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Home My WebLink About219-161ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD4-499 50103208100000 2191610 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit data drophard driveVia CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 CD3-107 50-103-20529-01 206189_CD3-107_Packer_16Apr2022 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 CD3-303 50-103-20568-00 208013_CD3-303_CHC_21Feb2023 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 WD-02 50-103-20285-00 198258_WD-02_WFL_22May2022 WD-03 50-103-20835-00 221103_WD-03_IBC DSLT_12Feb2022 221103_WD-03_USIT_28Feb2022 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38298 T38299 T38300 T38301 T38302 T38303 T38304 T38305 T38306 2/29/2024 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:46:16 -09'00' DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20810-00-00Well Name/No. COLVILLE RIV UNIT CD4-499Completion Status1-OILCompletion Date1/19/2020Permit to Drill2191610Operator ConocoPhillips Alaska, Inc.MD12865TVD4050Current Status1-OIL5/29/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RES/SonicNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC1/31/202023 2421 Electronic Data Set, Filename: CD4-499 TeleScope_Gamma_Ray_RM_LWD001.las32004EDDigital DataC1/31/20202347 5468 Electronic Data Set, Filename: CD4-499_EcoScope_Service_RM_LWD002.las32004EDDigital DataC1/31/20205330 12864 Electronic Data Set, Filename: CD4-499_Scope_Service_RM_LWD003.las32004EDDigital DataC1/31/20206 12864 Electronic Data Set, Filename: CD4-499_Scope_Service_RM.las32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD001.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD001.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD002.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD003.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope Service_RM_LWD003.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope_Service_RM.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Scope_Service_RM.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Gyro_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_Gyro_RM_LWD002.html32004EDDigital DataFriday, May 29, 2020AOGCCPage 1 of 4CD4-,499_Scope_Service_RM.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20810-00-00Well Name/No. COLVILLE RIV UNIT CD4-499Completion Status1-OILCompletion Date1/19/2020Permit to Drill2191610Operator ConocoPhillips Alaska, Inc.MD12865TVD4050Current Status1-OIL5/29/2020UICNoC1/31/2020 Electronic File: CD4-499_TeleScope_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_TeleScope_RM_LWD002.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_EcoScope_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_EcoScope_RM_LWD002.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PDX6_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PDX6_RM_LWD002.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_TeleScope_RM_LWD002.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_TeleScope_RM_LWD002.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_adnVISION_RM_LWD003.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_adnVISION_RM_LWD003.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_ImPulse_RM_LWD003.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_ImPulse_RM_LWD003.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PD X5 475_RM_LWD003.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PD X5 475_RM_LWD003.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PeriScope_RM_LWD003.dlis32004EDDigital DataC1/31/2020 Electronic File: CD4-499_PeriScope_RM_LWD003.html32004EDDigital DataC1/31/2020 Electronic File: CD4-499_VISION_Service_2MD_RM.Pdf32004EDDigital DataC1/31/2020 Electronic File: CD4-499_VISION_Service_2TVD_RM.pdf32004EDDigital DataFriday, May 29, 2020AOGCCPage 2 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20810-00-00Well Name/No. COLVILLE RIV UNIT CD4-499Completion Status1-OILCompletion Date1/19/2020Permit to Drill2191610Operator ConocoPhillips Alaska, Inc.MD12865TVD4050Current Status1-OIL5/29/2020UICNoC1/31/2020 Electronic File: CD4-499_VISION_Service_5MD_RM.pdf32004EDDigital DataC1/31/2020 Electronic File: CD4-499_VISION_Service_5TVD_RM.pdf32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD27 EOW Compass Surveys [Canvas].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD27 EOW Compass Surveys [Macro].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD27 EOW Compass Surveys [Petrel].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD27 EOW Compass Surveys [Survey].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD27 EOW Compass Surveys.pdf32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD83 EOW Compass Surveys [Canvas].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD83 EOW Compass Surveys [Macro].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD83 EOW Compass Surveys [Petrel].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD83 EOW Compass Surveys [Survey].txt32004EDDigital DataC1/31/2020 Electronic File: CD4-499 NAD83 EOW Compass Surveys.pdf32004EDDigital Data0 0 2191610 COLVILLE RIVER UNIT CD4-499 LOG HEADERS32004LogLog Header ScansC2/7/2020 Electronic File: CD4-499_2MD_DEL_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_2MD_FEL_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_2TVD_FEL_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_5MD_FEL_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_5TVD_FEL_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_Show 1_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_Show 2_Final.pdf32025EDDigital DataC2/7/2020 Electronic File: CD4-499_Show 3_Final.pdf32025EDDigital DataFriday, May 29, 2020AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20810-00-00Well Name/No. COLVILLE RIV UNIT CD4-499Completion Status1-OILCompletion Date1/19/2020Permit to Drill2191610Operator ConocoPhillips Alaska, Inc.MD12865TVD4050Current Status1-OIL5/29/2020UICNoWell 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:1/19/2020Release Date:11/27/20190 0 2191610 COLVILLE RIVER UNIT CD4-499 LOG HEADERS32025LogLog Header ScansC5/29/20202421 12863 Electronic Data Set, Filename: CD4-499_GasExport01102020_0240 hrs.las32025EDDigital DataFriday, May 29, 2020AOGCCPage 4 of 4CD4-,499_GasExport01102020_0240 hrs.lasM. Guhl5/29/2020 TT RR AA NN SS MM II TT TT AA LL FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD4-499 Permit: 219-161 DATE: 05-29-2020 Transmitted: North Slope, Colville River Unit, Alaska Via email ___Final Mud log .las file Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: CD4-499- e-transmittal well folder Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 Received by the AOGCC 05/29/2020 PTD: 2191610 E-Set: 32025 Abby Bell 05/29/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,865 feet None feet true vertical 4,050 feet None feet Effective Depth measured 9,371 feet 5,134 feet true vertical 4,076 feet 4,049 feet Perforation depth:N/A feet N/A feet Tubing (size, grade, measured and true vertical depth)3.5 ''L-80 5,259' MD 4,060' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 5,134' MD 4,049' TVDMD12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Adam Klem Contact Name:Adam Klem Authorized Title:Completion Engineer Contact Email:adam.klem@cop.com Contact Phone:907 263-4529 Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-038 1059 4112 51 874 365 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure øø ø350 300 5,838 - 9,370 MD Total Well - 5 stages, 391,209lbs of proppant placed….see attached schematick for full FRAC details Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: PRODUCTION 4,124 feet 4 1/2 '' 9,371' MD 4076' TVD CONDUCTOR 80 feet 16 '' 106' MD 106' TVD INTERMEDIATE 5,429 feet 7 '' 5,456' MD 4072' TVD SURFACE 2,381 feet 10 3/4 ''2,408' MD 2361' TVD Packer measured true vertical Casing Length Size MD TVD POST FRAC REPORT Colville River Unit/Qannik Pool Plugs measured Junk measured Burst Collapse 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-103-20810-00-00 8. Well Name and Number: CRU CD4-499ADL 380077, ADL 384211, ADL 380082, ADL 388903, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 219-161-0 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 4/2017 Submit Original Only Adam Klem Digitally signed by Adam Klem Date: 2020.04.14 07:50:58 -08'00' By Samantha Carlisle at 8:16 am, Apr 14, 2020 VTL 4/14/20 RBDMS HEW 4/14/2020 DSR-4/14/2020 CDW 04/14/2020 DTTM START JOBTYP SUMMARYOPS 2/23/20 DRILLING SUPPORT - CAPITAL DRIFTED TBG. TO XN NIPPLE @ 5193' MD WITH 2.79" G-RING & 2.74" CENTRALIZER. SET 2.81" CAT SV @ 5193' MD; MITT PASSED; MIT-IA PASSED; PULLED 2.81" CAT SV @ 5193' MD. 3/9/20 DRILLING SUPPORT - CAPITAL PERFORM FRACTURE TREATMENT PER DESIGN PLACING 391,209# 20/40 WANLI SAND INTO 5 STAGES, WELL IS FREEZE PROTECTED. 3/12/20 DRILLING SUPPORT - CAPITAL BRUSH & GAUGE TBG TO 3.79" TO 4524' RKB. LOCATE GLM @ 3428' RKB & FLAG WIRE. SET 3.5" EVO TREVE PLUG @ 3510' RKB. MITT TO 2500 psi. **PASS**. DEPLOY 2.79" AVA CATCHER TO 3510' RKB. PULL DV @ 3428' RKB. IN PROGRESS 3/16/20 DRILLING SUPPORT - CAPITAL (MISC) : TEST BPV TO 1200 PSI (PASSED), T POT (PASSED), IC POT (PASSED), T X IA DDT TO 0 PSI (PASSED), 3/18/20 DRILLING SUPPORT - CAPITAL (MISC) : SWAP 10K FRAC TREE (COMPLETE), T PPPOT (PASSED), SHELL TEST TREE TO 5K (PASSED), 3/19/20 DRILLING SUPPORT - CAPITAL ASSIST FMC WITH REMOVAL OF BPV. SET DV @ 3427' RKB. GOOD TBG TEST. PULLED CATCHER & 3.5'' EVO TRIEVE PLUG @ 3485' SLM. SET SLIPSTOP CATCHER @ 4420' RKB; PULLED DV @ 4393' RKB & REPLACE WITH OV. GOOD DDT ON IA. PULLED CATCHER. JOB COMPLETE. READY FOR FLOWBACK. CD4-499 FRAC STIMULATE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD4-499 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: UPDATED FRAC Summary 4/2/2020 CD4-499 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 26.5 Set Depth (ftKB) 106.5 Set Depth (TVD) … 106.5 Wt/Len (l… 62.50 Grade H-40 Top Thread NA Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 26.9 Set Depth (ftKB) 2,408.0 Set Depth (TVD) … 2,361.4 Wt/Len (l… 45.50 Grade L-80 Top Thread TXP BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 26.9 Set Depth (ftKB) 5,456.0 Set Depth (TVD) … 4,071.7 Wt/Len (l… 26.00 Grade L-80 Top Thread H563 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,247.5 Set Depth (ftKB) 9,371.3 Set Depth (TVD) … 4,076.4 Wt/Len (l… 12.60 Grade L-80 Top Thread H563 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,247.5 4,059.3 85.90 PACKER Baker "HRD-E" ZXP Liner Top Packer 4.020 5,274.0 4,061.1 86.08 HANGER Baker "Flex-Lock Liner Hanger 3.880 5,490.5 4,073.3 87.64 SWELL PACKER Baker Swell Packer "F" 4 1/2", 12.6#, L80 3.880 5,837.9 4,076.6 90.66 FRAC SLEEVE Baker frac sleeve #4, HYD563, 2.425" ID, Ball Seated 2.445" 3.840 6,175.5 4,071.6 90.79 SWELL PACKER Baker Swell Packer "E" 4 1/2", 12.6#, L80 3.900 6,563.8 4,073.5 89.36 FRAC SLEEVE Baker frac sleeve #3, HYD563, 2.385" ID, Ball Seated 2.415" 3.840 6,908.0 4,081.0 88.51 SWELL PACKER Baker Swell Packer "D" 4 1/2", 12.6#, L80 3.910 7,295.0 4,082.9 90.46 FRAC SLEEVE Baker frac sleeve #2, HYD563, 2.345" ID, Ball Seated 2.375" 3.890 7,595.7 4,080.6 89.86 SWELL PACKER Baker Swell Packer "C" 4 1/2", 12.6#, L80 3.920 7,898.8 4,087.8 86.64 DST SINGLE PACKER Baker Swell Packer "B" 4 1/2", 12.6#, L80 3.940 8,329.0 4,100.0 91.22 FRAC SLEEVE Baker frac sleeve #1, HYD563, 2.305" ID, Ball Seated 2.335" 3.850 8,792.8 4,082.5 91.98 DST SINGLE PACKER Baker Swell Packer "A" 4 1/2", 12.6#, L80 3.900 Tubing Strings Tubing Description PROD TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.7 Set Depth (ft… 5,258.8 Set Depth (TVD) (… 4,060.1 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) 24.7 24.7 0.00 HANGER FMC 11" X 4 1/2" Tubing Hanger, HYD 563 (BPV installed) 4.500 1,500.5 1,490.2 11.92 NIPPLE Nipple Landing 3 1/2" X 2.813, SN:4284952 2.813 5,082.1 4,042.8 81.90 SOLID GAUGE MANREL SLB solid gauge mandrel (SGM) 12.6# L-80 HYD563, SN:33972- 01 2.935 5,133.8 4,049.3 83.76 PACKER Baker Premier Packer, HYD563, 3-1/2" x 7", SN:104197711-01 2.870 5,193.7 4,055.1 85.04 NIPPLE NIPPLE, LANDING, 3-1/2" X 2.813", XN, EUE 8rd, 2.75" NOGO, SN:4292341 2.750 5,237.1 4,058.5 85.83 LOCATOR Mechanical locator, w/ Pup joint, 3-1/2", 9.3#, L-80, EUE 8rd 2.980 5,244.4 4,059.0 85.88 SHOE Baker WLEG 3.000 Frac Summary Start Date 3/9/2020 Proppant Designed (lb) 74,375.0 Proppant In Formation (lb) 72,623.0 Stg # 1 Start Date 3/9/2020 Top Depth (ftKB) 9,328.0 Btm (ftKB) 9,370.0 Link to Fluid System #20 Waterfrac G, #20 Boragel Vol Clean (bbl) 1,405.00 Vol Slurry (bbl) 1,481.00 Start Date 3/9/2020 Proppant Designed (lb) 74,375.0 Proppant In Formation (lb) 73,530.0 Stg # 2 Start Date 3/9/2020 Top Depth (ftKB) 8,329.0 Btm (ftKB) 8,331.0 Link to Fluid System #20 Waterfrac G, #20 Boragel Vol Clean (bbl) 815.00 Vol Slurry (bbl) 892.00 Start Date 3/9/2020 Proppant Designed (lb) 74,375.0 Proppant In Formation (lb) 75,637.0 Stg # 3 Start Date 3/9/2020 Top Depth (ftKB) 7,295.0 Btm (ftKB) 7,297.0 Link to Fluid System #20 Waterfrac G, #20 Boragel Vol Clean (bbl) 818.00 Vol Slurry (bbl) 897.00 Start Date 3/9/2020 Proppant Designed (lb) 74,375.0 Proppant In Formation (lb) 75,551.0 Stg # 4 Start Date 3/9/2020 Top Depth (ftKB) 6,563.0 Btm (ftKB) 6,565.0 Link to Fluid System #20 Waterfrac G, #20 Boragel Vol Clean (bbl) 816.00 Vol Slurry (bbl) 896.00 Start Date 3/9/2020 Proppant Designed (lb) 74,385.0 Proppant In Formation (lb) 93,868.0 Stg # 5 Start Date 3/9/2020 Top Depth (ftKB) 5,838.0 Btm (ftKB) 5,840.0 Link to Fluid System #20 Waterfrac G, #20 Boragel Vol Clean (bbl) 937.00 Vol Slurry (bbl) 1,035.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,427.8 3,247.9 Camco KBMG 1 GAS LIFT DMY BK 3/19/2020 2 4,393.3 3,846.5 Camco KBMG 1 GAS LIFT OV BK 0.250 3/19/2020 Notes: General & Safety End Date Annotation 2/12/2020 Note: WELLVIEW Alaska Schematic 10.0 HORIZONTAL, CD4-499, 4/14/2020 6:37:10 AM Vertical schematic (actual) PRODUCTION LINER; 5,247.5- 9,371.3 Hydraulic Fracture; 9,328.0 Hydraulic Fracture; 8,329.0 Hydraulic Fracture; 7,295.0 Hydraulic Fracture; 6,563.0 Hydraulic Fracture; 5,838.0 INTERMEDIATE; 26.9-5,456.0 SHOE; 5,244.4 LOCATOR; 5,237.1 NIPPLE; 5,193.7 PACKER; 5,133.8 SOLID GAUGE MANREL; 5,082.1 Annular Fluid - Saltwater/Brine; 4,724.0-5,247.0; 1/17/2020 GAS LIFT; 4,393.3 Annular Fluid - Fresh Water; 1,543.0-5,456.0; 1/8/2020 GAS LIFT; 3,427.8 Annular Fluid - Saltwater/Brine; 1,375.0-4,724.0; 1/17/2020 SURFACE; 26.9-2,408.0 NIPPLE; 1,500.5 Annular Fluid - Diesel; 26.8- 1,543.0; 1/8/2020 Annular Fluid - Diesel; 24.6- 1,375.0 CONDUCTOR; 26.5-106.5 HANGER; 24.7 WNS PROD KB-Grd (ft) 28.00 Rig Release Date 1/19/2020 CD4-499 ... TD Act Btm (ftKB) 12,865.0 Well Attributes Field Name TRACT OPERATION TR1027 Wellbore API/UWI 501032081000 Wellbore Status PROD Max Angle & MD Incl (°) 95.40 MD (ftKB) 11,750.92 WELLNAME WELLBORECD4-499 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Hydraulic Fracturing Fluid Product Component Information DisclosureHydraulic Fracturing Fluid Composition:Job Start Date:3/9/2020Job End Date:3/9/2020State:AlaskaCounty:Harrison BayAPI Number:50-103-20810-00-00Operator Name:ConocoPhillips Company/Burlington ResourcesWell Name and Number:CD4-499Latitude:70.29217500Longitude:-150.98929600Datum:NAD83Federal Well:NOIndian Well:NOTrue Vertical Depth:4,138Total Base Water Volume (gal):200,010Total Base Non Water Volume:0Trade NameSupplierPurposeIngredientsChemicalAbstractServiceNumber(CAS #)MaximumIngredientConcentrationin Additive (% by mass)**MaximumIngredientConcentrationin HF Fluid (% by mass)**CommentsSea WaterOperatorBase FluidWater7732-18-596.0000076.60999Density = 8.560IngredientsListed AboveListed AboveWater7732-18-5100.000000.38685 Wanli 20/40Wanli Proppant CompanyAdditiveListed BelowLVT-200PenrecoFreeze ProtectListed BelowCAT-3ACTIVATORHalliburtonActivatorListed BelowSP BREAKERHalliburtonBreakerListed BelowBE-6MICROBIOCIDEHalliburtonBiocideListed BelowLOSURF-300DHalliburtonNon-ionicSurfactantListed BelowWG-36 GELLING AGENTHalliburtonGelling AgentListed BelowCL-31CROSSLINKERHalliburtonCrosslinkerListed BelowCorundum1302-74-565.0000011.34330Mullite1302-93-845.000007.85305Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients. * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 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 lineNote: 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)Sodium chloride7647-14-54.000003.19208Hydrotreated Distillate, light64742-47-8100.000002.00563Guar gum9000-30-0100.000000.20900EDTA/Copper chelateProprietary30.000000.09940Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226Potassium metaborate13709-94-960.000000.05553Ethanol64-17-560.000000.04101Sodium persulfate7775-27-1100.000000.03845Oxylated phenolic resinProprietary30.000000.02734Heavy aromatic petroleum naphtha64742-94-530.000000.02051Potassium hydroxide1310-58-35.000000.00463Poly(oxy-1,2-ethanediyl),alpha-(4-nonylphenyl)-omega-hydroxy-,branched127087-87-05.000000.00342Naphthalene91-20-35.000000.003422-Bromo-2-nitro-1,3-propanediol52-51-7100.000000.001401,2,4 Trimethylbenzene95-63-61.000000.00068Sodium sulfate7757-82-60.100000.00004 Hydraulic Fracturing Fluid Product Component Information Disclosure 2020-01-20 Alaska Harrison Bay 5010320810 CONOCOPHILLIPS NORTH SLOPE - EBUS CD4 499 -150.98616 70.292499 NAD27 none Oil 4,138 200,010 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone Sea Water Operator Base Fluid Water 7732-18-5 96.00% 76.60999% 1643597 Density = 8.560 BE-6 MICROBIOCIDE Halliburton Biocide Listed Below Listed Below 0 NA CAT-3 ACTIVATOR Halliburton Activator Listed Below Listed Below 0 NA CL-31 CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0 NA LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA SP BREAKER Halliburton Breaker Listed Below Listed Below 0 NA WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below Listed Below 0 NA LVT-200 Penreco Freeze Protect Listed Below Listed Below 0 NA Wanli 20/40 Wanli Proppant Company Additive Listed Below Listed Below 0 NA Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00068% 15 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00140% 30 Corundum 1302-74-5 65.00% 11.34330% 243361 EDTA/Copper chelate Proprietary 30.00% 0.09940% 2133 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281- 871-6226 Halliburton Denise Tuck Denise.Tuck@ Halliburton.co m 281-871-6226 Ethanol 64-17-5 60.00% 0.04101% 880 Guar gum 9000-30-0 100.00% 0.20900% 4484 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02051% 440 Hydrotreated Distillate, light 64742-47-8 100.00% 2.00563% 43029 Mullite 1302-93-8 45.00% 7.85305% 168480 Naphthalene 91-20-3 5.00% 0.00342% 74 Oxylated phenolic resin Proprietary 30.00% 0.02734% 587 Halliburton Denise Tuck Denise.Tuck@ Halliburton.co m 281-871-6226 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00% 0.00342% 74 Potassium hydroxide 1310-58-3 5.00% 0.00463% 100 Potassium metaborate 13709-94-9 60.00% 0.05553% 1192 Sodium chloride 7647-14-5 4.00% 3.19208% 68484 Sodium persulfate 7775-27-1 100.00% 0.03845% 825 Sodium sulfate 7757-82-6 0.10% 0.00004% 1 Water 7732-18-5 100.00% 0.38685% 8301 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. v3.3 Fracture Date State: County: API Number: Operator Name: Well Name and Number: Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line 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 directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Longitude: Latitude: Long/Lat Projection: Indian/Federal: Production Type: True Vertical Depth (TVD): Sales Order# Prepared By: Keegan Lambe Chad Burkett Nanook Crew 0906366755 Intervals 1-5 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. CD4-499 Conoco Phillips Alaska Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20810 Prepared for: Adam Klem March 9, 2020 Qannick Formation 20# Boragel Table of Contents Section Page(s) Executive Summary Wellbore Information Actual Design Interval Summary Fluid System-Proppant Summary Interval 1 Plots Interval 2 Plots Interval 3 Plots Interval 4 Plots Interval 5 Plots Appendix Well Summary Chemical Summary Planned Design Water Straps Water Analysis Day 1 Real-Time QC Fann 15 Prejob Break Test Fann 15 Zone 1 Fann 15 Zone 2 Fann 15 Zone 3 Fann 15 Zone 4 Fann 14 Zone 5 Event Log Lab Testing 56-57 51 52 53 54 55 50 45 46 47 48 49 34 - 37 38 - 41 42 43 44 6 - 11 12 13 - 25 26 - 29 30 - 33 3 4 5 Conoco Phillips Alaska - CD4-499 TOC 2 189,350 gallons of 20# Boragel 5,559 gallons of 20# WaterFrac G 1,260 gallons of Freeze Protect 371,875 pounds of Wanli 20/40 194,429 gallons of 20# Boragel 5,581 gallons of 20# WaterFrac G 1,247 gallons of Freeze Protect 374,400 pounds of Wanli 20/40 Thank you, Keegan Lambe Technical Professional Halliburton Energy Services 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. Engineering Executive Summary On March 09, 2020 a stimulation treatment was performed in the Qannick formation on the CD4-499 well in Harrison Bay County, AK. The CD4-499 was a 5 stage Horizontal Sleeve Design. The proposed treatment consisted of: The actual treatment fully completed 5 of 5 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: During the final interval of the day proppant got hung up in the castle due to a frozen chunk of proppant. After getting it loose, continued into 6ppg. Durring the 6ppg stage of the final interval proppant ran long to clean out the castle. 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. Conoco Phillips Alaska - CD4-499 Executive Summary 3 Conoco Phillips AlaskaQannickCD4-49950-103-20810*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) Grade FUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing3.5 2.992 9.3 L-80 0.3652 0 5,247 1,916 10,160Tubing4.5 3.958 12.6 L-80 0.6392 5,247 9,373 2,637 8,430Total9,3734,554ft0.73ft89.9ftft0.73ft89.9ftTop MD (ft)Btm MD (ft)Average TVD (ft)Interval #Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)BH Seat Pressure (psi)BH Peak Pressure (psi)BH Differential (psi)Rate at Shift (bpm)Toe9,328 9,370 4,0761Qannik89.8NA NA NA NA NANANA NA NA NA NA NA NA8,329 8,331 4,1002Qannik89.91:51:00 PM 1:57:00 PM 1,481 1,544 1,5703.51,825 4,404 2,579 3,028 5,437 2,409 12.57,295 7,297 4,0833Qannik89.82:38:00 PM 2:42:00 PM 2,374 2,421 2,4482.81,742 5,046 3,304 2,938 5,354 2,416 12.46,563 6,565 4,0744Qannik89.73:24:00 PM 3:28:00 PM 3,272 3,308 3,3370.71,706 4,618 2,912 2,939 4,537 1,598 12.2Heel5,838 5,840 4,0775Qannik89.84:10:00 PM 4:13:00 PM 4,169 4,194 4,2212.61,644 4,537 2,893 2,836 4,620 1,784 12.23,22576.82,7572,294Displacement to Top Sleeve/Perf (gal)(BBLS)4,525107.73,88692.565.754.6Interval #1Max Pressure (psi)8,400Isolation TypeTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data4,0829,373Directional Data3/9/2020KOPTemperature DataSleeve/Perf DepthSleeves2345Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf4,1009,370KOPAvg. TVDTotal MDConoco Phillips Alaska - CD4-499 Wellbore Information4 CUSTOMERConoco Phillips AlaskaAPIBFD (lb/gal)8.54LAT 70.29249974LEASECD4-499SALES ORDERBHST (°F)90LONG-150.9861685FORMATIONQannickDATE Max Pressure (psi)8400*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalSurfactant Crosslinker Catalyst Freeze Protect Gel Biocide BreakerInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-0 Shut-In Shut-In-1-1 20# Boragel Establish Stable Fluid 15.0 4,200 5,032 120 120 1.00 1.00 4.00 20.00 0.15 4.001-2 20# Boragel Minifrac 20.0 12,600 12,573 299 299 1.00 1.00 4.00 20.00 0.15 4.001-3 20# WaterFrac G Flush 20.0 4,525 4,532 108 108 1.00 4.00 20.00 0.15 4.001-4 Shut-In Shut-In-1-5 20# Boragel Establish Stable Fluid 15.0 4,200 2,567 61 61 1.00 1.00 4.00 20.00 0.15 4.001-6 20# Boragel Pad 20.0 10,920 10,940 260 260 1.00 1.00 4.00 20.00 0.15 4.001-7 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20.0 4,025 4,029 96 100 4,025 3,804 1.00 1.00 4.00 20.00 0.15 4.001-8 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20.0 3,875 3,886 93 100 7,750 7,583 1.00 1.00 4.00 20.00 0.15 4.001-9 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20.0 3,700 3,707 88 99 11,100 10,238 1.00 1.00 4.00 20.00 0.15 4.001-10 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20.0 3,575 3,583 85 99 14,300 13,116 1.00 1.00 4.00 20.00 0.15 4.001-11 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20.0 3,450 3,463 82 100 17,250 16,822 1.00 1.00 4.00 20.00 0.15 4.001-12 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20.0 3,325 4,172 99 121 19,950 21,060 1.00 1.00 4.00 20.00 0.15 4.001-13 20# Boragel Spacer and Ball drop 15.0 1,000 529 13 13 1.00 1.00 4.00 20.00 0.15 4.002-1 20# Boragel Pad 20.0 10,920 10,993 262 262 1.00 1.00 4.00 20.00 0.15 4.002-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20.0 4,025 4,029 96 99 4,025 3,323 1.00 1.00 4.00 20.00 0.15 4.002-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20.0 3,875 3,872 92 100 7,750 7,405 1.00 1.00 4.00 20.00 0.15 4.002-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20.0 3,700 3,670 87 98 11,100 10,405 1.00 1.00 4.00 20.00 0.15 4.002-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20.0 3,575 3,573 85 99 14,300 13,632 1.00 1.00 4.00 20.00 0.15 4.002-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20.0 3,450 3,463 82 101 17,250 17,381 1.00 1.00 4.00 20.00 0.15 4.002-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20.0 3,325 4,178 99 122 19,950 21,384 1.00 1.00 4.00 20.00 0.15 4.002-8 20# Boragel Spacer and Ball drop 15.0 1,000 464 11 11 1.00 1.00 4.00 20.00 0.15 4.003-1 20# Boragel Pad 20.0 10,920 10,932 260 260 1.00 1.00 4.00 20.00 0.15 4.003-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20.0 4,025 4,028 96 100 4,025 3,846 1.00 1.00 4.00 20.00 0.15 4.003-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20.0 3,875 3,885 93 101 7,750 7,853 1.00 1.00 4.00 20.00 0.15 4.003-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20.0 3,700 3,700 88 100 11,100 10,895 1.00 1.00 4.00 20.00 0.15 4.003-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20.0 3,575 3,575 85 100 14,300 13,920 1.00 1.00 4.00 20.00 0.15 4.003-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20.0 3,450 3,456 82 100 17,250 17,072 1.00 1.00 4.00 20.00 0.15 4.003-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20.0 3,325 4,285 102 125 19,950 22,051 1.00 1.00 4.00 20.00 0.15 4.003-8 20# Boragel Spacer and Ball drop 15.0 1,000 490 12 12 1.00 1.00 4.00 20.00 0.15 4.004-1 20# Boragel Pad 20.0 10,920 10,932 260 260 1.00 1.00 4.00 20.00 0.15 4.004-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20.0 4,025 4,032 96 100 4,025 3,943 1.00 1.00 4.00 20.00 0.15 4.004-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20.0 3,875 3,878 92 101 7,750 7,906 1.00 1.00 4.00 20.00 0.15 4.004-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20.0 3,700 3,717 89 100 11,100 11,288 1.00 1.00 4.00 20.00 0.15 4.004-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20.0 3,575 3,544 84 99 14,300 13,766 1.00 1.00 4.00 20.00 0.15 4.004-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20.0 3,450 3,460 82 100 17,250 17,059 1.00 1.00 4.00 20.00 0.15 4.004-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20.0 3,325 4,223 101 123 19,950 21,589 1.00 1.00 4.00 20.00 0.15 4.004-8 20# Boragel Spacer and Ball drop 15.0 1,000 505 12 12 1.00 1.00 4.00 20.00 0.15 4.005-1 20# Boragel Pad 20.0 10,920 10,925 260 260 1.00 1.00 4.00 20.00 0.15 4.005-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20.0 4,025 4,038 96 100 4,025 3,624 1.00 1.00 4.00 20.00 0.15 4.005-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20.0 3,875 3,874 92 100 7,750 7,800 1.00 1.00 4.00 20.00 0.15 4.005-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20.0 3,700 3,700 88 100 11,100 11,285 1.00 1.00 4.00 20.00 0.15 4.005-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20.0 3,575 3,584 85 100 14,300 14,350 1.00 1.00 4.00 20.00 0.15 4.005-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20.0 3,450 3,458 82 99 17,250 16,218 1.00 1.00 4.00 20.00 0.15 4.005-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20.0 3,325 7,485 178 221 19,950 40,591 1.00 1.00 4.00 20.00 0.15 4.005-8 20# WaterFrac G Flush 15.0 1,034 1,049 25 25 1.00 4.00 20.00 0.15 4.005-9 Freeze Protect Freeze Protect 10.0 1,260 1,247 30 301000.00196,169 201,257 4,792 5,202 371,875 391,209Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP 371,875 391,209 374,400(gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)189,350 194,429 - - - Initial Design Material Volume 194.9 189.4 779.6 1,260.0 3,898.2 29.2 779.65,559 5,581 - - - Actual Design Material Volume 200.0 194.4 800.0 1,247.0 4,000.2 30.0 800.01,260 1,247 - - - Physical Material Volume Pumped 195 182 805 6,300 4484 30 825- - - - - Physical Material Volume Deviance -3% -6% 1% 405% 12% 0% 3%--** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 194 189 774 - 4,215 - 773--** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance -3% -3% -3% - 5% - -3%----Loaded--Excess to Bid-195 -189 -780 -1,260 -3,898 -29 -780Excess to Actual-200 -194 -800 -1,247 -4,000 -30 -80050-103-208100906366755Liquid AdditivesDry Additives--Fluid TypeSeawater20# Boragel20# WaterFrac GFreeze Protect-Proppant TypeWanli 20/40-------Interval 1Qannik@ 9328 - 9369.74 ft 89.8 °FInterval 2Qannik@ 8328.97 - 8331 ft 89.9 °FInterval 3Qannik@ 7295 - 7297 ft 89.8 °FInterval 4Qannik@ 6563 - 6565.34 ft 89.7 °FInterval 5Qannik@ 5837.95 - 5840.29 ft 89.8 °FConoco Phillips Alaska - CD4-499Actual Design5 3/9/20 12:02 3/9/20 13:57 115 min NA bpm NA psi NA psi 20.1 bpm 2,902 psi 3,527 psi 18.2 bpm 1,845 psi 2,033 psi 3,188 psi 823 hhp 592 psi 920 psi 6.22 ppg 16 cP 61.9 F 8.95 72,623 lbs 72,623 lbs 72,623 lbs 0 gal 0 bbls 54,481 gal 1,297 bbls 4,532 gal 108 bbls 0 gal 0 bbls 12,573 gal 299 bbls 10,940 gal 260 bbls 22,840 gal 544 bbls 4,532 gal 108 bbls 0 gal 0 bbls 529 gal 13 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Average pH: Total Proppant Pumped* : Flush Volume: During the minifrac, one of the pumps continued to die. During the time between the minifrac and resuming pumping operations the mechanic got the pump fixed and was avalible for the rest of the stage. Pumps kicked due to high preloads. The minifrac was pumped from 12:02 until 12:35. The average rate was 15.62bpm, the average surface pressure was 2092psi and the average downhole pressure was 3133psi. Pumping restarted at 12:59. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Freeze Protect Volume: Spacer and Ball Drop Volume: Wanli 20/40 Pumped: Proppant Summary Interval Status: Josh Caprio Chad Burkett Scott Pessetto Paul Bessette Keegan Lambe Freeze Protect Volume: Average Visc: Average Temp: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Interval Summary CD4-499 - Qannick - Interval 1 Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial OA Pressure: Average Surface Pressure: Max Proppant Concentration: Average Rate: Average Missile Pressure: Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Minifrac Volume: Pad Volume: Proppant Laden Fluid Volume: Proppant in Formation: Seawater Volume: 20# Boragel Volume: 20# WaterFrac G Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Max OA Pressure: Conoco Phillips Alaska - CD4-499 Interval Summary 6 3/9/20 13:57 3/9/20 14:42 45 min 12.5 bpm 4,404 psi 5,437 psi 20.3 bpm 4,773 psi 5,807 psi 19.3 bpm 2,482 psi 2,680 psi 3,848 psi 1,176 hhp 717 psi 851 psi 6.88 ppg 16 cP 71.8 F 9.14 73,530 lbs 73,530 lbs 73,530 lbs 0 gal 0 bbls 34,242 gal 815 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 10,993 gal 262 bbls 22,785 gal 543 bbls 0 gal 0 bbls 0 gal 0 bbls 464 gal 11 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: Kicked a pump due to preload. Interval pumped to design. Josh Caprio Chad Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Scott Pessetto Paul Bessette CD4-499 - Qannick - Interval 2 Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Average Surface Pressure: Average BH Pressure: Average Missile HHP: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: Average Visc: Average Temp: Average pH: Wanli 20/40 Pumped: Total Proppant Pumped* : Proppant in Formation: Seawater Volume: 20# Boragel Volume: 20# WaterFrac G Volume: Freeze Protect Volume: Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) Minifrac Volume: Pad Volume: Proppant Laden Fluid Volume: Flush Volume: Freeze Protect Volume: Spacer and Ball Drop Volume: Keegan Lambe Conoco Phillips Alaska - CD4-499 Interval Summary 7 3/9/20 14:42 3/9/20 15:28 46 min 12.4 bpm 5,046 psi 5,354 psi 20.3 bpm 2,442 psi 3,174 psi 19.6 bpm 1,648 psi 1,844 psi 2,983 psi 792 hhp 849 psi 907 psi 6.49 ppg 16 cP 69.4 F 9.21 75,637 lbs 75,637 lbs 75,637 lbs 0 gal 0 bbls 34,351 gal 818 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 10,932 gal 260 bbls 22,929 gal 546 bbls 0 gal 0 bbls 0 gal 0 bbls 490 gal 12 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Average Visc: Proppant Summary Wanli 20/40 Pumped: Fluid Summary (by fluid description) 20# WaterFrac G Volume: Freeze Protect Volume: Keegan Lambe Josh Caprio Chad Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Scott Pessetto Paul Bessette CD4-499 - Qannick - Interval 3 Interval Summary Pump Time: Average Missile Pressure: Average Surface Pressure: Initial Rate (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Fluid Summary (by stage description) Minifrac Volume: Total Proppant Pumped* : Proppant in Formation: Proppant Laden Fluid Volume: 20# Boragel Volume: Max OA Pressure: Spacer and Ball Drop Volume: Interval Status: Interval Pumped to design. Seawater Volume: Start Date/Time: End Date/Time: Average Missile HHP: Average BH Pressure: Pad Volume: Average Temp: Average pH: Max Proppant Concentration: Flush Volume: Initial OA Pressure: Freeze Protect Volume: Conoco Phillips Alaska - CD4-499 Interval Summary 8 3/9/20 15:28 3/9/20 16:13 45 min 12.2 bpm 4,618 psi 4,537 psi 20.3 bpm 2,452 psi 3,024 psi 19.6 bpm 1,534 psi 1,726 psi 2,856 psi 737 hhp 881 psi 922 psi 6.28 ppg 16 cP 69.4 F 9.18 75,551 lbs 75,551 lbs 75,551 lbs 0 gal 0 bbls 34,291 gal 816 bbls 0 gal 0 bbls 0 gal 0 bbls 0 gal 0 bbls 10,932 gal 260 bbls 22,854 gal 544 bbls 0 gal 0 bbls 0 gal 0 bbls 505 gal 12 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: Interval Pumped to design. Keegan Lambe Josh Caprio Chad Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Scott Pessetto Paul Bessette Fluid Summary (by stage description) Spacer and Ball Drop Volume: CD4-499 - Qannick - Interval 4 Interval Summary Proppant Summary Total Proppant Pumped* : Seawater Volume: Initial BH Pressure (Breakdown): Pump Time: Average BH Pressure: Start Date/Time: Max BH Pressure: Average Rate: Freeze Protect Volume: Average Missile HHP: Average Visc: Initial OA Pressure: Max OA Pressure: Proppant in Formation: Wanli 20/40 Pumped: Max Rate: Proppant Laden Fluid Volume: Average Surface Pressure: 20# Boragel Volume: 20# WaterFrac G Volume: Initial Rate (Breakdown): Max Proppant Concentration: Average Temp: Average pH: Fluid Summary (by fluid description) Flush Volume: Freeze Protect Volume: Average Missile Pressure: Max Surface Pressure: Initial Surface Pressure (Breakdown): Minifrac Volume: Pad Volume: End Date/Time: Conoco Phillips Alaska - CD4-499 Interval Summary 9 3/9/20 16:13 3/9/20 17:05 52 min 12.2 bpm 4,537 psi 4,620 psi 20.3 bpm 1,977 psi 2,891 psi 19.0 bpm 1,482 psi 1,672 psi 2,773 psi 692 hhp 857 psi 891 psi 6.44 ppg 17 cP 64.1 F 9.29 2722 psi 0.668 psi/ft 93,868 lbs 93,868 lbs 93,868 lbs 0 gal 0 bbls 37,064 gal 882 bbls 1,049 gal 25 bbls 1,247 gal 30 bbls 0 gal 0 bbls 10,925 gal 260 bbls 26,139 gal 622 bbls 1,049 gal 25 bbls 1,247 gal 30 bbls 0 gal 0 bbls Completed ISDP: Final Fracture Gradient: Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) Spacer and Ball Drop Volume: End Date/Time: Start Date/Time: Freeze Protect Volume: Average Missile HHP: 20# Boragel Volume: 20# WaterFrac G Volume: Total Proppant Pumped* : Proppant in Formation: Average pH: CD4-499 - Qannick - Interval 5 Pump Time: Initial BH Pressure (Breakdown): Initial Rate (Breakdown): Max Surface Pressure: Average Missile Pressure: Average Temp: Interval Summary Flush Volume: Minifrac Volume: Pad Volume: Average BH Pressure: Initial OA Pressure: Max OA Pressure: Average Surface Pressure: Proppant Laden Fluid Volume: Wanli 20/40 Pumped: Seawater Volume: Max Rate: Average Visc: Initial Surface Pressure (Breakdown): Max BH Pressure: Average Rate: Interval Status: Max Proppant Concentration: Freeze Protect Volume: Conoco Phillips Alaska - CD4-499 Interval Summary 10 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Chad Burkett *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Scott Pessetto Paul Bessette Keegan Lambe Josh Caprio During the 5ppg stage the proppant got stuck in the Castle. After jarring the castle a large ice chunk fell out and proppant resumed flowing into the hopper. After getting the castle broke free, the castle went into the negatives on the scale weight. All extra proppant was pumped in the 6ppg stage. Conoco Phillips Alaska - CD4-499 Interval Summary 11 CustomerFormationLeaseAPIDateWell SummaryWanli 20/40 Total ProppantBH Pressure Rate Visc Temp pH BH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs13188 18.2 16 61.9 9.0 3527 20.1 54,481 1,297 4,532 108 59,013 1,405 72,623 72,623 23848 19.3 16 72 9.1 5807 20.3 34,242 815 34,242 815 73,530 73,530 32983 19.6 16 69 9.2 3174 20.3 34,351 818 34,351 818 75,637 75,637 42856 19.6 16 69 9.2 3024 20.3 34,291 816 34,291 816 75,551 75,551 52773 19.0 17 64 9.3 2891 20.3 37,064 882 1,049 25 1,247 30 39,360 937 93,868 93,868 Minimum34242 815 1049 25 1247 30 34242 815 72623 72623 Average38886 926 2791 66 1247 30 40251 958 78242 78242 Maximum54481 1297 4532 108 1247 30 59013 1405 93868 93868 Wanli 20/40 Total ProppantPressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs TotalPlanned0 0 189,350 4,508 5,559 132 1,260 30 196,169 4,671 371,875 371,875Recorded3130 19.2 16 67 9.15 5807 20.3 0 0 194,429 4,629 5,581 133 1,247 30 201,257 4,792 391,209 391,209Weight Tickets374,400 374,400** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software Total FluidFluidsProppantsFluidsProppantsTotal FluidFreeze ProtectFreeze ProtectAverage Max20# WaterFrac GSeawater20# BoragelSeawater20# BoragelIntervalAverage Max20# WaterFrac GMarch 09, 202050-103-20810CD4-499QannickConoco Phillips AlaskaConoco Phillips Alaska - CD4-499 Fluid System-Proppant Summary12 <-Paste Interval 1 Plots HerePressure Test - Day 13/8/202013:0813:0913:1013:1113:1213:1313:1413:153/8/202013:16Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)232221Global Event Log212223Prime Pumps Pressure Test Good Test13:08:03 13:09:51 13:13:02Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots13 <-Paste Interval 1 Plots HereNitrogen Pop-Off Test - Day 13/8/202013:1813:1913:2013:2113:2213:2313:243/8/202013:25Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)262524Global Event Log242526N2 Test N2 Pop @ 7990psi N2 Pop @ 8801psi13:17:55 13:19:32 13:23:33Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots14 <-Paste Interval 1 Plots HerePressure Test - Day 23/9/202010:2010:2210:2410:2610:2810:303/9/202010:32Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)7654Global Event Log4567Pressure Test Pressure Test - GlobalsPressure Test - Locals Pressure Test - Max10:20:32 10:20:5110:21:37 10:25:26Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots15 <-Paste Interval 1 Plots HereBlender Chemical Plot - Bucket Tests3/9/202006:32:0006:32:3006:33:0006:33:3006:34:0006:34:303/9/202006:35:00Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 WB Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)ABBCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots16 ADP Chemical Plot - Bucket Tests3/9/202007:16:3007:17:0007:17:3007:18:0007:18:3007:19:003/9/202007:19:30Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)ABCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots17 Treatment Plot - Minifrac3/9/202012:0512:1012:1512:2012:2512:303/9/202012:35Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots18 Blender Chemical Plot - Minifrac3/9/202012:0512:1012:1512:2012:2512:303/9/202012:35Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots19 Halliburton Pumping Diagnostic Analysis ToolkitMinifrac - G Function0.20.40.60.81.01.2G(Time)222022402260228023002320234023602380A0100200300400D (0.0034, 466.1) (Y = 464.3) Gauge BH Pres (psi)Smoothed Pressure (psi)Smoothed Adaptive 1st Derivative (psi)Smoothed Adaptive G*dP/dG (psi)AADD11ClosureTime1.21GBP2568SP2570DP146.2FE38.95Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots20 ADP Chemical Plot - Minifrac3/9/202012:0512:1012:1512:2012:2512:303/9/202012:35Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots21 Treatment Plot - Interval 013/9/202013:0013:1013:2013:3013:403/9/202013:50Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD11413121110987652Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots22 Blender Chemical Plot - Interval 013/9/202013:0013:1013:2013:3013:403/9/202013:50Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB11413121110987652Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots23 ADP Chemical Plot - Interval 013/9/202013:0013:1013:2013:3013:403/9/202013:50Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB11413121110987652Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots24 Net Pressure Plot - Interval 01567892345610Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 2500 psi 0 Time = 03/09/20 12:55:35 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 1 Plots25 <-Paste Interval 2 Plots HereTreatment Plot - Interval 023/9/202014:0014:1014:2014:303/9/202014:40Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1876543211432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 2 Plots26 <-Paste Interval 2 Plots HereBlender Chemical Plot - Interval 023/9/202014:0014:1014:2014:303/9/202014:40Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB1876543211432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 2 Plots27 <-Paste Interval 2 Plots HereADP Chemical Plot - Interval 023/9/202014:0014:1014:2014:303/9/202014:40Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB1876543211432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 2 Plots28 <-Paste Interval 2 Plots HereNet Pressure Plot - Interval 0223410Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 2500 psi 0 Time = 03/09/20 13:58:03 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 2 Plots29 <-Paste Interval 3 Plots HereTreatment Plot - Interval 033/9/202014:4014:5015:0015:1015:203/9/202015:30Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD187654321843Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 3 Plots30 <-Paste Interval 3 Plots HereBlender Chemical Plot - Interval 033/9/202014:4014:5015:0015:103/9/202015:20Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB187654321843Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 3 Plots31 <-Paste Interval 3 Plots HereADP Chemical Plot - Interval 033/9/202014:4014:5015:0015:1015:203/9/202015:30Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB187654321843Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 3 Plots32 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 032345678923410Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 2500 psi 0 Time = 03/09/20 14:41:20 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 3 Plots33 <-Paste Interval 4 Plots HereTreatment Plot - Interval 043/9/202015:3015:4015:5016:003/9/202016:10Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD187654321854Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 4 Plots34 <-Paste Interval 4 Plots HereBlender Chemical Plot - Interval 043/9/202015:3015:4015:5016:003/9/202016:10Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB187654321854Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 4 Plots35 <-Paste Interval 4 Plots HereADP Chemical Plot - Interval 043/9/202015:3015:4015:5016:003/9/202016:10Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB187654321854Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 4 Plots36 <-Paste Interval 4 Plots HereNet Pressure Plot - Interval 04923410Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 2500 psi 0 Time = 03/09/20 15:32:08 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 4 Plots37 <-Paste Interval 5 Plots HereTreatment Plot - Interval 053/9/202016:1016:2016:3016:4016:503/9/202017:00Time0100020003000400050006000A0102030405060708090100B024681012C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD98765432185Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 5 Plots38 <-Paste Interval 5 Plots HereBlender Chemical Plot - Interval 053/9/202016:1016:2016:3016:4016:503/9/202017:00Time012345A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 Cat 3 Conc -LA5 (gal/Mgal)B1 SP Breaker Conc -DA1 (lb/Mgal)AAB98765432185Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 5 Plots39 <-Paste Interval 5 Plots HereADP Chemical Plot - Interval 053/9/202016:1016:2016:3016:4016:503/9/202017:00Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA2 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AB98765432185Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 5 Plots40 <-Paste Interval 5 Plots HereNet Pressure Plot - Interval 05789234510Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 2500 psi 0 Time = 03/09/20 16:15:25 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Mar-2020Sales Order #: 0906366755Well Description: CD4 499UWI: 50-103-20810Conoco Phillips Alaska - CD4-499 Interval 5 Plots41 Sales Order# - - - - - - - - - - Field Break Test Lab Testing Event Logs Fann 15 Minute Real-Time QC Well Summary Stimulation Treatment Appendix Chemical Summary Planned Design Water Straps Water Analysis Prepared for: Adam Klem March 9, 2020 Harrison Bay County, AK 0906366755 Conoco Phillips Alaska CD4-499 Intervals 1-5 Qannick Formation API: 50-103-20810 Conoco Phillips Alaska - CD4-499 Appendix 42 Interval Date Designed Proppant (lbs) Proppant in Formation (lbs) Vol Clean (bbl) Vol Slurry (bbl) Top Perf (ft) Bottom Perf (ft) Fluid System 1 3/9/2020 74375 72,623 1405 1,481 9,328 9,370 Boragel 2 3/9/2020 74375 73,530 815 892 8,329 8,331 Boragel 3 3/9/2020 74375 75,637 818 897 7,295 7,297 Boragel 4 3/9/2020 74375 75,551 816 896 6,563 6,565 Boragel 5 3/9/2020 74385 93,868 937 1035 5,838 5,840 Boragel CD4-499 Interval Highlights Conoco Phillips Alaska - CD4-499 Well Summary 43 CustomerConoco Phillips AlaskaFormationQannickLeaseCD4-499API50-103-20810DateInterval Summary - Chemicals LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)Prime Up0 000000157 53 229 0 1403 9 228233 33 133 0 774 5 133333 33 131 0 760 5 131433 33 134 0 791 5 134538 29 179 6300 756 6 200Total 195 182 805 6300 4484 30 825w/o Prime Up195 182 805 6300 4484 30 825Interval3/9/2020Dry AdditivesLiquid AdditivesConoco Phillips Alaska - CD4-499 Chemical Summary44 CUSTOMERConoco Phillips AlaskaFALSEAPIBFD (lb/gal)8.54LAT 70.29249974LEASECD4-499SALES ORDERBHST (°F)90LONG-150.9861685FORMATIONQannickDATE Max Pressure (psi)8400*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeSurfactant Crosslinker Catalyst Freeze Protect Gel Biocide BreakerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In1:18:29 1-2 20# Boragel Establish Stable Fluid 15 4,200 100 100 0:06:40 1:18:29 1.00 1.00 4.00 20.00 0.15 4.001-3 20# Boragel Minifrac 20 12,600 300 300 0:15:00 1:11:49 1.00 1.00 4.00 20.00 0.15 4.001-4 20# WaterFrac G Flush 20 4,525 108 108 0:05:23 0:56:49 1.00 4.00 20.00 0.15 4.001-5 Shut-In Shut-In0:51:25 1-6 20# Boragel Establish Stable Fluid 15 4,200 100 100 0:06:40 0:51:25 1.00 1.00 4.00 20.00 0.15 4.001-7 20# Boragel Pad 20 10,920 260 260 0:13:00 0:44:45 1.00 1.00 4.00 20.00 0.15 4.001-8 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20 4,025 96 100 4,025 0:05:01 0:31:45 1.00 1.00 4.00 20.00 0.15 4.001-9 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20 3,875 92 100 7,750 0:05:02 0:26:45 1.00 1.00 4.00 20.00 0.15 4.001-10 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20 3,700 88 100 11,100 0:05:00 0:21:43 1.00 1.00 4.00 20.00 0.15 4.001-11 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20 3,575 85 100 14,300 0:05:02 0:16:42 1.00 1.00 4.00 20.00 0.15 4.001-12 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20 3,450 82 100 17,250 0:05:03 0:11:40 1.00 1.00 4.00 20.00 0.15 4.001-13 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20 3,325 79 100 19,950 0:05:02 0:06:38 1.00 1.00 4.00 20.00 0.15 4.001-14 20# Boragel Spacer and Ball drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 4.00 20.00 0.15 4.002-1 20# Boragel Pad 20 10,920 260 260 0:13:00 0:44:45 1.00 1.00 4.00 20.00 0.15 4.002-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20 4,025 96 100 4,025 0:05:01 0:31:45 1.00 1.00 4.00 20.00 0.15 4.002-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20 3,875 92 100 7,750 0:05:02 0:26:45 1.00 1.00 4.00 20.00 0.15 4.002-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20 3,700 88 100 11,100 0:05:00 0:21:43 1.00 1.00 4.00 20.00 0.15 4.002-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20 3,575 85 100 14,300 0:05:02 0:16:42 1.00 1.00 4.00 20.00 0.15 4.002-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20 3,450 82 100 17,250 0:05:03 0:11:40 1.00 1.00 4.00 20.00 0.15 4.002-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20 3,325 79 100 19,950 0:05:02 0:06:38 1.00 1.00 4.00 20.00 0.15 4.002-8 20# Boragel Spacer and Ball drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 4.00 20.00 0.15 4.003-1 20# Boragel Pad 20 10,920 260 260 0:13:00 0:44:45 1.00 1.00 4.00 20.00 0.15 4.003-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20 4,025 96 100 4,025 0:05:01 0:31:45 1.00 1.00 4.00 20.00 0.15 4.003-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20 3,875 92 100 7,750 0:05:02 0:26:45 1.00 1.00 4.00 20.00 0.15 4.003-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20 3,700 88 100 11,100 0:05:00 0:21:43 1.00 1.00 4.00 20.00 0.15 4.003-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20 3,575 85 100 14,300 0:05:02 0:16:42 1.00 1.00 4.00 20.00 0.15 4.003-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20 3,450 82 100 17,250 0:05:03 0:11:40 1.00 1.00 4.00 20.00 0.15 4.003-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20 3,325 79 100 19,950 0:05:02 0:06:38 1.00 1.00 4.00 20.00 0.15 4.003-8 20# Boragel Spacer and Ball drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 4.00 20.00 0.15 4.004-1 20# Boragel Pad 20 10,920 260 260 0:13:00 0:44:45 1.00 1.00 4.00 20.00 0.15 4.004-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20 4,025 96 100 4,025 0:05:01 0:31:45 1.00 1.00 4.00 20.00 0.15 4.004-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20 3,875 92 100 7,750 0:05:02 0:26:45 1.00 1.00 4.00 20.00 0.15 4.004-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20 3,700 88 100 11,100 0:05:00 0:21:43 1.00 1.00 4.00 20.00 0.15 4.004-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20 3,575 85 100 14,300 0:05:02 0:16:42 1.00 1.00 4.00 20.00 0.15 4.004-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20 3,450 82 100 17,250 0:05:03 0:11:40 1.00 1.00 4.00 20.00 0.15 4.004-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20 3,325 79 100 19,950 0:05:02 0:06:38 1.00 1.00 4.00 20.00 0.15 4.004-8 20# Boragel Spacer and Ball drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 4.00 20.00 0.15 4.005-1 20# Boragel Pad 20 10,920 260 260 0:13:00 0:59:49 1.00 1.00 4.00 20.00 0.15 4.005-2 20# Boragel Proppant Laden Fluid Wanli 20/40 1.00 20 4,025 96 100 4,025 0:05:01 0:46:49 1.00 1.00 4.00 20.00 0.15 4.005-3 20# Boragel Proppant Laden Fluid Wanli 20/40 2.00 20 3,875 92 100 7,750 0:05:02 0:41:48 1.00 1.00 4.00 20.00 0.15 4.005-4 20# Boragel Proppant Laden Fluid Wanli 20/40 3.00 20 3,700 88 100 11,100 0:05:00 0:36:46 1.00 1.00 4.00 20.00 0.15 4.005-5 20# Boragel Proppant Laden Fluid Wanli 20/40 4.00 20 3,575 85 100 14,300 0:05:02 0:31:45 1.00 1.00 4.00 20.00 0.15 4.005-6 20# Boragel Proppant Laden Fluid Wanli 20/40 5.00 20 3,450 82 100 17,250 0:05:03 0:26:44 1.00 1.00 4.00 20.00 0.15 4.005-7 20# Boragel Proppant Laden Fluid Wanli 20/40 6.00 20 3,325 79 100 19,950 0:05:02 0:21:41 1.00 1.00 4.00 20.00 0.15 4.005-8 20# WaterFrac G Flush 15 1,034 25 25 0:01:38 0:16:38 1.00 4.00 20.00 0.15 4.005-9 Freeze Protect Freeze Protect 2 1,260 30 30 0:15:00 0:15:00 1000.00196,169 4,671 5,060 371,875Design Total (gal)Design Total (lbs)LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP 371,875(gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)189,350- Initial Design Material Volume 194.9 189.4 779.6 1,260.0 3,898.2 29.2 779.65,559-1,260---LoSurf-300D CL-31 CAT-3 LVT-200 WG-36 BE-6 SP -(gpm) (gpm) (gpm) (gpm) ppm ppm ppm-Max Additive Rate 0.8 0.8 3.4 840.0 16.8 0.1 3.4-Min Additive Rate3/9/20Liquid AdditivesDry Additives50-103-208100906366755Fluid TypeSeawater20# Boragel20# WaterFrac GFreeze Protect----Proppant TypeWanli 20/40----Interval 1Qannik@ 9328 - 9369.74 ft 89.8 °FInterval 2Qannik@ 8328.97 - 8331 ft 89.9 °FInterval 3Qannik@ 7295 - 7297 ft 89.8 °FInterval 4Qannik@ 6563 - 6565.34 ft 89.7 °FInterval 5Qannik@ 5837.95 - 5840.29 ft 89.8 °F4:32:33 Conoco Phillips Alaska - CD4-499Planned Design45 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan CD5 101 19,175 457 98 9 1,444 342 Atigan CD5 103 19,562 466 100 48 8,702 2073 Atigan CD5 104 19,755 470 100 104 19,755 4704 Atigan CD5 106 20,142 480 103 106 20,142 4805 Atigan CD5 104 19,755 470 102 16 2,722 656 Atigan CD5 104 19,755 470 103 9 1,444 347 Atigan CD5 105 19,949 475 104 9 1,444 348 Atigan CD5 105 19,949 475 103 9 1,444 349 Atigan CD5 106 20,142 480 101 9 1,444 3410 Atigan CD5 105 19,949 475 102 9 1,444 3411 Atigan CD5 102 19,368 461 104 9 1,444 3412 Atigan CD5 104 19,755 470 104 9 1,444 3413 Atigan CD5 104 19,755 470 106 9 1,444 34Gallons Barrels Gallons Barrels Gallons Barrels257,010 6,119 64,320 1,531 192,690 4,588Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):471 471 471 471Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips AlaskaCD4-4993/9/2020Qannick0906366755Conoco Phillips Alaska - CD4-499 Water Straps46 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 1.030 65.4 0 27,450 800 1,560 1,560 3,120 14.0 6.78 7.51 9.10 Y 2,655 2 1.030 68.3 0 30,120 1,200 1,640 1,320 2,960 13.0 6.97 7.10 9.05 Y 9,800 3 1.031 69.4 0 27,450 800 1,680 1,280 2,960 14.0 6.69 7.05 9.11 Y 80,027 4 1.030 67.8 0 27,450 800 1,560 1,480 3,040 14.0 6.84 7.08 9.10 Y 1,140 5 1.029 64.1 0 30,120 800 1,480 1,400 2,880 14.0 6.96 7.14 9.08 Y 686 6 1.030 65.7 0 33,150 1,200 1,640 1,560 3,200 13.0 7.04 7.21 9.11 Y 504 7 1.031 67.9 0 33,150 800 1,520 1,480 3,000 14.0 7.03 7.22 9.07 Y 804 8 1.031 64.3 5 30,120 1,200 1,480 1,880 3,360 14.0 6.94 7.14 9.05 Y 2,497 9 1.030 67.8 0 33,150 800 1,400 1,880 3,280 13.0 6.97 7.18 9.14 Y 4,210 10 1.028 69.4 0 33,150 1,200 1,520 1,720 3,240 13.0 7.14 7.25 9.05 Y 1,887 11 1.031 60.1 0 30,120 1,200 1,640 1,440 3,080 14.0 7.04 7.31 9.04 Y 30,867 12 1.030 59.3 5 30,120 800 1,800 1,440 3,240 13.0 7.06 7.29 9.11 Y 2,572 13 1.032 62.4 5 33,150 800 1,720 1,440 3,160 13.0 7.09 7.25 9.04 Y 2,127 Average 1.030 67.7 0 28,118 900 1,610 1,410 3,020 13.8 6.82 7.19 9.09 - 23,405 Maximum 1.032 69.4 5 33,150 1,200 1,800 1,880 3,360 14.0 7.14 7.51 9.14 - 80,027 Minimum 1.028 59.3 0 27,450 800 1,400 1,280 2,880 13.0 6.69 7.05 9.04 - 504 Range 0.004 10.1 5 5,700 400 400 600 480 1.0 0.45 0.46 0.10 - 79,523 Well Name:CD4-499 Water Source: Alaska District Field QC Prejob Water Analysis on Location Company: Conoco Phillips Conoco Phillips Alaska - CD4-499 Water Analysis Day 1 47 Linear XL Interval Stage Visc pH Temp °F pH 1 Minifrac 10 6.8 49.7 9.00 Pad166.53829.06 1# 16 6.54 73 9.05 2# 16 6.55 72 9.00 .3# 16 6.8 72 9.03 4# 17 7 68 9.27 5# 17 6.85 68 9.32 6# 16 6.89 68 9.27 2 Pad 16 7 66.9 9.25 1# 17 7.02 70 9.06 2# 16 6.95 70 9.27 3# 17 6.9 69 9.10 4# 16 6.94 70.3 9.23 5# 16 7 68.5 9.28 6# 15 6.89 71.2 9.31 3 Pad 18 6.95 66.5 9.35 1# 18 6.96 66 9.14 2# 17 6.92 68 9.36 3# 16 6.98 70.1 9.17 4# 16 6.86 70.1 9.31 5# 16 6.6 72 9.35 6# 16 6.8 66.8 9.30 4 Pad 15 6.98 72 9.21 1# 16 6.87 70 9.16 2# 16 6.98 71 9.22 3# 18 6.93 68 9.16 4# 18 6.9 67.1 9.19 5# 17 6.9 68.5 9.15 6# 16 6.8 69 9.15 5 Pad 17 6.95 57.7 9.27 1# 18 6.91 64.5 9.29 2# 17 6.9 66 9.36 3# 17 6.9 65.5 9.29 4# 16 6.8 66 9.31 5# 17 6.8 65 9.27 6#Missed Sample Customer:ConocoPhillips Alaska, Inc. Wellname & #:CD4-499 Date:March 9, 2020 Comments Adjusted ADP Setpoints Conoco Phillips Alaska - CD4-499 Real-Time QC 48 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test749.101.001.004.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SPKK.LambeHydration Visc:1369.4All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.98Hydration pH:7.10CD4-499Stage(s):Break Test90Water Source:CD5ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/7/2020ConocoPhillipsProject No:0500100015002000250030002.00 4.00 10.00 20.00 30.00 60.00 90.00 120.00 150.00 180.0030:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsSeries1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 15 Prejob Break Test49 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->mini FracPad1PPG4PPG1.001.004.004.004.001.001.004.001.001.004.004.001.001.004.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SP BreakerCChad BurkettHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:CD4-499Stage(s):190Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/9/2020ConocoPhillipsProject No:050010001500200025003000350000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 15 Zone 150 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad1PPG1.001.004.004.004.001.001.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SP BreakerCChad BurkettHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:CD4-499Stage(s):290Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/9/2020ConocoPhillipsProject No:020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 2 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 15 Zone 251 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad4.001.001.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SP BreakerCChad BurkettHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:CD4-499Stage(s):390Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/9/2020ConocoPhillipsProject No:0200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 3 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 15 Zone 352 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad3PPG1.001.004.004.004.001.001.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SP BreakerCChad BurkettHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:CD4-499Stage(s):490Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/9/2020ConocoPhillipsProject No:020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 4 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 15 Zone 453 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad3PPG1.001.004.004.004.001.001.004.00Temp 0FPHLOSURF-300DCL-31CAT-3SP BreakerCChad BurkettHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:CD4-499Stage(s):590Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:3/9/2020ConocoPhillipsProject No:02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 5 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips Alaska - CD4-499Fann 14 Zone 554 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 05:24:52 (03/09/20) Start Job Starting Job 0 15 15 0 151 05:24:52 (03/09/20) Next Treatment Treatment Interval 1 0 15 15 0 151 5:24:56 Next Stage Shut-In 0 99 27 0 13242 9:15:19 Prime Pumps Prime Pumps 0 74 30 0 18773 9:55:35 Pressure Test Pressure Test Little Red 0 124 126 0 18774 10:20:31 Pressure Test Pressure Test 0 49 68 0 18775 10:20:50 Pressure Test Pressure Test - Globals 0 172 129 0 18776 10:21:36 Pressure Test Pressure Test - Locals 0 579 570 0 18777 10:25:25 Pressure Test Pressure Test - Max 0 9491 9515 0 18778 10:33:03 Pressure Test Pressure Test - Little Red 0 74 139 0 18779 10:49:58 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 255 285 0 187710 11:29:44 Other Mixing Gel 0 557 451 0 188011 12:02:55 Open Well Open Well 0 544 412 0 18682 12:03:59 Next Stage Establish Stable Fluid 0.6 860 771 2.2 224712 12:05:48 Other Pump Died 12.95 2149 1998 8.1 326813 12:11:47 Other Pump Died 100.47 2383 2276 19.4 33993 12:13:00 Next Stage Minifrac 120.38 2195 2049 18.1 32944 12:28:37 Next Stage Flush 419.74 2126 1967 19.2 320814 12:30:43 Other Pump Kicked due to Preload 460.04 1031 925 17.2 317715 12:32:39 Other Pump Kicked due to Preload 487.45 1542 1351 12.3 258916 12:33:58 Other Pump Kicked due to Preload 506.34 962 798 13.6 30655 13:01:06 Next Stage Shut-In for FET Analysis 527.64 1044 924 2 27246 13:01:18 Next Stage Establish Stable Fluid 528.13 1133 1007 2.8 27937 13:05:46 Next Stage Pad 589.26 2149 2001 18.3 321717 13:13:48 Other Swapping Rate on Pump 742.88 2022 1812 18.6 31958 13:19:12 Next Stage 1.00ppg Wanli 20/40 849.75 2254 2087 19.9 32369 13:24:15 Next Stage 2.00ppg Wanli 20/40 950.03 2140 1984 19.8 322018 13:27:13 Other Pump Kicked Preload 1008.43 1916 1763 15.3 320010 13:29:32 Next Stage 3.00ppg Wanli 20/40 1050.25 2080 1897 19.8 323419 13:33:56 Other Pump Kicked Out Preload 1137.18 1491 1304 16.9 304111 13:34:45 Next Stage 4.00ppg Wanli 20/40 1149.36 1799 1600 14.7 312020 13:35:51 Other Ball Loaded 1166.06 2270 2099 18.3 331412 13:40:03 Next Stage 5.00ppg Wanli 20/40 1248.55 2046 1857 19.7 323213 13:45:10 Next Stage 6.00ppg Wanli 20/40 1348.81 2015 1810 19.6 326314 13:51:23 Next Stage Spacer and Ball Drop 1470.46 2111 1925 19.9 329621 13:51:53 Drop Ball Drop Ball 1480.47 2631 2469 20 34362 13:52:01 (03/09/20) Next Treatment Treatment Interval 2 1483.14 2865 2680 20 34651 13:52:01 Next Stage Pad 1483.47 2899 2717 20 352522 13:57:11 Ball on Seat Ball on Seat 1569.83 1840 1627 12.6 304323 13:57:16 Break Formation Break Formation 1570.87 1201 1830 12.5 54522 14:06:13 Next Stage 1.00ppg Wanli 20/40 1744.88 3737 3491 20.1 47383 14:11:11 Next Stage 2.00ppg Wanli 20/40 1844.66 3296 3084 20 442824 14:15:45 Other Pump Kicked Out Preload 1936.09 2540 2336 20 36754 14:16:17 Next Stage 3.00ppg Wanli 20/40 1944.36 2007 1813 14.7 33185 14:21:35 Next Stage 4.00ppg Wanli 20/40 2042.75 2163 1939 20 333925 14:24:12 Other Ball Loaded 2095.11 2030 1890 19.9 32786 14:26:34 Next Stage 5.00ppg Wanli 20/40 2142.27 1945 1736 19.932267 14:31:39 Next Stage 6.00ppg Wanli 20/40 2243.12 1856 1675 19.832108 14:37:49 Next Stage Spacer and Ball Drop 2365.23 2029 1844 20.2322326 14:38:16 Drop Ball Drop Ball 2374.33 2533 2342 20.233623 14:38:22 (03/09/20) Next Treatment Treatment Interval 3 2376.35 2579 2384 20.233041 14:38:22 Next Stage Pad 2376.69 2579 2387 20.2329827 14:42:43 Ball on Seat Ball on Seat 2448.13 1756 1577 12.3295228 14:42:49 Break Formation Break Formation 2449.35 478 646 12.3 53692 14:52:21 Next Stage 1.00ppg Wanli 20/40 2637.16 1926 1730 20.2 29353 14:57:19 Next Stage 2.00ppg Wanli 20/40 2736.79 1910 1684 20.1 29724 15:02:21 Next Stage 3.00ppg Wanli 20/40 2837.61 1884 1631 20 29965 15:07:21 Next Stage 4.00ppg Wanli 20/40 2937.56 1841 1653 19.9 302829 15:08:38 Other Load Ball 2962.92 1796 1619 19.9 30126 15:12:22 Next Stage 5.00ppg Wanli 20/40 3037.41 1835 1661 19.9 30387 15:17:25 Next Stage 6.00ppg Wanli 20/40 3137.45 1799 1631 19.8 30518 15:23:46 Next Stage Spacer and Ball Drop 3262.81 1914 1708 20.1 309130 15:24:13 Drop Ball Drop Ball 3272.23 2283 2099 20.2 31534 15:24:20 (03/09/20) Next Treatment Treatment Interval 4 3274.57 2400 2209 20.2 31561 15:24:21 Next Stage Pad 3274.91 2420 2256 20.2 315631 15:28:18 Ball on Seat Ball on Seat 3336.79 1721 1531 12.2 295432 15:28:23 Break Formation Break Formation 3337.61 793 1865 12.2 45522 15:38:21 Next Stage 1.00ppg Wanli 20/40 3534.99 1875 1625 20.3 28273 15:43:19 Next Stage 2.00ppg Wanli 20/40 3635.5 1811 1622 20.2 28604 15:48:20 Next Stage 3.00ppg Wanli 20/40 3736.19 1715 1577 20.1 28895 15:53:21 Next Stage 4.00ppg Wanli 20/40 3836.32 1674 1512 19.9 28966 15:58:21 Next Stage 5.00ppg Wanli 20/40 3935.6 1664 1514 19.9 28977 16:03:24 Next Stage 6.00ppg Wanli 20/40 4035.7 1748 1492 19.7 29338 16:09:39 Next Stage Spacer and Ball Drop 4159.1 1793 1614 20.1 293433 0.673703704 Drop Ball Drop Ball 4168.87 2287 2106 20.2 30375 16:10:15 (03/09/20) Next Treatment Treatment Interval 5 4171.23 2406 2229 20.2 30311 16:10:15 Next Stage Pad 4171.56 2406 2229 20.2 303334 16:13:31 Ball on Seat Ball on Seat 4221.37 1659 1466 12.2 285135 16:13:36 Break Formation Break Formation 4222.19 588 1033 12.2 46352 16:24:09 Next Stage 1.00ppg Wanli 20/40 4431.76 1788 1615 20.3 27313 16:29:05 Next Stage 2.00ppg Wanli 20/40 4531.4 1756 1600 20.2 27584 16:34:06 Next Stage 3.00ppg Wanli 20/40 4632.24 1699 1508 20.1 27665 16:39:05 Next Stage 4.00ppg Wanli 20/40 4732.28 1658 1422 20 28026 16:44:06 Next Stage 5.00ppg Wanli 20/40 4832.48 1636 1400 19.9 281336 16:47:02 Other Frozen Prop Stuck In Castle 4890.85 1636 1491 19.9 28297 16:49:07 Next Stage 6.00ppg Wanli 20/40 4932.32 1729 1526 19.9 28438 17:00:15 Next Stage Flush 5153.17 1818 1603 20.1 28659 17:02:15 Next Stage Freeze Protect 5178.22 1459 1277 9.5 278937 17:05:40 ISIP ISIP 5207.92 1365 1141 0 273638 17:15:53 Other Blow Down 5207.92 145 -12 0 2710Event Log Intervals 1-5Conoco Phillips Alaska - CD4-499 Event Log 55 Laboratory Project ID Number: Customer: Well Name & Number: Fluid System: Date: Technician(s) Performing Testing: Reviewed & Approved By: 2071409 Conoco Phillips CD4-499 Seawater SL #1455 BoraGel Prudhoe Bay Field Laboratory - Rockies NWA March 1, 2020 Jason Doyle First 10 minutes at 511 1/sec After 10 minutes the shear rate was decreased to 100 1/sec Summary of Testing and Results Customer:Fluid System: Bob Type: Well Name:Water Source: Shear Rate (1/sec): Date:BHST (oF):Lab Project ID:2071409 Lot # Units ppt gpt ppt ppt gpt gpt Test No: Water pH Min. Viscosity (cP)Temp. (oF): Base Gel (#)1 6.0 75 Base Gel Visc (cP)2 7.0 75 Base Gel pH 3 8.0 75 Base Gel Temp. (oF)4 9.0 75 Buffered pH 5 10.0 75 Crosslink pH 10 13 75 Final pH 4 5 8.46 B5X 1 2 13.0 6.976.97 13.0 Break Time (hr:min) 8.76 20.00 3 4 20.00 7.12 8.858.92 7.12 75 75 65 Test Temp. (oF) n/a Test Notes: 90 2:45 90 BREAK TEST CHART *calculated values FLUID PROPERTIES Gel Hydration (511/s) March 1, 2020 3 CD4-499 FLUID DESIGN Conoco Phillips BoraGel 511 / 100 20.00 4.000.00 20.00 2 6 0.15 Test No: BE-6 WG-36 0.15 LoSurf 300D 1 90 JOB INFORMATION AND TESTING CONDITIONS Seawater 1.00 Chemical Concentrations 1.00CL31 1.00 4.000.00Cat 3 SP Breaker Chemical 1.00 60 65 70 75 80 85 90 95 100 0 100 200 300 400 500 600 0:00 1:12 2:24 3:36 4:48 6:00Viscosity, cP/Shear Rate, s-1Time, h:mm Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Shear Rate Viscosity Temperature Temperature Temperature Temperature Temperature Temperature X DLB CDW 04/14/2020 5957530 CDW DSR-4/9/2020 Colville DLB DLB 4/9/2020 272 sx 15.8 Class G VTL 5/27/20 THE STATE R FA' OAD 6011, WE I GOVERNOR MIKE DUNLEAVY Adam Klein Completion Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Oil Pool, CRU CD4 -499 Permit to Drill Number: 219-161 Sundry Number: 3 20-03 8 Dear Mr. Klein: Alaska Oil and Gas Conservati®n Commissi®n 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 r y rice Chair DATED this day of February, 2020. RBDMS ±4 FEB 18 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED JAN 2 202p AO CC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 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 0 Stratigraphic ❑ Service ❑ 219-161 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20810-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU -CD4 -499 Will planned perforations require a spacing exception? Yes ❑ No 9. Property Qesignation (Lease Number): 0 10. Field/Pool(s): ADL380077, ADL384211' ADL380082 ADL388903 Colville River Unit, Qannik 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): 12,865' 4050' 9371 4076 6500 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 120' 120' Surface 2367' 10-3/4" 2408' 2361' 5210 2470 Intermediate 5415' 7-5/8" 5456' 4072' 6890 4790 Production Liner 4,124 4-1/2" 9,371 4076 7,780 6,350 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none n/a 4.5" & 3.5" L80 5,259' Packers and SSSV Type: Halliburton TNT, No SSSV Packers and SSSV MD (ft) and TVD (ft): 5,134' 4,049' TVD 12. Attachments: Proposal Summary ❑ Wellbore schematic FZ] 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic L-1Development Service ❑ 14. Estimated Date for 2>>6 /20 15. Well Status after proposed work: Commencing Operations: _Vi 'i&ny OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: �, Z, 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: Compjetion Engineer Contact Email: adam.klem Conoco hllli S.com Contact Phone: 907-263-4529 Date: � ' � J Authorized Signature: r/` l`� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1io- V 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS !�-' FEB 18 2020 Post Initial Injection MIT Req'd? Yes ❑ No �f Exception Required? Yes No Subsequent Form Required: Spacing APPROVED BY Approved by: .'' J COMMISSIONER THE COMMISSION Date: p� t ti CPW �' ''202'0 VTL _-7//g/2 0 Submit Form and Form 10-403 Revis d 4/2017 Approved application is v4Ud fo%12 rrlogt sdate of approval. Attachmen s in Duplicate ''/ 53.8 alr��ao CD4 -499 — Qannik DHG 3'/Z"Premier Packer 2.75" XN Landing Nipple 16" 94# H-40 Welded Conductor to 120' 2.813" X Landing Nipple 131/2' Surface Hole 10-3/4" 45.5# L-80 TXP Surface Casing 2,408' MD 3'/2" 1" GLM 3'/2" 9.3# EUE Production Tubing 8-%" Intermediate Hole 3-1/2" 1" GLM ..... . ...... . .... 7" 26# L-80 Hyd563 Intermediate Casing 5,456" MD 4'/2" 12.6# L-80 Hyd563 Frac Sleeves + 5.5" OD Swell packers 9,371' MD ....... . ................................. 6-1/8" Production Hole 12,865' ""NS PROD Legal Wellname CD4 -499 COCIOCOPhillips +ell Attributes Set Depth (TVD) wBLea call Des Do (in) 10 (In) Top dhKB) Set Depth (RKB) (ftKS) 0bM) Grade Top Thread Wellbore Field Name AI;�SkeJlr.:. TRACT OPERATIOI F mmon WellnameCD4-499 , Max Anale & MD ITD Casing Strings AK All Wellbores Schem Set Depth (TVD) wBLea call Des Do (in) 10 (In) Top dhKB) Set Depth (RKB) (ftKS) 0bM) Grade Top Thread Wellbore Conductor 18 15.25 26.5 106.5 106.51 62.50 H40 NA CD4.499 HORIZONTAL, CD4 -499,2/12/2020 12:25:53 PM Surface 10 314 .95 -26 9 2,408.0 2,361.4 45.50 L-80 TXP BTC CD4 -499 Intermediate 7 6.28 26.9 5,456.0 4,071.7 26.00 L H563 CD4 -499 M p (ft K B - ._ Vertical schematic (actual) .-•n,,,,• •� •. �..n°r°,^-•=•"°+m= .............................................................. ^°'^••° ��"'-"•'^'�^°°_•_ "°"'"•^°"°_°° per.,, •_.+°. ,, ,. ,, r".." .,,�,,., _ .., ti,.,, ••«°",1 _„"_._ '"� ^°•m'"•'°•'°•'^^.,m.=�= "`° "°""'""°'•"•"""' "", Producllon 5, 47.5 9,371.3 ,078.4 .80 L- H-50- 49 Tubing Strings String Des Max Nominal Do (in) fl) (in) Top(ftKB) Set Depth (Me) Set Depth (TVD) (ftKB) Wtill M) I Grade I Top Thread I Wellbore Tubing - Production 1 31/2 1 2.991 5,258.8 4,080.1 1 9.30 L-80 EUE&d CD4 -099 Completion Details Top (TVD) Top Incl Nominal Top (RKB) (RKB) (°) Item Des Com 10 (In) Wellbore 24.7 24.7 0.00 Hanger FMC 11"X 4 112" Tubing Hanger, HYD 563 (BPV installed) CD4499 1,500.5 1,490.2 11.92 X Nipple Nipple Landing 3 1/2' X 2.813, SN:4284952 2.813 CD4 -099 5,133.8 ,049.3 83.76 Packer Baker Premier Packer, HYD563, 3-112"x 7', SN:1041977 1-01 2.870 CD4-099 5,193.7 85.04 XN Nipple NIPPLE, LANDING, 3-1/2X 2.813', XN, EUE and, .75' NOGO, 2.750 D4-09 SN:4292341 --TO-58.5 7.237.1 85.83 Locator Mechanical locator, w/ Pup joint. 3-1/2", 9.3#, L$0, EUE 8rd 2.980 CD4499 5,244.4 4,059.0 85.88 Shoe BakerwLEG Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftK B) Top Incl (°) Des Co. Run Data ID (In) I Wellbore 24.7 24.7 0.00 Kerrier -Back Pressure Valve TypeH 1119/2020 I 0.000 CD4 -499 Liner Details Top(TVD) Top(ftKB) (ftKB) Top Incl I') Item Des Com Nominal ID (in) Wellbore 7,247.5 4,059.3 85.90 Pecker Baker "HRD-E" ZXP Liner Top Packer 5.020 CD44 5, 7 .0 4,061.1 86.08 Hanger Baker"Flex-Lock Liner Hanger 3.880 CD4499 5,490.5 41073.3 87.64 Swell Packer Baker Swell Packer "F' 4 112", 12.6#, L80 3.880 CD4 -099 5,837.9 4,076.6 90.66 Frec Sleeve Baker frac sleeve #4, HYD563, .425' 10, Ban 3.840 CD4-499 Seated 2.445' 6,175.5 4,071.6 90.79 Swell Packer Baker Swell Packer *E" 4 1/2", 12.6#, L80 3.900 CD4 -499 6,563.8 4,073.5 8936 Frac Sleeve Baker frac sleeve #3, HYD563, 5" ID, Ball 3.840 CD4 -09 Seated 2.415' 6,906.0 4,0 1.0 8-8-5T Swell Packer Baker Swell Packer "D' 4 1/2', 12.6#, L80 3.910 CD4499 7,295.0 4,082.9 90.46 Frac Sleeve Baker frac sleeve #2, HYD563, 2.345' ID, Ball 3.890 C04499 Seated 2.375' 7.7977 4, .6 89.8 Swell Packer Baker Swell Packer' ' 4 /2", 1 . #, L ---3-970 TD -47T9 - D4 978 78.8 4,087.8 86.64 Swell Packer Baker Swell Packer 'B" 4 112", 12.6#, L80 3.940 CD4 -4-99- D4-0 98,329.0 8,329.04,100.0 91.22 Frac Sleeve Baker frac sleeve #1, HYD563, 2.305' ID, Ball 3.850 CD4 -099 Seated 2.335' 8,792.8 4,082.51 91.98 1 Swell Packer Baker Swell Packer "A' 4 112", 12.6#, L80 3.900 CD4499 Mandrel Inserts at No Top (TVD) Valve Latch Port TRO Run Top(ftKB) (nKB) I Make Model Do (in) Ser, Type Type Size (in) (psi) Run Data Com Wellbore 1 4,393.31 3,846.5 1 Carrico KBMG 1 GAS LIFT 1DMY BK 1118/2020 CD4 -499 2 3,427. 3,247.9 Camco KBM 1 GAS LIFT DMY BK 1/18/2020 CD4499 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 Request of ConocoPhillips Alaska, Inc. for Hydraulic fracturing for the CD4 -499 Well under the Provisions of 20 AAC 25.280 STATE OF ALASKA THIRD JUDICIAL DISTRICT 1 AFFIDAVIT OF Jason C. Parker Jason C. Parker, being first duly sworn, upon oath, deposes and states as follows: My name is Jason C. Parker. 1 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. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On January 20, 2020, CPA[ 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 201h day of January, 2020. Jaso rl� STATE OF ALASKA j §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 20t11 day of January, 2020, by Jason C. Parker. STATE OF &LASKA NO'CARY PUBLIC REBECCA SWENSEN i; o ary Public, State of Alaska �My Coinmisslon fxplrys AuAuiji, 27.0.2020. �.(4�id�,i�4�ri��t0I1 CX�f1�J.4ay r ConocoPhillips Alaska January 20, 2020 VIA CERTIFIED MAIL and/or HAND DELIVERY To: Operator and Owners (shown on Exhibit 2) Jason C. Parker Senior Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 office: 907-265-6297 Fax: 907-263-4966 jason. c. pa rker@cop.com Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD4 -499 Well ADL 380077, ADL 384209, ADL 384211, ADL 380082, and ADL 388903 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 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 CD4 -499 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 20, 2020. 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 ADL 380077 and ADL 384211, as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township_Ran a Section Meridian Surface 2877' 51' T11 N R4E 24 Umiat Top Open Interval 3974' 3205' T11 N __TJ1 R5E _R5 19 Umiat Bottomhole 4119' 56' N E 30 Umiat 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 ("Notification Area"), which includes the reservoir section. 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, ason C, P rke Senior Landman Attachments: Exhibits 1 & 2 Exhibit 1 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 -Operator): None Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attn: Teresa Imm, Executive VP, Regional and Resource Development State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Tom Stokes, Director Surface Owners: 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 r j ADL38OD75 ADL372097 _.,_Qannik PAj AOL37209 ADL380077 � -_ �`-�--�•�? --.may' � ADL384211 tae NU3�—' C?4.240PBs • b..1aF�61 L_,.ps9_ _ — ` �,. '+ (,y•-�''�Grl. TJ `, cA �4sJ,w\ ADL380082 Al ADL3800SI ADL384209i1 r ADL388903 ADL308902 \\\ AD 8905 ADL391687 • FrasPnrs '� Q Hell Virile rrae ports Buffer ADL391590 QHal Vile'Netf Track Suffer — — '�VCliS wltltln Teck Me, 41's{f Track d .M a.enhteral ADL380044 0. Cot1oCOPhillips _.. Qartnk PA U _ Alasl;u L — Unit 300daryCD4-499 CPkI _ease I 'F ' Lease Plat — 0 0.2 0.4 0.fi C.8 1 I U vemcliL.t a L390672 MiI_S Date: 1,1271'2020 1 Qannik to ADL380075 ADL380077 �a 0 �� C04 g3P -07 ICICD4-304 CD4 -304P61 1 f CD4 -322 -- —" n _CD4 -t6 CD4 -17 ' �4-05 / b cp4- 4-2138P B1 C04-2138 Cp � ry Cp4_2138PB2 a a N O . Gia CAp°� R � VO a� o Qp ry Q �g $ ADL; 1 \ GO 9 D oQ-- a— ry CO 4 St Q o � N � O V O\ a \ ADL388902 ADL388905 • Frac Ports Q Half Mile Frac Ports Buffer Q Half Mile Well Track Buffer Wells within Track Buffer Well Track Open Interval L.._..i Qannik PA - — - Unit Boundary CPAI Lease Oil Search Lease ADL372097 , ADL384211 CD4 -298 CD4-298PB1 CD4 -302 no d,� Cp4-301 CD4 -30 B 30114 1 n Ami � 00-s� a s� �Qv ADL380082 �9 6ggpy, t09 22 c�`v C.O�S'9S ADL388903 10811 IADL391587 i---------•—---•—•— ADL391590— -� i ADL380044 V . ConocoPhillips Lo L Alaska ZD �•--- CD4 -499 ' N Lease Plat 0 0.2 0.4 0.6 0.8 1A Miles Date: 1/27/2020 Table 1: Wells within .5 miles Well Name API Well Type I Status Field Name CD2 -77 501032062900 PROD ACTIVE ALPINE CD4 -03 501032064100 INJ ACTIVE ALPINE CD4 -12 501032041401 INJ ACTIVE ALPINE CD4-12PB1 501032041470 EXPEND PA ALPINE CD4 -208 501032051700 INJ PA NANUQ CD4 -208A 501032051701 PROD ACTIVE ALPINE CD4-208AL1 501032051760 PROD ACTIVE ALPINE CD4-208APB1 501032051771 EXPEND PA ALPINE CD4-208PB1 501032051770 EXPEND PA NANUQ CD4 -209 501032053200 INJ ACTIVE NANUQ CD4 -289 501032069700 INJ ACTIVE NANUQ CD4 -290 501032067400 PROD ACTIVE NANUQ CD4 -291 501032067200 INJ ACTIVE NANUQ CD4-291PB1 501032067270 EXPEND PA NANUQ CD4 -292 501032066900 PROD ACTIVE NANUQ CD4 -298 501032062300 PROD ACTIVE NANUQ CD4-298PB1 501032062370 EXPEND PA NANUQ CD4 -301 501032055700 PROD PA NANUQ KUPARUK CD4 -301A 501032055701 PROD PA NANUQ KUPARUK CD4 -3018 501032055702 PROD ACTIVE NANUQ KUPARUK CD4 -302 501032054500 INJ ACTIVE NANUQ KUPARUK CD4 -320 501032053100 PROD ACTIVE NANUQ KUPARUK CD4-320PB1 501032053170 EXPEND PA NANUQ KUPARUK CD4 -594 501032080700 INJ ACTIVE TRACT OPERATION TR1026 CD4-594PH1 501032080770 EXPEND PROP TRACT OPERATION TR1026 CD4 -595 501032077800 PROD ACTIVE TRACT OPERATION TR1024 CD4-595PH 501032077870 EXPEND PA TRACT OPERATION TR1024 CD4 -93 501032069000 PROD PA ALPINE CD4 -93A 501032069001 PROD ACTIVE ALPINE CD4 -96 501032067300 PROD PA ALPINE CD4 -96A 501032067301 PROD ACTIVE ALPINE CD4-96APB1 501032067370 EXPEND PA ALPINE NORTH ALASKA NANUK 1 501032023800 EXPLOR PA EXPLORATION NANUQ 5 501032041400 EXPLOR PA ALPINE 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 12/27/2019 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 1,000 psi and the floats were checked, and they held. The 7" casing cement report on 1/3/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G tail. Full returns were seen throughout the job. The plug bumped at 1,900 psi, and the floats were checked, and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone 1 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 12/29/2019 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 1/4/2020 the 7" casing was pressure tested to 3,500 psi for 30 mins. The 3.5" & 4.5" tubing will be pressure tested to 4,200 psi prior to frac'ing. The 7" casing will be pressure tested to 4,200 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,480 Annulus pressure during frac 3,800 Annulus PRV setpoint during frac 3,900 7" Annulus pressure test 4,200 3.5" & 4 1/2" Tubing pressure Test 4,200 Nitrogen PRV 7,980 Highest pump trip 7,480 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" 26.0 L-80 7,240 psi 5,410 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 eleod I Tattle Tele Tank Kauldwnd Pop -Off Tank Stimulation Surface Rig -Up W > m • 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 Pop-off Tank Pump Tiudc t I i j • ii Wll� 4 t ArfGsa At.4k'�E-AY, isx 'c� fila xSA S43ru � 't . i .0 IK . sirq t.iiH•:G is-r`+5. 1:.tl4'Y 111 e SL'. ptY ni ]1BtvU 6 �. ' r 30 t 1., .f ,. T it nU t IqC eppfla: d,V h'1E 4rat x f' - - C+C' 141n9 Ph W -REE 'o- [ZEE ..... ........ ?lWt A C 1tt,;Gf�lca y_� 7 nF(le .rn p. f .R ils t 4 HYfI h { "al re e r ,r r s Awa t� A n] J�TMf A fUlU 8f �-0 lFf� � .! ! l b . r..w.. I •Ys.�i { y 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 Qannik interval is approximately 110' TVD (12' net pay) thick at the heel of the lateral, based on offset well control (CD4 -208). The base of the Qannik interval was not encountered in the lateral. The Qannik reservoir is very fine grained, quartz and lithic rich, with a coarsening upward log profile. Top Qannik (K-2) at 5,271' MD/4,012' TVDSS. The estimated fracture gradient for the Qannik reservoir is 12.3-12.5 ppg. - The overlying confining zone consists of greater than 1500' TVD of Seabee (dominantly mudstones), beginning at base of C-30 (2,578' MD, 2,541' TVDSS). The estimated fracture gradient for this interval is 16-17 ppg. The underlying confining zone consists of approximately 150' TVD of Albian mudstones, based on nearby well control and was not penetrated in the CD4 -499 wellbore. The estimated fracture gradient for this interval is 16-17 ppg.., 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: CD2 -77: The two stage 7 5/8" casing cement report on 1/21/2011 indicates the first stage was pumped with 15.8ppg Class G cement. The plug did not bump. Waited on cement so casing could be pressured up to shear out the stage collar. The second stage cement operation was pumped with 15.8ppg Alpine cement. The plug bumped at 1,600psi. Partial returns were seen throughout the job. CD4 -03: The 7" casing cement report on 11/10/ 2011 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 @1,900psi. Pressure drill pipe to 3000psi. Had partial returns until switching to mud push. Remained static throughout job. CD4 -12: The two stage 7" casing cement report on 8/25/2010 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 1,200psi. Full returns were seen throughout the job. The second stage cement job was pumped with 15.8 ppg Class G cement, displaced with 11.0 ppg LSND. The plug bumped at 2,700 psi. CD4-12PB1: Was plugged and abandoned per state regulations on 8/14/2010 CD4-208PB1: Was plugged and abandoned per state regulations on 3/31/2011 CD4-208APB1: Was plugged and abandoned per state regulations on 5/30/2011 CD4 -208A & CD4-208AL1: The two stage T' casing cement pump report on 6/11/2011. Indicates that returns were not seen throughout the job. The cement job was pumped with 15.8 ppg tail cement and 15.8 ppg Class G tail cement, displaced with 11.0 ppg LSND mud. Did not bump plug. Pumped job with no returns. The second stage cement job was pumped with 15.8ppg Class G cement and displaced with 11.0ppg LSND mud. Bumped plug at 1,450psi. Full returns were seen throughout cement job. CD4 -209: The T' casing cement report on 6/2/2006 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement and displaced with 9.6ppg LSND mud. The plug was bumped at 1,OOOpsi, floats held, and full circulation was seen throughout the job. CD4 -289: The 7 5/8" casing cement report on 12/27/2014 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Qannik cement. Bumped plug at 660psi. Floats held. Full returns were seen throughout the cement job. The second stage cement job was pumped with 15.8ppg Qannik cement. Plug bumped at 630psi and floats held. CD4 -290: The 7 5/8" casing cement report on 1/4/2014 shows that the 1St stage cement job was pumped with 15.8ppg Class G cement. The plug did not bump, and floats did not hold. No losses were seen. The second stage cement job was pumped with 15.8ppg Alpine- Qannik blend. Displaced well with 209bbls of 10.2ppg mud. Bumped plug and full returns were seen throughout the job. CD4 -291: The 7' casing cement report on 9/4/2013 shows that the 2 -stage cement job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg cement. Plug bumped, floats held. The second stage cement job was pumped with 15.8ppg. Displaced well with 9.8ppg LSND mud, Bumped plug and returns were seen throughout job. CD4 -292: The 7' casing cement report on 8/6/2013 shows that the 2 -stage cement job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement. Displaced well with 245bbls of 9.8ppg LSND mud. Bumped plug @ 1000psi, floats held, and full returns were seen throughout job. The second stage cement job was pumped with 15.8ppg Class G cement. Displaced well with 161 bbls of 9.8ppg mud. Bumped plug, floats held and full returns were seen throughout job. CD4-298PB1: The two stage 7" casing cement report on 12/13/2010 was plugged and abandoned per state regulations. CD4 -298: The two stage 7" casing cement report on 11 /25/2010 The cement job shows that the job was pumped as design, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement and displaced with 10.Oppg LSND mud. The plug bumped at 1,100psi and the floats held. Full circulation was seen throughout the job. The second stage cement job was pumped as designed, indicating competent cementing operations. The second stage cement job was pumped with 15.8ppg tail cement with 10.Oppg LSND mud. Bumped plug at 2,200psi. Full circulation was seen throughout the job. CD4 -301: The 7" casing report on 12/20/2007 shows that this two-stage job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 238sxs of 15.9 Class G cement. The second stage cement job was pumped with 293 sxs of Class G cement. The well was displaced with 10.2ppg mud. ETOC was @9,817'. CD4 -301A: The 7" casing report on 12/30/2007 shows that this job was pumped as designed, indicating competent cementing operations. The job was pumped with 54bbls of 17ppg Class G cement. CD4 -301 B: The two stage 7" casing cement report on 1/8/2008 shows that this two-stage job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 88bbls of 11.0ppg Lead slurry and 22bbls of 15.8ppg tail slurry Class G cement. The second stage was pumped with 40bbls of 15.8ppg talk slurry class G cement. The plugs bumped @ 1500psi and the well was displaced with 315.4bbi of 10.7 CACL2. CD4 -302: The 7' casing report on 6/14/2007 indicated that after landing casing, the hole packed off and required SLB eline to pert casing 20' below baffle plate. 130 bbls of 11.0ppg of LiteCrete cement was pumped. The well was displaced with 79.5bbls of 9.6ppg mud. Casing was tested to 3500psi for 10 mins. Test was good. CD4 -320: The 7" casing cement report on 7/18/2006 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement and displaced with 10.5ppg mud. The plug was bumped at 1,670psi, floats held, and full circulation was seen throughout the job. CD4-320PB1: The three stage 7" casing cement report on 7/13/2006 was plugged and abandoned per state regulations. CD4 -594: The 7" casing report on 11/24/2019 shows that this job was pumped as designed, indicating competent cementing operations. The job was pumped with 81.2bbls of 13.5ppg Class G cement followed by 28.1 bbls of 15.8 class G tail cement. The well was displaced with 257bbis of 10.Oppg LSND. The plug bumped on strokes at 1,190psi and floats held. CD4-594PH: The two-stage pilot hole cementing job was completed on 11/11/2019. The cement job was pumped as planned. Full returns were seen throughout the job and TOC was verified by tagging top of abandonment string at 10,721'MD. CD4 -595: The 7" casing cement report on 1/26/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement and displaced with 279bbls of 9.5ppg brine w/corrosion inhibitor. The plug was bumped at 1,190psi, floats held, and full circulation was seen throughout the job. CD4-595PH: The 4 abandonment plug cementing report on 1/7/2019 through 1/9/2019 was abandoned per state regulations. CD4 -93: Was plugged and abandoned per state regulations on 2/16/2015. CD4 -93A: The 7" casing cement report on 9/26/2014 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 12.2ppg lead cement abd 15.8ppg tail cement. The plug did not bump. An additional bbl was pumped, plug bumped @ 1,100psi and floats held. CD4 -96A: The 7" casing cement report on 6/23/2014 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8 Qannik cement. Well was displaced with 11.0ppg LSND mud. Bumped plug and full returns were seen throughout the job. CD4 -96: Was plugged and abandoned per state regulations on 5/30/2014 CD4-96PB1: Was plugged and abandoned per state regulations on 7/24/2014 SECTION 11 - LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that 1 fault or fracture system transects the Qannik interval. This fault intersects the Qannik reservoir at 7713' MD (-4031' TVDSS) within the wellbore and potentially continues into the confining zone, terminating below the C-30, within one half mile radius of the wellbore trajectory for CD4 -499. Thickness and fracture pressure for the confining layer is discussed in Section 9. This fault or fracture system was interpreted from seismic data prior to drilling and was confirmed with log data while drilling. No losses were observed at the fault crossing while drilling. The fault is interpreted to be a single fault plane with -21' of throw. The effective fracture half-length is estimated to be 400' and swell packers will be placed around the fault for isolation. All of the fractures will be longitudinal, running parallel to the CD4 -499 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. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the observed fault will not interfere with containment. Well Depth Depth Vertical Loss Name MD (ft) TVDSS (ft) Displacement (bbls/hr) (ft) CD4 -499 7713' 4,031' 21' None v cr4— O Q O +1 C� C 4 - Ln -+N Q� 4 U C6 L LL Z m m N _ m C c 0 m 0 m o S m N uE Y c oEE m y E m vE ,�0 E '� n a n ^ n u 9 _ „ d a a °' m c o a w a d o H v o N a a m w A N D N b � w n o 7 u m a m um' l7 l7 °° U' o O (7 l7 m. l7 l7 g 0 l7o. m U d Z nE n n9 m wry �° aLD Yn nv a.y nN m n m e m N cN as nN av a� a9 ooE Nim n c m c c cm . m n" u vi v .�. ^' .�. m —" w m x E' E h V w u N a a '�` w u w x w u a w a m- v xN m v .+ v co ao « ' n a_ v n n Y e ot! N1 m m c c It c i Nb cri of v v a a y o3 v v u O u O v O O O VO r 0 c y0 o 0 0 _c ° w t r o c = uo n o o c K c I o o m. — w c — d — N d o v v v yu 0 0 76 u u u u u u u E n m\ m V O o� 0 r m m m ni n ni m N y m mml N m E NO N � N N ilf b O n 0 n N v v o+ v e v m o m cc O O o � r N O O O O O O O O O O r o O O m a o o v `o yp f m N v vi vi N v v n c H � � Bo n N a a a a a a V i m 3 V U V V V V V V U CC 4— O m L Q 0 4� E Ln v L v � co 0 L LL 0 m ro Y.a, m zo Y" z z z w o - -tp u 00u `E my'„ m umm m v m c iO my v N vi °° ,� .: .: Y" oR .�."� c vi E .. V E .. E .. �`o E a a Ynovi NOS N E.i n E N Z a H i vi N w N N v N a .. w a a a a " „ "' o u N N u u o a tD .n¢ a c < a a s a a v in — a — a" a e < a m `v N7 el o n .'n. v _ °° ob m a E E of N1 O uo tO m u ^ m o a m V O e u a a a v m dU @J o 0 o u O I o a 0 Y, 9 o 0 O o 0 0` 9 O - O 2 Q O O - - o N o h o 0 o 0 o a a v v v v m e m m m m m m c a o m 0 O v c e O v O v O v m N m vt v v v v o i a a ✓ J po 6 6 � p ��.// Q i ..l m V V V V V V U V V V 3 a, b y < o "° a of E a a;Ea �'a z ry am z c«m z z O N N w w ` w N J � E n w E o y L7 0 a a d m a c m e d n m m n "" W N 6 a w 1 N S O as c� m ,m -i O m c« Cw O W Y aaa A O V1 9 Y w~m ob n a N W m 00 m u N C am c C N C u � c W Yl O O O O w ¢ a a u 1O N O"w u cq w d~ O N O u a O O d a a V O C a e a a a E m u o m `° a—.. ^ uai c n n a o n e ^ �o m a w a � � m m m � o. °a o 0 o u p O O u O o_ T o o o 0 o 2 - o 0 w w a a6 w i to 0 u" u o u � v m � 3 ,o a a Z ry m a z a ^iD m o1. m o c w I o0 w z w w 0 0 = = = = o v e c c N c c N O o v 0 v 0 v 0 v �7 0 o 0 o o 0 o 0 0 S w w s w N bo a a a a a 7 > u u u u u u u u V V CU 0 fC 41 L a 0 E Ln a, 4 U f0 LL ¢ z ¢ z ¢ z u n w v m u 0 E d E a m E a i a a 0 u 0 u 0 v 0 0 v v 0 ao 0 O m Qa o u d a z d a z Plat 2: CD4 -499 Fault Analysis ADL380075 ADL380077 ti ADL384209 ADL3889D2 0 Fro. Pons F -I Ha1F hle7w Perls Buffer Hal Vile Sall Track Biffar FOU'. in Frac For. Suffer 'Aw, Track Own 1.1aroal wnm PA UnI 3DLnda-j CPAI -90SI? F7G. SuivuliLtdw IADL372097 ADL384211 U4 CD4 29flpal ADL380082 ADL3889D3 _!_ ADL391590 LiJ Z ADL380044 -0 Conocc;hfllijay CD4 -499 Fault Plat 0 0.2 0.4 0.6 0.8 1 mmmmmcz:�Miles F� Date: 1,127.2020 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD4 -499 was completed in 2020 as a single lateral horizontal producer in the Qannik formation. The well was completed with 3.5" tubing. In the Qannik is a 4.5" liner with ball actuated sliding sleeves. We will establish injection pump a mini frac and then shut down to monitor pressures. After a sufficient period, we will establish rate and pump the first stage and then drop a ball which will shift a sleeve open to establish the second frac stage. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Qannik 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. 4,839 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 @ 35bpm 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). 11&1.1.1.1 .I C) CP 1111111111 Y a wl O c 0 v iydraulic Fracturing Fluid Product Component Information Disr- Rndue Data 2929-01-20 Bbte: Alaska Handsaw Ba CoWdy: Apt NlarA 6010220810 NORTH SLOPE - opefolmNamc: EBUS COI 499 Well Name and Number; Lpngdude: 460.99 70.29 le8tude: Lprg/Lat Wolecu— NA -D27 nome IniumfFederat Production Type, D9 Trus VertrAl Depth(IVD)' 4,139 Total Water Vtteoe 201,770 Hydraulic Fracturing Fluid Composition: Chelni-I Maximum Abstract Maximum Ingredient IngredientIngredient Mess Comments Company First Name Last Name Email Phone Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in It's Number (CAS (7. by mase)•• HF Fluid (Y. by Mass)., 7732-18.5 96.008 11.793911 1650312 Density=8.520 Sea WaterBa BE -S Oeralor masharlon se Fluk Biocide NJate: Dated Below Listed Below 0 NA MICROBIOCIDE 0 NA CAT -3 Halfbunon Activator Lhld Below lasted Beim ACTIVATOR '.CL -72 UC Haabudon Cmsahker llsted Bele.lusted 5.1- p NA 'CL-31 Hal9burton Crasslmker Usld Below Listed Beim 0 NA CROSSUNKER 0 NA GBW-30 kHMourtem Break. Usled Below Listed Below BREAKER LOSURF-300D Halliburton Non-lomc Surfactant tlstd Below Listd Below 0 0 NA MA MO -57 tlabuden pH Control Addilive Wld Below used Below, 0 NA SP BREAKER Halliburton Breaker Dsted Below listed Below WC 36 GELLING Haggaa on Gang Agent luded BNgv Use! Bele. 0 NA AGENT LVT-200 Penreco Freeze Protect Usled Below Used Below 0 NA Wart 20(40 PropPrd IE Adtl9Ne Dsld Below "'Nd Below B NA Ingreolerd. Ustd Above Usld Above 1,2.4 Tf dh benmle 95-038 1. o0s WO. 0.orm— 001411 16 30 2-8romo-2-nitro-1,3 ipro anedkl 52-51-7 100.0 D.M. Tuck, H."""".3000 Denlse.Tuck® co\ 0.0033'1 2B N. Sam Houston HaBburtun Dwdae Tuck HwibVlon.eo 261-01-6716 Acryhl. poymar Proprialery 1. Pkwy E., Houston. TX 77032,281- 871 -MG D.nlae.T.1k@ 60.006 0.0790" 1678 Halliburton Denise Tuck 11a191burtonco 281-871-6226 Borate sails Proprietary Corundum 1302-745 65.00\ 11.393501 241719 Crystalline seise, quartz 1450MO-7 0.309 0.0110136 3 Ombe.Tuck� 0.100761 2138 Hasounon Dandee Tuck FWlburt= 2-1$71-8228 phenolic resin IImpfels, I 30.0081 0.020698 1'2Klhaned!Y�l��ha-(4- ....,.n�.�n 5.091 0.00356\ • Total Water Volume sources may inames nesn..,.r,......._._. '• Information is based on the maximum potential for concentration antl thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level 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 directed to the supplier who provided it The Occupational Safely and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary",'Prada secret", and "confdential business information" and the criteria for how this infprmation is re orted on an MSDS is sub'ece to 29 CFR 1910.1200 and endix D. 0 J aj _ .T vi .N L N :3 4- (n L L LL40 0 0 0 0 0 > 0o Q v to W 14a v O- 0 Q) Q Q O � i Ln i cB O OE Q) m Q E >- L L1. W 0 vii Ln T N Ln 0 u Ln N c O D E M +-1 u +Ln W 00 00 W DD 4-J N N N N N Q) Ln Ln Ln Ln Ln Q CL c: E N J Uji +�+ O O � L 0 4-1 a 0 O -0 z o 0Ln E Lna� E N to Ol I� t0 le 4-J Ol Ql �i Ql Ql Q tn fy-� m cy f`n ryi 0 N m Ql I- r-► m m Ql l0 4 m m N Lii 00 4- I— Ln Ln Ln Ln Ln in m m m m m r—i N m Lfl fC N _ .T vi .N N :3 4- (n L L ON v bA v 0o o v to v O- 0 Q) Q Q O � i Ln i cB O OE Q) m Q E >- cB W 0 vii Ln a� N Ln 0 u Ln N c O D E M +-1 u +Ln V) -0 v iJ — O +- V) N c: E N w Uji +�+ O � 0 4-1 0 O -0 z o 0Ln E Lna� E N O O E v tn 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.) Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles ter. Table 1: Wells within .5 miles Well Name API Well Type Status CD4 -03 501032064100 INJ ACTIVE CD4 -12 501 32041401 INJ ACTIVE CD4 -208 5010 2051700 INJ PA CD4 -208A 5010351701 PROD ACTIVE CD4-208AL1 5010320 1760 PROD ACTIVE CD4-208APB1 50103205 71 EXPEND PA CD4-208PB1 5010320517 0 EXPEND PA CD4 -209 50103205320 INJ ACTIVE 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. all CD4 -03: The 7" casing cement report on 11/10/ 2011 shows that the job was pumped as designed, indicating cb�mpetent cementing operations. The first stage cement job was pumped with 15.8ppg Class G tail. The plug bumped @1,9,00psi. Pressure drill pipe to 3000psi. Had partial returns until switching to mud push. Remained static throughout job. CD4 -12: The two stage 7" casing cement pump report on 8/25/2010 shows that the job was pumped as designed, indicaticompetent cementing operations. The first stage cement job was pumped with 15.8ppg Clas ;G tail. The plug bumped at 1,200psi. Full returns were seen throughout the job. The second stage cement job was purnp6d with 15.8 ppg Class G cement, displaced with 11.0 ppg LSND. The plug bumped at 2,700 psi. CD4-208PB1: Was plugged and abandoned '}�er state regulations on 3/31/2011 CD4-208APB1: Was plugge4-and abandoned p�rI state regulations on 5/30/2011 4, CD4 -208A & CD4-208ALt: The two stage 7" casinj cement pump report on 6/11/2011. Indicates that returns were not seen throughout the jo4,. The cement job was pumped with 15.8 ppg tail cement and 15.8 ppg Class G tail cement, "'displaced with 11.0 ppg LSND mud. Did not bump plug. Pumped job with no returns. The second stage cement job was pumped with 15.8ppg Cla�s G cement and displaced with 11.0ppg LSND/mud. Bumped plug at 1,450psi. Full returns we)rp seen throughout cement job. .\ CD4-209�lthe 7" casing cement report on 6/2/2006 shows that the j`6P was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G cement and displaced with 9.6ppg LSND mud. The plug was bu ed at 1,000psi, floats held, and full circulation was seen throughout the job. yU� 21�v YTS � > & � 0 \ « \ � E Ln ? _ ro U- CS `3 \ ®\ IeS 41 ±< «. EE& 211o/ 2-6 211x/»& w, { §!} §\{ )\} \ \\\ \\\ \\\ - - - ------ - \\(\\ �k \ ��\� �) \\� \\� \k k` o ew co \ - / E. ( 2 / - / 19 (» - � \ \ Is / f \ k\:lo, &s , Z \ 7 , \` - ® ` CS `3 \ ®\ IeS 41 ±< «. EE& 211o/ 2-6 211x/»& § / CS `3 \ ®\ IeS 41 ±< «. EE& 211o/ 2-6 211x/»& SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFININGONES 20 AAC 25.283(a)(11) CPAI has formed t e opinion, based on seismic, well, and other subsurface information currently available that 1 fault or fracture system transects the Qannik interval. This fault intersects the Qanni reservoir at 7713' MD (-4031' TVDSS) within the wellbore and potentially continues i to the confining zone, terminating below the C-30, within one half mile radius of the wellbore trajectory for CD4 -499. Thickness and fracture pressure for the confining layer is discussed in Section 9. This fault or fracture systern was interpreted from seismic data prior to drilling and was confirmed with log data while drilling. No losses were observed at the fault crossing while drilling. The fault is interpreted to,,be a single fault plane with —21' of throw. The effective fracture half-length is estimated td..,be 400' and swell packers will be placed around the fault for isolation. All of the fractures will,b`)ongitudinal, running parallel to the CD4 -499 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. ' CPAI has formed the opinion, based on s currently available that the observed fault ic, well and other subsurface information not interfere with containment. well Depth ` Depth Vertical t Displacement Loss }Mame MD (ft) TVDSS (ft) (ft) (bbls/hr) CD4 -499 7713' 4,031' 21' None 7-1- -2-116 1- Z/fp / ZD Plat 2: CD4 -499 Fault Analysis m ADL380076 I A1,777 ADL384209 0 Frac Forts F-1 I tat MlU I rav Pons Sullor X HAM MIP WPR Traci: .1 Fault in Fra, Part R, Wella within F, ft Buftff et 02 Well Tral* c 7 w ADL372007 LL . C) Uamii A Ant FId Uaso OF 0.2 0-4 0.6 0. Ul Svwli Lumr ADL384211 ADL380082 � 29 cork ��ilfips AWKa (;D4-499 Fault Plat Date: 1113,12020 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Wednesday, February 12, 2020 11:00 AM To: Klem, Adam Subject: CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry WBS Adam, Do you have a schematic with depths for the premier packer, liner hanger? Victoria From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, February 12, 2020 7:04 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: RE: [EXTERNAL]CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Victoria, My apologies. The TOC numbers given on the AOR sheet for the below wells are for the 7" casing that penetrates the producing interval for that well. Therefore, the TOC is below the Qannik since they are a 4 string design. The 7" liner that penetrates the production zone is cemented up into the intermediate 9 5/8" wellbore. The Qannik is behind the 9 5/8" casing. Below are the TOC numbers for the 9 5/8" casing strings. CD4 -93A: 5900' MD, 3840'TVDSS CD4 -96A: 6307' MD, 3886' TVDSS For these following wells, we did not encounter any Qannik sands. Therefore I cannot provide tops for the Qannik sands here. However, here are the TOC for these, which is well above any Qannik tops encountered across the field. CD4 -594: 11,940' MD, 3547' TVDSS CD4 -595: 12,300'M D, 3626' TVDSS For the following wells, the cement does not cover the Qannik. However, if you see the attached map that shows the following wells' intersection with the top of the Qannik, you will see that the wells intersect the Qannik outside the mile radius. Additionally, none of the wells are in the direction of fracture propagation, as the fractures will propagate longitudinally along the length of the wellbore. Therefore the well will not interfere with the containment of the hydraulic fracturing fluid. CD4 -209 CD4 -301B CD4 -320 Feel free to contact me with any additional questions, Adam Klem Loepp, Victoria T (CED) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, February 12, 2020 7:04 AM To: Loepp, Victoria T (CED) Cc: Boyer, David L (CED); Schwartz, Guy L (CED) Subject: RE: [EXTERNAL]CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Attachments: CD4 -499 Offset wells Qannik intersection.PNG Follow Up Flag: Follow up Flag Status: Flagged Victoria, My apologies. The TOC numbers given on the AOR sheet for the below wells are for the 7" casing that penetrates the producing interval for that well. Therefore, the TOC is below the Qannik since they are a 4 string design. The 7" liner that penetrates the production zone is cemented up into the intermediate 9 5/8" wellbore. The Qannik is behind the 9 5/8" casing. Below are the TOC numbers for the 9 5/8" casing strings. CD4 -93A: 5900' MD, 3840'TVDSS CD4 -96A: 6307' MD, 3886' TVDSS For these following wells, we did not encounter any Qannik sands. Therefore I cannot provide tops for the Qannik sands here. However, here are the TOC for these, which is well above any Qannik tops encountered across the field. CD4 -594: 11,940' MD, 3547' TVDSS CD4 -595: 12,300'M D, 3626' TVDSS For the following wells, the cement does not cover the Qannik. However, if you see the attached map that shows the following wells' intersection with the top of the Qannik, you will see that the wells intersect the Qannik outside the mile radius. Additionally, none of the wells are in the direction of fracture propagation, as the fractures will propagate longitudinally along the length of the wellbore. Therefore the well will not interfere with the containment of the hydraulic fracturing fluid. CD4 -209 CD4 -301B CD4 -320 Feel free to contact me with any additional questions, Adam Klem From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 11, 2020 3:02 PM To: Klem, Adam <Adam.Klem @conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Adam, Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, February 11, 2020 3:02 PM To: Klem, Adam (Adam.Klem@conocophillips.com) Cc: Boyer, David L (CED); Schwartz, Guy L (CED) Subject: CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Attachments: CD5-96 Frac Stim AOR Spreadsheet updated version.xlsx; CD5-96 Sundry.doc; CD4_499 _CORRECTED_as_drilled_frac_fault_plat_20200127.png; CD4_499 _CORRECTED_as_drilled_frac_lease_plat_20200127.png Adam, Thank you for the updated AOR information. After reviewing the additional wells, there are seven wells in the AOR that need closer scrutiny. They include: CD4 -209 CD4 -301B CD4 -320 CD4 -594 CD4 -595 CD4 -93A CD4 -96A These wells appear to have the Qannik present and no cement across the Qannik. Please address how the fracture stimulation of the Qannik in CD4 -499 will effect each of these wells. 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. Loeppaalaska.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. Loepp4alaska.gov From: Klem, Adam <Adam.Klem @conocophillips.com> Sent: Monday, February 10, 2020 12:51 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Boyer, David L (CED) <david. boyer2@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Attached are all the updated documents Thank you for the updated AOR informa Lion. After reviewing the additional wells, ti. -.e are seven wells in the AOR that need closer scrutiny. They include: CD4 -209 CD4 -301B CD4 -320 CD4 -594 CD4 -595 CD4 -93A CD4 -96A These wells appear to have the Qannik present and no cement across the Qannik. Please address how the fracture stimulation of the Qannik in CD4 -499 will effect each of these wells. 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(cDalaska.go 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: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, February 10, 2020 12:51 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Attached are all the updated documents From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, February 7, 2020 2:16 PM To: Klem, Adam <Adam.Klem @conocophillips.com> Cc: Schwartz, Guy L (CED) <Ruy.schwartz@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, I will be out of the office next week, so please send the revised Area of Review map and mechanical condition information to Guy Schwartz, David Boyer (AOGCC's other geologist), with a cc to me. That will keep the application moving through AOGCC's review process. Thank you for your help, Steve Davies AOGCC JS PROD Legal Weliname CD4 -499 '" imon WellnameCD4-499 Lonocornnnps Field Na 1UULUS max Hngle 3 MU IU HeM Name Wellbore APINWI Wellbore Stelus Incl(') MD(M(e) Act Btm (RNB) Alaska. Ific TRACT OPERATION TR1027 501032081000 PROD 95.40 11,750.92 72,865.0 Camrrn! HIS (ppm) I Data Annetatlon I End Data K134rd (To RII Release Date 28.00 1/19/2020 Casing Strings AK All Wellbores Schem Set Depth (TVD) WVLen Csn Des OD (in) ID (In) Top in B) Set Depth (ttKB) (R(B) (IbIR) Grade Top Thread Wellbore Conductor 16 15.25 26.5 106.5 106.5 62.50 H40 NA CD4 -499 HORIZONTAL, CD4 -499, 2/12/2020 12:25:53 PM Surface 103141 .95 26.9 2,408.0 2,361.4 5. L-10 TXP BTC CD4499 Intermediate 6.28 26.9 5,456.0 4,071.7 .00 L-80 H56 CD4499 M D (H K B Vertical schematic (actual) Production 5, 7,5 9,371.3 4,076.4 72.60 L-8 H5 3 499 Tubing Strings String Des Maz Nominal OD (in) ID (in) Top (hK8) Set Depm (ftKB) Set Depth (TVD) (ttKB) Wt(lbtft) I Grade I Top Thread Wellbore - _ ........... =". ro.,,"„°= r•=•�="• w^--"�_•_°°•"°°°°°°_ °^°�°•"'°°�•"°°°° 'w^^°°"°'"°°°"°°^_�°°•_ ".,,°•�°�°',�� Tubing - Production 31121 2.99 24.7 5,258.8 4,060.11 9.30 1 L-80 I EUE Srd CD4499 Completion Details Top (TVD) Top Incl Nominal Top (RKB) (ttKB) (°) Item Des Com ID (In) Wellbore 24.7 24.7 0.00 Hanger FMC ll"X 4 112" Tubing Hanger, HYD 563 (BPV installed) CD4 -499 1,500.5 1,490.2 11.92 X Nipple Nipple Landing 3 112" X 2.813, SN:4284952 2.813 CD4499-"°%-',°:.:,:;Tlo„"„�T 5,133.8 4,049.3 83.76 Packer Baker Premier Pecker, HYD563, 3-112"x 7', SIM: 104197711-01 2.870 CD4499 57T7 ,05 .1 SW TN Nipple NIPPLE, LANDIN , 3-112" X 1 ', XN, EUE rd, .75" N GO, 2.750 704-499 SNA292341 5,237.1 4,058.5 85.83 Locator Mechanical locator, w/ Pup joint, 3-112', 9.3x, L-80, EUE Brd 2.980 CD4499 5,244.4 4,059.0 I 85.88 I Shoe Baker WLEG 3.000 CD4 -499 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (10(s) Top (TVD) (RKB) Tap Incl (°) Des Co. Run Data ID (In) Wellbore 24.7 24.7 0.00 Barrier - Back Pressure Valve I Type 1/19/2020 I 0.000 CD 99 Liner Details Top(TVD) Top IRKS) (RKB) Top Incl (°) Item Des corn Nominal ID (in) Wellbore 5,247.5 4,059.3 85.90 Packer Bake,'HRD-E' ZXP Liner Top Packer 5.020 CD4499 5,274.0 4,061.1 86.08 Hanger Baker"Flex-Lock liner Hanger 3.880 C04499 5,490.5 4,073.3 87.64 Swell Packer Baker Swell Pecker "F' 4 1/2", 12.6x, L80 3.880 CD4499 5, 37.9 4,076.6 90.66 Frac Sleeve Baker frac sleeve x4, HYD5 3, 2.425' ID, Bell 3.840 CD4499 Seated 2.445' 6,175.5 4,071.6 90.79 Swell Packer Baker Swell Packer *E" 4 112', 12.6x, L80 3.900 CD4499 6,563.8 4, 73.5 89.36 Frac Sleeve Baker frac sleeve #3, HYD 5' ID, Ball 3.870 D4499 Seated 2.415° 6,908.0 4,081.0 88.51 Swell Packer Baker Swell Packer'D" 4 1/2', 12.60, L80 3.910 CD4499 7,295.0 ,082.9 90.46 Frac Sleeve Baker frac sleeve x2, HYD563. 2.345' ID, Ball 3.890 CD4499 Seated 2.375" --776T 7,575-7- 89.86 Swell Packer Baker Swell Packer' "411 , 1 . x,L 0 3.920CD4-499 7,898.8 4,087.8 86.64 Swell Packer Baker Swell Packer 'B" 4 1/2•, 12.6x, L80 3.940 7D4499 8,329.0 4,100.0 91.22 Frec SleeveBaker frac sleeve xl, HYD563, 2.305" ID, Bell 3.850 CD4499 Seated 2.335" I 8,792. -4,072-6 91.98 ibwen Packer I Baker Swell Packer "A' 4 112•, 12.60f, L80 3.900 CD4499 Mandrel Inserts at Nu Top(TVD) Valve Latah Port TRO Run Top (111K.)(RKB) Make Model OD (In) Ser , Type Type Slze (in) (psi) Run Data Com Wellbore 1 4,393.3 3,846.5 Camco KBMG 1 GAS LIFT DMY BK 1/18/2020 cD4499- 2 3,427.8 3,247.9 Camco KBMG 1 GAS LIFT DMY BK 1118/2020 C 99 i ADL 380075 in ik PW ADL380077 0 --,3c poft --- — V061 7px a Opt- I pter, :I — -am M e :t3c P an S A& -�34 M e We -,x o SAe- �;)A : IX 001 94f -E-- Too a 3r* i. 3P *,I e^l *., b. s A CrAl L&Ye : See zm:�, Lc*e AD L372097 ADL384211 4 UZ, N. AD LaSS903 ADL391590 ADL38OD44 'A 0 02 04 oe,4 ()a I res AD L380082 072091 i a DL380061 AD LaSS903 ADL391590 ADL38OD44 'A 0 02 04 oe,4 ()a I res AD L380082 072091 i a VPI ConocoPhillips CD4 -499 Fault Plat Cate d"Z 11 2020 DL380061 ADL3915871 VPI ConocoPhillips CD4 -499 Fault Plat Cate d"Z 11 2020 Loepp, Victoria T (CED) From: Boyer, David L (CED) Sent: Tuesday, February 11, 2020 5:14 PM To: Loepp, Victoria T (CED) Cc: Davies, Stephen F (CED) Subject: RE: CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Follow Up Flag: Follow up Flag Status: Flagged Victoria, Very good question. I am anxious to see the response. Could be a show stopper. Dave B From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 11, 2020 3:02 PM To: Klem, Adam (Adam.Klem@conocophillips.com) <Adam.Klem@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: CRU CD4 -499 (PTD 219-161; Sundry 320-038) Frac Sundry AOR Adam, Thank you for the updated AOR information. After reviewing the additional wells, there are seven wells in the AOR that need closer scrutiny. They include: CD4 -209 CD4 -301B CD4 -320 CD4 -594 CD4 -595 CD4 -93A CD4 -96A These wells appear to have the Qannik present and no cement across the Qannik. Please address how the fracture stimulation of the Qannik in CD4 -499 will effect each of these wells. 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 Loepp, Victoria T (CED) From: Boyer, David L (CED) Sent: Tuesday, February 11, 2020 8:11 AM To: Loepp, Victoria T (CED) Cc: Schwartz, Guy L (CED) Subject: FW: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Attachments: CD5-96 Frac Stim AOR Spreadsheet updated version.xlsx; CD5-96 Sundry.doc; CD4_499 _CORRECTED_as_drilled_frac_fault_plat_20200127.png; CD4_499 _CORRECTED_as_drilled_frac_lease_plat_20200127.png Hi Victoria, After you are finished with this frac sundry, I need to update it with the enclosed corrected documents that Steve requested from CoP. There were many wells missing from the AOI. Steve is on vacation until next Tuesday, and this frac has a short fuse, if I recall. Thanks, Dave B. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, February 10, 2020 12:51 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Attached are all the updated documents From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, February 7, 2020 2:16 PM To: Klem, Adam <Adam.Klem @conocophillips.com> Cc: Schwartz, Guy L (CED) <Ruy.schwartz@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, I will be out of the office next week, so please send the revised Area of Review map and mechanical condition information to Guy Schwartz, David Boyer (AOGCC's other geologist), with a cc to me. That will keep the application moving through AOGCC's review process. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Friday, February 7, 2020 11:47 AM To: Klem, Adam <Adam.Klem @conocophill ips.com> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, Apologies, you are correct. I last checked our digital well log archive on Jan 27th; the curve files were stored on Jan 3151. My mistake. Thank you for the update on commencing operations. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Klem, Adam <Adam.Klem @conocophillips.com> Sent: Friday, February 7, 2020 11:17 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: Re: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Steve, Did SLB not provide all the logs as they normally do for their end of well report? I should have all the AOR stuff back to you shortly, some of the older wells are hard to find much data on. With the cold weather we are significantly delayed do not have an update on anticipated frac date but we are probably looking more like 2/20/20 if I had to guess. And that's assuming weather warms up soon. Adam From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, February 7, 2020 10:52:30 AM To: Klem, Adam <Adam.Klem @conocophillips.com> Subject: FW: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, In addition to the AOR information requested below, could CPAI also provide a copy of the field digital well log data for CRU CD4 -499 in .las or ASCII tab -delimited text format? I can work on this today, but I will be out of the office beginning on Monday, so could you email the files to me and David Boyer, AOGCC's other geologist? When does CPAI plan to conduct these operations? Your last estimate was next Monday, Feb 101H Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Tuesday, February 4, 2020 2:50 PM To: Klem, Adam <Adam.Klem @conocophillips.com> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, Just a reminder as I would like to move this application along through the AOGCC's review process since the estimated date for commencing operations is Feb 10tH Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, January 29, 2020 9:22 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Steve, Apologies for not responding sooner. I have been trying to figure out what exactly happened on why there wells weren't identified in our offset well list. It turns out there was an issue with the layers on the map used to grab the list. We have fixed the issue, and are now working to get all the data required for these offset wells. I hope to have it to you in the next day or so. Due to very cold weather on the slope, operations have mostly shut down, so the 4th is not a realistic date anymore. It is looking more like the 10th or so. Thanks, Adam From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, January 29, 2020 9:05 AM To: Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, I want to ensure that you received my email, below. I'd like to move this application along through the AOGCC's review process since the estimated date for commencing operations is Feb 4tH Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the r,.dska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Monday, January 27, 2020 4:49 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, In addition the wells and plugged -back wellbores included in CPAI's list of wells that may transect the confining zone, do any of the following wells also transect that confining zone? If so, please update the Mechanical Condition evaluation list provided in Section 10 of CPAI's application to hydraulically fracture CRU CD4 -499. If not, please let me know. Also, if there are any plugged -back wellbores for any of the following wells that also transect the confining zone, please include them in the updated evaluation list. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. T Well Permit API Number Operator Well Name Number 1960570 50103202380000 ARCO NANUK 1 2020420 50103204140000 Conoco Phillips Alaska, Inc. NANUQ 5 2141880 50103206970000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -289 2131300 50103206740000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -290 2131100 50103206720000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -291 2130350 50103206690000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -292 2101300 50103206230000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -298 2071500 50103205570000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -301 2071740 50103205570100 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -301A 2071800 50103205570200 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -301B 2070560 50103205450000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -302 2191610 50103208100000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -499 Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Friday, February 7, 2020 11:47 AM To: Klem, Adam Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, Apologies, you are correct. I last checked our digital well log archive on Jan 27th; the curve files were stored on Jan 31St. My mistake. Thank you for the update on commencing operations. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Friday, February 7, 2020 11:17 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: Re: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Steve, Did SLB not provide all the logs as they normally do for their end of well report? I should have all the AOR stuff back to you shortly, some of the older wells are hard to find much data on. With the cold weather we are significantly delayed. I do not have an update on anticipated frac date but we are probably looking more like 2/20/20 if I had to guess. And that's assuming weather warms up soon. Adam From: Davies, Stephen F (CED) <steve.davies@alaska.ROv> Sent: Friday, February 7, 2020 10:52:30 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: FW: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, In addition to the AOR information requested below, could CPAI also provide a copy of the field digital well log data for CRU CD4 -499 in .las or ASCII tab -delimited text format? I can work on this today, but I will be out of the office beginning on Monday, so could you email the files to me and David Boyer, AOGCC's other geologist? When does CPAI plan to conduct these operations? Your last estimate was next Monday, Feb 10tH Thank you for your help, Steve Davies AOGCC Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Tuesday, February 4, 2020 2:50 PM To: Klem, Adam Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, Just a reminder as I would like to move this application along through the AOGCC's review process since the estimated date for commencing operations is Feb 10th Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, January 29, 2020 9:22 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Steve, Apologies for not responding sooner. I have been trying to figure out what exactly happened on why there wells weren't identified in our offset well list. It turns out there was an issue with the layers on the map used to grab the list. We have fixed the issue, and are now working to get all the data required for these offset wells. I hope to have it to you in the next day or so. Due to very cold weather on the slope, operations have mostly shut down, so the 4th is not a realistic date anymore. It is looking more like the 10th or so. Thanks, Adam From: Davies, Stephen F (CED) <steve.davies@alaska.Rov> Sent: Wednesday, January 29, 2020 9:05 AM To: Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]FW: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Hi Adam, I want to ensure that you received my email, below. I'd like to move this application along through the AOGCC's review process since the estimated date for commencing operations is Feb 41n Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Monday, January 27, 2020 4:49 PM To: Klem, Adam <Adam.Klern@conocophillips.com> Subject: CRU CD4 -499 (PTD 219-161; Sundry 320-038) - Question Adam, In addition the wells and plugged -back wellbores included in CPAI's list of wells that may transect the confining zone, do any of the following wells also transect that confining zone? If so, please update the Mechanical Condition evaluation list provided in Section 10 of CPAI's application to hydraulically fracture CRU CD4 -499. If not, please let me know. Also, if there are any plugged -back wellbores for any of the following wells that also transect the confining zone, please include them in the updated evaluation list. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Well Permit API Number T Operator Well Name Number 1960570 50103202380000 ARCO NANUK 1 2020420 50103204140000 Conoco Phillips Alaska, Inc. NANUQ 5 2141880 50103206970000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -289 2131300 50103206740000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -290 2131100 50103206720000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -291 2130350 50103206690000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -292 2101300 50103206230000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -298 2071500 50103205570000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -301 2071740 50103205570100 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -301A 2071800 50103205570200 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -3016 2070560 50103205450000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -302 2191610 50103208100000 Conoco Phillips Alaska, Inc. COLVILLE RIV UNIT CD4 -499 Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 21 9 16 1 32 025 s ConocoPhillip TRANSMITTAL FROM: Sandra D. Lemke, ATO -704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: CD4 -499 Permit: 219-161 DATE: 02-07-2020 orth Slope, Colville River Unit, Alaska is email Final Mud log images in .PDF CD4 -499 2MD DEL Final CD4 -499_2M D_FEL_Fi n a I CD4 -499 2TVD FEL FinaL CD4 -499 SMD FEL Final CD4 -499 5TVD_FEL_Final CD4 -499 -Show Logs_Final TO: Meredith Guhl AOGCC 333 W. 71h Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: RECEIVED FEB 0 7 2020 A®GCC Transmittal instructions: please promptly sign, scan, and e-mail to Sandra. D. Lemke(a)conocgg17A1i25.com CC: CD4 -499- e -transmittal well folder f0 Receipt: Date: I Alaska/IT-GGRE I Conctc Phillips Alaska I Office: 907.265.6947; Mobile 907 440 4512 Schlumberger Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: Well Name: CD4 -499 Date Dispatched Service Order #: 19AKAO119 Dispatched By: 219161 32004 Transmittal #: 30JAN20-SP01 AOGCC: Natural Resource Tech Abby Bell 30 -Jan -20 Stephanie Pacillo Product Description Hardcopy Di ital Copy Logging Date LWD Recorded Mode Prints: N/A Contents on CD 15 -Jan -20 VISION Service 2" MD / TVD x 5" MD / TVD x R JAN 3 1 luzo w()GCC. Digital Data N/A Contents on CD DLIS / LAS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x CD 1 CD Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: 1 om.Osterkamp(cDconocophillips.com Alaska PTSPrintCenter(@slb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By. • v i r — / ! — l 15. 0 o� o� �o e CU kc FD Q n n n 0 0 O D 0 e-+ FD (p ((D Q a- O Ln O O O —+, - -+, � � O (D O_ O O _0 O = O N 3 O (rD CD r O =Y' m < � N fD e-+ r-+ rD e --F Q Ln 2 -h 0 O _0 e-+ m N C � (D ED O C7 O O N ::p O E7;' c O (D N D Q C CL O c n • m 3ul (o rt r+ fD (D Nr I� v Q- N O � \ Q V • Q, O W _') • �G o 00 _ (D M O O < > 3 3 o a 00 cn N O =3 • O (D -p (D cn N 1. =3 (D r+ � Lrl O Q �(D rD o o CD p O N(D _ (Do 0- � O —3N r1i N —I N (D (.D r° (10 rO r+ = (D O Q 3 r"+ Q N W O 1 ,1 I Y� 1 1 III 1 z�I 1\1 3:A I I III i C, O 5 g e ............. m -n z e � a a a .r f 'i� 1 I 1 I' 1 �',•a�' n _r 1 1 1 1 n. I �y�.c'i;P�ar�'1/r' t - _ _ V • �. �.r L+..,(I I 1 . i _ I , _;rte __ 111 1 an � '..F• 1 1 1 1 11 1 I v a ` V M 1 111 1 I I 1 1 I 1 I11 1 p �• c c O n o u 1 1 1 f 1 1 III 1 /11 nt e 1 1 1. 111. 111 o t m � V T a W J 1 1 1 I 1 I 111 M 1 V 1 1 1 1 I 1 111 I ^ CL (D• 1 1 1 I I 1 I11 I ? 1 � I � i 1 5 I S 1 ��11 I i 1 4 �„ �..�• ° O 66, d p o i � �,. f 1 !11 I � � �• M••s°rtaf Depth fill O �r 6 8 8 TVDSS 8 8 Q w b T 8 ° - ?Ee r V`S/1 ii s "VCD s "' n y � L (� O 8 � a _ CLC Y f CD e �s rD^ tN & r1+ a fD n CL / O H u N V�. J 1•'r O ca rt dd•�ir-! l O 8 0 N rh 3 Q Q rpt N to e --1- O rD (n rF O a m 00 O 0 rD 0 O L! Lrl O n II (D UNi (p O �--' \ O O O �. II � N Ln N N Q rr r~ (D 3 Q rr n O rD •w L� m e-+ r+ Ln C O \ p (D v _ N =3 r --h r•+ =3 O O M D OL) ■ IM 2 00O n O n 0 c: Ln a r+ Q (D O (D II —_ N E5 up O O r-+ n Ul (D O :3 70 � II Ln 0 N � O (� S� C7 V) rD rD CL r~ (D 3 r+ Ln 5* aq Vertical Category O F-� N W A ui 01 r) (D OG O N m 0 0 (ND =r =r �. !D (D (D � � N ■ ■ N N (D (D M M. (D (D (A N N I -A m ■ ■ O = � W Q N Q N = rt rD A A p A cn Q (D (D 7 t~D lD A O W V N V1 In \ N LD LD\ (D 1 T 0 Un N Z3 U7 O Q O N 7: Ln (D N Q. to Ln N U2 W DJ (D fD C Q FT-D ;,t4 —!(a Loepp, Victoria T (CED) From: Schwartz, Guy L (CED) Sent: Friday, January 17, 2020 10:10 AM To: Loepp, Victoria T (CED) Subject: RE: CD4 -499 TOC Follow Up Flag: Follow up Flag Status: Flagged Looks very good Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, January 17, 2020 8:37 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Fwd: C134-499 TOC Sent from my Whone Begin forwarded message: From: "Smith, Matt" <Matt.Smith2@conocophillips.com> Date: January 17, 2020 at 6:44:26 AM AKST To: "Loepp, Victoria T (CED)" <victoria.ioepp@alaska.gov> Cc: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com> Subject: CD4 -499 TOC C) 0 U) D mt- 7 rM n 0 D COMPANY: WELL: FIELD: STATE: COUNTRY: ConocoPhillips Alaska LLC. CD4499 Colville River Unit Alaska USA Location xT zma �_ n C O C D C) C) C) C N to > sv (nCD 0 o 0 ;a �� z- 0 CDri (00 p CDC cn C7 FOLD HERE: The well name, location and borehole reference data were furnished by the customer. 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 sery ices "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: 1/15/2020 Location: I Techlog 2019 e-mail:jburt2@slb.com Top of Cement is identified on the logs at 3451' MD based on the decrease in sonic amplitude. 4� Mull r bp►II 111x1 on MI1H IN IN ion on IOU 111N mu i11N INN Pf I- t ( ' € 1N�N1 MR IHHNN IM .�,�Hn. ■moi' INN Mil HHI INN INN IMI MR 4 I ' , .. INN INTI HHI MR MR 11TH INNi DIN INH I� 11l INH IIIH 0 IN MR INH ,' Company: ConocoPhillips Alaska, Inc. Well: C134-499 Field: Coleville River Unit State: Alaska Country: USA Schlumhepgep SonicScope Top of Cement PrD ae9 —/&> Loepp, Victoria T (CED) From: Smith, Matt<Matt.Smith2@conocophillips.com> Sent: Monday, January 13, 2020 2:05 PM To: Hobbs, Greg S; Loepp, Victoria T (CED) Cc: Regg, James B (CED); Schwartz, Guy L (CED); Rixse, Melvin G (CED); DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNAL]Doyon 141 - CD4 -499 BOP Test Extension Request -Approval TOOH Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria. We'll keep everyone in the loop as we progress. Thanks again! Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA. ATO -1 704 OFFICE: +1.907.263.4324 CELL: +1.432.269.6432 MATT.SM ITH2% COP.COM From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, January 13, 2020 2:04 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Smith, Matt<Matt.Smith2@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov> Subject: RE: [EXTERNAL]Doyon 141- CD4 -499 BOP Test Extension Request -Approval TOOH Thank -you! From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, January 13, 2020 1:59 PM To: Smith, Matt <Matt.Smith2@conocophillips.corr,>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov> Subject: [EXTERNAL]Doyon 141- CD4 -499 BOP Test Extension Request -Approval TOOH Matt, Thanx for the review slide pack outlining the unexpected slow pulling speed for TOOH after reaching TD. Approval is granted for a BOP test extension until TOOH. Please keep the AOGCC inspectors apprised of the status. 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)a laska.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. Loepp4aiaska.gov From: Smith, Matt<Matt.Smith2@conocophillips.com> Sent: Monday, January 13, 2020 1:29 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]Doyon 141- CD4 -499 BOP Test Extension Request Please find attached. Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA. ATO -1704 OFFICE: +1.907.263.4324 CELL: +l .432.269.6432 MAT1.SMITH2(Ci',COP.COM From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, January 13, 2020 8:21 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Smith, Matt <Matt.Smith2@conocophillips.com>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Regg, James B (CED) <lim.regg@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <r-ne.ElvinAxse�alaskav> Subject: RE: [EXTERNAL]Doyon 141- CD4 -499 BOP Test Extension Request Good Morning Victoria, I reviewed the operations with Matt this morning. Torque and drag indicators while drilling did not indicate the potential for issues that we are currently seeing in this trip. Timing from past Qannik well projects was used for projection and operation planning. All indicators prior to this trip were that the plan was sufficient to test the BOP well before the deadline. The current hole condition was not foreseen. Matt is gathering more data for discussion, and to your point below, 1 will reiterate that we plan our tests to prevent violation of the regulations, as this one was prior to the current issues. We will take this information forward on offset wells in this area. Thank -you! G reg Greg Hobbs, P.E. Compliance and Regulatory Engineer Drilling and Wells W:(907)263-4749 C:(907)231-0515 From: Loepp, Victoria T (CED) <victoria.loepp(@alaska.gov> Sent: Sunday, January 12, 2020 9:21 AM To: Smith, Matt <Matt.Smith2 conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs conocophillips.com>; DOA AOGCC Prudhoe Bay <doa aogcc prudhoe.bay@alaska.gov> Cc: Regg, lames B (CED) <Jm.regg alaska.gov>; Schwartz, Guy L (CED) <guy.schwa rtz alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: [EXTERNAL]Doyon 141- CD4 -499 BOP Test Extension Request Matt, Greg, The BOP test extension is approved for 24 hours. I would like to discuss with you why the BOPS were not tested at the last opportunity. The AOGCC will not be approving BOP test extensions when good opportunities to test the BOPS before the deadline were not taken. G reg, Please disseminate this information throughout your organization so that decisions on BOP test timing can be made to prevent violation of the regulations. This situation should not be occurring. Victoria Sent from my iPhone On Jan 12, 2020, at 8:52 AM, Smith, Matt<Matt.Smith2@conocophillips.com> wrote: Victoria, I hope you are having a good weekend. On Doyon 141, CD4 -499 we are due for a BOP test today. Unfortunately, we have had an extremely challenging TOOH after TD due to having to backream out, and fighting multiple packoff events, which has slowed us down considerably. We are currently still working our way out of the hole, but according to our forecast, it doesn't look like we'll be out of the hole until tomorrow around lunch time, if things continue to progress as expected. We would like to request an extension on our BOP test, until we get out of the hole and lay down our BHA, which should be — 12-24 hrs past our due date. The rig has been in constant communication with the field inspectors, and will continue to update them on our progress as well. Please let me know if this request is approved, or if you have any further questions. Thank you for the help, Matt Smith Drilling Engineer — Alaska W _ 700 G ST ANCHORAGE ALASKA. ATO -1704 OFFICE: +1.907.263.4324 CELL: +1.432.269.6432 MATT.SMITH2�;COP.COM P —1-0 ";),) q — /lv / Loepp. Victoria T (CED) From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Thursday, January 2, 2020 7:09 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Re: Doyon 141 shut in Follow Up Flag: Follow up Flag Status: Flagged Hey Victoria, we shut in using our Annular. We did test the annular and all valves that were used after TOOH, prior to running casing. Thanks, Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA. ATO -1 704 OFFICE: +1.907.263.4324 CELL: +1.432.269.6432 MATT. SMITH2 L COP.COM From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 01, 2020 8:44 PM To: Smith, Matt <Matt.Smith2@conocophillips.com> Subject: [EXTERNAL]Re: Doyon 141 shut in Matt, Please refer to AOGCC Guidance Bulletin 10-003. How was the well shut in? Was the component used tested once TOOH? Thanx, Victoria Sent from my iPhone On Jan 1, 2020, at 10:31 AM, Smith, Ma<Matt.Smith2@conocophillips.com> wrote: Happy New Year Victoria! Hope you were able to celebrate the end of a decade last night! I wanted to send a note of a shut in event on Doyon 141 last night. Please see the timeline of events below. The well was static with minimal gas upon circulation. At the time the flow was noticed, we were in the process of circulating sweeps and performing dilutions at TD, and believe we were likely out of balance, and observed the well u -tubing when we stopped pumping, and ultimately shut in. We are currently TOOH to run casing this morning. If you have any questions please let me know. Thank you, Matt Smith 432-269-6432 From: Doyon 141 Company Man <dd141cm@conocophillips.com> Sent: Wednesday, January 1, 2020 9:42 AM To: AOGCC Inspectors Cc: Doyon 141 toolpusher; Smith, Matt; Herbert, Frederick 0; Brady, Justin B Subject: Doyon 141 shut in At approximately 17:00 hrs on 12/31/2019 while circulating after reaching intermediate casing point on Well CD4 -499 the driller on Doyon 141 noticed a flow increase and a 5 barrel pit gain. He picked up off bottom, stopped pumping and monitored the well which continued flowing. The well was then shut-in and pressures were monitored. No casing pressure was observed. Obtaining drillpipe pressure would have been difficult since there were three non -ported floats in the drillstring. The well was then killed via the "Driller's Method" through the choke manifold. A small amount of gas was observed which dissipated after circulating bottoms up. The well was shut-in and no pressure was observed on the casing. The choke was opened and the well was static. Normal circulation resumed. We are currently back -reaming out of the hole to run 7" intermediate casing. Guy Whitlock / Jimmy Greco Drilling Supervisors Doyon 141 Company Man 907-670-4907 2 Ce6c C1�4-4-711 Regg, James B (CED) From: Doyon 141 Company Man <dd141cm@conocophilli s.com> Sent: Thursday, January 2, 2020 11:38 AMS` ` ((ZJ Z� To: Regg, James B (CED) (l ` Cc: Smith, Matt; Herbert, Frederick 0 Subject: RE: [EXTERNAL]RE: Doyon 141 shut in Jim, The PTD number for CD4 -499 is 219-161. The annular preventer was used to shut-in the well. We tested the annular preventer on 1/1/2020 after pulling out of the hole and changing the upper pipe rams to 7" solid bodied elements. We also tested the upper pipe rams at this time. We are currently running 7" intermediate casing. We will re -test out upper pipe rams and annular prior to drilling the production interval. Regards, Guy Whitlock / Jimmy Greco Drilling Supervisors Doyon 141 Company Man 907-670-4907 From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Thursday, January 2, 2020 10:31 AM To: Doyon 141 Company Man <dd141cm@conocophillips.com> Subject: [EXTERNAL]RE: Doyon 141 shut in Missing some info in your notice — refer to attached guidance bulletin. Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg alaska.gov. From: Doyon 141 Company Man <dd141cm@conocophiIhps.com> Sent: Wednesday, January 1, 2020 9:42 AM To: DOA AOGCC Prudhoe Bay<doa.aoRcc.Prudhoe. bay@alaska.Rov> Cc: Doyon 141 toolpusher <rig141@doyondrillinR.com>; Smith, Matt <Matt.Smith2@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Brady, Justin B <Justin. B. Brady@conocophillips.com> Subject: Doyon 141 shut in At approximately 17:00 hrs on 12/31/2019 while circulating after reaching intermediate casing point on Well CD4 -499 the driller on Doyon 141 noticed a flow increase and a 5 barrel pit gain. He picked up off bottom, stopped pumping and monitored the well which continued flowing. The well was then shut-in and pressures were monitored. No casing pressure was observed. Obtaining drillpipe pressure would have been difficult since there were three non -ported floats in the drillstring. The well was then killed via the "Driller's Method" through the choke manifold. A small amount of gas was observed which dissipated after circulating bottoms up. The well was shut-in and no pressure was observed on the casing. The choke was opened and the well was static. Normal circulation resumed. We are currently back -reaming out of the hole to run 7" intermediate casing. Guy Whitlock / Jimmy Greco Drilling Supervisors Doyon 141 Company Man 907-670-4907 2 THE STATE °'ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Colville River Field, Qannik Oil Pool, CRU CD4 -499 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-161 Surface Location: 2402' FSL, 51' FEL, SEC. 24, T1IN, R4E, UM Bottomhole Location: 1599' FNL, 3693' FEL, SEC. 32, TI IN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, r re . Price Chair DATED th07day of November, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVE® NOV 13 2019 An��r-% 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 10. Sp"i 14eWpWdVd for: Drill [21 ' Lateral ❑ Stratigraphic Test ❑ Development - Oil El • Service - Winj ❑ Single Zone R] • Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket E . Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 CRU -CD4 -499 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 14,783 TVD: 4,020 Colville River Unit Qannik Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2402' FSL, 51' FEL, Sec. 24, T11 N, R4E, UM • ADL380077, ADL384211, ADL380082, ADL388903 wjAj Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4055' FNL, 3181' FEL, Sec. 19, T11 N, R5E, UM LOINS 97-007 12/25/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1599' FNL, 3693' FEL, Sec. 32, T11 N, R5E, UM 2148, 2485, 640, 1214 4470' to ADL391587 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 46.5 15. Distance to Nearest Well Open Surface: x- 378194 y- 5957530 • Zone -4 GL / BF Elevation above MSL (ft): 19 to Same Pool: 12,026' CD2 -464 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 1918 • Surface: 1516 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 78.6 B Welded 79 41 41 120 120 10 yds 13.5" 10.75" 45.5 L-80 TXP 2396 41 41 2437 2390 989sx 11.0ppg, 272sx 15.8ppg G 8.75" 7" 26 L-80 Hyd 563 5463 41 41 5504 4070 228sx 15.8ppg Class G 6.125" 4.5" 12.6 L-80 Hyd 563 9429 5354 4020 14783 4150 Frac sleeves and swell packers 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑� No ❑ 20. Attachments: Property Plat ❑ OP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis g Seabed RepoDrilling Fluid Program 20 AAC 25.050 requirements Sketch 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: Matt Smith Authorized Name: Chip Alvord Contact Email: matt. smlth2 Co .Com Authorized Title: Drilling Manager Contact Phone: 907-263-4324 �1 t 3' 2-01 Authorized Signature: Date: Commission Use Only Permit to Drill q ,i l API Number: _ ��r(� JPermit Approval See cover letter for other Number: / ` W 50- �b3 Date: " requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m thane, gas hydrates, or gas contained in shales: Other: O S y �� 10 -�Samples req'd: Yes ❑ No � Mud log req'd: Yes ❑ No [2 355 IesJ �( H2S measures: Yes ❑ No� Directional svy req'd: Yes u No❑ �y� �.. � J a� G Spacing exception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes ❑ No� y .,4 $-( it j� �) Post initial injection MIT req'd: Yes ❑ No❑ �w? C6 its P_V'trr, APPROVED BY Approved by: I L COMMISSIONER THE COMMISSION Date: Submit dorm and Form 10-4�e/2017 This permit is valid f 2 o t r h d approval per 20 AAC 25.005(g) ////Attachments in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 12, 2019 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU CD4499 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Qannik sand production well from the CD4 drilling pad with rig Doyon 141. The intended spud date for this well is 12/25/2019. CRU C134-499 is planned to be Qannik sand lateral 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 an 8-3/4" BHA to TD, within the Qannik sand. This hole will be subsequently cased with a 7" casing 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 6-1/8" production hole will be horizontally drilled and completed as a producer in the Qannik sand. The production section will be lined with a 4-1/2" liner with frac sleeves and swell packers. The well will be hydraulicly stimulated. G �L 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 Matt Smith at 263-4324 (matt.smith2@ConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, cc: CD4499 Well File / Ann Haggerty -Sherrod ATO 1530 AOL Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Matt Smith Jennifer Crews ATO 1766 Drilling Engineer Lanston Chin Kuukpik Corp Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 CD4 -499 Application for Permit to Drill Document ConocoPhillips r Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f))............................................................ 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 of20AAC 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 gf 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 .......................8 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 8 15. Attachments................................................................................................................9 Attachment1 Cement Summary.................................................................................................................. 9 CD4 -499 APD Page 1 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 Attachment 2 Drilling Hazards Summary................................................................... Attachment 3 Completion Schematic.......................................................................... Attachment 4 Directional Plan.................................................................................. CD4 -499 APD Page 2 of 13 Printed: 13 -Nov -19 Application tor Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 1. Well Name (Requirements of 20 AAC 25.005 (fl) The well for which this application is submitted will be designated as CRU CD4 -499 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 2402' FSL, 50' FEL, Sec. 24, TI IN, R4E, UM NAD 1927 RKB Elevation 46.5' AMSL Northings: 5,957,530 Eastings: 378,194 Pad Elevation 19' AMSL Top of Productive Horizon Heel 4055' FNL, 3181 FEL, Sec. 19, TI IN, RSE, UM NAD 1927 Northings: 5,956,323 Eastings: 380,010 Measured Depth, RKB: 5,361' Total Vertical Depth, RKB: 4,061' Total Vertical Depth, SS: 4,015' Total Depth Toe 1599' FNL, 3693' FEL, Sec. 32, Tl IN, RSE, UM NAD 1927 Northings: 5,948,146 Eastings: 384,680 Measured Depth, RKB: 14,783' Total Vertical Depth, RKB: 4,021' Total Vertical Depth, SS: 3,994' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 141. CD4 -499 APD Page 3 of 13 Printed. 13 -Nov -19 r Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 120/ 120 10.9 51 56 10.75 2,437 / 2,390' 14.5 1,110 1,511 7 5504/4070' 12.5 1918 1516 4.5 14,783'/ 4,020' - 12.5 1,918 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - o.l]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/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 TVDNt k) -�, 7 irk 1.. ASP CALCULATIONS Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1] D _ [(10.9 x 0.052) - 0.1] x 120 = 56 psi OR ASP = FPP - (0.1 x D) = 1106 - (0.1 x 2390') = 867 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 2390' = 1563 psi OR ASP = FPP - (0.1 x D) = 1918 - (0.1 x 4070') = 1511 psi 3. Drilling below 7" surface casing ASP = [(FG x 0.052) - 0.1 ] D = [(12.5 x 0.052) - 0.1] x 4020' = 2211 psi OR ASP =FPP - (0.1 x D) = 1918 - (O.l x 4020') = 1516 psi (B) data on potential gas zones; Ya�� Pfd CD4 -499 APD Page 4 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 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 (e)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) P. Casing and Cementingr Program CsglTbg Hole siz1e weight Grade Conn. Length Top MDITVD Btm MD/TVD Cement Program CD (in) (Ib/ft) (ft) (ft) (ft) 16 42 94 H-40 Welded 80 28/28 108/ 108 10 yards Cement to Surface with 10.75 13.5 45.5 L-80 B �M 2,437 28/28 2,437' / 2,390' 989 sx DeepCrete Lead 11.0 ppg, 272 sx Class G Tail Slurry 15.8 ppg 7 8.75 26 L-80 Hyd563 5,504 28/28 5,504'/ 4,061' 228 sx of Class G at 15.8 ppg 4.5 6.125 12.6 L-80 Hyd563 9,529 5,354/ 4,056' 14,783/ 4,020' No cement, Frac Sleeves � 7i. Diverter System Information(Requirements of20AAC 25.dds(c)(7)) J� It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2),1Kgranted. At CD4, more than twenty-four penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. ,Q ; G 5 �� l �•L7 •f� CD4 -499 APD Page 5 of 13 Printed. 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 8. Drilling Fluid Program (Requirements of20 AAC 25.005(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 potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight between 9.5 to I I 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 kill weight prior to tripping to run casing. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production: 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 KCI and utilize MPD for adding backpressure during connections, if necessary Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD4 -499 APD Page 6 of 13 Printed. 13 -Nov -19 Surface Intermediate Production Hole Size in. 13.5 8.75 6.125 Casing Size in. 10.75 7 4.5 Density PPG 9.0-10.0 • 9.6-11 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 potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight between 9.5 to I I 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 kill weight prior to tripping to run casing. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production: 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 KCI and utilize MPD for adding backpressure during connections, if necessary Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD4 -499 APD Page 6 of 13 Printed. 13 -Nov -19 Application tor Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 9. Abnormally Pressured Formation Information (Requirements of 20AAC25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20AAC25.005 (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 141 onto CD4 -499. 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. 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 8-3/4" drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3 psi for 30 minutes. j 0,314( k Gs& u 9. Drill out 20' of new hole and perform. Maximum FIT to 15 ppg. Minimum LOT required to drill ahead is r 12 ppg EMW. 10. Drill 8-3/4" production hole to section TD, using Managed Pressure Drilling to maintain near constant bottom hole pressure on connections in shale formation (LWD Program: GR/RES).% 11. Change out upper pipe rams to 7" solid bodies and test same to 3,500 psi. 12. Run 7" casing and cement to 250' TVD above the hydrocarbon bearing zones (cementing schematic attached). 13. Install wellhead packoff and pressure test. Change casing ram to DP ram and perform BOP test 35�5�'-, 14. PU 6-1/8" production hole BHA. Log TOC with sonic in recorded mode. a6L L r 15. Chart casing pressure test to 3500 psi for 30 min 7 `i c``510�)- ,I G� 16. Drill out shoe track and 20 ft new formation. Perform FIT to 12ppg. Minimum required leak off value is 11 ppg. 17. Drill 6-1/8" hole to section TD (LWD Program: GR/Res/Den/Neutron) 18. POOH with drilling BHA. Review cement job details//and sonic log TOC. 19. Run 4-1/2" liner, set hanger and packer. 20. TOOH with liner running BHA and lay down. 21. RIH with 3.5" tubing with Baker Premier production packer. CD4 -499 APD Page 7 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 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. 133 w/ 1pl- -- 27. Nipple down BOP. 28. Install tubing head adapter assembly. N/U tree and test tree to 10,000 psi/10 minutes. 29. Freeze protect tubing and annulus. 30. Secure well.RDMO. 14. Discussion of Mud and Cuttings Disposal and Annul'ar"D`iisposal (Requirements of 20 AA 25.005 (e) (14)) Incidental fluids developed from drilling operations on well CD4 -499 will be injected into a permitted surface casing x production casing annulus on CD4. The CD4 -499 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 Qannik sand based on pre- drill interpretations. There will be 250' TVD of cement placed above the top of the Qannik reservoir. Once CD4 -499 has been drilled and completed, consideration maybe 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) * (2,390') + 1,500 psi = 2,992 psi Pore Pressure = 1,110 psi Therefore Differential = 2,992 — 1,110 = 1,882 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 CD4 -499 APD Page 8 of 13 Printed. 13 -Nov -19 Y� & L' P"' Application ror Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 10-3/4" 45.5 L-80 3 TXP/BTCM 2470 psi 2100 psi 5210 psi 4429 psi 7" 26 L-80 3 HYD563/BTCM 5410 psi 4600 psi 7240 psi 6154 psi 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD4 -499 APD Page 9 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 Attachment 1 — Cement Summary CD4 -499 Cementing Program: C014-499 — Cement Schematic 16•' 94# H-40 Welded Conductor to 108' ` I 5 C � l � I v3�`I u �5� I 13 IT Surface Hale 10-314'45.5# L-80 TXP Surface Casing 2,437 MD 12,390' TVD 25° inc 8-'!." Intermediate Hole Top of Cement 6-118" Production Hole 4,335' MD 13,829 TVD 4-1Y 12.6# L-80 Hyd563 Frac Sleeves + Swell packers 14,783° MD 14,020' TVD in r C� t M t -1 la to to to 1.1 1 /Top of QanmN k to ^W Gv 5,504" MD 14 070' TVD 4 7" 26# L-80 Hyd563 _ Intermediate Casing`' 5,504' MD / 4,070' TVD CD4 -499 APD Page 10 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 10.75" Surface Casing run to 2,437' MD / 2,390' TVD Cement from 2437' MD to 1,937' (500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,937' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1250' MD), zero excess in 20" conductor. Lead slurry from 2,000' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (108'— 28') X 0.7658 ft3/ft X 1.0 (0% excess) = 62 ft3 Permafrost to Conductor (1,250'— 108') X 0.3637 ft3/ft X 3.5 (250% excess) = 1,454 ft3 Top of Tail to Permafrost (1,937 — 1,250') X 0.3637 ft3/ft X 1.5 (50% excess) = 375 ft3 Total Volume = 62 + 1,454 + 375 = 1,890 ft3 => 9W sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,437' MD to 1,937' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,500'-2,000 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 => 272 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.17 ft3/sk 7" Intermediate Casing run to 5,504' MD / 4,070' TVD Top of slurry is designed to be at 4,335' MD, which is 250' TVD above the prognosis shallowest hydrocarbon bearing zone, the Qannik. Assume 50% excess annular vo u`1 me Tail slurry from 5,504' MD to 4,335' MD with 15.8 ppg Class G + additives 8-3/4" Hole to Top of Cement 1 (5,504' — 4,335') X 0.1503 ft3/ft X 1.50 (50% excess) = 264 ft3 Total Volume = 264 ft3 => 228 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk CD4 -499 APD Page 11 of 13 Printed: 13 -Nov -19 ./ Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -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 I Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gro 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, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use wei hted sweeps. Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Hydrogen Sulfide gas Low low density cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level 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. Well control drills, increased mud weight. No mapped faults occur Abnormal Reservoir Pressure Low across the path of the planned wellbore. across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers mud scavengers 6-1/8" Hole / 4-1/2" 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. Well control drills, increased mud weight. No mapped faults occur Abnormal Reservoir Pressure Low across the path of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers 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. ,i Shale Stability: The Seabee formations and instability in the uphole interval will require higher mud weights and 1� i 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 breakout or lost circulation if needed. CD4 -499 APD Page 12 of 13 Printed: 13 -Nov -19 Application for Permit to Drill, Well CRU CD4 -499 Saved: 13 -Nov -19 Attachment 3 — Completion Schematic CD4 -499 — 3 String Qannik 14 1 S 4-'f:" 12.6# L-80 Hyd563 DHG - Frac Sleeves + 5.5" OD Swell packers 14,783° MD f 4,020' TVD 3-1J2'Premier Packer 0 0 0 0 0 0 2.75" XN Landing Nippy T' 26# L-80 Hyd563 Intermediate Casing 6-18" Production Hole 5,504" MD f 4,070' TVD CD4 -499 APD Page 13 of 13 Printed: 13 -Nov -19 16" 94# H40 Welded Conductorto 108'. 2.813" X Landing Nipple 13 5T Surface Hale 10-3J4" 45.5# L-80 TXP Surface Casing 2,437 MD f 2,390' TVD 25° inc , , i i , , , , (b4) , 3-1h" 1" GLM 3-1h" 9.3# EUE Production Tubing , 8-s/." Intermediate Hole v� , , 3'h" 1" GLM 14 1 S 4-'f:" 12.6# L-80 Hyd563 DHG - Frac Sleeves + 5.5" OD Swell packers 14,783° MD f 4,020' TVD 3-1J2'Premier Packer 0 0 0 0 0 0 2.75" XN Landing Nippy T' 26# L-80 Hyd563 Intermediate Casing 6-18" Production Hole 5,504" MD f 4,070' TVD CD4 -499 APD Page 13 of 13 Printed: 13 -Nov -19 15:01. November 12 2019 CD4 -499 wp 15 Z55 0 0 0 0 V 0 a 0 m M 55 U) N c 0 28 C U 3000 6000 9000 12000 1500( Measured Depth - .=- Plan 19+27.5 @ 46.50usft (D141) 00, 10 ;74-. 13 1/ OOA .' i 41/2x61/ Oo- _7x83/ --i 3Q 1-eO g Q O- I C) a -Q- O. O. \ h 0 n W O O N � r 2000 4000 6000 8000 10000 12000 Horizontal Departure _ r %� Vii► . 1' 200 400 600 800 1000 1200 1400 Measured Denth Depth From Depth To Survey/Plan Tool Azi 27.50 1400.00 CD4 -499 wp15 (CD4 -499) GVD-GC-SS 300 490 Dleg aso - 670 1400.00 2430.00 CD4 -499 wp-15(CD4-499) MWD OWSG V. Osara 860 1040 300 6 60 1400.00 2430.00 CD4 -499 wp15(CD4-499) MWD+IFR2+SAG+MS 1410 - 1600 27.50 1600 - 2150 2430.00 2530.00 CD4-499wp15(CD4499) INC+TREND 14021.56 �qp Name 2530.00 4030.00 CD4-499wp15(CD4499) MWD OWSG 2390.00 2437.42 103/4x131/2 2530.00 5500.00 CD4 499 wp15 (CD4 -499) MWD+IFR2+SAG+MS 4069.47 5504.64 7 x 8-3/4 5500.00 5600.00 CD4-499wp15 (CD4499) 1NC+TREND 7100 - 8200 14783.39 41/2 x 61/8 5600.00 7100.00 CD4 499 wp15 (CD4499) MWD OWSG 5600.0014783.39 CD4-499wp15(CD4499) MWD+IFR2+SAG+MS DDI ' 6.750 Plan Summa 0 Inc Azi 27 __.......... 300 330 30 300 490 Dleg aso - 670 9 670 860 V. Osara 860 1040 300 6 60 1040 - 1230 1230 - 1410 0.00 1410 - 1600 27.50 1600 - 2150 3,.- 0 2150 2700 4PH1 I 700 - 3250 1 q 3250 - 3800 3800 -'- 4350 11_ 09 EGD 85PH14350 - 4900 "9 1 4900 - 5450 SD 5 7 4 8PB1 5450 - 6000 8 6000 - 7100 8 3 35 7100 - 8200 240 31 - W1A) wp0 8200 - 9290 83 26 3 9290 - 10390 5 4 3016 10390 11490 699.98 11490 12590 21 C- 3 - 1 3 150 12590 13690 D4- PB 1 13690 - 14783 0 Magnetic Model & Date: BGGM2018 31 -Dec -19 4 1351.35 agnetic North is 15.87° East of True North (Magnetic Declinatic 15.00 Magnetic Dip & Field Strength: 80.71 o 57361 nT 72.41 19.40 Lithology Column 0.00 Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation V. Osara za�ss 1 27.50 0.00 0.00 27.50 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 0.75'1100' DLS, 15° TF, for 200' 3 700.00 1.50 15.00 699.98 2.53 0.68 0.75 15.00 -1.66 Start 1.5°1100' DLS, 0° TF, for 651.35 C-30 4 1351.35 11.27 15.00 1346.50 72.41 19.40 1.50 0.00 -47.60 Hold for 101.97' 5 1453.31 11.27 15.00 1446.50 91.66 24.56 0.00 0.00 -60.25 Start 2.5°1100' DLS, 101* TF, for 1046.74' 6 2500.06 26.28 92.89 2446.50 180.32 287.05 2.50 101.00 20.39 Hold for 20' 17- 7 2520.06 26.28 92.89 2464.43 179.87 295.89 0.00 0.00 25.90 Adjust TF to 0°, for 280' 8 2800.06 26.28 92.89 2715.49 173.62 419.71 0.00 0.00 103.03 Start 3°/100' DLS, 60.14' TF, for 2430.25' C-20 9 5230.31 86.97 149.00 4054.98 -1065.50 1769.23 3.00 60.14 1896.05 Hold for 261.92' 10 549222 8697 149.00 4068.81 -1289.70 1903.94 0.00 0.00 2156.77 Start 3°1100' DLS, 85.96° TF, for 12.42' zees.s 11 5504.64 87.00 149,37 4069.47 -1300.35 1910.30 3.00 85.96 2169.12 Hold for 20' 12 5524.64 87.00 149.37 4070.51 -1317.53 1920.47 0.00 0.00 2189.02 Start 1.5°1100' DLS, -0.07° TF, for 168.46' 13 5693.10 89.53 149.37 4075.62 -1462.41 2006.26 1.50 -0.07 2356.76 Hold for 7358.1' 1413051.20 89.53 149.37 4136.37 -7793.46 5755.36 0.00 0.00 9687.15 Start 1.5°1100' DLS, -0.06° TF, for 31.85' 1513083.05 90.00 149.30 4136.50 -7820.85 5771.61 1.50 -8.06 9718.89 CD4 -499 Tgt 1 103119 Adjust TF to -2.42°, for 102.3' 1613185.35 91.53 149.24 4135.13 -7908.77 5823.88 1.50 -2.42 9820.81 Hold for 356.24' 1713541.59 91.53 149.24 4125.61 -8214.77 6006.03 0.00 0.0010175.66 Start 1.5°/100' DLS, 0.23' TF, for 241,8' 1813783.39 95.16 149.25 4111.50 -8422.17 6129.46 1.50 0.2310416.15 CD4 -499 Tgt 2 103119 Hold for 500' 1914283.39 95.16 149.25 4066.53 -8850.13 6384.07 0.00 0.0010912.35 Adjust TF to 0°, for 500' 2014783.39 95.16 149.25 4021.56 -9278.09 6638.68 0.00 0.0011408.55 TD: 14783.39' MD, 4021.56' TVD Ill - . Permit Pack 1 -By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and Tier Standard all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets • have a 100 feet lateral tolerance. I 1 C-10 38146 K-3 411UIt 1 repa Checked by Nccepted by Approved by: S. DeLapp V. Osara J. Ryan CoP DE CD4 -499 wp 15 Plan Vnew While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 0 - No 10 3/4 x 13 1/2 -2000 7 x 8-3/4 44000- 1000-6000 -6000 9 �Q16 -8000 b9 GOA. 4 1/2 x 6 1/8- - -2000 0 2000 4000 6000 8000 10000 West( -)/East(+) 14. pp„ NovemMrc 06 XJ 19 CD4 -499 wp15 27.50 To 14783.39 Spider C 4-07 CD 208 CD-3016 �4-'l 208PB CD4 -3 D4- D4- 04 CD4 - CD4 -30 A c 4-321 PB1 N C - 18A CD4 2 7 O 0 3 C 13 v D4-2 ' m CD4 -2 c r - 21 _ B D t Bt 0 z t _ NEC" D - 4_ 01 C 4- 4- 2 -CD4- 2 CD4- 4-209 D-9 D - - w 1 4-214 _ _ PBt D4-499 15 CD 5 SPH D4-288 NE3A) 01 -2 83 -A.CD4-96 \CD, 4-2 OB - CD4-xx (OAN 16 09) wp0 CD4 95 CD -594 wp 4v2 APB D4-20 4-27 4-210A P81 D4-297 (MA) 01 VD Easting (4500 usft/in) APB D4-20 4-210A ConocoPhillips Alaska Inc_WNS Western North Slope CD4 Nanuq Pad Plan: CD4 -499 50103xxxxx00 CD4 -499 Plan: CD4 -499 wp15 Standard Proposal Report 12 November, 2019 ConocoPhillips low, ,- ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wpl5 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True 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 CD4 Nanuq Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: CD4 -499 Well Position +N/•S 5.04 usft Northing: +E/ -W 19.46 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 19.00 usft Wellbore CD4 -499 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BG GM 2018 12/31/2019 15.87 80.71 57,361 FDI,gn CD4 -499 wpl5 tNotes:ion: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 144.42 11/12/2019 3: 03 17P Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 Plan Survey tool Program Date 11/12/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 27.50 1,400.00 CD4 -499 wp15 (CD4 -499) 2 1,400.00 2,430.00 CD4 -499 wp15 (CD4 -499) 3 1,400.00 2,430.00 CD4 -499 wp15 (CD4 -499) 4 2,430.00 2,530.00 CD4 -499 wp15 (CD4 -499) 5 2,530.00 4,030.00 CD4 -499 wp15 (CD4 -499) 6 2,530.00 5,500.00 CD4 -499 wp15 (CD4 -499) 7 5,500.00 5,600.00 CD4 -499 wp15 (CD4 -499) 8 5,600.00 7,100.00 CD4 -499 wp15 (CD4 -499) 9 5,600.00 14,783.39 CD4 -499 wp15 (CD4 -499) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+M S OWSG MWD + IFR2 + Sag + A INC+TREND Inclinometer + known azi trend MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A INC+TREND Inclinometer + known azi trend MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+M S OWSG MWD + IFR2 + Sag + A ConocoPhillips Standard Proposal Report Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 1111212019 3:03:17PM Page 3 COMPASS 5000 14 Build 85H r ConocoPhillips p Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wpl5 Plan Sections Measured Depth (usft) 27.50 500.00 700.00 1,351.35 1,453.31 2,500.06 2,520.06 2,800.06 5,230.31 5,492.22 5,504.64 5,524.64 5,693.10 13,051.20 13, 083.05 13,185.35 13, 541.59 13,783.39 14,283.39 14.783.39 Inclination Azimuth (% (°) 0.00 0.00 1.50 11.27 11.27 26.28 26.28 26.28 86.97 86.97 87.00 87.00 89.53 89.53 90.00 91.53 91.53 95.16 95.16 95.16 0.00 0.00 15.00 15.00 15.00 92.89 92.89 92.89 149.00 149.00 149.37 149.37 149.37 149.37 149.30 149.24 149.24 149.25 149.25 149.25 Vertical Build Depth +NI -S (usft) (usft) 27.50 0.00 500.00 0.00 699.98 2.53 1,346.50 72.41 1,446.50 91.66 2,446.50 180.32 2,464.43 179.87 2,715.49 173.62 4,054.98 -1,065.50 4,068.81 -1,289.70 4,069.47 -1,300.35 4,070.51 -1,317.53 4,075.62 -1,462.41 4,136.37 -7,793.46 4,136.50 -7,820.85 4,135.13 -7,908.77 4,125.61 -8,214.77 4,111.50 -8,422.17 4,066.53 -8,850.13 4,021.56 -9,278.09 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +E/ -W (usft) 0.00 0.00 0.68 19.40 24.56 287.05 295.89 419.71 1,769.23 1,903.94 1,910.30 1,920.47 2,006.26 5,755.36 5,771 .61 5,823.88 6,006.03 6,129.46 6,384.07 6,638.68 ConocoPhillips Standard Proposal Report Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature Dogleg Build Turn Rate Rate Rate (°/100usft) (°1100usft) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 0.75 0.75 0.00 1.50 1.50 0.00 0.00 0.00 0.00 2.50 1.43 7.44 0.00 0.00 0.00 0.00 0.00 0.00 3.00 2.50 2.31 0.00 0.00 0.00 3.00 0.21 2.99 0.00 0.00 0.00 1.50 1.50 0.00 0.00 0.00 0.00 1.50 1.49 -0.21 1.50 1.50 -0.06 0.00 0.00 0.00 1.50 1.50 0.01 0.00 0.00 0.00 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 15.00 0.00 0.00 101.00 0.00 0.00 60.14 0.00 85.96 0.00 -0.07 0.00 -8.06 CD4 -499 Tgt 1 10311 -2.42 0.00 0.23 CD4 -499 Tgt 2 10311 0.00 0.00 11/1212019 3:03 17PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD4 -499 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan 19+27.5 @ 46.50usft (D141) Project: Western North Slope MD Reference: Plan 19+27.5 @ 46.50usft (D141) Site: CD4 Nanuq Pad North Reference: True Well: Plan: CD4 -499 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -499 Design: CD4 -499 wp15 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 27.50 0.00 0.00 27.50 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 KOP: Start 0.75°/100' DLS, 15° TF, for 200' 600.00 0.75 15.00 600.00 0.63 0.17 -0.42 0.75 0.75 0.00 700.00 1.50 15.00 699.98 2.53 0.68 -1.66 0.75 0.75 0.00 Start 1.5°/100' DLS, 0° TF, for 651.35' 800.00 3.00 15.00 799.90 6.32 1.69 -4.15 1.50 1.50 0.00 900.00 4.50 15.00 899.68 12.64 3.39 -8.31 1.50 1.50 0.00 1,000.00 6.00 15.00 999.26 21.48 5.75 -14.12 1.50 1.50 0.00 1,100.00 7.50 15.00 1,098.56 32.83 8.80 -21.58 1.50 1.50 0.00 1,200.00 9.00 15.00 1,197.52 46.69 12.51 -30.69 1.50 1.50 0.00 1,300.00 10.50 15.00 1,296.08 63.05 16.89 -41.44 1.50 1.50 0.00 1,351.35 11.27 15.00 1,346.50 72.41 19.40 -47.60 1.50 1.50 0.00 Hold for 101.97' 1,400.00 11.27 15.00 1,394.21 81.60 21.86 -53.64 0.00 0.00 0.00 1,453.31 11.27 15.00 1,446.50 91.66 24.56 -60.25 0.00 0.00 0.00 Start 2.5°/100' DLS, 101° TF, for 1046.74' 1,500.00 11.11 20.96 1,492.30 100.27 27.35 -65.63 2.50 -0.35 12.76 1,600.00 11.16 33.93 1,590.43 117.29 36.20 -74.33 2.50 0.05 12.97 1,700.00 11.75 46.19 1,688.46 132.37 48.95 -79.17 2.50 0.59 12.26 1,800.00 12.80 56.88 1,786.18 145.48 65.58 -80.15 2.50 1.05 10.69 1,900.00 14.22 65.72 1,883.42 156.58 86.05 -77.27 2.50 1.41 8.84 2,000.00 15.90 72.87 1,979.99 165.67 110.34 -70.53 2.50 1.68 7.15 2,100.00 17.77 78.61 2,075.71 172.72 138.39 -59.94 2.50 1.87 5.75 2,200.00 19.77 83.26 2,170.40 177.71 170.14 -45.52 2.50 2.00 4.65 2,300.00 21.87 87.07 2,263.87 180.65 205.55 -27.31 2.50 2.10 3.81 2,400.00 24.05 90.23 2,355.94 181.52 244.53 -5.33 2.50 2.18 3.16 2,437.42 24.88 91.28 2,390.00 181.31 260.02 3.85 2.50 2.22 2.80 10 3/4 x 13 1/2 2,465.27 25.50 92.02 2,415.20 180.97 271.87 11.03 2.50 2.23 2.65 C-30 2,500.00 26.28 92.89 2,446.45 180.32 287.02 20.37 2.50 2.25 2.52 2,500.06 26.28 92.89 2,446.50 180.32 287.05 20.39 2.50 2.25 2.45 Hold for 20' 2,520.06 26.28 92.89 2,464.43 179.87 295.89 25.90 0.00 0.00 0.00 Adjust TF to 0°, for 280' 2,600.00 26.28 92.89 2,536.11 178.09 331.24 47.92 0.00 0.00 0.00 2,700.00 26.28 92.89 2,625.78 175.85 375.46 75.47 0.00 0.00 0.00 2,800.00 26.28 92.89 2,715.44 173.62 419.68 103.02 0.00 0.00 0.00 2,800.06 26.28 92.89 2,715.49 173.62 419.71 103.03 0.00 0.00 0.00 Start 3°/100' DLS, 60.14° TF, for 2430.25' 2,838.64 26.87 95.11 2,750.00 172.41 436.93 114.03 3.00 1.54 5.76 C-20 2,900.00 27.89 98.46 2,804.49 169.07 464.93 133.05 3.00 1.65 5.45 3,000.00 29.69 103.43 2,892.13 159.87 512.16 168.01 3.00 1.81 4.98 3,100.00 31.67 107.86 2,978.15 146.06 561.25 207.81 3.00 1.97 4.43 3,120.91 32.10 108.73 2,995.90 142.59 571.73 216.73 3.00 2.06 4.13 C-10 3,200.00 33.78 111.81 3,062.28 127.68 612.05 252.32 3.00 2.12 3.90 11/1212019 3:03:17PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Desian: CD4 -499 wpl5 Planned Survey Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature Measured 87.00 149.37 Vertical -1,317.53 1,920.47 Vertical Dogleg Build Turn Depth Inclination -0.07' TF, for 768.46' Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 3,300.00 36.00 115.34 3,144.31 104.77 664.43 301.43 3.00 2.22 3.53 3,400.00 38.31 118.50 3,224.02 77.39 718.24 355.01 3.00 2.31 3.16 3,500.00 40.70 121.35 3,301.17 45.63 773.34 412.90 3.00 2.39 2.85 3,600.00 43.16 123.93 3,375.57 9.56 829.58 474.96 3.00 2.45 2.58 3,700.00 45.67 126.29 3,447.00 -30.70 886.80 541.00 3.00 2.51 2.35 3,800.00 48.22 128.44 3,515.27 -75.06 944.84 610.85 3.00 2.55 2.16 3,900.00 50.81 130.44 3,580.20 -123.39 1,003.55 684.31 3.00 2.59 1.99 4,000.00 53.43 132.29 3,641.60 -175.55 1,062.76 761.19 3.00 2.62 1.85 4,100.00 56.08 134.02 3,699.31 -231.41 1,122.32 841.28 3.00 2.65 1.73 4,200.00 58.75 135.64 3,753.17 -290.81 1,182.05 924.35 3.00 2.67 1.62 4,300.00 61.44 137.17 3,803.03 -353.59 1,241.80 1,010.17 3.00 2.69 1.53 4,324.46 62.10 137.54 3,814.60 -369.44 1,256.40 1,031.56 3.00 2.70 1.48 K-3 149.37 4,083.93 -2,328.76 2,519.29 3,359.87 0.00 0.00 0.00 6,800.00 4,400.00 64.14 138.63 3,848.76 -419.58 1,301.41 1,098.52 3.00 2.71 1.45 4,500.00 66.86 140.02 3,890.22 -488.60 1,360.70 1,189.15 3.00 2.72 1.39 4,600.00 69.59 141.36 3,927.31 -560.45 1,419.51 1,281.81 3.00 2.73 1.34 4,700.00 72.33 142.65 3,959.93 -634.94 1,477.70 1,376.24 3.00 2.74 1.29 4,800.00 75.08 143.90 3,987.98 -711.86 1,535.08 1,472.20 3.00 2.75 1.25 4,900.00 77.84 145.12 4,011.39 -791.01 1,591.52 1,569.41 3.00 2.76 1.22 5,000.00 80.60 146.31 4,030.10 -872.17 1,646.85 1,667.60 3.00 2.76 1.19 5,100.00 83.37 147.49 4,044.04 -955.11 1,700.92 1,766.52 3.00 2.77 1.18 5,200.00 86.13 148.65 4,053.19 -1,039.62 1,753.58 1,865.89 3.00 2.77 1.16 5,230.31 86.97 149.00 4,054.98 -1,065.50 1,769.23 1,896.05 3.00 2.77 1.16 Hold for 261.92' 5,300.00 86.97 149.00 4,058.66 -1,125.16 1,805.08 1,965.43 0.00 0.00 0.00 5,315.83 86.97 149.00 4,059.50 -1,138.71 1,813.22 1,981.19 0.00 0.00 0.00 K-2 5,400.00 86.97 149.00 4,063.94 -1,210.76 1,856.51 2,064.97 0.00 0.00 0.00 5,492.22 86.97 149.00 4,068.81 -1,289.70 1,903.94 2,156.77 0.00 0.00 0.00 Start 3"/100' DLS, 86.96° TF, for 12.42' 5,500.00 86.99 149.23 4,069.22 -1,296.36 1,907.93 2,164.51 3.00 0.21 2.99 5,504.64 87.00 149.37 4,069.47 -1,300.34 1,910.30 2,169.12 3.00 0.21 2.99 Hold for 20'- 7 x 8-3/4 5,524.64 87.00 149.37 4,070.51 -1,317.53 1,920.47 2,189.02 0.00 0.00 0.00 Start 1.6"/100' DLS, -0.07' TF, for 768.46' 5,600.00 88.13 149.37 4,073.71 -1,382.32 1,958.83 2,264.03 1.50 1.50 0.00 5,693.10 89.53 149.37 4,075.62 -1,462.41 2,006.26 2,356.76 1.50 1.50 0.00 Hold for 7368.1' 5,700.00 89.53 149.37 4,075.67 -1,468.34 2,009.77 2,363.64 0.00 0.00 0.00 5,800.00 89.53 149.37 4,076.50 -1,554.38 2,060.73 2,463.26 0.00 0.00 0.00 5,900.00 89.53 149.37 4,077.32 -1,640.43 2,111.68 2,562.88 0.00 0.00 0.00 6,000.00 89.53 149.37 4,078.15 -1,726.47 2,162.63 2,662.51 0.00 0.00 0.00 6,100.00 89.53 149.37 4,078.98 -1,812.51 2,213.58 2,762.13 0.00 0.00 0.00 6,200.00 89.53 149.37 4,079.80 -1,898.55 2,264.53 2,861.75 0.00 0.00 0.00 6,300.00 89.53 149.37 4,080.63 -1,984.59 2,315.49 2,961.38 0.00 0.00 0.00 6,400.00 89.53 149.37 4,081.45 -2,070.64 2,366.44 3,061.00 0.00 0.00 0.00 6,500.00 89.53 149.37 4,082.28 -2,156.68 2,417.39 3,160.62 0.00 0.00 0.00 6,600.00 89.53 149.37 4,083.10 -2,242.72 2,468.34 3,260.25 0.00 0.00 0.00 6,700.00 89.53 149.37 4,083.93 -2,328.76 2,519.29 3,359.87 0.00 0.00 0.00 6,800.00 89.53 149.37 4,084.76 -2,414.80 2,570.25 3,459.49 0.00 0.00 0.00 6,900.00 89.53 149.37 4,085.58 -2,500.85 2,621.20 3,559.12 0.00 0.00 0.00 7,000.00 89.53 149.37 4,086.41 -2,586.89 2,672.15 3,658.74 0.00 0.00 0.00 7,100.00 89.53 149.37 4,087.23 -2,672.93 2,723.10 3,758.36 0.00 0.00 0.00 11/1212019 3:03.17PM Page 6 COMPASS 5000.14 Build 85t ConoeoPhilli s p ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD4 -499 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan 19+27.5 @ 46.50usft (D141) Project: Western North Slope MD Reference: Plan 19+27.5 @ 46.50usft (D141) Site: CD4 Nanuq Pad North Reference: True Well: Plan: CD4 -499 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -499 (°) (usft) Design: CD4 -499 wpl5 (usft) (°/100usft) Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 7,200.00 89.53 149.37 4,088.06 -2,758.97 2,774.06 3,857.99 0.00 0.00 0.00 7,300.00 89.53 149.37 4,088.88 -2,845.01 2,825.01 3,957.61 0.00 0.00 0.00 7,400.00 89.53 149.37 4,089.71 -2,931.05 2,875.96 4,057.23 0.00 0.00 0.00 7,500.00 89.53 149.37 4,090.54 -3,017.10 2,926.91 4,156.86 0.00 0.00 0.00 7,600.00 89.53 149.37 4,091.36 -3,103.14 2,977.86 4,256.48 0.00 0.00 0.00 7,700.00 89.53 149.37 4,092.19 -3,189.18 3,028.82 4,356.10 0.00 0.00 0.00 Fault 1 7,800.00 89.53 149.37 4,093.01 -3,275.22 3,079.77 4,455.73 0.00 0.00 0.00 7,900.00 89.53 149.37 4,093.84 -3,361.26 3,130.72 4,555.35 0.00 0.00 0.00 8,000.00 89.53 149.37 4,094.66 -3,447.31 3,181.67 4,654.97 0.00 0.00 0.00 8,100.00 89.53 149.37 4,095.49 -3,533.35 3,232.62 4,754.60 0.00 0.00 0.00 8,200.00 89.53 149.37 4,096.31 -3,619.39 3,283.58 4,854.22 0.00 0.00 0.00 8,300.00 89.53 149.37 4,097.14 -3,705.43 3,334.53 4,953.85 0.00 0.00 0.00 8,400.00 89.53 149.37 4,097.97 -3,791.47 3,385.48 5,053.47 0.00 0.00 0.00 8,500.00 89.53 149.37 4,098.79 -3,877.52 3,436.43 5,153.09 0.00 0.00 0.00 8,600.00 89.53 149.37 4,099.62 -3,963.56 3,487.38 5,252.72 0.00 0.00 0.00 8,700.00 89.53 149.37 4,100.44 -4,049.60 3,538.34 5,352.34 0.00 0.00 0.00 8,800.00 89.53 149.37 4,101.27 -4,135.64 3,589.29 5,451.96 0.00 0.00 0.00 8,900.00 89.53 149.37 4,102.09 -4,221.68 3,640.24 5,551.59 0.00 0.00 0.00 9,000.00 89.53 149.37 4,102.92 -4,307.73 3,691.19 5,651.21 0.00 0.00 0.00 9,100.00 89.53 149.37 4,103.75 -4,393.77 3,742.14 5,750.83 0.00 0.00 0.00 9,200.00 89.53 149.37 4,104.57 -4,479.81 3,793.10 5,850.46 0.00 0.00 0.00 9,300.00 89.53 149.37 4,105.40 -4,565.85 3,844.05 5,950.08 0.00 0.00 0.00 9,400.00 89.53 149.37 4,106.22 -4,651.89 3,895.00 6,049.70 0.00 0.00 0.00 9,500.00 89.53 149.37 4,107.05 -4,737.93 3,945.95 6,149.33 0.00 0.00 0.00 9,600.00 89.53 149.37 4,107.87 -4,823.98 3,996.90 6,248.95 0.00 0.00 0.00 9,700.00 89.53 149.37 4,108.70 -4,910.02 4,047.86 6,348.57 0.00 0.00 0.00 9,800.00 89.53 149.37 4,109.53 -4,996.06 4,098.81 6,448.20 0.00 0.00 0.00 9,900.00 89.53 149.37 4,110.35 -5,082.10 4,149.76 6,547.82 0.00 0.00 0.00 10,000.00 89.53 149.37 4,111.18 -5,168.14 4,200.71 6,647.44 0.00 0.00 0.00 10,100.00 89.53 149.37 4,112.00 -5,254.19 4,251.66 6,747.07 0.00 0.00 0.00 10,200.00 89.53 149.37 4,112.83 -5,340.23 4,302.62 6,846.69 0.00 0.00 0.00 10,300.00 89.53 149.37 4,113.65 -5,426.27 4,353.57 6,946.31 0.00 0.00 0.00 10,400.00 89.53 149.37 4,114.48 -5,512.31 4,404.52 7,045.94 0.00 0.00 0.00 10,500.00 89.53 149.37 4,115.30 -5,598.35 4,455.47 7,145.56 0.00 0.00 0.00 10,600.00 89.53 149.37 4,116.13 -5,684.40 4,506.42 7,245.18 0.00 0.00 0.00 10,700.00 89.53 149.37 4,116.96 -5,770.44 4,557.38 7,344.81 0.00 0.00 0.00 10,800.00 89.53 149.37 4,117.78 -5,856.48 4,608.33 7,444.43 0.00 0.00 0.00 10,900.00 89.53 149.37 4,118.61 -5,942.52 4,659.28 7,544.05 0.00 0.00 0.00 11,000.00 89.53 149.37 4,119.43 -6,028.56 4,710.23 7,643.68 0.00 0.00 0.00 11,100.00 89.53 149.37 4,120.26 -6,114.61 4,761.18 7,743.30 0.00 0.00 0.00 11,200.00 89.53 149.37 4,121.08 -6,200.65 4,812.14 7,842.92 0.00 0.00 0.00 11,300.00 89.53 149.37 4,121.91 -6,286.69 4,863.09 7,942.55 0.00 0.00 0.00 11,400.00 89.53 149.37 4,122.74 -6,372.73 4,914.04 8,042.17 0.00 0.00 0.00 11,500.00 89.53 149.37 4,123.56 -6,458.77 4,964.99 8,141.79 0.00 0.00 0.00 11,600.00 89.53 149.37 4,124.39 -6,544.81 5,015.95 8,241.42 0.00 0.00 0.00 11,700.00 89.53 149.37 4,125.21 -6,630.86 5,066.90 8,341.04 0.00 0.00 0.00 11,800.00 89.53 149.37 4,126.04 -6,716.90 5,117.85 8,440.66 0.00 0.00 0.00 11,900.00 89.53 149.37 4,126.86 -6,802.94 5,168.80 8,540.29 0.00 0.00 0.00 12,000.00 89.53 149.37 4,127.69 -6,888.98 5,219.75 8,639.91 0.00 0.00 0.00 12,100.00 89.53 149.37 4,128.52 -6,975.02 5,270.71 8,739.53 0.00 0.00 0.00 12,200.00 89.53 149.37 4,129.34 -7,061.07 5,321.66 8,839.16 0.00 0.00 0.00 12,300.00 89.53 149.37 4,130.17 -7,147.11 5,372.61 8,938.78 0.00 0.00 0.00 11/12/2019 3:03:17PM Page 7 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD4 -499 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan 19+27.5 @ 46.50usft (D141) Project: Western North Slope MD Reference: Plan 19+27.5 @ 46.50usft (D141) Site: CD4 Nanuq Pad North Reference: True Well: Plan: CD4 -499 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -499 Design: CD4 -499 wpl5 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (_) (^j (usft) (usft) (usft) (usft) (°1100usft) (°1100usft) (°1100usft) 12,400.00 89.53 149.37 4,130.99 -7,233.15 5,423.56 9,038.41 0.00 0.00 0.00 12,500.00 89.53 149.37 4,131.82 -7,319.19 5,474.51 9,138.03 0.00 0.00 0.00 12,600.00 89.53 149.37 4,132.64 -7,405.23 5,525.47 9,237.65 0.00 0.00 0.00 12,700.00 89.53 149.37 4,133.47 -7,491.28 5,576.42 9,337.28 0.00 0.00 0.00 12,800.00 89.53 149.37 4,134.29 -7,577.32 5,627.37 9,436.90 0.00 0.00 0.00 12,900.00 89.53 149.37 4,135.12 -7,663.36 5,678.32 9,536.52 0.00 0.00 0.00 13,000.00 89.53 149.37 4,135.95 -7,749.40 5,729.27 9,636.15 0.00 0.00 0.00 13,051.20 89.53 149.37 4,136.37 -7,793.46 5,755.36 9,687.16 0.00 0.00 0.00 Start 1.5°/100' DLS, -8.06° TF, for 31.85' 13,083.05 90.00 149.30 4,136.50 -7,820.85 5,771.61 9,718.89 1.50 1.49 -0.21 Adjust TF to -2.42°, for 102.3' 13,100.00 90.25 149.29 4,136.46 -7,835.42 5,780.26 9,735.77 1.50 1.50 -0.06 13,185.35 91.53 149.24 4,135.13 -7,908.77 5,823.88 9,820.81 1.50 1.50 -0.06 Hold for 356.24' 13,200.00 91.53 149.24 4,134.74 -7,921.36 5,831.37 9,835.40 0.00 0.00 0.00 13,300.00 91.53 149.24 4,132.07 -8,007.25 5,882.50 9,935.01 0.00 0.00 0.00 13,400.00 91.53 149.24 4,129.39 -8,093.15 5,933.64 10,034.62 0.00 0.00 0.00 13,500.00 91.53 149.24 4,126.72 -8,179.05 5,984.77 10,134.23 0.00 0.00 0.00 13,541.59 91.53 149.24 4,125.61 -8,214.77 6,006.03 10,175.66 0.00 0.00 0.00 Start 1.5°/100' DLS, 0.23° TF, for 241.8' 13,600.00 92.41 149.24 4,123.60 -8,264.93 6,035.89 10,233.83 1.50 1.50 0.01 13,700.00 93.91 149.24 4,118.09 -8,350.73 6,086.96 10,333.32 1.50 1.50 0.01 13,783.39 95.16 149.25 4,111.50 -8,422.17 6,129.46 10,416.15 1.50 1.50 0.01 Hold for 500' 13,800.00 95.16 149.25 4,110.01 -8,436.39 6,137.92 10,432.64 0.00 0.00 0.00 13,900.00 95.16 149.25 4,101.01 -8,521.98 6,188.84 10,531.88 0.00 0.00 0.00 14,000.00 95.16 149.25 4,092.02 -8,607.57 6,239.76 10,631.12 0.00 0.00 0.00 14,100.00 95.16 149.25 4,083.02 -8,693.17 6,290.69 10,730.36 0.00 0.00 0.00 14,200.00 95.16 149.25 4,074.03 -8,778.76 6,341.61 10,829.60 0.00 0.00 0.00 14,283.39 95.16 149.25 4,066.53 -8,850.13 6,384.07 10,912.35 0.00 0.00 0.00 Adjust TF to 0°, for 500' 14,300.00 95.16 149.25 4,065.04 -8,864.35 6,392.53 10,928.84 0.00 0.00 0.00 14,400.00 95.16 149.25 4,056.04 -8,949.94 6,443.45 11,028.08 0.00 0.00 0.00 14,500.00 95.16 149.25 4,047.05 -9,035.53 6,494.37 11,127.32 0.00 0.00 0.00 14,600.00 95.16 149.25 4,038.06 -9,121.13 6,545.30 11,226.56 0.00 0.00 0.00 14,700.00 95.16 149.25 4,029.06 -9,206.72 6,596.22 11,325.80 0.00 0.00 0.00 14,783.39 95.16 149.25 4,021.56 -9,278.09 6,638.68 11,408.55 0.00 0.00 0.00 TD: 14783.39' MD, 4021.56' TVD 11/1212019 3: 03 17P Page 8 COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD4 -499 Company: ConocoPhillips Alaska Inc_WNS Vertical TVD Reference: Plan 19+27.5 @ 46.50usft (D141) Project: Western North Slope Depth Depth MD Reference: Plan 19+27.5 @ 46.50usft (D141) Site: CD4 Nanuq Pad (usft) (usft) North Reference: True Well: Plan: CD4 -499 2,465.27 2,415.20 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -499 2,838.64 2,750.00 C-20 LIGNITE Design: CD4 -499 wpl5 3,120.91 2,995.90 C-10 LIGNITE Design Targets 4,324.46 3,814.60 K-3 LIGNITE Target Name 5,315.83 4,059.50 K-2 LIGNITE hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape (°) (°) (usft) (usft) (usft) CD4 -499 Tgt 0 QM 0.00 0.00 4,069.50 -1,301.20 1,910.81 plan misses target center by 0.02usft at 5505.64usft MD (4069.52 TVD, -1301.20 N, 1910.81 E) Circle (radius 1,320.00) CD4 -499 Tgt 0 E Heel 1, 0.00 0.00 4,069.50 -1,301.20 1,910.81 plan misses target center by 0.02usft at 5505.64usft MD (4069.52 TVD, -1301.20 N, 1910.81 E) Circle (radius 100.00) CD4 -499 Tgt 2 QM 0.00 0.00 4,111.50 -8,422.17 6,129.46 plan hits target center Circle (radius 1,320.00) CD4-499Tgt2103119 0.00 0.00 4,111.50 -8,422.17 6,129.46 plan hits target center Circle (radius 100.00) CD4 -499 Tgt 1 103119 0.00 0.00 4,136.50 -7,820.85 5,771.61 plan hits target center Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,437.42 2,390.00 10 3/4 x 13 1/2 10.750 13.500 5,504.64 4,069.47 7 x 8-3/4 7.000 8.750 14,783.39 4,021.56 4 1/2 x 6 1/8 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,465.27 2,415.20 C-30 LIGNITE 0.00 2,838.64 2,750.00 C-20 LIGNITE 0.00 3,120.91 2,995.90 C-10 LIGNITE 0.00 4,324.46 3,814.60 K-3 LIGNITE 0.00 5,315.83 4,059.50 K-2 LIGNITE 0.00 7,700.00 4,092.19 Fault 1 0.00 11/12/2019 3:03.17PM Page 9 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 KOP: Start 0.75°/100' DLS, 150 TF, for 200' 700.00 699.98 2.53 0.68 Start 1.5°/100' DLS, 0° TF, for 651.35' 1,351.35 1,346.50 72.41 19.40 Hold for 101.97' 1,453.31 1,446.50 91.66 24.56 Start 2.5°/100' DLS, 101° TF, for 1046.74' 2,500.06 2,446.50 180.32 287.05 Hold for 20' 2,520.06 2,464.43 179.87 295.89 Adjust TF to 0°, for 280' 2,800.06 2,715.49 173.62 419.71 Start 3°/100' DLS, 60.14° TF, for 2430.25' 5,230.31 4,054.98 -1,065.50 1,769.23 Hold for 261.92' 5,492.22 4,068.81 -1,289.70 1,903.94 Start 3°/100' DLS, 85.96° TF, for 12.42' 5,504.64 4,069.47 -1,300.35 1,910.30 Hold for 20' 5,524.64 4,070.51 -1,317.53 1,920.47 Start 1.5°/100' DLS, -0.07° TF, for 168.46' 5,693.10 4,075.62 -1,462.41 2,006.26 Hold for 7358.1' 13,051.20 4,136.37 -7,793.46 5,755.36 Start 1.5°/100' DLS, -8.06° TF, for 31.85' 13,083.05 4,136.50 -7,820.85 5,771.61 Adjust TF to -2.42°, for 102.3' 13,185.35 4,135.13 -7,908.77 5,823.88 Hold for 356.24' 13,541.59 4,125.61 -8,214.77 6,006.03 Start 1.5°/100' DLS, 0.23° TF, for 241.8' 13,783.39 4,111.50 -8,422.17 6,129.46 Hold for 500' 14,283.39 4,066.53 -8,850.13 6,384.07 Adjust TF to 0°, for 500' 14,783.39 4,021.56 -9,278.09 6,638.68 TD: 14783.39' MD, 4021.56' TVD 11/1212019 3:03:17PM Page 10 COMPASS 5000.14 Build 85H ConocoPhillips Alaska Inc_WNS Western North Slope CD4 Nanuq Pad Plan: CD4 -499 CD4 -499 50103xxxxx00 CD4 -499 wp15 ConocoPhillips Clearance Summary Anticollision Report 12 November, 2019 Tmv. Cylinder North Proximity Scan on Current Survey Data (North Reference( Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - CD4 -499 - CD4 -499 wp15 Datum Height: Plan 19+27.5 LID 46.50usft (D141( Scan Range: 0.00 to 14,783.39 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Geodetic Scale FactorApplied Version: 5000.14 Build: 85H Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips t_ ConocoPhiilips Anticollision Report for Plan: CD4 -499 - CD4 -499 wp15 ConocoPhillips Alaska Inc_WNS Western North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - CD4 -499 -CD4-499 wp15 Scan Range: 0.00 to 14,783.39 usft. Measured Depth. Scan Radius Is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 CD4 Nanuq Pad CD4 -03 - CD4 -03 - CD4 -03 CD4 -03 - CD4 -03 - CD4 -03 CD4 -03 - CD4 -03 - CD4 -03 CD4 -05 - CD4 -05 - CD4 -05 C04-05 - CD4 -05 - CD4 -05 CD4 -05 - CD4 -05 - CD4 -05 C04-07 - C04-07 - CD4 -07 CD4 -07 - CD4 -07 - CD4 -07 CD4 -07 - CD4 -07 - CD4 -07 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - Nanuq 5 - Nanuq 5 CD4 -12 - Nanuq 5 - Nanuq 5 CD4 -12 - Nanuq 5 - Nanuq 5 CD4 -208 - CD4 -208 - CD4 -208 CD4 -208 - CD4 -208 - CD4 -208 CD4 -208 - CD4 -208 - CD4 -208 CD4 -208 - CD4 -208A - CD4 -208A CD4 -208 - CD4 -208A - CD4 -208A CD4 -208 - CD4 -208A - CD4 -208A CD4 -208 - CD4-208AL1 - CD4-208AL1 CD4 -208 - CD4-208AL1 - CD4-208AL1 CD4 -208 - CD4-208AL1 - C04-208AL1 CD4 -208 - CD4-208APB1 - CD4-208APB1 490.36 58.38 490.36 54.04 500.00 13.440 Centre Distance Pass - 540.09 58.60 540.09 53.87 550.00 12.411 Ellipse Separation Pass - 688.75 62.66 668.75 57.00 700.00 11.069 Clearance Factor Pass - 315.40 97.82 315.40 94.89 325.00 33.363 Centre Distance Pass - 340.40 97.89 340.40 94.77 350.00 31.381 Ellipse Separation Pass - 858.53 140.67 858.53 133.65 875.00 20.025 Clearance Factor Pass - 115.47 140.00 115.47 138.52 125.00 94.811 Centre Distance Pass - 240.47 140.44 240.47 138.02 250.00 58.184 Ellipse Separation Pass - 957.29 184.91 957.29 178.64 975.00 29.519 Clearance Factor Pass - 564.66 232.64 564.66 228.48 575.00 55.891 Centre Distance Pass - 589.20 232.65 589.20 228.32 600.00 53.774 Ellipse Separation Pass - 2,587.51 1,673.62 2,587.51 1,615.12 3,175.00 28.608 Clearance Factor Pass - 564.66 232.64 564.66 228.48 575.00 55.691 Centre Distance Pass - 589.20 232.65 589.20 228.32 600.00 53.774 Ellipse Separation Pass - / 2,587.51 1,673.62 2,587.51 1,615.12 3,175.00 28.608 Clearance Factor Pass- r✓/ 567.56 232.63 567.56 228.45 575.00 55.630 Centre Distance Pass - 592.12 232.66 592.12 228.31 600.00 53.539 Ellipse Separation Pass - 2,573.08 1,656.88 2,573.08 1,600.68 3,150.00 29.480 Clearance Factor Pass - 27.50 160.49 27.50 159.53 36.15 166.498 Centre Distance Pass - 737.16 161.50 737.16 156.55 750.00 32.623 Ellipse Separation Pass - 2,610.38 1,134.02 2,610.38 1,080.24 2,900.00 21.085 Clearance Factor Pass - 27.50 160.49 27.50 159.53 36.33 166.498 Centre Distance Pass - 736.98 161.50 736.96 156.55 750.00 32.627 Ellipse Separation Pass - 2,606.00 1,134.45 2,606.00 1,080.92 2,900.00 21.191 Clearance Factor Pass - 27.50 160.49 27.50 159.83 36.15 242.491 Centre Distance Pass - 737.16 161.50 737.16 156.85 750.00 34.739 Ellipse Separation Pass - 2,606.14 1,134.56 2,606.14 1,081.22 2,900.00 21.270 Clearance Factor Pass - 27.50 160,49 27.50 159.53 36.33 166.498 Centre Distance Pass - 12 November, 2019 - 15:07 Page 2 of 8 COMPASS ConocoPhillips Anticollision Report for Plan: CD4 -499 - CD4 -499 wp15 ConocoPhillips Alaska Inc_WNS Western North Slope Tray. Cylinder North Proximity ScanonCurrent Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - CD4 -499 - CD4 -499 wp15 Scan Range: 0.00 to 14,783.39 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 CD4 -208 - CD4-208APB1 - CD4-208APB1 736.98 161.50 736.98 156.55 750.00 32.627 Ellipse Separation Pass - CD4 -208 - CD4-208APB1 - CD4-208APB1 2,606.00 1,134.45 2,606.00 1,080.81 2,900.00 21.148 Clearance Factor Pass - CD4 -208 - CD4-208PB1 - CD4-208PB1 27.50 160.49 27.50 159.26 36.15 130.529 Centre Distance Pass - CD4 -208 - C04-208PB1 - CD4-208PB1 737.16 161.50 737.16 156.55 750.00 32.623 Ellipse Separation Pass - CD4 -208 - CD4-208PS1 - CD4-208PB1 2,610.38 1,134.02 2,610.38 1,080.24 2,900.00 21.085 Clearance Factor Pass - CD4 -209 - CD4 -209 - CD4 -209 27.50 180.62 27.50 179.65 37.40 187.376 Centre Distance Pass - CD4 -209 - C04-209 - C04-209 114.40 180.87 114.40 179.45 125.00 127.705 Ellipse Separation Pass - CD4 -209 - CD4 -209 - CD4 -209 2,598.04 851.27 2,598.04 816.73 2,875.00 24.644 Clearance Factor Pass - CD4 -210 - CD4 -210 - CD4 -210 538.60 200.25 538.60 195.63 550.00 43.317 Centre Distance Pass - CD4 -210 - CD4 -210 - CD4 -210 587.97 200.40 587.97 195.41 600.00 40.114 Ellipse Separation Pass - CD4 -210 - CD4 -210 - CD4 -210 926.08 227.40 926.08 219.82 950.00 29.969 Clearance Factor Pass - CD4 -210 - CD4 -210A- CD4 -210A 540.51 200.25 540.51 195.61 550.00 43.182 Centre Distance Pass - CD4 -210 - CD4 -210A- CD4 -210A 589.89 200.42 589.89 195.41 600.00 40.001 Ellipse Separation Pass - CD4 -210 - CD4 -210A- CD4 -210A 927.88 227.82 927.88 220.22 950.00 29.969 Clearance Factor Pass - CD4 -210 - CD4-210APB1 - CD4-210APB1 540.51 200.25 540.51 195.61 550.00 43.182 Centre Distance Pass - CD4 -210 - C04-210APB1 - CD4-210APB1 589.89 200.42 589.89 195.41 600.00 40.001 Ellipse Separation Pass - CD4-210-CD4-210APB1-CD4-210APB1 927.88 227.82 927.88 220.22 950.00 29.969 Clearance Factor Pass - CD4 -210 - C04 -210B - CD4 -2108 540.51 200.25 540.51 195.92 550.00 46.190 Centre Distance Pass - / CD4 -210 - CD4 -2108 - CD4 -2108 589.89 200.42 589.89 195.71 600.00 42.567 Ellipse Separation Pass - J CD4 -210 - CD4 -2108 - CD4 -210B 927.88 227.82 927.88 220.52 950.00 31.209 Clearance Factor Pass - CD4 -211 - CD4 -211 - CD4 -211 687.30 218.25 687.30 212.66 700.00 39.106 Centre Distance Pass - CD4 -211 -CD4 -211 -CD4 -211 711.83 218.34 711.83 212.63 725.00 38.271 Ellipse Separation Pass - CD4 -211 -CD4 -211 -CD4 -211 1,053.12 239.60 1,053.12 232.58 1,075.00 34.144 Clearance Factor Pass - CD4 -211 - CD4 -211 Ll - CD4 -211 L1 687.30 218.25 687.30 212.97 700.00 41.343 Centre Distance Pass - CD4 -211 - CD4 -211 Ll - CD4 -211 Ll 711.83 216.34 711.83 212.94 725.00 40.411 Ellipse Separation Pass - CD4 -211 -CD4 -211 Li -CD4 -211 L1 1,077.31 243.61 1,077.31 236.78 1,100.00 35.662 Clearance Factor Pass - CD4 -211 - CD4 -211 Ll -01 - CD4 -211 L1-01 687.30 218.25 687.30 212.97 700.00 41.343 Centre Distance Pass - CD4 -211 - CD4 -211 Li -01 - CD4 -211 L1-01 711.83 218.34 711.83 212.94 725.00 40.411 Ellipse Separation Pass - CD4 -211 -CD4 -211 Ll -01 -CD4 -211 L1-01 1,077.31 243.61 1,077.31 236.78 1,100.00 35.662 Clearance Factor Pass - CD4 -289 - CD4 -289 - CD4 -289 27.50 199.37 27.50 198.36 36.45 197.243 Centre Distance Pass - 12 November, 2019 - 15:07 Page 3 of 8 COMPASS Conoco hillips Anticollision Report for Plan: CD4 -499 - CD4 -499 wp15 ConocoPhillips Alaska Inc_WNS Western North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - C134-499 - CD4 -499 vvp15 Scan Range: 0.00 to 14,783.39 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft CD4 -289 - CD4 -289 - CD4 -289 668.14 199.47 668.14 195.45 675.00 49.540 Ellipse Separation Pass - CD4 -289 - CD4 -289 - CD4 -289 3,998.07 724.66 3,998.07 679.35 3,800.00 15.992 Clearance Factor Pass - CD4 -290 - CD4 -290 - C04-290 793.19 175.27 793.19 170.34 800.00 35.543 Centre Distance Pass - CD4 -290 - CD4 -290 - CD4 -290 818.24 175.36 818.24 170.29 825.00 34.597 Ellipse Separation Pass - CD4 -290 - CD4 -290 - CD4 -290 4,410.23 369.83 4,410.23 316.90 4,200.00 6.987 Clearance Factor Pass - CD4 -291 - CD4 -291 - CD4 -291 3,874.89 144.81 3,874.89 82.99 3,700.06 2.342 Clearance Factor Pass - CD4 -291 - CD4 -291 - CD4 -291 3,896.47 143.09 3,896.47 82.87 3,725.00 2.376 Ellipse Separation Pass - CD4 -291 - CD4 -291 - CD4 -291 3,917.76 142.57 3,917.76 84.45 3,750.00 2.453 Centre Distance Pass - CD4 -291 - CD4 -291 P81 - CD4 -291 PB1 3,874.89 144.81 3,874.89 82.84 3,700.06 2.337 Clearance Factor Pass - CD4 -291 - C04-291 PB1 - CD4 -291 PBI 3,896.47 143.09 3,896.47 82.72 3,725.00 2.370 Ellipse Separation Pass - CD4 -291 - CD4 -291 PB1 - CD4 -291 PBI 3,917.76 142.57 3,917.76 84.30 3,750.00 2.447 Centre Distance Pass - CD4 -292 - CD4 -292 - CD4 -292 1,194.97 113.87 1,194.97 106.80 1,200.00 16.093 Ellipse Separation Pass - CD4 -292 - C04-292 - CD4 -292 2,611.70 388.91 2,611.70 335.60 2,625.00 7.295 Clearance Factor Pass - CD4 -298 - C04-298 - CD4 -298 316.10 19.66 316.10 16.96 325.00 7.277 Centre Distance Pass - CD4 -298 - C04-298 - CD4 -298 416.10 20.01 416.10 16.55 425.00 5.796 Ellipse Separation Pass - CD4 -298 - CD4 -298 - CD4 -298 541.11 22.30 541.11 17.91 550.00 5.080 Clearance Factor Pass - CD4 -298 - CD4-298PB1 - CD4-298PB1 316.10 19.66 316.10 16.96 325.00 7.277 Centre Distance Pass - CD4 -298 - CD4-298PB1 - CD4-298PB1 416.10 20.01 416.10 16.55 425.00 5.796 Ellipse Separation Pass - CD4 -298 - CD4-298PB1 - CD4-298PB1 541.11 22.30 541.11 17.91 550.00 5.080 Clearance Factor Pass - CD4 -301 - CD4 -301 - CD4 -301 440.26 13.86 440.26 9.99 450.00 3.584 Ellipse Separation Pass - CD4 -301 - CD4 -301 - CD4 -301 465.14 14.24 465.14 10.24 475.00 3.565 Clearance Factor Pass - CD4 -301 -CD4 -301A -CD4 -301A 440.26 13.86 440.26 9.99 450.00 3.584 Ellipse Separation Pass - CD4 -301 -CD4 -301A -CD4 -301A 465.14 14.24 465.14 10.24 475.00 3.565 Clearance Factor Pass - CD4 -301 -CD4 -301B -CD4 -3018 440.26 13.86 440.26 9.99 450.00 3.584 Ellipse Separation Pass - CD4 -301 -CD4 -301B -CD4 -3018 465.14 14.24 465.14 10.24 475.00 3.565 Clearance Factor Pass - CD4 -302 - CD4 -302 - CD4 -302 813.24 17.63 813.24 12.38 825.00 3.355 Ellipse Separation Pass - CD4 -302 - CD4 -302 - CD4 -302 837.83 17.80 837.83 12.41 850.00 3.300 Clearance Factor Pass - CD4 -304 - CD4 -304 - CD4 -304 27.50 80.10 27.50 79.14 36.20 83.099 Centre Distance Pass - CD4 -304 - CD4 -304 - CD4 -304 215.79 81.12 215.79 78.94 225.00 37.203 Ellipse Separation Pass - CD4 -304 - CD4 -304 - CD4 -304 738.77 97.25 738.77 91.19 750.00 16.052 Clearance Factor Pass - Separation Warning 9 12 November, 2019 - 15:07 Page 4 of 8 COMPASS ConocoPhillips Anticollision Report for Plan: CD4 -499 - CD4 -499 wpl5 ConocoPhillips Alaska Inc_WNS Western North Slope Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - CD4 -499 - CD4499 Wp15 Scan Range: 0.00 to 14,783.39 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft CD4 -304 - CD4-304PB1 - CD4-304PB1 27.50 80.10 27.50 79.14 36.20 83.099 Centre Distance Pass - CD4 -304 - CD4-304PS1 - CD4-304PB1 215.79 81.12 215.79 78.94 225.00 37.203 Ellipse Separation Pass - CD4 -304 - CD4-304PB1 - CD4-304PB1 738.77 97.25 738.77 91.19 750.00 16.055 Clearance Factor Pass - CD4 -306 - CD4 -306 - CD4 -306 515.06 117.33 515.06 113.21 525.00 28.487 Centre Distance Pass - CD4 -306 - CD4 -306 - CD4 -306 539.82 117.38 539.82 113.20 550.00 28.020 Ellipse Separation Pass - CD4 -306 - CD4 -306 - CD4 -306 959.12 137.36 959.12 131.23 975.00 22.390 Clearance Factor Pass - CD4 -595 - CD4 -595 - CD4 -595 147.90 79.38 147.90 77.96 150.00 56.131 Centre Distance Pass - CD4 -595 - CD4 -595 - CD4 -595 222.90 79.67 222.90 77.87 225.00 44.169 Ellipse Separation Pass - CD4 -595 -CD4 -595 -CD4 -595 9,822.83 1,673.47 9,822.83 1,486.52 8,400.00 8.951 Clearance Factor Pass - CD4 -595 - CD4-595PH1 - CD4-595PH1 147.90 79.38 147.90 77.82 150.00 50.884 Centre Distance Pass - CD4 -595 - CD4-595PH1 - CD4-595PH1 222.90 79.67 222.90 77.73 225.00 40.865 Ellipse Separation Pass - CD4 -595 - CD4-595PH1 - CD4-595PH1 9,822.83 1,673.47 9,822.83 1,486.31 8,400.00 8.941 Clearance Factor Pass - CD4 -93 -CD4 -93 -CD4 -93 1,300.65 113.76 1,300.65 106.50 1,300.00 15.655 Centre Distance Pass - CD4 -93 - CD4 -93 - CD4 -93 1,325.39 113.83 1,325.39 106.48 1,325.00 15.494 Ellipse Separation Pass - CD4 -93 - CD4 -93 - CD4 -93 1,397.75 115.96 1,397.75 108.32 1,400.00 15.189 Clearance Factor Pass - CD4 -93 - CD4 -93A- CD4 -93A 1,300.12 113.77 1,300.12 106.50 1,300.00 15.660 Centre Distance Pass - CD4 -93 - CD4 -93A- CD4 -93A 1,324.87 113.82 1,324.87 106.48 1,325.00 15.497 Ellipse Separation Pass - CD4 -93 - CD4 -93A- CD4 -93A 1,397.25 115.93 1,397.25 108.30 1,400.00 15.190 Clearance Factor Pass - CD4 -96 -CD4 -96 -CD4 -96 1,090.57 33.22 1,090.57 26.62 1,100.00 5.032 Clearance Factor Pass - CD4 -96 -CD4 -96A -CD4 -96A 1,090.43 33.22 1,090.43 26.62 1,100.00 5.032 Clearance Factor Pass - CD4-96-CD4-96APB1-CD4-96APB1 1,090.43 33.22 1,090.43 26.62 1,100.00 5.032 Clearance Factor Pass - Prelim: CD4 -287 (NEI B) - Plan: CD4 -287 (NEI B) - CD 300.50 240.15 300.50 237.67 300.00 97.159 Centre Distance Pass - Prelim: CD4 -287 (NEI B) - Plan: CD4 -287 (NE1 B) - CD 325.50 240.20 325.50 237.59 325.00 91.938 Ellipse Separation Pass - Prelim: C04-287 (NEI B) - Plan: CD4 -287 (NEI B) - CD 2,602.79 969.47 2,602.79 919.59 2,725.00 19.436 Clearance Factor Pass - Prelim: CD4 -288 (NE3A) - Plan: CD4 -288 (NE3A) - CD 300.50 220.14 300.50 217.66 300.00 89.064 Centre Distance Pass - Prelim: CD4 -288 (NE3A) - Plan: CD4 -286 (NE3A) - CD 325.50 220.21 325.50 217.61 325.00 84.814 Ellipse Separation Pass - Prelim: CD4 -288 (NE3A) - Plan: CD4 -288 (NE3A) - CD 5,260.50 1,671.70 5,260.50 1,623.70 4,275.00 34.829 Clearance Factor Pass - Prelim: CD4 -297 (NWIA) - Plan: CD4 -297 (NWIA) - C 300.50 40.13 300.50 37.66 300.00 16.237 Centre Distance Pass - Prelim: CD4 -297 (NWIA) - Plan: CD4 -297 (NWIA) - C 325.50 40.18 325.50 37.59 325.00 15.516 Ellipse Separation Pass - Prelim: CD4 -297 (NWIA) - Plan: C04-297 (NWIA) - C 10,062.93 1,426.55 10,062.93 1,186.83 8,850.00 5.951 Clearance Factor Pass - Separation Warning 12 November, 2019 - 15.'07 Page 5 of 8 COMPASS ✓ ConocoPhillips Alaska Inc_WNS ConocoPhillips Western North Slope Anticollision Report for Plan: CD4 -499 - CD4 -499 wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) To Survey/Plan (usft) Reference Design: CD4 Nanuq Pad - Plan: CD4 -499 - CD4 -499 - CD4 -499 wp15 27.50 1,400.00 CD4 -499 wp15 Scan Range: 0.00 to 14,783.39 usft. Measured Depth. 2,430.00 C04-499 wp15 1,400.00 2,430.00 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft CD4 -499 wp15 2,530.00 Measured Minimum @Measured Ellipse Site Name Depth Distance Depth Separation Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) Rig: CD4 -594 - CD4 -594 - CD4 -594 wp14v2 125.10 99.44 125.10 97.99 Rig: CD4 -594 - CD4 -594 - CD4 -594 wp14v2 200.10 99.66 200.10 97.86 Rig: CD4 -594 -CD4 -594 -CD4 -594 wp14v2 5,969.62 1,670.79 5,969.62 1,591.08 Rig: CD4-594-CD4-594PH1-CD4-594PH1 125.10 99.44 125.10 97.99 Rig: CD4-594-CD4-594PH1-CD4-594PH1 200.10 99.66 200.10 97.86 Rig: C04-594 - CD4-594PH1 - CD4-594PH1 5,970.24 1,671.21 5,970.24 1,591.62 Survey tool program From To Survey/Plan (usft) (usft) 27.50 1,400.00 CD4 -499 wp15 1,400.00 2,430.00 C04-499 wp15 1,400.00 2,430.00 CD4 -499 wp15 2,430.00 2,530.00 CD4 -499 wp15 2,530.00 4,030.00 CD4 -499 wp15 2,530.00 5,500.00 CD4 -499 wp15 5,500.00 5,600.00 CD4 -499 wp15 5,600.00 7,100.00 CD4 -499 wpi5 5,600.00 14,783.39 CD4 -499 wp15 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles 7 (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. @Measured Clearance Summary Based on Depth Factor Minimum Separation Warning usft 125.00 68.651 Centre Distance Pass - 200.00 55.331 Ellipse Separation Pass - 4,900.00 20.960 Clearance Factor Pass - 125.00 68.651 Centre Distance Pass - 200.00 55.331 Ellipse Separation Pass - 4,900.00 21.000 Clearance Factor Pass - Survey Tool GYD-GC-SS MWD OWSG MWD+IFR2+SAG+MS INC+TREND MWD OWSG MWD+IFR2+SAG+MS INC+TREND MWD OWSG MWD+IFR2+SAG+MS 72 November, 2019 - 15:07 Page 6 of 8 . ,MPASS ConocoPhillips Anticollision Report for Plan: CD4 -499 - CD4 -499 wp15 ConocoPhillips Alaska Inc_WNS Western North Slope Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor $ 134-208,CD4-208AL1,CD4-208AL1V0 $ 134-208, CD4-208APB1,CD4-208APB1 VO 10.00 - - - - -^rb-- 134-208, CD4-208PB1 , CD4-208PB1 V6 134-209, CD4 -209, CD4 -209 V4 C 134-210, CD4 -21 0, CD4 -21 0 V3 8.75',C D4-210, CD4 -210A, CD4 -210A VO D4-210,CD4-210APB1,CD4-210APB1 VO C 134-210, CD4 -210B, CD4 -2106 VO 7.50 134-211, CD4 -2 11, CD4 -211 V2 o -. -+-''.C 134-211, CD4 -211 L1, CD4 -211 L1 V0 6.25 - -- !- - - - -- $'; D4-211,CD4-211L1-01,CD4-211 L1-01 V0 134-289, CD4 -289, CD4 -289 VO m '.., '.. $ D4 -29Q CD4 -290, CD4 -290V0 LL c: 5.00- 134-291, CD4 -291, CD4 -291 VO --- - ., -- - - -$--.C 134-291, CD4 -291 PB1, CD4-291PB1 V0 CoC 134-292, CD4-292,CD4-292V0 rn 3.75 -}-' 134-298, CD4-298,CD4-298V0 Normal Operations -E�-_ D4-298,CD4-298PB1,CD4-298PB1V0 Caution Monitor Closely $_ 134-301, CD4 -301, CD4301 V0 2.50 _---.-,- ---....` _ --_-'_- - --' ' ___:` - ____-.- -- __-_ _ . - _.. _ _ __- _ - - - $� D4301,CD4-301A,CD4-301AV0 Take Immediate Action $ 134301, CD4 -301 B, CD4 -3011B V0 D4302,CD4-302,CD4-302V3 1.25 STOP Drilling ----- ----C 134-304, CD4 -304, CD4 -304 V6 - $'', D4304,CD4304PB1,CD4 304PB1V16 0.00 D4306, CD4306, CD4 -306 V 1 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 1201' 134-595, CD4 -595, CD4 -595 V0 Mewed Depth (2000 tsWr1) 134-595, CD4595PH1, CD4595PH1 V0 12 November, 2019 - 15:07 Page 8 of 8 COMPASS 15:09, November 12 2019 CD4 -499 wp15 Lddder View C� a 3 3 La W 2 m 0] Qpz N IT co N it Ft �T IY � LF 300 — - -- --- — -- - - - --- g I 'I li X150 U II { 0) ` U Equivalent Magnetic Distance 0 0 2000 4000 6000 8000 10000 Measured Depth SURVEY PROGRAM CASING DETAILS pth From Depth To Survey/Plan Tool TWD MD Nam 27.50 1400.00 CD4 -499 wp15 (CD4 -499) GYD-GC-SS 2390.00 2437.42 10 3/4 x 13 1/2 1400.00 2430.00 CD4 -499 wp15 (CD4 -499) MWD OWSG 4069.47 5504.64 7 x 8-3/4 1400.00 2430.00 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS 4021.56 14783.39 4 1/2 x 6 1/8 2430.00 2530.00 CD4 -499 wp15 (CD4 -499) INC+TREND 2530.00 4030.00 CD4 -499 wp15 (CD4 -499) MWD OWSG 2530.00 5500.00 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS 5500.00 5600.00 CD4 -499 wp15 (CD4 -499) INC+TREND 5600.00 7100.00 CD4 -499 wp15 (CD4 -499) MWD OWSG 5600.0014783.39 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS a zm C1 m o 00 N Q co r �mmco OO (O O , 60 i o m Q 0 f i r 30 230— U C-) ' Equivalent Magnetic Distant 0 0 400 800 1200 1600 2000 Partial Measured Depth 14:24, N— 6, 06 2019 CD4 -499 wp15 27.50 To 14783.39 Spider C 4.07 NLY LT iderj o 2D � -304 CD4 -208 fD4- 018 C � h o 208P8 30 h� h u1 0 PO4-301 c_ 70 y 2 o �p -,,nA-qnl 0 5 v v � 5 4 01 o c 0 b S `Q 5 4 C 2 �0 55 5 0 a z S 6 bo O 5 4_-59CD4- �4- 6 -209 K2' \IT CD X93 5 � C O 4-4 w a8 _2 (N t)4-288 P81 EA w 1 D4-2 OB _ D4- 4 wp14 2 CD4 -96 PB1 CD4- OAPB D4-20 Easting (4500 usft/in) P81 EA w 1 D4-2 OB _ D4- 4 wp14 2 CD4 -96 PB1 CD4- OAPB D4-20 C 4-210A CD4 -499 wp15 27.50 To 14783-39 r-MMUNIN,■■M■ M■■■■MER ■kinzb. ■■■ v MA M — I ■■■rlMEMO9 1 11, 11-114, iii■■F/J- rte: ' , ' y' 1 ! , ,\\ ,I �'��■ 10 ■■■ & M \�■Lmm ■■!!■■ -IMMEMENMEMEMMMEME410%, mokul 14 29, November 06 2019 CD4 -499 wp15 27.50 To 14783.39 Spider wells_, ONLY __f�,AC c o�&PB o N NOT a Spider) o ry N �y N � N � O o a n n o N CD4 -28 O N 30 95 O h h a -302 � a �'O S 20 0 RS 55 N 4 50 � rn c 45 20 5 5 a Z 0 50 2 0 "� CD4 2 3A) w S 3 g D-20 0 \1,rl S B�APB 35 4 C 6 �g 21O�AP f 2 0 CD4 -29 Eastin9 (450 usfVin) 14:74, Novertd:er O6 -19 CD4 -499 wp15 27.50 To 14783.39 Spider AC wells ONLY (NOT a Spider) ^6 74 a v N �2 N 0 N 0000� d O 12 N O N � 12 10 >r 4 N - 99 wp1 r o m o z s tia 2 B m y o 0 6a � � N 1 CR4- �9 v NCD4- 3A) w 1 LO a m10PIM-302 0 0 N N 12 412 4-29 B81 Easting (80 usft/in) November 12 2019= CD4 -499 wp 15 FC View From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 27.50 1400.00 GYD-GC-SS 27.50 0.00 0.00 27.50 0.00 0.00 1400.00 2430.00 MWD OWSG 500.00 0.00 0.00 500.00 0.00 0.00 KOP: Start 0.75%100' DLS, 151TF, for 200' 1400.00 2430.00 MWD+IFR2+SAG+MS 700.00 1.50 15.00 699.98 0.75 15.00 Start 1.5%100' DLS, 0°TF, for 651.35' 2430.00 2530.00 INC+TREND 1351.35 11.27 15.00 1346.50 1.50 0.00 Hold for 101.97' 2530.00 4030.00 MWD OWSG 1453.31 11.27 15.00 1446.50 0.00 0.00 Start 2.51/100' DLS, 101 'TF, for 1046.74' 2530.00 5500.00 MWD+IFR2+SAG+MS 2500.06 26.28 92.89 2446.50 2.50 101.00 Hold for 20' 5500.00 5600.00 INC+TREND 2520.06 26.28 92.89 2464.43 0.00 0.00 Adjust TF to 01, for 280' 5600.00 7100.00 MWD OWSG 2800.06 26.28 92.89 2715.49 0.00 0.00 Start 3%100' DLS, 60.14°TF, for 2430.25' 5600.0014783.39 MWD+IFR2+SAG+MS 5230.31 86.97 149.00 4054.98 3.00 60.14 Hold for 261.92' 5492.22 86.97 149.00 4068.81 0.00 0.00 Start 3%100' DLS, 85.96°TF, for 12.42' 5504.64 87.00 149.37 4069.47 3.00 85.96 Hold for 20' 5524.64 87.00 149.37 4070.51 0.00 0.00 Start 1.51100' DLS, -0.07°TF, for 168.46' 5693.10 89.53 149.37 4075.62 1.50 -0.07 Hold for 7358.1' 13051.20 89.53 149.37 4136.37 0.00 0.00 Start 1.5%100' DLS, -8.06°TF, for 31.85' 13083.05 90.00 149.30 4136.50 1.50 -8.06 CD4 -499 Tgt 1 103119 Adjust TF to -2.421, for 102.3' 13185.35 91.53 149.24 4135.13 1.50 -2.42 Hold for 356.24' 13541.59 91.53 149.24 4125.61 0.00 0.00 Start 1.51100' DLS, 0.23°TF, for 241.8' 13783.39 95.16 149.25 4111.50 1.50 0.23 CD4 -499 Tgt 2 103119 Hold for 500' 14283.39 14783.39 95.16 95.16 149.25 4066.53 149.25 4021.56 0.00 0.00 0.00 0.00 Adjust TF to 0°, for 500' TD: 14783.39' MD, 4021.56' TVD CASING DETAILS TVD MD Name 2390.00 2437.42 10 3/4 x 13 1/2 4069.47 5504.64 7 x 8-3/4 4021.56 14783.39 41/2 x 6 1/8 0 D4-93 180 330' 64 30 80 150 27 300 1491 300 490 12 98 490 670 00 670 860 D4-30 90 201098 60 860 1040 ;D4-30 ? 998 1040 1230 60 m D4-594 wp14v 0 _ __ 1410 D4-0 ', 18 1 1410 1600 0 1 085 92 1600 2150 3 8 86 g3 2150 2700 8 7 0 Q� 2700 3250 7 r �� ova 4-291 gfi 3250 3800 6 95 39 3800 4350 f \ 8 89 07 g 77 D4-594PH 50 -� 4900 D4-20 83 6 17 270 00 5450 39 7 D4-29 50 6000 _ 83 2 )4-05 00 7100 75 07 240 082 120 D4-59 00 8200 76 3- 5 76 4 00 4 9290 12 9290 1039 D4-20 58fi D4 -3o 10390 1149 11490 1259 3 1 0 210 D4-29 1369 4-297 (W1A) wp0�90 DN 90 __ _ _ 1478 _ D4-03 - - D4 -g 0 D4-301 180 15:14, November: 12 W19 CD4 -499 wp15 27.50 To 1000.00 AC Flipbook SURVEY PROGRAM 0 27 300 300 490 Depth From Depth To Tool 27.50 1400.00 GYD-GC-SS 1400.00 2430.00 MWD OWSG 1400.00 2430.00 MWD+IFR2+SAG+M 3 90 490 670 2430.00 2530.00 INC+TREND 2530.00 4030.00 MWD OWSG 330 30 670 860 2530.00 5500.00 MWD+IFR2+SAG+M 3 5500.00 5600.00 INC+TREND 5600.00 7100.00 MWD OWSG ______ 860 1040 5600.0014783.39 MWD+IFR2+SAG+M 1040 .. -- _._ 1230 60 1230 1410 300 60 D4-9 D4-59 1410 1600 1600 2150 CASING DETAILS TVD MD Nam 2390.00 2437.42 10 3/4 x 13 1/2 3 2150 2700 4069.47 5504.64 7 x 8-3/4 4021-56 14783.39 41/2x61/8 _ 00 �98 9j1i 2700 3250 3250 3800 MD Azi TFace 270 00 90 27.50 0.00 0.00 y 'rr 3800 4350 500.00 0.00 0.00 0 fan 700.00 15.00 15.00 ' 90 4350 4900 1351.35 15.00 0.00 1453.31 15.00 0.00 90 79 D D4-30 291 98� 4900 - - 5450 2500.06 92.89 101.00 90 330 2520.06 92.89 0.00 6 9 D4-29 5450 6000 2800.06 92.89 0.00 5 5230.31 149.00 60.14 895 6000 7100 5492.22 149.00 0.00 240 120 5504.64 149.37 85.96 7 6 8 3 71 00 8200 5524.64 149.37 0.00 5693.10 149.37 -0.07 60 04-297 (NW1A) wP0 8200 9290 13051.20 149.37 0.00 13083.05 149.30 -8.06 8 3 9290 10390 13185.35 149.24 -2.42 13541.59 149.24 0.00 D4-301 10390 11490 13783.39 149.25 0.23 D4-03 0 210 150 14283.39 149.25 0.00 90 11490 12590 14783.39 149.25 0.00 180 12590 13690 13690 14783 CD4 -499 wp15 � 900.00 to 2600.00 1 AC Flipbook Depth From Depth To Tool 27.50 1400.00 GYD-GC-SS 1400.00 2430.00 MWD OWSG 1400.00 2430.00 MWD+IFR2+f 2430.00 2530.00 INC+TREND 2530.00 4030.00 MWD OWSG 2530.00 5500.00 MWD+IFR2+: 5500.00 5600.00 INC+TREND 5600.00 7100.00 MWD OWSG 5600.00 14783.39 MWD+IFR2+; 2390.00 2437.42 10 3/4 x 13 1/2 4069.47 5504.64 7 x 8-3/4 4021.56 14783.39 4 1/2 x 6 1/8 MD Azi TFace 27.50 0.00 0.00 500.00 0.00 0.00 700.00 15.00 15.00 1351.35 15.00 0.00 1453.31 15.00 0.00 2500.06 92.89 101.00 2520.06 92.89 0.00 2800.06 92.89 0.00 5230.31 149.00 60.14 5492.22 149.00 0.00 5504.64 149.37 85.96 5524.64 149.37 0.00 5693.10 149.37 -0.07 13051.20 149.37 0.00 13083.05 149.30 -8.06 13185.35 149.24 -2.42 13541.59 149.24 0.00 13783.39 149.25 0.23 14283.39 149.25 0.00 14783.39 149.25 0.00 270 1 180 27 300 300--- 490 490 670 670 860 860-1040 1040-- 1230 1230 1410 1410 1600 1600 2150 2150 2700 2700 3250 3250 3800 90 3800 4350 4350 4900 4900 _._.._ 5450 5450 6000 D4"29� 6000 7100 7100 --- 8200 8200 9290 9290 10390 10390 11490 11490 12590 12590 13690 13690 14783 15'17, November 12 2019 CD4 -499 wp15 2500.00 To 14783.00 AC Flipbook SURVEY PROGRAM 27 _ 300 __ Depth FromDepth To Tool 27.50 1400.00 GYD-GC-SS Q 300 490 1400.00 2430.00 MWD OWSG 1400.00 2430.00 MWD+IFR2+SAG+M 270 490 670 2430.00 2530.00 INC+TREND 2530.00 4030.00 MWD OWSG 330 30 670 860 2530.00 5500.00 MWD+IFR2+SAG+M 5500.00 5600.00 INC+TREND ____ 5600.00 7100.00 MWD OWSG 860 1040 5600.0014783.39 MWD+IFR2+SAG+M D4-291 1040 -1230 18 1230 1410 3QQ,� 60 ' 41816 1410 1600 1600 2150 CASING DETAILS TVD MD Nam 9 2390.00 2437.42 10 3/4 x 13 1/2r� 2150 2700 4069.47 5504.64 7 x 8-3/4 4021.56 14783.39 4 1/2 x 6 1/8 41 2706 3256 i 3250 3800 Mo Azo TFace 90 27.50 0.00 0.00 - 4(}9' 3800 4350 500.00 0.00 0.00 700.00 15.00 15.00 4350 4900 1351.35 15.00 0.00 � 3 1453.31 15.00 0.00 4900---_. 5450 2500.06 92.89 101.00 jl 2520.06 92.89 0.00 5450 - 6000 2800.06 92.89 0.00 3 75 5230.31 149.00 60.14 t 6000 7100 5492.22 149.00 0.00 240 120 5504.64 149.37 85.96 7100 8200 5524.64 149.37 0.00 8 5693.10 149.37 -0.07 6 8200 9290 13051.20 149.37 0.00 13083.05 149.30 -8.06 5 9290 10390 13185.35 149.24 -2.42 13541.59 149.24 0.00 4 10390 11490 13783.39 149.25 0.23 210 150 14283.39 149.25 0.00 7 3 11490 12590 14783.39 149.25 0.00 180 12590 13690 13690 --_ 14783 ConocoPhillips Alaska Inc_WNS Western North Slope CD4 Nanuq Pad Plan: C134-499 50103xxxxx00 CD4 -499 Plan: CD4 -499 wp15 Error Ellipse Survey Report 12 November, 2019 Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wpl5 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: CD4 -499 TVD Reference: Plan 19+27.5 @ 46.50usft (D141) MD Reference: Plan 19+27.5 @ 46.50usft (D141) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: EDT 14 Alaska Production 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 Wellbore CD4 -499 Magnetics Model Name Sample Date BGGM2018 12/31/2019 Design CD4 -499 wp15 Audit Notes Declination (°) 15.87 Ground Level: Dip Angle (°) 80.71 Version: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 144.42 19.00 usft Field Strength (nT) 57.361 Survey Tool Program Date 11/12/2019 Site CD4 Nanuq Pad To Site Position: (usft) From: Map Description Position Uncertainty: 1,400.00 CD4 -499 wp15 (CD4 -499) 0.00 usft Gyrodata gyro single shots 1,400.00 2,430.00 CD4 -499 wp15 (CD4 -499) MWD OWSG OWSG MWD - Standard 1,400.00 Well Plan: CD4 -499 OWSG MWD + IFR2 + Sag + Multi -Station Correction Well Position +N/ -S 0.00 usft Inclinometer+ known azi trend +E/ -W 0.00 usft Position Uncertainty OWSG MWD - Standard 0.00 usft Wellbore CD4 -499 Magnetics Model Name Sample Date BGGM2018 12/31/2019 Design CD4 -499 wp15 Audit Notes Declination (°) 15.87 Ground Level: Dip Angle (°) 80.71 Version: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 144.42 19.00 usft Field Strength (nT) 57.361 Survey Tool Program Date 11/12/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 27.50 1,400.00 CD4 -499 wp15 (CD4 -499) GYD-GC-SS Gyrodata gyro single shots 1,400.00 2,430.00 CD4 -499 wp15 (CD4 -499) MWD OWSG OWSG MWD - Standard 1,400.00 2,430.00 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 2,430.00 2,530.00 CD4 -499 wp15 (CD4 -499) INC+TREND Inclinometer+ known azi trend 2,530.00 4,030.00 CD4 -499 wp15 (CD4 -499) MWD OWSG OWSG MWD - Standard 2,530.00 5,500.00 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 5,500.00 5,600.00 CD4 -499 wp15 (CD4 -499) INC+TREND Inclinometer+ known azi trend 5,600.00 7,100.00 CD4 -499 wpl5 (CD4 -499) MWD OWSG OWSG MWD - Standard 5,600.00 14,783.39 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 11/1212019 3,18 32PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well Plan: CD4 -499 Project: Western North Slope TVD Reference: Plan 19+27.5 @ 46.50usft (D141) Site: CD4 Nanuq Pad MD Reference: Plan 19+27.5 @ 46.50usft (D141) Well: and bias at survey station Plan: CD4 -499 North Reference: True Wellbore: CD4 -499 Survey Calculation Method: Minimum Curvature Design: CD4 -499 wpl5 Output errors are at 2.00 sigma Vertical 1(ighside Database: EDT 14 Alaska Production Vertical Magnitude Semi -major Semi-rninor Plan Survey Tool Program Date 11/1212019 Depth Depth From Depth To Error Bias Error (usft) (usft) Survey (Wellbore) Tool Name Remarks of Bias 1 27.50 1,400.00 CD4 -499 wp15 (CD4 -499) GYD-GC-SS (usft) (°) (°) (usft) Gyrodata gyro single shots (usft) 2 1,400.00 2,430.00 CD4 -499 wpl5 (CD4 -499) MWD OWSG (usft) (usft) (usft) (°) OWSG MWD - Standard 27.50 3 1,400.00 2,430.00 CD4 -499 wpl5 (CD4 -499) MWD+IFR2+SAG+MS 0.00 0.00 0.00 0.00 OWSG MWD + IFR2 + Sag + 0.00 4 2,430.00 2,530.00 CD4 -499 wp15 (CD4 -499) INC+TREND 100.00 0.00 0.00 100.00 Inclinometer + known azi tren( 0.00 5 2,530.00 4,030.00 CD4 -499 wpl5 (CD4 -499) MWD OWSG 0.00 0.10 0.10 0.00 OWSG MWD - Standard 200.00 6 2,530.00 5,500.00 CD4 -499 wpl5 (CD4 -499) MWD+IFR2+SAG+MS 0.00 0.39 0.00 2.30 OWSG MWD + IFR2 + Sag + 0.00 7 5,500.00 5,600.00 CD4 -499 wpl5 (CD4 -499) INC+TREND 300.00 0.00 0.00 300.00 Inclinometer + known azi tren( 0.00 8 5,600.00 7,100.00 CD4 -499 wpl5 (CD4 -499) MWD OWSG 0.01 0.68 0.68 0.00 OWSG MWD - Standard 400.00 9 5,600.00 14,783.39 CD4 -499 wp15 (CD4 -499) MWD+IFR2+SAG+MS 0.00 0.97 0.00 2.30 OWSG MWD + IFR2 + Sag + 0.02 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical 1(ighside Lateral Vertical Magnitude Semi -major Semi-rninor 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) (°) 27.50 0.00 0.00 27.50 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 0.10 0.00 0.10 0.00 2.30 0.00 0.00 0.10 0.10 0.00 GYD-GC-SS(1, 1) 200.00 0.00 0.00 200.00 0.39 0.00 0.39 0.00 2.30 0.00 0.00 0.39 0.39 0.00 GYD-GC-SS(1, 1) 300.00 0.00 0.00 300.00 0.68 0.00 0.68 0.00 2.30 0.01 0.01 0.68 0.68 0.00 GYD-GC-SS(1, 1) 400.00 0.00 0.00 400.00 0.97 0.00 0.97 0.00 2.30 0.02 0.02 0.97 0.97 0.00 GYD-GC-SS (1, 1) 500.00 0.00 0.00 500.00 1.26 0.00 1.26 0.00 2.31 0.03 0.03 1.26 1.26 0.00 GYD-GC-SS (1, 1) 600.00 0.75 15.00 600.00 1.55 0.00 1.55 0.00 2.31 0.04 0.04 1.55 1.55 135.00 GYD-GC-SS (1, 1) 700.00 1.50 15.00 699.98 1.84 0.00 1.84 0.00 2.32 0.06 0.06 1.84 1.84 135.00 GYD-GC-SS (1, 1) 800.00 3.00 15.00 799.90 2.12 0.00 2.13 0.00 2.32 0.08 0.08 2.13 2.13 105.60 GYD-GC-SS (1, 1) 900.00 4.50 15.00 899.68 2.41 -0.01 2.42 0.00 2.33 0.10 0.10 2.42 2.42 106.52 GYD-GC-SS (1, 1) 1,000.00 6.00 15.00 999.26 2.70 -0.01 2.71 0.00 2.33 0.12 0.12 2.71 2.71 12.89 GYD-GC-SS (1, 1) 1,100.00 7.50 15.00 1,098.56 2.98 -0.01 3.02 0.00 2.34 0.15 0.15 3.02 3.01 14.33 GYD-GC-SS (1, 1) 1,200.00 9.00 15.00 1,197.52 3.27 -0.02 3.33 0.00 2.34 0.18 0.18 3.33 3.30 14.58 GYD-GC-SS (1, 1) 1,300.00 10.50 15.00 1,296.08 3.56 -0.02 3.66 0.00 2.35 0.21 0.21 3.66 3.60 14.69 GYD-GC-SS(1, 1) 1,351.35 11.27 15.00 1,346.50 3.71 -0.02 3.83 0.00 2.35 0.23 0.23 3.83 3.76 14.72 GYD-GC-SS(1, 1) 1,400.00 11.27 15.00 1,394.21 3.86 -0.02 3.99 0.00 2.36 0.24 0.24 3.99 3.91 14.75 GYD-GC-SS(1, 1) 1,453.31 11.27 15.00 1,446.50 3.94 -0.02 4.09 0.00 2.76 0.00 0.02 4.09 4.00 14.74 MWD OWSG (1, 2) 1,500.00 11.11 20.96 1,492.30 3.95 -0.02 4.11 0.00 2.79 0.00 0.02 4.11 4.01 14.44 MWD OWSG (1, 2) 11/1212019 3:18.32PM Page 3 COMPASS 5000.14 Build 85H Company: ConocoPhiilipsAlaska Inc WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wpl5 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: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production 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) (°) 1°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 1,600.00 11.16 33.93 1.590.43 4.01 -0.02 4.22 0.01 2.87 0.00 0.02 4.24 4.05 17.83 MWD OWSG (1, 2) 1,700.00 11.75 46.19 1,688.46 4.11 -0.02 4.40 0.01 2.94 0.00 0.02 4.44 4.14 24.30 MWD OWSG (1, 2) 1,800.00 12.80 56.88 1,786.18 4.27 -0.02 4.65 0.02 3.02 0.00 0.02 4.73 4.26 31.82 MWD OWSG (1, 2) 1,900.00 14.22 65.72 1,883.42 4.46 -0.02 4.99 0.02 3.10 0.00 0.02 5.12 4.42 39.43 MWD OWSG (1, 2) 2,000.00 15.90 72.87 1,979.99 4.69 -0.01 5.43 0.02 3.18 0.00 0.02 5.61 4.61 46.74 MWD OWSG (1, 2) 2,100.00 17.77 78.61 2,075.71 4.94 -0.01 5.99 0.02 3.27 0.00 0.02 6.21 4.83 53.51 MWD OWSG (1, 2) 2,200.00 19.77 83.26 2,170.40 5.22 -0.01 6.69 0.02 3.36 0.00 0.02 6.96 5.08 59.64 MWD OWSG (1, 2) 2,300.00 21.87 87.07 2,263.87 5.52 -0.01 7.56 0.02 3.46 0.00 0.02 7.86 5.35 65.08 MWD OWSG (1, 2) 2,400.00 24.05 90.23 2,355.94 5.84 -0.01 8.60 0.02 3.58 0.00 0.02 8.93 5.64 69.87 MWD OWSG (1, 2) 2,437.42 24.88 91.28 2,390.00 5.46 -0.02 18.53 0.02 2.63 0.72 0.79 18.53 5.81 92.33 INC+TREND (2,3) 2,465.27 25.50 92.02 2,415.20 5.46 -0.02 18.53 0.02 2.63 0.72 0.79 18.53 5.81 92.33 INC+TREND (2,3) 2,500.00 26.28 92.89 2,446.45 5.46 -0.02 16.53 0.02 2.63 0.72 0.79 18.53 5.81 92.33 INC+TREND (2,3) 2,500.06 26.28 92.89 2,446.50 5.46 -0.02 18.53 0.02 2.63 0.72 0.79 18.53 5.81 92.33 INC+TREND (2,3) 2,520.06 26.28 92.89 2,464.43 5.56 -0.02 25.19 0.02 2.66 0.73 0.80 25.19 5.89 92.60 INC+TREND (2,3) 2,600.00 26.28 92.89 2,536.11 5.88 -0.02 38.86 0.02 3.75 0.01 0.03 38.86 6.24 92.76 MWD OWSG (2,4) 2,700.00 26.28 92.89 2,625.78 5.91 -0.02 38.97 0.02 3.84 0.01 0.03 38.97 6.28 92.74 MWD OWSG (2,4) 2,800.00 26.28 92.89 2,715.44 5.98 -0.02 39.14 0.02 3.95 0.01 0.03 39.14 6.35 92.71 MWD OWSG (2,4) 2,800.06 26.28 92.89 2,715.49 5.98 -0.02 39.14 0.02 3.95 0.01 0.03 39.14 6.35 92.71 MWD OWSG (2.4) 2,838.64 26.87 95.11 2,750.00 6.94 -0.02 39.20 0.02 4.07 0.01 0.03 39.40 6.44 92.71 MWD OWSG (2.4) 2,900.00 27.89 98.46 2,804.49 6.94 -0.02 39.20 0.02 4.07 0.01 0.03 39.40 6.44 92.71 MWD OWSG (2,4) 3,000.00 29.69 103.43 2,892.13 8.77 -0.02 39.08 0.02 4.19 0.01 0.03 39.74 6.57 92.77 MWD OWSG (2,4) 3,100.00 31.67 107.86 2,978.15 10.69 -0.02 38.89 0.02 4.33 0.01 0.03 40.20 6.75 92.93 MWD OWSG (2,4) 3,120.91 32.10 108.73 2,995.90 12.42 -0.02 38.73 0.02 4.48 0.01 0.03 40.79 7.00 93.23 MWD OWSG (2,4) 3,200.00 33.78 111.81 3,062.28 12.42 -0.02 38.73 0.02 4.48 0.01 0.03 40.79 7.00 93.23 MWD OWSG (2,4) 3,300.00 36.00 115.34 3,144.31 13.90 -0.01 38.68 0.02 4.66 0.01 0.03 41.51 7.36 93.70 MWD OWSG (2,4) 3,400.00 38.31 118.50 3,224.02 15.12 -0.01 38.81 0.02 4.86 0.01 0.03 42.38 7.85 94.36 MWD OWSG (2.4) 3,500.00 40.70 121.35 3,301.17 16.08 -0.01 39.16 0.02 5.08 0.01 0.03 43.41 8.50 95.24 MWD OWSG (2.4) 3,600.00 43.16 123.93 3,375.57 16.82 -0.01 39.78 0.02 5.34 0.01 0.03 44.61 9.30 96.35 MWD OWSG (2,4) 3,700.00 45.67 126.29 3,447.00 17.35 -0.01 40.68 0.02 5.63 0.01 0.03 46.00 10.24 97.68 MWD OWSG (2,4) 3,800.00 48.22 128.44 3,515.27 17.70 -0.01 41.89 0.02 5.95 0.01 0.03 47.57 11.29 99.23 MWD OWSG (2,4) 3,900.00 50.81 130.44 3,580.20 17.89 -0.01 43.40 0.02 6.30 0.01 0.03 49.35 12.43 100.96 MWD OWSG (2,4) 4,000.00 53.43 132.29 3,641.60 17.94 -0.01 45.21 0.02 6.69 0.01 0.03 51.34 13.62 102.86 MWD OWSG (2,4) 4,100.00 56.08 134.02 3,699.31 16.07 -0.01 34.24 0.02 6.03 0.01 0.03 42.30 10.62 96.65 MWD+IFR2+SAG+MS (3,4) 4,200.00 58.75 135.64 3,753.17 15.66 -0.01 34.47 0.02 6.28 0.01 0.03 42.87 11.39 97.56 MWD+IFR2+SAG+MS (3,4) 4,300.00 61.44 137.17 3,803.03 15.15 -0.01 34.83 0.02 6.55 0.01 0.03 43.48 12.22 98.58 MWD+1FR2+SAG+MS (3,4) 4,324.46 62.10 137.54 3,814.60 14.56 -0.01 35.31 0.02 6.83 0.01 0.03 44.14 13.07 99.70 MWD+IFR2+SAG+MS (3,4) 4,400.00 64.14 138.63 3,848.76 14.56 -0.01 35.31 0.02 6.83 0.01 0.03 44.14 13.07 99.70 MWD+IFR2+SAG+MS (3,4) 4,500.00 66.86 140.02 3,890.22 13.91 -0.01 35.91 0.02 7.12 0.01 0.03 44.86 13.96 100.91 MWD+IFR2+SAG+MS (3,4) 4,600.00 69.59 141.36 3,927.31 13.21 -0.01 36.61 0.02 7.43 0.01 0.03 45.62 14.86 102.22 MWD+IFR2+SAG+MS (3,4) 4,700.00 72.33 142.65 3,959.93 12.48 -0.01 37.41 0.02 7.74 0.01 0.03 46.44 15.76 103.60 MWD+IFR2+SAG+MS (3, 4) 4,800.00 75.08 143.90 3,987.98 11.77 -0.01 38.29 0.02 8.07 0.01 0.03 47.30 16.66 105.04 MWD+IFR2+SAG+MS (3, 4) 4,900.00 77.84 145.12 4,011.39 11.11 -0.01 39.24 0.02 8.40 0.01 0.03 48.21 17.55 106.53 MWD+IFR2+SAG+MS (3,4) 5,000.00 80.60 146.31 4,030.10 10.53 -0.01 40.25 0.02 8.74 0.01 0.03 49.15 18.41 108.06 MWD+IFR2+SAG+MS (3,4) 5,100.00 83.37 147.49 4,044.04 10.09 -0.01 41.30 0.02 9.08 0.01 0.03 50.14 19.25 109.61 MWD+IFR2+SAG+MS (3,4) 5,200.00 86.13 148.65 4,053.19 9.85 -0.01 42.39 0.02 9.43 0.01 0.03 51.16 20.06 111.16 MWD+IFR2+SAG+MS (3,4) 5,230.31 86.97 149.00 4,054.98 9.82 -0.01 42.72 0.02 9.54 0.01 0.03 51.47 20.30 111.63 MWD+IFR2+SAG+MS (3, 4) 5,300.00 86.97 149.00 4,058.66 10.07 -0.01 43.85 0.02 9.78 0.01 0.03 52.21 20.84 112.71 MWD+IFR2+SAG+MS (3,4) 5,315.83 86.97 149.00 4,059.50 10.42 -0.01 45.50 0.02 10.15 0.01 0.03 53.32 21.58 114.25 MWD+IFR2+SAG+MS (3,4) 5,400.00 86.97 149.00 4,063.94 10.42 -0.01 45.50 0.02 10.15 0.01 0.03 53.32 21.58 114.25 MWD+IFR2+SAG+MS (3,4) 5,492.22 86.97 149.00 4,068.81 10.76 -0.01 47.05 0.02 10.49 0.01 0.03 54.39 22.22 115.65 INC+TREND (3, 5) 5,500.00 86.99 149.23 4,069.22 10.88 -0.01 47.20 0.02 10.53 0.11 1.85 54.63 22.27 115.77 INC+TREND (3,5) 5,504.64 87.00 149.37 4,069.47 10.98 -0.01 47.29 0.01 10.55 0.16 2.95 54.77 22.29 115.85 INC+TREND (3, 5) 5,524.64 87.00 149.37 4,070.51 12.03 -0.01 51.57 0.01 11.64 0.16 2.96 57.52 24.74 120.00 MWD OWSG (3.6) 5,600.00 88.13 149.37 4,073.71 17.32 -0.04 70.25 0.02 17.18 0.04 0.04 72.60 30.95 133.18 MWD OWSG (3.6) 11/12/2019 3:18:32PM Page 4 COMPASS 5000.14 Build 85H Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 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: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Measured trtetination Azimuth Vertical Highside Lateral Vertical Magnitude Semi+najor Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (us(t) t°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) 5,693.10 89.53 149.37 4,075.62 17.24 -0.04 70.91 0.02 17.21 0.04 0.04 73.24 30.98 133.36 MWD OWSG (3,6) 5,700.00 89.53 149.37 4,075.67 17.24 -0.04 70.97 0.02 17.21 0.04 0.04 73.29 30.98 133.38 MWD OWSG (3,6) 5,800.00 89.53 149.37 4,076.50 17.31 -0.04 71.97 0.02 17.28 0.04 0.04 74.24 31.07 133.70 MWD OWSG (3,6) 5,900.00 89.53 149.37 4,077.32 17.41 -0.04 73.23 0.02 17.38 0.04 0.04 75.42 31.19 134.14 MWD OWSG (3, 6) 6,000.00 89.53 149.37 4,078.15 17.55 -0.04 74.75 0.02 17.52 0.04 0.04 76.84 31.35 134.66 MWD OWSG (3,6) 6,100.00 89.53 149.37 4,078.98 17.72 -0.04 76.49 0.02 17.69 0.04 0.04 78.48 31.53 135.24 MWD OWSG(3,6) 6,200.00 89.53 149.37 4,079.80 17.92 -0.04 78.46 0.02 17.89 0.04 0.04 80.33 31.73 135.87 MWD OWSG (3.6) 6,300.00 89.53 149.37 4,080.63 18.16 -0.04 80.63 0.02 18.13 0.04 0.04 82.37 31.94 136.52 MWD OWSG (3.6) 6,400.00 89.53 149.37 4,081.45 18.42 -0.04 82.98 0.02 18.39 0.04 0.04 84.61 32.17 137.19 MWD OWSG (3,6) 6,500.00 89.53 149.37 4,082.28 18.71 -0.04 85.51 0.02 18.69 0.04 0.04 87.02 32.39 137.85 MWD OWSG (3,6) 6,600.00 89.53 149.37 4,083.10 19.04 -0.04 88.19 0.02 19.01 0.04 0.04 89.59 32.61 138.49 MWD OWSG (3,6) 6,700.00 89.53 149.37 4,083.93 19.39 -0.04 91.02 0.02 19.36 0.04 0.04 92.31 32.82 139.12 MWD OWSG (3,6) 6,800.00 89.53 149.37 4,084.76 19.76 -0.04 93.98 0.02 19.73 0.04 0.04 95.16 33.03 139.71 MWD OWSG (3,6) 6,900.00 89.53 149.37 4,085.58 20.16 -0.04 97.06 0.02 20.13 0.04 0.04 98.15 33.23 140.28 MWD OWSG (3,6) 7,000.00 89.53 149.37 4,086.41 20.58 -0.04 100.24 0.02 20.55 0.04 0.04 101.24 33.42 140.81 MWD OWSG (3,6) 7,100.00 89.53 149.37 4,087.23 18.57 -0.04 78.70 0.02 16.55 0.04 0.04 80.50 32.16 136.11 MWD+IFR2+SAG+MS (4,6) 7,200.00 89.53 149.37 4,088.06 18.75 -0.04 79.64 0.02 18.72 0.04 0.04 81.39 32.29 136.40 MWD+IFR2+SAG+MS (4, 6) 7,300.00 89.53 149.37 4,088.88 18.93 -0.04 80.63 0.02 18.91 0.04 0.04 82.32 32.41 136.71 MWD+IFR2+SAG+MS (4, 6) 7,400.00 89.53 149.37 4,089.71 19.13 -0.04 81.66 0.02 19.10 0.04 0.04 83.29 32.53 137.01 MWD+IFR2+SAG+MS (4,6) 7,500.00 89.53 149.37 4,090.54 19.33 -0.04 82.72 0.02 19.30 0.04 0.04 84.30 32.66 137.32 MWD+IFR2+SAG+MS (4,6) 7,600.00 89.53 149.37 4,091.36 19.54 -0.04 83.82 0.02 19.52 0.04 0.04 85.34 32.78 137.62 MWD+IFR2+SAG+MS (4,6) 7,700.00 89.53 149.37 4,092.19 19.76 -0.04 84.95 0.02 19.73 0.04 0.04 86.41 32.91 137.92 MWD+IFR2+SAG+MS (4,6) 7,800.00 89.53 149.37 4,093.01 19.99 -0.04 86.11 0.02 19.96 0.04 0.04 87.52 33.03 138.22 MWD+IFR2+SAG+MS (4,6) 7,900.00 89.53 149.37 4,093.84 20.22 -0.04 87.30 0.02 20.20 0.04 0.04 88.66 33.16 138.52 MWD+IFR2+SAG+MS (4,6) 8,000.00 89.53 149.37 4,094.66 20.46 -0.04 88.53 0.02 20.44 0.04 0.04 89.84 33.26 138.81 MWD+IFR2+SAG+MS (4,6) 8,100.00 89.53 149.37 4,095.49 20.71 -0.04 89.78 0.02 20.69 0.04 0.04 91.04 33.40 139.09 MWD+IFR2+SAG+MS (4, 6) 8,200.00 89.53 149.37 4,096.31 20.97 -0.04 91.06 0.02 20.95 0.04 0.04 92.27 33.52 139.37 MWD+IFR2+SAG+MS (4,6) 8,300.00 69.53 149.37 4,097.14 21.23 -0.04 92.36 0.02 21.21 0.04 0.04 93.53 33.64 139.65 MWD+IFR2+SAG+MS (4,6) 8,400.00 89.53 149.37 4,097.97 21.50 -0.04 93.70 0.02 21.48 0.04 0.04 94.62 33.76 139.92 MWD+IFR2+SAG+MS (4,6) 8,500.00 69.53 149.37 4,098.79 21.78 -0.04 95.05 0.02 21.76 0.04 0.04 96.13 33.87 140.18 MWD+IFR2+SAG+MS (4,6) 8,600.00 89.53 149.37 4,099.62 22.06 -0.04 96.43 0.02 22.04 0.04 0.04 97.47 33.99 140.43 MWD+IFR2+SAG+MS (4,6) 8,700.00 89.53 149.37 4,100.44 22.35 -0.04 97.83 0.02 22.33 0.04 0.04 98.83 34.10 140.68 MWD+IFR2+SAG+MS (4, 6) 8,800.00 89.53 149.37 4,101.27 22.64 -0.04 99.25 0.02 22.62 0.04 0.04 100.21 34.21 140.92 MWD+IFR2+SAG+MS (4,6) 8,900.00 89.53 149.37 4,102.09 22.94 -0.04 100.69 0.02 22.92 0.04 0.04 101.62 34.32 141.16 MWD+IFR2+SAG+MS (4,6) 9,000.00 89.53 149.37 4,102.92 23.24 -0.04 102.15 0.02 23.22 0.04 0.04 103.04 34.43 141.38 MWD+IFR2+SAG+MS (4,6) 9,100.00 89.53 149.37 4,103.75 23.55 -0.04 103.63 0.02 23.53 0.04 0.04 104.49 34.53 141.60 MWD+IFR2+SAG+MS (4,6) 9,200.00 89.53 149.37 4,104.57 23.86 -0.04 105.13 0.02 23.84 0.04 0.04 105.95 34.63 141.82 MWD+IFR2+SAG+MS (4,6) 9,300.00 89.53 149.37 4,105.40 24.18 -0.04 106.65 0.02 24.16 0.04 0.04 107.44 34.74 142.02 MWD+IFR2+SAG+MS (4,6) 9,400.00 89.53 149.37 4,106.22 24.50 -0.04 108.18 0.02 24.48 0.04 0.04 106.94 34.84 142.22 MWD+IFR2+SAG+MS (4,6) 9,500.00 89.53 149.37 4,107.05 24.82 -0.04 109.72 0.02 24.81 0.04 0.04 110.45 34.93 142.42 MWD+IFR2+SAG+MS (4,6) 9,600.00 89.53 149.37 4,107.87 25.15 -0.04 111.29 0.02 25.13 0.04 0.04 111.99 35.03 142.60 MWD+IFR2+SAG+MS (4,6) 9,700.00 89.53 149.37 4,108.70 25.49 -0.04 112.86 0.02 25.47 0.04 0.04 113.54 35.13 142.79 MWD+IFR2+SAG+MS (4, 6) 9,600.00 89.53 149.37 4,109.53 25.82 -0.04 114.45 0.02 25.81 0.04 0.04 115.10 35.22 142.96 MWD+IFR2+SAG+MS (4, 6) 9,900.00 89.53 149.37 4,110.35 26.16 -0.04 116.06 0.02 26.15 0.04 0.04 116.68 35.31 143.13 MWD+IFR2+SAG+MS (4,6) 10,000.00 89.53 149.37 4,111.18 26.51 -0.04 117.67 0.02 26.49 0.04 0.04 118.28 35.40 143.29 MWD+IFR2+SAG+MS (4,6) 10,100.00 89.53 149.37 4,112.00 26.86 -0.04 119.30 0.02 26.84 0.04 0.04 119.88 35.49 143.45 MWD+IFR2+SAG+MS(4,6) 10,200.00 89.53 149.37 4,112.83 27.21 -0.04 120.94 0.02 27.19 0.04 0.04 121.50 35.58 143.60 MWD+IFR2+SAG+MS (4,6) 10,300.00 89.53 149.37 4,113.65 27.56 -0.04 122.59 0.02 27.54 0.04 0.04 123.13 35.67 143.75 MWD+IFR2+SAG+MS (4,6) 10,400.00 89.53 149.37 4,114.48 27.92 -0.04 124.25 0.02 27.90 0.04 0.04 124.77 35.76 143.89 MWD+IFR2+SAG+MS (4,6) 10,500.00 89.53 149.37 4,115.30 28.28 -0.04 125.92 0.02 28.26 0.04 0.04 126.43 35.84 144.03 MWD+IFR2+SAG+MS (4,6) 10,600.00 89.53 149.37 4,116.13 28.64 -0.04 127.61 0.02 28.62 0.04 0.04 128.09 35.93 144.16 MWD+IFR2+SAG+MS (4,6) 10,700.00 89.53 149.37 4,116.96 29.00 -0.04 129.30 0.02 28.99 0.04 0.04 129.77 36.01 144.29 MWD+IFR2+SAG+MS (4, 6) 10,800.00 89.53 149.37 4,117.78 29.37 -0.04 131.00 0.02 29.35 0.04 0.04 131.45 36.09 144.41 MWD+IFR2+SAG+MS (4, 6) 10,900.00 89.53 149.37 4,118.61 29.74 -0.04 132.71 0.02 29.72 0.04 0.04 133.15 36.17 144.53 MWD+IFR2+SAG+MS (4, 6) 11/12/2019 3:18:32PM Page 5 COMPASS 5000 14 Build 85H Company: ConocoPhillips Alaska Inc WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 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: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production 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) (°) 11,000.00 89.53 149.37 4,11943 30.11 -0.04 134.43 0.02 30.09 004 0.04 134.85 36.25 144.65 MWD+IFR2+SAG+MS (4,6) 11,100.00 89.53 149.37 4,120.26 30.48 -0.04 136.15 0.02 30.47 0.04 0.04 136.56 36.33 144.76 MWD+IFR2+SAG+MS(4,6) 11,200.00 89.53 149.37 4,121.08 30.86 -0.04 137.89 0.02 30.85 0.04 0.04 138.28 36.41 144.87 MWD+IFR2+SAG+MS (4,6) 11,300.00 89.53 149.37 4,121.91 31.24 -0.04 139.63 0.02 31.22 0.04 0.04 140.01 36.49 144.97 MWD+IFR2+SAG+MS (4,6) 11,400.00 89.53 149.37 4,122.74 31.62 -0.04 141.38 0.02 31.60 0.04 0.04 141.75 36.57 145.07 MWD+IFR2+SAG+MS(4,6) 11,500.00 89.53 149.37 4,123.56 32.00 -0.04 143.13 0.02 31.99 0.04 0.04 143.49 36.65 145.17 MWD+IFR2+SAG+MS (4,6) 11,600.00 89.53 149.37 4,124.39 32.38 -0.04 144.89 0.02 32.37 0.04 0.04 145.24 38.72 145.27 MWD+IFR2+SAG+MS (4,6) 11,700.00 89.53 149.37 4,125.21 32.77 -0.04 146.66 0.02 32.76 0.04 0.04 147.00 36.80 145.36 MWD+IFR2+SAG+MS (4,6) 11,800.00 89.53 149.37 4,126.04 33.16 -0.04 148.44 0.02 33.14 0.04 0.04 148.77 36.87 145.45 MWD+IFR2+SAG+MS (4,6) 11,900.00 89.53 149.37 4,126.86 33.55 -0.04 150.22 0.02 33.53 0.04 0.04 150.54 36.95 145.53 MWD+IFR2+SAG+MS(4,6) 12,000.00 89.53 149.37 4,127.69 33.94 -0.04 152.01 0.02 33.92 0.04 0.04 152.31 37.02 145.61 MWD+IFR2+SAG+MS (4,6) 12,100.00 89.53 149.37 4,128.52 34.33 -0.04 153.80 0.02 34.32 0.04 0.04 154.10 37.10 145.69 MWD+IFR2+SAG+MS (4,6) 12,200.00 89.53 149.37 4,129.34 34.72 -0.04 155.60 0.02 34.71 0.04 0.04 155.89 37.17 145.77 MWD+IFR2+SAG+MS (4,6) 12,300.00 89.53 149.37 4,130.17 35.12 -0.04 157.40 0.02 35.11 0.04 0.04 157.68 37.24 145.85 MWD+IFR2+SAG+MS (4,6) 12,400.00 89.53 149.37 4,130.99 35.52 -0.04 159.21 0.02 35.50 0.04 0.04 159.48 37.32 145.92 MWD+IFR2+SAG+MS(4,6) 12,500.00 89.53 149.37 4,131.82 35.92 -0.04 161.02 0.02 35.90 0.04 0.04 161.29 37.39 145.99 MWD+IFR2+SAG+MS(4,6) 12,600.00 89.53 149.37 4,132.64 36.31 -0.04 162.84 0.02 36.30 0.04 0.04 163.10 37.46 146.06 MWD+IFR2+SAG+MS (4,6) 12,700.00 89.53 149.37 4,133.47 36.72 -0.04 164.67 0.02 36.70 0.04 0.04 164.92 37.53 146.13 MWD+IFR2+SAG+MS(4,6) 12,800.00 89.53 149.37 4,134.29 37.12 -0.04 166.49 0.02 37.11 0.04 0.04 166.74 37.61 146.19 MWD+IFR2+SAG+MS (4,6) 12,900.00 89.53 149.37 4,135.12 37.52 -0.04 168.33 0.02 37.51 0.04 0.04 168.56 37.68 146.25 MWD+IFR2+SAG+MS (4,6) 13,000.00 89.53 149.37 4,135.95 37.93 -0.04 170.16 0.02 37.91 0.04 0.04 170.39 37.75 146.31 MWD+IFR2+SAG+MS(4,6) 13,051.20 89.53 149.37 4,136.37 38.13 -0.04 171.10 0.02 38.12 0.04 0.04 171.33 37.79 146.34 MWD+IFR2+SAG+MS (4,6) 13,083.05 90.00 149.30 4,136.50 38.25 -0.04 171.70 0.02 38.25 0.04 0.04 171.91 37.81 146.36 MWD+IFR2+SAG+MS (4,6) 13,100.00 90.25 149.29 4,136.46 38.31 -0.04 172.01 0.02 38.32 0.04 0.04 172.23 37.82 146.37 MWD+IFR2+SAG+MS (4,6) 13,185.35 91.53 149.24 4,135.13 38.63 -0.04 173.60 0.02 38.67 0.04 0.04 173.79 37.88 146.42 MWD+IFR2+SAG+MS (4,6) 13,200.00 91.53 149.24 4,134.74 38.69 -0.04 173.87 0.02 38.73 0.04 0.04 174.06 37.89 146.43 MWD+IFR2+SAG+MS (4,6) 13,300.00 91.53 149.24 4,132.07 39.09 -0.04 175.71 0.02 39.13 0.04 0.04 175.91 37.96 146.48 MWD+IFR2+SAG+MS (4,6) 13,400.00 91.53 149.24 4,129.39 39.50 -0.04 177.57 0.02 39.54 0.04 0.04 177.76 38.03 146.54 MWD+IFR2+SAG+MS (4,6) 13,500.00 91.53 149.24 4,126.72 39.91 -0.04 179.42 0.02 39.95 0.04 0.04 179.61 38.09 146.59 MWD+IFR2+SAG+MS (4,6) 13,541.59 91.53 149.24 4,125.61 40.08 -0.04 180.20 0.02 40.12 0.04 0.04 180.38 38.12 146.61 MWD+IFR2+SAG+MS (4,6) 13,600.00 92.41 149.24 4,123.60 40.30 -0.04 181.28 0.02 40.36 0.04 0.04 181.46 38.16 146.64 MWD+IFR2+SAG+MS(4,6) 13,700.00 93.91 149.24 4,118.09 40.67 -0.04 183.14 0.02 40.77 0.04 0.04 183.32 38.23 146.68 MWD+IFR2+SAG+MS (4,6) 13,783.39 95.16 149.25 4,111.50 40.98 -0.04 184.69 0.02 41.11 0.04 0.04 184.86 38.28 146.72 MWD+IFR2+SAG+MS (4,6) 13,800.00 95.16 149.25 4,110.01 41.05 -0.04 185.00 0.02 41.18 0.04 0.04 185.17 38.29 146.73 MWD+IFR2+SAG+MS (4,6) 13,900.00 95.16 149.25 4,101.01 41.46 -0.04 186.85 0.02 41.59 0.04 0.04 167.02 38.36 146.77 MWD+IFR2+SAG+MS (4,6) 14,000.00 95.16 149.25 4,092.02 41.88 -0.04 188.72 0.02 42.00 0.04 0.04 188.88 38.43 146.82 MWD+IFR2+SAG+MS (4,6) 14,100.00 95.16 149.25 4,083.02 42.29 -0.04 190.58 0.02 42.41 0.04 0.04 190.74 38.49 146.86 MWD+IFR2+SAG+MS (4,6) 14,200.00 95.16 149.25 4,074.03 42.70 -0.04 192.45 0.02 42.83 0.04 0.04 192.60 38.56 146.90 MWD+IFR2+SAG+MS (4, 6) 14,283.39 95.16 149.25 4,066.53 43.05 -0.04 194.01 0.02 43.17 0.04 0.04 194.16 38.61 146.94 MWD+IFR2+SAG+MS (4,6) 14,300.00 95.16 149.25 4,065.04 43.12 -0.04 194.32 0.02 43.24 0.04 0.04 194.47 38.62 146.94 MWD+IFR2+SAG+MS (4,6) 14,400.00 95.16 149.25 4,056.04 43.53 -0.04 196.19 0.02 43.65 0.04 0.04 196.34 38.68 146.98 MWD+IFR2+SAG+MS (4,6) 14,500.00 95.16 149.25 4,047.05 43.95 -0.04 198.06 0.02 44.07 0.04 0.04 198.21 38.75 147.02 MWD+IFR2+SAG+MS (4,6) 14,600.00 95.16 149.25 4,038.06 44.37 -0.04 199.94 0.02 44.48 0.04 0.04 200.08 38.81 147.06 MWD+IFR2+SAG+MS (4,6) 14,700.00 95.16 149.25 4,029.06 44.78 -0.04 201.82 0.02 44.90 0.04 0.04 201.96 38.88 147.09 MWD+IFR2+SAG+MS (4,6) 14,783.39 95.16 149.25 4,021.56 45.13 -0.04 203.39 0.02 45.25 0.04 0.04 203.53 38.93 147.12 MWD+IFR2+SAG+MS (4,6) 11/12/2019 3:18:32PM Page 6 COMPASS 5000 14 Build 85H Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Design Targets Hole Diameter Diameter (in) Target Name 10.750 13.500 7.000 8.750 hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape (o) (o) (usft) (usft) (usft) CD4 -499 Tgt 0 QM 0.00 0.00 4,069.50 -1,301.20 1,910.81 plan misses target center by 0.02usft at 5505.64usft MD (4069.52 TVD, -1301.20 N, 1910.81 E) Circle (radius 1,320.00) 4,324.46 3,814.60 K-3 LIGNITE CD4 -499 Tgt 0 E Heel 1 0.00 0.00 4,069.50 -1,301.20 1,910.81 plan misses target center by 0.02usft at 5505.64usft MD (4069.52 TVD, -1301.20 N, 1910.81 E) Circle (radius 100.00) 0.00 CD4 -499 Tgt 2 QM 0.00 0.00 4,111.50 -8,422.17 6,129.46 plan hits target center Circle (radius 1,320.00) CD4 -499 Tgt 2103119 0.00 0.00 4,111.50 -8,422.17 6,129.46 plan hits target center Circle (radius 100.00) CD4 -499 Tgt 1 103119 0.00 0.00 4,136.50 -7,820.85 5,771.61 plan hits target center Circle (radius 100.00) Casing Points Measured Depth (usft) 2,437.42 5,504.64 14,783.39 Formations Vertical Depth (usft) Name 2,390.00 10 3/4 x 13 1/2 4,069.47 7 x 8-3/4 4,021.56 4 1/2 x 6 1/8 Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Casing Hole Diameter Diameter (in) (in) 10.750 13.500 7.000 8.750 4.500 6.125 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology V) (�) 2,465.27 2,415.20 C-30 LIGNITE 0.00 2,838.64 2,750.00 C-20 LIGNITE 0.00 3,120.91 2,995.90 C-10 LIGNITE 0.00 4,324.46 3,814.60 K-3 LIGNITE 0.00 5,315.83 4,059.50 K-2 LIGNITE 0.00 7,700.00 4,092.19 Fault 1 0.00 11/12/2019 3:18:32PM Page 7 COMPASS 5000 14 Build 85H Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Plan: CD4 -499 Wellbore: CD4 -499 Design: CD4 -499 wp15 Plan Annotations Measured Depth (usft) 500.00 700.00 1,351.35 1,453.31 2,500.06 2,520.06 2,800.06 5,230.31 5,492.22 5,504.64 5,524.64 5,693.10 13, 051.20 13, 083.05 13,185.35 13, 541.59 13,783.39 14,283.39 14,783.39 Vertical Depth (usft) 500.00 699.98 1,346.50 1,446.50 2,446.50 2,464.43 2,715.49 4,054.98 4,068.81 4,069.47 4,070.51 4,075.62 4,136.37 4,136.50 4,135.13 4,125.61 4,111.50 4,066.53 4,021.56 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Local Coordinates +N/ -S +E/ -W (usft) (usft) 0.00 0.00 2.53 0.68 72.41 19.40 91.66 24.56 180.32 287.05 179.87 295.89 173.62 419.71 -1,065.50 1,769.23 -1,289.70 1,903.94 -1,300.35 1,910.30 -1,317.53 1,920.47 -1,462.41 2,006.26 -7,793.46 5,755.36 -7,820.85 5,771.61 -7,908.77 5,823.88 -8,214.77 6,006.03 -8,422.17 6,129.46 -8,850.13 6,384.07 -9,278.09 6,638.68 Comment Well Plan: CD4 -499 Plan 19+27.5 @ 46.50usft (D141) Plan 19+27.5 @ 46.50usft (D141) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production KOP: Start 0.75°/100' DLS, 15° TF, for 200' Start 1.5°/100' DLS, 0° TF, for 651.35' Hold for 101.97' Start 2.5°/100' DLS, 101' TF, for 1046.74' Hold for 20' Adjust TF to 0°, for 280' Start 3°/100' DLS, 60.14° TF, for 2430.25' Hold for 261.92' Start 3°/100' DLS, 85.96° TF, for 12.42' Hold for 20' Start 1.5°/100' DLS, -0.07° TF, for 168.46' Hold for 7358.1' Start 1.5°/100' DLS, -8.06° TF, for 31.85' Adjust TF to -2.42°, for 102.3' Hold for 356.24' Start 1.5°/100' DLS, 0.23° TF, for 241.8' Hold for 500' Adjust TF to 0°, for 500' TD: 14783.39' MD, 4021.56' TVD Checked By: Approved By: Date: 11/1212019 3:18.32PM Page 8 COMPASS 5000.14 Build 85H 15.OZ November 06 2019 CD4 -499 wp15 WELLBORE CD 4%Tgt 1 103119 C= C04499Tgt2103119 TMGET DETAILS 4136.50 4 411150 (MAP C6 DINATES) s, po Circa (Ratlw I'W,W7 Quarter Mile View CS_ Tg 0E Hee1110619 CN -499 Tgt amW 405950 4059 C—(Rad-10000) Circe RdWu 10000) Cute (Ratllus: 132000) 20 CD4 -499 Tqt 2 pM 4111 50 Cucle (Radws'. 1320 00) 00 GCDA=7•�0 GOA•9'�pg1 301p ''.. GOq O M 04 N 1 0 cav ewr '. 59 A06,. room O a CD4' -30i ®® ma^ a -2000 qo (A 41 42O O N v2 �� GO. °� v -4000 4 a� A•yea co QA.2 MA p 04-96 a z ..Fm -6000 _. _ __. -A yy1 ,C4 •29 __ 004i COA.2 G 2 69 G O CO 'L00 AZ - GO Q OA 211 A y0 9 GO Al -8000 y08 GO�P LGO°'93 N 9°j-1��p°1 E ,� GOA9 9 �Q16 a0 A203 '.any ", Oa• GA1 \ �yA a � GOA• -10000— 0� 4R� O� O O O -4000 -2000 0 2000 4000 6000 8000 10000 12000 CD4 -499p15 Surface Location M CPAI Coordinate Converter From: -- i Datum: NA583 Region: alaska i I r Latitude/Longitude IDecimal Degrees UTM Zone:— r- South State Plane Zone: q - Units: us -ft i r Legal Description (NAD27 only) To: -_ -- - - ---- Datum: NAD27 Region: alaska D- r Latitude/Longitude Decimal Degrees fR UTM Zone: True I- South i� State Plane Zone: q Units: us ft " Legal Description (NAD27 only) Starting Coordinates: - ---- Ending Coordinates: - - X: 11518227.75 X: 378194.239417181 i Y: 5957277.98 Y: I 5957530.82102219 .Transform ) Quit Help CD4 -499w 15 Surface Location CPAI Coordinate Ccn�-enter - ❑ X From: Datum: INAD83 Region: alaska r Latitude/Longitude Decimal Degrees t'° UTM Zone: — r South t% State Plane Zone: q Units: us -ft r i.-egal De- cription (t1JAD27 only) Starting Coordinates: — - X: 11518227.75 Y: 15957277.98 -� I t To: Datum: INZ27 I Region: jalaska I i C Latitude/Longitude Decimal Degrees f UTM Zone: True r- South C" State Plane Zone: F4—:-:] Units: us -ft r Legal Description (NAD27 only) Legal Description - - - - -- -- —� Township: 011 N Range: 004 E Meridian: U Section:24 FNL 2877.5301 FEL 50.641918 I ._. ..-. ._- _- Transform Quit Help CD4-499wp15_ ___ Surface Casin M CPAI Coordinate Converter From: iDatum: NAD83 j Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: f— r- South r State Plane Zone: q , Units: us ft C Legal Description (NAD27 only) Starting Coordinates: - M Y: ❑ X To: Datum NAD27 Region: alaska j i r Latitude/Longitude Decimal Degrees r UTM Zone: True South I State Plane Zone: q Units: us ft i Legal Description (NAD27 only) X: 378492.996886543 Y: 5957705.8402677 - ---- Ending Coordinates: 1518526.5 5957453.01 .................. ........................................, Transform Quit Help ICD4-499wp15 Surface Casing E CPAI Coordinate Converter - ❑ X From: Datum: INAD83 Region: alaska i Latitude/Longitude Decimal Degrees i UTM Zone: j" South i i t: State Plane Zone: q Units: us Ft i Starting Coordinates:- -- - - X: 1518526.5 Y: 15957453.01 To:-- ---_ _ ___. . _ _ - -_I Datum: FN—AD-27--_--3Region: Ialaska C' Latitude/Longitude IDecimalDegrees C UTM Zone: True r- South r State Plane Zone:q Units: us -ft 0 Legal Description (NAD27 only) Legal Description- --- --- - Township: 011 [-N ---1 Range: 005 E Meridian: U Section: Il9 FNL 2697.6896 FEL 4715.7776 -- - ---- ...._J .......... ...........Transform...Quit Help CD4-499wp15 Top_ of K-3 LCL CPAI Coordinate Converter rFrom: Datum: NApg� Region: alaska t-" LatitudelLongitudeDecimalDecimal Degreess {" UTM Zone: r— r South is Stake Plane Zone:14 - Units: us ft Legal Description (NAD27 only) Starting Coordinates: - ---- — X: 1519470.28 i Y: 5956896.74 i ❑ X - To: - --- - - - -. . Datum: NA527 Region: alaska r Latitude/Longitude Decimal Degrees t'" UTM Zone: True r South (0- State Plane Zone:: q Units: us -ft 4" Legal Description (NAD27 only) Ending Coordinates: X: Y: -379436,754848012 5957149.5253d285� Quit Help CD4-499wpl5 Top of K-3 M CPAI Coordinate Ccnverter - ❑ X From: — - - _ _ .... To: - _ __ _ __ --------- D atum: ____ Datum:NAD83 Region: alaska Datum: NAD27 Region: alaska i` Latitude/Longitude IDecimal Degrees > Latitude/Longitude Decimal Degrees C UTM Zone:i — r South r UTM Zone: True " South t� State Plane Zone: q Units: us -ft D- r State Plane Zone: F----] Units: us -ft i Legal Description (NAD27 only) Starting Coordinates: -- -- Legal Description --- - X: 1519470.28 Township 011 N Range:005 E Y 5956896.74 Meridian: U Section: I1 g .......... FNL 3238.7823 FEL 3765-3156 i ... .Transform Quit Help CD4-499wpl5 Intermediate Casing CPA[ Coordinate Converter - ❑ X From: -- - - - - Datum: NAD83 Region: alaska Latitude/Longitude Decimal Degrees r UTM Zone: r— f- South C State Plane Zone:14 Units: jus.ft r Legal Description (NAD27 only) Starting Coordinates: — — - - - — - X: 1520116.5 j Y: 15955946.87 To: - --- Datum:NAD27 Region: alaska I C" Latitude/Longitude Decimal Degrees 's r UTM Zone: True South State Plane Zone:4 Units: iuST r"` Legal Description (NAD27 only) i Ending Coordinates: — --- ----- X: 380082.936552435 Y 5956199.6189599 - Transform Quit Help CD4 -499w 15 Intermediate Casing I Ll CPAI Coordinate Converter - ❑ X From: Datum: NAD83 Region: alaska r" Latitude/Longitude Decimal Degrees C" UTM Zone: - f- South r- State Plane Zone: 4 Units: us -ft {�' L-eg.31 Lie:=::er�pti��t-i (Nis,D�'7 ur-d!,rl Starting Coordinates: ---- X: 1520116.5 Y: 15955946.87 - To: Datum: NAD27 - Region: alaska i' Latitude/Longitude Decimal Degree7..___., r" UTM Zone True f- South r`" State Plane Zone:4 Units: us ft r- Legal Description (NAD27 only) i Legal Description ------- - -- Township: 011 N Range: 005 E Meridian: U Section:19 FNL I 4178.3128 IFEL 3107.6995 ..................... _............... ... Transform ........... Quit Help CD4-499wp15 TD M CPAI Coordinate Converter — ❑ X From: Datum: NApg� Region: alaska r Latitude/Longitude Decimal Degrees + C` UTM Zone: F_ [_ South I t� Stake Plane Zone: 4 + Units: us -ft Legal Description (NAD27 only] Starting Coordinates:------------__� _ X: 11524714.2 -- Y. 15947893.98 To:- Datum:NAD27 � Re9ion alaska C-' Latitude/Longitude Decimal Degrees + UTM Zone: True South State Plane Zone: 4 - _ Units: us -ft i` Legal Description (NAD27 only) Ending Coordinates: ----- - — -- X: 384680.31721569 Y: 5948146.45718634 Transform Quit Help CD4 -499w 15 TD M CPAI Coordinate Converter — ❑ X From: — v - -- To: _w I Datum: NAD 83 Region: alaska Datum: NAD27 Region: alaska I r Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees t" UTM Zone:—Fm_._ F"' South I t"` UTM Zone: True South r State Plane Zone: 4 + Units:]jl r State Plane Zone: 4 Units: us ft us•ft I i t Legal Cjescription [NAD"27 ; jr"dyI r Legal Description (NAD27 only) -- Starting Coordinates:--- -- — -- Legal Description - — — — — X: 1524714.2 Township:9 005 Ran e 011 N E + Y: 5947893.98 Meridian: U + Section:32 - �— — FNL 1599.3063 FEL 3693.3954 Quit .Transform Help 9 13/31/14 1 AG I DE3 I C.A.1 UPDATED PER K140003ACS 1 1014/28/14 1 AG I DB I C.A.IUPDATED PER K140003ACS1 CONDUCTORS CD4 -X97 THRU CD4 -X28 ARE LOCATED IN PROTRACTED SEC. 24, T 11 N. R 4 E, U.M. CONDUCTOR CD4 -X96 IS LOCATED IN PROTRACTED SEC. 19, T 11 N, R 5 E, U.M. ' S LINE 0/S EXIST. WELL Y' °SEC .LINE LAT.(N) LONG.(W) FSL FEL GND PAD KUUKPIK NOTES; Y' I. COOROINATE5 SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.a Alpine Survey Office ALPINE MODULE: CD40 UNIT: CD ConocoPhillips ALPINE PROJECT CD -4 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FU N0. DRAWING N0: PART: REV: 05-03-03-15-2 10/11/05 1 CE-CD40-121 1 2 OF 3 10 C04 -X86 5,957 337.85 1,518,480.27 70' 17 32.458' 150' 59 14.133 2466 760 12.4 18.9 CD4 -287 5. 957 333.22 1,518,460.78 70' 17 32.409' 150' 59 14.699 2461 4780 12.4 19.1 C04 -X88 5.9 57 328.53 1 518,441.29 70' 17 32.360 150' 59 15.265 2456 4799 12.4 18.9 04-1$ 5,957,32.3.89 1 _1 8.421. 0' 1 . 11 150* 9 15.8 451 4 19 1 ,4 19.0 C04-190 5,957,319.25 1 518 402.44 70'17,32.252;4 150' 59 16.393 -T4 4-6 4838 12.4 19.0 CD4 -191 5,957,314.54 1,5'18,382.87 70' 17 32.213" 150' 59' 16.961" 2441 4857' 12.4 18.9 CD4 -292 5 957 310.03 1,518,363.49 70' 17 32.165' 150" 59 I 5524 2436 4877 12,4 18.8 CD4 -X93 5 957 305.15 1,518.34-4.09 70' 17 32.114 150' 59 13.087 2431 4896 12.4 19.0 CD4 -X94 5,957, 300.65 1,518.324.84 70' 17 32.067 150' 59 18.645 2426 4915 12.4 t 9.0 CD4 -X95 5 957 295.77 1,78-.30533 70" 17 32.01 fi 150` 59 19.212 --2--42 --49-T5-r-124 194 CD4 -X96 5,957 291.25 1 518,286.46 70' 17' 31.968' 150' 59 19.760" 2416 4953 12.4 18.9 CD4 -X97 5,957,286.78 1 518 266.76 70' 17 1.921 150' S9 20.331 2412 12 12.4 18.8 C04 --X98 5,957,282.22 1 518 2a-7.43 70' 17 31.873 150' 59 20.893 2407 31 12.4 19.1 C04 -x99 5,957 277.98 1,518.227.75 70' 17 31.828 150` 59' 21.464 2402 51 12.4 19.0 CD4 -301B 5 957 273.28 1,518 208.24 70' 7 31.779 150' 5F 22.030 --2T9--7r- 0 12.4 19.0 C04-302 5,957,268.3d 1,518,188.64 70' 17 31.728 150' 59 22,599 2392 90 12.4 19.6 CD4 -323 5,957,263.99 1,518,169.26 70' 17 31.681 150' 59 23.162" 2387 109 12.4 19.6 CD4 --304 957 259.26 1 518 149.87 70' 7 1.632 150' S 23. 25-2787- 1 8 12.4 19. C04-05 5,957 254.43 1,518,130.28 70' 17 31.581 150' 59 24.293 2377 148 12.4 19.5 C04-306 5 957 249.6 1,518,110,87 70' 17' 31.532 150' 59 4.857 2372' -T6 �7 12.4 19.6 CD4 -07 5,957,245.29 1 518 091.49 70' 17 31.485 150' 59 25.419 2367 186 12.4 19,7 CD4 -208 5,957,240.13 1,518 071.80 70' 17 31.431' 150' 59 25.997 _T3_6 -2 206 12.4 19.8 CD4 -209 5,957,235.77 1 518 052.15 70' 17' 31.385" 150' 59' 26.561 2357 226 12.4 19,7 G04- 210 5957 230.92 1.5 5 032.98 70' 17 31.334 154' 59 27.118 2352 245 12,4 19.6 C04-211 5,957 226.94 11518.013.75 70' 17 31.292 150' 59 27.676 2348' 264 12.4 20.0 GD4-212 5,957,222-25 1.517.994.40 70' 17 31.243 150` 59 28.238 2 43 283 12,4 19.6 C134--213 5,957 217.19 1,517,974.00 70' 17' 31.190" 150' 59' 28.812" 2337' 303 12.4 19.9 CD4 -214 5.957 212.46 1,517,955,51 70' 17 31.140 150" 59 29.367 2332 322 12.4 1 19.8 C04-215 5,957 208.07 1,517,935.87 70' 17 31.094 150' 59 29.937 2327 341--12.4 19.8 C04-16 5,957,203.17 1.,517,916.63 70' 17 31.043 150' 59 30.495' 2322 361 12.4 19,5 CD4 -17 5,957,198.80 1,5 7 897.14 70' 17 1.997 155, 59 31.06 2318 80 12.4 19.5 C04-318 5,957,193.71 1 517 877,38 70' 17 30.944 150' 59 31.634 2312 400 12.4 19.6 C04-319 5,957 189.64 1,517,857.90 70' 17 30.900 150' 59 32.200 2308 419 12.4 19.7 D4-3 0 5,957:185.03 1,517.838.95, 0' 1 0. 150* 9 7 2 4 -17 -4 --T-9-7- 9CD4-321 CD4-321 5,957 180.22 1 517,819.26 70' 17 30.802 150' 59 33.322 2298 458 12.4 19.0 CD4 -322 5 957 175.24 1.517 799.50 70' 17 30.749 150' 59 33.884 2292 477 12.4 19.0 CD4 -X23 5 957 170.76 1,517,780.38 70' 17 30.702" 150' 59 34.450 2288 496 12.4 19.0 C04 -X24 5,957166.23 1,517J66,82 70' 17 30.655 150' -,,r-0 35.011 2283 516 12.4 1!0 CD4 -X25 5.957,161-34 1 1 741.31 70' ,603 1 9 84 2 8 5 12.4 19.0 CD4 -X26 5.957.157.10 1 517 721.97 70' 17' 30.558 150' 59' 36.146" 2273'554' 12.4 19.5 C04-227 5,957 151.94 1'517,702.56 70' 17' 30.505" 150' 59' 36.709" 2268' 574' 12.4 19.6 CD4 -X27 5,957,150.77 1,517.697.37 0' 17 30,492 150' 59 36.860 2266 579- 12.4 1 .4 CD4 -X28 ,9 7 14 4 1,517,578.39 70' 17 .445 150' 59 .411 261 598 12.4 1 .8 KUUKPIK NOTES; Y' I. COOROINATE5 SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.a Alpine Survey Office ALPINE MODULE: CD40 UNIT: CD ConocoPhillips ALPINE PROJECT CD -4 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FU N0. DRAWING N0: PART: REV: 05-03-03-15-2 10/11/05 1 CE-CD40-121 1 2 OF 3 10 1 1111 1 11 VA" 03 np c p 4 °a n cep gN-aAa CD4J CHEMICAL _e TANK FARM �\ I [rmsoN caxma. 44 4 D DRILL SITE PLOT PLAN DRAWN BY. ALKET MICI (8.53 ACRES) 25 50 100 FT. �1 _ IM PoP-IiAF .A' ,Lonocornuups CD4 LAYOUT DRAWING Alaska, Inc. 11'.17' Nae ea Same DRAWN BY: ALKET MICI FDA,,: o9—oA—zme qEY: i ■ 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 is canacafdr�ps ■ 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 4 1/16-5K TREE CAP 4 I/16 -5K GV 41.65 O!O CROSS, C-600 (STDD), -T- - " " q/I6-SK STOO RUN % 9/16-sK ST00 OUTLETS O' O 4 1/16-5K GV W/ CHAIN WHEEL 91.96 4 1/16-5K ACTD GV 4 t/16 -5K GV O'O OO ADAPTER, A -4-M. II -SK STOD BTM X TUBING HANGER, TC -IA -EMS, 4 1/16-5K STDD TOP O.BBO BOWL. BORED F/7.115 OD EN 4 1/2 HYDRIL 563 12.60 LB/FT BTM . TOP FIRED F/7.1 -0002 W/2 CONT SCS SV PORTS P1000199023 TUBING HEAD SECTION ASSY. 10.380 THRU-BORE, 11-5K STOD BTM - - - _ _ _ _ _ _ % 11 -SK FLG TOP .qi PI20190-0002 13.00 2 1/I6 -5K M120 PLUS GV �I 26.42 57.78 PACKOFF, A -i5 ! 10.380 BOWL % 7 UNIHEAD SECTION ASSY, 12-150-016 - - - - 10.380 BOWL, 12 INCH NOM TAPER M -TO -M SEAL BTM X -5K FLG TOP .16 'i, PICO 137665 2 1/16-5K M120 PLUS GV I3.60 CASING HANGER,C-21 10.380 BOWL % 7 1 12-093-112 22.T5 CASING HANGER, MANDREL, FLUTED F/ 10.380 BOWL, BELL NIPPLE, li X.000 TSH 563.26 LB/FT (F)BTM 10 J/4 SOW W/ TP % 8.000-4 NA -2G -LH (M) TOP 12 -NOM TAPER M -TO -M SEAL TOP P1000124695 P166636 10.23 CASING HANGER MANDREL LANDING RING, 16.16 FLUTED, F/ 15.27 BOWL, 10.75 4P1 BC IFI% 10.36 50-4 SAM2-2G-LH (F), W CASING HANGER, C-21 W/ 5 DEG NOM M -TO -M SEAL PREP TOP 15 I/4 X 10 3/4 P1683 W/ STEP-DOWN OD LANDING RING P104011 16 SOW BTM PREP X 16.00 SLICK NECK TOP, 14.60 1O X 15.27 BOWL 13-140-660 16' OD CASING 'i 10 3/1.00 CASING 7.OD CASING 4 1/2.00 TBC GEN 5 SLIM HOLE O OON(OO OOPHOLLOPS ALASKA 16X103/4X7X41/2 QUOTE LAYOUT REF: DMI00153363 PRIVATE AND CONFIDENTIAL DESCRIPTION .N BY, T. PHAM OATEa 10-25-17 121 ro 1N .R1r I=' wMMO«—ALL T AFTING c:ca: SURFACE WELLHEAD LAYOUT A �TeCNVpFhC WY 16 X 10 3/4 X 7 Z. MARQUEZ 10-25-17 . X 4 1/2 CASING PROGRAM, E61GNREVIEW. D.TE: sN.1s12E II -5K X 4 1/16-5K, C. McNELIS 10-25-17 NA UF.CTLRING APPROVAL, IATE, ECNNUMBER 1307631 V B CONOCOPHILLIPS, ALASKA Ip Ri0VE0 BY, G.SCOTT Ai E: R.NIHG NI EET 10-10-18 DM100271949 I/2 COP-GHT T.m.IPFMC Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, November 26, 2019 8:42 AM To: Smith, Matt Cc: Hobbs, Greg S; Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CD4-499 (PTD 219-161) Matt, Thanks for the answers and the diagram.... I agree on the SCMT as a backup plan in case sonic log is inconclusive. Greg, AOGCC has been requesting wellhead diagrams for all new PTD's recently. Please start including them from now on for new wells. Can you pass this on to your drilling engineers. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). From: Smith, Matt<Matt.Smith2@conocophillips.com> Sent: Tuesday, November 26, 2019 6:24 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CD4-499 (PTD 219-161) Guy, thanks for the comments. Please see responses below. If you have any further questions or comments, please let me know! Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA. ATO -1704 OFFICE: +1.907.263.4324 CELL: + 1.432.269.6432 MATT.SMITQ(C7 cop.cOM From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Monday, November 25, 2019 10:53 AM To: Smith, Matt <Matt.Smith2@conocophillips.com> Subject: [EXTERNAL]CD4-499 (PTD 219-161) Matt, A couple of comments on the PTD: 1) The 10 %" casing test should be 2500 psi vs 3500 psi . ( Burst on 10 % in 5210 psi) -we've been testing our wells to 3500 psi, which is still only —67% of burst (33% safety factor), which we feel is sufficient. 2) Please provide a vendor wellhead diagram. See attachment 3) The CBL for the 7" should be a Memory SCMT. The LWD conics we have seen in past are very low quality. (Run SCMT with the frac liner) we've been running Sonic logs in our BHA's for quite a while now. They have been acceptable to date, and the only issue I have heard occurred once, because we didn't start logging early enough and did not catch free ringing pipe, to compare. We are able to run SCMT on our liner running tool, however we like to keep that as a contingency, if for some reason we do not get data from our Sonic tool. If the SCMT is our only method, and it doesn't give us good data, then we are using rig time to run another wireline log, before being able to complete the well. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). Remark: AOGCC PTD No. 219-161 Coordinate Check 14 November 2019 INPUT Geographic, NAD27 CRU -CD4 -499 Latitude: 70 17 31.01489 Longitude: 150 59 10.19601 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet ff Northing/Y: 5957327. 471 Easting/X: 378190.948 Convergence: -0 55 42.27439 Scale Factor: 0.999916855 Corpscon v6.0.1, U.S. Army Corps of Engineers Remark: AOGCC PTD No. 219-161 Coordinate Check 14 November 2019 INPUT Geographic, NAD83 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. CRU -CD4 -499 1/1 Latitude: 70 17 31.82800 Longitude: 150 59 21.64600 Northing/Y: 5957530-886 Easting/X: 378187.999 Convergence: -0 55 42.45734 Scale Factor: 0.999916856 Datum Shift (m): Delta Lat. = 36.782, Delta Lon = -117.848 Corpscon v6.0.1, U.S. Army Corps of Engineers AOGCC PTD No. 219-161 Coordinate Check 14 November 2019 INPUT OUTPUT Geographic, NAD83 Geographic, NAD27 Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. CRU -CD4 -499 1/1 Latitude: 70 17 31.82800 Latitude: 70 17 33.01489 Longitude: 150 59 21.46400 Longitude: 150 59 10.19601 Datum Shift (m.): Delta Lat. = 36.782, Delta Lon = -117.848 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: �,� C/0 `t` — 7 l PTD: Z19--/,�� t/ Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: ,� �j/��L� POOL: 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) in the attached application, the following well logs are also required for this well: Well Logging Requirements J 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, QANNIK OIL - 120180 Well Name: COLVILLE RIVER UNIT CD4 -499 Program DEV Well bore seg ❑ PTD#:2191610 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 - - - - - - - Surface location in ADL 380077, top prod interval in ADL 384211, portion of productive -interval _ 3 Unique well -name and number - - - - - - - - - - - - - - - Yes - - - - - - - lies in_ADL 380082, TD in ADL 388903-- - - - - - - - - - - - - - - - - - - - 4 Well located in -a- defined pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - No_ - _ _ _ Horizontal section will be drilled within_Qannik Pool, toe of well wi_II be drilled upward to_ _ _ _ _ - 5 Well located proper distance from drilling unit -boundary - - - - - - - - - - - - - - - - - Yes - - - intercept the _Narwhal Sand in an- undefined pool. - - - - - - - - - - - - - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 -if_deviated,is_wellbore plat -included ----------------------------------- Yes ---------------------------------------------------------------- 9 Operator onlyaff_ectedparty---------------------------------- - - - - -- Yes------------------------------------------------------- -------- 10 Operator has_appropriatebond0force -------------------- ---- - - - -.- Yes --------- ------------------------_---------------------------- 11 Permit_can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Yes, but Conservation Order needed before regular production begins_ IF theNarwhal_ Sand is Appr Date 12 Permit can be issued without administrative -approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - hydrocarbon_ bearing. If so, either the Qannik Pool must be expanded to include the_ - - - - - - - - 13 Can permit be approved before 15-day_wait _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ Narwhal Sand -or a commingling order is needed. _ _ _ _ _ _ _ _ _ SFD 11/14/2019 14 Well located within area and strata authorized by Injection Order # (put 10# in_comments)_(For_ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 area All wells within 1/4_mil _e area of review identified (For service well only) _ _ _ _ _ _ _ - - - NA_ 16 Pre -produced injector: of pre -production less than 3 months _(For service well only) - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven.gas conforms -to AS31.05.030(l.1.A),(j,2.A-D)_______---------------- NA_________________-_________________ 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - _ 20" Conductor at 120 ft. - - - - - - - - - Engineering 19 Swilacecasing- p_rotects all -known_ USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - _ _ _ _ - No aquifers - - _ - - - - - - - - - - - _ - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - 20 CMT_ vol adequate_ to circulate on conductor _& surf_csg - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - _ - - - 21 CMT -vol adequate_to tie -in -long string to surf csg_ - - - - - - - - - - - - - - - No_ - _ - - - - - 7" TOC_planned for 4335 ft md_(3820 ft TVD) _ - - - - - - - 22 CMT_will coverall known -productive horizons - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ - - - - Lateral will_have swell packers and frac sleeves_ - - - - - - - - - - - - - - - - - - - - - - 23 Casing designs adequate for CJ, B &_permafr_ost- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - - - - - - - - - - _ _ _ - - _ - - - _ _ - - _ _ _ _ _ _ _ _ _ - _ - - - - -- 24 Adequatetankage_orreservepit------- ------------------------------ Yes - - - - - - - Rig_hassteel tanks ----------_- 25 If a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - NA_ - - - _ 26 Adequate wellbore separation proposed- - - - - - - - - Yes - - - No issues ..._ collision data provided- - - - - - - - - - - - - - - - - - - 27 If_diverter required, does it meet regulations_ - - - NA- - - - - - - - Diverter plan provided-- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid_ program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - max formation_ pressure =_1918 psi (9_.17 ppg E_M_W )_ Will drill lateral with 8.8-9.5 ppg mud with _MPD GLS 11/26/2019 29 BOPEs,_do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - - - - DQyon 141_ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ - - _ _ _ - _ - - - - - 30 BOPE_press rating appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes - _ _ - - - - AMSP = 1518_psi-will test BOPE to 3500 psi _ _ - _ - - - - - - - _ - _ _ - . - - _ _ - - - - - - - - - - - - - - - - - 31 Choke manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Sundry -required frac stimulate_the well. - - _ _ _ _ - _ - - _ _ - _ _ - - - _ _ _ _ 33 Is presence of H2S gas probable _ _ - - _ _ _ Yes _ _ _ H2S on_ pad 34 Mechanical_condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - NA_ - -- - - - - - - - - - - - - - - - - _ _ - _ _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - None encountered in_nearby well CD4 -595 drilled to same_ intervals. Rig has sensors and alarms._ - - Geology 36 Data_presented on potential overpressure zones - - -- - - - - - - - - _ Yes _ _ _ _ - - - None anticipated: -none encountered in nearby -well CD4 -595, which drilled the same geologic section._ Appr Date 37 Seismic analysis of shallow gas -zones- - - - - - - - - - - - - - - - - _ - _ _ _ _ _ _ _ _ NA- _ _ _ _ - - - Planned mud program, with Managed _Pressure Drilling, appears adequate to control operator's_ SFD 11/14/2019 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - forecast pressures._ - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - 39 Contact name/phone for weekly -progress reports_ [exploratory only] - - - - - _ NA_ _ - - - - - - - - Geologic Engineering Public Horizontal section will be drilled within Qannik Pool; toe of well will be drilled upward to intercept the Narwhal Sand in an Commissioner: Date: Commissioner: Date Co missio Date undefined pool. Conservation Order needed before regular production begins.