.38 MWD+IFR2+SAG+MS (4,3) 19,600.00 90.47 332.00 7,447.98 49.96 0.00 236.14 0.00 50.08 0.00 0.00 239.31 47.16 142.48 MWD+IFR2+SAG+MS (4,3) 19,700.00 90.47 332.00 7,447.17 50.26 0.00 237.51 0.00 50.38 0.00 0.00 240.64 47.40 142.57 MWD+IFR2+SAG+MS (4,3) 19,800.00 90.47 332.00 7,446.35 50.56 0.00 238.89 0.00 50.68 0.00 0.00 241.97 47.64 142.67 MWD+IFR2+SAG+MS (4,3) 19,900.00 90.47 332.00 7,445.53 50.86 0.00 240.28 0.00 50.98 0.00 0.00 243.31 47.88 142.76 MWD+IFR2+SAG+MS (4,3) 20,000.00 90.47 332.00 7,444.72 51.16 0.00 241.67 0.00 51.28 0.00 0.00 244.66 48.11 142.86 MWD+IFR2+SAG+MS (4,3) 20,100.00 90.47 332.00 7,443.90 51.47 0.00 243.08 0.00 51.59 0.00 0.00 246.02 48.34 142.95 MWD+IFR2+SAG+MS(4,3) 20,200.00 90.47 332.00 7,443.08 51.78 0.00 244.49 0.00 51.90 0.00 0.00 247.39 48.57 143.04 MWD+IFR2+SAG+MS (4,3) 20,300.00 90.47 332.00 7,442.26 52.09 0.00 245.91 0.00 52.21 0.00 0.00 248.77 48.80 143.13 MWD+IFR2+SAG+MS (4,3) 20,400.00 90.47 332.00 7,441.45 52.40 0.00 247.33 0.00 52.52 0.00 0.00 250.15 49.02 143.22 MWD+IFR2+SAG+MS (4,3) 20,500.00 90.47 332.00 7,440.63 52.72 0.00 248.77 0.00 52.83 0.00 0.00 251.54 49.25 143.31 MWD+IFR2+SAG+MS (4,3) 20,600.00 90.47 332.00 7,439.81 53.03 0.00 250.21 0.00 53.15 0.00 0.00 252.94 49.47 143.40 MWD+IFR2+SAG+MS (4,3) 20,700.00 90.47 332.00 7,438.99 53.35 0.00 251.66 0.00 53.47 0.00 0.00 254.35 49.69 143.49 MWD+IFR2+SAG+MS (4,3) 20,800.00 90.47 332.00 7,438.18 53.67 0.00 253.11 0.00 53.79 0.00 0.00 255.77 49.91 143.57 MWD+IFR2+SAG+MS (4,3) 20,900.00 90.47 332.00 7,437.36 54.00 0.00 254.57 0.00 54.11 0.00 0.00 257.19 50.13 143.66 MWD+IFR2+SAG+MS (4,3) 21,000.00 90.47 332.00 7,436.54 54.32 0.00 256.04 0.00 54.43 0.00 0.00 258.62 50.35 143.74 MWD+IFR2+SAG+MS (4,3) 21,100.00 90.47 332.00 7,435.73 54.65 0.00 257.52 0.00 54.76 0.00 0.00 260.06 50.56 143.83 MWD+IFR2+SAG+MS (4,3) 21,200.00 90.47 332.00 7,434.91 54.98 0.00 259.00 0.00 55.09 0.00 0.00 261.51 50.78 143.91 MWD+IFR2+SAG+MS (4,3) 21,300.00 90.47 332.00 7,434.09 55.31 0.00 260.49 0.00 55.42 0.00 0.00 262.96 50.99 143.99 MWD+IFR2+SAG+MS (4, 3) 21,400.00 90.47 332.00 7,433.27 55.64 0.00 261.99 0.00 55.75 0.00 0.00 264.42 51.20 144.07 MWD+IFR2+SAG+MS (4,3) 21,500.00 90.47 332.00 7,432.46 55.97 0.00 263.49 0.00 56.08 0.00 0.00 265.89 51.41 144.15 MWD+IFR2+SAG+MS (4,3) 21,600.00 90.47 332.00 7,431.64 56.31 0.00 265.00 0.00 56.42 0.00 0.00 267.36 51.61 144.23 MWD+IFR2+SAG+MS (4,3) 21,700.00 90.47 332.00 7,430.82 56.65 0.00 266.51 0.00 56.75 0.00 0.00 268.84 51.82 144.31 MWD+IFR2+SAG+MS (4,3) 21,800.00 90.47 332.00 7,430.00 56.98 0.00 268.03 0,00 57.09 0.00 0.00 270.32 52.02 144.39 MWD+IFR2+SAG+MS (4, 3) 21,900.00 90.47 332.00 7,429.19 57.32 0.00 269.56 0.00 57.43 0.00 0.00 271.82 52.23 144.46 MWD+IFR2+SAG+MS (4,3) 22,000.00 90.47 332.00 7,428.37 57.67 0.00 271.09 0.00 57.77 0.00 0.00 273.32 52.43 144.54 MWD+IFR2+SAG+MS (4, 3) 22,100.00 90.47 332.00 7,427.55 58.01 0.00 272.62 0.00 58.11 0.00 0.00 274.82 52.63 144.61 MWD+IFR2+SAG+MS (4,3) 22,200.00 90.47 332.00 7,426.74 58.35 0.00 274.17 0.00 58.46 0.00 0.00 276.33 52.83 144.69 MWD+IFR2+SAG+MS (4,3) 22,300.00 90.47 332.00 7,425.92 58.70 0.00 275.72 0.00 58.80 0.00 0.00 277.85 53.02 144.76 MWD+IFR2+SAG+MS (4,3) 22,400.00 90.47 332.00 7,425.10 59.05 0.00 277.27 0.00 59.15 0.00 0.00 279.37 53.22 144.83 MWD+IFR2+SAG+MS (4,3) 22,500.00 90.47 332.00 7,424.28 59.40 0.00 278.83 0.00 59.50 0.00 0.00 280.90 53.41 144.90 MWD+IFR2+SAG+MS (4,3) 22,600.00 90.47 332.00 7,423.47 59.75 0.00 280.39 0.00 59.85 0.00 0.00 282.44 53.61 144.97 MWD+IFR2+SAG+MS (4, 3) 22,700.00 90.47 332.00 7,422.65 60.10 0.00 281.96 0.00 60.20 0.00 0.00 283.98 53.80 145.04 MWD+IFR2+SAG+MS (4,3) 22,800.00 90.47 332.00 7,421.83 60.45 0.00 283.54 0.00 60.55 0.00 0.00 285.53 53.99 145.11 MWD+IFR2+SAG+MS (4,3) 22,900.00 90.47 332.00 7,421.01 60.81 0.00 285.12 0.00 60.91 0.00 0.00 287.08 54.18 145.18 MWD+IFR2+SAG+MS (4,3) 23,000.00 90.47 332.00 7,420.20 61.17 0.00 286.70 0.00 61.26 0.00 0.00 288.63 54.37 145.25 MWD+IFR2+SAG+MS (4,3) 23,100.00 90.47 332.00 7,419.38 61.52 0.00 288.29 0.00 61.62 0.00 0.00 290.20 54.55 145.31 MWD+IFR2+SAG+MS (4,3) 23,200.00 90.47 332.00 7,418.56 61.88 0.00 289.89 0.00 61.98 0.00 0.00 291.76 54.74 145.38 MWD+IFR2+SAG+MS (4,3) 23,300.00 90.47 332.00 7,417.75 62.24 0.00 291.48 0.00 62.34 0.00 0.00 293.34 54.92 145.44 MWD+IFR2+SAG+MS (4,3) 2/23/2019 11:54:49AM Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) 0 23,400.00 90.47 332.00 7,416.93 62.60 0.00 293.09 0.00 62.70 0.00 0.00 294.91 55.10 145.51 MWD+IFR2+SAG+MS (4,3) 23,500.00 90.47 332.00 7,416.11 62.97 0.00 294.70 0.00 63.06 0.00 0.00 296.50 55.29 145.57 MWD+IFR2+SAG+MS (4, 3) 23,600.00 90.47 332.00 7,415.29 63.33 0.00 296.31 0.00 63.42 0.00 0.00 298.08 55.47 145.63 MWD+IFR2+SAG+MS (4,3) 23,700.00 90.47 332.00 7,414.48 63.69 0.00 297.92 0.00 63.79 0.00 0.00 299.68 55.65 145.70 MWD+IFR2+SAG+MS (4,3) 23,800.00 90.47 332.00 7,413.66 64.06 0.00 299.55 0.00 64.15 0.00 0.00 301.27 55.83 145.76 MWD+IFR2+SAG+MS (4,3) 23,900.00 90.47 332.00 7,412.84 64.43 0.00 301.17 0.00 64.52 0.00 0.00 302.87 56.00 145.82 MWD+IFR2+SAG+MS (4,3) 24,000.00 90.47 332.00 7,412.02 64.79 0.00 302.80 0.00 64.89 0.00 0.00 304.48 56.18 145.88 MWD+IFR2+SAG+MS (4,3) 24,100.00 90.47 332.00 7,411.21 65.16 0.00 304.43 0.00 65.25 0.00 0.00 306.09 56.36 145.93 MWD+IFR2+SAG+MS (4, 3) 24,200.00 90.47 332.00 7,410.39 65.53 0.00 306.07 0.00 65.62 0.00 0.00 307.70 56.53 145.99 MWD+IFR2+SAG+MS (4,3) 24,300.00 90.47 332.00 7,409.57 65.91 0.00 307.71 0.00 65.99 0.00 0.00 309.32 56.70 146.05 MWD+IFR2+SAG+MS (4,3) 24,400.00 90.47 332.00 7,408.75 66.28 0.00 309.36 0.00 66.37 0.00 0.00 310.95 56.88 146.11 MWD+IFR2+SAG+MS (4,3) 24,500.00 90.47 332.00 7,407.94 66.65 0.00 311.01 0.00 66.74 0.00 0.00 312.57 57.05 146.16 MWD+IFR2+SAG+MS (4,3) 24,600.00 90.47 332.00 7,407.12 67.03 0.00 312.66 0.00 67.11 0.00 0.00 314.21 57.22 146.22 MWD+IFR2+SAG+MS (4,3) 24,700.00 90.47 332.00 7,406.30 67.40 0.00 314.31 0.00 67.49 0.00 0.00 315.84 57.39 146.27 MWD+IFR2+SAG+MS (4,3) 24,800.00 90.47 332.00 7,405.49 67.78 0.00 315.97 0.00 67.86 0.00 0.00 317.48 57.56 146.32 MWD+IFR2+SAG+MS (4,3) 24,900.00 90.47 332.00 7,404.67 68.16 0.00 317.64 0.00 68.24 0.00 0.00 319.12 57.72 146.38 MWD+IFR2+SAG+M8 (4,3) 25,000.00 90.47 332.00 7,403.85 68.53 0.00 319.31 0.00 68.62 0.00 0.00 320.77 57.89 146.43 MWD+IFR2+SAG+MS (4, 3) 25,100.00 90.47 332.00 7,403.03 68.91 0.00 320.98 0.00 69.00 0.00 0.00 322.42 58.06 146.48 MWD+IFR2+SAG+MS (4,3) 25,200.00 90.47 332.00 7,402.22 69.29 0.00 322.65 0.00 69.38 0.00 0.00 324.08 58.22 146.53 MWD+IFR2+SAG+MS (4,3) 25,300.00 90.47 332.00 7,401.40 69.67 0.00 324.33 0.00 69.76 0.00 0.00 325.74 58.39 146.58 MWD+IFR2+SAG+MS (4,3) 25,400.00 90.47 332.00 7,400.58 70.06 0.00 326.01 0.00 70.14 0.00 0.00 327.40 58.55 146.63 MWD+IFR2+SAG+MS (4, 3) 25,500.00 90.47 332.00 7,399.76 70.44 0.00 327.69 0.00 70.52 0.00 0.00 329.07 58.71 146.68 MWD+IFR2+SAG+MS (4,3) 25,600.00 90.47 332.00 7,398.95 70.82 0.00 329.38 0.00 70.90 0.00 0.00 330.74 58.88 146.73 MWD+IFR2+SAG+MS (4,3) 25,700.00 90.47 332.00 7,398.13 71.21 0.00 331.07 0.00 71.29 0.00 0.00 332.41 59.04 146.78 MWD+IFR2+SAG+MS (4,3) 25,800.00 90.47 332.00 7,397.31 71.59 0.00 332.76 0.00 71.67 0.00 0.00 334.08 59.20 146.82 MWD+IFR2+SAG+MS (4,3) 25,900.00 90.47 332.00 7,396.50 71.98 0.00 334.46 0.00 72.06 0.00 0.00 335.76 59.36 146.87 MWD+IFR2+SAG+MS (4, 3) 26,000.00 90.47 332.00 7,395.68 72.36 0.00 336.16 0.00 72.44 0.00 0.00 337.45 59.52 146.92 MWD+IFR2+SAG+MS (4,3) 26,100.00 90.47 332.00 7,394.86 72.75 0.00 337.86 0.00 72.83 0.00 0.00 339.13 59.68 146.96 MWD+IFR2+SAG+MS (4,3) 26,200.00 90.47 332.00 7,394.04 73.14 0.00 339.57 0.00 73.22 0.00 0.00 340.82 59.83 147.01 MWD+IFR2+SAG+MS (4,3) 26,300.00 90.47 332.00 7,393.23 73.53 0.00 341.28 0.00 73.61 0.00 0.00 342.52 59.99 147.05 MWD+IFR2+SAG+MS (4,3) 26,400.00 90.47 332.00 7,392.41 73.92 0.00 342.99 0.00 74.00 0.00 0.00 344.21 60.15 147.10 MWD+IFR2+SAG+MS (4,3) 26,500.00 90.47 332.00 7,391.59 74.31 0.00 344.70 0.00 74.39 0.00 0.00 345.91 60.30 147.14 MWD+IFR2+SAG+MS (4,3) 26,600.00 90.47 332.00 7,390.77 74.70 0.00 346.42 0.00 74.78 0.00 0.00 347.61 60.46 147.18 MWD+IFR2+SAG+MS (4,3) 26,700.00 90.47 332.00 7,389.96 75.09 0.00 348.14 0.00 75.17 0.00 0.00 349.32 60.61 147.22 MWD+IFR2+SAG+MS (4, 3) 26,800.00 90.47 332.00 7,389.14 75.49 0.00 349.86 0.00 75.56 0.00 0.00 351.02 60.77 147.27 MWD+IFR2+SAG+MS (4, 3) 26,900.00 90.47 332.00 7,388.32 75.88 0.00 351.59 0.00 75.95 0.00 0.00 352.73 60.92 147.31 MWD+IFR2+SAG+MS (4,3) 27,000.00 90.47 332.00 7,387.51 76.27 0.00 353.31 0.00 76.35 0.00 0.00 354.45 61.07 147.35 MWD+IFR2+SAG+MS (4,3) 27,100.00 90.47 332.00 7,386.69 76.67 0.00 355.04 0.00 76.74 0.00 0.00 356.16 61.23 147.39 MWD+IFR2+SAG+MS (4, 3) 27,200.00 90.47 332.00 7,385.87 77.06 0.00 356.78 0.00 77.14 0.00 0.00 357.88 61.38 147.43 MWD+IFR2+SAG+MS (4, 3) 27,300.00 90.47 332.00 7,385.05 77.46 0.00 358.51 0.00 77.53 0.00 0.00 359.61 61.53 147.47 MWD+IFR2+SAG+MS (4,3) 27,400.00 90.47 332.00 7,384.24 77.86 0.00 360.25 0.00 77.93 0.00 0.00 361.33 61.68 147.51 MWD+IFR2+SAG+MS (4,3) 27,500.00 90.47 332.00 7,383.42 78.25 0.00 361.99 0.00 78.32 0.00 0.00 363.06 61.83 147.54 MWD+IFR2+SAG+MS (4,3) 27,600.00 90.47 332.00 7,382.60 78.65 0.00 363.73 0.00 78.72 0.00 0.00 364.79 61.98 147.58 MWD+IFR2+SAG+MS (4.3) 27,700.00 90.47 332.00 7,381.78 79.05 0.00 365.48 0.00 79.12 0.00 0.00 366.52 62.13 147.62 MWD+IFR2+SAG+MS (4,3) 27,800.00 90.47 332.00 7,380.97 79.45 0.00 367.22 0.00 79.52 0.00 0.00 368.25 62.28 147.66 MWD+IFR2+SAG+MS (4,3) 27,900.00 90.47 332.00 7,380.15 79.85 0.00 368.97 0.00 79.92 0.00 0.00 369.99 62.43 147.69 MWD+IFR2+SAG+MS (4,3) 28,000.00 90.47 332.00 7,379.33 80.25 0.00 370.73 0.00 80.32 0.00 0.00 371.73 62.57 147.73 MWD+IFR2+SAG+MS (4, 3) 28,100.00 90.47 332.00 7,378.52 80.65 0.00 372.48 0.00 80.72 0.00 0.00 373.47 62.72 147.77 MWD+IFR2+SAG+MS(4,3) 28,200.00 90.47 332.00 7,377.70 81.05 0.00 374.24 0.00 81.12 0.00 0.00 375.22 62.87 147.80 MWD+IFR2+SAG+MS (4,3) 28,300.00 90.47 332.00 7,376.88 81.45 0.00 375.99 0.00 81.52 0.00 0.00 376.96 63.01 147.83 MWD+IFR2+SAG+MS (4, 3) 28,400.00 90.47 332.00 7,376.06 81.86 0.00 377.75 0.00 81.92 0.00 0.00 378.71 63.16 147.87 MWD+IFR2+SAG+MS (4,3) 28,500.00 90.47 332.00 7,375.25 82.26 0.00 379.52 0.00 82.33 0.00 0.00 380.46 63.30 147.90 MWD+IFR2+SAG+MS (4,3) 28,600.00 90.47 332.00 7,374.43 82.66 0.00 381.28 0.00 82.73 0.00 0.00 382.22 63.45 147.94 MWD+IFR2+SAG+MS (4,3) 28,700.00 90.47 332.00 7,373.61 83.07 0.00 383.05 0.00 83.13 0.00 0.00 383.97 63.59 147.97 MWD+IFR2+SAG+MS (4,3) 2/23/2019 11:54:49AM Page 8 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 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: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMP1 Position uncertainty and bias at survey station Vertical Casing Hole Depth Measured Inclination Azimuth Vertical Highslde 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) (°) 28,738.16 90.47 332.00 7,373.30 83.22 0.00 383.72 0.00 83.29 0.00 0.00 384.64 63.65 147.98 MWD+1FR2+SAG+MS (4, 3) Design Targets Target Name hittmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (1 (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude CD5-92 (11A) T02 Toe L 0.00 0.00 7,373.30 20,880.52 -13,684.07 5,986,854.25 1,476,465.24 70° 22' 14.852 N 151° 19'57.241 W plan hits target center Circle (radius 100.00) CD5-92 (11A) T01 Heel - plan hits target center -Circle (radius 100.00) CD5-92 (11A) T01 Heel plan hits target center Circle (radius 1,320.00) Casing Points 0.00 0.00 7,493.30 6,521.12 -6,020.02 5,972,345.00 1,483,839.00 700 19' 53.724 N 151° 16' 12.690 W I 0.00 0.00 7,493.30 6,521.12 -6,020.02 5,972,345.00 1,483,839.00 70° 19' 53.724 N 151° 16' 12.690 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 118.40 118.40 20 x 42 20.000 42.000 2,245.93 2,188.30 10-3/4 x 13-1/2 10.750 13.500 12,459.68 7,493.30 7-5/8 x 9-7/8 by 11 7.625 11.000 28,738.16 7,373.30 4-1/2 x 6-3/4 4.500 6.750 2/23/2019 11:54:49AM Page 9 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-92 Wellbore: CD5-92 Design: CD5-92 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: CD5-92 - Slot 92 Plan: D142 39.4+33.9 @ 73.30usft (D142) Plan: D142 39.4+33.9 @ 73.30usft (D142) True Minimum Curvature 2.00 sigma OAKEDMP1 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,325.93 1,323.30 Permafrost Base 2,336.18 2,267.30 C-30 4,552.12 3,713.30 K-3 5,005.35 3,951.30 K-2 5,652.82 4,291.30 Albian 97 7,442.90 5,231.30 Albian 96 10,964.02 7,080.30 HRZ 11,208.93 7,208.30 Kalubik 11,388.00 7,291.30 Kuparuk C 11,390.36 7,292.30 LCU 11,879.09 7,443.30 Alpine C 11,906.11 7,448.30 UJU 12,383.25 7,489.30 AlpineA Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 750.00 750.00 0.00 0.00 1,050.00 1,049.69 10.20 -5.89 2,245.93 2,188.30 301.52 -174.08 2,265.93 2,205.89 309.76 -178.84 3,837.02 3,337.79 1,128.23 -854.12 11,155.24 7,180.71 5,544.86 -5,245.21 12,159.68 7,477.60 6,275.71 -5,848.18 12,459.68 7,493.30 6,521.12 -6,020.02 12,479.68 7,494.35 6,537.48 -6,031.48 12,870.26 7,502.98 6,870.18 -6,235.32 28,738.16 7,373.30 20,880.52 -13,684.07 Comment KOP: Start 1.5°/100' DLS, 330° TF, for 300' Start 2°/100' DLS, 0° TF, for 1195.93' Hold for 20' Start 2°/100' DLS, -24.7° TF, for 1571.09' Hold for 7318.22' Start 3°/100' DLS, 19.86° TF, for 1004.45' Hold for 300' Adjust TF to 0°, for 20' Start 2°/100' DLS, 63.75° TF, for 390.58' Hold for 15867.9' TD: 28738.16' MD, 7373.3' TVD Checked By: Approved By: Date: 2/23/2019 11:54.49AM Page 10 COMPASS 5000.14 Build 85D *dF . ............ ........... . . ............ . 8:", January 16 2019 WELLBORE TARGET DETAILS (IMP CG ROIHATES) CD5-92 wp05 Hame TVD 90,M) COS92 (t1A) T02 1418 7491.70 Circle (Radom.- 10000) THft- Up 20 7C IIIA) T02 Tce Update OR3049'OHCietle (Radius.- IW.M 2017 COS (117) ..__. X817 7488-70 C W (R,dim: Quarter Mile View 2017 CD' (148) Tce D 1 7371.70 C (Radm. 10000) IMM 2017 CD5 (14B) Hee1082817 7829.]0 C'vck (Rallis: 100110) 2017 COS (148) T 0 W ]530.70 Cvcb (Radi,s: IMOG)) M17C05 (1 C) Hee1082817 7�MC (Radom: 10000) Z11] LO.5 (14C) Tce 082817 7858.70 Grob (Radius: 10000) COS92 (11A) MI Heel W1218 7534.70 Gide (Radi,s: 100001 COSW (IIA) T01 Heel 121418_T4GI1OCirb IRa m: 132000) 2(11A) TW Tce 091218 7414.70 C (RedM: 100.00) 92 (11 A) TM Toe 121418 7379.70 Cede (Radius: 100.00) CD592 (11N T02T 121418 DR9.70C6cb Rffi : 1320.00 22500- 25008000 l G GOA05A2P A8000— �O C C) O !;� 3500 _ _ _ 1- — —_.......... ___.... _... i 5 2 c0 + � � I -9000- _. ........................ ....... c o 4500- 5000 0- -27000 -27000 -22500 -18000 -13500 -9000 -4500 0 4500 9000 CD5-92wp05 Surface Location Ll CPA,I Coordinate Converter — ❑ X From: To: Datum: INAD83 I Region: alaska Datum: NAD27 Region: lalaska f Latitude/Longitude Decimal Degrees �' Latitude/Longitude Decimal Degrees + R r UTM Zone: F— r South r UTM Zone: True South i+` State Plane Zone:4 + Units: us -ft ro State Plane Zone: 4 Units: us ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: -- ____..___--... _ _ _. __ ___ Ending Coordinates: --- - -- -- X: 1589726.49 X 349693.3514262 Y: 5965704.86 Y 5965958.88690897 ..........G- rans .........................., ransform Quit Help CD5-92wa05 Surface Casin M CPA[ Coordinate Converter From: - Datum NAD83 Region: alaska + r Latitude/Longitude Decimal Degrees C UTM Zone:y r South C' State Plane Zone: 4 D Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X: 11489558.51 -- Y: 15966009.79 — ❑ x -To: --- -----] Datum NAD27 Region: alaska f- Latitude/Longitude I Decimal Degrees���� C` UTM Zone: True r South f+ State Plane Zone: 4 Units: ft C Legal Description (NAD27 only) - Ending Coordinates. -- X 349525.381623568 Y: I 5966263.82411026 i Transform Quit Help CD5-92w 05 Intermediate Casing M CPAI Coordinate Converter — ❑ X Datum: NA1)83 Region: jalaska Datum: INAD27 Region: jalaska wl f __ r Latitude/Longitude Decimal Degrees I" Latitude/Longitude Decimal Degrees r UTM Zone: South i" UTM Zone: True i South e r State Plane Zone:4 Units: us fk t* State Plane Zone: 4 + Units: us fk Legal Description (NAD27 only) ; t" Legal Description (NAD27 only) Starting Coordinates:— Ending Coordinates:---- - - — x: 11483839 X: 343806.048652669 I Y: 15972345 Y: 5972599.2732402 € Transform Quit Help CD5-92w 05 Tog of Production Horizon M CP:AI Coordinate Converter — ❑ X - From: To: Datum: NA583+ Region: alaska w Datum: INAD27 + Region: alaska + f' Latitude/Longitude Decimal De Degrees Degrees Latitude/Longitude Decimal � 9 t" UTM Zone:1 South r UTM Zone: True I— South >+ State Plane Zone: 4 + Units us-ft + i� State Plane Zone: q + Units: us-ft + Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: - -- — -- t Ending Coordinates: X: 1483872.30 X: 343839.347093835 Y: 5972295.84 Y: 5972550.11150277 Transform w Quit Help CD5-92wp05 TD M CPAI Coordinate Converter — ❑ X From: — — — _ f- To: — Datum: NpD$3 Region: alaska Datum: NAD27 Region: alaska r LatitudeiLongitude IDecimal Degrees i j ( Latitude/LongitudeDecimal Degrees i" UTM Zone: f— r- South t UTM Zone: True r- South C� State Plane Zone: q Units: us ft I +: State Plane Zone:14 Units: us•ft C` Legal Description (NAD27 only) r Legal Description (NAD27 only) i Starting Coordinates:- - - - - - ( Ending Coordinates - -- X: 11476465.24 X: 336432.7$$696867- 1 Y: 15986854.25 I I y 15987108.93705226 i Transform Quit Help CD5-92wn05 Surface Location M C -N l Coerdinate'_ _ nerter From: Datum: FAD-83Region: alaska Latitude/Longitude Decimal Degrees r UTM Zone:IF South State Plane Zone:4 Units: us ft Starting Coordinates: - -_ CD5-9 Fri Y: 1489726.49 5965704.86 Surface Casin M Cpgl CQmrdinate Converter El X Datum: IAD27 � Region: alaska 1 f ' Latitude/Longitude Decimal Degrees UTM Zone: ITrue F South State Plane Zone: 4 Units: Ius fk if Legal Description (NAD27 only) Legal Description_ Township: 011 N 7, Range: 004I E Meridian: Section: 1g FNL 1249.59596 IFEL 112286.6235 Transform Quit Help — 0 X From:_.___ __. To: IaDatum: NAD83 Region: alaska . Datum. NAD27 Region: alaska i" Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees J r UTM Zone: r— f- South t" UTM Zone: True r South i C- State Plane Zone: 4 Units: us ft r Skate Plane Zone: 4 Units: us ft 3 r Leval L e rrs,,ti[rrt 4.'L F a :',) t- Legal Description (NAD27 only) L_.-- ----_______ FStarting Coordinates — - - Legal Description- - - -- ---- --, X 1489558.51 { Township: 011 N Range: 004 E . Y: 15966009.79 Meridian: U Section: 7— FNL 5224.8199 FF: -]2459.5210 ................_Transform Quit Help CD5-92wp05 Intermediate Casi M CPAI Coordinate Converter - From: Datum: Ngpg3 Region: alaska Latitude}Longitude Decimal Degrees " UTM Zone:I F South State Plane Zone: 4 Units: us fk Starting Coordinates:— - -~- X: Y: 1483839 5972345 ❑ x To: -_ Datum: INAD27 I Region: jalaska T Latitude/Longitude Decimal Degrees t- UTM Zone: True South r State Plane Zone: T Units: us -ft r+ Legal Description (NAD27 only) i Legal Description--------------- _ ...... Township: 011 N Range:003 E Meridian: I" Section FNL 4287.0582 FEL 3379.5793 ..................... I Transform Quit Help CD5-92wp05 Top of Production Horizon �CPAI Coordinate Converter — ❑ X - From:Datum: Region: NAD 83 Region: alaska i" Latitude?Longitude Decimal Degrees t f" UTM Zone: �(`" South I r+" State Plane Zone: 14 Units: us -ft (' Legal De�zeriptix:)n (NAD4'7 oi-i t=') Datum: INAD27 Region: jala,ka T f` Latitude/Longitude Decimal Degrees " UTM Zone: True i- South f State Plane Zone: f -4 -----,l Units: Jus.ft Legal Description (NAD27 only) r Starting Coordinates: -- --- --___ _ _ Legal X: ji4538EW0 Y: 15972295.84 Township: 011 N Range: 003 E Meridian: Section:11 FNL 114335.5261 FEL .-113345.2899 Transform Quit Help CD5-92w 05 TD M CPAI Coordinate Converter Datum: NAD83 Region: alaska t" Latitude/Longitude Decimal Degrees C TM Zone: I- South Stake Plane Zone: 4 Units: us -ft Leg_-- 21 ut1V� Starting Coordinates: ❑ X Datum: NAD27 . Region: jalaska (" Latitude/Longitude IDecimalDegrees • UTM Zone:True F South • State Plane Zone: 4 Units: us k . f' Legal Description (NAD27 only) ,-Legal Description — - - - - --� X: 11476465.24 Township: 012 [-N -_-1 Range: 003 E ! Y: 15986854.25 Meridian: JU`- Section:27 FNL 496.97166 FEL 1 487.49780 FFNL r .................... _............. .........._.... . Transform Quit Help Tollerable Collision Risk Worksheet REV I DATE I BY I CK I APP I DESCRIPTION I REV I DATE I BY I CK I APP I DESCRIPTION 1 4/24/15 1 CZ I DB I C. A. 1 UPDATED PER K150003ACS 1 2 5/2/16 CZ I GD I C. A. 1 UPDATED PER K160003ACS ALPINE SATELLITE DEVELOPMENT W LOCATION OF THIS SURVEY T12 CD -5 PAD T11 N CD4 TO ALPINE CD5" D ' - ACCESS ROAD r* ._•- CD N C� 1 z O\ L, cur 1pZ LL IT CD1 iP VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 7, T. 11 N., R. 4 E., U.M. SECTION 18, T. 11 N., R. 4 E., U.M. PPp CD -5 OF PAD ��pER n a r 91' SNO OES\ON Qo�1�laa x 00 � xco •�•••• o0o"o C�QOcP �0 S6 �1 \ xx NN WN ••• - PLANT N N 1 0 o\Lp NOTE: 15.40 52" CONDUCTOR CD5-x14 WAS PLUGGED AND �--A ABANDONED LCMF APRIL 2016. KUUKPIK `� 1 UMIAQ ALPINE SURVEY OFFICE `\ PHONE :907-670-4739 �.� ALPINE MODULE: CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD -5 WELL CONDUCTORS Alaska, Inc. I AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 15-03-02-1 04/18/2015 1 CE—CD50-1025 1 1 OF 3 2 ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6 'sii's'siii"SU s C.,o ;hiliips I ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, February 28, 2019 8:54 AM To: 'Marushack, Andy Y; Beat, Andrew T (Andrew.T.Beat@conocophilIips.com) Subject: CRU CD5-92(PTD 219-034) Anti -collision Andy, The anti -collision report seems to be missing the separation warning of pass, major risk failure, minor etc. Has the reporting format changed? Clearance factors indicate close approach for CD5-98L1 at 11,414' MD and for CD5-91 at 28,642' MD. Are these major risk failures? Are they in zone? Are mitigating measures necessary and if not, why? 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@alaska.aov Transform Points Source coordinate system Target coordinate system State Plane 1921- Aaska Zone 4 J�G �R( Abers Equal Area (-150) Datum: Datum: NAD 1927 - North America Datum of 11327 (Mean) NAD 1927 - North America Datum of 1927 (Mean) I �ype values into e --s-p--r-e--a-d-s--h--e-e--t--o-r copy- andpastecollu-m ;s --of datafroma---spreadsheet -u-s-i-ng—t—he—k-ey--b-o--a-r-d--s--h-o—ft--c-i—A-s--C--tfl--+-,C—t--o- 1copy and Ctd+Vto paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish E Cancel j Help TRANSMITTAL LETTER CHECKLIST WELL NAME: R �,(� C D 5— 9 � PTD: I ^ Q 3 q-77 V Development Service Exploratory _ Stratigraphic Test Non -Conventional FIELD: O✓ d I L (l (✓e 1/' POOL: A l A i 1g 2 d I l Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of % well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL - 120100 Well Name: COLVILLE RIV UNIT CD5-92 Program DEV Well bore seg ❑ PTD#:2190340 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 - 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance_ from drilling unit _boundary- Yes 6 Well located proper distance_ from other wells_ Yes 7 Sufficient acreage_ available in drilling unit_ Yes 8 If deviated, iswellboreplat included No Directional plan view -& cross-sectional view included. 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes Can permit be approved before 15-day_wait Yes DLB 2/26/2019 113 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 AS31.05.0300.1.A),0.2.A-D) NA 18 Conductor string provided Yes 76' conductor Engineering 19 Surface casing_ protects all known_ USDWs Yes Surface casing set to 2267' -MD 120 CMT vol adequate to circulate on conductor & surf_csg Yes 169% excess cement 21 CMT -vol- adequate to tie-in long string to surf csg - No 22 CMT will cover -all known -productive horizons- No Productive interval will -be completed with blank pipe and-frac ports 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 10-403 for abandonment been approved NA - 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; CD5-98L1 and CD5-91 close approach at a point in zone. 27 If diverter required, does it meet regulations - Yes Diverter variance approved per 20 AAC 25.035(h)(2_) Appr Date 28 Drilling fluid program schematic -& equip list adequate Yes Max formation pressure is 3200 psig(10.1 ppg_EMW); will drill w/ 9.0-10.8 ppg EMW VTL 2/27/2019 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments)_ Yes MPSP is 2463 psig; will test BOPS to 3500 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not encountered in offset wells._ However, rig will be equipped with operational sensors/alarms. Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA DLB 2/26/2019 j38 Seabed condition survey (if off -shore) - - NA_ 39 Contact name/phone for weekly progress reports_ [exploratory only] NA_ Geologic Engineering Public Commissioner: Date: commission7: Date c Commissioner Date f� -� 2 -Z f -l/
