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221-075
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23389-61-00Well Name/No. KUPARUK RIV UNIT 3C-17 L1-01Completion Status1-OILCompletion Date11/17/2021Permit to Drill2210750Operator ConocoPhillips Alaska, Inc.MD10541TVD6638Current Status1-OIL1/31/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR, ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF12/17/20216910 10541 Electronic Data Set, Filename: 3C-17L1-01 GAMMA RES.las36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 2MD Final Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5MD Final Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5TVDSS Final Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 13 PWD Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 14 PWD Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 15 PWD Log.cgm36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 GAMMA RES.ASC36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01_ PWD Digital Data_Run 13.ASC36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01_ PWD Digital Data_Run 14.ASC36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01_PWD Digital Data_Run 15.ASC36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 2MD Final Log.PDF36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5MD Final Log.PDF36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5TVDSS Final Log.PDF36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 13 PWD Log.pdf36096EDDigital DataMonday, January 31, 2022AOGCCPage 1 of 4PB13C-17L1-01 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23389-61-00Well Name/No. KUPARUK RIV UNIT 3C-17 L1-01Completion Status1-OILCompletion Date11/17/2021Permit to Drill2210750Operator ConocoPhillips Alaska, Inc.MD10541TVD6638Current Status1-OIL1/31/2022UICNoDF12/17/2021 Electronic File: 3C-17L1-01 Run 14 PWD Log.pdf36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 15 PWD Log.PDF36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 NAD27 Definitive Survey.pdf36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 NAD27 Definitive Survey.txt36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 NAD83 Definitive Survey.pdf36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 NAD83 Definitive Survey.txt36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 2MD Final Log.tif36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5MD Final Log.tif36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 5TVDSS Final Log.tif36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 13 PWD Log.tif36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 14 PWD Log.tif36096EDDigital DataDF12/17/2021 Electronic File: 3C-17L1-01 Run 15 PWD Log..tif36096EDDigital Data0 0 2210750 KUPARUK RIV UNIT 3C-17 L1-01 LOG HEADERS36096LogLog Header Scans0 0 2210750 KUPARUK RIV UNIT 3C-17 L1-01 PB1 LOG HEADERS36097LogLog Header ScansDF1/31/20226910 10605 Electronic Data Set, Filename: 3C-17L1-01PB1 GAMMA RES.las36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 2MD Final Log.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5MD Final Log.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5TVDSS Final Log.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 09 PWD.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 10 PWD.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 11 PWD.cgm36097EDDigital DataMonday, January 31, 2022AOGCCPage 2 of 43C-17L1-01PB1GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23389-61-00Well Name/No. KUPARUK RIV UNIT 3C-17 L1-01Completion Status1-OILCompletion Date11/17/2021Permit to Drill2210750Operator ConocoPhillips Alaska, Inc.MD10541TVD6638Current Status1-OIL1/31/2022UICNoDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 12 PWD.cgm36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 GAMMA RES.ASC36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1_PWD Digital Data_Run 09.ASC36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1_PWD Digital Data_Run 10.ASC36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1_PWD Digital Data_Run 11.ASC36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1_PWD Digital Data_Run 12.ASC36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 2MD Final.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5MD Final.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5TVDSS Final.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 09 PWD.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 10 PWD.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 11 PWD.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 12 PWD.PDF36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 NAD27 Definitive Survey.pdf36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 NAD27 Definitive Survey.txt36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 NAD83 Definitive Survey.pdf36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 NAD83 Definitive Survey.txt36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 2MD Final.tif36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5MD Final.tif36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 5TVDSS Final.tif36097EDDigital DataMonday, January 31, 2022AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23389-61-00Well Name/No. KUPARUK RIV UNIT 3C-17 L1-01Completion Status1-OILCompletion Date11/17/2021Permit to Drill2210750Operator ConocoPhillips Alaska, Inc.MD10541TVD6638Current Status1-OIL1/31/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample 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:11/17/2021Release Date:10/8/2021DF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 09 PWD.tif36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 10 PWD.tif36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 11 PWD.tif36097EDDigital DataDF1/31/2022 Electronic File: 3C-17L1-01PB1 Run 12 PWD.tif36097EDDigital DataMonday, January 31, 2022AOGCCPage 4 of 4M. Guhl 1/31/2022 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA January 31, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. 3C-17L1-01PB1 Kuparuk River API #: 50-029-23389-71-00 Permit No: 221-075 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. API # updated Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com A. Carolina Martinez Arelys.Martinez@bakerhughes.com 01/31/2022 PTD: 2210750 E-Set: 36097 Re-submittal from 12/17/2021--API Number Corrected By Abby Bell at 11:43 am, Jan 31, 2022 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA December 17, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. 3C-17L1-01PB1 Kuparuk River API #: 50-029-23389-70-00 Permit No: 221-075 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com 15% &4FU 12/20/2021 By Abby Bell at 3:35 pm, Dec 17, 2021 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA December 17, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. 3C-17L1-01 Kuparuk River API #: 50-029-23389-61-00 Permit No: 221-075 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com 15% &4FU 12/20/2021 By Abby Bell at 3:34 pm, Dec 17, 2021 ! 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PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3C-17 L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 221-075 Surface Location: 1076’ FNL, 1266’ FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 54’ FNL, 2641’ FEL, SEC. 24, T12N, R9E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced well. The permit is for a new wellbore segment of existing well Permit 208-059, API 50-50-029-23389- 00-00. Production should continue to be reported as a function of the original API number stated above. 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 AOGCCwithin 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, Jeremy M. Price Chair DATED this ___ day of October, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.08 12:52:49 -08'00' ! 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y Meredith Guhl at 1:35 pm, Sep 21, 2021 Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.09.21 12:54:42-08'00' Foxit PDF Editor Version: 11.0.0 James Ohlinger X X X X VTL 10/8/21 X 221-075 DLB 09/23/2021 X X DSR-9/21/21 X A variance to 20 AAC 25.015(b) is granted to allow the kickoff point to be any point along the parent lateral. BOP test pressure to 4500 psig Annular test pressure to 2500 psig 50-029-23389-61-00 dts 10/8/2021 JLC 10/8/2021 10/8/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.08 12:53:13 -08'00' !! " # $ %& "' (") *!"+,! -./ 0'1%2 3 $ 4!# "+!#+## 5%. ) 1%" +!+#"65 )1 7" ,+, -./ 8 + 8 ## -!!+ ) 1""!##"!" , "!"*, # # + #+$ 9 #) " ++" ,#+"!& '%":0 ; 4 8 + 8 %+!* %"' 8 + 8 ! 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DLB % 4 9 ! . + >@ 86, &'" /# , 68('; /4= &'( 3"' +'6$5 > :/-+-A( B> , &/,'# &!B> # J/ + A<B> & &'( ' 3"' +' $5 1#0 , A<B> , &/,'# !B> # J/ + A(!B> ,4EI#64=+ >6, &'" % . + '#0 ++ # ' + + # % " #,4 $ +,$ , 34E" 5 , # $+ , -,2 2 $$ > 7 $4E", ,#+ + + , -,2 2 $$ + 3$ 2- 2 #+ , + 4E" + 5+ , #$#02 2 ++ , , 2 2 $4E"+ #0' ,##, + $ # 7 + $ - -, 2 ,$ +9 $4E"+ $+ # 4E"+ $ - , 2+ @ $+ , -,2 2 $# + 2 $ ,# +$4 -$$4E" +$ ,# +$ ,#7 I# $ -,2 2 $ -,2 2 ++ $4E" -+ #2 #0' *$$4E" #+ $+ # +$4E" 2 2$ 3$ 2- 2 #+ ,+ 4E" + 5 "# + + , , 2 2 ++ , #$#02 2 2 $4E" $+ 2$4E"2-$+ + $ ,# 2+# , +,2$+ $# + , + $4E"-$$+ , , 2 2 $+ , #$#02 2 $ # + +$# + ,7 I +$$ + , , 2 2 + $?#$+ + $ 7 I+ +$+ + $4E"+# + ,-+ $$ 4E" + $ +,2, 2+ 2 ! $&'( - ,+ #+2, # +3A :645 . & 9 / #+ *$ '&;:/ + ?'&;:/' + ,- , +, # + " 2 2 + $ ?$++$#-#+ # + + -$$ # ?2 + $'&;:/ - 2+ #+ - # -$ '&;:/ % 4 9 * +6 + 3 $ 55 6 ?#$ - " +- - , +$++?## ' +$4 + @#+ + ++ - ,?#+1 0 @@+ - 3 ': 4+ # 5 +$' 1 0# 2 , " - +- + $ +$+ , +# ++ + #1 0=2 +7 +- # # 3 !<'(5 / % ) " & $" # $ #+- "#$%# >#+# 2 - ,02 & 6 - , >*+# 2 + - , 2$$ # % " < %45 " = !:B &<B $ 7 % : B&' <B K' 14 7 + $: .$!;$8 .$!;$.$ + : < =+ .$! + : < =+ .$!;$8 .$!;$.$ !"#$% &'()$"*+,- +,(&+).*'+ #"-.) /0 110/ 0 0 2 1 +,(.+ # & 33.- // 1 4 5 5 1 6.-7 (,89+ &-" :; -" :+8-" 71 4 5. -"'(33+,8-";;1 :+8-" 71 9 . -"<+ &-"; // )<(-// 1 1 )<(- ;; )<(- )+ #3-"*) 1 1 =>51/ ;; 9/)<(- )<(- 11 )+ #3-"*) 1; 1 1 ?3 5.+ -#@ (3(* -"@ 1 ?3 5.+ -#@0 (3(* -"@1 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Tagged Top of Cement) 7,128.0 8/29/2021 3C-17 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tagged TOC and installed new GLD) 12/30/2021 3C-17 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 40.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 41.5 Set Depth (ftKB) 4,145.0 Set Depth (TVD) … 3,780.3 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 39.3 Set Depth (ftKB) 6,268.1 Set Depth (TVD) … 5,563.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-M Casing Description LINER 5.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,067.4 Set Depth (ftKB) 7,079.0 Set Depth (TVD) … 6,237.5 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,067.4 5,392.9 30.10 PACKER BAKER ZXP LINER TOP PACKER 4.870 6,084.8 5,408.0 30.14 HANGER BAKER HMC LINER HANGER 4.810 7,033.2 6,199.1 33.05 COLLAR FLOAT COLLAR 0.000 Casing Description LINER 3.5" OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 5,974.9 Set Depth (ftKB) 7,651.0 Set Depth (TVD) … Wt/Len (l… 9.20 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,974.9 5,312.9 30.32 PACKER C-2 ZXP LINER TOP PACKER HD 4.870 5,989.5 5,325.5 30.19 HANGER FLEX LOCK LINER HANGER 4.900 5,999.4 5,334.1 30.10 XO 5.5x5" Flex Lock Hanger 4.710 6,000.2 5,334.8 30.09 SBE Sealbore Extension 4.000 6,019.6 5,351.6 29.97 XO 5x4.5" Cross Over 5-1/2" BTC Box X 5" BTC pin 4.490 6,021.7 5,353.4 29.98 XO 4.5x3.5" Cross Over 5" BTC box 4.5 IBT pin 2.970 7,553.0 6,652.8 24.07 COLLAR Type one Landing Collar 2.910 7,585.1 6,682.1 23.91 COLLAR 3-1/2" Float Collar 2.992 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.4 Set Depth (ft… 6,004.7 Set Depth (TVD) (… 5,338.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.4 36.4 0.00 HANGER 3.5" Gen V Tubing Hanger EUE 8rd Mod (Pup jt 1.59') 3.500 2,090.6 1,997.3 31.39 SAFETY VLV 3.5" TRMAXX-5E SCSSV w/ 2.812" X Profile EUE 8rd Mod. Locked out 5/20/19. (Flapper only) 2.812 5,944.1 5,286.3 30.59 NIPPLE 3.5" D Nipple w/ 2.75" profile 2.750 5,986.9 5,323.2 30.21 LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.990 5,987.7 5,324.0 30.20 SEAL ASSY Baker 80-40 PBR w/Seal Assembly O.D. 4.01" I.D. 2.99 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,300.0 6,425.2 29.76 CIBP NINE ENERGY COMPOSITE BRIDGE PLUG 2.75" EZ MILL COMPOSITE PLUG 10K PSI RATING 8/24/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,186.0 7,209.0 6,327.5 6,346.8 C-1, 3C-17 12/23/2017 6.0 APERF 2.5" POWERJET, 2.5" OD, 60°, C1 Sand 7,380.0 7,388.0 6,496.0 6,503.2 A-5, A-4, 3C-17 1/21/2010 6.0 APERF 2.5" Millenium II, 60° random 7,388.0 7,419.0 6,503.2 6,531.0 A-4, A-3, 3C-17 1/18/2009 6.0 APERF 2.5" PJ HSD 60° random 7,388.0 7,420.0 6,503.2 6,531.9 A-4, A-3, 3C-17 1/20/2010 6.0 RPERF 2.5" Millenium II, 60° random 7,420.0 7,440.0 6,531.9 6,549.9 A-3, 3C-17 8/26/2008 6.0 IPERF 2.5" HSD GUN 60° phase 7,450.0 7,500.0 6,559.0 6,604.4 A-2, 3C-17 1/18/2009 6.0 APERF 2.5" PJ HSD 60° random Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 9/4/2008 7,420.0 7,440.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,128.0 7,300.0 6,278.6 6,425.2 Squeeze – Reservoir Squeeze 8/25/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,548.5 2,396.5 27.85 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,221.0 8/30/2021 2 3,577.3 3,300.2 31.01 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,218.0 8/30/2021 3 4,510.6 4,088.6 32.20 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,213.0 8/30/2021 4 5,283.0 4,727.8 34.82 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,207.0 8/29/2021 5 5,896.6 5,245.5 30.79 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/29/2021 HORIZONTAL, 3C-17, 8/31/2021 7:49:16 AM Vertical schematic (actual) LINER 3.5"; 5,974.9-7,651.0 APERF; 7,450.0-7,500.0 FRAC; 7,420.0 IPERF; 7,420.0-7,440.0 RPERF; 7,388.0-7,420.0 APERF; 7,388.0-7,419.0 APERF; 7,380.0-7,388.0 CIBP; 7,300.0 APERF; 7,186.0-7,209.0 Squeeze – Reservoir Squeeze; 7,128.0 ftKB LINER 5.5"; 6,067.4-7,079.0 INTERMEDIATE; 39.3-6,268.1 SEAL ASSY; 5,987.7 LOCATOR; 5,986.9 NIPPLE; 5,944.1 GAS LIFT; 5,896.6 GAS LIFT; 5,283.0 GAS LIFT; 4,510.6 SURFACE; 41.5-4,145.0 GAS LIFT; 3,577.3 GAS LIFT; 2,548.5 SAFETY VLV; 2,090.6 CONDUCTOR; 40.0-120.0 HANGER; 36.4 KUP PROD KB-Grd (ft) 43.80 Rig Release Date 6/29/2008 3C-17 ... TD Act Btm (ftKB) 7,652.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292338900 Wellbore Status PROD Max Angle & MD Incl (°) 35.53 MD (ftKB) 6,444.36 WELLNAME WELLBORE3C-17 Annotation Last WO: End DateH2S (ppm) 205 Date 12/9/2016 Comment SSSV: TRDP Notes: General & Safety End Date Annotation 7/17/2008 NOTE: VIEW Alaska Schematic9.0 HORIZONTAL, 3C-17, 8/31/2021 7:49:17 AM Vertical schematic (actual) LINER 3.5"; 5,974.9-7,651.0 APERF; 7,450.0-7,500.0 FRAC; 7,420.0 IPERF; 7,420.0-7,440.0 RPERF; 7,388.0-7,420.0 APERF; 7,388.0-7,419.0 APERF; 7,380.0-7,388.0 CIBP; 7,300.0 APERF; 7,186.0-7,209.0 Squeeze – Reservoir Squeeze; 7,128.0 ftKB LINER 5.5"; 6,067.4-7,079.0 INTERMEDIATE; 39.3-6,268.1 SEAL ASSY; 5,987.7 LOCATOR; 5,986.9 NIPPLE; 5,944.1 GAS LIFT; 5,896.6 GAS LIFT; 5,283.0 GAS LIFT; 4,510.6 SURFACE; 41.5-4,145.0 GAS LIFT; 3,577.3 GAS LIFT; 2,548.5 SAFETY VLV; 2,090.6 CONDUCTOR; 40.0-120.0 HANGER; 36.4 KUP PROD 3C-17 ... 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rue Vertical Depth (150 usft/in)-400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000Vertical Section at 45.00° (400 usft/in)3C-17L1 T4 3C-17L1 T63C-17L1 T3.1 3C-17L1 T3.33C-17L1 T5 3C-17L1 T3.5 3C-17L1 T3.6 3C-17L1 T3.2 3C-17L1 T33C-17L1 T3.4 3C-17L1 T2 3C-17L1 T1 3C-17/3C-17L1-01 wp023C-17/3C-173C-17/3C-17L1 wp03SECTION DETAILSSecMD Inc Azi TVDss+N/-S+E/-W Dleg TFaceVSect1 7398.0 26.22 117.92 6424.8 -2497.9 2077.8 0.00 0.00 -29.02 7400.0 26.18 117.94 6426.6 -2498.3 2078.6 2.01 167.56 -28.83 7421.0 29.12 117.94 6445.2 -2502.9 2087.2 14.00 0.00 -25.94 7587.4 104.00 117.94 6506.8 -2569.4 2212.6 45.00 0.00 15.85 8100.0 88.36 97.45 6451.2 -2721.7 2694.4 5.00-126.00 248.86 8400.0 88.42 112.45 6459.7 -2798.8 2983.3 5.00 90.00 398.57 8700.0 88.73 97.45 6467.2 -2876.0 3272.3 5.00 -89.00 548.38 8900.0 89.44 107.43 6470.4 -2919.0 3467.3 5.00 86.00 655.79 9200.0 93.40 86.79 6462.8 -2956.0 3763.2 7.00 -79.00 838.910 9700.0 90.50 51.89 6445.3 -2782.3 4223.5 7.00 -94.00 1287.111 9800.0 90.98 44.91 6444.0 -2715.9 4298.2 7.00 -86.00 1386.912 10550.0 89.80 352.42 6438.5 -2030.0 4529.9 7.00 -91.00 2035.713 11350.0 89.85 32.42 6441.0 -1264.5 4698.4 5.00 90.00 2696.2WELL DETAILS: 3C-17Ground Level: 46.8+N/-S +E/-W Northing EastingLatittudeLongitude-479.6 100.6 5995355.93 528308.03 70° 23' 54.238 N149° 46' 10.676 WKuparuk River UnitKuparuk 3C Pad3C-173C-17L1 CTD Sidetrack3C-17L1 wp03WELLBORE DETAILS3C-17L1 CTD SidetrackParent Wellbore : 3C-17Planned Tie On Depth (ft MD): 7398Azimuths to True NorthMagnetic North: 15.32°Magnetic FieldStrength: 57306.7nTDip Angle: 80.75°Date: 12/1/2021Model: BGGM2021TM-4500-3750-3000-2250-1500South(-)/North(+) (1500 usft/in)2250 3000 3750 4500 5250 6000 6750West(-)/East(+) (1500 usft/in)3C-17L1-01 wp023C-173C-17L1 wp03Reference Coordinate: Site Kuparuk 3C Pad, True NorthReference TVD: Mean Sea LevelReference Section:Slot - (-479.6N, 100.6E)Reference MD:3C-17 @ 87.3usft (Doyon 15 (46.8 + 40.5))Calculation Method: Minimum Curvature ) "$%$"$%&( " / $/ = $ >9 # - ).9 - ).2 - ).>9 # ) < # ! #+ < )) ! #+9 ,2 + ) *%"01+"+ )+' : +' +# , - ) . ) * " #$"$%$"$%&' # $"$%&( "9 # - ). ; #9 / " #%&'"%'%&'"%'%&'"% ( %)( (*( +), -(%)+ .* ) -) --(*( +), '%&'"%'%&'"%'%&'"% ( (), (*(%")% -(/)/ .*% ) ,)( ((*(%")%& '%&'"%'%&'"%'%&'"% ( %)( (*( +), -(%)+ .* ) -) --(*( +), '%&'"%'%&'"%'%&'"% ( (), (*(%")% -(/)/ .*% ) ,)( ((*(%")%& '%&'"+'%&'"+'%&'"+ ,,%) .* ) //,)( -*/ ) ,) +(.* ) & '%&'"+'%&'"+'%&'"+ ,,%)/ .* %")% // )% -*, ) /)(,(.* %")% '%&'"+'%&'"+'%&'"+ -,+). .*%((). , (). .* ) /),,,.*%(().& '%&'"+'%&'"+'%&'"+ ,,%) .* ) //,)( -*/ ) ,) +(.* ) & '%&'"+'%&'"+'%&'"+ ,,%)/ .* %")% // )% -*, ) /)(,(.* %")% '%&'"+'%&'"+'%&'"+ -,+). .*%((). , (). .* ) /),,,.*%(().& '%&'"-'%&'"-'%&'"-+%5+$"0+%5++%5+ < <?&$%&'"-'%&'"-'%&'"-+%5+$"0+%5++%5+ < <?&$ < - ).'- ). @ '-*%(.) ""*%/ ) %&'"-" % 011 2 3 45 ' ) 3 6 )& 3 3 $ )& 7 $ #8 $ ' 9) : 6 6 ) 3 3 :0 232&3 4 3 2) -3600 -2700 -1800 -900 0 900 South(-)/North(+) (900 usft/in)1800 2700 3600 4500 5400 6300 West(-)/East(+) (900 usft/in)2750300032503500375040004250450047505000525055005750600062506500675067803C-13/3C-13475057506000625065006799 3C-14/3C-14 3C-14/3C-14A 3C-14/3C-14B60006 50066553C-17/3C-17PB1 225 0 25002750300032503500375040 004250 450064 3 7 3C-10/3C-10A27503000325035003750400042504500475050005250550057506000625065006647 3C-11/3C-11275030003250350037504000425045004750500052505500575060006250 6429 3C-11/3C-11A 2750300032503500375040004250450047505000525055005750600062506487 3C-11/3C-11AL1275030003250350037504000425045004750500052505500 5750600062506500675067803C-13/3C-13525055005750600062506500 67503C-14/3C-14 3C-14/3C-14B 66553C-17/3C-17 3C-17/3C-17PB1 6441 3C-17/3C-17L1 CTD Sidetrack Project:Kuparuk River Unit Site:Kuparuk 3C Pad Well:3C-17 Wellbore:3C-17L1 CTD Sidetrack Plan: 3C-17L1 wp03 (3C-17/3C-17L1 CTD Sidetrack) Mean Sea Level WELLBORE DETAILS:3C-17L1 CTD Sidetrack Parent Wellbore:3C-17 Tie on MD:7398.0 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well 3C-17, True North Vertical (TVD) Reference:Mean Sea Level Section (VS) Reference:Slot - (0.0N, 0.0E) Measured Depth Reference:3C-17 @ 87.3usft (Doyon 15 (46.8 + 40.5)) Calculation Method: Minimum Curvature Azimuths to True North Magnetic North: 16.26° Magnetic Field Strength: 57395.9nT Dip Angle: 80.88° Date: 12/31/2019 Model: BGGM2018 T M ConocoPhillips Alaska Inc_Kuparuk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rue Vertical Depth (150 usft/in)1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200Vertical Section at 180.00° (300 usft/in)3C-17L1-01 T1 3C-17L1-01 T3 3C-17L1-01 T53C-17L1-01 T23C-17L1-01 T43C-17/3C-173C-17/3C-17L1 wp033C-17/3C-17L1-01 wp02SECTION DETAILSSecMD Inc Azi TVDss+N/-S+E/-W Dleg TFaceVSect1 9000.0 90.07 112.39 6470.3 -2953.0 3561.3 0.00 0.00 2473.42 9070.0 94.31 114.85 6467.7 -2981.0 3625.4 7.00 30.00 2501.43 9200.0 89.07 122.29 6463.8 -3043.1 3739.4 7.00 125.00 2563.54 9450.0 89.11 139.79 6467.8 -3206.6 3927.2 7.00 90.00 2727.05 9600.0 83.89 148.93 6477.0 -3328.1 4014.3 7.00 120.00 2848.56 9900.0 85.02 170.00 6506.3 -3606.2 4118.4 7.00 88.00 3126.57 10100.0 91.01 182.67 6513.3 -3805.1 4131.1 7.00 65.00 3325.58 10450.0 90.36 200.15 6509.1 -4146.9 4062.2 5.00 92.00 3667.29 11050.0 90.31 170.15 6505.5 -4737.6 4008.9 5.00 -90.00 4258.0WELL DETAILS: 3C-17Ground Level: 46.8+N/-S +E/-W Northing EastingLatittudeLongitude-479.6 100.6 5995355.93 528308.03 70° 23' 54.238 N149° 46' 10.676 WKuparuk River UnitKuparuk 3C Pad3C-173C-17L1-01 CTD Sidetrack3C-17L1-01 wp02WELLBORE DETAILS3C-17L1-01 CTD SidetrackParent Wellbore : 3C-17L1 wp03Planned Tie On Depth (ft MD): 9000Azimuths to True NorthMagnetic North: 15.32°Magnetic FieldStrength: 57306.7nTDip Angle: 80.75°Date: 12/1/2021Model: BGGM2021TM-4500-3750-3000-2250-1500South(-)/North(+) (1500 usft/in)2250 3000 3750 4500 5250 6000 6750 7500West(-)/East(+) (1500 usft/in)3C-173C-17L1 wp033C-17L1-01 wp02Reference Coordinate: Site Kuparuk 3C Pad, True NorthReference TVD: Mean Sea LevelReference Section:Slot - (-479.6N, 100.6E)Reference MD:3C-17 @ 87.3usft (Doyon 15 (46.8 + 40.5))Calculation Method: Minimum Curvature ) "$%$"$%&$( / $/ A $ B9 # - ).9 - ).2 - ).B9 # ) < # ! #+ < )) ! #+9 ,2 + ) *++ )+9 # +' +# , - ) . ) * " #$"$%$"$%&$' # $"$%&$( 9 # - ). ; #9 / C # !! !! !! !! " # " " #! !! $ ! !! !! < - ).'- ). D ' %&'( )*#+, '+ +) )*#+, '+ +) )*#+, '+ +) - )*#(* $ ! .! !!!/ 01 ! !2 / ! 3- !! / !! !/ 4 ! 5#! %- 4 !67#! %- 4 !$ ! 8#! %- !!2! 92 ! 3- - 3 ! ! !- / /! 92) ./. / 0 / .2 -4800 -4000 -3200 -2400 -1600 -800 0 South(-)/North(+) (800 usft/in)0 800 1600 2400 3200 4000 West(-)/East(+) (800 usft/in) 5750 6000 6250 6500 67506761 1Q-21/1Q-21 5750 6000 6250 6500 67506761 1Q-21/1Q-21 0250500750 100012501500175020002250250027503000325035003750400042504500475050005250550057503C-13/3C-13 0250 5 00750100 0125015001750200022502 5002750300032503500375040004250575060006250650067993C-14/3C-14 0250 5 00750100 0125015001750200022502 50027503000325035003750400042505500575060003C-14/3C-14A 0250 5 00750100 0125015001750200022502 500275030003250350037504000425060006371 3C-14/3C-14B 0250 5 00750100 0125015001750200022502 50027503000325035003750400042506413 3C-14/3C-14BPB1030003250350037504000425045004750500052505750600062 50650066553C-17/3C-17 0250 300032503500375040004250450047505000525057506000625067423C-17/3C-170300032503500375040004250450047505250575060006250 64 41 3C-17/3C-17L1 CTD Sidetrack 0250 300032503500375040004250450047505250575062503C-17/3C-17PB10300032503500375040004250450047505750 65 0 0 65 0 6 3C-17/3C-17L1-01 CTD Sidetrack Project: Kuparuk River Unit Site:Kuparuk 3C Pad Well:3C-17 Wellbore:3C-17L1-01 CTD Sidetrack Plan: 3C-17L1-01 wp02 (3C-17/3C-17L1-01 CTD Sidetrack) Mean Sea Level WELLBORE DETAILS:3C-17L1-01 CTD Sidetrack Parent Wellbore:3C-17L1 CTD Sidetrack Tie on MD:9000.0 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well 3C-17, True North Vertical (TVD) Reference:Mean Sea Level Section (VS) Reference:Slot - (0.0N, 0.0E) Measured Depth Reference:3C-17 @ 87.3usft (Doyon 15 (46.8 + 40.5)) Calculation Method: Minimum Curvature Azimuths to True North Magnetic North: 16.26° Magnetic Field Strength: 57395.9nT Dip Angle: 80.88° Date: 12/31/2019 Model: BGGM2018 T M Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole 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 name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements 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 (_______________________________) in the attached application, the following well logs are also required for this 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. KRU 3C-17L1-01 221-075 X Kuparuk River Kuparuk River Oil X 208-059 029-23389-00-00 X X WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3C-17 L1-01Initial Class/TypeDEV / 1-OILGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2210750KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view included, no land plat.8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NAConductor set for KRU 3C-1718Conductor string providedNA19Surface casing protects all known USDWsNASurface casing set and fully cemented20CMT vol adequate to circulate on conductor & surf csgNA21CMT vol adequate to tie-in long string to surf csgYesProductive interval will be completed with uncemented slotted liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 4614 psig(14.14 psig); will drill w/8 8.6 ppg EMW and maintain overbal w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 3981 psig; will test BOPs to 4500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)No163 ppm H2S reported in KRU 3C-17 on 11/09/2020.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate9/23/2021ApprVTLDate10/8/2021ApprDLBDate10/7/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 10/8/2021
