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Home My WebLink About219-1681. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill erforate New Pool Repair Well Re-enter Susp Well Other: PROD to WINJ 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 14,948 feet None feet true vertical 6,769 feet None feet Effective Depth measured 11,871 feet 11,581 feet true vertical 6,805 feet 6,713 feet Perforation depth: feet feet Tubing (size, grade, measured and true vertical depth)3.5 '' J-55 11,610' MD 6,727' TVD Packers and SSSV (type, measured and true vertical depth) PACKER BAKER HB RETR. PKR 11,581' MD 6,713' TVD SSSV CAMCO TRDP-1A 1,816' MD 1,719' TVD 12. 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: Jennifer McLeod Contact Name:Jennifer McLeod Authorized Title:Petroleum Engineer Contact Email:jennifer.mcleod@cop.com Contact Phone:(907) 265-1050 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-22200-65-00 8. Well Name and Number:KRU 1R-23AL2ADL 25635, ADL 25636, ADL 25627 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: 219-168-0 Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field / Kuparuk River Oil Pool Plugs measured Junk measured Burst Collapse CONDUCTOR 79 feet 16 '' 123' MD 123' TVD PRODUCTION 12,138 feet 7 '' 12,178' MD 7002' TVD SURFACE 6,289 feet 9 5/8 ''6,331' MD 4072' TVD Slotted Liner 275 feet 2 3/8 '' 11,871' MD 6805' TVD N/A Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: 80 500 2500 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 00 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. 320-184 GINJ SUSP SPLUGGGG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Jennifer McLeod Digitally signed by Jennifer McLeod Date: 2020.05.08 11:16:52 -08'00' By Samantha Carlisle at 11:31 am, May 08, 2020 RBDMS HEW 5/8/2020 SFD 5/8/2020VTL 05/26/20 DSR-5/11/2020 1 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 May 8, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 1R-23AL2 (PTD# 219-168). If you have any questions regarding this matter, please contact me at 907-265-1050. Sincerely, Jennifer McLeod Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Jennifer McLeod Digitally signed by Jennifer McLeod Date: 2020.05.08 11:16:02 -08'00' 1R-23AL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/23/2020: STATE WITNESSED MIT-IA (PASSED TO 1905 PSI) 2/13/2020: WELL PLACED ON INJECTION 1/26/2020: MIT-IA (PASSED TO 2000 PSI) 1/25/2020: PERFORM POST CDR SBHP @ THE LINER TOP 11595' RKB (3675 PSI) 1/24/2020: DRIFT W/2.64" CENT & SAMPLE BLR TO TAG LINER TOP @11595' RKB 1/20/2020: RIG RELEASED 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: PROD to WINJ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,948'N/A Casing Collapse Conductor Surface Production Slotted Liner Packers and SSSV Type: 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Jennifer McLeod Contact Name:Jennifer McLeod Petroleum Engineer Contact Email: Contact Phone: (907) 265-1050 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Name: Authorized Title:jennifer.mcleod@cop.com Authorized Signature: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3.500'' J-55 PACKER - BAKER HB RETRIEVABLE PACKER Camco TRDP-1A SSSV PACKER MD= 11581 and TVD= 6713 SSSV MD=1816 and TVD=1719 2/13/2020 11,610' Packers and SSSV MD (ft) and TVD (ft): 275' 2 3/8 11,871' 6,805' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,138' 7'' 12,178' 7,002' 79' 16'' 123' 123' 6,289' 9 5/8 6,331' 4,072' Length Size MD TVD Burst N/A P. O. Box 100360, Anchorage, Alaska 99510 50-029-22200-65-00 KRU 1R-23AL2 ADL 25635, ADL 25636, ADL 25627 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,769' 11871 6805 2841psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.219-168-0 Perforate Reppair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Jennifer McLeod Digitally signed by Jennifer McLeod Date: 2020.04.28 13:33:11 -08'00' By Samantha Carlisle at 2:17 pm, Apr 28, 2020 320-184 DSR-4/28/2020 10-404 DLB 4/28/2020VTL 5/4/20 X X X Comm. 5/4/2020 dts 4/4/2020 JLC 5/4/2020 1 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 April 27, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1R- 23AL2 from Oil Production to Water Injection service. Enclosed you will find the 10-403 application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1R-23AL2 (PTD# 219-168). If you have any questions regarding this matter, please contact me at 907-265-1050. Sincerely, Jennifer McLeod Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Application Proposal Summary Area Map Well Schematic Jennifer McLeod Digitally signed by Jennifer McLeod Date: 2020.04.28 13:33:50 -08'00' 1R-23AL2 PROPOSAL SUMMARY ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1R-23AL2 (PTD # 219-168) from Oil Production Service to Water Injection Service. Area of Review: Kuparuk River Unit Well 1R-23AL2 was completed as an unlined CTD lateral leg of well 1R-23A on 1/20/2020. This well was converted to provide water injection into the reservoir to increase the ultimate recovery of oil. Well 1R-23A will provide support to existing producer 1R-25. Area map with 1/4 mile radius around target injection zone (see attached): The map attached shows that there are no wells located within a 1/4 mile radius of the 1R-23AL2 penetration of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1R-23A is good. The CTD well was completed with 275' of slotted liner. The injection tubing/casing annulus is isolated via a Baker HB Retrievable Packer at 11,581' md (6/713' tvd). The well passed a pre-injection MIT on 1/26/2020. A passing state witnessed MIT-IA was performed once well 1R-23A was placed on water injection and stabilized. Interpretation of Cement Quality: Parent well cementing details: The 16" Conductor was cemented with 331 SX AS I. The 9-5/8" Surface casing was cemented with 1300 SX PF E, 630 SX CLASS G. The 7" Production casing was cemented with 380 SX CLASS G. 1R-23A Final CTD Schematic9-5/8" 36# J-55 shoe @ 6331' MD7" 26# L-80 shoe @ 12,178' MD16" 62# H-40 shoe @ 123' MDC-sand perfs squeezed11,710' - 11,770' MDKOP @ 11,682' MD via 7" HEW3-1/2 Camco TRDP-1A SSSV at 1816' MD3-1/2" 9.3# J-55 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrel at 3251'3-1/2" OTIS gas lift mandrel at 11,485'OTIS X Selective landing nipple @ 11,530' MD (2.813" ID)Baker 3-1/2" PBR at 11,568' MD Baker HB packer at 11,581' MD (2.89" ID)OTIS XN-nipple at 11,598' MD (milled out to 2.80")3-1/2" SOS at 11,609' MDModified by RTM 1/30/20201R-23L1PB1TD @ 14,088' MDOH-Anchor Billet @ 12,190' MD1R-23L1PB2TD @ 13,010' MDOH-Anchor Billet @ 12,130' MD1R-23L1PB3TD @ 13,760' MD1R-23APB1TD @ 13,876' MDOH-Anchor Billet @ 13,521' MD and 13,525' MD1R-23ATD @ 14,723' MDOH-Anchor Billet @ 14,075' MDslotted liner 11,595'-11,871'1R-23AL2TD @ 14,948' MD' MDKOP @ 11,651' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 11,735.0 9/21/2019 1R-23 famaj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Added Liner top 1/24/2020 1R-23 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 44.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 42.0 Set Depth (ftKB) 6,330.8 Set Depth (TVD) … 4,072.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 40.0 Set Depth (ftKB) 12,177.7 Set Depth (TVD) … 7,002.5 Wt/Len (l… 26.00 Grade L-80 Top Thread NSCC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.3 Set Depth (ft… 11,609.9 Set Depth (TVD) (… 6,726.7 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUEABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.3 38.3 0.01 HANGER FMC GEN IV TUBING HANGER 3.500 1,816.0 1,719.4 39.09 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 11,529.9 6,689.0 61.87 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 11,567.5 6,706.7 61.89 PBR BAKER PBR 3.000 11,581.2 6,713.1 61.90 PACKER BAKER HB RETRIEVABLE PACKER 2.890 11,597.5 6,720.8 61.91 NIPPLE OTIS XN NIPPLE NO GO 2.750 11,609.2 6,726.3 61.88 SOS BAKER SHEAR OUT SUB 2.992 Tubing Description BOP Test (rig) String Ma…ID (in) Top (ftKB)Set Depth (ft… Set Depth (TVD) (…Wt (lb/ft) Grade Top Connection Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 11,595.0 6,719.6 61.91 CTD Liner CTD 1R-23A liner 1/20/2020 1.990 11,682.0 6,760.7 61.66 WHIPSTOCK Northern Solutions 350-700 High Expansion Wedge. Set 4.6 degrees ROHS. w/ RA tag at 11689' (7' below top of HEW). OAL 8.8' Max OD 2.625" 9/28/2019 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,590.0 11,592.0 6,717.3 6,718.2 UNIT D, 1R-23 11/19/2019 3.0 CMT SQZ 2" Powerflow 3 spf 120 deg phasing. 11,710.0 11,770.0 6,774.1 6,803.1 C-2, C-1, UNIT B, 1R-23 1/5/1992 10.0 IPERF 4.5" Csg Gun; 60 deg ph Frac Summary Start Date 10/11/1995 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/11/1995 Top Depth (ftKB) 11,710.0 Btm (ftKB) 11,770.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 11,590.0 11,770.0 6,717.3 6,803.1 Cement Squeeze 12/15/201 9 C Sand Cement Squeeze 11,590.0 11,770.0 6,717.3 6,803.1 Cement Plug 12/15/201 9 Pumped 16.5 PPG Cement to plug off C Sand 11,590.0 11,609.2 6,717.3 6,726.3 Cement Plug 12/15/201 9 Pumped 16.5 ppg Cement to plug tubing 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 3,250.7 2,493.2 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 10/27/1992 2 11,484.5 6,667.5 OTIS LBD 1 1/2 GAS LIFT DMY RM 0.000 0.0 4/1/1992 Notes: General & Safety End Date Annotation 11/20/2019 NOTE: 1R-23, 4/28/2020 9:11:51 AM Vertical schematic (actual) PRODUCTION; 40.0-12,177.7 "A" Lateral CTD; 11,595.5- 11,871.0 IPERF; 11,710.0-11,770.0 HPBD; 11,710.0 CTD Liner; 11,595.0 WHIPSTOCK; 11,682.0 Cement Squeeze; 11,590.0 ftKB SOS; 11,609.2 NIPPLE; 11,597.5 CMT SQZ; 11,590.0-11,592.0 Cement Plug; 11,590.0 ftKB PACKER; 11,581.3 PBR; 11,567.6 NIPPLE; 11,529.9 GAS LIFT; 11,484.5 SURFACE; 42.0-6,330.8 GAS LIFT; 3,250.7 SAFETY VLV; 1,816.0 CONDUCTOR; 44.0-123.0 HANGER; 38.3 KUP INJ KB-Grd (ft) 42.99 Rig Release Date 10/27/1991 1R-23 ... TD Act Btm (ftKB) 12,180.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292220000 Wellbore Status INJ Max Angle & MD Incl (°) 66.10 MD (ftKB) 3,000.00 WELLNAME WELLBORE1R-23 Annotation Last WO: End Date 1/6/1992 H2S (ppm) DateComment SSSV: TRDP Frac Summary Start Date 10/11/1995 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/11/1995 Top Depth (ftKB) 11,710.0 Btm (ftKB) 11,770.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1R-23AL2, 4/28/2020 9:11:51 AM Vertical schematic (actual) "A" Lateral CTD; 11,595.5- 11,871.0 PRODUCTION; 40.0-12,177.7 CTD Liner; 11,595.0 Cement Squeeze; 11,590.0 ftKB SOS; 11,609.2 NIPPLE; 11,597.5 CMT SQZ; 11,590.0-11,592.0 Cement Plug; 11,590.0 ftKB PACKER; 11,581.3 PBR; 11,567.6 NIPPLE; 11,529.9 GAS LIFT; 11,484.5 SURFACE; 42.0-6,330.8 GAS LIFT; 3,250.7 SAFETY VLV; 1,816.0 CONDUCTOR; 44.0-123.0 HANGER; 38.3 KUP INJ KB-Grd (ft) 42.99 Rig Release Date 10/27/1991 1R-23AL2 ... TD Act Btm (ftKB) 14,948.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292220065 Wellbore Status INJ Max Angle & MD Incl (°) 97.61 MD (ftKB) 13,850.13 WELLNAME WELLBORE1R-23 Annotation End DateH2S (ppm) DateComment DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-65-00Well Name/No. KUPARUK RIV UNIT 1R-23AL2Completion Status1-OILCompletion Date1/20/2020Permit to Drill2191680Operator ConocoPhillips Alaska, Inc.MD14948TVD6769Current Status1-OIL4/20/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC2/10/2020 Electronic File: 1R-23AL2 EOW - NAD27.pdf32029EDDigital DataC2/10/2020 Electronic File: 1R-23AL2 EOW - NAD27.txt32029EDDigital DataC2/10/2020 Electronic File: 1R-23AL2 EOW - NAD83.pdf32029EDDigital DataC2/10/2020 Electronic File: 1R-23AL2 EOW - NAD83.txt32029EDDigital Data0 0 2191680 KUPARUK RIV UNIT 1R-23AL2 LOG HEADERS2191680 KUPARUK RIV UNIT 1R-23AL2 LOG HEADERS32029LogLog Header ScansC2/13/202011086 14948 Electronic Data Set, Filename: 1R-23AL2 GAMMA RES.las32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 2MD Final.cgm32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5MD Final.cgm32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5TVDSS Final.cgm32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 2MD Final.pdf32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5MD Final.pdf32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5TVDSS Final.pdf32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 EOW - NAD27.pdf32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 EOW - NAD27.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 EOW - NAD83.pdf32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 EOW - NAD83.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 Final Surveys TD 14948.csv32036EDDigital DataMonday, April 20, 2020AOGCCPage 1 of 31R-23AL2GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-65-00Well Name/No. KUPARUK RIV UNIT 1R-23AL2Completion Status1-OILCompletion Date1/20/2020Permit to Drill2191680Operator ConocoPhillips Alaska, Inc.MD14948TVD6769Current Status1-OIL4/20/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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: 1/20/2020Release Date:12/4/2019C2/13/2020 Electronic File: 1R-23AL2 Final Surveys TD 14948.xlsx32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 Survey Listing.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 Surveys.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2_25_tapescan_BHI_CTK.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2_5_tapescan_BHI_CTK.txt32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2_output.tap32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 2MD Final.tif32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5MD Final.tif32036EDDigital DataC2/13/2020 Electronic File: 1R-23AL2 5TVDSS Final.tif32036EDDigital Data0 0 2191680 KUPARUK RIV UNIT 1R-23AL2 LOG HEADERS2191680 KUPARUK RIV UNIT 1R-23AL2 LOG HEADERS32036LogLog Header ScansMonday, April 20, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-65-00Well Name/No. KUPARUK RIV UNIT 1R-23AL2Completion Status1-OILCompletion Date1/20/2020Permit to Drill2191680Operator ConocoPhillips Alaska, Inc.MD14948TVD6769Current Status1-OIL4/20/2020UICNoComments:Compliance Reviewed By:Date:Monday, April 20, 2020AOGCCPage 3 of 3M. Guhl4/20/2020 SDF 4/10/2020 VTL 4/17/20 DSR-4/9/2020 Baker � PRINT DISTRIBUTION LIST Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1 R-23AL2 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska 219168 32035 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE January 20, 2020 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cDbakerhughes.com TODAYS DATE February 11, 2020 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 Rev. Requested by: FIELD 1 FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) -9-OF PRINTS # UF PKIN 16 1 # OF COPIES # OF COPIES 1# OF COPIES 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico 11,.W 16- r ATO 708 FEB 3 2020 .700 G Street Anchorage, AK 99510 w -% f- (- r. 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 J —M - SII VI]IUII UI VII M "ab - -- Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Q+.— ,nnnr;m—t;.w — Xn . mi— to nNR V OC GAtlIVI ALIVII �t1lgJhri) �Vl. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 U r 2 1 9 1 6 8 ( Q 32®29 Letter of Transmittal Baker Hughes C I Date: February 7, 2020 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 rom: Harvey Finch Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 ;Please find enclosed the directional survey data for the following well(s): 1R -23A 1R-23APB1 1R -23 -AL2 FEB 0 2020 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch Baker Hughes Wellplanner Harvey.Finch@bakerhughes.com voo ��_� 0 C N 'C O N r x- N w O rh--z _■ = oN O ;t] (D 0 O X77 Q. 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PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-23AL2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-168 Surface Location: 4854' FNL, 144' FWL, SEC. 17, TI 2N, RI OE, UM Bottomhole Location: 4223' FNL, 3334' FWL, SEC. 4, T12N, RIDE, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 219-166, API No. 50-029-22200- 01-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the 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, Je M. rice Chair DATED this day of December, 2019. KLUL1V1=U STATE OF ALASKA NOV 21 2019 ALF, A OIL AND GAS CONSERVATION COMMIL �N PERMIT TO DRILL A P-% r% f"t f' I 20 AAC 25.005 la. Type of Wo Drill ❑ Lateral 0 Redrill ❑ Reentry ❑ d Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil El • Service - Winj ❑ Single Zone ❑� - Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket 0 . Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 1 R-23AL2 ^ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: ^ MD: 17,700 TVD: 6703' 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool - 4a. Location of Well (Governmental Section): Surface: 4854' FNL, 144' FWL, Sec 17, T12N, R10E, UM ^ Top of Productive Horizon: 3976' FNL, 2361' FWL, Sec 9, T12N, R10E, UM Total Depth: 4223' FNL, 3334' FWL, Sec 4, T12N, R10E, UM 7. Property Designation: :. `.5 �. -Z-,7�4-34j ADL 25627 ALK 2560 8. DNR Approval Number: !! • ' �-Z ' j LONS 83-134 13. Approximate Spud Date: 12/5/2019 9. Acres in Propertv: 2560 14. Distance to Nearest Propertv: 2541' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 539830 y- 5991630 - Zone- 4 10. KB Elevation above MSL (ft): 88' GL / BF Elevation above MSL (ft): 45' 15. Distance to Nearest Well Open to Same Pool: 2872', 1 R-35 16. Deviated wells: Kickoff depth: 12,500 • feet Maximum Hole Angle: 101 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3515 R Surface: 2841 - 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) 3" 2-3/8" 4.7# L-80 ST -L 6095' 11,605' . 6724' 17,700' . 6703 Slotted/blank liner with oil & water tracer pups 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): 12180' 7004' N/A 12178' 7003' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 331 sx AS 1 123' 123' Surface 6289' 9-5/8" 1300 sx PF E, 630 sx Class 'G' 6331' 4072' Production 12149' 7" 380 sx Class 'G' 12178' 7003' Perforation Depth MD (ft): 11710'-11770' Perforation Depth TVD (ft): 6774'-6803' Hydraulic Fracture planned? Yes F-1 No ❑ 20. Attachments: Property Plat ❑ BOP Sketch ❑� Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑� 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughlin Authorized Name: James Ohlinger Contact Email: an.mclaU hlin c0 .cOm Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 664e- Ge "I4An Authorized Signature: Date: ComMission Use Only Permit to Drill / /� (� Number: �(—l(G�i API Number; _ 50 L� 2�.�j "'�:� ` Permit Approval Date: i2 ee cover Sletter for other requirements. -� Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: U , Other: 00p fts% fb 35-o O 7 9 Samples req'd: Yes ❑ No Mud log req'd: Yes[] No[l� r �r f� Z 5-7t2r�iieasures: Yes [� No❑ Directional svy req'd: Yes &Z No E] 6 Spacing xception req'd: Yes El Noy Inclination -only svy req'd: Yes[_]Nod Vim%^/ G f-7 C f0 ©'�% ff �' .2 J� d i S (6 y Post initial injection MIT req'd: Yes ❑ No /3 g`avii--d fe 51,/1ot, fhz k1`cA-cF 'po1'ki1 fo be ct Q O {-� f O 3 7 Gj / %7 C G! r��'7 t /Gi f7'I-a- I . / / ✓ APPROVED BY 1 Approved by: COMMISSIONER THE COMMISSION Date:/ { �Z ^f- / Submit Form and Form 1 - evis 17 This permi is valid fo 2 r t f pproval per 20 AAC 25.005(8) Attachments in Duplicate ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 20, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 1 R-23 (PTD# 191-101) using the coiled tubing drilling rig, Nabors CDR3-AC. ° CDR3-AC previously attempted to drill the 1 R-231_1 (219-128) lateral in October 2019, but after drilling 3 plugbacks due to hole cleaning and hole stability issues, the decision was made to RDMO. The well is currently being set-up for a cement pilot hole exit by cement squeezing the original C -sand perforations up to the tubing tail. CDR3-AC plans to return to the well and CTD operations are scheduled to begin on December 5th, 2019. The objective will be to drill three laterals — 1 R -23A and 1 R-23AL1 will be unlined delineation laterals to the north and east, crosscutting through the A3 and C1 sands. 1 R-23AL2 will be drilled to the north targeting the C1 sands and lined with 2-3/8" solid and slotted liner from TD up into the tubing tail. The fourth lateral, 1 R- 23AL3, will be a contingency lateral that will target the C1 sands in an upthrown fault block. This lateral will be drilled only if the oil -water -contact comes in higher than anticipated and the project does not get completed to scope. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1 R -23A, 1 R-23AL1, & 1 R-23AL2, & 1 R-23AL3 - Detailed Summary of Operations - Directional Plans for 1 R -23A, 1 R-23AL1, & 1 R-23AL2, & 1 R-23AL3 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)). ................................................................................................................................................ 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)). .... .................... ............................................................... ...................................................... 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3........................................................7 Attachment 2: Current Well Schematic for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3.............................................7 Attachment 3: Proposed Well Schematic for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3..........................................7 Page 1 of 7 November 11, 2019 PTD Application: 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3. The laterals will be classified as "Development - Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C1 and A3 sand packages in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3517 psi in 1 R-23 (i.e. 10.0 ppg EMW), the maximum potential surface pressure in 1 R-23, assuming a gas gradient of 0.1 psi/ft, would be 2841 psi See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 R-23 was measured to be 3517 psi (10.0 ppg EMW) on 12/20/2010. The maximum downhole pressure in the 1 R-23 vicinity is the 1 R-23 at 3517 psi or 10.0 ppg EMW on 12/20/2010. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 R -23A laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 R -23A laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-2sAL1, & 1 R-23AL2 & 1 R-23AL3 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Existing Casing/Liner Information Category Liner Top Liner Btm Liner Top Liner Btm Top MD Lateral Name MD MD TVDSS TVDSS Liner Details 16" 62.5 H-40 Welded Surface Delineation lateral — will be unlined 1 R -23A N/A N/A N/A N/A with an anchored billet set at 14,100' 36.0 J-55 BTC Surface 6331' MD 4072' 3520 2020 Production 7" Delineation lateral — will be unlined 1 R-23ALl N/A N/A N/A N/A with an anchored billet set at 12,500' 4980 4320 Tubing 3-1/2" 9.3 MD EUEABMOD I Surface 11,610 1 Surface 1 6727' 1 2-3/8", 4.7#, L-80, ST -L slotted/solid 1R-23AL2 11,605' - 17,700' . 6636' 6615' liner, with oil and water tracer pups, and sealbore deployment sleeve 1R-23AL3 11,605' 14,000' 6636' 6500' 2-3/8", 4.7#, L-80, ST -L slotted liner Existing Casing/Liner Information Category OD Weight (ppf)TVD Grade Connection Top MD Btm MD Top Btm TVD Burs t psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 123' Surface 123' 1640 670 Surface 9-5/8" 36.0 J-55 BTC Surface 6331' Surface 4072' 3520 2020 Production 7" 26.0 L-80 NSCC Surface 12,178' Surface 7003' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUEABMOD I Surface 11,610 1 Surface 1 6727' 1 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with a weighted completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 -psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-23NL1, & 1 R-23AL2 & 1 R-23AL3 In the 1 R -23A laterals we will target a constant BHP of 11.8 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1R -23A Window (11,650' MD, 6745' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background In October 2019, CDR3-AC rigged up and attempted to drill 3 laterals out of KRU 1 R-23. After 3 plugbacks while drilling the 1 R-231_1 lateral, due to poor hole conditions and hole cleaning issues, the decision was made to RDMO and reattempt at a later date via cement pilot hole exit. This will require E -line to perforate the tubing tail, and service coil to cement squeeze the C -sand perforations up to the tubing tail. This wellwork is ongoing. CDR3-AC will return to 1 R-23 in mid-December, mill a pilot hole down to 11,680' MD, set a whipstock and mill a 2.80" window in the production casing at a depth of 11,650' MD. After that, the 1 R -23A delineation lateral will be drilled to the north and crosscut through the C1 and A3 sands to determine rock quality and oil -water contact in both sand packages. An anchored billet will be set and the 1 R-23AL1 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to determine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1 R-23AL2 lateral will be drilled to the north, targeting the C1 sands, and ✓, lined with 2-3/8" slotted liner to the tubing tail. If the C1 sands are found to be wet due to a higher than anticipated oil -water -contact, the 1 R-23AL2 lateral will not be drilled and instead a contingency lateral, 1 R-23AL3, will be Page 4 of 7 September 16, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 10.0 3507 psi 3507 psi Mud Hydrostatic 8.6 3016 psi 3016 psi Annular friction (i.e. ECD, 0.080 psi/ft) 932 psi 0 psi Mud + ECD Combined no chokepressure) 3948 psi Overbalanced —441psi) 3016 psi Underbalanced -V491 psi Target BHP at Window 11.8 4139 psi 4139 psi Choke Pressure Required to Maintain Target BHP 191 psi 1123 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background In October 2019, CDR3-AC rigged up and attempted to drill 3 laterals out of KRU 1 R-23. After 3 plugbacks while drilling the 1 R-231_1 lateral, due to poor hole conditions and hole cleaning issues, the decision was made to RDMO and reattempt at a later date via cement pilot hole exit. This will require E -line to perforate the tubing tail, and service coil to cement squeeze the C -sand perforations up to the tubing tail. This wellwork is ongoing. CDR3-AC will return to 1 R-23 in mid-December, mill a pilot hole down to 11,680' MD, set a whipstock and mill a 2.80" window in the production casing at a depth of 11,650' MD. After that, the 1 R -23A delineation lateral will be drilled to the north and crosscut through the C1 and A3 sands to determine rock quality and oil -water contact in both sand packages. An anchored billet will be set and the 1 R-23AL1 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to determine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1 R-23AL2 lateral will be drilled to the north, targeting the C1 sands, and ✓, lined with 2-3/8" slotted liner to the tubing tail. If the C1 sands are found to be wet due to a higher than anticipated oil -water -contact, the 1 R-23AL2 lateral will not be drilled and instead a contingency lateral, 1 R-23AL3, will be Page 4 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-23HL1, & 1 R-23AL2 & 1 R-23AL3 drilled targeting the C1 sands in an upthrown block This lateral will be lined with 2-3/8" slotted liner from TD to the tubing tail. Pre -CTD Work 1. RU E -line: Perforate Tubing Tail 2. RU CTU: Injectivity test, cement 1 R-23 up to the tubing tail, mill XN nipple to 2.80", mill cement to 11,609' MD Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 1 R -23A Lateral (Delineation Lateral A/C Sands - North) a. Mill cement from tubing tail (11,609' MD) to 11,680' MD b. Set whipstock at 11,650' MD c. Mill 2.80" window at 11,650' MD d. Drill 3" bi-center lateral to TD of 15,846' MD e. Set anchored aluminum billet at 14,100' MD 1 R-23AL1 Lateral (Delineation Lateral A/C Sands - East) a. Kickoff of the aluminum billet at 14,100' MD b. Drill 3" bi-center lateral to TD of 16,665' MD c. Set anchored aluminum billet at 12,500' MD 4. 1 R-23AL2 Lateral (Cl Sand - North) a. Kick off of the aluminum billet at 12,500' MD b. Drill 3" bi-center lateral to a TD of 17,700' MD c. Run 2-3/8" slotted/blank liner with oil/water tracer pups and sealbore deployment sleeve from TD up to 11,605' MD 1 R-23AL3 Lateral (C1 Sand - North) a. Kick off of the aluminum billet at 12,400' MD b. Drill 3" bi-center lateral to a TD of 14,000' MD c. Run 2-3/8" slotted liner and sealbore deployment sleeve from TD up to 11,605' MD 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. RU E -Line: Set LTP 2. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. - Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the Page 5 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 R -23A 4790' 1 R-23AL1 3041' 1R-23AL2 2541' 1 R-23AL3 5105' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 R -23A 2935' 1 R-35 1 R-23AL1 3002' 1 R-35 1 R-23AL2 2872' 1 R-35 1 R-23AL3 2972' 1 R-35 Page 6 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-2:IAL1, & 1 R-23AL2 & 1 R-23AL3 16. Attachments Attachment 1: Directional Plans for the IR -23A, 1 R-23AL 1, & 1 R-23AL2 & 1 R-23AL3 laterals Attachment 2: Current Well Schematic for 1R-23 Attachment 3: Proposed CTD Well Schematic for the IR -23A, 1 R-23AL 1, & 1 R-23AL2 & 1 R-23AL3 laterals Page 7 of 7 September 16, 2019 k 2 \ m � S 0 c 0 (u!Gm 009)(+)oNj(-)9mS ` : : { ConocoPh i l l i s p ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1 R Pad 1 R-23 1 R-23AL2 Plan: 1 R-23AL2 wp03 (Draft A) Standard Planning Report 18 November, 2019 ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1 R Pad Well: 1 R-23 Wellbore: 1 R-23AL2 Design: 1 R-23AL2_wp03 (Draft A) ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Baker Hughes S Well 1 R-23 Mean Sea Level 1 R-23 @ 88.00usft (1 R-23) ' True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1R Pad Site Position: Northing: 5,991,050.01 usft Latitude: 70° 23' 11.370 N From: Map Easting: 539,829.93 usft Longitude: 149° 40'33.803 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1 R-23 Well Position +N/ -S 0.00 usft Northing: 5,991,630.19 usft Latitude: 70° 23' 17.076 N +E/ -W 0.00 usft Easting: 539,829.67 usft Longitude: 1490 40'33.721 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 R-23AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2018 12/1/2019 16.33 80.88 57,400 Design 1R-23AL2_wp03 (Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 12,500.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 12,500.00 86.64 39.76 6,672.66 6,161.37 7,475.84 0.00 0.00 0.00 0.00 12,570.00 85.46 37.22 6,677.49 6,216.02 7,519.30 4.00 -1.69 -3.64 245.00 12,770.00 92.02 32.63 6,681.89 6,379.83 7,633.67 4.00 3.28 -2.29 325.00 12,970.00 87.43 26.08 6,682.85 6,554.00 7,731.64 4.00 -2.30 -3.28 235.00 13,070.00 87.45 19.07 6,687.33 6,646.19 7,769.98 7.00 0.02 -7.01 270.00 13,270.00 87.45 19.07 6,696.23 6,835.02 7,835.27 0.00 0.00 0.00 0.00 13,370.00 89.45 15.61 6,698.94 6,930.42 7,865.06 4.00 2.00 -3.46 300.00 13,950.00 89.45 15.61 6,704.50 7,489.00 8,021.13 0.00 0.00 0.00 0.00 14,150.00 97.45 15.61 6,692.47 7,681.12 8,074.81 4.00 4.00 0.00 0.00 14,350.00 97.45 15.61 6,666.54 7,872.11 8,128.18 0.00 0.00 0.00 0.00 14,440.00 100.71 14.06 6,652.33 7,958.01 8,150.94 4.00 3.62 -1.72 335.00 14,745.00 90.10 8.00 6,623.61 8,255.50 8,208.79 4.00 -3.48 -1.99 210.00 16,240.00 90.10 8.00 6,620.88 9,735.95 8,416.80 0.00 0.00 0.00 0.00 16,440.00 90.24 360.00 6,620.27 9,935.31 8,430.74 4.00 0.07 -4.00 271.00 17,700.00 90.24 360.00 6,614.94 11,195.29 8,430.72 0.00 0.00 0.00 0.00 11/1812019 9:16:43AM Page 2 COMPASS 5000.14 Build 85H Planned Survey ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1R-23 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-23 @ 88.00usft (1 R-23) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-23 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-23AL2 Depth Inclination Azimuth Design: 1 R-23AL2_wp03 (Draft A) +N/ -S +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°I100usft) (°) (usft) (usft) 12,500.00 86.64 39.76 6,672.66 6,161.37 7,475.84 6,161.37 0.00 0.00 5,997,830.68 547,271.86 TIP/KOP 12,570.00 85.46 37.22 6,677.49 6,216.02 7,519.30 6,216.02 4.00 -115.00 5,997,885.56 547,315.02 Start DLS 4.00 TFO 325.00 12,600.00 86.44 36.53 6,679.60 6,239.96 7,537.25 6,239.96 4.00 -35.00 5,997,909.59 547,332.84 12,700.00 89.72 34.24 6,682.95 6,321.43 7,595.11 6,321.43 4.00 -34.95 5,997,991.36 547,390.26 12,770.00 92.02 32.63 6,681.89 6,379.83 7,633.67 6,379.83 4.00 -34.87 5,998,049.96 547,428.50 Start DLS 4.00 TFO 235.00 12,800.00 91.33 31.65 6,681.01 6,405.22 7,649.62 6,405.22 4.00 -125.00 5,998,075.44 547,444.32 12,900.00 89.03 28.38 6,680.69 6,491.80 7,699.63 6,491.80 4.00 -125.03 5,998,162.27 547,493.86 12,970.00 87.43 26.08 6,682.85 6,554.00 7,731.64 6,554.00 4.00 -125.04 5,998,224.64 547,525.54 Start DLS 7.00 TFO 270.00 13,000.00 87.43 23.98 6,684.20 6,581.16 7,744.32 6,581.16 7.00 -90.00 5,998,251.85 547,538.07 13,070.00 87.45 19.07 6,687.33 6,646.19 7,769.98 6,646.19 7.00 -89.91 5,998,317.02 547,563.38 Start 200.00 hold at 13070.00 MD 13,100.00 87.45 19.07 6,688.66 6,674.51 7,779.77 6,674.51 0.00 0.00 5,998,345.39 547,573.02 13,200.00 87.45 19.07 6,693.12 6,768.93 7,812.42 6,768.93 0.00 0.00 5,998,439.97 547,605.16 13,270.00 87.45 19.07 6,696.23 6,835.02 7,835.27 6,835.02 0.00 0.00 5,998,506.17 547,627.66 Start DLS 4.00 TFO 300.00 13,300.00 88.05 18.03 6,697.41 6,863.44 7,844.81 6,863.44 4.00 -60.00 5,998,534.64 547,637.04 13,370.00 89.45 15.61 6,698.94 6,930.42 7,865.06 6,930.42 4.00 -59.96 5,998,601.72 547,656.94 Start 580.00 hold at 13370.00 MD 13,400.00 89.45 15.61 6,699.23 6,959.31 7,873.13 6,959.31 0.00 0.00 5,998,630.65 547,664.85 13,500.00 89.45 15.61 6,700.19 7,055.62 7,900.04 7,055.62 0.00 0.00 5,998,727.09 547,691.25 13,600.00 89.45 15.61 6,701.15 7,151.93 7,926.95 7,151.93 0.00 0.00 5,998,823.53 547,717.64 13,700.00 89.45 15.61 6,702.10 7,248.23 7,953.86 7,248.23 0.00 0.00 5,998,919.97 547,744.03 13,800.00 89.45 15.61 6,703.06 7,344.54 7,980.77 7,344.54 0.00 0.00 5,999,016.41 547,770.43 13,900.00 89.45 15.61 6,704.02 7,440.85 8,007.68 7,440.85 0.00 0.00 5,999,112.85 547,796.82 13,950.00 89.45 15.61 6,704.50 7,489.00 8,021.13 7,489.00 0.00 0.00 5,999,161.07 547,810.02 Start Build 4.00 14,000.00 91.45 15.61 6,704.11 7,537.15 8,034.59 7,537.15 4.00 0.00 5,999,209.29 547,823.21 14,100.00 95.45 15.61 6,698.09 7,633.27 8,061.44 7,633.27 4.00 0.00 5,999,305.54 547,849.55 14,150.00 97.45 15.61 6,692.47 7,681.12 8,074.81 7,681.12 4.00 0.00 5,999,353.45 547,862.67 Start 200.00 hold at 14150.00 MD 14,200.00 97.45 15.61 6,685.99 7,728.87 8,088.15 7,728.87 0.00 0.00 5,999,401.26 547,875.75 14,300.00 97.45 15.61 6,673.02 7,824.36 8,114.84 7,824.36 0.00 0.00 5,999,496.89 547,901.93 14,350.00 97.45 15.61 6,666.54 7,872.11 8,128.18 7,872.11 0.00 0.00 5,999,544.71 547,915.01 Start DLS 4.00 TFO 335.00 14,400.00 99.26 14.75 6,659.27 7,919.85 8,141.14 7,919.85 4.00 -25.00 5,999,592.51 547,927.71 14,440.00 100.71 14.06 6,652.33 7,958.01 8,150.94 7,958.01 4.00 -25.12 5,999,630.71 547,937.31 Start DLS 4.00 TFO 210.00 14,500.00 98.63 12.85 6,642.26 8,015.53 8,164.70 8,015.53 4.00 -150.00 5,999,688.30 547,950.76 14,600.00 95.15 10.86 6,630.26 8,112.67 8,185.08 8,112.67 4.00 -150.20 5,999,785.54 547,970.62 14,700.00 91.67 8.88 6,624.30 8,210.99 8,202.18 8,210.99 4.00 -150.44 5,999,883.94 547,987.20 14,745.00 90.10 8.00 6,623.61 8,255.50 8,208.79 8,255.50 4.00 -150.56 5,999,928.48 547,993.57 Start 1495.00 hold at 14745.00 MD 14,800.00 90.10 8.00 6,623.51 8,309.96 8,216.44 8,309.96 0.00 0.00 5,999,982.98 548,000.93 14,900.00 90.10 8.00 6,623.32 8,408.99 8,230.35 8,408.99 0.00 0.00 6,000,082.07 548,014.31 15,000.00 90.10 8.00 6,623.14 8,508.02 8,244.27 8,508.02 0.00 0.00 6,000,181.16 548,027.70 15,100.00 90.10 8.00 6,622.96 8,607.05 8,258.18 8,607.05 0.00 0.00 6,000,280.25 548,041.08 15,200.00 90.10 8.00 6,622.78 8,706.07 8,272.10 8,706.07 0.00 0.00 6,000,379.34 548,054.47 15,300.00 90.10 8.00 6,622.59 8,805.10 8,286.01 8,805.10 0.00 0.00 6,000,478.43 548,067.85 1111812019 9:16:43AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: Company: Project: Site: Well: Wellbore: Design: EDT 14 Alaska Production ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit Kuparuk 1 R Pad 1 R-23 1 R-23AL2 1 R-23AL2_wp03 (Draft A) Local Co-ordinate Reference: Well 1 R-23 TVD Reference: Mean Sea Level MD Reference: 1 R-23 @ 88.00usft (1 R-23) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/_W Section Rate Azimuth Northing Easting (usft) I (°) (I (usft) (usft) (usft) (usft) ('1100usft) (°) (usft) (usft) 15,400.00 90.10 8.00 6,622.41 8,904.13 8,299.92 8,904.13 0.00 0.00 6,000,577.52 548,081.24 15,500.00 90.10 8.00 6,622.23 9,003.15 8,313.84 9,003.15 0.00 0.00 6,000,676.61 548,094.62 15,600.00 90.10 8.00 6,622.05 9,102.18 8,327.75 9,102.18 0.00 0.00 6,000,775.70 548,108.01 15,700.00 90.10 8.00 6,621.87 9,201.21 8,341.67 9,201.21 0.00 0.00 6,000,874.79 548,121.39 15,800.00 90.10 8.00 6,621.68 9,300.24 8,355.58 9,300.24 0.00 0.00 6,000,973.88 548,134.78 15,900.00 90.10 8.00 6,621.50 9,399.26 8,369.49 9,399.26 0.00 0.00 6,001,072.97 548,148.16 16,000.00 90.10 8.00 6,621.32 9,498.29 8,383.41 9,498.29 0.00 0.00 6,001,172.06 548,161.55 16,100.00 90.10 8.00 6,621.14 9,597.32 8,397.32 9,597.32 0.00 0.00 6,001,271.15 548,174.93 16,200.00 90.10 8.00 6,620.95 9,696.34 8,411.23 9,696.34 0.00 0.00 6,001,370.24 548,188.32 16,240.00 90.10 8.00 6,620.88 9,735.95 8,416.80 9,735.95 0.00 0.00 6,001,409.88 548,193.67 Start DLS 4.00 TFO 271.00 16,300.00 90.15 5.60 6,620.75 9,795.53 8,423.90 9,795.53 4.00 -89.00 6,001,469.48 548,200.46 16,400.00 90.22 1.60 6,620.43 9,895.31 8,430.18 9,895.31 4.00 -89.01 6,001,569.29 548,206.20 16,440.00 90.24 360.00 6,620.27 9,935.31 8,430.74 9,935.31 4.00 -89.02 6,001,609.28 548,206.54 Start 1260.00 hold at 16440.00 MD 16,500.00 90.24 360.00 6,620.02 9,995.30 8,430.73 9,995.30 0.00 0.00 6,001,669.27 548,206.22 16,600.00 90.24 360.00 6,619.60 10,095.30 8,430.73 10,095.30 0.00 0.00 6,001,769.26 548,205.69 16,700.00 90.24 360.00 6,619.17 10,195.30 8,430.73 10,195.30 0.00 0.00 6,001,869.25 548,205.16 16,800.00 90.24 360.00 6,618.75 10,295.30 8,430.73 10,295.30 0.00 0.00 6,001,969.24 548,204.62 16,900.00 90.24 360.00 6,618.33 10,395.30 8,430.73 10,395.30 0.00 0.00 6,002,069.22 548,204.09 17,000.00 90.24 360.00 6,617.90 10,495.30 8,430.73 10,495.30 0.00 0.00 6,002,169.21 548,203.55 17,100.00 90.24 360.00 6,617.48 10,595.30 8,430.73 10,595.30 0.00 0.00 6,002,269.20 548,203.02 17,200.00 90.24 360.00 6,617.06 10,695.30 8,430.72 10,695.30 0.00 0.00 6,002,369.19 548,202.49 17,300.00 90.24 360.00 6,616.63 10,795.30 8,430.72 10,795.30 0.00 0.00 6,002,469.18 548,201.95 17,400.00 90.24 360.00 6,616.21 10,895.30 8,430.72 10,895.30 0.00 0.00 6,002,569.16 548,201.42 17,500.00 90.24 360.00 6,615.79 10,995.30 8,430.72 10,995.30 0.00 0.00 6,002,669.15 548,200.88 17,600.00 90.24 360.00 6,615.36 11,095.29 8,430.72 11,095.29 0.00 0.00 6,002,769.14 548,200.35 17,700.00 90.24 360.00 6,614.94 ' 11,195.29 8,430.72 11,195.29 0.00 0.00 6,002,869.13 548,199.82 Planned TD at 17700.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 17,700.00 6,614.94 2-3/8" 2.375 3.000 11/18/2019 9.16:43AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes S Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1R Pad Well: 1 R-23 Wellbore: 1 R-23AL2 Design: 1 R-23AL2_wp03 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 R-23 Mean Sea Level 1 R-23 @ 88.00usft (1 R-23) True Minimum Curvature Plan Annotations i Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 12,500.00 6,672.66 6,161.37 7,475.84 TIP/KOP 12,570.00 6,677.49 6,216.02 7,519.30 Start DLS 4.00 TFO 325.00 12,770.00 6,681.89 6,379.83 7,633.67 Start DLS 4.00 TFO 235.00 12,970.00 6,682.85 6,554.00 7,731.64 Start DLS 7.00 TFO 270.00 13,070.00 6,687.33 6,646.19 7,769.98 Start 200.00 hold at 13070.00 MD 13,270.00 6,696.23 6,835.02 7,835.27 Start DLS 4.00 TFO 300.00 13,370.00 6,698.94 6,930.42 7,865.06 Start 580.00 hold at 13370.00 MD 13,950.00 6,704.50 7,489.00 8,021.13 Start Build 4.00 14,150.00 6,692.47 7,681.12 8,074.81 Start 200.00 hold at 14150.00 MD 14,350.00 6,666.54 7,872.11 8,128.18 Start DLS 4.00 TFO 335.00 14,440.00 6,652.33 7,958.01 8,150.94 Start DLS 4.00 TFO 210.00 14,745.00 6,623.61 8,255.50 8,208.79 Start 1495.00 hold at 14745.00 MD 16,240.00 6,620.88 9,735.95 8,416.80 Start DLS 4.00 TFO 271.00 16,440.00 6,620.27 9,935.31 8,430.74 Start 1260.00 hold at 16440.00 MD 17,700.00 6,614.94 11,195.29 8,430.72 Planned TD at 17700.00 11/18/2019 9:16.43AM Page 5 COMPASS 5000.14 Build 85H 1111.1 ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 1 R Pad Site Error: 0.00 usft Reference Well: 1 R-23 Well Error: 0.00 usft Reference Wellbore 1R-23AL2 Reference Design: 1 R-23AL2_wpO3 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1R-23 1 R-23 @ 88.00usft (1 R-23) 1 R-23 @ 88.00usft (1 R-23) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 1R-23AL2_wpO3 (Draft A) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 12,500.00 to 17,700.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 11/15/2019 From To Minimum Reference (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 11,600.00 1 R-23 (1 R-23) GCT -MS Schlumberger GCT multishot 11,600.00 12,500.00 1R-23A_wpO6(Draft A)(1R-23A) MWD OWSG OWSGMWD- Standard 12,500.00 17,700.00 1R-23AL2_wp03 (Draft A) (1R-23AL2) MWD OWSG OWSG MWD - Standard Summary Between Between Minimum Reference Offset Distance Separation Factor (usft) Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) 1.69 Kuparuk 1 R Pad 3.177 3.16 2.16 1.00 3.166 1 R-23 - 1 R -23A - 1 R-23A_wpO6 (Draft A) 12,824.73 12,825.00 5.89 1.59 1.370 Take Immediate Action, CC, 1 R-23 - 1 R -23A - 1 R-23A_wpO6 (Draft A) 14,928.94 14,950.00 52.53 4.93 1.104 Take Immediate Action, SF 1R-23- 1R-23AL1 - 1R-23AL1_wp04 (Draft A) 12,824.73 12,825.00 5.89 1.59 1.370 Take Immediate Action, CC, 1 R-23 - 1 R-23AL3 - 1 R-23AL3_wp01 ( Draft A) 12,720.47 12,725.00 63.12 62.76 177.398 CC, ES 1 R-23 - 1 R-23AL3 - 1 R-23A13_wp01 (Draft A) 13,958.27 14,000.00 239.80 227.21 19.040 SF 1 R-23 - 1 R-231-1 PB1 - 1 R-2311 PB1 13,076.99 13,200.00 69.84 54.90 4.676 CC 1 R-23 - 1 R-231-1 PB1 - 1 R-231-1 PB1 13,101.58 13,225.00 69.92 54.85 4.640 ES, SF 1 R-23 - 1 R-2311 PB2 - 1 R-2311 PB2 12,500.00 12,550.00 200.51 193.46 28.466 CC, ES 1 R-23 - 1 R-231-1 PB2 - 1 R-231-1 PB2 12,910.76 13,010.00 217.44 205.15 17.691 SF 1 R-23 - 1 R-2311 PB3 - 1 R-231-1 PB3 13,513.66 13,760.00 202.06 181.09 9.632 CC, ES, SF 1 R-35 - 1 R-35 - 1 R-35 Out of range 1 R-35 - 1 R-35 - 1 R-35 Out of range 1 R-35 - 1 R-35 - 1 R-35 TD Projection Out of range 1 R-36 - 1 R-36 - 1 R-36 Out of range Offset Design Kuparuk 1 R Pad - 1 R-23 - 1 R -23A - 1 R-23A_wp06 (Draft A) Survey Program: 100 -GCT -MS, 11600 -MWD OWSG Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Depth Depth Depth Depth from North +N/ -S +El -W (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) 12,525.00 6,762.22 12,525.00 6,762.06 0.08 0.18 65.32 6,180.63 7491.71 12,549.99 6,763.96 12,550.00 6,763.32 0.17 0.37 64.47 6,200.05 7,507.41 12,574.96 6,765.87 12,575.00 6,764.45 0.25 0.56 63.75 6,219.62 7,522.93 12,599.96 6,767.60 12,600.00 6,765.43 0.34 D.75 64.99 6,239.34 7,538.26 12,624.97 6,768.98 12,625.00 6,766.29 0.45 0.96 67.47 6,259.21 7,553.41 12.649.99 6,769.99 12,650.00 6,767.00 0.55 1.16 70.94 6,279.22 7.568.37 12,675.00 6,770.65 12,675.00 6,767.58 0.66 1.36 75.50 6,299.38 7,583.15 12,700.01 6,770.95 12,700.00 6,768.02 0.76 1.56 81.37 6,319.68 7,597.73 12,725.01 6,770.89 12,725.00 6,768.37 0.88 1.78 89.21 6,340.12 7,612.12 12,749.98 6,770.48 12,750.00 6,768.72 1.00 1.99 100.26 6,360.72 7,626.28 12,774.92 6,769.72 12,775.00 6,769.07 1.12 2.21 114.56 6,381.47 7,640.22 Offset Site Error: 0.00 usft Offset Well Error: 0.00 usft Distance Between Between Minimum Separation Warning Centres Ellipses Separation Factor (usft) (usft) (usft) 0.18 -0.17 0.35 0.509 STOP Drilling 0.72 0.24 0.48 1.495 Take Immediate Action 1.60 0.99 0.61 2.616 Normal Operations 2.47 1.69 0.78 3.177 3.16 2.16 1.00 3.166 3.68 2.41 1.27 2.898 Normal Operations 4.05 2.45 1.60 2.527 Normal Operations 4.31 2.3D 2.01 2.146 Caution Monitor Closely 4.45 1.94 2.51 1.775 Caution Monitor Closely 4.52 1.43 3.09 1.462 Take Immediate Action 4.68 1.04 3.64 1.264 Take Immediate Action CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1111512019 2:05:10PM Page 2 COMPASS 5000.14 Build 85H N 'o ■ 0 0 0 0 0 00 0 P, o 0 0 0 0 0 0 m o o o 0 000 ;a0 t500o0o� -HF-'oH o O O O t O L O L O O L O L (6 0 0 0 a i ti o vo o v v v o 47 Oa JJ J O JO � OJ J m -j o 3 o 000N0i. m100�O�2 d r c Jo sss ¢ rn �n cn rn cn rn cn cn in cn cn w c) n "' NNM OONN ON.-�O d u n tO Oil VJ N too u7 t71� (p 1� tC) V'M MCO I" - N r r -NM lC)(D cOm V CO N O Cl O O o 0 0 O 0 0 0 0 Cl 0 Cl y Z O Cl 0 0 0 0 0 0 0 0 0 0 0 0 0 O'cl, OgNMOO�000M00 �O P m 00 0 0 0 0 0 0 0 0 0 0 0 0 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ovovovvovo V O cc cc! 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The paperwork has just increased. This is what is needed: 1. A plug for redrill sundry for KRU 1R-23(PTD 191-101); we can change this existing sundry(319-492) to plug for redrill by hand. No need to resubmit the whipstock sundry. 2. However, the naming convention of the sidetrack and laterals must change as follows and new PTDs must be submitted: a. Well KRU 111-231-1 will need to be resubmitted as KRU 111-23A b. Well KRU 1R-231-1-01 will need to be resubmitted as KRU 1R -23A-01 c. Well KRU 111-231-1-02 will need to be resubmitted as KRU 1R -23A-02 d. These will all be assigned new PTD and API numbers. The motherbore will be abandoned and the KRU 111-231-1 closed out. I will route the plug for redrill whipstock for KRU 111-23 for approval today or Monday. However, please submit the required new PTDs. So sorry for the additional paperwork. let me know if any clarification is needed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loe1pp4alaska.gov Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, October 29, 2019 10:18 AM To: McLaughlin, Ryan Cc: Ohlinger, James J Subject: KRU 1 R-23L1(PTD 219-128) Operations Shutdown Request Follow Up Flag: Follow up Flag Status: Completed Ryan, Verbal approval is granted for the Operations Shutdown for CRD3-AC for KRU 1R-23L1(PTD 219-128). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a-)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepo@alaska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, October 29, 201910:13 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Subject: 1R-23 (PTD 191-101) Operations Shutdown Request Hello Victoria On October 16th CDR3-AC rigged up to drill a tri -lateral project on 1R-23. After 3 unsuccessful attempts at drilling the 1R -23L1 lateral, primarily due to hole cleaning issues in the 7" production casing, the decision was made to rig down CDR3-AC from 111-23 and set the well up for a cement pilot hole exit for the rig to come back at a later date and complete the scope of the project under the approved PTD. In preparation for resuming CTD operations on this well, perforations will be shot in the tubing tail, cement will be pumped to occupy the 7" casing and plug off C -sand perforations, and the XN nipple in the tubing tail will be milled out. CDR3-AC will mill a cement pilot hole, set a 3-1/2" whipstock, and mill a 2.80" window in the production casing at a depth of 11,662' MD and complete the original scope of the project under the existing permits . We are requesting verbal approval for an Operations Shutdown with the Sundry to oe submitted today. We will also submit a subsequent sundry request for cement -squeezing the C -sand perforations and setting a new whipstock prior to beginning the service coil work. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, November 7, 2019 9:18 AM To: Melvin Rixse; Schwartz, Guy L (CED) Cc: Chmielowski, Jessie L C (CED); Carlisle, Samantha J (CED); Boyer, David L (CED) Subject: FYI: KRU/CRU PTD(10-401 s) while Victoria on A/L Attachments: Sonic Conditions of Approval.docx; Permit_219-140_101619.pdf, 8.13.19 Conditions of Approval NFT.SSSV.ESP 311-111.docx; Perm it_219-134_102219.pdf Mel, Guy, Sam, FYI Rotary PTDs that will be submitted for AOGCC approval include KRU 3R-107(producer) and CRU CD5-96: Guy will handle these. Guy attached are conditions of approval that I'm attaching to DS -3R producers relating to the no flow test required for elimination of the SSSV requirement. I worked on these conditions with Jim and would like to be consistent with the DS -3R producers. CTD PTDs that will be submitted include KRU 1R-23 sidetrack and laterals and 3H-01 sidetrack and laterals: Mel will handle these; Mel, I attached 10-401 "condition" for kickoff point variance so you can see what we have been granting on these CTD laterals. Note, originally the 1R-23 PTDs were approved as laterals because C sand was left open in the motherbore. This has changed. They are now plugging the motherbore and drilling a sidetrack (1R -23A) plus laterals. The plug for redrill sundry for the motherbore has been approved however they will be submitting new PTDs(10-401s) for the 1R-23 sidetrack and laterals. Also attached is 10-401 Conditions of Approval for running the sonic for cement evaluation for wells to be fracked or injectors which I have been including as a part of the 10-401 approval. Thank you! Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp a(_.alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or v Ctcr 1 oer))) ��Ins qo_v_ TRANSMITTAL LETTER CHECKLIST WELL NAME: IC Li �� Z3 /� L.- z PTD: 2– Development Development _ Service _ Exploratory — Stratigraphic Test _ Non -Conventional l FIELD:/�' r �t�v' POOL: J ,�e _r i ... ' i I L r 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. Z– t'' ��(� API No. 50- - (If last two digits Production should continue to be reported as function in API number are a of the original API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs Pilot Hole acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - - ) from records, data and logs acquired for well name on rmit . The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Exception Approval to Produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Comnanv Name) Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where sam les are first caught and 10' sam le intervals throug4 target zones. Please note the following special condition of this permit: Non -Conventional production or production testing of coal bed methane is not allowed for (name of well1 until after (Company Name) has designed Well and implemented a water well testing program to provide baseline data on water quality and quantity. (Compan Namel must contact the AOGCC to obtain advance a royal of such water well testin Program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 da s after com letion, su rasion or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well - - Well Name: KUPARUK RIV UNIT 1R-23AL2 Program DEV Well bore seg 9JPTD#: 2191680 Company ConocoPhillips Alaska. Inc. Initial Class/Type DEV/PEND GeoArea 890_ _ Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - _ NA_ 2 Lease number appropriate_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - Surface Location lies within ADL0025635; Portion -of Well Passes Thru ADL0025636;- 3 Unique well -name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - To Prod Int_& TD of -this Lateral I_ie within -ADI -002-5627. _ - 4 Well located in a_definedpool- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes -- - - - - Kuparuk River Oil Pool, governed by Conservation Order No. 432D - _ - _ _ _ - - - - - 5 Well located proper distance from_ drilling unit -boundary -------- Yes - - - - - - CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened in_ - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - Yes - - - - a well_ closer_than_500 feet to an external property -line where ownership or landownership changes._ 7 Sufficient acreage available in -drilling unit_ - - - - - - - - - - - - - - Yes -- - - - - As planned, this lateral well branch conforms with_ spacing_ requirements- - - - - - - - - - - - - - 8 If deviated, -is-wellbore plat_induded - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - _ _ - _ 9 Operator only affected party - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - ------------------------------------- 10 Operator has -appropriate bond in force - - - - - - - - - - - - - Yes - - - - - - - - - 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - - - Yes - - ---------------------------------------------------- - - - - - - - - Appr Date 12 Permit_ can be issued without admin istrativ_e_approval -- - - - - - - - - - - - - Yes- - . - - - - - - - - - - - - - - - -- - -- -- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 13 Can permit be approved before 15-daywait_ Yes- SFD 11/22/2019 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - _ - - - 14 Well located within area and_strata authorized by -Injection Order # (put_10# in_comments)_(For_ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - 15 All wells -within -1/4-mile-area-of review identified (For seryice well only) - - - _ _ _ _ _ _ _ NA_ 16 Pre -produced injector_ duration of pre production less than 3 months _(For service well only) - _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven. gas conforms to AS31,05.030(1.1_.A),0.2_.A-D) NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string -provided - - - - - - - - _ - _ _ _ NA_ _ _ _ _ _ _ _ Conductor set_for _KRU_ 1_R-23 Engineering 19 Surface casing -protects all -known_ USDWs - - - - - - - - - - - - - - NA_ - - - - - - - Surface casing set for KRU_1R-23_ - - - - - 20 CMT_vol_adequate_to circulate on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - Surface casing set and fully_cemented - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_ vol_ adequate_ to tie-in long string to surf csg----------------------------- A_ - _ - _ _ _ _ - - _ - --------------------_ _ - - _ - - - - - _ _ _ _ _ - _ _ . - _ - - - - - - 22 CMT -will cover all known productive horizons- - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ _ Productive -interval will be completed with- an -uncemented solid/sl_otted_ liner_ - 23 Casing designs adequate for C, T, B &_permafrost- - - - - - - - - - - - - - - - - - - - - - _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ---------- 24 Adequate tankage_or reserve pit - - - - - - - - - - _ - - - - - - _ _ _ Yes Rig has steel tanks; all -waste -to approved disposal wells_ - - - - 25 -Ifa_re-drill, has_a_ 10-403 for abandonment been approved - - - - - ---- - - - - - - - - - - - _ NA_ - - - - - _----------------------------------------- - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ - Anti -collision analysis complete; no major risk failures - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ 27 If diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ - - - - - - - ----------------------- _ _ - - - - - - - - - - - - - - - - - -- Appr Date 28 Drilling fluid_ program schematic & equip -list-adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ _ _ _ Max formation_ pressure is 3515 psig(10 ppg E_M_W); will drill w/ 8.6-ppg EMW_ and maintain overbal_w/ MPD_ _ _ - VTL 12/4/2019 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE-press rating appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP is 2841_ psig; will test BOPs_to 3500_p5ig _ _ - - - - - - _ _ _ _ - _ _ _ _ _ _ _ _ - - - - - _ _ _ _ _ _ 31 Choke_manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - _ -------------- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ _ _ _ _ _ _ _ --------------------------------------------------------------- 33 Is presence of 1-12S gas probable_ - - Yes _ _ _ _ _ - _ 1-12S measures required - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical condition of wells within AOR verified (For service well only) - - - - - - - - - _ NA_ --------------------- ------- - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit_can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No No_ _ _ _ _ _ _ _ Wells_on_1R-Pad are_H2S-bearing. 1-12S measures required. - - - - - - - _ - - - - _ - _ _ _ - ---- - --- - - -- Geology 36 Data -presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - _ - _ . - Expected reservoir pressure is 10.0 ppg, with some potential of higher pressure due to gas - - - - - - - Appr Date 37 Seismic analysis_ of shallow gas_zones_ _ _ _ _------------------ - _ -------- NA - _ - - - - - _ injection within this area. Well will be drilled using 8.6 ppg mud,a coiled -tubing rig, and SFD 11/22/2019 38 Seabed condition survey (if off -shore) _ - - - - - - ---------------_ _ _ _ _ _ _ _ - NA_ _ _ - _ _ _ - managed pressure drilling -technique to control_ formation_ pressures and_stabilize shale sections_by---------- 39 Contact name/phone for weekly -progress reports_ [exploratory only] - - - - - - - - - - - - - - - - NA_ _ _ _ - _ - _ maintaining a constant pressure gradient of about 1.1.8_ ppg EMW. - - - _ _ - - - - - - - - - - - - - _ _ - Geologic Engineering Public Commissioner: Date: Commissioner: Date mmissi n Date