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200-040
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ ConocoPhillips Alaska, Inc.Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11956 feet Cement top: 8306 feet true vertical 9595 feet 10737 feet Effective Depth measured 8306 feet 8671, 10716 feet true vertical 6365 feet 6634, 8396 feet Perforation depth Measured depth 8750-11813 feet True Vertical depth 6694-9456 feet Tubing (size, grade, measured and true vertical depth)3-1/2"L-80 10790' 8467' Packers and SSSV (type, measured and true vertical depth) Packer HLB THB Prod Packer 8671 6634 Packer HLB THB Prod Packer 10716 8396 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:NA 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Kate Dodson Contact Email:WNSIntegrity@conocophillips.com Authorized Title:Senior Interventions and Integrity Engineer Contact Phone:907-265-6181 2020' Burst Collapse measured TVD Production Liner 11912' Casing Structural 9562'11947' Plugs Junk measured NA Length 76' 2789' 114'Conductor Surface Intermediate 16" 9-5/8" NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025557, ADL0025558, ADL0025559 Colville River Field/ Undefined WDSP CRU CD1-19A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-040 50-103-20294-01-00 P.O. Box 100360, Anchorage, AK 995103. Address: NA 7" NA NANA NA NANA measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD NA Size 114' 2826' Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG NA Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) NA NA p k ft t Fra O s O 200 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 4:05 pm, Apr 18, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 18, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry for CRU CD1-19A (PTD 200-040) Commissioner Chmielowski, Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. well CRU CD1-19A (PTD 200-040). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection Form - Photographs - Location Plot Plan - Wellbore Schematic Please contact me 265-6181 if you have any questions. Sincerely, Kate Dodson Well Integrity Specialist ConocoPhillips Alaska, Inc. CD1-19A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: TOC 8,306.0 5/8/2013 CD1-19A osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CMT Retainers/CMT IA/Suspend Well, Tag 5/13/2013 CD1-19A osborl Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 114.0 Set Depth (TVD) 114.0 Wt/Len (lb 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.8 Set Depth (ftKB) 2,825.9 Set Depth (TVD) 2,393.5 Wt/Len (lb 36.00 Grade J-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.9 Set Depth (ftKB) 11,947.2 Set Depth (TVD) 9,586.2 Wt/Len (lb 26.00 Grade L-80 Top Connection BTCM Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String 3 1/2 ID (in) 2.99 Top (ftKB) 32.9 Set Depth (ft 10,791.6 Set Depth (TVD 8,468.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 32.9 32.9 0.00 HANGER 4.500 10.800 1,794.6 1,701.6 39.04 NIPPLE 2.813 4.520 8,670.7 6,633.5 42.81 PACKER 3.875 5.875 10,715.9 8,395.8 16.78 PACKER 3.875 5.875 10,778.4 8,455.6 16.44 NIPPLE 2.750 4.260 10,789.9 8,466.7 16.38 WLEG 3.125 4.520 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Des Com Run Date ID (in) SN 8,610.0 6,589.0 42.84 TBG PUNCHES 5' OF TUBING PUNCHES, 4spf, 0 DEGREE PHASE 4/20/2013 2.992 10,112. 0 7,824.6 20.49 CMT Retainer WEATHERFORD CEMENT RETAINER 5/1/2013 10,689. 0 8,370.0 17.00 CMT Retainer WEATHERFORD CEMENT RETAINER 4/28/2013 10,737. 0 8,416.0 16.64 FISH SLICKLINE TOOL STRING, PLUG & GAUGES (OAL=31'2") 5/24/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,750.0 8,760.0 6,691.7 6,699.0 K-1 Marker, CD1-19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5, CD1- 19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, CD1- 19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, CD1- 19A 1/5/2003 12.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,720.0 11,740.0 9,365.6 9,385.0 IVISHAK, CD1- 19A 1/5/2003 6.0 APERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, CD1- 19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, CD1- 19A 6/3/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, CD1- 19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, CD1- 19A 6/2/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, CD1- 19A 2/27/2003 6.0 IPERF 2.5" HSD HJ 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, CD1- 19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, CD1- 19A 2/27/2003 12.0 RPERF 2.5" HSD HJ Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,420.0 10,689.0 8,114.4 8,370.0 CMT PLUG 8,306.0 10,420.0 6,365.4 8,114.4 CMT PLUG 5/1/2013 7,776.0 8,610.0 5,978.5 6,589.0 CMT PLUG INNER ANNULUS 5/4/2013 8,306.0 8,610.0 6,365.4 6,589.0 CMT PLUG 5/5/2013 Notes: General & Safety End Date Annotation 5/5/2013 NOTE: WELL SUSPENDED, TUBING/CASING/IA CEMENTED; TBG TOC @ 8306'; IA TOC 7776' 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 CD1-19A, 5/20/2022 1:47:24 PM Vertical schematic (actual) PRODUCTION; 34.9-11,947.2 RPERF; 11,803.0-11,813.0 IPERF; 11,800.0-11,803.0 IPERF; 11,793.0-11,794.0 RPERF; 11,780.0-11,793.0 IPERF; 11,768.0-11,776.0 RPERF; 11,750.0-11,763.0 RPERF; 11,749.0-11,750.0 APERF; 11,720.0-11,740.0 RPERF; 11,504.0-11,520.0 RPERF; 11,463.0-11,483.0 FISH; 10,737.0 PACKER; 10,715.9 CMT Retainer; 10,689.0 CMT PLUG; 10,420.0 ftKB CMT Retainer; 10,112.0 IPERF; 8,990.0-9,000.0 IPERF; 8,750.0-8,760.0 PACKER; 8,670.7 TBG PUNCHES; 8,610.0 CMT PLUG; 8,306.0 ftKB CMT PLUG; 8,306.0 ftKB CMT PLUG; 7,776.0 ftKB SURFACE; 36.8-2,825.9 NIPPLE; 1,794.6 CONDUCTOR; 38.0-114.0 WNS DISP KB-Grd (ft) 44.16 RR Date 4/21/1999 Other Elev CD1-19A ... TD Act Btm (ftKB) 11,956.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032029401 Wellbore Status DISP Max Angle & MD Incl (°) 54.05 MD (ftKB) 2,710.56 WELLNAME WELLBORECD1-19A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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 Suspension Renewalr: ___________________ 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?NA Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Colville River Field/ Undefined WDSP 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11956' 9595' 8306' 6365' Cement Top: 8306' 10737' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Kate Dodson Contact Email: WNSintegrity@conocophillips.com Contact Phone: 907-265-6181 Authorized Title: Conditions of approval: Notify AOGCC 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 AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 8671' MD and 6633' TVD Packer: 10716' MD and 8396' TVD SSSV: N/A Perforation Depth TVD (ft): Tubing Size: L-80 10790' 6/30/2022 Packer: HLB THB Prod Packer Packer: HLB THB Prod Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025557 Exp: 7/31/2026 ADL025558 Exp: 7/31/2026 ADL025559 Exp: 8/31/2031 200-040 P.O. Box 100360, Anchorage, AK 99510 50-103-20294-01-00 ConocoPhillips Alaska, Inc CRU CD1-19A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY MD 114' 2020' 114' 2826' 9562'11947' 16" 9-5/8" 76' 2789' Perforation Depth MD (ft): 8750-11813' 11912' 6694-9456' 3-1/2" 7" Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-232 By Kayla Junke at 3:33 pm, Apr 18, 2023 Kathleen Dodson Digitally signed by Kathleen Dodson Date: 2023.04.18 14:02:24 -08'00' DSR-4/18/23 suspension renewal effective for five years from approval date of this sundry. X SFD 6/8/2023 2023 SFD 10-407 VTL 7/19/2023$%8($8 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.01 13:23:16 -08'00'11/01/23 RBDMS JSB 110223 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Renewal Colville River Unit CD1-19A (PTD 200-040) Please call me on 265-6181 if you have any questions. Sincerely, Kate Dodson Well Integrity Specialist ConocoPhillips Alaska, Inc. Dear Commissioner Chmielowski: Enclosed please find the suspended well renewal application as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Colville River Unit well CD1-19A (PTD 200- 040). CD1-19A holds potential for future utility as a Class I disposal well, targeting the Ivishak formation, if it were sidetracked from the existing casing. CD1-19A served as a permitted Class I well in the past, and the need for this type of service at CD1 will continue throughout the life of the WNS area. CD1-19A could be determined to be an acceptable sidetrack mother bore during future scoping of disposal candidates. Currently CD1-19A’s OA has shown no indications of communication with near formations as the OA pressure remains stable. The well was cemented in 2013, with cement plugs in both the tubing and inner annulus to fully isolate formation from fluid movement to surface or other formations. CD1-19A is located on the CD1 well row (Colville River Unit) and consequently receives regular surveillance of its surface condition. As stated above, this well is located within the Colville River Unit so renewal stipulation 20 AAc.25.110 (a)(3) does not apply to this well. Kathleen Dodson Digitally signed by Kathleen Dodson Date: 2023.04.18 14:01:31 -08'00' CD1-19A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: TOC 8,306.0 5/8/2013 CD1-19A osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CMT Retainers/CMT IA/Suspend Well, Tag 5/13/2013 CD1-19A osborl Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (lb… 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.8 Set Depth (ftKB) 2,825.9 Set Depth (TVD) … 2,393.5 Wt/Len (lb… 36.00 Grade J-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.9 Set Depth (ftKB) 11,947.2 Set Depth (TVD) … 9,586.2 Wt/Len (lb… 26.00 Grade L-80 Top Connection BTCM Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 3 1/2 ID (in) 2.99 Top (ftKB) 32.9 Set Depth (ft… 10,791.6 Set Depth (TVD… 8,468.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 32.9 32.9 0.00 HANGER 4.500 10.800 1,794.6 1,701.6 39.04 NIPPLE 2.813 4.520 8,670.7 6,633.5 42.81 PACKER 3.875 5.875 10,715.9 8,395.8 16.78 PACKER 3.875 5.875 10,778.4 8,455.6 16.44 NIPPLE 2.750 4.260 10,789.9 8,466.7 16.38 WLEG 3.125 4.520 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,610.0 6,589.0 42.84 TBG PUNCHES 5' OF TUBING PUNCHES, 4spf, 0 DEGREE PHASE 4/20/2013 2.992 10,112. 0 7,824.6 20.49 CMT Retainer WEATHERFORD CEMENT RETAINER 5/1/2013 10,689. 0 8,370.0 17.00 CMT Retainer WEATHERFORD CEMENT RETAINER 4/28/2013 10,737. 0 8,416.0 16.64 FISH SLICKLINE TOOL STRING, PLUG & GAUGES (OAL=31'2") 5/24/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,750.0 8,760.0 6,691.7 6,699.0 K-1 Marker, CD1-19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5, CD1- 19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, CD1- 19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, CD1- 19A 1/5/2003 12.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,720.0 11,740.0 9,365.6 9,385.0 IVISHAK, CD1- 19A 1/5/2003 6.0 APERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, CD1- 19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, CD1- 19A 6/3/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, CD1- 19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, CD1- 19A 6/2/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, CD1- 19A 2/27/2003 6.0 IPERF 2.5" HSD HJ 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, CD1- 19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, CD1- 19A 2/27/2003 12.0 RPERF 2.5" HSD HJ Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,420.0 10,689.0 8,114.4 8,370.0 CMT PLUG 8,306.0 10,420.0 6,365.4 8,114.4 CMT PLUG 5/1/2013 7,776.0 8,610.0 5,978.5 6,589.0 CMT PLUG INNER ANNULUS 5/4/2013 8,306.0 8,610.0 6,365.4 6,589.0 CMT PLUG 5/5/2013 Notes: General & Safety End Date Annotation 5/5/2013 NOTE: WELL SUSPENDED, TUBING/CASING/IA CEMENTED; TBG TOC @ 8306'; IA TOC 7776' 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 CD1-19A, 5/20/2022 1:47:24 PM Vertical schematic (actual) PRODUCTION; 34.9-11,947.2 RPERF; 11,803.0-11,813.0 IPERF; 11,800.0-11,803.0 IPERF; 11,793.0-11,794.0 RPERF; 11,780.0-11,793.0 IPERF; 11,768.0-11,776.0 RPERF; 11,750.0-11,763.0 RPERF; 11,749.0-11,750.0 APERF; 11,720.0-11,740.0 RPERF; 11,504.0-11,520.0 RPERF; 11,463.0-11,483.0 FISH; 10,737.0 PACKER; 10,715.9 CMT Retainer; 10,689.0 CMT PLUG; 10,420.0 ftKB CMT Retainer; 10,112.0 IPERF; 8,990.0-9,000.0 IPERF; 8,750.0-8,760.0 PACKER; 8,670.7 TBG PUNCHES; 8,610.0 CMT PLUG; 8,306.0 ftKB CMT PLUG; 8,306.0 ftKB CMT PLUG; 7,776.0 ftKB SURFACE; 36.8-2,825.9 NIPPLE; 1,794.6 CONDUCTOR; 38.0-114.0 WNS DISP KB-Grd (ft) 44.16 RR Date 4/21/1999 Other Elev… CD1-19A ... TD Act Btm (ftKB) 11,956.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032029401 Wellbore Status DISP Max Angle & MD Incl (°) 54.05 MD (ftKB) 2,710.56 WELLNAME WELLBORECD1-19A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 InspectNo:susGDC230404193632 Well Pressures (psi): Date Inspected:4/5/2023 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:5/8/2013 #312-423 Tubing:0 IA:850 OA:340 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Bruce Richwine Date AOGCC Notified:3/31/2023 Type of Inspection:Subsequent Well Name:COLVILLE RIV UNIT CD1-19A Permit Number:2000400 Wellhead Condition Good condition with old signs of hydrocarbons and some rust. No signs of any active leaks or other issues. The well is protected by a wellhouse. Surrounding Surface Condition Ground covered in snow and ice. No signs of hydrocarbons. Area should be reinspected after the snow and ice have melted away. Condition of Cellar The cellar was full of clean dry gravel. Comments Location of the well was verified by a well pad map. Supervisor Comments Photos (6) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, May 19, 2023 2023-0405_Suspend_CRU_CD1-19A_photos Page 1 of 3 Suspended Well Inspection – CRU CD1-19A AOGCC Inspect # susGDC230404193632 PTD 2000400 Photo by AOGCC Inspector G. Cook 2023-0405_Suspend_CRU_CD1-19A_photos Page 2 of 3 2023-0405_Suspend_CRU_CD1-19A_photos Page 3 of 3 ! "#$ %& ' ('! )* * % + , ) -./, ) * 0 , & 1! '2 3 3 ' '! ! 3 4 $5 2 ! . '(!5 % + , ) -./, ) * 05/ ' ! 2!67 5 /2 " ! !& ) )* * ) ' ('! ) 4 ! ! )8 ! . . ). "' .! 9$) 9 2 3 5 ! ' . ! (" : ' ! '! ! . '(!5 Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-29 14:36:09 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch 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): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 200-040 50-103-20294-01-00 ADL0025559 CD1-19A n/a Colville River Field/Undefined WDSP 11956 9595 cement n/a 0 0 8671 6633 Conductor 76' 16" 114 114 Surface 2789' 9-5/8" 2826 2020 Production 11912' 7" 11947 9562 8750-11813 (sqz'd) 6694-9456 (sqz'd) 3-1/2" L-80 10790' MD 8467' TVD Halliburton THB Packer 8671' MD 6633' TVD n/a n/a n/a n/a n/aStephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 Suspended Well Inspect ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-07-29 14:36:33 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch By Jody Colombie at 7:08 am, Jul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asing Strings Casing Description CONDUCTOR String O... 16 String ID ... 15.062 Top (ftKB) 38.0 Set Depth (f... 114.0 Set Depth (TVD) ... 114.0 String Wt... 62.58 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 9 5/8 String ID ... 8.921 Top (ftKB) 36.8 Set Depth (f... 2,825.9 Set Depth (TVD) ... 2,393.5 String Wt... 36.00 String ... J-55 String Top Thrd BTC Casing Description PRODUCTION String O... 7 String ID ... 6.276 Top (ftKB) 34.9 Set Depth (f... 11,947.2 Set Depth (TVD) ... 9,586.2 String Wt... 26.00 String ... L-80 String Top Thrd BTCM Tubing Strings Tubing Description TUBING String O... 3 1/2 String ID ... 2.992 Top (ftKB) 32.9 Set Depth (f... 10,791.6 Set Depth (TVD) ... 8,468.3 String Wt... 9.30 String ... L-80 String Top Thrd EUE 8RD Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 32.9 32.9 -0.38 HANGER FMC TUBING HANGER 4.500 1,794.6 1,701.6 39.62 NIPPLE HES X NIPPLE 2.813 8,670.7 6,633.5 42.81 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 10,715.9 8,395.8 16.78 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 10,778.4 8,455.6 16.40 NIPPLE HES XN NIPPLE w/ NO GO PROFILE 2.750 10,789.9 8,466.7 16.35 WLEG WIRELINE RE-ENTRY GUIDE 3.125 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Description Comment Run Date ID (in) 8,610.0 6,589.0 42.84 TBG PUNCHES 5' OF TUBING PUNCHES, 4spf, 0 DEGREE PHASE 4/20/2013 2.992 10,112.0 7,824.7 20.49 CMT Retainer WEATHERFORD CEMENT RETAINER 5/1/2013 10,689.0 8,370.0 17.00 CMT Retainer WEATHERFORD CEMENT RETAINER 4/28/2013 10,737.0 8,416.0 16.56 FISH SLICKLINE TOOL STRING, PLUG & GAUGES (OAL=31'2") 5/24/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 8,750.0 8,760.0 6,693.9 6,701.0 K-1 Marker, CD1-19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5, CD1-19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, CD1-19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, CD1-19A 1/5/2003 12.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,720.0 11,740.0 9,365.5 9,385.0 IVISHAK, CD1-19A 1/5/2003 6.0 APERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, CD1-19A 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase w/mag 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, CD1-19A 6/3/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, CD1-19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, CD1-19A 6/2/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, CD1-19A 2/27/2003 6.0 IPERF 2.5" HSD HJ 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, CD1-19A 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, CD1-19A 2/27/2003 12.0 RPERF 2.5" HSD HJ Notes: General & Safety End Date Annotation 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 5/5/2013 NOTE: WELL SUSPENDED, TUBING/CASING/IA CEMENTED; TBG TOC @ 8306'; IA TOC 7776' Comment SSSV: NIPPLEWell Config: - CD1-19A, 5/20/2013 6:38:08 AM Schematic - Actual TD (CD1-19A), 11,956 PRODUCTION, 35-11,947 TBG HOLE, 10,348 RPERF, 11,803-11,813 IPERF, 11,800-11,803 IPERF, 11,793-11,794 RPERF, 11,780-11,793 IPERF, 11,768-11,776 RPERF, 11,750-11,763 RPERF, 11,749-11,750 APERF, 11,720-11,740 RPERF, 11,504-11,520 RPERF, 11,463-11,483 WLEG, 10,790 NIPPLE, 10,778 FISH, 10,737 PACKER, 10,716 CMT Retainer, 10,689 CMT PLUG, 10,420 CMT PLUG, 8,306 TBG HOLE, 10,416 TBG HOLE, 10,316 CMT Retainer, 10,112 IPERF, 8,990-9,000 IPERF, 8,750-8,760 PACKER, 8,671 TBG PUNCHES, 8,610 CMT PLUG, 8,306 CMT PLUG, 7,776 SURFACE, 37-2,826 NIPPLE, 1,795 CONDUCTOR, 38-114 HANGER, 33 Annotation Last Tag: TOC Depth (ftKB) 8,306.0 End Date 5/8/2013 Annotation Rev Reason: CMT Retainers/CMT IA/Suspend Well, Tag Last Mod ... osborl End Date 5/13/2013 WNS KB-Grd (ft) 44.16 Rig Release Date 4/21/1999 Annotation Last WO: End Date CD1-19A H2S (ppm) Date... TD Act Btm (ftKB) 11,956.0 Well Attributes Wellbore API/UWI 501032029401 Field Name ALPINE Well Status DISP Max Angle & MD Incl (°) 54.05 MD (ftKB) 2,710.56 CD1-19A ConocoPhillips April 1, 2019 Alaska Oil and Gas Conservation Commission 333 West 71^ Avenue, Suite 100 Anchorage, AK 99501 Attention: Commissioner Dan Seamount RE: 2018 Annual Disposal Well Performance Report WD -02, CD1-19A and CD1-01A Undefined Disposal Pool, Colville River Unit Dear Commissioner Seamount, rjTD 2oa-mc Sam Johnstone Supervisor, WNS Production Engineering ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Telephone: 907-263-4617 RECEIVED APR 01 2019 A®GCC ConocoPhillips Alaska Inc., as operator and sole working interest owner of the Colville River Unit, submits the 2018 Disposal Well Performance Reports for the Undefined Disposal Pool in the Colville River Unit. These reports are submitted in accordance with Area Injection Order No. 18D and the requirements of 20 AAC 25.432. Inquiries regarding this report may be directed to Mr. Stefan Weingarth (670-4934) at this office. Sincerely, Sam Johnstone Supervisor, WNS Production Engineering North Slope Operations and Development ConocoPhillips 2018 Annual Disposal Well Performance Report WD -02 API 50-103-20285-00-00 Undefined Disposal Pool Colville River Unit April 1, 2019 INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18D, dated June 20, 2017, which requires the submission of an annual performance report for slurry injection wells, and the requirements of 20 AAC 25.432 (Report of Underground Injection). Well WD -02, which was drilled and completed in the Ivishak Formation (undefined disposal pool) as a Class I well in April 1999, continued to serve as the primary source of disposal for camp fluids in 2018. CLASS I DISPOSAL WELL WD -02 Infection Volumes Fluid injection volumes for the 12 -month period of January 2018 through December 2018 totaled 377,272 bbls. This represents a monthly average of 31,439 bbls. Cumulative injection into the Sadlerochit Group since the start of the project is 6,477,368 bbls. Injection volumes for WD -02 are summarized in both table and plot form as Attachments 1 and 2. Infection Rates The injection pumps operate on level controls located on upstream holding tanks. Alpine base camp effluent water was the primary fluid injected down WD -02 in 2018, hence injection volumes varied in response to field manpower and staffing. The injection pumps are operated at 15 - 20 gpm each, up to the 3,200 psi allowable injection pressure. The maximum allowable wellhead injection pressure was increased to 3,500 psi with the re -issuance of the EPA permit in March 2019. Iniection Pressures Injection pressures are monitored and recorded continuously (Attachment 2). Normal wellhead pressure when the pump is offline ranges from 1,200 - 1,500 psi. With the pumps running at 20 - 60 gpm, injection pressure typically ranges from 1,200 - 1,700 psi. Annulus Pressures Annulus pressures are monitored and recorded continuously (Attachment 2). When produced formation fluids are disposed of into WD -02, the hot fluids expand and elongate the tubing 2018 CRU Disposal Well Performance Report WD -02 1 string, which impacts the annulus volume, increasing the annulus pressure. Plant operators bleed off fluid from the annulus as a precaution to avoid annulus pressures reaching the 1,500 psi operating limit. The annulus pressure averaged 928 psi during 2018. On March 3, 2018, the annual EPA MITIA was performed. The results are as follows: EPA witnessed by Jason Selitsch and Ryan Gross; MITIA passed at 3,510 psi Depth Tans Mechanical integrity work was aligned with the EPA integrity testing on CD1-01A. Fill was tagged on March 4, 2018 at 9,871' RKB. Fracture Growth The surface fracture pressure of the Ivishak Formation, as measured during the step rate test conducted April 11, 1999, was 1,984 psi. This pressure coincides with an injection rate of 1.38 bpm, or 1,987 bpd. The associated bottomhole fracture pressure extrapolated from the step test data is 6,259 psi. This equates to a gradient of 0.66 psi/ft, or fluid equivalent of 12.7 ppg. With the exception of short-term injection periods, tubing tests, and miscellaneous data spikes, the injection pressures have not exceeded the surface fracture pressure for any extended period of time during 2018. Wellwork Event Summary WD -02 Date Event 03/05/2018 PERFORM CALIPER FROM TD TO SURFACE. 03/04/2018 PERFORM WLF STATIONS AND IPROF TO SATISFY EPA REGULATORY MONITORING AND ALSO TO DETERMINE INJECTION CONTRIBUTIONS TO PERFS. 03/04/2018 TAGGED FILL c@ 9871' RKB w/ 2.69" G -RING. READY FOR E -LINE. IN PROGRESS 03/03/2018 EPA WITNESSED (JASON SELITSCH/RYAN GROSS) MIT -IA PASSED TO 3510 PSI. 03/03/2018 PUMP SEAWATER BLEACH SOLUTION & FREEZE PROTECT, PUMPED 200 BBLS OF SEAWATERIBLEACH SOLUTION DOWN TBG FOLLOWED BY 26 BBLS DIESEL FOR FREEZE PROTECT. JOB COMPLETE 2018 CRU Disposal Well Performance Report WD -02 2 ATTACHMENT 1: WD -02 2018 INJECTION SUMMARY TABLE January through December 2018 Injection Summary Well: WD -02 Disposal Order: 18 Field: Colville River Unit API: 50103202850000 Pool: Undefined Disposal Pool Permit to Drill: 198-258 Pool Code: 120036 Month Days In Tubing Pressure Operation Max Pressure Tbg Pressure Avg Pressure Casing Pressure Max Pressure Csg Pressure Avg Pressure Daily Average Liquid (bbl) Gas (mcf) Monthly Liquid (bbl) Total Gas (mcf) Cumulative Liquid (bbl) January 31 1,737 1,493 1,058 892 978 0 30,314 0 30,314 February 28 1,743 1,579 1,024 918 1,185 0 33,188 0 63,502 March 29 2,836 1,472 1,141 828 1,163 0 33,732 0 97,234 April 30 3,876 1,525 2,859 888 1,094 0 32,819 0 130,053 May 31 1,705 1,515 1,075 979 976 0 30,260 0 160,314 June 301 1,729 1,532 1,118 1,0071 976 0 29,273 0 189,586 July 31 1,767 1,606 1,217 1,038 1,248 0 38,682 0 228,268 August 31 1,762 1,563 1,190 908 1,100 01 34,100 0 262,368 September 30 1,734 1,548 1,056 962 982 0 29,459 0 291,828 October 31 1,719 1,509 1,021 899 872 0 27,027 0 318,855 November 30 1,751 1,530 1,024 884 909 0 27,280 0 346,135 December 31 1,758 1,5701 1,101 935 1,004 0 31,138 0 377,272 Monthly Average 2,010 1,5371 1,2401 9281 1,041 0 31,439 0 2018 CRU Disposal Well Performance Report WD -02 ATTACHMENT 2: WD -02 2018 INJECTION SUMMARY PLOT 2018 CRU Disposal Well Performance Report WD -02 —�— WD -02 Daily Injection Total (BBLS) ■ WD -02 Tubing Pressure (PSIG) 3000 •WD -02 Inner Annulus Pressure (PSIG) 1,800 ■■ ■■ ■ • ■ �~ j Ji *■ ohm! r 1,600 2,500 _ _ _ 4,4..,."�r44 1,400 m 2,000 ■ -- --_-- 1,200 m E 7 ■ ♦ � • �I i 1,000 m n 1,500 m • 800 • 4A nAA m 1,000 A AA 600 0 400 soo 200 0 0 Jan -18 Mar -18 May -18 Jul -18 Sep -18 Nov -18 Jan -19 2018 CRU Disposal Well Performance Report WD -02 ConocoPhillips 2018 Annual Disposal Well Performance Report CD1-19A API 50-103-20294-01-00 Undefined Disposal Pool Colville River Unit April 1, 2019 INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18D, dated March 26, 2009, and the requirements of 20 AAC 25.432 (Report of Underground Injection). Disposal well CD1-19A was drilled and completed in May 2000 to provide a disposal source for Class II fluids generated during wellwork and drilling operations. It was converted to a Class I well in April 2008 and continued to serve as a disposal well for fluids generated during wellwork and drilling operations through May 12, 2012. The CD1-19A well was partially abandoned in May 2013 by placement of cement across the injection zone (Ivishak Formation). CD1-01A was drilled, completed, and placed in service in November 2012. CLASS I DISPOSAL WELL CD1-19A Injection Volumes No fluids were injected into CD1-19A in 2018. Wellwork Event Summary No wellwork. CD1-19A Date Event No wellwork events in 2018 2018 CRU Disposal Well Performance Report CD1-19A 1 ConocoPhillips 2018 Annual Disposal Well Performance Report C131 -01A API 50-103-20299-01-00 Undefined Disposal Pool Colville River Unit April 1, 2019 INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18D, dated June 20, 2017, and the requirements of 20 AAC 25.432 (Report of Underground Injection). CD1-01A was drilled and completed in September/October of 2012 as a replacement for CD1-19A. CD1- 01A was placed in service in November 2012. CLASS I DISPOSAL WELL CD1-01A Infection Volumes Fluid injection volumes for the 12 -month period of January 2018 through December 2018 totaled 412,950 bbls. This represents a monthly average of 34,413 bbls. Cumulative injection into the Ivishak Formation since the start of the project is 1,896,412 bbls. Injection volumes for CD1-01A are summarized in both table and plot form as Attachments 1 and 2. Iniection Rates Disposal operations for CD1-01A are recorded via a Micromotion flow rate meter. Various trucks and rig units are utilized to transport and dispose of fluids into this well. Injection rates vary from 0.5 - 4 bpm. Disposed fluids primarily include drilling mud and cuttings, and wellwork fluids. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically in Attachment 2. Injection Pressures Injection pressures are monitored and recorded via MadgeTech pressure gauge transmitters. These reports are summarized in the data plot (Attachment 2). Normal wellhead pressures during disposal operations vary from 2,100 - 3,900 psi. Annulus Pressures Annulus pressures are monitored and recorded, and displayed in graphical form on the well performance plot (Attachment 2). Inner annulus pressure averaged 598 psi during 2018 and remained stable during injection periods. 2018 CRU Disposal Well Performance Report CD1-01A 1 On March 3, 2018, the MITIA for CD1-01A was performed. The results areas follows: • EPA witnessed by Jason Selitsch and Ryan Gross; MITIA passed at 4,200 psi Depth Tags Mechanical integrity work was aligned with the EPA integrity testing after CD1-01A was commissioned in November 2012. Fill was tagged on March 4, 2018 at 9,692' RKB. On August 23, 2018, fill was tagged at 9,678' RKB and again on December 22, 2018, at 9,504' RKB. Fracture Growth During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. A pressure fall-off (PFO) test was performed on Alpine's Class II Disposal Well, CD1-19A, on June 19, 2004, after injecting 227,000 bbls of approved fluids for the purpose of estimating fracture growth. The complete test report was submitted on July 26, 2004. Referring to the square root of time plot from the June 2004 PFO, a fracture was observed to close at dt = 7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early -time analysis. A regression fit to the early -time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1 percent. A Nolte -Smith plot from the injection data yielded a quarter slope, indicating a Perkins and Kern system, i.e. a wedge-shaped vertically contained fracture, which is growing in length. CD1-01A is of like reservoir quality and is expected to have similar fracture properties as demonstrated by CD1-19A above. 2018 CRU Disposal Well Performance Report CD1-01A Well Work Summary CD1-01A Date Event 12/22/2018 TAG FILL @ 9504' RKB WITH 1.75" S.BAILER & 2.43" CENT. "RECOVERED SAMPLE OF MUD-'. COMPLETE. 08/23/2018 DRIFT & TAG FILL @ 9678'RKB w/ 1.75" S.BLR. EST. 358' OF OPEN PERFS. JOB COMPLETE. 07/17/2018 TBG DISPLACEMENT/FREEZE PROTECT—PUMPED 5 BBLS CRUDE FOLLOWED BY150 BELS FRESH WATER OWN TBG, WELL HANDED OVER TO WIF BEFORE JOB WAS COMPLETED (JOB COMPLETE) 03/07/2018 PERFORM ELINE WATERFLOW LOG + INJECTION PROFILE TO SATISFY EPA REQUIREMENTS. LOGS WITNESSED BY EPA REPRESENTATIVES. 03/06/2018 E -LINE CALIPER LOG PERFORMED FROM 9690' TO SURFACE 03/04/2018 TAGGED FILL @ 969Z RKB w/ 2.69" G -RING. READY FOR E -LINE. IN PROGRESS 03/03/2018 EPA WITNESSED (JASON SELITSCH/RYAN GROSS) MIT -IA PASSED TO 4200 PSI. Micromotion flow rate and MadgeTech pressure gauge transmitters are installed with an alarm system to detect excess injection pressures and rates. The well is monitored 24 hours a day during injection. The well operates at a maximum 4,200 psig wellhead pressure and an annulus pressure up to 2,000 psig. Continuous, recorded monitoring of volumes of hard piped waste streams are captured through the Alpine automation system. 2018 CRU Disposal Well Performance Report CD1-01A 3 ATTACHMENT 1: CD1-01A 2018 INJECTION SUMMARY TABLE January through December 2018 Injection Summary Well: CD1-01A Disposal Order: 18 Field: Colville River Unit API: 50103202990100 Pool: Undefined Disposal Pool Permit to Drill: 212-099 Pool Code: 120036 Month Days In Operation Tubing Pressure Max Pressure Tbg Pressure Avg Pressure Casing Pressure Csg Pressure Max Pressure Avg Pressure Daily Average Liquid (bbl) Gas (mcf) Monthly Total Liquid (bbl) Gas (mct) Cumulative Liquid (bbl) January 22 3,659 2,337 1,151 581 1,861 0 40,9501 0 40,950 February 18 3,528 1,825 1,202 690 1,683 0 30,299 0 71,249 March 22 3,570 2,080 1,276 705 1,695 0 37,296 0 108,545 April 20 3,321 2,363 1,068 731 1,479 0 29,5851 0 138,129 May 18 3,992 2,798 1,447 782 2,136 0 38,452 0 176,581 June 14 3,943 2,347 1,052 676 2,024 0 28,342 0 204,924 July 21 3,957 2,474 1,837 884 1,988 0 41,749 0 246,673 August 22 3,942 2,284 1,022 647 1,749 0 38,485 0 285,158 September 19 3,904 2,322 1,149 465 1,831 0 34,7831 0 319,941 October 16 3,928 2,376 794 425 1,881 0 30,0881 0 350,029 November 214,042 2,770 554 355 1,558 0 32,722 0 382,751 December 17 3,587 2,650 484 2401 1,776 0 30,199 L 0 412,950 Monthly Average 3,781 1 2,3851 1,086 598 1 1,805 0 34,413 T 0 2018 CRU Disposal Well Performance Report CD1-01A ATTACHMENT 2: CD1-01A 2018 INJECTION SUMMARY PLOT Daily Injection Total CDI-01A Tubing Pressure (PSIG) off CD1-01A Inner Annulus Pressure fill,I, illl III ��! � �1 i �li I .li.I'�,Il�,lil�l 111111���E�lii� II II I il�" i li I I� II!6��►�►�I�111��1"�i!!i�N,�,! il. !, Il�lih; !!. I'�!�iiiIl�IIfIIII,�i� IIIIIiI��l;16►I i grid",� Ali ��� , „ ,,,�I �,,I �,��,;��„�;,,;i��i; � ���, � �•� �I�III111 Ih II I I iq � " " � I��I�, �,Il�i�i�,�l�����1���,�l�r� ;;���, �I,,��i;��:���11 � ����, ; ►� � ���I� ii�i�ii� ��,i��� ��.li, ���•.,E� ,. .. � =��Il,,�liilll, 2018 CRU Disposal Well Performance Report CD1-01A 2.6o 0 440 Sam Johnstone COnOCOPI1i I I i ps Supervisor,WNS Production Engineering ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage,AK 99510-0360 Telephone:907-263-4617 MAP 3 12D'7 GO March 31, 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 APP 1 d�01( Anchorage, AK 99501 ���� " Attention: Commissioner Dan Seamount RE: 2016 Ann_ -I Disposal Well Performance Report WD-02 CD1-19 .nd CD1-01A Undefine• Disposal Pool, Colville River Unit Dear Commissioner Seamount, ConocoPhillips Alaska Inc., as operator and on behalf of the working interest owners of the Colville River Unit, submits the 2016 Disposal Well Performance Reports for the Undefined Disposal Pool in the Colville River Unit. These reports are submitted in accordance with Area Injection Order No. 18C and the requirements of 20 AAC 25.432. Inquiries regarding this report may be directed to Mr. Stefan Weingarth (670-4934) at this office. Sincerely, Sam Johnstone Supervisor, WNS Production Engineering North Slope Operations and Development • i ConochiIIips 2016 Annual Disposal Well Performance Report WD-02 API 50-103-20285-00-00 Undefined Disposal Pool Colville River Unit March 31, 2017 2016 CRU Disposal Well Performance Report WD-02 1 • • INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, which requires the submission of an annual performance report for slurry injection wells, and the requirements of 20 AAC 25.432 (Report of Underground Injection). Well WD-02, which was drilled and completed in the Ivishak Formation (undefined disposal pool) as a Class I well in April 1999, continued to serve as the primary source of disposal for camp fluids in 2016. CLASS I DISPOSAL WELL WD-02 Injection Volumes Fluid injection volumes for the 12-month period of January 2016 through December 2016 totaled 326,323 bbls. This represents a monthly average of 27,194 bbls. Cumulative injection into the Sadlerochit Group since the start of the project is 5,767,875 bbls. Injection volumes for WD-02 are summarized in both table and plot form as Attachments 1 and 2. Infection Rates The injection pumps operate on level controls located on upstream holding tanks. Alpine base camp effluent water was the primary fluid injected down WD-02 in 2016, hence injection volumes varied in response to field manpower and staffing. The twin injection pumps are operated at 15 - 20 gpm each, up to the 3,200 psi allowable injection pressure. Injection Pressures Injection pressures are monitored and recorded continuously (Attachment 2). Normal wellhead pressure when the pump is offline ranges from 1,100 - 1,400 psi. With the pumps running at 20 - 60 gpm, injection pressure typically ranges from 1,100 - 1,700 psi. Annulus Pressures Annulus pressures are monitored and recorded continuously (Attachment 2). When produced formation fluids are disposed of into WD-02, the hot fluids expand and elongate the tubing string, which impacts the annulus volume, increasing the annulus pressure. Plant operators 2016 CRU Disposal Well Performance Report WD-02 2 • bleed off fluid from the annulus as a precaution to avoid annulus pressures reaching the 1,500 psi operating limit. The annulus pressure averaged 899 psi during 2016. On March 3, 2016, the annual EPA MITIA was performed. The results are as follows: • EPA witnessed by Jason Selitsch, Thor Cutler and Evan Osborne; MITIA passed at 3,540 psi Depth Tags Mechanical integrity work was aligned with the EPA integrity testing on CD1-01A. Fill was tagged on March 6, 2016 at 9,844' SLM. Fracture Growth The surface fracture pressure of the Ivishak Formation, as measured during the step rate test conducted April 11, 1999, was 1,984 psi. This pressure coincides with an injection rate of 1.38 bpm, or 1,987 bpd. The associated bottomhole fracture pressure extrapolated from the step test data is 6,259 psi. This equates to a gradient of 0.66 psi/ft, or fluid equivalent of 12.7 ppg. With the exception of short-term injection periods, tubing tests, and miscellaneous data spikes, the injection pressures have not exceeded the surface fracture pressure for any extended period of time during 2016. Wel!work Event Summary WD-02 Date Event 03/11/2016 ASSIST E-LINE WITH OXYGEN ACTIVATION LOG,PUMPED 350 BBLS OF SEAWATER DOWN TBG WHILE E-LINE LOGS TBG, PUMPED 30 BBLS DIESEL FOR FREEZE PROTECT.JOB COMPLETE 03/11/2016 LOG 24 ARM CALIPER FROM TAG FO 9862' TO SURFACE. ON INJECTION PROFILE PUMPING 1.0 BPM OBSERVED 30%INFO PERFS AT 9459',22%FROM PERFS AT 9514'AND 47%FROM PERFS AT 9803 OR BELOW. NO UPFLOW OBSERVED AT 9449', 9424'OF 9399'AT 1.0 BPM OR 1.5 BPM.JOB COMPLETE 03/06/2016 DRIFT FOR E-LINE w/2.25"SWEDGE.TAG FILL @ 9844'SLM.APPROX 175'FILL.JOB COMPLETE. 03/03/2016 PUMPED 200 BBLS WATER/BLEACH SOLUTION FOLLOWED BY 30 BBLS DSL FOR FREEZE PROTECT. JOB COMPLETE. 03/03/2016 (EPA WITNESSED THOR CUTLER, JASON SELITSCH, EVAN OSBORNE)MITIA PASSED TO 3540 PSI. 2016 CRU Disposal Well Performance Report WD-02 3 • • d = N- co co I. O CO O O co Co Co co > .Q Cfl co N 0 6) N CO CIO I� N 'E; . N- N 0) Nar N N N. N- r r CO CO CO O 6 6 O LC) co- I- N r (6 'd N CO CO co co N N- 0) N N N N N CO M IS 0—i In O O O O O co co O O O C O O d- co0 I_. — I- 0) CO 0) N N. co O CO 6) O N O --0 N N. N ti CO CM 0)) O CO rt r c r I- OIn 6) tt CO W h LP) U) LCA 00 r T .O N C`O NNNNNNNNNNN r 5 C' a. 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N 0 O. ; > o a; r o a 4' °' 'I'LL °o a m m 2 sz m S = = m m m m r �ia - c c ca _' -) Q coo E aEas i o m 75 ° m sz U o a) ea 2 m a in z o • 0 pisd)aJnssaJd 0 0 0 00 8 8 0 8 8 8 8 8 <4r-i .-i .-i co N O I LU gS 40. • ■ 1— iii � ® > J 0 Pt ♦ O Z r C m 0 L Q to E o v w a c Lo o N r-+ Cl) 6 v c t ami a' a c - v) O T C i U _ er ., W o 0 0 0 0 0 *Olt +' _' O el eu Q N N Q) _ 0 N c Z ■ = ♦ E W ■ o ■ ■ -_ 1 a) 2 ■ Q •, a) in■ .i t 4. u),_o litij♦eCC co • i1 to 0 .. • + . '1 N ru0 0 0 00 0 O 8 8 0 8 OV1 M N N , e-1 (s1g8)awnpn uoipaful Am • • ConocoPhilli ps 2016 Annual Disposal Well Performance Report CD1 -19A API# 50-103-20294-01-00 Undefined Disposal Pool Colville River Unit March 31, 2017 2016 CRU Disposal Well Performance Report CD1-19A 6 • INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, and the requirements of 20 AAC 25.432 (Report of Underground Injection). Disposal well CD1-19A was drilled and completed in May 2000 to provide a disposal source for Class II fluids generated during wellwork and drilling operations. It was converted to a Class I well in April 2008 and continued to serve as a disposal well for fluids generated during wellwork and drilling operations through May 12, 2012. The CD1-19A well was partially abandoned in May 2013 by placement of cement across the injection zone (Ivishak Formation). CD1-01A was drilled, completed, and placed in service in November 2012. CLASS I DISPOSAL WELL CD1-19A Injection Volumes No fluids were injected into CD1-19A in 2016. Wellwork Event Summary No wellwork. CD1-19A Date Event No wellwork events in 2016 2016 CRU Disposal Well Performance Report CD1-19A 7 • • NiPPv ConocoPhillups 2016 Annual Disposal Well Performance Report CD1 -01A API# 50-103-20299-01-00 Undefined Disposal Pool Colville River Unit March 31, 2017 2016 CRU Disposal Well Performance Report CD1-01A 8 . • • INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, and the requirements of 20 AAC 25.432 (Report of Underground Injection). CD1-01A was drilled and completed in September/October of 2012 as a replacement for CD1-19A. CD1- 01A was placed in service in November 2012. CLASS I DISPOSAL WELL CD1-01A Injection Volumes Fluid injection volumes for the 12-month period of January 2016 through December 2016 totaled 351,257 bbls. This represents a monthly average of 29,271 bbls. Cumulative injection into the Ivishak Formation since the start of the project is 1,154,894 bbls. Injection volumes for CD1-01A are summarized in both table and plot form as Attachments 1 and 2. Injection Rates Disposal operations for CD1-01A are recorded via a Micromotion flow rate meter. Various trucks and rig units are utilized to transport and dispose of fluids into this well. Injection rates vary from 0.5 -4 bpm. Disposed fluids primarily include drilling mud and cuttings, and wellwork fluids. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically in Attachment 2. Injection Pressures Injection pressures are monitored and recorded via MadgeTech pressure gauge transmitters. These reports are summarized in the data plot (Attachment 2). Normal wellhead pressures during disposal operations vary from 1,800 - 3,600 psi. Annulus Pressures Annulus pressures are manually recorded and reported, and displayed in graphical form on the well performance plot (Attachment 2). Inner annulus pressure averaged 759 psi during 2016 and remained stable during injection periods. 2016 CRU Disposal Well Performance Report CD1-01A 9 • • On March 3, 2016, the MITIA for CD1-01A was performed. The results are as follows: • EPA witnessed by Jason Selitsch, Thor Cutler and Evan Osborne; MITIA passed at 2,800 psi Depth Tags Mechanical integrity work was aligned with the EPA integrity testing after CD1-01A was commissioned in November 2012. Fill was tagged on March 2, 2016 at 9,658' SLM. Fracture Growth During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. A pressure fall-off(PFO) test was performed on Alpine's Class II Disposal Well, CD1-19A, on June 19, 2004, after injecting 227,000 bbls of approved fluids for the purpose of estimating fracture growth. The complete test report was submitted on July 26, 2004. Referring to the square root of time plot from the June 2004 PFO, a fracture was observed to close at dt = 7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early-time analysis. A regression fit to the early-time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1 percent. A Nolte-Smith plot from the injection data yielded a quarter slope, indicating a Perkins and Kern system, i.e. a wedge-shaped vertically contained fracture, which is growing in length. CD1-01A is of like reservoir quality and is expected to have similar fracture properties as demonstrated by CD1-19A above. 2016 CRU Disposal Well Performance Report CD1-01A 10 • • Well Work Summary CD1-01A Date Event 09/16/2016 MEASURED BTM HOLE PRESSURE @ 9706'RKB w/2.2"CENT, DUAL SPARTEK GAUGES(5344 PSI @ 177* F)LIGHT TAG ON FILL @ 9711'RKB w/SAME.COMPLETE 06/28/2016 TAGGED FILL @ 9769'RKB w/2"CENT,SAMPLE BAILER. RECOVERED MUD IN BAILER.COMPLETE 06/16/2016 PERFORMED FILL CLEANOUT FROM 9523' CTMD TO HARD TAG AT 9788' CTMD PUMPING SLICK SEAWATER WITH DUO-VIS SWEEPS AT 1.5 BPM (EST. 20' OF RATHOLE) MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, MODERATE SAND CONCENTRATIONS OBSERVED. EST TOTAL SOLIDS VOLUME AT 6 BBLS,TURN WELL OVER TO DSO TO PUT ON INJECTION,JOB COMPLETE. 03/04/2016 PERFORM INJECTION PROFILE W/ TMD3D IN OXYGEN ACTIVATION MODE ALONG W/ STANDARD PL TOOLS. IMPULSE TESTING AT 9310, 9295,AND 9270'SHOW NO UPFLOW BEHIND PIPE AT 2 AND 2.5 BPM INJECTION. INJECTION PROFILE AT 2 BPM SHOWS INJECTION AT UPPER ZONE 1=16%, ZONE 2=10%, ZONE 3=24%, ZONE 4=50% AND LOWER ZONE 5=0%. LOG CORRELATED TO TUBING DETAIL RECORD DATED 29 OCT 2012. MISWACO TO PUMP FRZ PROTECT,READY FOR SLICKLINE. 03/03/2016 (EPA WINTNESSED THOR CUTLER,JASON SELITSCH, EVAN OSBORNE)MITIA PASSED TO 2800 PSI. 03/03/2016 LOG 24 ARM CALIPER SURVEY FROM TAG AT 9678'TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 29 OCT 2012. DATA SENT TO ANCHORAGE FOR FINAL PROCESSING. READY FOR WATERFLOW/INJ PROFILE. 03/02/2016 DRIFT TBG w/ 10'X 2" DD BAILER(MS-BALL). TAG FILL @ 9658'SLM (-31' HIGHER THAN PREVIOUS TAG ON 7-4-2015). **RECOVERED SAMPLE**. GAUGE TBG TO 2.79"TO XN-NIP @ 8799' RKB. **READY FOR E- LINE**. Micromotion flow rate and MadgeTech pressure gauge transmitters are installed with an alarm system to detect excess injection pressures and rates. The well is monitored 24 hours a day during injection. The well operates at a maximum 4,200 psig wellhead pressure and an annulus pressure up to 2,000 psig. Continuous, recorded monitoring of volumes of hard piped waste streams are captured through the Alpine automation system. 2016 CRU Disposal Well Performance Report CD1-01A 11 • • m > -a Co Nr N CO N CCO CO N- co M M 10 :an co CO co co co Co co O) N- O CD N :.a N Co CO CO N--LO 7 CO in o) - CO Lo 7 N N N N C'O 00 M 7; a' 0 J W 0000000000000 CO N Ur r To.r.. N- N- CA CO CO N V' CO CA CO O CO o .• co r. N OD CD P'') r Or co N N CCOO N V N- C` O CO O CO CO CO 01 00 N- CA >. .a N CO tt CO LU C) N r CO N N N W C• a• Cl,Q O 0 0 0 0 0 0 0 O 0 0 0 O �-- co 0 ›- a) _ . 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Q. - ._ __ coo 11 ____ _ a) .. . ....=w.i. , _ • • Ear--_ws__. 0 o N O O O O O O O O 0 O 0 --+ 8 8 0 8 0 80 8 In In •:, m m N N a-1 (s1gs)awnlon uoipa(ui Area • • 1_,DOrtoct 0 NOV Jack Walker Supervisor,WNS Production Engineering ConocoPh i I I i ps North Slope Operations&Development ConocoPhillips Alaska,Inc. PO Box 100360 Anchorage,AK 99510-0360 Phone:(907)265-6268 March 30, 2015 t� Alaska Oil and Gas Conservation AF(10. 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 MAR 3 1 ?MS Attention: Commissioner Dan Seamount RE: 2014 Annual Disposal Well Performance Reports WD-02, CD1-19A and CD1-01A Undefined Disposal Pool, Colville River Field Dear Commissioner Seamount, ConocoPhillips Alaska Inc., as operator and on behalf of the working interest owners of the Colville River Unit, submits the 2014 Disposal Well Performance Reports for the Undefined Disposal Pool in the Colville River Field. These reports are submitted in accordance with Area Injection Order No. 18C and the requirements of 20 AAC 25.432. Inquiries regarding these reports may be directed to Mr. Garrett McKee (670-4934) at this office. Sincerely, SCANNED 2, ;1 , Jack Walker Supervisor, WNS Production Engineering North Slope Operations and Development • • ConocoPhilhi ps 2014 Annual Disposal Well Performance Report WD-02 API 50-103-20285-00-00 Undefined Disposal Pool Colville River Field March 30, 2015 2014 CRU Disposal Well Performance Report WD-02 1 • • INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, which requires the submission of an annual performance report for slurry injection wells, and the requirements of 20 AAC 25.432 (Report of Underground Injection). Well WD-02, which was drilled and completed in the Ivishak Formation (undefined disposal pool) as a Class I well in April 1999, continued to serve as the primary source of disposal for camp fluids in 2014. Field produced fluids were also occasionally pumped to WD-02 in 2014. CLASS I DISPOSAL WELL WD-02 Injection Volumes Fluid injection volumes for the 12-month period of January 2014 through December 2014 totaled 373,117 bbls. This represents a monthly average of 31,093 bbls. Cumulative injection into the Sadlerochit Group since the start of the project is 5,068,232 bbls. Injection volumes for WD-02 are summarized in both table and plot form as Attachments 1 and 2. Injection Rates The injection pumps operate on level controls located on upstream holding tanks. Alpine base camp effluent water was the primary fluid injected down WD-02 in 2014, hence injection volumes varied in response to field manpower and staffing. Field produced water was also injected for short durations during the year. The twin injection pumps are operated at 15 - 20 gpm each, up to the 3,200 psi allowable injection pressure. Injection Pressures Injection pressures are monitored and recorded continuously (Attachment 2). Normal wellhead pressure when the pump is offline ranges from 1,000 - 1,300 psi. With the pumps running at 20 - 60 gpm, injection pressure typically ranges from 1,000 - 1,500 psi. Annulus Pressures • Annulus pressures are monitored and recorded continuously (Attachment 2). When produced formation fluids are disposed of into WD-02, the hot fluids expand and elongate the tubing 2014 CRU Disposal Well Performance Report WD-02 2 string, which impacts the annulus volume, increasing the annulus pressure. Plant operators bleed off fluid from the annulus as a precaution to avoid annulus pressures reaching the 1,500 psi operating limit. The annulus pressure averaged 776 psi during 2014. On March 7th, 2014, the annual EPA MIT was performed. Summary results are shown below: • EPA Witnessed (Thor Cutler) MIT-IA (Passed at 3,500 psi) Depth Tags Mechanical integrity work was aligned with the EPA integrity testing on CD1-01 A. Fill was tagged on March 6th, 2014 at 9,866' md. Fracture Growth The surface fracture pressure of the Ivishak Formation, as measured during the step rate test E conducted April 11, 1999, was 1,984 psi. This pressure coincides with an injection rate of 1.38 bpm, or 1,987 bpd. The associated bottomhole fracture pressure extrapolated from the step test data is 6,259 psi. This equates to a gradient of 0.66 psi/ft, or fluid equivalent of 12.7 ppg. With the exception of short-term injection periods, tubing tests, and miscellaneous data spikes, the injection pressures have not exceeded the surface fracture pressure for any extended period of time during 2014. Wellwork Event Summary WD-02 Date Event 3/5/2014 CALIPER LOG FROM 9864'MD TO SURFACE INJECTION PROFILE LOGGED, NO UPFLOW BEHIND PIPE, 80% OF 3/6/2014 INJECTION ENTERING PERFORATION SET FROM 9837'-9867' MD, 20% ENTERING FROM 9803'-9818' MD.TAG AT 9866' MD 3/7/2014 EPA WITNESSED (THOR CUTLER) MIT-IA(PASSED AT 3500 PSI) 2014 CRU Disposal Well Performance Report WD-02 3 0 ! a) 0) N N N- CO LO LO 00 N ' N > 0) N- N O CO CO CO N N N r •a LI) 0) r Is N 0) LI) LO N r OD CO- (D 0) R •a Ln 4 M N 6 M 7 CSE n e CO O 0) CO CO - N N N CO M CO 7 C.) N O O O O O O O O O O O O O CO 00) CO LI) N- LO CO O 0) CO .-•ct ONO 00)) OM) • .a r CO CO T O CO CO CO CO O CO CO O '� N M r M N: R. 0) O ) O` N 0) UO O) C p CSS CO M COCON N M N N N N CO M GI- J 2 a) O O O O O O O O O O O O O W N 0) co N O d' U) co CO CO T CO N- 0) Co 00 OA CO 0) LO II) CO N CO r P. .. O r O r CO 0) 0 0) 0) 0) 0) O O CO H r" 3 X2- CI Q J a O 0) CO I LO CO LO r 0 N- CO 00 O N r 01 O) CO LO 1' CO O UD Is.. 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Tr .._ 0 ■ • sr- 7, 0 in H J a m O co ---, v a 0_ N ' ', r -4E5 v ■ • 2 t- v a 4 Q 0 � . • .-' m 1-1 a y C . Pk- N M to Q Illi C/) >. c Z c t O 0 0 1-- c y 4 _..,.. 0._ O O ' Z ....... _, CNI cTr 0 .) *f O ■ '� ■ •• - 6 N i o • ! • Frik- o csr- CI CD N IIIii- e-Ij c IL 8 2 f Q °' ■ o_ p CCU 'milk o N .lf 0 0 0 0 i - (sq9) 0M awnpn uoi})aful Amies • • ConocoPh�l l i ps 2014 Annual Disposal Well Performance Report CD1-19A API# 50-103-20294-01-00 Undefined Disposal Pool Colville River Field March 30, 2015 2014 CRU Disposal Well Performance Report CD1-19A 6 • INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, and the requirements of 20 MC 25.432 (Report of Underground Injection). Disposal well CD1-19A was drilled and completed in May 2000 to provide a disposal source for Class II fluids generated during wellwork and drilling operations. It was converted to a Class I well in April 2008 and continued to serve as a disposal well for fluids generated during wellwork and drilling operations through May 12, 2012. The CD1-19A well was partially abandoned in May 2013 by placement of cement across the injection zone (Ivishak Formation). CD1-01 A was drilled, completed, and placed in service in November 2012. CLASS I DISPOSAL WELL CD1-19A Injection Volumes No fluids were injected into CD1-19A in 2014. Wel!work Event Summary No wellwork. CD1-19A Date Event No wellwork events in 2014 2014 CRU Disposal Well Performance Report CD1-19A 7 • • ConocoPhillips 2014 Annual Disposal Well Performance Report CD1-01 A API# 50-103-20299-01-00 Undefined Disposal Pool Colville River Field March 30, 2015 2014 CRU Disposal Well Performance Report CD1-01A 8 INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, and the requirements of 20 AAC 25.432 (Report of Underground Injection). CD1-01A was drilled and completed in September/October of 2012 as a replacement for CD1-19A. CD1- 01 A was placed in service in November 2012. CLASS I DISPOSAL WELL CD-01A Injection Volumes Fluid injection volumes for the 12-month period of January 2014 through December 2014 totaled 221,002 bbls. This represents a monthly average of 18,417 bbls. Cumulative injection into the Ivishak Formation since the start of the project is 486,921 bbls. Injection volumes for CD1-01 A are summarized in both table and plot form as Attachments 1 and 2. Injection Rates Disposal operations for CD1-01 A are recorded via Micromotion flow rate meter. Various trucks and rig units are utilized to transport and dispose of fluids into this well. Injection rates vary from 0.5 - 4 bpm. There is no permanent disposal pump or piping installed at this time. Disposed fluids primarily include spent wellwork and flowback fluids; additional disposal included drilling mud and cuttings. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically in Attachment 2. Injection Pressures Injection pressures are monitored and recorded via MadgeTech pressure gauge transmitters. These reports are summarized in the data plot (Attachment 2). Normal wellhead pressures during disposal operations vary from 2,000 - 3,300 psi. Annulus Pressures Annulus pressures are manually recorded and reported, and displayed in graphical form on the well performance plot (Attachment 2). Inner annulus pressure averaged 768 psi during 2014 and remained stable during injection periods. 2014 CRU Disposal Well Performance Report CD1-01A 9 • • f✓ On March 8, 2014, the MITIA for CD1-01A was performed. Summary results from the Well Service Report are shown below: • EPA Witnessed (Thor Cutler) MIT-IA Passed @ 2,340 psi Depth Tags Mechanical integrity work was aligned with the EPA integrity testing after CD1-01A was commissioned in November 2012. Fill was tagged on March 2nd, 2014 at 9432' md. Fracture Growth During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. A pressure fall-off (PFO) test was performed on Alpine's Class II Disposal Well, CD1-19A, on June 19, 2004, after injecting 227,000 bbls of approved fluids for the purpose of estimating fracture growth. The complete test report was submitted on July 26, 2004. Referring to the square root of time plot from the June 2004 PFO, a fracture was observed to close at dt= 7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early-time analysis. A regression fit to the early-time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1 percent. A Nolte-Smith plot from the injection data yielded a quarter slope, indicating a Perkins and Kern system, i.e. a wedge-shaped vertically contained fracture, which is growing in length. CD1-01 A is of like reservoir quality and is expected to have similar fracture properties as demonstrated by CD1-19A above. 2014 CRU Disposal Well Performance Report CD1-01A 10 • ' • Well Work Summary CD1-01A Date Event 9/9/2014 TAGGED FILL AT 9736' MDRKB 6/30/2014 LOGGED INJECTION PROFILE, NO UPFLOW SEEN. 100% OF INJECTION ENTERING 9679'-9768' MDRKB 6/19/2014 PERFORM FCO TO 9786' MD, PERFORM INJECTIVITY TEST (4 BPM TO 2410 PSI) 3/8/2014 EPA WITNESSED (THOR CUTLER) MIT-IA PASSED @ 2340 PSI. LOGGED INJECTION PROFILE, NO UPFLOW SEEN. 100% OF INJECTION 3/8/2014 ENTERING TOP PERF SET 3/3/2014 PERFORMED CALIPER SURVEY FROM TAG AT 9416' MD TO SURFACE 3/2/2014 TAGGED FILL AT 9432' MDRKB Micromotion flow rate and MadgeTech pressure gauge transmitters are installed with an alarm system to detect excess injection pressures and rates. The well is monitored 24 hours a day during injection. The well operates at a maximum 4,200 psig wellhead pressure and an annulus pressure up to 2,000 psig. Continuous, recorded monitoring of volumes of hard piped waste streams are captured through the Alpine automation system. 2014 CRU Disposal Well Performance Report CD1-01A 11 d r 1 • 0 G) Ln 0) CO CD CD 10 CO CO N > co CO co to .1- O CO co 0) O W O r CD N O O) N N N O N- C) Ln N CO Ln O CY) O) Ln LU 7 0-53 r Ln CO O r CO T T CD T 0) N E J r N 7 C) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N T 10 to Ln v co o rn rn rn In o N- CO O Cr) CO CO 0) LC) 0 (0 Ln In _ () CM 0) 'Cr N CO CO to O) Cr) CO NI" r r 3 r coNco r N 00 in r Ln In C7) N 00 O 00'.0 OE— J - 2 W J CO U) 0 0 0 0 0 0 0 0 0 0 0 0 0 I- 1 C7 a) CD CO N CD CD d' r N CO 0) 0) CC O C7) CO CD Ln O CO r` CO C7) CO N CO CC >6 C•0 y 0 T O O) '_ 7.r O) CO r r T T CaJ� M U) Z .1- o.) O 1- O v.) o) 0) N CO CO CO O in CO Tr N CO O N- CD CD CO) N. CO i �-. N 0 N. CO CO O) N. N Ln ch LC) N- 17: coH N o)N C1 r r Ua`wa` a z — O_ O O) LC) N Ln N Nt' CO TrCO N. O) LC) N 0 CO 0) CO N. '4' CO N N T O N 3 ' Co_ O O 7, CO CM C�) Q 0 r r r r r T r r r C'�) r r r N C 3 N p) r N 0 0) CAu - U) o a o 0 d COa a r 0 O o N a R U CO O 2 r I.0N U N d O — O N N CO N. CO 0) CO Ln •ct CO _ N N O a N r N. T t` CO LC) Ln CO CO N ch cc 0i a Z a Z Cr r CO Ln Ln Ln N 00 Ln r CO 0 a 0 N u) N C") C') C') C'') N r r r r r N a)Z C Q• ` d'7/3 C a a a as w m o corn E 2 0 0 ~ a Baa) V -0 a < d NCO r CO r N. N 0 d1.0 N. ') t` Ln r CO O) N N O N Ln 't CD •C d 3 O) CO O O CO N O) C7) CO N CD O) H C) C) ' � vi C,- To E; z a) Cl- a 0 c to 6 m 0CC- (.) V NNOCO CO r UC O . IT d Q O CI T _) N M y R W s r '_> •c 00 co m 0 01) N Cl U Q r 0 > 2 Q m o 'O as co i a _a _o _a Jo t i > u a 0 C C i as Q ' - cm E o E C ct5 0 Q Q 0 > U 2 0 a (n Z 0 • eeci —►94. Regg, James B (DOA) ZeJO o4' From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Monday, September 08, 2014 12:30 PM Ve - To: Regg, James B (DOA) Cc: Senden, R. Tyler; NSK Well Integrity Proj Subject: Suspended Well Inspections CD1-19A (200-040) &2M-01 (192-103) Attachments: 2M-01 schematic.pdf; CD1-19A schematic.pdf Categories: Red Category Jim, I preparation for the quinquennial suspended well inspections that are due within 24 months of Sept 30th of years ending with a 5 or a 0, ConocoPhillips discovered 2 wells that have not had the initial inspection required within 1 year of the suspension as per 20 AAC25.110(e). CD1-19A(200-040)—was recently re-categorized from a P&A'd well to a suspended well in both the CoP and AOGCC databases and therefore did not originally show up in our system as requiring an inspection. The original suspension completion report was received May 31, 2013. Which means the inspection was due before May 31 2014. 2M-01 (192-103)—was suspended in June 2012(inspection due June 2013)and not properly recorded in our compliance database until the recent audit for wells requiring quinquennial inspections. Both wells are in field and have daily well house and pressure gage inspections. The State Witnessed Inspections will be bundled with other inspection work in the area and completed as soon as practical. Schematics are attached. Let me know if you have any questions. • MJ k6 (A)t" Cif WeCQ ► MJ Loveland / Martin Walters kyCtai 4- Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 SCANNED MAY 2 2 2015 1 4. WNS CD1-19A ,.-- Conoco hillipsg Well Attributes Max Angle&MD TD AIas,,t Ir1C Wellbore APVUWI Field Name Well Status 'noir) MD(ftKB) Act Btm(ftKB) 501032029401 ALPINE DISP 54.05 2,710.56 11,956.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 44.16 4/21/1999 Well.CoMst: CD1.19A,52020136'.38'.08 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:TOC 8,306.0 5/8/2013 Rev Reason:CMT Retainers/CMT IA/Suspend Well,Tag osborl 5/13/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd HANGER,33 l' `�� CONDUCTOR 16 15.062 38.0 114.0 114.0 62.58 H-40 WELDED olli, a s.,. P Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 36.8 2,825.9 2,393.5 36.00 J-55 ETC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd I s PRODUCTION 7 6.276 34.9 11,947.2 9,586.2 26.00 L-80 BTCM g9 Tubing Strings I ,Tubing Description String 0... String ID...Top(R103) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR. TUBING 3 1/2 2.992 32.9 10,791.6 8,468.3 9.30 L-80 EUE 8RD 3&114 ) Completion Details Top Depth e (ND) Top not Nomi... --;;; Top(ftKB) (0K8) (") Item Description Comment ID lin) NIPPLE,1.795 i= 32.9 32.9 -0.38 HANGER FMC TUBING HANGER 4.500 1,794.6 1,701.6 39.62 NIPPLE HES X NIPPLE 2.813 8,670.7 6,633.5 42.81 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 10,715.9 8,395.8 16.78 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 I II- 10,778.4 8,455.6 16.40 NIPPLE HES XN NIPPLE w/NO GO PROFILE 2.750 SURFACE, ,, , 10,789.9 8,466.7 16.35 WLEG WIRELINE RE-ENTRY GUIDE 3.125 37-2,826 CMT PLUG, , Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 7.776 a.. Top Depth CMT PLUG, (ND) Top Incl TBG Top(RKB) IRKS) ("I Description Comment Run Date ID(M) PUNCHES, 8,610.0 6,589.0 42.84 TBG 5'OF TUBING PUNCHES,4spf,0 DEGREE PHASE 4/20/2013 2.992 8,610 a PUNCHES 10,112.0 7,824.7 20.49 CMT Retainer WEATHERFORD CEMENT RETAINER 5/1/2013 '. 10,689.0 8,370.0 17.00 CMT Retainer WEATHERFORD CEMENT RETAINER 4/28/2013 PACKER,8.671 ten._: 10,737.0 8,416.0 16.56 FISH SLICKLINE TOOL STRING,PLUG&GAUGES(OAL=31'2")5/24/2012 0.000 ir ark Perforations&Slots Shot Top(ND) Btm(TVD) Dons IPERF. Top(ftKB) Btm(065) (RKB) (RKB) Zone Date (sh-• Type Comment e.750-e760 8,750.0 8,760.0 6,693.9 6,701.0 K-1 Marker, 5/23/2000 4.0 IPERF Sqz Gun;pert date approx. IPERF, g WERE. 8'990.9.000 i 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5,CD1-19A 5/23/2000 4.0 IPERF Sqz Gun;peri date approx. CMT Retainer, 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, 1/5/2003 6.0 RPERF 2.5"HSD 2506 HJ,60 deg Phase 1o,112 - 1 CD1-19A w/mag Tec HOLE, 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, 1/5/2003 12.0 RPERF 2.5"HSD 2506 HJ,60 deg Phase 10.316 CD1-19A w/mag 11,720.0 11,740.0 9,365.5 9,385.0 IVISHAK, 1/5/2003 6.0 APERF 2.5"HSD 2506 HJ,60 deg Phase CD1-19A w/mag TBG H0416 OLE, 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, 1/5/20039 6.0 RPERF 2.5"HSD 2506 HJ,60 de Phase CD1-19A w/mag CMT PLUG, 6.306 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, 6/3/2000 12.0 RPERF 212 HSC;60 deg ph CMT PLUG. CD1-19A 10.420 CMT Retainer, 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, 6/2/2000 6.0 IPERF 21/2 HSC;60 deg ph 10,689 CD1-19A it liv 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, 6/2/2000 12.0 RPERF 2 1/2 HSC;60 deg ph CD1-19A PACKER 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, 2272003 6.0 IPERF 2.5"HSD HJ 10,716 CD1-19A 1 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, 6/2/2000 6.0 IPERF 212 HSC;60 deg ph CD1-19A 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, 2/27/2003 12.0 RPERF 2.5"HSD HJ FISH.10.737 CD1-19A iNotes:General&Safety NIPPLE,10.778 11'3C End Date Annotation ill 1/6/2011 NOTE:View Schematic w/Alaska Schematic9.0 WLEG,10,790 5/5/2013 NOTE:WELL SUSPENDED,TUBING/CASING/IA CEMENTED;TBG TOC @ 8306';IA TOC 7776' RPERF, 11,463-11,483 RPERF, 11,509-11,520 RPERF, ,'T.0 11,720-11.740 ?a•. RPERF. 11,749-11,750 RPERF. 11,750-11,763 , 11.768-11PE,77RF6 , RPERF, - 11,780.11,793 tom' IPERF, 11.793-11,794 IPERF, - 11.800-11803 RPERF, 11.803-11.813RPEF. 3 TBG HOLE, 10.340 PRODUCTION. 35-11,947 TD(CD1-19A). , 11 11,956 Imag '--J' 'roject Well History File Cover '-3e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file. may be scanned during a special rescan activity or are viewable by direct inspection of the file dO 0- 0 Yo Well History File Identifier Organizing" , JE CAN Color items' 1111111111111111111 0 Tv/o,Slded DIGITAL DATA 0 Diskettes. No. 0 Grayscale items: Poor Quality Originals: Other. NofType 0 0 0 Other: NOTES: 8( BEVEPl( R081tJ VltJ':E~JT SHE""Bv"~Ü( Project Proofing 8( BEliEI',L'r'ROE!IN VinCENT SHEP'L ÐVltJC'( Scanning Preparation -3- x 30 = 10 8( BEVEPl' R081rJ V,rJCE/lT SHERII@'fJD' Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: 8,': - BEI,IE.R(.[:'3Ü81~~~VIW;ENT SHEP ,'L M1PIA W/tJD, Stage 2 ~~escan r Jeeded 1111111111111111111 OVERSIZED (Scannable) 0 Maps: 0 Olher items scannable by large scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other DATE tl ß4/03/:,' 01 ~ 1111111111111111111 DATE ~l J03 19 VVtf + = TOTAL PAGES C¡(J D~TE t.tÞtjð;?P ~~ 9?J -Á-YES _NO DUTE5/-Q3'SI ,,~ - YES ,)(:.. NO DUTE6C>?-Q3/SI ~ 1111111111111111111 8,-: IF NO IN STAGE 1. PAGE(S) DISCREPANCIES WERE FOUND: BE\ (Rl"(~:~:~:.)./rNCE rJT SHE'" ,'L M~PIA WI~JD,' Sr A'''~I',,:; I; .:(\'JI~Le TI! A 1 '1-1,:: t")I.rr 'JrILE~.:. ::,Cet"~I~1. .!to 11E'.1Itjr. I'; J: ¡;:")I.'IPI!(lI)P~ Af~ 1I~r:"'.II:.I.'Ð I. t:'",~ I;: flA :13 [.'IJ£ Ic.QLI!IoI.IT" .:: :'A'~C"lE C.R(.')L0PI""A.:I;:~ I ReScanned ' ,,/, . RESCANr~EDB.( BEVERL',' R081~J VltJCEfJT SHERlt MAPI.. Wlfm,' General Notes or Comments about this file. 1111111111111111111 DIITE ISI Quality Checked ,,/ ',,,, I 1111111111111111111 12111)1')2R~. 3NOTS~an"g~ '^pa STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETI REPORT AND LOG la.Well Status: Oil Gas SPLUG Ill ❑ Plugged ❑ Abandoned El Suspended -II Class: 20AAC 25.105 20AAC 25 10 j/1-n� CIDevelor ent ❑ Exploratory GINJ 11 WINJ [l] WAG CI WDSPL ❑ Other ii No.of Completions: A cttna e ce 0 StratigraphicTest Ell, 2.Operator Name: 5.Date Comp.,Susp., 12. rmit to Drill Number: ConocoPhillips Alaska, Inc. ' or Abend.: May 8,20 200-040/312-423 ' 3.Address: 6.Date Spudded: 13.API Number: P.0. Box 100360,Anchorage,AK 99510-0360 April 5,2000 50-103-20294-01 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 351'FNL,2447'FWL,Sec.5,T11 N, R5E, UM April 17,2000 CD1-19A • Top of Productive Horizon: 8.KB(ft above MSL): 36'RKB 15.Field/Pool(s): 972'FSL,69'FEL,Sec.29,T12N, R5E, UM GL(ft above MSL): 56'AMSL Colville River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 1736'FNL,3325'FEL,Sec.33,T12N, R5E,UM 8306'MD/6365'TVD Undefined Disposal Pool. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-385873 y- 5975778 Zone-4 11956'MD/9595'TVD . • ADL 25559,25558,25557 •TPI: x-388714 y- 5982339 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-390706 y- 5979599 Zone-4 ' nipple @ 1795'MD/1702'TVD 932104,932102,932106 18.Directional Survey: Yes ❑ No O 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 896'MD/896'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD caliper not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 38' 114' _ 38' 114' 24" 10 cu yds Portland Type 3 1 9.625" 36# J-55 37' 2826' 37' 2394' 12.25" 860 sx AS III LW,230 sx Class G 7" 26# L-80 35' 11947' 35' 9586' 8.5" 566 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/IVO) 3.5" 10792' 8671'MD/6633'TVD and abandoned 10716'MD/8396'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ...f AAI t ; &� i, Was hydraulic fracturing used during completion? Yes❑ No El ` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED MAY 3 1 2`01'i 8306' 13 bbls of 15.8 ppg Class G AO CC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No a . Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE SCANNED MAY 2 9 RBDMS JUN -7 2013 2014 Form 10-407 Revised 10/2012 )/// CONTINUE`D9N REVERSE T'If „sioli Submit original only V 1 I//Z/' /✓)4- L 4//!nw//.. - / Z. 29. GEOLOGIC MARKERS(List all formations and m,_ s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? l__! Yes D No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 896' 896' needed,and submit detailed test information per 20 AAC 25.071. Alpine D 10350' 6835' Base Alpine 10407' 6852' ' N/A Formation at total depth: Alpine D 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: T.Senden @ 265-1544 Email: R.Tyler.Senden@conocophillips.com Printed N Senden Title: Staff Wells Engineer Signature . 1\ 265-1544 Date / 3/13 "1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 WNS CD1-19A ConocoPhiUUips " &WBpa Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Well Status Ind(*) MD(ftKB) Act Btm(ftKB) 501032029401 ALPINE DISP 54.05 2,710.56 11,956.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 44.16 4/21/1999 Well Conan:-C01-19A.5/17/201310:12:18 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:CTMD 10,700.0 4/21/2012 Rev Reason:CMT Retainers/CMT IA/Suspend Well osborl 5/13/2013 Casing Strings Casing Description String 0... String ID.. Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String String Top Thrd HANGER,33 CONDUCTOR 16 15.062 38.0 114.0 114.0 62.58 H-40 WELDED o Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd SURFACE 9 5/8 8.921 36.8 2,825.9 , 2,393.5 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ` I7. PRODUCTION 7 6.276 34.9 11,947.2 9,586.2 26.00 L-80 BTCM if Tubing Strings I _,...1_4nm Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd coNDucrop, TUBING 13 1/2 I 2.992 I 32.9 I 10,791.6 I 8,468.3 I 9.30 I L-80 I EUE 8RD 38-114 Completion Details Top Depth (TVD) Top Incl Noel... Top(RKB) (KKB( P) Item Description Comment ID(in) NIPPLE i.795 �� 32.9 32.9 -0.38 HANGER FMC TUBING HANGER 4.500 HIE 1,794.6 1,701.6 39.62 NIPPLE HESXNIPPLE 2.813 8,670.7 6,633.5 42.81 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 10,715.9 8,395.8 16.78 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 10,778.4 8,455.6 16.40 NIPPLE HES XN NIPPLE w/NO CO PROFILE 2.750 SURFACE. , 10,789.9 8,466.7 16.35 WLEG WIRELINE RE-ENTRY GUIDE 3.125 37-2,828 CMT PLUG. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 7,778 Top Depth CMT PLUG, 8,306 (ND) Top Incl TOG Top(ftKB)_(ftKB) (°) Description Comment Run Date ID(In) PUNCHES, 8,610.0 6,589.0 42.84 TBG 5'OF TUBING PUNCHES,4spf,0 DEGREE PHASE 4/20/2013 2.992 8,610 PUNCHES p 10,112.0 7,824.7 20.49'CMT Retainer WEATHERFORD CEMENT RETAINER 5/1/2013 , I 10,689.0 8,370.0 17.00 CMT Retainer WEATHERFORD CEMENT RETAINER 4/28/2013 PACKER.6,671 �... 10,737.0 8,416.0 16.56 FISH SLICKLINE TOOL STRING,PLUG 8 GAUGES(OAL=31'2")5/24/2012 0.000 i( Perforations&Slots Shot Top(ND) Btm(TVD) Dens IPERF, Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone Date (oh... Type Comment 8,75041,780 8,750.0 8,760.0 6,693.9 6,701.0 K-1 Marker, 5/23/2000 4.0 IPERF Sqz Gun;pert date approx. IPERF, CD1-19A °•�0"�•0°° 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5,CD1-19A 5/23/2000 4.0 IPERF Sqz Gun;pert date approx. CMT R.aln.r, 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, 1/5/2003 6.0 RPERF 2.5"HSD 2506 HJ,60 deg Phase I 10,112 CD1-19A w/mag TBG HOLE. 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, 1/5/2003 12.0 RPERF 2.5"HSD 2506 HJ,60 deg Phase 10,318 CDi-19A w/mag 11,720.0 11,740.0 9,365.5 9,385.0 IVISHAK, 1/5/2003 6.0 APERF 2.5"HSD 2506 HJ,60 deg Phase CD1-19A w/mag TOG HOLE,0.416 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, 1/5/2003 6.0 RPERF 2.5"HSD 2506 HJ,60 deg Phase CMT PLUG. CD1-19A w/mag 6.906 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, 6/3/2000 12.0 RPERF 212 HSC;60 deg ph CMT PLUG. N CD1-19A 10,420 CMT Retainer, ju 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, 6/2/2000 6.0 IPERF 212 HSC;60 deg ph 10,689 r CD1-19A 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, 6/2/2000 12.0 RPERF 212 HSC;60 deg ph CD1-19A PACKER._ 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, 2/27/2003 6.0 IPERF 2.5"HSD HJ 10,716 - CD1-19A 1. 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, 6/2/2000 6.0 IPERF 212 HSC;60 deg ph IIPCD7-19A 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, 2/27/2003 12.0 RPERF 2.5"HSD HJ FISH,10,737 I R. CD1-19A Ili Notes:General&Safety NIPPLE.10.778 111'C End Date Annotation - 1/6/2011 NOTE:View Schematic w/Alaska Schematic9.0 WLEG,10,790 11 t 5/5/2013 NOTE:WELL SUSPENDED,TUBING/CASING/IA CEMENTED;TBG TOC @ 8306';IA TOC 7776' RPERF, 11,48}11,483 11.504 11,520 RPERF, II APERF, , 11,720.11,710 RPERF, 11,749-11,750 RPERF, I I 11,750-11,763 3 IPERF. , 11,788-11,778 RPERF, , 11,780-11,793 IPERF, - - 11,793-11,794 = IPERF, 11,800-11,803 RPERF, 11,803-71,813 TBG 10,34HOLE6, PRODUCTION, 35-11,947 TD(CDI-19A),� -. Ilk 11.956 DATE. JOBTYP SUMMARY 3/29/12 State EPA witnessed (Talib Syed) MITIA(PASSED). Testing State (AOGCC)waived witness. 3/29/12 State LRS DSPL TBG WITH 188 BBLS SEAWATER &35 BBLS DSL. PULLED 2.81" Testing MCX INJ VLV( SN:MCX-304 ) DRIFT TBG WITH 5' x 2.5"; TAGGED IN TBG @ 10,363' SLM. READY FOR E/L. 5/7/12 FCO PERFORMED FCO USING GEL SWEEPS TO 11,821'. (APROX 40' RATHOLE) HEAVY SOLIDS SEEN IN RETURNS. FREEZE PROTECTED WELL TO 3000'. JOB COMPLETE. 5/8/12 State MOBILIZE TO ALPINE AND PREP EQUIPMENT FOR UPCOMING CALIPER AND Testing SPECTRAFLOW JOB. 5/9/12 State ATTEMPT CALIPER LOG. TOOLS COULD NOT BE FLOWN IN ON A CARGO Testing FLIGHT DUE TO FOG. WILL REATTEMPT TOMORROW. 5/10/12 State PERFORMED CALIPER SURVEY TO EVALUATE THE CONDITION OF THE Testing TUBULARS FROM TAG TO SURFACE 5/12/12 State ATTEMPTED SPFUIPROF, OBSERVED FLOW EXITING TUBING THROUGH Testing THREE LEAKS BETWEEN PACKERS. LEAKS OBSERVED WITH SPINNERS, TEMPERATURE AND SPECTRAFLOW TOOLS AT 10316', 10348', AND 10416'. WELL LEFT SHUT-IN AND FREEZE PROTECTED. 5/19/12 SBHP/FBH GAUGED TBG TO 2.80"TO 10778' RKB. SET HES GAUGE ASSY ON 2.81"XN- P Survey LOCK @ 10778' RKB (OAL: 80.5"/BATTERIES CONNECTED @ 11:34 am). RAN (11) CHECK SET TO VERIFY LOCK SET. RETURN IN 5 DAYS FOR GAUGE DUNK. 5/24/12 SBHP/FBH MEASURED BHP @ 9092' RKB. 4812 PSI/ 142 F. ATTEMPTED TO EQUALIZE P Survey XXN PLUG @ 10,778' RKB. TOOL STRING HUNG UP @ 10,778' RKB, FREED (11) UP TS. BAILLED FILL&TAGGED PLUG BODY @ 10,778' RKB. IN PROGRESS. 5/26/12 Ann-Comm GAUGE TBG TO 2.80"TO 11,778' SLM. LATCH XXN PLUG, UNABLE TO GET PLUG ABOVE 10,478' SLM. ATTEMPT TO SHEAR OFF PLUG, DECISION MADE TO DROP CUTTER, WLVs NOT HOLDING & HAVE TO SECURE WELL. ATTEMPT TO F/P WELL &0 RING ABOVE WLV LEAKS, TURN IN RAMS &GET CONTROL OF LEAK. WELL WATCH UNTIL MORNING. CHANGE OUT W/770 CREW. 5/27/12 SBHP/FBH CLOSED SWAB ON WIRE LEAVING WIRE (APPROX 10,730') AND P Survey TOOLSTRING ((24'-5" OAL OF TOOLSTRING AND TOOL+ 80.5" OF PLUG AND (11) GAUGES)) IN WELL. RIGGED DOWN UNIT 772. IN PROGRESS. 5/27/12 Ann-Comm PREP FOR FUTURE FISHING JOB. TESTED BOTH UNITS WIRELINE VALVE. IN PROGRESS. 5/29/12 Ann-Comm ATTEMPT TO KNOCK WIRE OFF ROPESOCKET& SD HIGH @ 10,546' SLM IN FILL. IN PROGRESS. 5/30/12 Ann-Comm RAN SIDEWALL CUTTER&CUT WIRE @ 1763' SLM. RECOVERED APPROX. 1760' OF .125"WIRE. IN PROGRESS. 10/17/12 Slickline VERIFIED WIRE ACROSS SSSV NIP. ATTEMPTED TO PUSH WIRE DN THRU Misc. Drift, SAME @ 1795' RKB. IN PROGRESS. Tag, etc. 10/18/12 Slickline RECOVERED APPROX 12' OF WIRE (SINGLE PIECE). IN PROGRESS. Misc. Drift, Tag, etc. 10/19/12 Slickline TAGGED POSSIBLE FILL @ 10,495' SLM. APPROX 250 ABOVE FISH. SET Misc. Drift, SIDEWALL WIRE CUTTER @ 10,491' SLM w/GUIDANCE OF CPAI FIELD SUPR. Tag, etc. IN PROGRESS. 10/20/12 Slickline FISHED APPROX 8700' OF WIRE. IN PROGRESS. Misc. Drift, Tag, etc. 10/21/12 Slickline BAILED ON SIDEWALL CUTTER. PULLED SIDEWALL CUTTER @ 10,498' SLM. Misc. Drift, JOB SUSPENDE ° Tag, etc. 11/22/12 Secure MOBILIZE CREW TO ALPINE, MIRU CTU#4, JOB IN PROGRESS Well 11/23/12 Secure PERFORM FCO WITH JSN PUMPING KCL W/BIO SWEEPS. CLEAN TO HARD Well TAG AT 10,689' CTMD MAINTAINING 1:1 RETURNS. LARGE AMOUNT OF SOLIDS IN RETURNS TANK. NOT CERTAIN IF TAG IS FISH, WILL RETURN IN AM FOR LIB RUN. JOB IN PROGRESS. 11/24/12 Secure RIH WITH 2" DJN TO HARD TAG AT 10735' CTMD. PUMP 10 BBL BIO GEL Well SWEEP, BRING TO SURFACE TAKING 1:1 RETURNS. RIH WITH 2.60" LIB, LOCKS UP AT 10,559' CTMD. BEGIN POOH, LOSE POWER TO UNIT. STRIPPER LEAKS 1/2 GALLON DIESEL ONTO TOP OF WELLHOUSE. RETURN POWER, AT SURFACE. LIB SHOWS DEFINITE TUBING DAMAGE. RETURN IN AM, JOB IN PROGRESS. 11/25/12 Secure RIH W/2.26' SWEDGE AND BAKKE HAMMER TO TRY AND OPEN COLLAPSED Well TBG, TAGGED UP AT 10560' CTMD, WORK SWEDGE DN TO 10619' CTMD, POOH, F/P TBG, INSPECT SWEDGE--NO DAMAGE, JOB IN PROGRESS. 11/26/12 Secure RIH W/2.26"SWEDGE AND JARS, TAG DAMAGED TBG AT 10614' CTMD, GET Well 50 JARLICKS, WORKED DOWN TO 10623' CTMD, F/P CT AND TGB WHILE POOH, CUT 100' OF CT, RD CTU, STAGE IN CONTAINMENT, JOB IN PROGRESS 11/29/12 Secure RAN 2.78" LIB AND SD @ 1768' SLM, NOT ABLE TO PASS. RAN 2.75" LIB, TAG Well HARD @ 10540' SLM . IMPRESSION OF WIRE ON TOP& SIDES. RAN 3 PRONG WIRE GRAB, RECOVERED -2' 1"OF WIRE. **NO CROSS FLOW ENCOUNTERED**. IN PROGRESS. 11/30/12 Secure RECOVERED-19' OF WIRE @ 341' &-2'WIRE @ 10610' SLM. ABLE TO WORK Well WIRE GRAB TO 10615' SLM. LEFT WIRE GRAB ASSY(21" BAIT SUB,XO &25" 3 WIRE GRAB (OAL= 50.5") @ SAME. IN PROGRESS. 12/1/12 Secure PULLED WIRE GRAB ASSY @ 10612' SLM. BAILED FINE SLURRY FROM 10615' Well - 10626' SLM. RAN WIRE GRAB ASSY TO 10623' SLM & RECOVERED 37" OF WIRE. IN PROGRESS. 12/2/12 Secure BAILED FINE SOLIDS f/ 10623' - 10630' SLM. NO WIRE RECOVERED. IN Well PROGRESS. 12/3/12 Secure RECOVERED A 3" PIECE OF WIRE WHILE BAILING FINE DEPOSITS (-3 GAL) Well @ 10630' SLM. ATTEMPT TO FISH WIRE, BENT WIRE GRAB AT 10630' SLM, LIB INDICATES WIRE AND FILL. IN PROGRESS. 12/4/12 Secure RECOVERED -1 GAL FINES @ 10631' SLM. OBTAINED PIC OF 3 WIRE Well STRANDS @ 3-6 &9 0-CLOCK. ATTEMPT TO SET 3-PRONG WIRE GRAB, UNABLE TO PLANT IN WIRE. RAN 2.789"G.RING TO 10630' SLM. RAN 2.5" MAGNET TO 10631' SLM. RECOVERED 1/2" OF METAL SHAVINGS ON TOP OF MAGNET. IN PROGRESS. 12/5/12 Secure RAN 1.4" LIB TO 10631'. PICTURE OF FILL&WIRE ON TOP & SIDE. Well RECOVERED -'1 GAL FILL f/ 10630' SLM WITH 2" BAILER. RAN WIRE SPEAR'S TO 10630'. UNABLE TO LATCH WIRE FISH w/SPEARS. IN PROGRESS. 12/8/12 Secure ATTENDED ENVIRONMENTAL STAND UP. TRAVELED TO ALPINE. MOBILIZED Well UNIT TO CD1-19 AND SPOTTED INTO LOCATION. 12/11/12 Secure CLEANED OFF TOP OF FISH AT 10,623'. JETTED ON FISH WITH BIOZAN. Well FREEZE PROTECTED WELL TO 2000'ND. MAINTAINED SLIGHTLY LESS THAN 1:1 RETURNS. JOB IN PROGRESS. 12/12/12 Secure ATTEMPTED TO FISH SLICK LINE WIRE BALL. TAGGED TOP OF FISH AT Well 10622' CTMD. WASHED DOWN TO 10623.9'. PULLED 5K POUNDS OVER SET DOWN TO CONFIRM MOVEMENT OF FISH. AT SURFACE NO WIRE RETRIEVED. WELL FREEZE PROTECTED JOB IN PROGRESS. 12/15/12 Secure STANDBY FOR WEATHER UNTILL 1:00 PM. CHANGED PACKOFFS AND Well HEATED UP UNIT. WEATHER DROPPED BELOW MINIMUMS AGAIN. SUSPENDED OPERATIONS. 12/16/12 Secure SET DOWN AT 10 421' ON SOFT TAG SET DOWN AND WASHED DOWN TO Well 10601'WORKIN DEXING TOOL SEVERAL TIMES. PULL 32K. (11.5K OVER) REMAINEu HEAVY TILL 2300'WEIGHT BROKE BAG... NO FISH RECOVERED. WELL FREEZE PROTECTED. JOB IN PROGRESS. 12/25/12 Secure RAN 2.75" LIB TO 10625' SLM. PIC OF FILL. RAN 2" DD BAILER. RECOVERED Well -3/4 GAL FILL. IN PROGRESS. 12/26/12 Secure BAIL FILL f/ 10628' - 10632' SLM. RAN 2.75" LIB TO 10632' SLM. LIB Well INCONCLUSIVE. ATTEMPT TO LATCH WIRE BALL @ SAME. IN PROGRESS. CD1-19A Well Work Summary DTTMSTART SUMMARY 4/1/2013 Dress up X nipple at 1795'w/2.80"diamond speed mill, RIH w/2.80" cut-rite edge burnover shoe to dry tag of 10,615' ctmd. Milled for four hours trying to swallow wire debris without success. Motor stalls became more frequent as time progressed. Will return in the morning with wire/rope spear for coil and attempt to fish out.125 slickline. 4/4/2013 RIH to fish .125" slickline with wire spear on coil, tagged fish at 10,615' ctmd. Worked fish down to 10,651'ctmd. RIH w/three prong wire grab to same location, unable to latch wire. LDFN 4/5/2013 RIH w/wire spear and motor to tag at 10,643'ctmd, rotate motor to stall and PU w/5000#over pull for 20'. Appears we lost wire while POOH. Will return in the AM. 4/6/2013 Continue clearing ice from riser sections and surface lines, replace PO and make up BHA for AM 4/7/2013 RIH w/Si-Di &down ported blind box to top of fish @ 10,642'ctmd. Multiple stalls on Si-Di without making headway. C-pump on coil failed and lost the ability to pump beyond gravity feed. POOH for repairs. Will resume in the AM. 4/8/2013 RIH w/2.20" DJN and remove hydrate plug at surface and condition the well back to hot SW from 9000'to surface. RIH w/wire spear on motor and tag wire fish several times at 10,649'ctmd. OOH pulling 5000#over for 3000', once at surface two small pieces of.125 left in wire spear. 4/9/2013 CREW CHANGE OUT. PERFORMED BOPE TEST. 4/10/2013 MADE VENTURI RUN TO TAG AT 10,601' CTMD. STALLED 5 TIMES WITH NO EVIDENT MOTOR WORK SEEN. RECOVERED APPROXIMATELY 4 FEET TOTAL LENGTH OF WIRE PIECES AND NOMINAL FILL. WELL FREEZE PROTECTED. JOB IN PROGRESS. 4/11/2013 RAN TO 10,608' CTMD WITH VENTURI RECOVERED FULL BASKET OF FILL. MADE ANOTHER RUN TO 10,678' CTMD WITH WIRE GRAB AND RECOVERED APPROXIMATELY 2.5'OF WIRE. FREEZE PROTECTED WELL FROM 2000'ND. 4/12/2013 MADE TWO RUNS WITH WIRE GRAB/SPEAR. TAGGED AT 178.4' RECOVERED LARGE WIRE BALL FROM THE FIRST RUN. SECOND RUN TAGGED AT 10,666.2' CTMD WORKED PIPE TO 10,677.9' CTMD RECOVERED 15' OF WIRE ON SECOND RUN. WELL FREEZE PROTECTED. IN 4/13/2013 RIH TO 3500' DEVELOPED A LEAK AT THE PACKOFFS CALLED SECURITY AND ACS SPILL WAS CLEANED UP. PULLED OUT AND INSPECTED PACK OFFS APPEARED TO HAVE MELTED. MADE RUN TO 10689'WITH WIRE GRAB/SPEAR OVER PULLED 2K. RECOVERED NO WIRE AT SURFACE. WELL FREEZE PROTECTED IN PROGRESS. 4/14/2013 MADE VENTURI RUN TO 10,683' CTMD RECOVERED FULL BASKET OF FILL. MADE WIRE GRAB/SPEAR RUN TO 10,703'CTMD UNABLE TO GET ANY DEEPER. RECOVERED APPROXIMATELY 6 FEET OF WIRE. WELL FREEZE PROTECTED. JOB IN PROGRESS. 4/15/2013 FIRST RUN TO 10,710'WITH WIRE GRAB, FILL ON SPEAR RECOVERED NO WIRE. MADE CLEAN OUT RUN TO 10,731' CTMD HARD TAG. JETTED ON TAG, UNABLE TO PENETRATE ANY DEEPER. WELL FREEZE PROTECTED. IN PROGRESS. 4/16/2013 Ran 2.79" blind box on BIDI Hipp Tripper to 10710' CTMD. Pulled 38 k bind (25.5 K over pull) and came free. Inspected blind box at surface. Wire marks all around the sides of the blind box. In 4/17/2013 RAN 2" NOZZLE DOWN TO A HARD TAG @ 10,729' CTMD. RAN SPEAR WIRE GRAB TO 10726' CTMD, RECOVERED 15—OF WIRE. WELL IS FREEZE PROTECTED WITH DIESEL, IN 4/18/2013 MADE 2 RUNS WITH WIRE SPEAR ON MOTOR TO 10727' CTMD. RECOVERED—15" OF WIRE ON 1ST RUN, NO RECOVERY ON 2ND RUN. WELL READY FOR SLICKLINE & E-LINE. 4/19/2013 DRIFT TBG TO 2.80"TO 10150' SLM. UNABLE TO PASS. RAN 2.3" LIB &2.58" CENT TO 10699' SLM. MARKS ON LIB MAY INDICATE SITTING DWN IN BTM OF PACKER @ 10716' RKB. READY 4/19/2013 LOG JEWLERY CORRELATION LOG TO DETERMINE IF WE CAN GET BELOW PACKER. FOUND WE COULD GET 9' BELOW PACKER TO 10734' **IN PROGRESS** 4/20/2013 JET CUT TUBING TAIL WITH CUT DEPTH AT 10727.1' CCL TO CUTTER 5.1' CCL STOP AT 10722'THIS WAS AS DEEP AS WE GOT WITH THE CUTTER. SHOT CIRCULATION HOLE IN TUBING WITH TOP SHOT AT 8610'CCL TO TOP SHOT 3.9'CCL STOP AT 8606.1' SHOT 5' OF 4 SPF 0 DEG PHASED BH CIRCULATION CHARGES, GOOD COMMUNICATION ESTABILSHED WITH IA. ATTEMPT SECOND JET CUT OF TUBING TAIL BUT COULD NOT GET PAST 10721' 4/21/2013 TAG @ 10700' CTMD. WORK BAKKE HAMMER, STALLED HAMMER ONCE AND LOST CIRCULATION DOWN THE COIL. UPON INSPECTION, BAKKE HAMMER WAS LOCKED UP. JOB SUSPENDED FOR UNIT MAINTENANCE AND PIPE SWAP, IN PROGRESS. 4/24/2013 Weather delayed start. Mobilize CTU#5 to Alpine and prep for job. In progress. 4/25/2013 Conduct weekly BOP test 300/4,000 psi. Tag at 10,697-ft ctmd, clean out down to 10,733-ft ctmd. In Progress. 4/26/2013 Set Baker Retrievable Packer at 10,660-ft. Injectivity test into Ivishak, .9 bpm at 4,000 psi, .7 bpm at 3,800 psi, .3 bpm at 3,340 psi. Pulled retrievable packer. In progress. 4/28/2013 Set Weatherford Cement Retainer at 10,689-ft, unable to inject below retainer into Ivishak, several attempts made to regain ious injection rate. Waiting on town for p! -rward. In progress. 4/2972013 Wait on orders from town. established inject rates 1 bpm at 1,750 psi, opm at 1,880 psi and 2 bpm at 2,030 psi, freeze protect well. In progress. 4/30/2013 Lay in 5 bbls 15.8 ppg cement from 10,689-ft, wash tubing from 9,800-ft down to top of cement at 10,420-ft maintaining 1:1 returns. Established injectivity rates 1 bpm at 2,406 psi, 1.5 bpm at 2,582 psi and 2 bpm at 2,780 psi for 35 bbls total. Freeze protect well. In progress. 5/1/2013 Displace wellbore to 12.1 ppg brine. Set Weatherford 3-1/2" Cement Retainer at 10,112-ft. Squeeze 50 bbls of 15.8 ppg class"G"cement behind pipe up to the Alpine prefs. Freeze protect. Ready for E- 5/2/2013 Rig off well, inspect job site with ACS. Travel from Alpine to Prudhoe for scheduled maintenance. 5/2/2013 DRIFTED TBG. TO 2.65", TAG CEMENT @ 10,101' SLM. READY FOR E-LINE. 5/3/2013 LOGGED FROM 10,100' -8,600'WITH A REPEAT PASS FROM 10,100' -9,900'AND A FREE PIPE PASS FROM 3915' -3700'. FOUND TOP OF CEMENT AT 8998' 5/5/2013 Injected 30 bbls of diesel into IA to confirm communication. Tag cement retainer at 10,115' ctmd. Lay in 13 bbls of 15.8 ppg class G cement from retainer to 8590', opened casing valve taking returns up IA and squeezed 22 bbls of cement into IA. Well is now suspended! 5/8/2013 TAGGED TOC @ 8306' SLM. SAMPLE RECOVERED. MITT:PASSED MITIA:PASSED 22537 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 7, 2013 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAY 10 2013 RE: Radial Cement Bond Log: CD1-19A A0000 Run Date: 5/3/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com CD1-19A Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20294-01 Cement Bond Log 1 Color Log 50-103-20294-01 SCANNED MAR 1. 3 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: 5 lyd Signed: ,� MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 69113 TO: Jim Regg ���� DATE: May 8, 2013 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore Plug verification Petroleum Inspector C.P.A.!. CD1 -19A Colville River Field PTD# 200 -040 - SCANNED MAY 14 2.013 Sundry# 312 -423 - Wednesday, May 08, 2013: I witnessed the verification of suspension plug placement by wireline tag and pressure test on C.P.A.I.'s well CD1 -19A in the Colville River Field. I travelled from Deadhorse this morning by Shared Services "Twin Otter" to the Alpine facility CD -1 pad where I was met by Perry Klein and we went over the plug particulars. The HES wireline unit was on location and ready to go in the hole. They ran in with a centralized 1 3/4" bailer. The bailer fetched up at 8306' WLM (zeroed at THF). I had the operator jar down a few times and pull back up, with some over -pull he came free and pulled out of the hole. Upon reaching surface the tools were withdrawn from the lubricator and a sample of what appeared to be contaminated cement was captured from the bailer. I requested - that this sample be retained and analyzed for content and reason for not setting up. In reading the well service reports, which seemed "thin ", it was not evident whether the Coil unit "washed off" the top of the cement they laid in or spaced a fresh water spacer above before they freeze protected with diesel which may be the reason the cement on top did not set up. Also there was an additional retainer run and the depths on the approved procedure did not match up with the well service reports or our tag. The cement top was shallower than what was called for in the approved procedure. There was not anything to be done with the depths at this point and after discussion with Mr. Klein it was decided to proceed with the pressure tests but I requested that until the different depth and competency of the cement was approved by our office they not go any farther with the P&A program on this well. 20 1 3 -050 8_Suspend_Plug_CRU_CD 1- 19A_lg.docx 1 of 2 • The pressure test of the tubing went well. Little Red Services (LRS) pumped 1 /2 barrel of diesel to brin g the tubing pressure from 0 psi up to 2240 psi, following are particulars of the test: Tubing Test Pretest Initial 15 Minutes 30 minutes IA 100 100 100 100 OA 400 400 400 400 Tubing 0 2240 ' 2060 2030 - After this test was bled off LRS rigged over to the Inner Annulus which had 100 psi on it. I requested that this be bled to a bleed trailer to remove any gas or air column. The initial bleed was a very small amount of gas /air and went quickly to fluid which also bled off quickly to zero psi. The Inner Annulus was pressured up using 3.3 bbl's of diesel and the following pressures were observed. Inner Annulus Pretest Initial 15 Minutes 30 minutes Test IA 0 2260 " 2160 2125 OA 425 425 430 430 Tubing 90 350 350 350 Summary: Although the pressure tests were within accepted guidelines there are some questions pertaining to the depths and consistency of the cement samples of " the plug in the tubing. Attachments: None 201 3- 0508_Suspend_Plug_CRU_CD 1- 19A_lg. docx 2 of 2 op • . Lynn DeGeorge MAT Sr. Environmental Coordinator Iry ConocoPhillips Alaska ConocoPhilli s An G Street Anchorage AK 99501 Phone 907 - 263 -4671 IP April 30, 2013 Mr. Peter Contreras Certified Mail O Supervisor, Ground Water Protection Unit 7010 1060 0000 5093 8549 U.S. Environmental Protection Agency (OCE -082) Return Receipt Requested 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 SCANNED MAY 0 7 2013 RE: Class I Well Permit #AK11010- A,D1- 19A))Permit to Drill , o. 200 -040 Class I Well Permit #AK1I010 -A (CD1 -01A), Permit to Drill o. -099 -0 Class I Well Permit #AK- 11003 -B (WD -02), Permit to Drill No. 90258 Biennial Report — 4 Quarter 2012 and 1s Quarter, 2013 p Dear Mr. Contreras, On behalf of ConocoPhillips Alaska, Inc., I submit to you the Alpine Class I Well Report for the • fourth quarter of 2012 and first quarter of 2013 for Class !Wells CD1 -19A, CD1 -01A (AK- AK1I010 -A) and WD -02 (AK- 11003 -B). CD1 -19A was replaced with CD1 -01A in November 2012. Pursuant to requirements in Part II.E of the subject permits, the following information is provided: • • Report Certification • • EPA Form 7520 -8, Injection Well Monitoring Report • • Graphical plots of continuous injection pressure and rate monitoring 0 • Raw monitoring data in electronic format • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results • Other reports and back -up information • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely, i l V 11;16 -�' H l Lynn DeGeorge P Senior Environmental Coordinator Enclosures: Report and Raw Data CD p • • ConocoPhilli s P PTD 200 -040 2012 Annual Disposal Well Performance Report CD1 -19A API# 50- 103- 20294 -01 -00 Alpine Oil Pool Colville River Field April 1, 2013 •id • • I fa/ ABDAIIS APR 0 2 M scow APL 1 7 ni3 2012 CRU Disposal Well Performance Report CD1 -19A - 6 - \� THE STATE Alaska Oil and Gas &4 � 'il °fALASKA Conservation Commission wet GOVERNOR SEAN PARNELL 333 West Seventh Avenue 01„ t. ' Anchorage, Alaska 99501 -3572 NEB SAN 2 2� Main: 907.279.1433 Fax: 907.276.7542 SCI►N T. Senden Staff Wells Engineer ConocoPhilli sAlaska, Inc. —.0 1 � P P.O. Box 100360 �® Anchorage, AK 99510 Re: Colville River Field, Undefined Disposal Pool, CD 1 -19A Sundry Number: 312 -423 Dear Mr. Senden: Enclosed is the approved Application for 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, le / Cathy :. Foerster Chair DATED this Aray of November, 2012. End. STATE OF ALASKA t" - � I SKA OIL AND GAS CONSERVATION COMMSION ' APPLICATION FOR SUNDRY APPROVALS \\ Iv �•Y • 1 20 AAC 25.280 1. Type of Request: Abandon Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend V Plug Ferforations 1 ; • Perforate r Pill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate Aft er casing g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200 -040 • 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20294 -01 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r NO CD1 - 19A • 9. Property Designation (Lease Number): 10. Field /Pool(s): // / ADL 25558 Colville River Field / i ool (A i / i c' Gr / 4 11. PRESENT WELL CONDITION SUMMARY A tt 7 � z Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11956 • 9595 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114' 114' SURFACE 2789 9.625 2826' 2394' PRODUCTION 11912 7 11947' 9586' L NOV 0 2012 4 CC Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): from 8750'- 11813' 6694' -9456' 3.5 L -80 10792 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - HALLIBURTON THB PRODUCTION PACKER MD= 8671 TVD= 6633 PACKER - HALLIBURTON THB PRODUCTION PACKER MD= 10716 TVD= 8396 NO SSSV 12. Attachments: Description Summary of Proposal r' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11742' 11/9/2012 Oil r Gas r WDSPL r Suspended 1 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned # . Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden © 265 -1544 p Email: R. TVIer.SendenAconocophillios.com Printed Name \\ den ��� � \ Title: Staff Wells Engineer \ Signature % ►RR1 ®�� Phone: 265 -1544 Date 11/4 I z \ Commission Use Only Sundry Number312 (15 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ri BOP Test r Mechanical Integrity Test r Location Clearance r Other: /V6141 rK Sa G l Cyr Z i G�r� Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /01107 1 07 I 1 t APPROVED BY / (� ` ` Approved by: 'AI 1 THE COMMISSION Date: jl jJ - ( L At �Hp yea application is vans tor 1z montns trom the sate of approval. F-, w 0 R F e 'sed i ,'± 2) t ip NOV 0 81012 0m- Submit F orm and Attachments in Du licate • • Procedure Justification CD1 -19A is a Class -I disposal well that was diagnosed with multiple tubing leaks in the straddle across the Alpine squeeze pert - which are leaking. It has been decided to abandon this • completion in lieu of attempting repairs. le A36,0511 J6 2'ive5 iev.�v YES pR� t,iC�I . M 0 Describe the Objectives /I PC 9 " yX ' Abandon both the Ivishak and Alpine perfs via cement placement. • Special Job Concerns (e.g. fill, tight spots, high gas, reservoir pressure for FCO's) The Alpine squeeze perfs, via the compromised straddle assembly, have been dumping solids on the Ivishak portion of the completion. After SL dropped a sidewall cutter they had a couple feet of fill in just the day before getting back to retrieve the cutter Min ID: HES XN Nipple, 2.750" at 10778' RKB Procedure Coiled Tubing 1. RU CTU 2. RIH with 2" JSN, tag fill at 10515' RKB and clean out to top of SL tool string, -10748' RKB. Make several passes up and down to evaluate interference of the SL wire. Be cognizant of potential fill from the holes in the straddle. We need to have at least 10' of open tubing below the bottom packer at 10716'. E -Line 3. RU EL (we could do this step with coil) 4. RIH with jet cutter and cut tubing tail at -10728' RKB (expect downward flow) 5. RIH and punch tubing at -8600' RKB using 4' of tubing punches. Confirm communication between tubing and annulus. Coiled Tubing 6. RU CTU, PT equipment. Notify State and EPA to witness. 7. RIH with cement retainer and set at -10725' RKB (in the tubing below the bottom packer but just above the tubing cut). Pump 25 bbl of 15.8 ppg class G cement in to Ivishak perfs. 8. POOH and RIH hole with cement retainer and set at 8675' RKB (below tubing punches but above the top packer). Pump $Qbbls of 15.8 ppg class G cement into the Alpine perfs. After the 30 bbls are pumped away unsting from retainer and open IA casing valve. Close in returns from the tubing side and place 15 bbls of cement into the annulus. Then close the IA casing valve and lay in the remaining 5 bbls of cement on top of the retainer. Remember to account for pipe displacement while pulling out of hole. _ 9. FP well while POOH. 1 SfS (36' - 10. RD MO Ab• `�` � Slickline Zo arty/ k' " 11. Notify the State AOGCC inspectors for potential witness of the tag and pressure test. /° ' by 12. RIH and gauge tubing for cement stringers. Tag top of cement and note depth. <#4 3. PT tubing and annulus to 2000 psi each. �—�! rO C 'IOD'MD E -line $60 14. RIH and punch tubing at the TOC depth identified by slickline in the previous steps. Pumping 15. Pump XX bbls of XX ppg brine followed by XX bbls of freeze protect. 16. U -tube the tubing and annulus to freeze protect both sides. • y , s WNS CD1 -19A ConocoP li lips 04 Well Attributes Max Angie & MD TD Ald$k 1, hi(;. Wellborn APIIUWI Field Name Well Status Intl (°) MD (ftKB) Act Btm (ftKB) ca+ompwxps 501032029401 ALPINE DISP 54.05 2,710.56 11,956.0 "" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date Wrza Conf - CDt - 19A 7l23 AM SSSV: NIPPLE Last WO: 44.16 4/21/1999 emahc Iu Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag' SLM 11,760.0 1/12/2011 Rev Reason: WELL REVIEW Pre WO osborl 7/23/2012 T Casing Strings _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 114.0 1140 62.58 H - 40 WELDED HANGER, 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd A. ..:„.. SURFACE 9 5/8 8.921 36.8 2,825.9 2,393.5 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 34.9 11,947.2 9,586.2 26.00 L -80 BTCM 9 1 Tubing Strings Tubing Deseription String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WI... String ... String Top Thrd TUBING 3 1/2 2.992 32.9 10,7 8,4 9.30 L - EUE 8RD Completion D Top Depth CONDUCTOR, mL (TVD) Top Intl No.- 39 -174 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 32.9 32.9 - 0.38 HANGER FMC TUBING HANGER 4.500 1,794.6 1,701.6 39.62 NIPPLE HES X NIPPLE 2.813 8,670.7 6,633.5 42.81 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 MR NIPPLE, 1,795 �* VALVE, 1,795 , 10,715.9 8,395.8 16.78 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 4I 10,778.4 8,455.6 16.40 NIPPLE HES XN NIPPLE w/ NO GO PROFILE 2.750 10789.9 8,466.7 16.35 WLEG WIRELINE RE -ENTRY GUIDE 3.125 Other In Hole !reline retrievable plugs, valves, pumps, fish, etc.) { Top Depth 1 (TVD) Top Intl J Top (ftKB) (ftKB) ( 1 Description phon Comment Run Date ID (in) 1,794.6 1,701.6 39.62 VALVE MCX INJ VLV (MCX 304) BEAN 1.1", OAL =31" 1/12/2011 1.100 SURFACE, 372,826 ; peo tbg leaks at: 10316', gig v 10348' & 10413' Shot Top (ftKB) Btm (ftKB) 1„K3) (ftKB) ions Data ( -. Type Comment 8,750.0 8,760.0 6,693.9 6,701.0 K - 1 Marker, 5/23/2000 4.0 IPERF Sqz Gun; pert date approx. PACKER,8,871 CD1 - 19A 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5, CD1 -19A 5/23/2000 4.0 IPERF Sqz Gun; pert date approx. / 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, 1/5/2003 6.0 RPERF 12.5" HSD 2506 HJ, 60 deg Phase CD7 -19A iw /mag Mk 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, 1/5/2003 12.0 RPERF 12.5" HSD 2506 HJ, 60 deg Phase IPERF, i< A .: CD1 -19A w /mag 8,]50 -0,760 M m 11,720.0 11,740.0 9,365.5 9,385.0 IVISHAK, 1/5/2003 6.0 APERF 2.5" HSD 2506 HJ, 60 deg Phase CD1 -19A w /mag IPERF, E e, 990 - 9, 000 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase CD1 -19A w /mag Fill/ 10515' 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, 6/3/2000 12.0 RPERF 121/2 HSC; 60 deg ph wire 1 CD1 -19A Ink :. 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph II CD1 -19A PACKER, 11,780.0 11,7930 9,423.8 9,436.4 IVISHAK, 6/2/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph 10,716 CD - j - '11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, 2/27/2003 6.0 IPERF 2.5 " HSD HJ Top SL xb� CD1 -19A tool string 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, 6/2/2000 6.0 IPERF 21/2 HSC; 60 deg ph I 10748' CD1 -19A J -' 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, 2/27 /2003 12.0 RPERF X 12.5" HSD HJ NIPPLE. 70.]]8 CD1 4 If • Notes: General & Safety End Date Annotation WLEG. 10.790 - - - -- 0 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 RPERF, 1 _- 11,483. 11,483 XN plug with tandem RPERF. I - gauge assemblies 11,504- 11,520 APERF, I 71,720- 11,740 RPERF, - wv 17,749- 17,150 i - RPERF, v 11 150- 11,783 PE ' RF, 11,768- 17,776 RPERF. , 11,780 - 11,793 IPERF, - 11,793. 11,794 IPERF, aw 11,800-11,803 RPEF, i 11,803- 11.8 PRODUCTION. 3511,94] TO IC01 -19A 11,956 l e WNS CD1 -19A • Conoc ) Well Attributes Max Angle & MD TD AIdS1ta (Ilt. Wellbore APIIUWI Field Name Well Status Inc/ ( °) MD (RKB) Act Btm (f1KB) 501032029401 ALPINE DISP 54.05 2,710.56 11,956.0 Comment 1125 (ppm) Date Annotation End Date KB -Grd (fl) Rig Release Date • Well cen6g- c01 -19A, 7n3rz672 5:13:55 AM SSSV: NIPPLE Last WO: 44.16 4/21/1999 Sdremaac- AC'ual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,760.0 1/12/2011 Rev Reason: WELL REVIEW Pre WO osborl 7/23/2012 Casing Strings Casing Description String 0... String ID... Top (RKB) Set Depth (1... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 _ 114.0 114.0 62.58 H - 40 WELDED HANGER, 33 I ,' Casin Descr i p tion String 0... Stri ID ... T ( RKB) Set De p th ( f... Set Depth ( TVD) ... Strin WI... String ... String Top Thrd SU R F ACE 9 5/ 8.92 36.8 2, 2,3 3 6.0 0 J -55 ETC Casing Description String 0... String ID... Top (RKB) Set Depth (f... Set Depth (TOO)... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.9 11,947.2 9,586.2 26.00 L -80 BTCM Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd TUBING 3 1/2 2.992 32.9 10,791.6 8,468.3 9.30 L -80 EUE 8RD Corn letion Details Top Depth CONDUCTOR, I (TVO) Top Inc' Nomi... 38.114 Top (RKB) IftKB) ( °) Item Description Comment ID (in) 32.9 32.9 -0.38 HANGER FMC TUBING HANGER 4.500 1,794.6 1,701.6 39.62 NIPPLE HES X NIPPLE 2.813 •CKER HALLIBURTON THB PRODUCTION PACKER 3.875 NIPPLE 1,795 1795 ` CKER HALLIBURTON THB PRODUCTION PACKER 3.875 VALVE, . Itt, 'PLE HES XN NIPPLE wl NO GO PROFILE 2.750 .EG WIRELINE RE -ENTRY GUIDE 3.125 Cement etrievable plugs, valves, pumps, fish, etc.) Cement top - tubing top - IA \ lescription Comment Run Date ID (in) SURFACE, y ♦ [\ / 6942' LVE MCX INJ VLV (MCX 304) BEAN 1 1' OAL =31' 1/12/2011 1.100 7533' f Cement Retainer Shot Bbn (TVD) Dens (RKB) Zone Date (5h... Type Comment F` 6,701.0 K - 1 Marker, 5/23/2000 4.0 IPERF Sqz Gun, pen date approx. PACKER, 0,6 CD1 - 19A -- tbg leaks at: 10316'' 6,875.5 ALPC5,CD1 -19A 5/23/2000 4.0 IPERF Sqz Gun pert date approx tbg punch holes f 10348' & 10413' 9,135.6 IVISHAK, 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase 8600' (4') CD1 -19A w /mag 9,171.5 IVISHAK, 1/5/2003 12.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase IPERF CD1 -19A w /mag 0,750-0,760 9,385.0 IVISHAK, 1/5/2003 6.0 APERF .2.5" HSD 2506 HJ, 60 deg Phase CD1-19A �. w /mag IPE 6,956 - 9 RF, , 000 9,394.7 IVISHAK, 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase CD1-19A w /mag Cement Retainer 9,4073 IVISHAK, 6/3/2000 12.0 RPERF 121/2 HSC; 60 deg ph CD1 -19A 9,419.9 IVISHAK, 6/2/2000 6.0 IPERF 12 1/2 HSC; 60 deg ph CD1 -19A I Tbg cut 9,436.4 IVISHAK, 6/2/2000 12 0 RPERF 2 1/2 HSC{ 60 deg ph CD1 -19A ` -I 10728' 9,437.4 IVISHAK, 2/27/2003 6.0 IPERF 2.5" HSD HJ CD1 -19A 9 446.2 IVISHAK, 6/2/2000 6.0 IPERF 12 1/2 HSC; 60 deg ph 15.8 ppg Class G CD1 -19A I / - Cement 9,455.9 IVISHAK, 2/27 /2003 12.0 RPERF 25" HSD HJ CD1 -19A NIPPLE. 10,78 Annotation WLEG, 10, 790 - - - -- - - -- - - -- - thematic w/ Alaska Schematic9.0 RPERF. / 11,463- 11,403 RPERF, I' v 11 504- 11,520 , €1 11720- 11,14APE RF0 RPERF, - It149- 11,750 RPERF, 11,750 -11 763 IPERF, 11,768 -11 776 RPERF, 11 700- 11,793 PERF, 11 193- 11,794 IPERF, 11,800 - 11,603 RPERF, , 11,803 - 11.813 i I I, ,. PRODUCTION, Fl 3571,947 TO (001 -19A), 11,956 2-AV 9 A 9 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 18, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool /Leak Detect Log: CD 1 -19A Run Date: 05/10/2012 & 05/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1 -19A MIT /LDL Data in LAS format, Digital Logs, Interp. Report, 3D Viewers 1 CD Rom 50 -103- 20294 -01 Leak Detect Log (field print) SCANNED FEB 2 7 Z013 1 Color Log 50 -103- 20294 -01 MIT Caliper Log (field print) 1 Color Log 50- 103- 20294 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 2- Signed: / oat cti_tco_ �NJ za)0400 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, May 13, 2012 12:07 PM ) ej`t 51 14(i To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C; ALP Env Coord Spills Waste Land & Other Subject: ConocoPhillips CD1 -19A Class I Disposal Well Attachments: CD1- 19A.pdf Jim, Guy ConocoPhillips Alaska Inc. (CPAI) reports on 5/12/12 that the Alpine Class 1 disposal well CD1 -19A indicated failed barriers during the scheduled 2 -year caliper / water flow log required by permit. The well was immediately shut in — From the preliminary field log there are tubing leaks in the straddle section. This data is based on a field interpretation and the depths and total number of holes may change. We are waiting on the caliper data to be processed. Pending the results from the caliper, repair options will be evaluated. The appropriate paperwork will be submitted prior to repair. An EPA witnessed MITIA passed on 03/29/12. The EPA has been notified via email. Currently the well has not been added to the monthly injector report as the leaks pertain to zonal isolation and not annular integrity. Attached for your reference is a wellbore diagram. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 40000 ti ZUIZ 1 WNS 0 CD119A CO ifips i Weil butes is $ N,, „0. I : - Wellbore APVUWI Field Name (M. Well Status Inel (°) M D (ftKB) Act Btm (ftKB) = aps 501032029401 ALPINE DISP 54.0 2,710.56 11,956.0 "` " "" Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well 0onfia .cot 79A 2/L/221 a,3B15PM T ov SSSV: NIPPLE Last WO: 44.16 4/21/1999 ScFrematic= Aotual _. .{ Annotation Depth MKS) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,760.0 1/12/2011 Rev Reason: FORMAT UPDATE Imosbor 2/5/2011 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt...'String ...'String Top Thrd um `mo j. CONDUCTOR 16 15.062 38.0 114.0 114.0 62.58 H - 40 WELDED HANGER. 33 " �, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 'i SURFACE 95/8 8.921 36.8 2,825.9 2,393.5 36.00 J -55 BTC • PRODUCTION 7 6.151 34.9 11,947.2 9,586.2 26.00 L -80 BTCM it, 2 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd V. �.w.. l binq Stir,',"' i „ Tubing Description S t r i n g O. Stang ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TUBING (QC) 3 1/2 2.992 32 9 10,791 6 8,468.3 9.30 L -80 EUE 8RD y �� Ohpletion Details V 7 ,. Top Depth _ CONDUCTOR, (TVD) Top Inc! Nomi.. 38-174 Top (ftKB) (MB) (") Item Description Comment ID (in) 32.9 32.9 -0.38 HANGER FMC TUBING HANGER 4.500 1,794.6 1,701.6 39.62 NIPPLE HES XNIPPLE 2.813 ` - 8,670.7 6,633.5 42.81 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 NIPPLE, VE, 11, 1,7795 95 - 10,715.9 8,395.8 16.78 PACKER HALLIBURTON THB PRODUCTION PACKER 3.875 VAL 10 778.4 8,455.6 16.40 NIPPLE HES XN NIPPLE w/ NO GO PROFILE 2.750 10 789.9 8,486.7 16.35 WLEG WIRELINE RE -ENTRY GUIDE 3.125 e t ireline retrievable piags;'iratr; piFiS'l?) __ ' 0 lit, Top Depth (TVD) Top Intl Top (ftKB) (5KB) (") Description Comment Run Date ID (in) 1,794.6 1,701.6 39.62 VALVE MCX INJ VLV (MCX 304) BEAN= 1.1 ", OAL =31" 1/12/2011 1.100 SUR FACE, , . 37.2,828 s _ - =ems," p C4 Slots Shot Top (TVD) Btet (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (84(8) Zone Date (sh••• Type Comment 8,750.0 8,760.0 6,693.9 6,701.0 K - 1 Marker, 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. PACKER. 8.671 ' " C01 - 19A Si 8,990.0 9,000.0 6,868.1 6,875.5 ALPC5, CD1 -19A 5/23/2000 4.0 IPERF Sqz Gun; perf date approx. 11,463.0 11,483.0 9,116.2 9,135.6 IVISHAK, 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase ____ CD1.19A w /mag 11,504.0 11,520.0 9,156.0 9,171.5 IVISHAK, 1/5/2003 12.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase 8,750. IP8.7ER60 F, - - CD1 -19A w/mag " 11,720.0 11,740.0 9,365.5 9,385.0 IVISHAK, 1/5/2003 6.0 APERF 2.5" HSD 2506 HJ, 60 deg Phase _ CD1 -19A w /mag IPERF, 6.990 - 9,000 - - 11,749.0 11,750.0 9,393.7 9,394.7 IVISHAK, 1/5/2003 6.0 RPERF 2.5" HSD 2506 HJ, 60 deg Phase CD1 -19A w /mag 11,750.0 11,763.0 9,394.7 9,407.3 IVISHAK, 6/3/2000 12.0 RPERF 2 1/2 HSC; 60 deg ph CD1 -19A 11,768.0 11,776.0 9,412.2 9,419.9 IVISHAK, 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph CD1 -19A PACKER, 11,780.0 11,793.0 9,423.8 9,436.4 IVISHAK, 6/2/2000 12.0 RPERF 21/2 HSC; 60 deg ph 10,716 CD1 -19A 11,793.0 11,794.0 9,436.4 9,437.4 IVISHAK, 2/27/2003 6.0 IPERF 2.5" HSD HJ CD1 -19A I. 11,800.0 11,803.0 9,443.2 9,446.2 IVISHAK, 6/2/2000 6.0 IPERF 2 1/2 HSC; 60 deg ph CD1 -19A 11,803.0 11,813.0 9,446.2 9,455.9 IVISHAK, 2/27/2003 12.0 RPERF 2.5" HSD HJ NIPPLE, 10,778 CD1 - 19A IL 0;. " End Date Annotation WLEG. 10.790 tr ,. 1/6/2011 NOTE: View Schematic w/ Alaska Schematic9.0 RPERF, 11,463. 11,483 ;, RPERF, 11,504. 11,520 - APERF, 11,720.11,740 - - - RPERF, 11,748- 11,750 - RPERF, 11,750-11,763 IPERF, 11,768-11,776 RPERF, 11,780.11,793 - IPERF. 11.793-11,794 - - IPERF 11,800.11,803 RPERF. 11403- 11,813 1 PRODUCTION. 35- 11,947 TD (CD1 -19A), 11,966 • (- 76t, 04 00 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Saturday, March 31, 2012 3:33 PM e'f/l 4 I li l 1 v To: Regg, James B (DOA); Schwartz, Guy L (DOA) l Cc: 'talibs @ecentral.com'; 'cutler.thor @epamail.epa.gov'; Neville, David J Subject: CD1 -19A (PTD 200 -040) MIT form 03 -29 -12 Attachments: MIT CRU CD1 -19A 03- 29- 12.xls All, Attached is the MIT form for the EPA Class 1 injection well CD1 -19A (PTD 200- 040)'s passing MIT that was performed on 03/29/12. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 SLANNED APR 1 0 allZ 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recicaalaska.gov: doa .aoocc.prudhoe.bav(alaska.gov; phoebe.brooks( alaska.gov; tom.maunder(ctalaska.gov OPERATOR: ConocoPhillips Alaska Inc. Rgg 4 (Z-(1 t.,- FIELD / UNIT/ PAD: Alpine / CRU / CD1 DATE: 03/29/12 OPERATOR REP: David Neville AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD1 -19A Type Inj. I TVD - 6,634' Tubing 2500 ' 2500 2500 '2500 Interval p P.T.D. 2000400 Type test P Test psi "2100 Casing 393 2,135 2,106 2,100 P/F P Notes: EPA Class 1 injection well annual MITIA OA 467_ 497 494 496 Witnessed b Talib Syed (EPA Rep) Test to 2100 psi Der permit No. AK- 11010 -A Well I Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) • Form 10 -426 (Revised 06/2010) MIT CRU CD1 - 19A 03 - 29 - 12 . Lynn DeGeorg ° Sr. Environmental Coordinator ' b ~' *l ConocoPhillips Alaska 700 G Street ConocoPhillips RECEIVED Ph 9 ge AK 99501 4 OCT 2 7 2011 11 Oct 26, 2011 Mssk* Ail & Gas Cons, Conk *tics Mr. Peter Contreras Certified Mail Supervisor, Ground Water Protection Unit 7010 1060 0000 5093 7993 U.S. Environmental Protection Agency (OCE -082) Return Receipt Requested 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 ': Z-9_:� lr RE: Class I Well Permit #AK- 11003 -A (CD1 -19A), ermit to Drill No. 200 Class I Well Permit #AK- 11003 -B (WD -02), Permit to Drill No. 99 -258 Biennial Report — 2 Quarter and 3 Quarter, 2011 Dear Mr. Contreras, On behalf of ConocoPhillips Alaska, Inc., I submit to you the Alpine Class I Well Report for the second and third quarters of 2011 for Class 1 Wells CD1 -19A (AK- 11003 -A) and WD -02 (AK- 11003 -B). Pursuant to requirements in Part II.E of the subject permits, the following information is provided: • Report Certification 5 • EPA Form 7520 -8, Injection Well Monitoring Report • Graphical plots of continuous injection pressure and rate monitoring • Raw monitoring data in electronic format • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results • Other reports and back -up information • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely, � y Lynn DeGeorge Senior Environmental Coordinator Enclosures: Report and Raw Data CD • • 0 United States Environmental Protection Agency EPA Washington, DC 20460 1 1111 \/ Injection Well Monitoring Report 2011 Month Month Month 0 Injection Pressure (P810) April May June 0 1. Minimum 1,280 1,460 1 O 2. Average 2,413 2,249 2,108 O 3. Maximum 3,457 3,141 3,297 0 injection Rate (Gal/Min) 1. Minimum 0.0 0.0 0.0 2. Average 37.0 10.0 15.6 3. Maximum 160.8 155.3 159.0 0 Annular Pressure (PSIG) . 1 0 1. Minimum 194 197 1 2. Average 484 543 508 0 3. Maximum 1,171 1,142 947 Injection Volume (Gal) 4 1. Monthly Total 1,598,673 446,997 673,287 4 2. Yeady Cumulative 4,265,544 4,712,542 5,385,829 Temperature (F ° ) 1. Minwnum not required not required not required 2. Average not required not required not required 4 3. Max 0 pH 4 1. Minimum not required not required not required lb 2. Average not required not required not required 3. Maximum not required not required not required Other Name and Address of Permlttee Permit Number ConocoPhillips Alaska, inc., P.O. Box 100360, Anchorage, Alaska, 99510-0360 AK-11010A Name and Official Title (Please type or print) Signature l Date Signed 0 Lynn DeGeorge, Senior Environmental Coordinator " { w y' 0 it I/ EPA Form 75208 (rev. 9 note - form recreated by CPAI to allow data entry via PC 0 1 Page 3 of 54 1 II • • 0 V 4 United States Environmental Protection Agency &EPA Washington, DC 20480 4 Injection Well Monitoring Report 4 2011 Month Month Month Injection Pressure (PSIG) July August September 1. Minimum 858 876 0 if 2. Average 2,384 2,454 1,969 3. Maximum 3,411 3,366 3,309 - Injection Rate (GaUMin) 4 1. Minimum 0.0 0.0 0.0 4 2. Average 16.0 8.0 4.0 gi 3. Maximum 164.8 163.1 144.4 . i Annular Pressure (PSIG) 1. Minimum 240 245 185 4 2. Average 590 542 550 Va 3. Maximum 1,182 743 656 li Injection Volume (Gal) i 1. Monthly Total 715,940 357,851 171,455 2. Yearly Cumulative 6,101,770 6,459,621 6,631,077 Temperature (F ° ) 1. Minimum not required not required not required M 2. Average not required not required not required r 3. Maximum PH ' 1. Minimum not required not required not required 2. Average not required not required not required r 3. Maximum not required not required not required 1 Other 1 1 1 . i 1 Name and Address of Permittee Permit Number , ConocoPhillips Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510 - 0360 AK 1 Name and Official Title (Please type or print) Siature Date Signed °T 1 .-- .D.4 v14, ID - /Z - 1I III Lynn DeGeorge, Senior Environmental Coordinator / EPA Form 7520 -8 (rev. 9-91) note - form recreated by CPAI to allow data entry via PC III III 1 0 4 f Page4of54 4 4 ID • E oF - SEANPARNELL, GOVERNOR AsKA 555 Cordova Street Anchorage, Alaska 99501 Phone: (907) 269 -6258 Fax: (907) 269 -3487 DEPARTMENT OF ENVIRONMENTAL CONSERVATION www.dec.state.ak.us DIVISION OF WATER WASTEWATER DISCHARGE AUTHORIZATION PROGRAM June 23, 2011 DEC File No.: 375.48.030 Mr. Ray Hinchcliff MOWED JUL 1 1 2011 0 0 ConocoPhillips Alaska Inc. P.O. Box 100360, ATO 1720 Anchorage, AK 99510 ()k,- `s is Re: Authorization 2010DB0001 -0014; Colville River Unit UIC, Well CD- -A h`'Z_• Dear Mr. Hinchcliff: The Alaska Department of Environmental Conservation has completed its review of the Notice of Intent for the Colville River Unit UIC, Well CD -119 -A and is issuing authorization 2010DB0001 -0014. The department has both an informal review process and a formal administrative appeal process for final permit decisions. An informal review request must be delivered within 15 days after receiving the department's decision to the Director of the Division of Water at the following address: Director, Division of Water Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Interested persons can review 18 AAC 15.185 for the procedures and substantive requirements regarding a request for an informal department review. See http: / /www.dec. state. ak.us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. An adjudicatory hearing request must be delivered to the Commissioner of the department within 30 days of the permit decision or a decision issued under the informal review process, whichever is later. An adjudicatory hearing will be conducted by an administrative law judge in the Office of Administrative Hearings within the Department of Administration. A written request for an adjudicatory hearing shall be delivered to the Commissioner at the following address: Commissioner Alaska Department of Environmental Conservation 410 Willoughby Avenue, Suite 303 Juneau, AK 99811 -1800 • Interested persons can review 18 AAC 15.200 for the procedures and substantive requirements regarding a request for an adjudicatory hearing. See http: / /www.dec. state .ak.us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. This authorization became effective on May 18, 2011 and expires at midnight on April 21, 2015. You must reapply for an authorization on or before January 21, 2015, 90 days prior to the expiration date. If you have any questions concerning this authorization, please contact Marc H. Bentley at 907.269.6287, marc.bentley @alaska.gov or Adele Fetter at 907.269.7235, adele.fetter@alaska.gov. Sincerely, Michelle Bonnet Section Manager Enclosure: Permit No. 2010DB0001 Authorization 2010DB0001 -0014 cc: Marc Bentley, DEC, Division of Water, Anchorage Tom Maunder, AOGCC, Anchorage Thor Cutler, EPA, Seattle • • STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Division of Water AUTHORIZATION NUMBER 2010DB0001 -0014 UNDER CLASS I INJECTION WELL DEC File Number: 300.48.030 General Permit Number 2010DB0001 See this General Permit for additional permit requirements The following responsible party is authorized to discharge in accordance with the terms of general permit 2010DB0001, the information provided in the Notice of Intent, and any site specific requirements listed in this authorization: RESPONSIBLE PARTY: First Name: Ray Last Name: Hinchcliff Company: ConocoPhillips, Alaska Inc. Phone Number: 907.263.4464 Mailing Address: P.O. Box 100360, ATO 1720 City: Anchorage State: Alaska Zip: 99510 Email: ray. s.hinchcliff @conocophillips.com ON SITE CONTACTS: First/Last Name: Shellie Colegrove Phone Number: 907.670.4200 Fax Number: 907.670.4205 FACILITY: NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: Alpine Oil Field Phone Number: 907.670.4200 Mailing Address: P.O. Box 100360, ALP Fax Number: 907.670.4205 City: Anchorage State: Alaska Zip: 99510 PHYSICAL ADDRESS: Physical Location: North Slope of Alaska City: Nuiqsut State: Alaska Zip: 99789 GENERAL DESCRIPTION OF THE PROJECT: The Alpine CDI -19A injection well waste stream may include mostly produced water with relatively small volumes of non - hazardous waste; treated sanitary wastewater; gray water, stormwater, glycol, etc. pH- neutral: TDS — 10,000 — 35,000 ppm; TSS — 10 — 200 ppm; TPH < 10 ppm. AUTHORIZED DATES OF DISCHARGE Beginning Date: May 18, 2011 Ending Date: April 21, 2015 EPA CLASS 1 INJECTION WELL PERMIT NUMBER: AK- 1I010 -A Beginning Date From: December 1, 2007 Ending Date To: November 30, 2017 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 24, 2011 10:27 AM To: 'DeGeorge, Lynn A' Subject: RE: p 49 - 55, UIC Clas 1 Well Report 5 -17 -11 Thanks much Lynn. ao O --ok4 V From: DeGeorge, Lynn A [mailto: Lynn .A.DeGeorge @conocophillips.com] °L,\ � �� . IN4\ Sent: Tuesday, May 24, 2011 10:18 AM C To: Maunder, Thomas E (DOA) L kV€ Subject: p 49 - 55, UIC Clas 1 Well Report 5 -17 -11 Hi Tom, A copy of the illegible pages is attached for your records. Thanks for letting me know about the bad copies. Lynn 263 -4671 l ,`' 4 Z i From: DeGeorge, Lynn A Sent: Tuesday, May 24, 2011 9:44 AM To: DeGeorge, Lynn A Subject: 5/24/2011 • in DeGeorge Senior Environmental Coordinator `/ 700 G Street, ATO -1756 ConocoPhillips P.O. o, Alaska Anchorage, Alaska 99510 -0360 j \ Phone: 907 - 263-4671 Alaska, Inc. ''"°" $ `k/ Fax:907- 265 -6715 MAY '1 9 2U`I1, May 17, 2011 Ath Ka O & GRA Coo Gam mission Mr. Peter Contreras Anc erage Certified Mail Supervisor, Ground Water Protection Unit 7008 0150 0002 1586 9879 U.S. Environmental Protection Agency (OCE -082) Return Receipt Requested 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 RE: Class I Well Permit #AK- 11003 -A (CD1 -19A), Permit to Drill No. 200 -040 Class I Well Permit #AK- 11003 -B (WD -02), Permit to Drill No.8 Biennial Report — 4 Quarter 2010 and 1 Quarter, 2011 `C: fr1 \\ Dear Mr. Contreras, On behalf of ConocoPhillips Alaska, Inc., I submit to you the Alpine Class I Well Report for the fourth quarter of 2010 and first quarter of 2011 for Class I Wells CD1 -19A (AK- 11003 -A) and WD -02 (AK- 11003- B). Pursuant to requirements in Part II.E of the subject permits, the following information is provided: • Report Certification • EPA Form 7520 -8, Injection Well Monitoring Report • Graphical plots of continuous injection pressure and rate monitoring • Raw monitoring data in electronic format • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results • Other reports and back -up information • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely, Lynn DeGeorge Senior Environmental Coordinator Enclosures: Report and Raw Data CD Page 1 of 55 RE: Class I Well Permit #AK -1 I0410 (CD1 -19A) • May 17, 2011 Class I Well Permit #AK- 11003 -B (WD -02) Biennial Report — 4 Quarter 2010 and 1 Quarter 2011 cc: (with Raw Data CD) Director, OCE EPA (OCE -164) Thor Cutler EPA Talib Syed TSA, Inc. (EPA Consultant) cc: (without Raw Data CD) Peter McGee ADEC Tom Maunder AOGCC Tom Miller Anadarko Steve Freemeyer Anadarko 2 RE: Class I Well PermitC- 11003 -A (CD1 -19A) • May 17, 2011 Class I Well Permit #AK- 11003 -B (WD-02) Biennial Report — 4 Quarter 2010 and 1 Quarter 2011 bcc: (without Raw Data CD) Colegrove /Smith ALP -14 Mahan /McCullough NSK -61 Lynn DeGeorge bcc: (with Raw Data CD) Alpine General File Central Files 3 • Report Certification Page 4 of 55 • • Statement of Certification This report is hereby certified in accordance with the requirements of Part I.E.15 of the Environmental Protection Agency Permit AK- 11003 -A and AK- 11003 -B. I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. S /&// Ray Hinchcliff � Date Manager Western North Slope Operations • EPA Form 7520 -8 CD1 -19A Note: Please be advised that minimum injection pressure represents the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. I • United States Environmental Protection Agency vEPA Washington, DC 20460 Injection Well Monitoring Report 2010 Month Month Month Injection Pressure (PSIG) October November December 1. Minimum 185 1,235 23 2. Average 1,999 1,984 1,871 3. Maximum 2,594 3,106 3,808 Injection Rate (Gal/Min) 1. Minimum 0.0 0.0 0.0 2. Average 8.0 16.8 6.8 3. Maximum 146.1 144.3 131.8 Annular Pressure (PSIG) 1. Minimum -4 -5 275 2. Average 135 305 608 3. Maximum 744 1,087 805 Injection Volume (Gal) 1. Monthly Total 356,684 726,161 301,254 2. Yearly Cumulative 8,817,645 9,543,807 9,845,061 Temperature (F ° ) 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum pH 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum not required not required not required Other Name and Address of Permittee Permit Number ConocoPhillips Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510 -0360 AK- 11003 -A Name and Official Title (Reese type or print) Signature Date Signed Lynn DeGeorge, Senior Environmental Coordinator 01 bt (.� --�yt 'z- L— ! I EPA Form 7520-8 (rev. 9-91) note - form recreated by CPAI to allow data entry via PC . • trotted *tool EmAronmeetai Prateetl°n Amway VEIPEPA Woolameauk DC OrMe Injection Well Monitoring Report 2011 IAonth Motes Month hjecGon Pressure (P810) January February March 1. Mkimun 1 388 1 2. Average 1,920 2,222 2,112 3. Mmir.m 3,246 3,340 3,849 kieclion Rate (O ) 1. Iinrnun 0.0 0.0 0.0 2. Avenge 11.7 24.9 25.5 3. Magnum 141.4 150.1 150.9 Mauler Pram (MO) 1. Minimum 261 217 2 2. Average 562 495 514 3. iom0r.ra 1,036 1,093 4.038 Injection volume pet) 1. Mon04*Tder 523,757 1,005,595 1,137,518 2. YeaAy o sndara 523,757 1,529,352 2,686,870 Temperature (F ° ) i. Minimum not required not required not required 2. Avenge not required not required not required 3. Marinam pH t Minimum not required not required not required 2. Av.ape not required not required not required 3. Mabansn not required not required not required Other Nona aid Adams et Perm ss Pen* Number Con000P1911pe Alaska, Mc., P.O. Box 100360. Anchorage Alaska, 99510.0380 AK- 11003 -A Name and Oeldd Tkre (Mew nee apint) Cate Signed L .. c • . - , .Senior Environmental Coordinator - v .T — / ( EPA Faun 76204 (n v. 941) ups - ban recreated by CPAI to aloe dw *lay vie PC • Injection Pressure and Rate Monitoring CD1 -19A Clarification of Data Date Time Comment 3/30/2011 15:00 Annual EPA witnessed MITIA. For Details, please see "Mechanical Integrity Test Results, EPA 2011 Annual MIT Report" in the "Other Reports" section of this report. CD1 -19A 10/1/2010 Through 10/10/2010 11:59:59 PM 001 "•••Inj Pres Limit ••IA Press Limit Inj Press IA Press Flow Rate 4500 ________ 10.0 4000 - — — - -- -- — - _____ t -- 9.0 3500 — _— —. - -- - _-- ----- ,__ —.- _ -- 8.0 • — 7.0 3000 - - — -- - ___. - -- 0 -- 6.0 m a 2500 - - - - --- - -- -- - -- - - -_ -_ • — -... -- m PI ai m 2000 3 If.: o — 4.0 L'- 1500 — ' — — _ -- — 3.0 1000 -- - — I : ' -_ I _ _ — — 2.0 500 -- _ - 0 - ' 0.0 10/01/10 10/02/10 10/03/10 10/04/10 10/05/10 10/06/10 10/07/10 10/08/10 10/09/10 10/10/10 10/11/10 Page 12 of 55 CD1 -19A 10/11/2010 Through 10/20/2010 11:59:59 PM '"""'Inj Pres Limit ••••IA Press Limit Inj Press —IA Press —Flow Rate 4500 — _._...____.__r —_ --.-,- 10.0 4000 – 9.0 • 3500 – 8.0 3000 - – 7.0 C9 – 6.0 2 ET) 2500 d m Of ai 5 – 5.0 m Cl) 2000 - — cc a. 4.0 0 -- "- 1500 – 3.0 • 1000 – 2.0 500 – 1.0 V , 0.0 11 -Oct 12 -Oct 13 -Oct 14 -Oct 15 -Oct 16 -Oct 17 -Oct 18 -Oct 19 -Oct 20 -Oct 21 -Oct CD1 -19A 10/21/2010 Through 10/31/2010 11:59:59 PM Pres Limit ••■•••*IA Press Limit Inj Press —IA Press —Flow Rate 4500 �a� _______ ______� 10.0 4000 - - 9.0 3500 ' 8.0 • - 7.0 3000 - - 0 - 6.0 2500 0- m Elf -5.0 to ce 2000 - a r.... o 4.0 1500 - - 3.0 1000 - - - 2.0 500 r L — 1.0 0 — --- -r^' 0.0 21 -Oct 22 -Oct 23 -Oct 24 -Oct 25 -Oct 26 -Oct 27 -Oct 28 -Oct 29 -Oct 30 -Oct 31 -Oct 1 -Nov CD1 -19A 11/1/2010 Through 11/10/2010 11:59:59 PM 'mm' "'Inj Pres Limit ' ■•••'IA Press Limit Inj Press —IA Press Flow Rate 4500 - -- 10.0 4000 - -- — -- — — — — — — — 9.0 3500 — — - - -- — 8.0 -- 7.0 3000 — — —. — — 0 — 6.0 2 a 2500 — — — — — m —5.0 iti 2000 a - 4.0 o u- — 3.0 1000 - — — — — — — 2.0 500 — 1.0 L 0 11 0.0 11/01/10 11/02/10 11/03/10 11/04/10 11/05/10 11/06/10 11/07/10 11/08/10 11/09/10 11/10/10 11/11/10 CD1 -19A 11/11/2010 Through 11/20/2010 11:59:59 PM ---Inj Pres Limit •IA Press Limit Inj Press —IA Press —Flow Rate, J 4500 - - - 10.0 4000 – 9 . 0 3500 – 8.0 III – 7.0 3000 - ` 0 i – 6.0 2 m 2500 - m a m 2_i N j� – 5.0 it? 2000 414 o a – 4.0 "_- 1500 - – 3.0 • 1000 � - " ..I - 2.0 500 - �r 1.0 • 0___I kiN •- , - 0.0 11 -Nov 12 -Nov 13 -Nov 14 -Nov 15 -Nov 16 -Nov 17 -Nov 18 -Nov 19 -Nov 20 -Nov 21 -Nov CD1 -19A 11/21/2010 Through 11/30/2010 11:59:59 PM ••• -Inj Pres Limit •IA Press Limit Inj Press —IA Press —Flow Rate 4500 - - - 10.0 4000 – 9.0 ill – 8.0 3500 – 7.0 3000 L 1 1 A - 6.0 41 11-Yri a a 2500 m m g3 2000 m – 5.0 m I L ,� 0 _ 3 0 a` I – 4.0 ''- 1500 - i - t ' L l 1000 *1 � ' .1� 500 - L r ` c - 1.0 0 - r i C--"1/4-+ i — - 0.0 21 -Nov 22 -Nov 23 -Nov 24 -Nov 25 -Nov 26 -Nov 27 -Nov 28 -Nov 29 -Nov 30 -Nov 1 -Dec • CD1 -19A 12/1/2010 Through 12/10/2010 11:59:59 PM 1••••••Inj Pres Limit saimmil-'1A Press Limit Inj Press IA Press Flow Rate 4500 ® _ --°-- 10.0 4000 - — - _ - 9.0 3500 - - -- - - - - - -- — - 8.0 -- 7.0 3000 - — — -'- 6.0 ET) 2500 - - -- o_ - 5.0 m 10 2000 - ....�.�. 3 0. — 4.0 u- 1500 - -- - - -- — - - 3.0 1000 - -- — — - 2.0 500 --- - — - _ —__ . _ _ — • 1.0 0 0.0 12/01/10 12/02/10 12/03/10 12/04/10 12/05/10 12/06/10 12/07/10 12/08/10 12/09/10 12/10/10 12/11/10 CD1 -19A 12/11/2010 Through 12/20/2010 11:59:59 PM ""sum`Inj Pres Limit ■■IA Press Limit lnj Press —IA Press —Flow Rate 4500 10.0 4000 - - 9.0 3500 t - 8.0 - 7.0 3000 a a. 2500 J m m Elf ai g ' - 5.0 m a 2000 - o cc -- '._.._'_ ` - 4.0 I 1500 to - 3.0 114-• , - 2.0 IIII 500 ''V V -- 1.0 + a li 11 - Dec 12 -Dec 13 -Dec 14 -Dec 15 -Dec 16 -Dec 17 -Dec 18 -Dec 19 -Dec 20 -Dec 21 -Dec CD1 -19A 12/21/2010 Through 12/31/2010 11:59:59 PM -----Inj Pres Limit •IA Press Limit Inj Press —IA Press Flow Rate l 4500 10.0 4000 - — 9.0 — 8.0 3500 - II -- 7.0 3000 — 6.0 m C9 ! a_ n_ 2500 i 1 m lik 11.---------------- a i w cx � 2000�1 � a o a — 4.0 u- 1500 ��-L�r� j — 3 1000 L ' 1 1 I — 2.0 M • 500 I 1,) — -1.0 0 h -1 - 0.0 21 -Dec 22 -Dec 23 -Dec 24 -Dec 25 -Dec 26 -Dec 27 -Dec 28 -Dec 29 -Dec 30 -Dec 31 -Dec 1 -Jan CD1 -19A 1/1/2011 Through 1/10/2011 11:59:59 PM -- -Inj Pres Limit -CIA Press Limit Inj Press IA Press Flow Rate 4500 �_.___..� r 10.0 4000 — 9.0 — 8.0 3500 -- 7.0 3000 rr ill 0 - 6.0 g a 2500 J m ai 0 li 0 I — 5.0 L 2000 --• o a — 4.0 1 ` - 1500 - III l - 3.0 i 1000 ,,- 4 - 2.0 500 l lr V \f — 1.0 0 �t IP 0.0 T 01/01/11 01/02/11 01/03/11 01/04/11 01/05/11 01/06/11 01/07/11 01/08/11 01/09/11 01/10/11 • • CD1 -19A 1/11/2011 Through 1/20/2011 11:59:59 PM ---Inj Pres Limit --•IA Press Limit Inj Press IA Press Flow Rate l 4500 10.0 4000 - — — - 9.0 3500 -- -- - - - — 8.0 3000 — 7.0 • a 2500 - — �� m N g 2000 f - 5.0 m g a ° } - 4.0 L- 1 1500 -- - - - --- 1 - 3.0 1000 - - - -- - -- - 1 i - - ilk ;I - 2.0 • 500 _ - i ';11 lir — 1.0 0 -L- j 0.0 11 -Jan 12 -Jan 13 -Jan 14 -Jan 15 -Jan 16 -Jan 17 -Jan 18 -Jan 19 -Jan 20 -Jan 21-Jan CD1 -19A 1/21/2011 Through 1/31/2011 11:59:59 PM --■- -Inj Pres Limit —IA Press Limit Inj Press IA Press Flow Rate 4500 -- — _ - ---- - --- — —_� — _ 10.0 4000 -- -- — — — 9.0 • — 8.0 3500 — — — 7.0 3000 - — — — 6.0 0 d a 2500 m ,4„...... m 5.0 as u) it; 2000 3 o 1500 �-� -r -- - -_. _ - - - -- - - - -- -- - v T — 3.0 • �Y` 1000 _- -1 -- --- -- - -, - 2.0 500 6„ . ` -- - > 1.0 V r ,---- I 0.0 0 - T r I T I 1 T � I � 21 -Jan 22 -Jan 23 -Jan 24 -Jan 25 -Jan 26 -Jan 27 -Jan 28 -Jan 29 -Jan 30-Jan 31 -Jan 1 -Feb CD1 -19A 2/1/2011 Through 2/10/2011 11:59:59 PM •---Inj Pres Limit —IA Press Limit Inj Press IA Press Flow Rate 4500 --- 10.0 4000 -- – -- - 9.0 3500 – — — — -- .. – – – 8.0 • – 7.0 3000 t i la 2500 - 1 I m I - - l R �. ^ l�l 6.0 i i El 1 I I z fLi — 5.0 2000 j 3 I o - 4.0 x- 1500 — r0 �. _ r(� – 3.0 1000 - mill -. ' _. _ I 2.0 500 tit r h uh_I I r • i 1.0 !I 0.0 02/01/11 02/02/11 02/03/11 02/04/11 02/05/11 02/06/11 02/07/11 02/08/11 02/09/11 02/10/11 02/11/11 CD1 -19A 2/11/2011 Through 2/20/2011 11:59:59 PM .—Inj Pres Limit —IA Press Limit _ Inj Press IA Press -- Row Rate 4500 _�__ a _ ___ _ _ ®� 10.0 4000 - 9.0 • - 8.0 3500 -- - - - — - - -- - - 3000 - 6.0 g m a 2500 -- -- - - ---- - - - - -- � - 5.0 m E 2000 r I o a` — 4.0 LL 1500 - - - - -- - - - 3.0 f • 1000 -- -- �'- - - j - - - 2.0 500 1 111' - 1.0 0 1li - 0.0 11 -Feb 12 -Feb 13 -Feb 14 -Feb 15 -Feb 16 -Feb 17 -Feb 18 -Feb 19 -Feb 20 -Feb 21 -Feb CD1 -19A 2/21/2011 Through 2/28/2011 11:59:59 PM --Inj Pres Limit ---IA Press Limit Inj Press IA Press Flow Rate 4500 — __. _ - - - -- 10.0 4000 - _. __ -. -- ____ —__. ._ _ — _ —= 9.0 3500 -- - -- - 8.0 - 7.0 • 3000 - - - - -- -_ o - 6.0 g (7) - 2500 -- -- — ► - — n- a. m Si ai - 5.0 co rx 2000 _ r -- j 1 , � - 4.0 11 1500 - - -- - - _ L — — -- — — -- — - 3.0 1000 ----F — - 1--r- — -- - -- _— — — 500 - -- l Y.---- -1.0 • V 0 1 0.0 21 -Feb 22 -Feb 23 -Feb 24 -Feb 25 -Feb 26 -Feb 27 -Feb 28 -Feb 1 -Mar CD1 -19A 3/1/2011 Through 3/10/2011 11:59:59 PM ---Inj Pres Limit - -IA Press Limit Inj Press IA Press Flow Rate 1 4500 10.0 4000 - - -- — — -- - -- — - 9.0 • - 3500 -- — �_ _- -- 8.0 3000 -- - -- - 7.0 -- — I 6.0 a a 2500 - - j m E ll M - 5.0 m IfiVil CO 1 2000 r � rY - 4.0 1 1500 r- - - - - -- -- - -'i{i _- - - - 3.0 • i it 1000 _ , - - .. — — � _ = : 47 _. - - 1 r �"" - 2.0 500 ,/�^ - -- _ _ 0 , r- r - - r 0.0 03/01/11 03/02/11 03/03/11 03/04/11 03/05/11 03/06/11 03/07/11 03/08/11 03/09/11 03/10/11 03/11/11 CD1 -19A 3/11/2011 Through 3/20/2011 11 :59:59 PM --Inj Pres Limit —IA Press Limit In] Press IA Press Flow Rate 4500 - -- -- -- - - _._.._�- .,._� - 10.0 4000 - 9.0 3500 -- -- — -- — - 8.0 7.0 3000 - - — — C7 - 6.0 g a 2500 _ — — _ �� m P - 5.0 m m 2000 a ° - 4.0 1500 -- — — - -- - -- '� 3.0 1000 1.1 - 2.0 500 _ . - ' • 11 -Mar 12 -Mar 13 -Mar 14 -Mar 15 -Mar 16 -Mar 17 -Mar 18 -Mar 19 -Mar 20 -Mar 21 -Mar CD1 -19A 3/21/2011 Through 3/31/2011 11:59:59 PM - lnj Pres Limit —IA Press Limit Inj Press IA Press Flow Rate 4500 --- - �.. _ .. - 10.0 4000 — - - — - 9.0 • - 8.0 3500 -- - - - - -- - - - -- - -- - - - - - -- - - 7.0 3000 -- -- 1 - Ar - - - - - - -- — I 5.0 ce w ii it; 2000 r ' ' 3 r 0 a. r - 4.0 '� 1500 - — — — — -- - - 3.0 . 1000 -- wa , iii.1 _ 2.0 rn - 1.0 500 III ,'tl� o i 111 I ii iI 0.0 21 -Mar 22 -Mar 23 -Mar 24 -Mar 25 -Mar 26 -Mar 27 -Mar 28 -Mar 29 -Mar 30 -Mar 31 -Mar 1 -Apr i • Raw Data (see accompanying Data CD) Page 49 of 55 • • Injected Fluid Characteristics • • Note: Waste streams sampled during the reporting period are shown. The remaining waste streams will be sampled at a later date, in accordance with the frequency outlined in the Waste Analysis Plan. • • • Injected Fluid Characteristics ALPINE ANNUAL WDO2 & CD1 -19A CLASS I SAMPLING — 2010 Non - Exempt Typical Location Sampled Date Sampled & Result Waste Streams Non-Exempt Sources Sewage / sludge Camp wastewater treatment plant(s) and site enviro- Wastewater Plant Treatment Sampled 6/10/2010 PASS vacs Plant wastewater Sump fluids/ Snowmelt and external dirt from vehicles and MI Sump for Solids Sump Solids- sampled 5/16/2010 — Sump solids equipment, collected in floor drains PASS Floor washings J1 shop sump Liquids Sump Liquids - PASS Incidental equipment leaks & spills Glycol / heat Chemical storage tanks Fleet Shop AF Sampled 6/13/2010 exchange media Vehicles & equipment (antifreeze) Fleet Shop Glycol Sampled 6/22/2010 - PASS Photo processor Spent developer solution from x -ray equipment Kakivik X Ray Shop processing Sampled 6/10/2010 PASS fluid (corrosion tests), after passing through silver fluid recovery unit Non - exempt spill Fluids recovered from cleanup of non - exempt spills Class 1 soil bin ACS Sampled 5/16/2010 Liquid and solid clean -up Contaminated gravel or snow PASS Hydrotest fluid Pressure test new or non - exempt process lines, Welding shop drum of Sampled 5/16/2010 - PASS (water or glycol vessels Glycol only) Non - exempt methanol or diesel must be recovered for re-use, not disposal Boller blow Rig or production facility boilers Doyon 19 Rig Boiler T/14/2010 - PASS down Ott spec product Products spilled, out-dated or no longer acceptable Fire Water Mist Sampled 6-22 -2010 - PASS for original purpose Non- exempt Drilling mud and additives that have not been MI Drilling Mud oil based Sampled 12/10/2010 -PASS drilling, well circulated downhole unused work materials Gel, barite, calcium carbonate, polymers, lost circulation material (LCM) Cement/cement rinsates Fresh or seawater rinsate with product residual Turbine wash Routine cleaning of turbine fins Cl Turbine Wash Water Sampled 6-22 -1010 — PASS water Contained snow Outdoor containment around fuel and chemical CD1 Pad Containment Water Sampled 6/10/2010 - PASS / ponded water storage tanks Depressions on or between pads & roads Non - exempt Internal or external washdown of skids, modules From vehicle wash water Sampled 6/13/2010 PASS rinsate/ wash Equipment cleaning (using non - hazardous detergents placed In a clean sump water or degreasers) 1. Note that similar wastes may be RCRA exempt, depending on waste - generating process. 2. Red denotes common wastestreams that will be sampled annually. Certain wastestreams may not be generated or injected and therefore, may not be sampled for a particular year. Note: Waste streams sampled during the reporting period are shown. The remaining waste streams will be sampled at a later date, in accordance with the frequency outlined in the Waste Analysis Plan. s • . Summary of Significant Well Maintenance CD1 -19A and WD -02 Not applicable for this reporting period. • Mechanical Integrity Testing Results CD1 -19A and WD -02 Please see, "Mechanical Integrity Test Results, EPA 2011 Annual MIT Report" in the "Other Reports" section of this report Other Reports Mechanical Integrity Test Results Well WD -02 & CD1 -19A Colville River Field Internal Mechanical Integrity Test Requirements According to 40 CFR § 146.8(a), an injection well has mechanical integrity if there is no significant leak in the casing, tubing, or packer, and there is no significant fluid movement into an underground source of drinking water through vertical channels adjacent to the injection wellbore. The current permit for the Alpine Class I wells WD -02 and CD1 -19A describes the requirements for performing and evaluating a standard annulus pressure test (SAPT). The results for these testing requirements are summarized below. Overview An SAPT on the tubing/casing annulus was conducted on March 30,2011 for CD1 -19A, followed by testing March 31— April 1, 2011 on WD -02. Little Red Hot Oil Services performed the testing under the direction of David Neville, CPAI engineering representative and Bernard Glansbeek, CPAI operations representative. Talib Syed, EPA representative, witnessed the pressure test. A representative of the Alaska Oil and Gas Conservation Commission waived witnessing of the SAPT Operations Summary - Annulus Pressure Test • Calibrated gauges (located on the wellhead) were used to monitor the inner annulus and tubing pressures during testing. Digital gauges also measured annulus and tubing pressures in the same, continuous fashion as during regular injection operations. • The casing and tubing pressure did not change during the 30- minute test period on CD1 -19A. • During the 30 minute test period on WD -02, the casing showed a continuous drop in pressure that didn't demonstrate a stabilizing tendency. This behavior was confirmed by separate tests both with the well on injection and with the well shut -in. Following this demonstration of lost tubing and casing annulus integrity, the well was shut -in. • The AOGCC Mechanical Integrity Test form was signed by the EPA Inspectors present for the test. See Attachment 1. The pressure data is shown in graphical form on Attachment 2. • i WD-02 Final MIT Results Pretest Initial 15 Min. 30 Min. Result Tubing 550 540 520 500 Casing 3090 3540 3380 3250 Fail OA 530 530 530 540 • Diesel volume injected into casing annulus prior to SAPT was —2.3 bbl • EPA witnessed by Talib Syed *See full suite of SAPT test results in attachment 1 Conclusion — the SAPT demonstrated a slow leak from the tubing/casing annulus. CD1 -19A Final MIT Results Pretest Initial 15 Min. 30 Min. Result Tubing 1830 1838 1831 1830 Casing 545 2130 2085 2074 Pass OA 404 432 434 434 • Diesel volume injected into casing annulus prior to SAPT was —1.5 bbl • EPA witnessed by Talib Syed Conclusion — the SAPT conclusively demonstrated that the tubing/casing annulus is mechanically competent and no leak paths are present above the packer. • • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Id Sent: Saturday, April 02, 2011 11:00 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: ALP DS Lead and Simops Coord; Neville, David J; NSK Problem Well Supv Subject: Alpine Witnessed MIT Forms Attachments: MIT CRU CD1 -19A 03- 30- 11.xis; MIT CRU WD -02 04- 01- 11.xis; MIT CRU WD -02 03- 31- 11.xis All, 1' 6 ZOc-- 040 Attached for your records are the MIT forms for tests performed on Alpine EPA Class I Disposal wells from 03/30/11 through 04/01/11 as witnessed by Talib Syed. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1 7 O 4/4/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION j � 1' �� It Mechanical Integrity Test Submit to: jim.regq(8 alaska.gov: doa .aogcc.orudhoe.bava!alaska.00v. phoebe.brooks(caalaska.aov; tom.maunder(caalaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD / UNIT / PAD: Alpine / CRU / CD1 DATE: 03/30/11 OPERATOR REP: David Neville AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 19A Type Inj. I TVD 6,634' Tubing 1830 1838 1831 1830 Interval 0 P.T.D. 2000400 Type test P Test psi 1659 ' Casing 545 2,130 2,085 2,074' P/F P i Notes: EPA Class I injection Well Annual MITIA j OA 404 432 434 434 Witnessed by Talib Syed (EPA Rep) Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1 = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT CRU CD1 -19A 03 -30 -11 (2).xls " I- ft Gaute Naadland Supervisor, WNS Base ConocoPhillips Company ConocoPh il lips Anchorage AK 99501 -0360 Telephone 907 - 265.6822 REcE March 31, 2010 Alaska Oil and Gas Conservations Commission M I ;NI; 333 W 7 Avenue, Suite 100 Anchorage AK 99501 Nalka y7y� @ Cans. o{$� n t, Mi �aB .�.9 Atl Ot:d Attention: Commissioner Daniel Seamount, Jr. RE: 2010 Disposal Well Performance Report Alpine Oil Pool, Colville River Field Dear Commissioner Seamount, ConocoPhillips Alaska, Inc., as operator and on behalf of the working interest owners of the Colville River Field, submits this 2010 Disposal Well Performance Report for the i Alpine Oil Pool. This report is submitted in accordance with Area Injection Order No.18C and Disposal Injection Order No.18. Inquiries regarding this report may be directed to Scott Reed / David Neville (670 -4934) at this office. Sincerely, . --(), A. C1S — / / / i C.. \ — \c-\ N \ aoo-u-k0 Gaute Naadland Supervisor WNS Base North Slope Operations and Development Enclosures p 1 `,V1 ConocoPhillips 2010 Annual Disposal Well Performance Report Alpine Oil Pool Colville River Field MARCH 31, 2011 Table of Contents Introduction 2 Class I Disposal Well WD -02 3 Class I Disposal Well CD1 -19A 5 Attachment 1: WD -02 2010 Injection Summary Table 8 Attachment 2: WD -02 2010 Injection Summary Plot 9 Attachment 3: CD1 -19A 2010 Injection Summary Table 10 Attachment 4: CD1 -19A 2010 Injection Summary Plot 11 2010 CRU Disposal Well Performance Report 1 ii INTRODUCTION This report is prepared in accordance with Rule 9 of Area Injection Order No. 18C, dated March 26, 2009, which requires the submission of an annual performance report for slurry injection wells. Additionally, this report is prepared in accordance with Rule 5 of Disposal Injection Order 18, dated April 19, 1999 and the requirements of 20 AAC 25.432 (Report of Underground Injection). Well WD -02, which was drilled and completed as a Class 1 well in April 1999, continued to serve as the primary source of disposal for camp fluids in 2010. Field produced fluids were also occasionally pumped to WD -02 in 2010. A second disposal well, CD1 -19A, was drilled and completed in May 2000, to provide a disposal source for Class II fluids generated during wellwork and drilling operations. It was converted to a Class 1 well in April 2008 and continued to serve as a disposal source for fluids generated during wellwork and drilling operations in 2010. 2010 CRU Disposal Well Performance Report 2 CLASS I DISPOSAL WELL CD1 -19A Injection Volumes Fluid injection volumes for the 12 -month period of January 2010 through December 2010 totaled 292,792 bbls. This represents a monthly average of 24,399 bbls. Cumulative injection into the Sadlerochit Group since the start of the project is 1,726,317 bbls. D1 -19A are summarized in both table and ' n volumes for C lot form as Attachments 3 p Injectio 0 and 4. Injection Rates Disposal operations for CD1 -19A are recorded via Micromotion flow rate meter. Various trucks and rig units are utilized to transport and dispose of fluids into this well. Injection rates vary between 0.5 -3.7 bpm. There is no permanent disposal pump or piping installed at this time. Disposed fluids primarily include spent wellwork and flowback fluids. In 2010, additional disposal included drilling mud and cuttings. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically in Attachment 4. Injection Pressures Injection pressures are monitored and recorded via Madegetech pressure gauge transmitters. These reports are summarized in the data plot (Attachment 4). Normal wellhead pressures during disposal operations vary between 1,900 psi and 3,900 psi. Annulus Pressures Annulus pressures are manually recorded and reported, and displayed in graphical form on the well performance plot (Attachment 4). Inner annulus pressure averaged 668 psi during 2010 and remained stable during injection periods. On April 10, 2010, the annual EPA MIT was performed. Summary results from the Well Service Report are shown below: > EPA Witnessed MITIA - Passed (Thor Cutler), Initial T /I /O = 2850/515/350 Initial test T /I /O = 2850/2224/381, 15 minute T /I /O = 2850/2101/382, 30 minute T /I /O = 2850/2173/381, 45 minute T /I /O = 2850/2168/382, 60 minute T /I /O = 2850/2166/380. AOGCC waived witness on 4.10.10 by John Crisp 2010 CRU Disposal Well Performance Report 5 Depth Tags A depth tag was performed in 2010 with slickline and determined that fill was covering the perforations. Date MD Depth (ft Feet of Open Perfs. 12/12/2010 10,433 0' Surveillance Logging A Spectra Flow and (PROF log were performed on April 12, 2010. The purpose of these logs was to assess the upflow, if any, behind tubing. Fluid is entering the formation through perforations. Fracture Growth During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi /ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. A pressure fall -off (PFO) test was performed on Alpine's Class 11 Disposal Well, CD1 -19A on June 19, 2004 after injecting 227,000 bbls of approved fluids for the purpose of estimating fracture growth. The complete test report was submitted on July 26, 2004. Referring to the square root of time plot from the June 2004 PFO, a fracture was observed to close at dt = 7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi /ft. The elevated fracture gradient can most likely be attributed to poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early -time analysis. A regression fit to the early -time fall -off data resulted in a fracture half - length of 356 feet and a fluid efficiency of 1 percent. A Nolte -Smith plot from the injection data yielded a quarter slope, indicating a Perkins and Kern system, i.e. a wedge- shaped vertically contained fracture, which is growing in length. 2010 CRU Disposal Well Performance Report 6 Wellwork Event Summary DATE EVENT 4/10/2010 MITIA Passed, Tagged Fill, & Caliper Tbg 4/12/2010 Injection Profile: No upward movement of fluid detected 12/12/2010 Tagged Fill & Caliper Tbg Class I Conversion ConocoPhillips applied for the Class I status for CD1 -19A to serve as the primary back -up to WD -02 in 2007. The well was converted into a Class I disposal well on April 6, 2008. Micromotion flow rate and Madegetech pressure gauge transmitters were installed with an alarm system to detect excess injection pressures and rates. The well is monitored 24 hours a day during injection. The well operates at a maximum 4200 psig wellhead pressure and an annulus pressure up to 2000 psig. Continuous, recorded monitoring of volumes of hard piped waste streams are captured through the Alpine automation system, Setcim. I 2010 CRU Disposal Well Performance Report 7 2010 Disposal Well Performance Report Colville River Field - ATTACHMENT 3: CD1 -19A 2010 INJECTION SUMMARY TABLE January through December 2010 Injection Summary Well: CD1 -19A Disposal Order: 18B Field: Colville River Unit API No.: 501032029401 Permit to Drill Pool: Alpine Oil Pool No.: 200 -040 Pool Code: 120036 Tubing Casing Daily Monthly Days In Pressure Average Pressure Average Average Total Cumulative Month Operation Max Pressure Pressure Max Pressure Pressure Liquid (bbl) Gas Liquid(bbl) Gas Liquid (bbl) January 13 3,984 2,304 893 564 1,109 0 14,412 0 14,412 February 15 3,826 2,499 1,577 609 1,419 0 21,289 0 35,701 March 23 4,071 2,930 2,206 457 1,153 0 26,515 0 62,216 April 23 4,065 2,588 2,620 640 919 0 21,141 0 83,357 May 17 2,823 1,803 1,474 423 2,036 0 34,620 0 117,978 June 8 5,242 1,865 1,640 184 4,806 0 38,447 0 156,424 July 14 2,952 1,882 1,319 163 2,380 0 33,315 0 189,739 August 16 2,990 2,019 836 121 2,354 0 37,657 0 227,396 September 21 3,330 2,021 1,210 204 1,233 0 25,894 0 253,290 October 8 2,594 1,999 744 135 2,900 0 23,196 0 276,486 November 14 3,106 1,984 1,087 305 518 0 7,247 0 283,733 December 9 3,808 1,871 805 608 1,007 0 9,059 0 292,792 Yearly Averages 3,566 2,147 1,368 368 1,819 0 24,399 0 2010 CRU Disposal Well Performance Report 10 2010 Disposal Well Performance Report Colville River Field ' ATTACHMENT 4: CD1 -19A 2010 INJECTION SUMMARY PLOT 2010 _._ Avg. Daily Tubing Pressure (PSIG) CD1 - 19A Injection Performance Avg. Daily Inner Annulus Pressure (PSIG) —Avg. Daily Injection Rate (BPM) 4 1 3,500 — 3.5 3,000 - I I —3 \ I 2,500 - I 2.5 E Q s ai 2,000 + Y I - 2 * 3 I I to Ct 1 t V N ,, tat • 1,500 - ` Vi i 1.5 Q I I I I 1,000 \ 1 i � m, 500 Y�I ! A (�� 10.5 r t, 1 r ,„,,,,,,,,, ' ' , , ' , , ' ' O '\ , , ' , ' , , , ' \ O , , ' , '\ O �O 0O �O rO t' �O � 1 0 �O �O9 10 4 10 r (1 0 �O �O �O �O �O r , �O r r N , , p ot ,, \ r \�l\ �\'� k) „ \ '� C �\ <0 , 4, �\"' 6\ 4 j \ O\5 A \'` G j \ AC' 6\ p\ 69' O\'` n�\ O\`' ^ O\'` n�\ X 61' ^ ''\ r y \ � N . l \ � 6\ �\ � rt9' 2010 CRU Disposal Well Performance Report 11 CD1 -19A and Wd -02 Disposal Well Performance Report CC List State of Alaska, Department of Natural Resources Mr. Kevin Banks, Director 5550 West 7th Avenue, Suite 800 Anchorage, Alaska 99501 -3560 Alaska Oil and Gas Conservation Commission Attention: Mr. Dan Seamount 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Arctic Slope Regional Corporation Ms. Teresa Imm, Resource Development Manager 3900 C Street Suite 801 Anchorage AK 99503 Anadarko Petroleum Corporation Mr. Steve Dodds 1201 Lake Robbins Drive Houston, TX 77380 (832) 636 -3087 Kuukpik Corporation Mr. Isaac Nukapigak, President P. O. Box 187 Nuiqsut, AK 99789 -0187 Electronic Copies Warwick King Ato 1226 Gaute naadland ATO 1770 Jack Walker ATO 1742 Catherine Roso ATO 1782 Doria Soria ATO 1468 Page 1 of 2 Maunder, Thomas E (DOA) From: Neville, David J [David.J.Neville @conocophillips.com] Sent: Wednesday, March 30, 2011 4:52 PM To: Maunder, Thomas E (DOA); NSK Well Integrity Proj; talibs @ecentral.com Cc: NSK Problem Well Supv Subject: RE: CD1 -19A MITIA results Tom, thanks for catching the missing date. I've sent a copy that has the date included. MJ, thanks for sending this on to the appropriate wells group rep. David Neville Alpine Production Engineer (907) 670 -4934 (Field Office) (907) 943 -1256 (Field Cell) From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, March 30, 2011 4:39 PM To: NSK Well Integrity Proj; Neville, David 3; talibs @ecentral.com Cc: NSK Problem Well Supv Subject: RE: CD1 -19A MITIA results Thanks MJ. From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Wednesday, March 30, 2011 4:38 PM To: Maunder, Thomas E (DOA); Neville, David 3; talibs @ecentral.com Cc: NSK Problem Well Supv Subject: RE: CD1 -19A MITIA results David, The Problem Well Supervisor will do this for you. MJ Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, March 30, 2011 4:37 PM To: Neville, David 3; talibs @ecentral.com Cc: NSK Well Integrity Proj Subject: RE: CD1 -19A MITIA results 4/1/2011 Page 2 of 2 David, Please fill out and submit the AOGCC excel sheet MIT Rorm, 10 -426 at http: / /doa.alaska.gov /oac /forms /formsindex.html . Also, I did not see any date on the document you sent. Regards, Tom Maunder, PE AOGCC From: Neville, David J [mailto:David.J.Neville @conocophillips.com] Sent: Wednesday, March 30, 2011 4:29 PM To: 'cutler.thor @epa.gov'; 'talibs @ecentral.com'; Maunder, Thomas E (DOA); ALP Env Coord Spills Waste Land & Other; DeGeorge, Lynn A; ALP DS Lead and Simops Coord; ALP Ops Maint Supt; NSK Well Integrity Proj; Reed, Scott; Walker, Jack A; Schneider, Tim S.; Kolesar, Dan 3; Naadland, Gaute Subject: CD1 -19A MITIA results Attached are the results of today's EPA witnessed MITIA on CD1 -19A: Thanks, David Neville Alpine Production Engineer (907) 670 -4934 (Field Office) (907) 943 -1256 (Field CeII) 4/1/2011 "."°'� United States Environmental Protection Agency Region 10 a 1200 Sixth Avenue, Suite 900 ° " &°" " Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e-mail: cutler.thor�,7epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility 1 Well 1 Permit No. PTD No. • ConocoPhillips Alaska - Alpine/CRU CRU CD 1 -19A AK- 1I010 -A 2000400 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 3/30/11 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval / Comments Presssure (psi) test TVD) 2,100 Diesel 6,633' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature • Note volume of diesel pumped in annulus during test. T STAR TIME: RECORDED PRESSURES (PSI) RESULT 3 E ' 0 PRE, T INITIAL 15 �MI 30 MIN 45 MIN 60 MIN j F 1111.411111/ S TUBING niI�irkfia T INNERANNULUS IfillIVA1 lj:L'i `r)4 1 OUTER ANNULUS trinillratakinallEM1.11111.111111111111111 1 COMMENTS: ' I tf (,5 hI O t'le. eueVi, T START TIME: ( RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRF, MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS , FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: EPA Gass 1 well test as per permit. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during fist 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). I I I I 1 -- E -mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: t 1 � � „ ;tied 1), t v 1 Talib Syed, Inspector /1 • • • Lynn DeGeorge Senior Environmental Coordinator 700 G Street, ATO -1756 CanocoPhlHHips P.O. Box 100360 Anchorage, Alaska 99510 -0360 Phone: 907-263-4671 Alaska, Inc. ns Fax: 907- 265 -6715 .ti February 23, 2011 FEB 7 0i1 Mr. Peter Contreras . iI &Gas Cony. co. , .'ssio Certified Mail Supervisor, Ground Water Protection Unit tRCit>Elf 7008 0150 0002 1586 9879 U.S. Environmental Protection Agency (OCE -082) Return Receipt Requested 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 RE: Class I Well Permit #AK- 11003 -A (CD1 -19A), Permit to Drill No. 200 -040 Class I Well Permit #AK- 11003 -B (WD -02), Permit to Drill No. 99 -258 Biennial Report - 3rd and 4 Quarters, 2010 Dear Mr. Contreras, On behalf of ConocoPhillips Alaska, Inc., I submit to you the Alpine Class 1 Well Report for the third and fourth quarters of 2010 for Class I Well CD1 -19A (AK- 11003 -A) and WD -02 (AK- 11003 -B). Pursuant to requirements in Part II.E of the subject permits, the following information is provided: • Report Certification • EPA Form 7520 -8, Injection Well Monitoring Report • Graphical plots of continuous injection pressure and rate monitoring t 4 "--C\ • Raw monitoring data in electronic format Q `cy� c\ • Physical, chemical, and other relevant characteristics of injected fluid ((�� • Summary of significant well maintenance A - 9- --41k4 • Mechanical integrity test results • Other reports and back -up information �� t • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely,h \�( ` Lynn O P � S CS Seni or r Environmental Coordinator c'C Enclosures: Report and Raw Data CD Page 1 of 58 • • RE: Class I Well Permit #AK- 11003 -A (CD1 -19A) February 23, 2011 Class I Well Permit #AK- 11003 -B (WD -02) Biennial Report — 3 and 4 Quarters, 2010 cc: (with Raw Data CD) Director, OCE EPA (OCE- 164 Thor Cutler EPA +; . Talib Syed TSA, Inc. (EPA Consultant) i cc: (without Raw Data CD) Peter McGee ADEC Tom Maunder AOGCC Joe Martin Anadarko Steve Freemeyer Anadarko RE: Class I Well Permit #AK- 11003 -A (CD1 -19A) February 23, 2011 Class I Well Permit #AK- 11003 -B (WD -02) Biennial Report — 3 and 4 Quarters, 2010 bcc: (without Raw Data CD) Colegrove /Smith ALP -14 Mahan /McCullough NSK -61 Lynn DeGeorge bcc: (with Raw Data CD) Alpine General File Central Files • • Report Certification Statement of Certification This report is hereby certified in accordance wth the requirements of Part I.E.15 of the Environmental Protection Agency Permit AK- 11003 -A and AK-11003-13. 1 certify under the penalty of taw that 1 have personally examined and am familiar with the information submitted in this document and as attachments and that based on my inquiry of those individuals immediately responsible for obtaining the information 1 believe that the i*tormation is true, accurate, end complete. 1 am aware that there are significant penailies for submitting false information, including the possibility of line and Imprisonment P .. Manager Western North Slope Operations • • • EPA Form 7520 -8 CD1 -19A Note: Please be advised that minimum injection pressure represents the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. • • United States Environmental Protection Agency EPA Washington, DC 20460 Injection Well Monitoring Report 2010 Month Month Month Injection Pressure (PSIG) July August September 1. Minimum 967 558 753 2. Average 1,882 2,019 2,021 3. Maximum 2,952 2,990 3,330 Injection Rate (Gal/Min) 1. Minimum 0.0 0.0 0.0 2. Average 15.6 17.2 28.8 3. Maximum 150.0 145.7 148.9 Annular Pressure (PSIG) 1. Minimum 11 2 - 2. Average 163 121 204 3. Maximum 1,319 836 1,210 Injection Volume (Gal) 1. Monthly Total 696,590 768,173 1,244,412 2. Yearly Cumulative 6,448,374 7,216,548 8,460,960 Temperature (F ° ) 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum pH 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum not required not required not required Other $1/ ;cbl'‘ Name and Address of Permittee Permit Number ConocoPhillips Alaska, Inc., P.O. Box 100360, AnchoracZe, Alaska, 99510 - 0360 AK 11003 - A Name and Official Title (Please type or print) Signature Date Signed inn DeGeorge, Senior Environmental Coordinator J 71.) q / lie ``` `'`;f " % Z - 1 i EPA Form 7520 -8 (rev. 9 -91) note - form recreated by CPAI to allow data entry via PC • • United States Environmental Protection Agency EPA Washington, DC 20460 Injection Well Monitoring Report 2010 Month Month Month Injection Pressure (PSIG) October November December 1. Minimum 185 1,235 23 2. Average 1,999 1,984 1,871 3. Maximum 2,594 3,106 3,808 Injection Rate (Gal /Min) 1. Minimum 0.0 0.0 0.0 2. Average 8.0 16.8 6.8 3. Maximum 146.1 144.3 131.8 Annular Pressure (PSIG) 1. Minimum - - 275 2. Average 135 305 608 3. Maximum 744 1,087 805 Injection Volume (Gal) 1. Monthly Total 356,684 726,161 301,254 2. Yearly Cumulative 8,817,645 9,543,807 9,845,061 Temperature (F ° ) 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum pH 1. Minimum not required not required not required 2. Average not required not required not required 3. Maximum not required not required not required Other kq v '5". 3 C.nt -tc,N, Name and Address of Permittee Permit Number ConocoPhillips Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510 - 0360 AK 11003 - A Name and Official Title (Please type or print) Signature Date Signed Lynn DeGeorge, Senior Environmental Coordinator v`y ` �� z.- Z - t t EPA Form 7520 -8 (rev. 9 -91) note - form recreated by CPAI to allow data entry via PC ConocoPh~Il~ps Alaska, Inc. ~~ July 26, 2010 Mr. Peter Contreras Supervisor, Ground Water Protection Unit U.S. Environmental Protection Agency {OCE-082) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 ~U~~~,2010 C11sSio(t ~~~isk~ ffi~ G>~s C~ ~.;tich:~r~g~ LJ Lynn Oet;eorQe Sanlor Envaonmental Coordinator 700 G Strset, ATO-1756 P.O.Box 100380 Anchorage, Alaska 99510-0360 P1,one: ~7-263-4671 Fax: ~7-265-6715 Cert~ed Mail 7008 0150 0002 1546 9756 Return Receipt Requested RE; Class 1 Well Perm!# AK-110x3 A (CD1-19A), Permit to Drill No. 200-040 Class I Wetl Permit AK-11003-B (WD-02), Permit to Drill No. 99-258 Biennial Report-1~ and 2nd Quarters, 2010 Dear Mr. Contreras, On behalf of ConocoPhiUips Alaska, inc., enclosed is the Alpine Class I welt report for the first and second quarters of 2010 for Class I Weii CD1-19A (AK-1!003-A) and WD-02 (AK-11003-B). Pursuant to requirements in Part ll.E of the subject permits, the following information is provided: • ort Certification '~ ~ ~ ~ ""- Rep ~--~.J`~ ~. ~.. ,~~ ~ <~ ~~~c ~~~~ ~' ~ ~~ • EPA Form 7520-8, Injection Well Monitoring Repo • Graphical plats of continuous injection pressure and rate monitoring • Raw monitoring data in electronic #ormat • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results ~~, °~~~ 1~R.? ; ;%~ ~~ ~..~~~1 ~:, ,~ . • Other reports and back-up information • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely, 1 Lynn DeGeorge Senior Environmental Coordinator Enclosures • • ~ Mechanical Integrity Test Results Well WD-02 & CD1-19A Colville River Field Internal Mechanical Integrity Test Requirements ~ According to 40 CFR § 146.8(a), an injection well has mechanical integrity if there is no significant leak in the casing, tubing, or packer, and there is no significant fluid movement into an underground source of drinking water through vertical channels adjacent to the injection wellbore. The current permit for the Alpine Class I wells WD- 02 and CD 1-19A describes the requirements for performing and evaluating a standard annulus pressure test (SAPT). Additionally, in accordance with the permits a caliper ~ survey is required. The results for these testing requirements are summarized below. Overview An SAPT on the tubing/casing annulus was conducted on April 10-11, 2010. Little Red Aj Hot Oil Services performed the testing under the direction of Jared Brake, CPAI Wells ~ Representative. Thor Cutler, EPA Inspector, witnessed the pressure test. A ~ representative of the Alaska Oil and Gas Conservation Commission waived witnessing of the SAPT. ProActive Diagnostic. Services (PDS) completed the caliper survey, while Halliburton E-line completed the water-flow log. Operations Summary -Annulus Pressure Test • Calibrated gauges (located on the wellhead) were used to monitor the inner annulus and tubing pressures during testing. Digital gauges also measured annulus and tubing pressures in the same, continuous fashion as during regular injection operations. • The casing and tubing pressure did not change during the 30-minute test period. ~ • The AOGCC Mechanical Integrity Test form was signed by the EPA Inspectors present for the test. See Attachment 1. The pressure data is shown in graphical form on Attachment 2. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 2010 Annual M/1~port Page 2 of 7 WD-OZ MIT Results Pretest Initial 15 Min. 30 Min. Tubin 700 700 700 700 Interval Casin 3 020 3 500 3 480 3 480 P/F P OA 580 580 580 580 EPA witnessed by Thor Cutler Figure 1. Digital Gauge Test Results • Volume of diesel injected into the casing annulus prior to performing the SAPT was ~ 0.9 bbls. CD1-19A MIT Results Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Tubin 2,850 2,850 2,850 2,850 2,850 2,850 Interval Casin 515 2 224 2,101 2 173 2,168 2,166 P/F P OA 350 381 382 381 382 380 EPA witnessed byThor Cutler Figure 2. Digital Gauge Test Results • Volume of diesel 'injected into the casing annulus prior to performing the SAPT was 2.0 bbls. Conclusion -the SAPT conclusively demonstrated that the tubing-casing annulus is mechanically competent and no leak paths are present above the packer. Operations Summary -Caliper Survey In accordance with the Enhanced Surveillance Plan (ESP) for WD-02 and CDl-19A, a caliper survey was conducted in the intermediate casing and tubing. Prior to performing the caliper survey, a drift and tag procedure was performed to determine the plug-back total depth (PBTD). The WD-02 and CD1-19A tag depths were 9,902' MD and 11,500' MD respectively. • ProActive Diagnostic Services completed the caliper survey on April 10-11, 2010 • One pass was completed for this caliper survey in the tubing and casing • The caliper tool selected utilizes 40 independent fingers to survey the casing wall. Each "finger" is capable of recording a penetration as deep as 0.30". WD-02 Caliper Survey Results The caliper recordings indicate the 4.5" tubing is in good to poor condition, with a ~ maximum wall penetration of 59% recorded in joint #4 at 165' MD. Recorded damage appears as corrosion above DB nipple and apparent erosion throughout the majority of the 4.5 tubing. The survey was the first performed on the tubing. 1 ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips , EPA 2010 Annual M/T ~rt Page 3 of 7 • A total of 264 joints of tubing were surveyed with only one pass. The results of the relative penetration and metal loss of the tubing are displayed in Figure 3 4.5" Tubing Results: Frequency Joints < 1 % Penetration 0 Joints 1%-10% Penetration 3 Joints 10%-20% Penetration 58 Joints > 20% Penetration 203 Joints < 1 % Loss 1 Joints 1 %-10% Loss 44 Joints 10%-20% Loss Joints > 20% Loss 218 1 Figure 3. Caliper Survey Results: 4.5" Tubing The caliper of the 7" casing indicate the condition is good to fair with respect to corrosive and mechanical damages. The maximum wall penetration of 25% was recorded at 8,496'. A total of 38 joints of tubing were surveyed with only one pass, those joints between the tubing tail and the top of the injection interval. The results of the relative penetration and metal loss of the tubing are displayed in Figure 4 7" Casing Results Frequency Joints < 1 % Penetration 0 Joints 1%-10% Penetration 0 Joints 10%-20% Penetration 30 Joints > 20% Penetration 8 Joints < 1 % Loss 0 Joints 1%-10% Loss 38 Joints 10%-20% Loss Joints > 20% Loss 0 0 Figure 4. Caliper Survey Results: 7" Casing ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 2010 Annual M/T ~rt Page 4 of 7 CD1-19A Caliper Survey Results • The caliper recordings indicate the 3.5" tubing is in good to poor condition, with a maximum wall penetration of 50% recorded in joint #320 at 10,018' MD. No significant areas of cross-sectional wall loss are recorded in the interval logged. A total of 349 joints of tubing were surveyed with only one pass. The results of the relative penetration and metal loss of the tubing are displayed in Figure 5 4.3" Tubing Results: Frequency Joints < 1 % Penetration 0 Joints 1%-10% Penetration 3 Joints 10%-20% Penetration 268 Joints > 20% Penetration 77 Joints < 1% Loss 4 Joints 1%-10% Loss 331 Joints 10%-20% Loss Joints > 20% Loss 14 0 Figure 5. Caliper Survey Results: 3.5" Tubing Conclusion (Caliper) -There are no existing areas of concern, and no pending potential leak points in the casing wall between the tubing tail and the perforated injection interval for both CD1-19A and WD-02. According to the PDS Log Results Summary, "A comparison between the current and previous log (April 13, 2008) indicates a slight increase in corrosive damage in the 7" casing interval logged." Attachments/Supporting Documents The AOGCC Mechanical Integrity Test Form (Attachment 1). The casing/tubing pressure data (plotted) for the performed SAPT (Attachment 2). PDS Caliper Graphical Comparison Report (Attachment 3). Overall Summary Conclusion -the SAPT conclusively demonstrated that the tubing-casing annulus is mechanically competent and no leak paths are present above the packer. The condition of WD-02 and CDl-19A are sound, with full mechanical integrity. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips 1 1 1 1 i EPA 2010 Annual M/T R~rt • Page 5 of 7 External Mechanical Integrity Test Requirements According to 40 CFR §146.8(a), an injection well demonstrates `external' mechanical integrity if there is no significant fluid movement into an underground source of drinking water through vertical channels adjacent to the injection well bore. In accordance with Part II.C.3.b.2, the approved 20041ogging program included temperature and oxygen activation to detect and identify fluid movement exiting the permitted injection interval. The Oxygen Activation (OA) technique was approved by the EPA beginning with the 2002 inspection program as an acceptable substitute for radioactive tracer surveys (RAT). In the event OA evaluation of external fluid movement is inconclusive, RAT logging may be required. Though not required, a Production Spinner Profile (PSP) was performed to obtain an injection profile over the permitted interval. WD-02 Water Flow Log Results The results of the OA Water Flow Log (WFL) and PSP are summarized below. Operations Summary -Oxygen Activation Method (Water Flow Log) On April 12, 2010, Halliburton ran the Water Flow Log (WFL) in combination with a Spinner Profile Log in WD-02 to evaluate fluid movement. • Over the past 6 months, the average injection rate was approximately 1.5 bpm. • The injection rate used during the WFL was 2.5 bpm at an average WHIP of 2,500 psi. • The following is a summary of the WFL survey: Station Tool Depth ft Flow Detection pump Rate Flow Detected 1 9,459 - 9,472 Up 1.5 bpm No 2 9,514 - 9,552 Up 1.5 bpm No 3 9,612 - 9,627 Up 1.5 bpm No 4 9,702 - 9,712 U 1.5 b m No 5 9,803 - 9,818 U 1.5 b m No 6 9,837 - 9,867 U 1.5 b m No Figure 6. WLF Logging Stations: 1.5 bpm at 1650 psi The top perforation is located at 9,459'. The top of the Sag River is located at 8,937', which corresponds to the base of the confming interval or top of the injection interval. Conclusion -These surveys did not detect any fluid escaping the injection interval. This is consistent with caliper logging results. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 2010 Annual MIT f ort Page 6 of 7 Operations Summary -Spinner Profile Log Following completion of the WFL segment, a spinner survey was conducted to analyze fluid movement as it exits the casing. All passes were logged at 1.5 bpm. Note that PBTD was determined as approximately 9,902' MD with a tag. The following is a summary of the results from this log: - Logged a depth correlation pass and verified tool performance. - Surveyed from above the perforations at 9,000' to 9,900' (PBTD) - Passes run included: -Up and Down passes at 40/80/120 fpm - Surveyed stop counts at the following depths: 9,000' /9,400'/9,500'/9,575'/9,650'/9,750'/9,825' /9,869' Splits show the fluids leaving the wellbore in Figure 7. Perforated Interval Fluid 9,459 - 9,472 0% 9,514 - 9,552 0% 9,612 - 9,627 0% 9,702 - 9,712 17% 9,803 - 9,818 83% 9,837 - 9,867 0% Figure 7. Percentage of Fluid Leaving Wellbore Conclusion -The splits shown identify the perforation intervals from 9,803'-9,818' MD as the primary location of fluids exiting the wellbore. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 201 D Annual M/T R~rt Page 7 of 7 CDl-19A Water Flow Log Results Operations Summary -Oxygen Activation Method (Water Flow Log) On April 12, 2010, Halliburton ran the Water Flow Log (WFL) in combination with a Profile Log (PFCS) in WD-02 to evaluate fluid movement. • Over the past 6 months, the average injection rate was approximately 1.1 bpm. • The injection rate used during the WFL was 1.1 bpm • The following is a summary of the WFL survey: It was determined that 100% of the fluids were entering the perforations below the fill at 11,472' MD. Given that the tool was not able to get past the first perforation no splits were determined. The SpectraFlow tool was logged to determined the upflow behind the 7" casing perforations. The tool was run at 11400' MD, 11425' MD, and 11450' MD to complete an impulse test. The impulse tests show no water flow up behind the casing. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips • • Brian Barreda WNS Production Engineer 700 G Street, ATO-1752 ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Alaska, ~r1C. Telephone 907-265-6036 ® ~~' i~ ~~~ JUN 2010 ~ z ~^_ .. assn June 1, 2010 ~ ~~~ .,r .i_ Mr. Mike Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency [OW-137] 1200 Sixth Avenue Seattle, Washington 98101 Subject: Annual Mechanical Integrity Test Report Alpine Class I Disposal Wells Permit Number AK-1I003-A (WD-02) Permit Number AK-1 I003-B (CD 1-19A) Dear Mr. Bussell: Sent Certified Mail Return Receipt Requested 7008 0150 002 1586 9718 ConocoPhillips Alaska, Inc. submits for your review and approval the Annual Mechanical Integrity Test Report for our Class 1 disposal well in the Colville River Field. The testing of well WD-02 and CD1-19A has been performed in compliance with stipulations in Part II.C.3.b of Permit AK-1I003-A. Testing concluded on April 12, 2010 and the EPA requires submission of a descriptive and interpretive report within 45 days. Two copies of the report are enclosed in accordance with Section II.C.3.c.1. A Standard Annular Pressure Test confirmed the mechanical integrity of well WD-02 and CD1-19A. There is no evidence that any of the injected fluids are escaping the wellbore or permitted injection interval. Thor Cutler from the EPA was present to witness the annual inspection. Should you have any comments or concerns, please feel free to contact me at 907.265.6036. Sincerely, /~~ /~3~~ Brian Barreda WNS Production Engineer ., ~ 1:. ,~ ,. •~' .~~ • ~ •. ConocoPhillfps Alaska, Inc. cc with attachments: Mr. Thor Cutler U.S. Environmental Protection Agency [OCE-127] 1200 Sixth Avenue Seattle, Washington 98101 Mr. Tom Irwin, Commissioner Alaska Department of Natural Resources 550 West 7~' Ave Suite 800 Anchorage, AK 99501-3035 Peter McGee ADEC 610 University Ave. Fairbanks, Alaska 99709 Mr. Dan Seamount, Director Alaska Oil and Gas Conservation Commission 333 West 7~' Ave. Suite 100 Anchorage, Alaska 99501 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 89050 Nuiqsut, Alaska 99789 Mr. Joe Martin Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-13 3 0 • " Bltian BarPeda" "' "" ~'' ': " INNS Rroducti8n_=Engineer, I00 ~ _$treet ;4'i'O 1752,,. . ; .. Post Office Bigz",~1003~D :. ;_ .` raii~horage, Ai~ska 995'1.0=0360 `(elephone 907-155-6945, Talib Syed Talib Syed and Associates, Inc. ConocoPhilli s p Alaska, Inc. Brian Barreda WNS Production Engineer 700 G Street, ATO-1752 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6945 6551 South Revere Parkway, Suite 215 Centennial, CO 80111 :.BFi~n Barreda.. ~ ,... WNS Producfion,~tgitieer 700 G Street, ATO-1752 ConoeoPhil li ps Post Office BoX 1°0360 Anchorage, Alaska 99510-0360 Alaska, ~f1C. Telephone 907-265-6945 bcc: (cover letter only) Gaute Naadland Ray Hinchliff Warwick King bcc: (with attach) ATO 1770 ATO 1720 ATO 1226 Brian Barreda ATO 1752 Lynn DeGeorge ATO 1756 ALP. Env. Coord. ALP 14 File: Alpine General Files 1.2.5.2 STATEMENT OF CERTIFICATION This report is hereby certified in accordance with the requirements of Part I.E.15 of EPA Permit #AK-11004A. "I certify under the penalty of law that I haven personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment." Ray Hincliff Operations Manager Alpine Development -~/~/,~ Dat- e Mechanical Integrity Test Results Well WD-02 & CD1-19A Colville River Field Internal Mechanical Integrity Test Requirements According to 40 CFR § 146.8 (a), an inj ection well has mechanical integrity if there is no significant leak in the casing, tubing, or packer, and there is no significant fluid movement into an underground source of drinking water through vertical channels adjacent to the injection wellbore. The current permit for the Alpine Class I wells WD- 02 and CD1-19A describes the requirements for performing and evaluating a standard annulus pressure test (SAPT). Additionally, in accordance with the permits a caliper survey is required. The results for these testing requirements are summarized below. Overview An SAPT on the tubing/casing annulus was conducted on April 10-11, 2010. Little Red Hot Oil Services performed the testing under the direction of Jared Brake, CPAI Wells Representative. Thor Cutler, EPA Inspector, witnessed the pressure test. A representative of the Alaska Oil and Gas Conservation Commission waived witnessing of the SAPT. ProActive Diagnostic Services (PDS) completed the caliper survey, while Halliburton E-line completed the water-flow log. Operations Summary -Annulus Pressure Test • Calibrated gauges (located on the wellhead) were used to monitor the inner annulus and tubing pressures during testing. Digital gauges also measured annulus and tubing pressures in the same, continuous fashion as during regular injection operations. • The casing and tubing pressure did not change during the 30-minute test period. • The AOGCC Mechanical Integrity Test form was signed by the EPA Inspectors present for the test. See Attachment 1. The pressure data is shown in graphical form on Attachment 2. i i EPA 2090 Annual MIT Reporf Page 2 of 7 WD-02 MIT Results Pretest Initial 15 Min. 30 Min. Tubing 700 700 700 700 Interval Casin 3,020 3,500 3,480 3,480 P/F P OA 580 580 580 580 EPA witnessed byThor Cutler Figure 1. Digital Gauge Test Results • Volume of diesel injected into the casing annulus prior to performing the SAPT was ~ 0.9 bbls. CD1-19A NIIT Results Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Tubing 2,850 2,850 2,850 2,850 2,850 2,850 Interval Casin 515 2,224 2,101 2,173 2,168 2,166 P/F P OA 350 381 382 381 382 380 EPA witnessed by Thor Cutler Figure 2. Digital Gauge Test Results • Volume of diesel injected into the casing annulus prior to performing the SAPT was 2.0 bbls. Conclusion -the SAPT conclusively demonstrated that the tubing-casing annulus is mechanically competent and no leak paths are present above the packer. Operations Summary -Caliper Survey In accordance with the Enhanced Surveillance Plan (ESP) for WD-02 and CD1-19A, a caliper survey was conducted in the intermediate casing and tubing. Prior to performing the caliper survey, a drift and tag procedure was performed to determine the plug-back total depth (PBTD). The WD-02 and CD1-19A tag depths were 9,902' MD and 11,500' MD respectively. • ProActive Diagnostic Services completed the caliper survey on April 10-11, 2010 ® One pass was completed for this caliper survey in the tubing and casing ® The caliper tool selected utilizes 40 independent fingers to survey the casing wall. Each "forger" is capable of recording a penetration as deep as 0.30". WD-OZ Caliper Survey Results The caliper recordings indicate the 4.5" tubing is in good to poor condition, with a maximum wall penetration of 59% recorded in joint #4 at 165' MD. Recorded damage appears as corrosion above DB nipple and apparent erosion throughout the majority of the 4.5 tubing. The survey was the first performed on the tubing. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 2090 Annual M/T Report Page 3 of 7 A total of 264 joints of tubing were surveyed with only one pass. The results of the relative penetration and metal loss of the tubing are displayed in Figure 3 4.5" Tubing Results: Frequency Joints < 1 % Penetration 0 Joints 1%-10% Penetration 3 Joints 10%-20% Penetration 58 Joints > 20% Penetration 203 Joints < 1% Loss 1 Joints 1%-10% Loss ~ Joints 10%-20% Loss Joints > 20% Loss 218 1 Figure 3. Caliper Survey Results: 4.5" Tubing The caliper of the 7" casing indicate the condition is good to fair with respect to corrosive and mechanical damages. The maximum wall penetration of 25% was recorded at 8,496' . A total of 38 joints of tubing were surveyed with only one pass, those joints between the tubing tail and the top of the injection interval. The results of the relative penetration and metal loss of the tubing are displayed in Figure 4 7" Casing Results Frequency Joints < 1% Penetration 0 Joints 1%-10% Penetration 0 Joints 10%-20% Penetration 30 Joints > 20% Penetration 8 Joints < 1 % Loss 0 Joints 1%-10% Loss 38 Joints 10%-20% Loss Joints > 20% Loss 0 0 Figure 4. Caliper Survey Results: 7" Casing ConocoPhillips Alaska, Inc. is a Subsidiary of GonocoPhillips EPA 2010 Annual MIT Report Page 4 of 7 CD1-19A Caliper Survey Results The caliper recordings indicate the 3.5" tubing is in good to poor condition, with a maximum wall penetration of 50% recorded in joint #320 at 10,018' MD. No significant areas ofcross-sectional wall loss are recorded in the interval logged. A total of 349 joints of tubing were surveyed with only one pass. The results of the relative penetration and metal loss of the tubing are displayed in Figure 5 4.3" Tubing Results: Frequency Joints < 1 % Penetration 0 Joints 1%-10% Penetration 3 Joints 10%-20% Penetration 268 Joints > 20% Penetration 77 Joints < 1 % Loss 4 Joints 1%-10% Loss 331 Joints 10%-20% Loss Joints > 20% Loss 14 0 Figure 5. Caliper Survey Results: 3.5" Tubing Conclusion (Caliper) -There are no ezisting areas of concern, and no pending potential leak points in the casing wall between the tubing tail and the perforated injection interval for both CD1-19A and WD-02. According to the PDS Log Results Summary, "A comparison between the current and previous log (Apri113, 2008) indicates a slight increase in corrosive damage in the 7" casing interval logged." Attachments/Supporting Documents The AOGCC Mechanical Integrity Test Form (Attachment 1). The casing/tubing pressure data (plotted) for the performed SAPT (Attachment 2). PDS Caliper Graphical Comparison Report (Attachment 3). Overall Summary Conclusion -the SAPT conclusively demonstrated that the tubing-casing annulus is mechanically competent and no leak paths are present above the packer. The condition of WD-02 and CD1-19A are sound, with full mechanical integrity. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips According to 40 CFR § 146.8(a), an injection well de~iibnstrate~ ~t~na~ ;rnecnantcai v ~ L4 i integrity if there is no significant fluid movem~rit mtts `~.n urtdergrourtc~ ~~~r~e b€ ' drinking water through vertical channels add ac~rit to tie ~PJ.1 ectiotl ~~1~ tier~~ ~n accordance with Part II.C.3.b.2, the approved 2004 logging pfogra~ trlc~ude~ ' temperature and oxygen activation to detect and ~d~nt~fy flit mbvei~riett~ exrtuig the permitted injection interval. The Oxygen Activ~tit~n (OAS) techtuque vvas appxbvetl by `. the EPA beginning with the 2002 inspection program as a"n a~deptalile sub~tttut~ Cdr radioactive tracer surveys (RAT). In the event OA ev_aluatron of external'flmd movement is inconclusive, RAT logging maybe required. THough not regti~~d; ~ . . , Production Spinner Profile (PSP) was performed to obtain ~.i injection profile over the :. permitted interval. WD-02 Water Flow Log Results The results of the OA Water Flow Log (WFL) and PSP are summarized below. Operations Summary -Oxygen Activation Method (Water Flow Log) On April 12, 2010, Halliburton ran the Water Flow Log (WFL) in combination with a Spinner Profile Login WD-02 to evaluate fluid movement. ® Over the past 6 months, the average injection rate was approximately 1.5 bpm. • The injection rate used during the WFL was 2.5 bpm at an average WHIP of 2,500 psi. • The following is a summary of the WFL survey: Station Tool Depth ft Flow Detection Pump Rate Flow. Detected 1 9,459 - 9,472 Up 1.5 bpm No 2 9,514 - 9,552 Up 1.5 bpm No 3 9,612 - 9,627 Up 1.5 bpm No 4 .9,702 - 9,712 U 1.5 b m No 5 9,803 - 9,818 U 1.5 b m No 6 9,837 - 9,867 Up 1.5 b m No Figure 6. WLF Logging Stations: 1.5 bpm at 1650 psi The top perforation is located at 9,459'. The top of the Sag River is located at 8,937', which corresponds to the base of the confining interval or top of the injection interval. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhiliips ~ ~ EPA 2010 Annual MIT Report Page 6 of 7 Conclusion -.These surveys did not detect any fluid escaping the injection interval. This is consistent with caliper logging results. Operations Summary -Spinner Profile Log Following completion of the WFL segment, a spinner survey was conducted to analyze fluid movement as it exits the casing. All passes were logged at 1.5 bpm. Note that PBTD was determined as approximately 9,902' MD with a tag. The following is a summary of the results from this log: - Logged a depth correlation pass and verified tool performance. - Surveyed from .above the perforations at 9,000' to 9,900' (PBTD) - Passes run included: -Up and Down passes at 40/80/120 fpm - Surveyed stop counts at the following depths: 9,000'/9,400'/9,500'/9,575'/9,650'/9,750'/9,825'/9,869' Splits show the fluids leaving the wellbore in Figure 7. Perforated Interval Fluid 9,459 - 9,472 0% 9,514 - 9,552 0% 9,612 - 9,627 0% 9,702 - 9,712 17% 9,803 - 9,818 83% 9,837 - 9,867 0% Figure 7. Percentage of Fluid Leaving Wellbore Conclusion -The splits shown identify the perforation intervals from 9,803'-9,818' NID as the primary location of fluids exiting the wellbore. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhillips EPA 2010 Annual MIT Report Page 7 of 7 CD1-19A Water Flow Log Results Operations Summary -Oxygen Activation Method (Water Flow Log) On April 12, 2010, Halliburton ran the Water Flow Log (WFL) in combination with a Profile Log (PFCS) in WD-02 to evaluate fluid movement. • Over the past 6 months, the average injection rate was approximately 1.1 bpm. • The injection rate used during the WFL was 1.1 bpm • The following is a summary of the WFL survey: It was determined that 100% of the fluids were entering the perforations below the fill at 11,472' MD. Given that the tool was not able to get past the first perforation no splits were determined. The SpectraFlow tool was logged to determined the upflow behind the 7" casing perforations. The tool was run at 11400' MD, 11425' MD, and 11450' MD to complete an impulse test. The impulse tests show no water flow up behind the casing. ConocoPhillips Alaska, Inc. is a Subsidiary of ConocoPhiilips • A ~ °. Attachment 1 Mechanical Integrity Test Form Attachment 2 Digital IA Pressure Plot WD-02 SAPT Test: Passed April 10th, 2010 4000 3500 3000 'v~ a 2500 N d L a N 2000 c a 1500 L 1000 500 0 Test Start \. Cest End ~.. • • • • • • 4:48 AM 6:00 AM 7:12 AM 8:24 AM 9:36 AM 10:48 AM 12:00 PM CD1-19A SAPT Test:Passed Apri 111th, 2010 .~ n. ai L N N d L a c a w Test Start \. Test End • • • 2500 2000 1500 1000 500 0 7:12 AM 8:24 AM 9:36 AM 10:48 AM 12:00 PM 1:12 PM 2:24 PM • Attachment 3 PD S Caliper Graphical Comparison Report • • lti~ eIE: l•1'D-02 FEId: A€pmE Coi~tpany: ConocoPhiBlips Alaska; Inc. Country: US,4 Maximum Recorded Pei~e~ratian Can~parisan To Previous S.un'Ey Qate: .ipr+l 10, 2014 P(EY. Date: .~;.ril 3 S, 2008 Tool: L1Eh~ h4FC 44 Igo. 21$451 Tubing: ?' 20 tb L-S4 BTCi14 Qverlay Differe~ice Oiif. in h4az. Pen. ~niils) -1 Q,7 -54 0 50 54,E 1 11 E z .Q 21 31 -50 -25 0 27 50 .~tprax, Corrosion Rate gimpy} Attachment 3: WD-02 Caliper Comparison of Casing • L'L'EII: CDt-19A Feld: AlRine Companw. ConocoPhilfipsAlsska fnc. Country: USA Maxin~ti~m Recorded Penetration Comparison To Previous Surrey Dn~: Anri110, 2014 Prev. Date: Seatemher #, 2047 Too[: U1~1' h'i{=C 2~ No 218527 Tubixtg 3-5' 93 Ib !$0 EUE SRD pr~erlay A4ax. Rec, Pen. Cmitz) 0 i0 t00 150 200 250 1 11 21 31 ~1 51 fi0 70 80 40 100 110 120 150 140 150 ~ 160 3 170 z 180 ~~ 140 200 110 - 220 z3o 2:~0 -_ 250 260 270 277-3 287 247 _ 307 317 s 32J ""'~' 337 3.13.1 iApril 10, 2010 ^September ~, 2007 Di'feret3ce Dif#, in Max, Pen. (mils) -200 -1 D!0 0 100 200 I ' t1 , 21 31 ~1 _ 51 . -" i b4 SO ~- 90 _ 100 110 120 130 - 1 ~0 -- 150 4 160 ., 1,0 2 150 •0 190 200 21D 224 234 2ao _ 250 260 270 77.3 257 297 307 317 _ 337 _ 337 ' -- -J7 -35 4 35 77 ,'kpprox. Con•a9ion Rate (mF}•1 Attachment 3: CD1-19A Caliper Comparison of Tubing Attachment 4 • Wellbore Schematic • ConocoPhillips Alaska, Inc. ALPINE VItD-02 ,: _ _ _ Y 7vewc API: 501032024500 We(IT DISP An le TS: d Q (D-7975, 00:4.500, SSSV T e: YP WDRP Ori Com letion: 9 P 4!4/1999 Angle TD: eo 14 de ~ 10255 g 103.956) Annular Fluid: Lest WIO: Rev Reeson: Reset INJ VLV Reference Lo Ref Lo Date: Lnst U ate: 4/16/2008 PROD Last Te : 9909 TD: 10255 ftK8 ~~"~ .Last Te Date: 5/29/2005 Max Hole An le: 20 de 5450 oD:7.fiu, Casi Stnri =~AL'L'~' _ rah. ~:- _ ~i - -;~- , " wt:z9.7D) Descri ion Size To Bottom 1YD Wt hreea Grode 1 _ CONDUCTOR 18.000 0 137 137 82.58 H-40 1NELDED SURF CASING 9.625 0 2800 2782 36.00 J-55 BTC-MOD PROD CASING 7.825 0 1564 1570 29.70 L-80 STL-FL PROD CASING 7.000 1584 10244 9901 26-00 L-80 BTCM Tu6i'° ;Sinn- '~T(1BIIJG a;~ - ~z,."~,,-~ =Y'~"~ ~ ~ ~~ sue'..: ¢e o om r raoe rasa 4.500 0 7975 7729 12.60 L-60 IBTM S STL-FL PROD z:a ~, PBrrtO(8Ef0~15'SU~TIR1~ -- ery - ,._ Ta,,.„5,-`,-v~„'• ~. -; _ - ~ 'B-h-.^`'Te~~we~ v~ - ~~ Hess-toz4s Mterva one tus t Date a mmeM . oD:7.Dw, 8459 -9472 9144 - 9156 13 6 4/9/1889 IPERF 3 3!8 HSD' 60 de h wtz6.DD> 9514 - 9532 8197 - 9214 18 6 419!1898 IPERF 3 3I8 HSD; 60 d h 9532 - 9552 9214 - 8233 20 6 4l8I1889 IPERF 3 318 HSD; 80 d h 8612 - 9627 9281 - 8305 15 6 46/1899 IPERF 3 318 HSD- 60 d h 8702 - 9712 8377 - 9387 10 6 4!8/1899 IPERF 3 3!8 HSD- 60 d h 9803 - 9618 9474 -9488 75 6 4/8!1899 IPERF 3 318 HSD- 60 de h - 9837 - 9867 8507 -9536 30 6 4I7l1999 IPERF 3 3!8 HSD' 60 de h 9876 - 9696 9545 - 9564 20 6 4!7!1999 IPERF 3 318 HSD- 60 d h 99170 - 9920 8588 - 9567 20 6 4/7/1938 IPERF 3 3!8 HSD: 60 de h "m - 10017 - 10047 9681 - 8770 30 6 4/7/1999 IPERF 3 3!8 HSD- 60 degph _ (7s4tas4z. ' 'Ot}®t u .5~ „v ui =~eic . `'Ji=VNELRY~~':~'*~a i~' . ti-- '?"'~, t '''~~'~~..~~,~' ~,< -w ~~ 00:4.560} ~ ' - . De th TVD . T e Des cri lion ID VALVE (7941-7942, . ,r ?: 1200 7193 CABLE DHH ELECTRICAL HEAT TRACE CABLE SET 0 - 1200' TVD 0.100 003.812) _ _ 1355 1345 NIP CAMCO'DB' NIPPLE 3.612 1355 1345 VALVE A-1 INJECTION VALVE SN ~ HRS-44 set 4!15!2008 1.250 7864 7623 PKR BAKER SABL-3 PACKER W/KBH-22 ANCHOR SEAL 3.937 7941 7696 NIP HES'XN' NIPPLE 3.812 7941 7698 VALVE 3.75" HES STANDING VALVE set 12/24i20D4 3.750 7975 7729 WLEG BAKER WIRELINE RE-ENTRY GUIDE 4.120 wt.Ec (7975-7976, on:s.teDy Pen (9458-9472) Pert (9514-9572) Pert (95325552) Pcrt (961b9~7} Pen (97025712) Pert (98035818) Pert (99375867) Pert (9876-9896) Pert (99059920) PM ;700'17-10047) • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile /Water Flow Log: CD1-19A Run Date: 4/12/2010 ~ ~- ~ a~ ~- o~ 6 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CDl-19A WFL/IPROF Data in DLIS/LAS format, Digital Log file, Interp. report 1 CD Rom 50-103-20294-01 Injection Profile /Water Flow Log (field print) 1 Color Log 50-103-20294-01 SpectraFlow Oxygen Activation Log (post-processed) 1 Color Log 50-103-20294-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ~ 9(0.5 ~ n May 7, 2010 rafael.barreto ,~ a ;'~ Date: MAY ~ i 2010 Signed: .. ~° a '. n U ff Is>~~LL sL.~E.7° 1~. PrtoAcrive DinyNOZric Seevices, INC. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. -~ Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 :x; ' ~"'' ~' `~ `' °+ ' Kt: ~ ~1 ~~+'r' Fax: [907) 245-8952 u 1) Caliper Report 10 Aprv10 CD1-19A EDE 50-103-2029401 2) ~~( 6 Signed Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCWORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~dsanch®ragefa~mer~orv9op.eflrta WEBSITE:3nnAr~r.~rernoryio~a.~om C:~DocumenE and Settings\IIiane WilliamsiDesktop\Transmit_Conoco.docx Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Saturday, April 17, 2010 5:09 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: EPA witnessed tests on WD -02 and CD1 -19A Attachments: CRU WD -02 04- 10- 10.xls;, , 9A 04- 11- 10.xls All, O ®— O '-* Q Attached are the test forms for the EPA witnessed tests that were performed on WD -02 and CD1 -19A. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 4'4 4/7/2011 ill • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brookst@alaska.gov; tom.maundertgalaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT t PAD: Alpine / CRU / CD1 DATE: 04/11/10 OPERATOR REP: Jared Brake - CPAI AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD1 -19A Type Inj. N TVD 6,633' Tubing 2,850 2,850 2,850 2,850 Interval V P.T.D. 2000400 _ Type test I P Test psi 1,658 Casing 515 2,224 2,101 2,173 P /F_ P Notes: Annual EPA MITIA witnessed by Thor Cutler OA 350 381 382 381 AOGCC waived right to be present 45 min TIO= 2850/2167/382, 60 min T /I /0= 2850/2166/380 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test I Test psil Casing P/F Notes: OA P.T.D. Type test I Test psi Tubing Casing Interval P/F Notes: OA P.T.D. Type test I Test p Casing Interval P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle 1= Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 CRU CD1 -19A 0411- 10.xls ConocoPh i I I i ps Alaska, Inc. January 25, 2010 • Lynn DeGeorge. Senior Environmental Coordinator 700 G Street, ATO-1756 P.O. Box 100360 Anchorage, Alaska 99510-0360 Phone:907-263-4671 Fax: 907-265-6715 Mr. Peter Contreras Certified Mai! Supervisor, Ground Water Protection Unit 7008 0150 0002 1586 9381 U.S. Environmental Protection Agency (OCE-082) Return Receipt Requested 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 ~ ~ ~ I~ ~,_? '. ~~ RE: Class I Well Permit #AK-11003-A (CD7-19A ~4O-- Owl "~""``~~~ ~ `' ~~~~ ~C ass I Well Permit K-11003-B (WD-02) ~C.~~ a 5 ~ ~ . f ~„ ~ _~0gll€ p rd th Biennial Re ort - 3 and 4 Quarters, 2009 ~ ~ - ~ E i; ~ I . , :~;. Dear Mr. Contreras, On behalf of ConocoPhillips Alaska, Inc., enclosed is the Alpine Class I well report for the third and fourth quarters of 2009 for Class I Well CD1-19A (AK-11003-A) and WD-02 (AK-11003-B). Pursuant to requirements in Part II.E of the subject permits, the following information is provided: • Report Certification • EPA Form 7520-8, Injection Well Monitoring Report • Graphical plots of continuous injection pressure and rate monitoring • Raw monitoring data in electronic format • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results ~+~~ ~~~ ~ ~'~~~ • Other reports and back-up information • Any other test required by the director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone numbers or address. Sincerely, [ri j c (~ :.{ ~~ 1 c~~~~~~~ `~. ~ ~ ~~6~~ ~ ~ ~~ Lynn DeGeorge Senior Environmental Coordinator Enclosures Recent CPAI MITs ~ • Page 1 of 1 Regg, James B (DOA) ~ ~~ -- ~C From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, April 08, 2009 8:18 AM ~P(~~ ~ I ~ l~~ To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Recent CPAI MITs Attachments: MIT KRU 3K-22A 04-05-09.x1s; MIT CRU WD-02 04-07-09.x1s; MIT CRU CD1-19A 04-07- 09.x1s «MIT KRU 3K-22A 04-05-09.x1s» «MIT CRU WD-02 04-07-09.x1s» «MIT CRU CD1-19A 04-07-09.x1s» Attached for your records are recent ConocoPhillips' MITs. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/8/2009 ~~ Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Conoco Phillips Alaska ~~ ~ ~ ~f o CRU CD1-19A 04/07/09 Ives/Colee • Packer Depth Pretest Initial 15 Min. 30 Min. Well CD1-19A Type Inj. W TVD 6,633' Tubing 3160 3120 3050 3005 Interval O P.T.D. 2000400 T pe test P Test psi 1658 Casing 540 '`2120 1980 X1980 P/F P Notes: Annual EPA MIT witnessed by Talib Syed OA 600 600 600 575 AOGCC witness waived by Chuck Schieve Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 2009-0407_MIT_CRU_CD1-19A.xls Page 1 of ~ • • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com) Sent: Tuesday, October 07, 2008 1:43 PM To: Maunder, Thomas E (DOA) Subject: RE: Change of Status CD1-19A (200-040) Tom, You are correct. There was some injection between January 14th and April 6th. Perry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 07, 2008 10:49 AM To: NSK Well Integrity Proj Cc: NSK Probtem Welt Supv Subject: RE: Change of Status CD1-19A (200-040) Perry, I presume that injection occurred between January 14 and April 6, correct? Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, October 07, 2008 10:34 AM To: Maunder, Thomas E (DOA) CG: N5K Problem Well Supv :~~,,4~~6~ ~, `3 ~,~„ y{ ~ ?fir Subject: RE: Change of Status CD1-19A (200-040) Tom, Sorry for the delay. MJ and myself were out of the office for training. Regarding the status change, Thor Cutler stated that, in the EPAs eyes, the status change is effective as of the signing date of the permit. Under that direction the official date of status change is January 14th 2008. -- Additionally the first Class I injection in CD1-19A occurred on 416!08. Let me know if you have any other questions Sincerely Perry Ktein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 10/7/2008 Page 1 of 1 • Maunder, Thomas E (DOA) U From: Maunder, Thomas E (DOA) Sent: Tuesday, September 30, 2008 9:06 AM To: 'NSK Well Integrity Proj ; 'NSK Problem Well Supv'; 'NSK Well Integrity Field Supv' Subject: Change of Status CD1-19A (200-040) All, I am reviewing the 404 documenting the change in status of this well from Class II to Class I. When was the effective date of the change? i don't find any date noted on the form. Thanks in advance. An email response is fine. Tom Maunder, PE AOGCC 9/30/2008 ~~.~ STATE OF ALASKA ~ ~P ~ ~ ZO08 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPEIOI~IS~s ~°~'s• ~ommiss;olz 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ ' the ^ Class 1 well status Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ v Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 200-040 ' 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20294-01 ' 7. KB Elevation (ft): 9. Well Name and Number: KBE = 52.T RKB CD1-19A ' 8. Property Designation: 10. Field/Pool(s): ul~~ iRt~ .~'`~ ADL 25558, 25557 & 25558 Colville River Field / AI i 9 • $•D$ 11. Present WeII Condition Summary: Total Depth measured 11956' feet true vertical 9595' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2772' 9-5/8" 2825' 2393' PRODUCTION 11894' 7" 11947' 9586' Pertoration depth: Measured depth: 8750' - 8760', 8990' - 9000', 11463' - 11483', 11504' - 11520', 11720' - 11740', 11749' - 11763', 11768' - 11776', 11780' - 11794', 11800' - 11813' true vertical depth: 6692' - 6699', 6868' - 6876', 9116' - 9136', 9156' - 9171', 9366' - 9385', 9394' - 9407', 9412' -9420', 9424' -9437', 9443' -9456' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10792' MD. Packers &SSSV (type & measured depth) HES THB prod. Pkr @ 8670', HES THB prod. Pkr @ 10716' No SSSV. MCX In j vavle set @ 1795' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-McF Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation na na na na na 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WIND ^ WDSPL^~ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Brian Barreda Printed Name ian Barr Title Production Engineer ~ ~/~~ ~ Signature .Phone Date / ~ ~~ 265-6036 Pre red b Jeanne L. Haas 63-4470 Form 10-40 Revised 04/2006 ~ ' 1"'~ ~ ~~~,, (" r~ 2~0~ Submit Original O ly S~/~ ~,., f ~' ~, 7 f p EPA witnessed MITIA forms for CD-19A & WD-02 Page 1 of 1 Regg, James B (DOA) • • From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, April 15, 2008 2:32 PM 1~~~~ ~ ltbl~`~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: EPA witnessed MITIA forms for CD-19A & WD-02 Attachments: MIT CRU WD-02 04-14-08.x1s; MIT CRU CD1-19A 04-14-08.x1s; MIT CRU CD1-19A 04-15-08.x1s Tom, Jim, & Bob Attached are the EPA witnessed MITIA forms for compliance testing on CD1-19A(PTD 2000400) and WD-02 (PTD 1982580) that were done on 04/14/08 and 04/15/08. The two tests done on CD1-19A on 4/14/08 were considered a passing test by the EPA representative as the pressure loss was less than 10% over the 30 min test, however CPAI was not satisfied the sowed stabilization which we believe was due to constant change in the injection temperature during the test. CPAI elected to shut the well in overnight and let it thermally stabilize, then perform another MITIA to verify integrity. The test form on 04/15/08 shows the passing test results. Please let me know if you have any questions. «MIT CRU WD-02 04-14-08.x1s» «MIT CRU CD1-19A 04-14-08.x1s» «MIT CRU CD1-19A 04-15-08.x1s» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 659-7224 Pager (907} 659-7000 pgr. 909 ~~Rih~ APR ~. `~ 2008 4/16/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska lnc. "~ ~ ~l(~Cz~~ FIELD /UNIT /PAD: Alpine /CRU ! CD1-19A ~~~~ 6 DATE: 04/15/08 OPERATOR REP: Bates/Colee - AES AOGCC REP: Waived right to be present by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well CD1-19A Type Inj. N TVD X6,633' Tubing 660 675 675 675 Interval V P.T.D. 2000400 Type test P Test psi X7100 Casing 972 2,111 2,081 2,078 P/F P Notes: Class 1 Injection Well OA 323 359 360 360 Yearly test per EPA Permit AK-11010-A EPA witnessed by Thor Cutler Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I = {ndustrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT CRU CD1-19A 04-15-08.x1s • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. ~ ¢//~'l~ Alpine !CRU / CD1-19A ~~ 04/14/08 Bates/Colee - AES Waived right to be present by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well CD1-19A Type Inj. I TVD /6,633' Tubing 2,700 2,700 2,700 2,700 Interval V P.T.D. 2000400 Type test P Test psi X2100 Casing 748 /2,135 2,036 1,958 P/F F Notes: Class 1 Injection Well OA 388 438 430 418 Yearly test per EPA Permit AK-11010-A 45 min T/I/0=2700/1904/408, 60 min T/I/0=2700/1860/399 Well CD1-19A Type Inj. I TVD 6,633' Tubing 2,700 2,700 2,700 2,700 Interval V P.T.D. 2000400 Type test P Test psi °``1100 Casing 1,860 :2,130 2,091 2,060 P/F F Notes: EPA witnessed by Thor Cutler OA 399 408 401 396 EPA passed test with less than 10°~ loss over 30 min test. Elected to re-test once well thermally stabilizes on 04/15/08 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT CRU CD1-19A 04-14-O8.xls ADEC Notice of Disposal CD~9A • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 01, 2007 9:28 AM To: Jim Regg Subject: FW: ADEC Notice of Disposal CD1-19A (200-040) --~-~-- Attachments: ADEC App.PDF Jim, FYI. I wiii place a copy of the document in the file for CD1-19A and the order file.. Tom Page 1 of 1 From: Charton, Jason T. [mailto:Janon.T.Charton@conocophillips.com] Sen#: Monday, October 01, 2007 9:09 AM To: cutler.thor@epa.gov; tatib syed; Inukapigak@kuukpik.com; Maunder, Thomas E (DOAj Subject: ADEC Notice of Disposal CDi-19A «ADEC App.PDF» Jason Charton PO Box 100360, ATO 1756 Anchorage, AK 99510-0360 Phone: 907.263.4978 Fax: 907.265.1515 ~~ ~~ {~~~ NC1~ ~. 20G7 10/1/2007 ConocoPt~illips Alaska, Inc October 1, 2D07 Mr. Shawn Stokes Manager, Wastewater Discharge Program Alaska Department of Environmental Conservation 555 Cordova St. Anchorage, AK 995D1 RE: Class i We11 Apptica#ion WeH CD1-19A Dear Mr. Stokes: Jason Charton Senior Environmenta4 Coordinator 700 G Street, ATO 1756 P.O. Box 100360 Anchorage, Alaska 99510-0360 Phone 907.263-4978 Fax 907.265.1515 Cert~ed Mail 7001 251 D OD02 9588 7849 Return Receipt Requested ConocoPhillips Alaska, Inc. hereby submits a Notice of Disposal for an existing disposal well at the Alpine Oilfield. The well is known as CD1-19A. It is currently permitted by the State of Alaska Oil and Gas Conservation Commission as a dedicated Class 11 disposal well. CPAI is permitting the weA for Class I disposal. The Environmental Protection Agency ("EPA") Underground Injection Control ("U!C°) permi# will be forwarded upon receipt. Please find the enclosed $275 application fee, EPA UIC permit application binder and form 2005DB0001. Should you have any questions or need additional information, please feel free to contac# me at the numbers or address listed above. Sincerely, ason Charton Senior Environmental Coordinator Enclosures Cc: Thor Cutler -EPA (electronic wio binder) Talib Syed - TSA, Inc. (electronic wio binder) Tom Maunder - AOGCC (electronic wia binder) Isaac Nukapigak - Kuukpik (electronic w/o binder) • STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION_ DIVIION OF WATER ~ NOTICE OF DISPOSAL FOR CLASS i INJECTION WELL 2005DB000'1 See General Permit, for detarils on etigibility, requested application information and permit requirements RESPONSIBLE PARTY (owner, operator, or person responsible for overall management ofthe roject): First Name: Jason Last Name: Charton Phone Number: 907.263.4978 Com an Name: ConocoPhilli s Alaska, Inc. Fax Number: 907.265.1 S I S Mailin Address: PO Box 100360, ATO-1756 Ci Ancho e State: AK Zi : 99S 10 Email Address: 'ason.t.charton Conoco hilli s.com ON SITE CONTACT: First Name: Wend /Jodi Last Name: Mahan/Smith Phone Number: 907.670.4423 FACILITY: NAICS Code former l the Standard Industrial Code SIC) :221111 Facili Name: AI ine Oil Field Phone Number: 907.670.4423 Mailin Address: PO Box 100360, ALP 14 Fax Number: 907.670.4205 City: Ancho a State: AK Zi : 99S 10 Ph sicat Address:. North Slo CONSULTANT: First Name: N/A bast Name: N/A Phone Number: N/A . Company Name• N/A Fax. Number: N/A EPA CLASS I INJECTION WELL PERMIT NUMBER: Pending Beginning Date: T131) Ending Date: TBI) INJECTION FLOW RATES AND VOLUME: Avera e: SOM Gallons Per D Maximum: 200M Gallons Per Day Estimated Total Injection Volume: 874 MM Gallons over 20 years LOCATION OF INJECTION POINTS}: Area(s): Colville River Unit Name of formation and depth(s): Ivishak Formation 9200 ft Latitude /Longitude of Injection Point(s) in decimad degrees: We11: CDl-19A Latitude: 70.35331530001 Longitude: 150.93035103966 Well: Latitude: Longitude: Well: Latitude: Longitude: Well: Latitude: Longitude: LatlLong Coordinate Source: ^ Internet ^ MAP ®GPS/Survey Datum: NAD 27 9/26/2007 Page 2 ADEC 2005DB0001 NOD MAPS OF INJECTION POINT(S): Submit to ADEC two maps: a map that shaves the general location of the facility and a detailed map that shows the facility layout monitoring wells, injection wells, drinking water wells, abandoned wells, water bodies and other pertinent information within the area of interest (0.5 mile radius of the facility). Maps may be drawings, USGS maps, or aerial photographs and must include a scale. ~ Maps attached GENERAL DESCRIPTION OF TIC PROJECT: Describe where the wastewater to be injected comes from; the chemical, physical, and biological characteristics of the wastewater; and what if an wastewater treatment will be rformed. See attached UIC ap location far r uested detail. " OTHER PERTINENT INFORMATION: Describe unusual circumstances that ma aid in rmit rocessin . None RENEWAL REQUEST: LJ Current ADEC vermit Number: N/A If any operation or procedures have changed since the issuance of the last general permit authorization or individual ermit lease describe below. N/A WASTEWATER PERMIT APPLICATION SIGNATURE: The information given on this application is complete and accurate to the best of my knowledge. gnature Date Jason Charton Senior Environmental Coordinator Printed Name Title If it is not possible to submit this Notice of Disposal electronically, please mail or fax the Notice to the address below. Alaska Department of Environmental Conservation Division of Water 555 Cordova Street Anchorage, Alaska 99501 Telephone (907) 269-7500 Fax (907) 269-7652 Email: WA Uermit(a7dec.stf MEMORANDUM • To: Jim Regg ~~~~, 1'~Z-~ ~u 7 P.I. Supervisor r >;ROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~ DATE: Wednesday, September 19, 20 SUBJECT: Mechanical Intee ity Tests CONOCOPHILLIPS ALASKA INC CDl-19A COLVILLE RIV UNIT CDl-19A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name' COLVILLE RIV UNIT CD1-19A API Well Number: 50-103-20294-01-00 Inspector Name• Bob Noble Insp Num' mitRCN070917070954 Permit Number• Zoo-oao-o Inspection Date• 9/13/2007 Rel Insp Num: Packer Depth Pretest Initial l5 Min. 30 Min. 45 Min. 60 Min. Well CD]-19A 'Type Inj. N I TVD 6633 ' I IA ~ ] ]00 ~-2000 1970 i 1970 P.T ~ 2000400 ~TypeTCSt ~ SPT ~ '~eSt pSl ~ 2~ DA ~ 300 ~ 400 j _J_ 380 380 ~ ~ __ ~ ~ Interval pT~R P/F P ~. 925 ~ 925 ~I Tubing , j 925 925 ~ I Notes' Disposal well, 2 year test. ,~~ccice~-`7!,'~ CSC 7i~' r'`~~ ~3117~zc~_, Icy--4ca- ,f n Wednesday, September 19, 2007 Page 1 of 1 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Christine ~ahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/~echanical Logs and/or Tubing Inspection(Caliper / ~ The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmrttalletter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2J 3) 4) 5) 6J 7J 1 Report / EDE 1 Report / EDE C01 - 19 CD1 - 40 Ca6per Report Caliper Report 04Sep.07 03-Sep.07 ~óO - c:J..¡.ö It- 15~ I Ò 10/1 - cH4 ~ I 5l/ II SCANNED SEP 1 32007 RE Signed: ~Jjr--- Date : ~FP 1 0 _?" 00' _;1 v__¿ _-'-" Print Name: ~11 (ì 6ft ~~ o~ YIiJ.a. {,uA.1f {ì t., Oil & Gas Cons, Commission PROACTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT AD SUITE C, ANCHORAGE, AK 99518 PHONE: {907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _Copy _ 00 ]DSANC.2OxxIZ _ Word\Distribulion\TransmittaC SheeIs\Transmit_ Original,doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 4, 2007 9509 1 3.5" 9.3 lb. L-80 Tubing Well: CD1-19 Field: Alpine State: Alaska API No.: 50~103-20294-01 Top Log Intvl1.: Surface Bot. Log IntvI1.: 10,792 Ft (MD) Inspection Type : COMMENTS: Corrosive 8, Mechanical Damage Inspection This caliper data Is tied into the 3.5" WLEG @ 10,792' (Drillers Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing Jogged is in good condition. No significant wall penetration, areas of significant cross sectional wall loss, or significant 1.0. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>18%) are recorded in the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross sectional wall loss (>13%) are recorded in the tubing logged. MAXIMUM RECORDED 10 RESTRICTIONS: No significant 1.0. restrictions are recorded in the tubing logged. I Field Engineer. S. Carpenter Analyst: B. Qi Witness: T. Crumrine ProActive Diagnostic Services! Inc. I P.O, Box 1369! Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 UTe... 800 - 04D ~'6"410 I I I We/!: Field: CD1·19 Inc. I USA Nom.OD 3.5 ins Weight 9.3 f Grade 8< Thread L-80 I I Penetration and Metallos!! wail) penetration body metal loss I 400 300 200 100 0 o to 1"1" 1 to 10 to 20 to 40 to over 10% 20% 40% 85% 85% I I o o 16 22 171 321 I I 80 I 60 40 I 20 o I isolatc>d general line ring pitting corrosion corrösion corrosion I o I I Date: Tool Type: Tool Size: No. of Ana! st: NomJD 2.992 ins Bottom of Analysis Overview page 2 I I rt Region Analysis 4,2007 UW MfC 24 No. 212330 1.69 24 B. ¡ Nom, 3.5 ins Upper len. 6.0 ins penetration Profile wall) 101 201 299 = 343.4 metal loss 50 Lower 6.0 ins 100 I I I I I I I I I I I I I I I I I I I Wall: Upset Wan: Nomina! I.D.: 3.5 in 9.3 0254 in 0.254 in 2.992 in Jt. Depth Joint No. Pen. (Ins.) .1 77 7 h3 3 99 4 135 ~ g 14 ~$ 0..0310 11 3.1 R=;= 12 '179 13 410 O.íFf 14 441 0.1141 15 47J 16 '11n 17 533 18 564 19 594 20 625 0 11 657 0 0.0416 '11 6.).031? 23 7 æ ;~2 ~; om 27 843 0 0.03 I 28 872 0 om ¡ '9 30 31 32 3'i 34 3~ 36 37 38 ,q 40 41 42 43 44 45 46 47 48 49 50 .0 933 961 991 1022 1052 1084- 1114 1146 1177 1706 1.237 1269 1300 1331 1362 1393 1424 1454 1485 1517 1548 o o o o o o o o o n o o 0.02 0.00 I 1 ~ JOINT U 1.-80 Pen. I !%!~~-.-¡;;¡ Min. I Loss 1.0. (Ins.) 51:1 ..2.J1'i "12\ ~ 2.95 ¡ .95 /.94 7.94 2.Q5 2.96 i~i 2.95 '-- '-- '-- '--- L13 ~ 2.94 2.95 2.96 L 1.96 ,,1 ~:i Wen: Reid: Survey PUP Shallow nitti...". low nittin2. allow rut1Ín2. Shallow nìtlinQ. nìtti"" . itlimI. Shallow "¡tlina. "i!'li"",. Shallow nittina Shallow nit [rul. Shallow rut I1!Z. Sh"U':;w nit1 mY. Shallow ",¡tlinG. 9 Shallow rutlÎfIQ. Shallow nittinll. CD1·19 USA 4,2007 Commen!5 Inc. ,,,;" ! p'~fi¡e \ to Will' J o 100 I I I I I PDS JOINT ULATION SH Wall: Upset WaR: Nominal I.D.: 35 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Wen: Field: CD1-19 Alpine ConocoPhißíps USA September 4, 2007 Inc. Survey Date: I I I I I Joint Jt. Depth Pen Pen. Pen lvk;¡;;r Min. h ,., '.:~.m"" No. 1.0, Comments '''I' \I" 'IV"'" (Ins) (Ins.) (Ins.) 0 50 100 51 1577 ~ 'i7 ¡ 1 h08 <::h~II~", "'¡'lina. S, I 1640 0.03 11 I:h"II"'M "'itiina. 54 11'.70 11 ~ 1701 \ ~ 1730 2.~ ~ 1761 -2ZJ. 1788 X NIPPLE 59 1821 0.0 60 11'1<;, 0.03 ;;;:Iv-Ik'w."'ittinu. 1'\1 1885 Shallow nitlim:r eft 1916 0.01 .5 1947 11 1:94 64 1 I ?(¡it. 6'1 J T 2.94 66 2 .94 67 )0 3 I .Qt:; Sh",¡¡",w,.,iUioa. 6R 7105 0 .97 69 2135 qa 70 2167 -¡:; .94 71 2198 P .96 72 JJ29 ' .96 73 2260 ì 74 2291 r¡ .j Hi n<>. 75 2324 76 2354 77 11M 0.02 -2 78 741q 003 10 :2 79 2450 0.03 f¡ 80 2481 ? Shallow nitlinq 81 . 2513 I 2.95 ~ I 83 J 2.93 84 2605 ì 2.95 85 2636 ( 0.03 3 / q, Shallow ",Wino It. DebOsits. 86 7674- ( 0.02 'J (¡~ 87 2707 ( 0.02 j 2.97 88 7738 I 0 2.96 89 2769 i ( ~ 2.96 90 27qq i ?,Q6 Shallow nitliml. 91 =1=:2830 2.96 92 7860 7.95 93 2892 2.96 94 29/3 =! 2.95 95 2954 3 Ii Shallow nitlinq. 96 298') 97 3016 0.04 Shallow Ditlinll. 98 3047 99 3078 I 0.04 2.94 Shallow n¡tlin". 2 R JOINT LATION SH I I I I I I I I I I I I I I I I I Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf l-80 0254 in 0.254 in 2.992 in Well: Field: Company: CQ1-19 Alaska, loe. USA 4,2007 Joint Jt. Depth Pen, Pen. PerL i\/1et;¡1 Min. Profile No. I(:::~(;t ;s 1.0. Comments ("/0 (Ins.) 0 50 100 100 3109 ) 2.Q5 101 -:¡14O 102 3171 tJ]¡ 3202 n (] 7' 3233 {) 12 1 105 3264 t .9 2.Q, 107 2.9 10 1.9 1õ9 3388 {) '-- 110 3419 111 34'>0 !1 1P 34.R1 113 3517 .0 114 0.01 ! 115 3581 0,02 116 3612 ittina. 117 3643 "5":9ïf DR 3674 9 -4 295 119 3706 2.95 ~736 t 0.03 7 1.<:15 ~768 0.02 . t 2.94 122 3799 003 .J 7 9~ 123 3831 mmI Shallow oiUimz. 174 3863 5 125 3893 o 4 P6 3977 u I 0.02 7 127 3958 ! 0.02 9 128 3990 ~ 2 % Sh"low"""., 129 4021 2.95 130 4053 if;i5 131 4083 002 It 132 4114 ! .04 1. ·t~na. 133 4145 W2 (, 134 4176 W311 (, 135 4206 136 4 3.7 137 4 '68 138 4: 99 139 4330 140 4360 nitiino. 141 4392 142 un 143 = ~44<¡i ¡ ~ Shallow nittiOQ. 144 ~ -:q3 145 0.03 ¡ :2 93 146 4547 0.D2 298 147 4578 , I ~C 2.92 14.R 4¡;OR ±± 7.91 149 4640 0 2.94 Body Metallos!> Body 3 I I I I I I I I I I I I I I I I I I PDS JOINT TABULATION Pipe: BodyWalJ: Upset WaD: Nomina! 1.0.: 3.5 in 9.3 ppf L..aO 0.254 in 0.254 in 2.992 in Well: C01.19 Field: inc. USA September 4, 2007 Joint Jt. Depth Pen. Pen. Pen. ¡Me!al Min. . Profile No. W. Comments wall) , I ::i (Ins.) 0 SO 100 'ISO 4671 2.93 151 4702 2.'14 152 4733 2.94 153 4763 ! I 002 2.96 154 4794 I 0.03 2.94 155 4824 2.96 1% ¡ 485" ! 2.95 157 ! 4.A87 ! ~ Shallow DÌttim!. 158 ¡ 4917 159 4948 7.93 160 4978 ~ 161 ~ 0.01 'i 162 0.02 9 9 2.93 163 {, 2.96 164 5103 I ~ 165 5134 I n 166 ~ 0 167 ! 0 --- -:¡ 94 168 5231 r u(i iT ~ 169 5264 I 0 7 I 170 0.D3 0 ft 2.93 171 5326 0.D2 ì I 172 5357 0.02 ~: ,: ' 1T'1 538Q 174 5419 175 5450 0.02 176 5481 0.00 ! 2.9A- 177 5511 o ±it ---' m 2.95 178 5542 - 2.94 179 5573 I-- 2.95 100 5605 ! 0.02 2.94 181 5636 ! 0.D2 2.95 182 5667 ! ! 7 2.9'> 183 5698 I 2 2.95 184 5729 ! 185 5760 ! ! I 186 5791 !III 187 5822 2.93 188 58"4 0.0 2.96 189 5M3 (tm 2.93 190 '>9 Hi =*= 0.01 2.95 191 5946 0.01 2.94 192 5975 0.02 2.95 193 6007 0 0.D3 13 2.95 Shallow DÌttim!:. 194 6039 0 m 293 195 6069 0 2.95 196 101 2.95 '\h"lIo\AI ,,¡tlina. 197 132 1ft 198 16, Om 199 6194 0.02 1(3 2.95 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Waft: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: C01-19 Alaska, !nc. Survey COUNrRY September 4, 2007 Joint Jt. Depth Perl, Pen. F'en, i 1\1elal Min. Profile No. (Ft.) (::~:E;I 1.0. Comments (% wall) (Ins.) 0 50 100 ~6225 0 ¡ 2.95 Shallow oiuÎrnt. 201 625'1 004 ) 2.94 Shallow oitiim,¡:. 202 6292 0.03 203 6323 0.00 204 2.93 205 4 2.94 206 6416 3 2.94 207 6447 0 5 2.95 208 6479 I n 94 209 6510 + 0 0.Q2 95 I 210 6571 g 0.04 4 Shallow oîtting. 211 0.02 93 212 C 0.03 Shallow oitlil12. 213 6633 ¡ () 0.03 2 Shallow oitlim:r. 214 6664 6 215 6694 i94 216 6729 ( 2.94 217 6761 0.02 ·¡i 296 218 6790 0.04 14 4 2.94 Shallow oittinSl.. 219 6811 0.ü1 5 2.94 220 6853 0.03 I 2.93 221 6884 0.Q2 q I 2,96 222 6915 0.03 ) Ji i 223 6947 0.0 4. 224 0.0: 225 70f 0.0: ) 226 70 ( 0 7:94 227 7071 n i I 2.95 228 7103 0 2.94 229 7 I 2.94 230 7 2.94 231 7197 0.02 2.95 232 7228 0 I 2.94 233 7260 0.04 2.94 Shallow oittinSl.. 234 7291 i 294 235 7322 2.94 Shallow pitting. 236 7353 5 2.93 Shallow oitlin!.!:. 237 7384 J 2 2.94 238 74L'5 0.02 I 1it 239 7446 om 2. 240 7477 0.01 ~.93 241 7'i08 0.02 242 7539 om 1: l :.: ¡ 243 7571 0 om 244 7602 0 0.03 245 7634 =+= 0,02 9 246 7665 =I 247 7696 4 2.95 Shallow oit!ÍI1S1.. 248 7727 0 q 2.96 Shallow oit!Írn!. 249 7758 0 1 2.93 Body Metal loss Body 5 Joint Jt. Depth Pen. Pen. Pere ¡\¡jeta! Min. No. Upset ¡.D. (Ins) (Ins.) (ins.) 2 ( 7789 nEÐm '.95 2 1 7820 (. 2.93 ') 2 7852 0.03 Tf 2.94 253 7879 0.03 =PF 2.93 ?"i4. Hi 0.03 255 ·OJ14 4 256 0112 t; 2">7 8004 ~ 258 003r:, n 2"9 8067 n 260 0097 0 261 8129 262 8159 263 8191 264 8223 265 8254 66 8785 h7 8-16 68 8347 269 8378 270 8410 271 8441 272 8472 :lli= ~~~~ 275 8566 276 8"96 277 8626 ~ 277.3 8685 278 8694 279 8726 200 8757 281 8787 282 8818 281 i 8849 I I I I I I I I I I I I I I I 285 286 287 288 189 290 191 292 293 294 1q<; 296 891 894 897 9007 9038 9070 9098 9129 9160 9191 91/1 9255 3.5 in 9.3 0.254 in 0.254 in 2.992 in 2" 2.94 Shallow nittincr. '94 2.93 2.94 2.93 294 PUP ~ PACKER ~ PUP 5 ¡ttina. 2.94 Shallow "Îtlina. -ffi- 2.97 2.94 2.92 Shallow "ittin"'. ~ Shallo\!V nitlÍna. 2.93 2.95 2.94 2.93 291 gg~ I:; '-"~ ~ ~ Shallow nitlina. l..oo .9 2.94 t o 0.03 0.0? o 0.03 0.02 O.O? 0.03 o 4 o ( i ( ( 0.01 0.û2 DiY o n m-04 ( 0.03 ( 0.03'11 ±±~11 n 0.03 0.03 ( 1 n o o ( 0.03 JOINT Well: field: Date: 5h"II..."" "itlincr. Sh "lln"" nitlino. Shallow ,,¡tlino. Sh:1l!ow"ittin". 511:111""" "iUna. 2.94 2.4 Shallow niftino. Shallow nitJir¡o. 'h"llow nit6no. 6 ULATION EIT CD1·19 ConocoPhilips Alaska, Ine. USA 4,2007 Comments "" ~ r-:;~¡e \ /0 Wdll, o 50 100 - I I I I Wall: UpsetWaH: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint jt Depth Perl. Pen. No. 'r (Ins.) 297 298 9316 299 9347 300 9378 ~ 94011 ( ~ 9438 0 303 9469 304 9499 305 9530 306 95t11 958 9 0 9650 310 91182! 11 31 I I I I 314 315 316 9871 317 I 9901 18 9932 31 I I I 321 322 323 324 325 326 ~ 330 331 332 333 334 335 336 1005 tOOS6 10116 10147 10178 10209 10240 10271 10302 10333 10364 10395 10426 10455 10486 9777 o o o ( ! 'j O. o 0.03 0.02 0.02 8 0.031' 10 8 9 0.03 10 9 I ,,340 341 1 342 1 0; 13 I 342. 1 343 1 0 .03 I I I Pen. . ,!v!el;¡/ Min. 1.0. (Ins.) """ I 2 ¡ 2.93 ¡ 2.93 I JOINT WeD: Field: w nittin2. Shallow oittimz. ¡ ·linlit. '-- 2.92 2.94 Shallow oittim. Shallow oitli!1ll. '--- Shallow rntlÌ!''IIl. :-- Shallow Ditlimz. - '--- 2.93 ¡tlinll. 2.9 2 2.94 i 2.91 Shallow nitûrJl,¡;. 2.93 2.93 ~ 2.92 2.92 2.93 2.91 2.9 PUP KER PUP .93 7 LA TrON CD1-19 USA 4, 2007 Comments Inc. o ,,,;0 ~~file \ II> "''''''1 100 m- W1 I I I I Wall: WaD: Nominal I.D.: 343.1 343.2 43 '} 34 .4 I I I I I I I I I I I I I PDS JOINT 3.5 in 9.3 ppf l-OO 0.254 in 0.254 in 2.992 in WeD: Field: Date; Joint Jt. No. 8 ULATION CD1-19 USA Comments Alaska, Inc. 4,2007 o 50 100 I lPINE CD1..19A I I I I I 16 12 I 20 6 6 Perl I (8900-9000) 13 12 I I I I I Perf 11463-114<!3) Perf I 11504-11520) Pelf 117'20-11740) I I Pelf 11700-11793) I I I . Con~illips Alaska, Inc . Jason Charton Senior Environmental Coordinator 700 G Street, ATO 1756 P.O. Box 100360 Anchorage, Alaska 99510-0360 Phone 907.263-4978 Fax 907.265.1515 RECEIVED JUL 2 5 2007 Alaska Oil & Gas Cons. Co-mmis. Certified Mail .Anchorage 7005 1820 0001 6483 2650 Return Receipt Requested July 23, 2007 Mr. Mike Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency (OCE-164) 1200 Sixth Avenue Seattle, WA 98101 ~oo - 0L1Q\ RE: No USDW Ruling Confirmation Data - Well CD1-19A Dear Mr. Bussell: The Environmental Protection Agency ("EPA") approved a Class I injection well, WD-02, at the Alpine Development Project ("Alpine") on February 3, 1999. The permit fact sheet documents EPA's no underground source of drinking water ("USDW") ruling for the Alpine field. ConocoPhillips Alaska, Inc. ("CPAI") anticipates submitting a Class I well permit application for an additional, existing well at Alpine. The well is known as CD1-19A. It is currently permitted by the State of Alaska Oil and Gas Conservation Commission as a dedicated Class II disposal well. Given that the EPA has ruled there are no USDWs in the Alpine field, CPAI believes a well specific ruling is not required to support the application. However, CPAI has enclosed the CD1- 19A salinity log and interpretive memo to support the previous ruling. CPAI respectfully requests EPA's confirmation that CD1-19A is located within a no USDW area. Should you have any questions or need additional information, please feel free to contact me at the numbers or address listed above. ason Charton Senior Environmental Coordinator SCANNED SEP 0 7 2007 Enclosures Cc: Thor Cutler - EPA Tom Maunder - AOGCC . . Conoc;Phillips Alaska, Inc. P. O. BOX 100360, ATO-1454 ANCHORAGE, ALASKA 99510-0360 Telephone 907- 265-1505 Facsimile 907- 263-4966 To: Don Andrews From: Wayne Campaign Petrophysicist Subject: Shallow Salinity analysis from CD1-19A Date: July 19, 2007 I have evaluated this well from the top of the logs to the top K-3 interval (4803' md, 3737' ss) for sand, porosity and water salinity. This memo will document those results. This well was logged with LWD neutron/density/resistivity/GR from 2822' md (2335' ss) to TD through the Ivishak. I have analysed this data with a standard model to derive volume shale, porosity and water salinity. This last curve was calculated using the Rwa techniques described in EPA documentation. All values were corrected for formation temperature and plotted in the attachment. The plot has volume of shale, input gamma ray and TDS curves in the first track. The TDS curve has been colored blue were VSH < 38%, thus highlighting any potential sands. Tracks 2 and 3 contain input curves and Effective Porosity. Only 2 very marginal shaly sand intervals are present in this section of the well. Average values of Shale volume, effective porosity and TDS are listed on the plot. Bot~noe igh shale content with effective porosities of 18%. Neither is likely to flow any fluids.· Iso, both calculate salinities in excess of 10,000 ppm NaCI. ¡ I SVI{)VJ In conclusion, there are no potential shallow fresh water acquifers in this well. r.fr If you have any questions or coments, feel free to call on me. Wayne Campaign Principal Petrophysicist ConocoPhillips Alaska, Inc. (907) 265-1505 1. ConocÓPhimps Salinity highlighted in Blue for Sands (VSH < 38%) in Track 1. . . SARAH PAL/N, GOVERNOR AI~ASIiA OiLAl'iD GAS lCONSERVATlON COMMISSION :'vIa; It, 2007 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907ì 276-7542 Mr. David Hansen HES Supervisor, Kuparuk and Western North Slope ConocoPhillips Alaska Inc. P.O. Box 196105 (NSK-45) Anchorage, AK 99519-6105 ~MAY 1620D7 Dear Mr. Hansen: The Alaska Oil and Gas Conservation Commission CAOGCC" or "Commission") has completed its review of an apparent misinjection of non-exempt fluid at Colville River Unit Well CD 1-19A. ConocoPhillips Alaska Inc. CCP AI") reported the apparent misinjection verbally and by electronic mail dated February 22, 2006. The apparent misinjection involved 5 barrels of diesel used in hydro-testing a gas line as part of its commissioning. The diesel was removed from the line after successful testing and mixed with production wastes prior to injecting into CDI-19A. Injection occurred on February 17, 2006. The Commission considers this review closed and intends to take no enforcement action for the apparent misinjection. The letter dated March 23, 2006 reported the results of CPAl's internal investigation and included the events leading up to the apparent misinjection. The Commission has reported this as a significant noncompliance on EP A Form 7540, Part IV (Quarterly Exceptions List) in its July 24, 2006 quarterly VIC performance report. While this represents a serious matter, the Commission is convinced the actions taken by CPAI were unintentional and of no consequence to well integrity and the continued geologic contìnement of fluids injected in CD 1-19A. The absence of fresh water aquifers underlying the Colville River Unit means the risk of contamination is nonexistent. The Commission is further satisfied with CPAl's initiative to self-disclose and investigate this incident, as well as to proactivel . plement corrective actions as referenced in the March 23,2006 letter. Sincerely, IJdA ¡;/~. è, I ~ """/-- '''1// r /~~ '-- Cathy/V Foerster Commissioner Daniel T. Seamount, Jr. Commissioner bbO-o'(ò . . Memorandum Date: May 11, 2007 To: Commissioner John Norman Commissioner Dan Seamount Commissioner Cathy Foerster File: Colville River Unit, Alpine Field File <6\ ,,\v1 ~1{l From: Jim Regg, Petroleum Engineer VIC Program Manger Subject: Closeout of AOGCC Review Potential Misinj ection of Diesel at CR U CD 1-19 A Background (copies in Alpine Field File, AIO 18B, and DIO 18) Record of verbal and electronic notice of potential misinjection dated February 22,2006; Letter from ConocoPhillips Alaska Inc. ("CP AI") dated March 23, 2006 (Alpine Development - CDI-19A Miss-injection of Non-exempt Fluid, 2/17/06); Mechanical Integrity Test results; Annual Alpine Oil Pool Disposal Well Performance Reports. Assessment CP AI notified the Commission of a potential misinjection of non-exempt diesel on February 22, 2006. Injection occurred on February 17,2006. The diesel in question was used to hydro-test a gas line being prepared for startup of operation by CP AI. Details of the events leading up to injection of waste fluids containing the diesel into Well CDl-19A (PTD 200-040) are outlined in a letter dated March 23, 2006. Approximately 5 barrels of diesel fuel were used in the hydro-testing of a gas line at Alpine because of its freeze protect characteristics, a necessary capability for f1uid used in testing of a flowline during February. This fluid would normally be removed from the line and manifested for some type of beneficial reuse or disposed of in the UIC Class I well WD-02 (PTD 198-258). On February 10, 2006 CP AI completed the successful hydro-test of the gas line and removed the diesel with an empty vacuum truck. The diesel was transported to and pumped into a temporary holding tank containing approximately 350 barrels of Class II wastes (generated from production operations). The resulting mixture was injected into Well CDI-19A on February 17,2006. The mixture of exempt and non-exempt fluids, including fluids such as diesel that exhibit hazardous characteristics is discussed in EP A 530-K-Ol-004, Exemption 0./ Oil and Gas Exploration and Production Wastes from Federal Hazardous Waste Regulations (January 2(02): "If, after mixing a non-exempt characteristic hazardous waste with an exempt waste, the resulting mixture does not exhibit any of the same characteristics as the hazardous waste, the mixture is exempt. Even ¡fthe mixture exhibits some other characteristic of a hazardous waste, it is still exempt." Investigation Closeout - Peial Misinjection of Diesel May 11,2007 . CP AI reported in their March 23, 2006 letter that the mixture of diesel and exempt Class II production wastes was non-hazardous as defined by the Resource Conservation Recovery Act. Ironically, had the same diesel been used for freeze protecting a wellbore or some other downhole activity, it would have been eligible for injection in the Class II well CDI-19A based on the common definition of a Class II fluid proclaimed by EP A (i.e., fluid that has been downhole). CP AI has implemented the following corrective actions in response to the apparent misinjection at CDI-19A: Included waste management and disposal options as part of pre-job planning for energy isolation projects; Reviewed the incident with all individuals involved; Issued an all-employee alert at Alpine that outlines the event and need for heightened awareness regarding proper waste management practices; Evaluated Class II injection procedure at Alpine to determine if additional pre-injection oversight is warranted. We have the opportunity to evaluate the effectiveness ofCPAI's corrective actions as part ofthe ongoing inspection and regulatory oversight for UIC Class II injection at Alpine. Well pressures (injection and annuli pressures) and injection rates are monitored daily and recorded manually by field personnel. Commission well records confirm that neither the geologic confinement of fluids injected nor the mechanical integrity of Well CDI-19A have been impacted as a result of the injection that occurred on February 17,2006. Further, there are no freshwater aquifers underlying the Colville River Unit (reference DIO 18 and AIO 18B) so the risk of contamination of freshwater is nonexistent. I recommend closeout of our review of this reported misinjection by sending the attached letter to CP AI. Note that I am recommending no enforcement action be taken against CP AI for the injection of a 355 barrel injection that contained the 5 barrels of diesel used for hydro-testing a gas line at Alpine. Timely, proactive and appropriate corrective actions implemented by CP AI relating to waste management practices at Alpine are sufficient to address this apparent noncompliance. Attachment 2 . P. O. BOX 196105 (NSK-45) ANCHORAGE, ALASKA 99519-6105 . v ConocoPhillips David W. Hanson/Warren Emerson HES Supervisor Kuparuk and Western North Slope 907 -659-7590 907 -659-7088 (fax) n1153@conocophillips.com (e-mail) March 23, 2006 James Regg State of Alaska Alaska Oil and Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 RE: Alpine Development - CD1-19A Miss-injection of Non-exempt Fluid, 2/17/06 Dear Mr. Regg: As per Area Injection Order No. 18A, October 7, 2004, ConocoPhillips must notify the Commission if it learns of any improper Class II injection (Rule 10 Notification). This letter is written to you as a follow-up to both a verbal notification to Mr. Tom Maunder and e-mail notice to you on February 22, 2006 regarding a potential miss-injection of approximately 5 bbls of non-exempt diesel fuel. This injection occurred at the CD1-19A, Class II injection well at Alpine on February 17, 2006. ConocoPhillips Alaska, Inc. (CPAI) has conducted an investigation of this event and determined the following: On the morning of February 10, 2006, a hydrostatic test was conducted on a gas line that CPAI is preparing for commissioning. Approximately 5 bbs of non-exempt diesel fuel was used to conduct the hydro test. The Operators involved reviewed the hydro test plan and effectively communicated this plan prior to conducting the hydro test. The hydro test plan did not address waste disposal options. A successful hydro test was completed and the 5 bbl of diesel was off-loaded to an empty bleed trailer (tank). An empty hydrocarbon Vac truck was used to haul the 5 bbl of diesel to a 400 bbl standup tank. The 5 bbl of non-Class II diesel was mixed with approximately 350 bbl of Class II, Exploration and Production (E&P) exempt fluids derived from Production drilling activities. The mixture of fluids was injected down CD1-19A via an injection skid associated with E&P waste management activities on February 17, 2006. Please note, while the injected fluids were not entireiy Class ii, they were not RCRA hazardous. CPAI's procedures, training and guidance have been developed to comply with applicable waste management permits and regulations. This includes instruction on proper North Slope waste manifesting procedures and a thorough review of the North Slope Waste Disposal & " Mr. Jim Regg March 23, 2006 . . Page 3 Reuse guide. The Operator who was responsible for the disposal of the diesel fuel had been properly trained on waste disposal and reuse options. Unfortunately, the Operator incorrectly manifested this non-exempt fluid to CD1-19A. The waste disposal manifest for this fluid was reviewed on February 22, 2006 by a CPAI Environmental Coordinator. It was determined at this time that a potential miss-injection had occurred and your office was contacted. As a result of CPAl's investigation, several corrective actions have been implemented. · An Operator template for Energy Isolation projects at Alpine has been revised to address waste management and disposal options as part of all pre job planning. · This incident has been thoroughly reviewed with all individuals involved. · An Alpine-wide alert was put out to for all employees in order to discuss this event and heighten awareness regarding proper waste disposal and reuse options. · The Class II injection procedure at Alpine is being evaluated to determine if additional pre-injection oversight is warranted. Though CPAI recognizes that this incident is a serious one that requires self disclosure to the Commission, it is important to note that CPAI does not feel that the environment or the well formation was damaged by the improper injection of this non-Class II fluid. Finally, CPAI expects our employees and contractors to follow established waste management procedures. Although CPAI recognizes that incorrect decisions were made, we do not believe it was a case of negligence. If you have any question, please feel free to contact me at (907-659-7590) or the Environmental Coordinator at Alpine (907-670-4423). ( Sincerely, .. ,~\~A~ David W. Hanson . . ~ ConocoPhillips Alaska p,JP P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 2¡ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~tNED APR 1 0 2007 :iv('JJ - D4-D Dear Mr. Maunder: 0, .,..,oJIOIII:''''' Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft . bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CDHO 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?/16/200? Alpine Field March 31,2007 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~1111zjfX DATE: Wednesday, September 07, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-19A COLVILLE RlV UNIT CDl-19A aDO ~o lfO FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SEI!- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CDI-19A API Well Number 50-103-20294-01-00 Insp Num: mitCS050906181322 Permit Number: 200-040-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 9/4/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i~~1~ï9A!Type inj._~_ I]-TVD -~-f6633---=[iA__~---r--mõ----:-'-_?170 i 2170 ----.---1----- P.T. ¡ 2000400 ITypeTest i SPT ! Test psi i 1658.25 I OA, 350 i 375 375! 375 I ___..__--L__._,__~.____.____1___'____._. ----1-· - .-¡-.---------..----+-.---.-- Interval ______ PIF _~_________Tubing i 850.-L.__~_____8~_ I 850 : ____ ¡ Notes Pretest pressures were observed for 30+ minutes and found stable_ . ;¡' ~ '¡)__ 0 1-.' 'C) ç-.j"-,l. l'.'~,lf.= n t) E ¡) :;,0 ) :(3\v~il'"'1~ \I.:" J~U ")., Wednesday, September 07, 2005 Page 1 of 1 Annual Disposal Well Performance Report Distribution -EPA Page 1 of 1 • Maunder, Thomas E (DOA) From: Schneider, Tim S. [ Tim. S.Schneider @conocophiIlips.com] Sent: Tuesday, May 02, 2006 8:56 AM To: Thomas Maunder��✓ Cc: mark. a. major@conocophil lips. com; Kemner, Maria R Subject: Annual Disposal Well Performance Report Distribution -EPA Tom, ConocoPhillips has been asked to submit a copy of the Annual Disposal Well Performance Report for the Colville River Unit to the EPA Director -Area 10. We plan to accommodate this request, but wanted to notify the AOGCC of this as a courtesy since the CD1 -19A Class 2 data is included in this report. We will forward a copy of the 2005 Annual disposal Well Performance Report this week. Regards, T;. 5d � ConocoPhillips Alpine Subsurface Engineering Staff Engineer 907 - 265 -6859 907 - 632 -8136 (Mobile) # im .s.schneider @conocophillips.com 1 on12008 Alpine CD 1 -19A (PTD 200 -040) Page 1 of 2 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, August 30, 2005 4:47 PM To: James Regg; Thomas Maunder Cc: Alonzo, Chris; Erwin, Michael D; Elmer, Matt J.; ALP Ops Maint Supv; Alpine Lead Operators; Hanson, Kelli L; Mooney, M; NSK Problem Well Supv Subject: Alpine CD1 -19A (PTD 200 -040) Jim/Tom, CD1 -19A is a Class II disposal well located on the Alpine CD1 drill site. The well is used for disposal of drilling and wellwork fluids in the Sadlerochit formation. CD1 -19A has been used for slurry injection intermittently since initial injection in August 2000. Under Area Injection Order No. 1813, Rule 6, a MIT is required every 2 years for slurry injection wells. The initial CD1 -19A MIT was conducted on 3/30/01; however, the next required MIT was not completed in 2003. This was an inadvertent omission as the completion report identifies this well as a waste disposal well and was believed to only require a 4 year MIT similar to other North Slope Class II disposal wells. A recent review of Area Injection Order 18B was conducted during preparations for normal 4 year injection well MIT's and revealed this error. As a result of this oversight, the MIT frequency has been corrected in our MIT database and we will pursue a MIT at the earliest possible opportunity. Though the 2003 MIT was not performed, the following describes regular monitoring and reporting activities that have occurred in accordance with AIO 18B and prudent operations practices: CD1 -19A Injection History: August 2000 - June 2001 Slurry disposal July 2001 - November 2002 Liquid disposal only December 2002 - May 2003 Slurry disposal June 2003 - October 2004 Liquid disposal only`'. 200 November 2004 - August 2005 Slurry disposal CD1 -19A Monitoring and Reporting Practices: Tubing, IA and OA Pressures monitored daily Tubing, IA and OA Pressures and pumped volumes recorded every 15 minutes during injection operations Annual Performance Reports submitted on 3/27/02, 4/15/03, 3/17/04 and 3/23/05 Current and historical data indicates the tubing - casing annulus has full mechanical Integrity. See the attached plot below for Tubing and IA pressures for the last 6 months. 10/7/2008 _ Alpine CD 1 -19A (PTD 200 -040) Page 2 of 2 CD1 -19A T/I 4000 3600 3000 2600 2000 1600 1000 600 0 u, Ln M Ln Ln Ln Ln Ln LD Ln Ln Ln LD M kn u 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 f iI7 M N LO N LO ¢) M ,V 12 CO CD v ' Ln LO r- N N [Y l Cr] b LID LO r- D ate +Tubing -. IA A MIT on CD1 -19A is tentatively scheduled for Saturday September 5th, contingent on State Inspector availability. Please let me know if you have any questions regarding this well. MJ Loveland Conoco Phillips Problem Well Supervisor 659 -7224 10/7/2008 Page 1 of 1 • Maunder, Thomas E (DOA) From: James Regg Uim_regg @admin.state.ak.us] Sent: Monday, July 12, 2004 2:30 PM To: Alonzo, Chris Cc: Tom Maunder O Subject: Re: CD1 -19A '"� Chris - thanks for the updateb w Jim Regg AOGCC Alonzo, Chris wrote: Jim, As a follow -up to your request dated May 5, 2004 and our follow -up phone c Ran down hole gauges on June 19th. Injected seawater into well and shut -in. Pulled Gauges June 26th. We are currently in the process of analyzing the SPFO data and will have a Chris Alonzo Alpine Engineering Supervisor ConocoPhillips, Alaska (907) 265 -6822 chris.alonzo @conoco hilli s.com 10/7/2008 Maunder, Thomas E (DOA) From: Clifford L Crabtree [ C .L.Crabtree @conocophillips.com] Sent: Monday, December 30, 2002 1:36 PM To: winton_aubert@admin.state.ak.us; tom_maunder @admin.state.ak.us Cc: Jeanne L Haas; William D Rauchenstein; Chris R Pierson; Aras Worthington Subject: Form 403 for pert /reperf of CD1 -19A disposal well. Attachments: CD1 -19A 403.xls; CD1 -19A reperf summary proc.doc; CD1- 19A.pdf CDl- 19A_403.xis CDi -19A reperf CD1- 19A.pdf (2 KB) (2 KB) summary proc.do... Winton /Tom CD1 -19A class II injection well surface injection pressures have increased enough to warrant reperforation of the Ivishack injection interval. We are planning to bring Schlumberger over this Thursday (1/2/03) to conduct this operation. I have attached a summary procedure,wellbore schematic and form 403. The bottom perforations may not be reshot if fill covers them. In addition to the reperf, we would like to add new perforations at 10,720' to 10,740' MD, which is situated between the currently perforated intervals. Jeanne Haas will bring over hard copies this afternoon (12/3/02). I will not be in after today. Please advise me and the above cc list via email when approved. Regards Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265 -6842; Cell: (907) 240 -5357 Email: ccrabtr @ppco.com; Fax:: (907) 265 -1515 (See attached file: CD1 -19A 403.xls)(See attached file: CD1 -19A reperf summary proc.doc)(See attached file: CD1- 19A.pdf) <; ! 8 2005 1 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) /- Conoc~hillips Alaska, Inc. ) ..,,--r" Chris Alonzo /~ Alpine E'ngineering Supervisor 700 G Street, ATO-1770 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6822 March 23, 2005 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Attention: Mr. John Norman RECEIVED MAR :2 4: 2005 A\~!¡sk~ Oil & Gas; Cons. Commi~~i@rn Ánchowtiige. Subject: Annual Disposal Well Performance Report Alpine Oil Pool/Colville River Unit Commissioner Norman: ~OO - 0 L{"-r~ ConocoPhillips Alaska, Inc., as Operator and on behalf of the worki~ interest owners of~ Colville River Unit submits this Annual Disposal Well Performance Report for the Alpine Oil Pool of the Colville River Unit. This report is submitted in accordance with Area Injection Order No.18B and Disposal Injection Order No.18. c\) \ - \.~ '.\ Inquiries regarding this report may be directed to Kelli Hanson (265-6945) at this office. Sincerely, ~.YV Chris Alonzo Alpine Engineering Supervisor SGANNEP L\ on (), .¡~ ')OOi-~ , "' ," ., j n I.' .', L.. ..u ( o p y ~ ) ConocoPhillips Alaska, Inc. cc: Mr. Mark Meyer, Director Alaska Department of Natural Resources Division of Oil & Gas 550 W. 7tl1 Avenue Suite 800 Anchorage, Alaska 99501-3035 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 3900 C Street Suite 801 Anchorage, Alaska 99503-5963 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 89050 Nuiqsut, Alaska 99789 Mr. Bill Esco Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-1330 ) Chris Alonzo Alpine Engineering Supervisor 700 G Street, ATO-1770 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6822 ) ) Annual Disposal Well Performance Report Alpine Oil Pool Colville River Unit March 2005 2004 Disposal Well Perf017'1!ance Report Colville River Field ) Table of Contents Section 1 Introduction 2 Class I Disposal Injection Volumes Injection Rates Injection Pressures Annulus Pressures Depth Tags Surveillance Logging Fracture Growth Wellwork Event Summary 3 Class II Disposal Injection Volumes Injection Rates Injection Pressures Annulus Pressures Depth Tags Surveillance Logging Fracture Growth Well work Event Summary 2 ') Page 4 5 10 2004 Disposal Well Perfo,.-'V'ce Report Colvüle River Field ) Attachments 1 2 3 4 WD-02 Annual Injection Summary Table WD-02 Annual Injection Summary Plot CDl-19A Annual Injection Summary Table CDl-19A Annual Injection Summary Plot 3 .... 2004 Disposal Well Perfor )ce Report Colville River Field ") Class II Disposal - CDl-19A Injection Volumes Fluid injection volumes for the 12-month period of January through December 2004 totaled 76,762 bbl. This represents a monthly average of 6,397 bbl. Cumulative injection into the Sadlerochit since the start of the project is 292,255 bbl. Injection volumes for CDl-19A are summarized on Attachment 3. Injection Rates Disposal operations for this well are manually recorded. Various trucks and rig units are utilized to transport and dispose of fluids into this well. Injection rates vary between 0.5- 3.7 bpm. There is no permanent disposal pump or piping installed at this time. Pressure and injection rate records are collected manually during disposal operations. Disposed fluids primarily include spent well work and flowback fluids. In late 2004, additional disposal included drilling mud and cuttings. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically on Attachment 4. Injection Pressures Injection pressures are monitored and recorded manually and reported to the Alpine Environmental staff. These reports are summarized in the data plot (Attachment 4). Normal wellhead pressures during disposal operations vary between 1,900 psi and 3,500 psi. Annulus Pressures Annulus pressures are manually recorded and reported, and displayed in graphical form on the well performance plot (Attachment 4). Inner annulus pressure averaged 45 psi during 2004 and remains stable during injection periods. Depth Tags Several depth tags were performed in 2004 while rigging up on CD1-19A for injection valve maintenance. Tags were also obtained in response to increased solids disposal operations in late 2004 as a result of increased drilling waste disposal. 2/26/2004 6/19/2004 1 0/9/2004 12/28/2004 Tag Depth (ft MD) 11,778 11,780 11,785 11,757 Feet of Open Perfs. 313 315 320 292 10 2004 Disposal Well Perfon ·Jce Report Colville River Field ) Surveillance Logging No surveillance logging was performed during 2004. Fracture Growth A pressure fall-off (PFO) test was performed on Alpine's Class II Disposal Well, CD 1- 19A on June 19,2004 for the purpose of estimating fracture growth. The complete test report was submitted on 7/26/04. During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. Referring to the square root of time plot from the June 2004 PFO, a fracture was observed to close at dt=7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to a reduction in well injectivity and poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early-time analysis. A regression fit to the early-time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1%. A Nolte-Smith plot from the injection data yielded a quarter slope, indicating a Perkins and Kern system, i.e. a wedge-shaped vertically contained fracture, which is growing in length. Wellwork Event Summary 2/26/2004 PULLED ERODED, DISFUNCTIONAL MCX @ 17951 RKB. TAGGED FILL @ 11,778' RKB, EST. 3151 OF OPEN PERFS. IN PROGRESS. 3/1/2004 SET 311 MCX (SIN 309) ON 2.8111 X-LOCK @ 17951 RKB; PASSED CLOSURE TEST. 6/19/2004 PULLED 311 MCX @ 17951 RKB; TAGGED FILL @ 11,7801 RKB; SET DUAL PANEX GAUGES ON AN XN LOCK @ 10,7781 RKB. LRS PUMPED 850 BBLS SW, 1.5 BPM @ 2950 PSI. 6/26/2004 PULLED PANEX GAUGES @ 10,7781 RKB. SET 311 MCX INJ VALVE ON 2.8111 X-LOCK @ 17951 RKB; PASSED CLOSURE TEST. 10/9/2004 PULLED 3112 MCX VALVE-(HAD BAD FLAPPER SEAT). TAGGED FILL @ 117851 RKB. (NEW MCX COMING IN FROM KUPARUK LATER ). 10/10/2004 SET 3112 MCX ISSSV @ 17951 RKB (PERFORMED CLOSURE TEST). 12/2812004 PULLED 3.5" MCX INJECTION VALVE @ 17951 RKB, TAGGED FILL @ 11 ,757'RKB. PUMPED INTO WELL @ 1 BPM @ 3500 PSI WI DIESEL. 11 Attachment 1 January - December 2004 Injection Summary Well: WD-02 DisposalOrder: 18 Field: Colville River Unit API No.: 103-20285-01 Pool: Alpine Oil Pool Pool Code: 120036 Tubing Pressure Casing Pressure Daily Average Monthly Total Year Cumulative Month Days In Max Average Max Average Liquid Gas Liquid Gas Liquid (BBL) Gas Operation Pressure Pressure Pressure Pressure (BBL) (BBL) ---- January 31 1,539 987 44 37 503 15,579 15,579 February 29 1,660 1,151 61 45 569 16,503 32,082 March 30 2,833 1,240 3,509 59 755 25,798 57,880 April 30 1,551 1,152 597 125 857 25,725 83,605 May 31 2,589 1 , 180 825 171 1,160 35,962 119,567 June 30 2,580 1,198 1,171 148 1,102 33,354 152,921 July 31 1,513 1,135 282 161 914 28,334 181,255 August 31 2,652 1,230 1,213 219 952 29,527 210,782 - September 30 2,422 1,178 837 196 873 26,194 236,976 October 31 2,732 1,111 924 654 724 22,452 259,428 November 30 1,581 1 , 180 1,031 608 634 19,011 278,439 December 28 2,778 1,153 3,561 560 524 16,470 294,909 ~ / Average 2,203 1, 158 1, 171 248 797 24,576 Attachment 2 WD-02 Injection Performance 1800 1600 - Annual EPA Inspection 1400 - -J . t ~r r {r I 3000 - Diy Avg Inj Press, psi - Diy Avg Ann Press, psi - Diy Inj, bbl - 2500 -" ,\ \ \' ~ \ yt II AJ \ I AI Y· ~ ~ ~ ì ~" ~ t '^ J.~. . - 2000 t ~ IV \. Il If r '~r Y\ ~ \ 1200 - .~ 10001fJ M ~ en en ~ 800- Q. '( I '. \ \ \ / \ l 11 · \ ~ ~ ~¡ ^ ' . V 400 - .1 ~ ~ ~ I tvv I ~., Mf' /" 200- Jv' J' -- ~ - -v1 600 - o 1/1/04 2/1/04 3/3/04 4/3/04 5/4/04 6/4/04 7/5/04 8/5/04 en ãi - 1500 t: CIS ED J \/~r r.M \i It r \tv.. I' -j¥ I L, ,r~ I \ ~V'\JN .,J 1 ~ \ I ~ - 500 - 1000 ~ J o 9/5/04 1 0/6/04 11/6/04 1217/04 Attachment 3 January - December 2004 Injection Summary Well: CDl-19A Injection Order: 18H Field: Colville River Unit API No.: 103-20294-01 Pool: Alpine Oil Pool Pool Code: 120036 Tubing Pressure IA Casing Pressure Daily Average Monthly Total Year Cumulative Month Days In Max Average Max Average Liquid Gas Liquid Gas Liquid Gas Operation Pressure Pressure Pressure Pressure (BBL) (BBL) (BBL) --- January 7 3,450 3,188 350 336 299 2,095 2,095 February 6 3,450 2,919 100 75 356 2,138 4,233 March 4 3,450 3,094 50 25 383 1,533 5,766 April 5 3,450 2,572 0 0 213 1,063 6,829 May 3 3,300 2,831 0 0 276 829 7,658 June 13 3,500 2,803 50 8 367 4,771 12,429 July 9 3,400 2,976 0 0 375 3,379 15,808 August 4 3,500 3,194 0 0 436 1,745 17,553 September 6 3,500 3,060 0 0 444 2,663 20,216 October 1 3,050 1,986 0 0 132 132 20,348 November 22 3,500 2,671 550 46 1,313 /'28,884~ 49,232 December 21 3,000 2,580 450 55 1,311 I 27,530 76,762 '"-". Average 3,379 2,823 129 45 491 ( 6,397/·/ ~~- '- 0.5 -' - 1.5 E - 2.5 Q. .c ar - C'IS a: 2 '- - .5 - - 3.5 4.5 o À V\A~A 1 0/2/04 11/2/04 12/2/04 - 1 ¡ I I t \'r-3 J L ' ~' ~ _I ~ ....... -4 9/2/04 8/2/04 - Diy Avg Tubing Press, psi - Diy Avg Inner Ann Press, psi -Diy Avg Rate, bpm 7/3/04 I~\ !\~ 6/2/04 5/3/04 4/2/04 3/3/04 o 1/2/04 2/1/04 ^ ~ 500 - 1000 _/ r----- ~ 1500 - 1ñ Q. or ~ 2000- en en (1) ... Q. 3500 - 4000 CD1-19A Injection Performance Attachment 4 ~ ConocoPhillips Alaska, Inc. Kelll L. Hanson Production Engineer 700 G Street, ATO-1764 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6945 July 26, 2004 \J~ ( :\)r\) ð Alaska Oil and Gas Conservation Commission Attention: Mr. James Regg, DIC Manager 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Subject: CD1-19A Class n Disposal Well Fracture Growth Estimate Dear Mr. Regg: This letter is in response to your May 5th letter requesting an estimate of fracture growth in the Alpine Class n Disposal Well CDI-19A. To comply with your request, a pressure fall-off (PFO) test was performed on the CDI-19A well in June 2004. The PFO data has been analyzed. Fracture extension and closure were evident in the early time fall-off data. The fracture resulting from the test closed at 7.58 minutes post injection at 6,492 psi a, corresponding to a fracture gradient of 0.716 psi/foot. The gradient has increased since the initial step rate test (0.665 psi/foot) as a result of changes in well injectivity index and poroelastic effects. The fracture half-length was estimated to be 356 ft. A Nolte-Smith plot of the injection data indicates the fracture grew in length, but was height constrained. Please see the attached report for further details. If you have any further questions, please call me at 265-6945. Sincerely, J(J.l¡ L· ft.b"'l1'" R,,,- t: jUl '2. F 7\)G~ Kelli L. Hanson CD 1 Production Engineer i\Hr::¥(ì O' ·r·..·'····""' ~ ConocoPh i II i pS Alaska, Inc. Date: July 26, 2004 Subject: CDI-19A Pressure Fall-Off Summary From/Location: Kelli Hanson, Alpine Production Engineer ATO-1764 Telephone: 265-6945 Test Overview -A pressure fall-off test was performed on Alpine's Class n Disposal Well, CDI-19A on June 19, 2004. Dual Panex gauges were run and set in a XN lock in the XN nipple at 10,778' RKB. Little Red Services pumped 850 bbls of seawater down the well at 1.5 bpm. Following seawater injection, the well was freeze protected with 20 bbls diesel at 1.0 bpm. The well was shut in and static bottom hole pressures were recorded. Analysis - Attachment 1 shows the pressure behavior recorded by the down hole pressure gauges. CDI-19A remained shut-in for approximately 4 days. Saphir pressure transient analysis software was utilized to analyze the data. Conventional and pressure derivative calculations were performed to calculate well/reservoir properties (permeability, skin, and wellbore storage coefficient) from the test. Assumed data for the analysis are given below. Porosity «I» 0.15 Viscosity (u.) 0.499 cp Formation Volume Factor (Bw) 1.0 RB/STB Well Radius (rw) 0.2615 ft Total Compressibility (Ct) 4.109 x 1O-() l/psi Depth (D) 11,465' MD (9,062' TVDSS) Pump Rate (Q) 1.5 bpm (2,160 BPD) water, 1 bpm (1,440 BPD) diesel FP A log-log plot of ßP versus ðt was constructed and is shown in Attachment 2 with the pressure derivative. A Homer plot is shown in Attachment 3. The early time data was also analyzed to determine fracture properties. A plot of pressure versus the square root of time (Attachment 4) was prepared to identify fracture extension and closure. Finally, a Nolte-Smith plot was created to model the fracture growth characteristics during injection. This plot is shown as Attachment 5. CD 1-19A PFO Summary Page 2 Results - The following table summarizes the well/reservoir properties obtained from analysis of the pressure fall-off data. k.h 745 md.ft Skin (s) 2.96 Wellbore Stora2e Coeff. (C) 0.211 bbl/psi Fracture Closure Pressure 6,492 psia @ dt=7.58 min Fracture Gradient 0.716 psi/ft Fracture Half-Len2th (Xf) 356 ft Fluid Efficiency 1% Pressure transient analysis yielded a k.h value of 745 md.ft. If it is assumed that most of the fluid entered the top two perforation sets (higher injectivity index), the thickness (h) would be 30-45 feet, resulting in a permeability of 17-25 md. This estimate compares favorably with the calculated log model liquid permeability of 21 md. The log-log plot shows a classic damaged well response and a skin of 2.96. Near- wellbore damage was expected due to the frequent disposal of dirty fluids. The skin has increased since the initial PFO, run 6/4/2000. Evaluation of that test demonstrated the well was slightly damaged, skin = 0.65. The initial test was conducted prior to regular disposal operations. During a step rate test on September 17, 2000, the formation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was calculated for the reservoir. During normal operations, injection occurs above this fracture pressure, thus hydraulically fracturing the well. Referring to the square root of time plot, Attachment 4, a fracture was observed to close at dt=7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to a reduction in well injectivity and poroelastic effects due to the long pumping period. Injection was assumed to enter the formation through the top two perforation sets, thus a fracture height of 35 feet was used in the early-time analysis. A regression fit to the early-time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1 %. Attachment 5 shows a Nolte-Smith plot from the injection data. The quarter slope indicates a Perkins and Kern system, i.e. a wedge-shaped contained fracture, which is growing in length. CD 1-19A PFO Summary Page 3 Conclusions -Due to disposal injection operations, the near well bore area has been damaged. Fractures extending past the damage zone have allowed continued injection. The data suggests the fractures extend in length, but are vertically contained. 6900 6700 6500 6300 =6' ~ 6100 CD ... ... 8 5900 .c ... Q. ~ 5700 I ca ëñ ~ 5500 e ~ U) = 5300 ... Q. 5100 Attachment 1 CD1-19A Panex Data 4900 4700 4500 0 10 20 30 40 50 60 70 80 90 100 110 Elapsed Time (hrs) '15.. Log-Log plot Attachment 2 , Company CPAI Well CD1-19A Field Alpine Test Name I # 6/28/04 PFO 1E+5 10000 1000 ~ VI oS -0. " " 100 c: (t 0. " 10 1 1E-5 1E-4 1E-3 0.G1 0.1 10 100 1000 dt [hr] top gauge (Mod) (Mod) fall-off #3 Rate 0 STBID Rate Change 1440 STBID P@dt=O 6577.49 psia Pi 4522.83 psia Smoothing 0.1 Selected Model Model Option Standard Model Well Storage + Skin WBS Type Changing Reservoir Homogeneous Boundary Infinite Results TMatch 2.09 [hr]**-1 PMatch 0.00734 [psia]**-1 C 0.211 bbl/psi CilCf 0.357 Alpha 22400 Skin 2.96 Delta P Skin 403.857 psi Pi 4522.83 psia k.h 745 md.ft k 21.3 md Rinv 1970 ft Test. Vol. 1.13919E+7 Barrels Saphir v3.10.09 - 07-2004 1-19A PF054 hrs Iead.ks3 .~ Horner plot Attachment 3 , Company CPAI Well CD1-19A Field Alpine Test Name I # 6/28/04 PFO ++++ + + 5000- 6000- ~ ïii oS 0. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 2 3 4 5 log(tp+dt)-Iog(dt) top gauge (Mod) (Mod) fall-off #3 Rate 0 STB/D Rate Change 1440 STBID P@dt=O 6577.49 psia Pi 4522.83 psia Smoothing 0.1 Sophir v3.10.09- 07-20041-19A PF054 his lead.ks3 6400 6300 GI ... ~ = 6200 GI ... Q. 6100 6000 0 Attachment 4 Square Root of Time 0.1 0.2 0.3 Square Root of dT 0.4 0.5 0.6 ..... 0 L() ¡s:: - c:: ~ Q) E ::s .!: V.) 0 V.) cø ~ ~ ~ ..... Ž . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 ...i...........~...........~..............~...........:...........i............... ~ : : : : : : C\I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 .i...........~...........~..............~...........:...........i............... ~ . . . . . . .... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . : : : : : 0 .............................................................................. 0 : : : : : 10 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 ....~...........~..............~....................................... 0 . . . . . C\I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 ...i....... .......................,............... 0 : : . CI:DJI:DCO Lto coo 0: 0 C . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ............~..............~....................................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ........~..............~...........:...........i............... ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ......~..............~...........~...........:............... 0 . . . . .... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 ...~..............~....................................... . . . . . 10 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 ..............~....................................... . : : : C\I . . . . . . . . . . . . . . . . . . . . . . . . . . . ........... . . . . . . . . . . . . . . ............... . . . . . . . . . . ...........,...... . . . . . . . . . . ..................... . . . . . . . . . . . . . . . . . . . . ......................... . . . . . . . . . . . . . . . . . . . . . . ............................ . . . . . . . . . . . . . . . . . . . . .......................~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . .................................. . . . . . . . . . . . . . . . . . . . . . . - 'C 0 10 oz 00<:: OO~ o~ O'S !sd 0'0 = UO!PP.::! '!sd ~. L9 ~9 = IOd 'aJnSSaJd ¡aN .........- ConocoPhilIi ps Alaska, Inc. Kelll L. Hanson Production Engineer 700 G Street, ATO-1764 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6945 ~._Q-\O ~ CJ \S-~ July 26, 2004 Alaska Oil and Gas Conservation Commission Attention: Mr. James Regg, mc Manager 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Subject: CDl-19A Class II Disposal Well Fracture Growth Estimate Dear Mr. Regg: This letter is in response to your May 5th letter requesting an estimate of fracture growth in the Alpine Class II Disposal Well CDl-19A. To comply with your request, a pressure fall-off (PFO) test was performed on the CDl-19A well in June 2004. The PFO data has been analyzed. Fracture extension and closure were evident in the early time fall-off data. The fracture resulting from the test closed at 7.58 minutes post injection at 6,492 psia. con-espondi ng to a fracture gradient of 0.716 psi/foot. The gradient has increased since the initial step rate test (0.665 psi/foot) as a result of changes in wel] injectivity index and poroelastic effects. The fracture half-length was estimated to be 356 ft. A Nolte-Smith plot of the injection data indicates the fracture grew in length, but was height constrained. Please see the attached report for further details. If you have any further questions, please call me at 265-6945. Sincerely, ~ L. I~"-rl- , .""T '., ,..-" C~' ~,"""" ' I " ~,. - ," ' i\ I" !}' ín0.~ J,.JL '.' - Kel1i L. Hanson CDl Production Engineer r: :",,:,-~ ,~ í) .,../ Co no coP hill ips Alaska, Inc. Date: July 26, 2004 Subject: CD 1-19A Pressure Fall-Off Summary From/Location: Kelli Hanson, Alpine Production Engineer ATO-1764 Telephone: 265-6945 Test Overview -A pressure fall-off test was performed on Alpine's Class n Disposal Well, CDI-I9A on June 19,2004. Dual Panex gauges were run and set in a XN lock in the XN nipple at 10,778' RKB. Little Red Services pumped 850 bbls of seawater down the well at 1.5 bpm. Following seawater injection, the well was freeze protected with 20 bbls diesel at 1.0 bpm. The well was shut in and static bottom hole pressures were recorded. Analysis - Attachment 1 shows the pressure behavior recorded by the down hole pressure gauges. CO 1-19A remained shut-in for approximately 4 days. Saphir pressure transient analysis software was utilized to analyze the data. Conventional and pressure derivative calculations were performed to calculate well/reservoir properties (permeability, skin, and wellbore storage coefficient) from the test. Assumed- data for the analysis are given below. . Porosity (<I» Viscosity (Jl) Formation Volume Factor (B\\,) Well Radius (rw) Total Compressibility (ct) Depth (0) Pump Rate (Q) 0.15 0.499 cp 1.0 RB/STB 0.2615 ft 4.109 x 10-611psi 11,465' MD (9,062' TVDSS) 1.5 bpm (2,160 BPD) water, 1 bpm (l,440 BPO) diesel FP A log-log plot of 8P versus 8t was constructed and is shown in Attachment 2 with the pressure derivative. A Homer plot is sho\vn in Attachment 3. The early time data was also analyzed to determine fracture properties. A plot of pressure versus the square root of time (Attachment 4) was prepared to identify fracture extension and closure. Fina]]y, a Nolte-Smith plot was created to model the fracture growth characteristics during injection. This plot is shown as Attachment 5. CD1-19A PFO Summary Page 2 Results - The fol1owing table summarizes the wel1/reservoir properties obtained from analysis of the pressure faJl-off data. k.h Skin (s) Wellbore Stora2e Coeff. (C) Fracture Closure Pressure Fracture Gradient Fracture Half-Len2th (XI) Fluid Efficiency 745 md.ft 2.96 0.211 bbJ/psi 6,492 psia @ dt=7.58 min 0.716 psi/ft 356 ft 1% Pressure transient analysis yielded a k.h value of 745 md.ft. If it is assumed that most of the fiuid entered the top two perforation sets (higher injectivity index), the thickness (h) would be 30-45 feet, resuJting in a penneability of 17-25 md. This estimate compares favorably with the caJculated log model liquid penneabi1ity of 21 md. - . The log-log plot shows a classic damaged well response and a skin of 2.96. Near- we]]bore damage was expected due to the frequent disposal of dirty fluids. The skin has increased since the initial PFO, run 6/4/2000. Evaluation of that test demonstrated the wel1 was slightly damaged, skin = 0.65. The initial test was conducted prior to regular disposal operations. During a step rate test on September 17, 2000, the fOnTIation fracture pressure was observed as 6,035 psi using a 9,062' column of 9.2 ppg brine and 1,700 psi on the wellhead. Using this data, a fracture gradient of 0.665 psi/ft was caJculated for the reservoir. During nonnal operations, injection occurs above this fracture pressure, thus hydraulical1y fracturing the well. Referring to the square root of time plot, Attachment 4, a fracture was observed to close at dt=7.58 minutes and 6,492 psia, yielding a fracture gradient of 0.716 psi/ft. The elevated fracture gradient can most likely be attributed to a reduction in wel1 injectivity and poroelastic effects due to the long pumpi ng peri od. Injection was assumed to enter the fonnation through the top two perforation sets, thus a fracture height of 35 feet was used in the early-time analysis. A regression fit to the early-time fall-off data resulted in a fracture half-length of 356 feet and a fluid efficiency of 1 %. Attachment 5 shows a Nolte-Smith plot from the injection data. The quarter slope indicates a Perkins and Kern system, i.e. a wedge-shaped contained fracture, which is growing in length. CD1-19A PFO Summary Page 3 Conclusions -Due to disposal injection operations, the near wellbore area has been damaged. Fractures extending past the damage zone have allowed continued injection. The data suggests the fractures extend in length, but are vertically contained. 6900 6700 - ~ ~ 6500 - , 6300 - - '1J ~ 6100 - e ... 8 5900- J: - Q. -8 5700 - I ca ëñ .B 5500 - e :J fI) ë 5300 - D.. 5100 - 4900 - 4700 - 4500 0 10 " 20 30 Attachment 1 CD1-19A Panex Data 40 50 60 Elapsed Time (hrs) 70 80 90 100 110 ~ KAPPA Log-Log plot Attachment 2 Company CPAI Well CD1-19A Field Alpine Test Name 1 # 6/28/04 PFO 1E+5 = I 1I1I11I I I 111111 I I 111111 I I II1II1 I 1111111 I I 11111I I I 111I11 10000 = ---------- ------ . ------ "-"-- -- ----- ïñ ..e. -Co "C "C I:: co C. "C 1000 =-----------------.-- -.---- 100 = 10 :;::----- + CJ 1 1E-5 I 1\ 11111 I +1 I 11111 0 I I 111111 I I I 11111 0.1 I I I 11111 I I 111111 10 I I I 11111 100 1E-4 1E-3 0.01 dt [hr] top gauge (Mod) (Mod) fall-off #3 Rate 0 STBID Rate Change 1440 STB/D P@dt=O 6577.49 psi a Pi 4522.83 psia Smoothing 0.1 Selected Model Model Option Standard Model Well Storage + Skin WBS Type Changing Reservoir Homogeneous Boundary Infinite Results TMatch 2.09 [hr]H-1 PMatch 0.00734 [psia]**-1 C 0.211 bbl/psi Ci/Cf 0.357 Alpha 22400 Skin 2.96 Delta P Skin 403.857 psi Pi 4522.83 psia k.h 745 md.ft k 21.3 md Rinv 1970 ft Test. Vol. 1.13919E+7 Barrels Saphlr v3 10.09 - 07.2004 1-19A PF054 hI'> lead 1153 I I I ¡lilt!: - - - - - I I I 11111 1000 ~ KAPPA ïi) .e. c. Horner plot Company CPAI Well CD1-19A 6000- 5000- Attachment 3 , Field Alpine Test Name 1 # 6/28/04 PFO :':.1,": '::I/'-'v 1 '11111/ 'I I I I I I I I ,. + + .,. -+ , , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , I ' , , , 1 2 3 4 5 log(tp+dt)-Iog( dt) top gauge (Mod) (Mod) fall-off #3 Rate 0 STB/D Rate Change 1440 STB/D P@dt=O 6577.49 psia Pi 4522.83 psia Smoothing 0.1 Saphll v3 1009 - 07.2004 1-19A PFOSol hrs leaa.ks3 6400 6300 - C1) ... j = 6200 - G) ... c.. 6100 - 6000 0 Attachment 4 Square Root of Time \ Fracture Extension Fracture Closure at 6492 psi, 7.58 liiinuteselapsed time - 0.1 0.2 0.3 Square Root of dT 0.4 0.5 0.6 Net Pressure. Pcl = 6167.1 psi, Friction = 0.0 psi 9Þ 50 ii . . 0. . ii : : : ! : : . . . ; . . . . . . . . . . . . . . . . . I . . . .. .. . .. .. ~................¡...........:...........~..............~...........¡...........¡..........., 0 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ ,...............i...........t...........~..............~... ...................i..........., 0 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ...... . . . . . . C)................t...........~...........~..............~...... ....:...........t...........1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~................:...........~...........~..............~.........~.:...........:...........I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 . . . .. . . . .. . . . . . I . . . . . . . . . . . . . . . . . . . . . . . . . ~t...............!...........~...........~..............~...........~".........:...........I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ...... 0 D : D D D 0 Db DDOJL[I]D,j. IIlllllUl. : : : C)................I...........~...........i......~ .......~..."......I...........I 0 . . . . . . . . . . . . . . .. . . . .. . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . I\) . . . . . . C)................t...........i...........~..............~...........t.... ...,..........., 0 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U1 : : : : : : °o................:...........~...........~..............~...........:......... ............1 . . . . . . . . . . . . . . . . . . . . . . . . . I . . . . . . . . . . . . . . . . . . ...... . . . . . . ~ I...............:...........~...........~..............~...........:...........:...........I 0 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . I\) . . . . . . ~ I...............:...........~...........~..............~...........:...........:..."......I 0 . . . . . . j . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.0 10 20 100 200 z (þ ,...,. '"'C » ~ ::I: (J) 1) (') (J) ::T t: 3 @ CD '"'C 3- 0 U1 ,...,. ~p~+ ;¿or- 01+0 r:", y r', c-.:J r-.=, :, \ \' ': j t" ;! ; ~ ~~- L Li~1j U L~ rr,'; r¡::-' : ! i : ' ~ U¿) L.:- (,i\-\ n íT\ ({lJ nfí n"\ '." '¡', \ " I r f> U\} ~ Lf::: ¡'J ci) u\~ - l-,- FRANK H. MURKOWSKI. GOVERNOR ^IIASKA OIL AND GAS CONSERVATION COMMISSION May 5, 2004 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 JO'b- 0 "to Mr. Chris Alonzo Alpine Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Alonzo: Disposal Injection Order 18 dated April 19, 1999, ahd Area Inj ection Order 18A dated April 18, 2000, address specific requirements for waste injection into specific disposal injection intervals within the Colville River Unit. Rule 9 of DIO l8A requires an annual performance report that includes "rate and pressure performance, surveillance logging, fill depth, survey results, and volumetric analysis of the disposal storage volume, estimate of fracture growth, if any, and updates of operational plans." The Alaska Oil and Gas Conservation Commission ("Commission") received from ConocoPhillips Alaska, Inc. ("ConocoPhillips") the 2003 Disposal Performance Report for the Alpine Oil Pool within the Colville River Unit. The report is dated March 17, 2004, and summarizes pressure and rate performance, surveillance, and testing of disposal injection Wells WD-2 and CDl-19A associated with Alpine Oil Pool development during calendar year 2003. The Commission has completed its review of the 2003 Disposal Well Performance Report. Regarding Well CDl-19A, ConocoPhillips states: "all fluid injection to date has occurred above fracture pressure." There is no estimate of fracture height and length as required by Area Injection Order 18A, Rule 9. ConocoPhillips notes that no data was collected to estimate fracture height and fracture length. Please provide the Commission with a summary of how ConocoPhillips' intends to resolve this deficiency in the annual surveillance requirements of Area Injection Order 18A. Sincerely, :i1~ B J:? ~ ~ James Regg t ( DIC Manager cc: John K. Norman, Chair Daniel T. Seamount, Jr., Commissioner , , é)GO-ðLfO ¥ ConocoPh i II i pS Alaska, Inc. Chris Alonzo Alpine Engineering Supervisor 700 G Street, ATO-1770 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265-6822 March 17, 2004 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 Anchorage, AK 99501 Attention: Mr. John Norman Subject: Annual Disposal Well Performance Report Alpine Oil Pool/Colville River Unit Commissioner Norman: ConocoPhillips Alaska, Inc., as Operator and on behalf of the working interest owners of the Colville River Unit submits this Annual Disposal Well Performance Report for the Alpine Oil Pool of the Colville River Unit. This report is submitted in accordance with Area Injection Order No.I8A and Disposal Injection Order No.I8. Inquiries regarding this report may be directed to Kelli Hanson (265-6945) at this office. Sincerely, Chris í\lonzo Alpine Engineering Supervisor -::( ì:"'J - I { - I ,,~,., \.......t:. . \MR 1 8 200 r,:;,,\,;-,":':::e~::11'" '1 ,II »,-~, <:t .{ ¥ ConocoPh i II i pS Alaska, Inc. Chris Alonzo Alpine Engineering Supervisor 700 G Street, ATO-1770 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-265.6822 cc: Mr. Mark Meyer, Director Alaska Department of Natural Resources Division of Oil & Gas 550 W. 7th Avenue Suite 800 Anchorage, Alaska 99501-3035 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 3900 C Street Suite 801 Anchorage, Alaska 99503-5963 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 89050 Nuiqsut, Alaska 99789 Mr. Bill Esco Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-1330 Annual Disposal Well Performance Report Alpine Oil Pool Colville River Unit March 2004 2003 Disposal Well Performance Report Colville River Field Table of Contents Section 1 Introduction Page 4 2 Class I Disposal Injection Volumes Injection Rates Injection Pressures Annulus Pressures Depth Tags Surveillance Logging Fracture Growth Significant Well Events Wellwork Event Summary 5 3 Class II Disposal Injection Volumes Injection Rates Injection Pressures Annulus Pressures Depth Tags Surveillance Logging Fracture Growth Significant Well Events Wellwork Event Summary 10 2 2003 Disposal Well Performance Report Colville River Field Attachments 1 2 WD-O2 Annual Injection Summary Table WD-O2 Annual Injection Summary Plot CDl-19A Annual Injection Summary Table CDl-19A Annual Injection Summary Plot 3 4 3 2003 Disposal Well Performance Report Colville River Field Introduction Rule 9 of Area Injection Order No. 18A, dated April 18, 2000, requires the submission of an annual performance report. Additionally, this report is prepared in accordance with Rule 5 of Disposal Injection Order 18 and the requirements of 20 AAC 25.432 (Report of Underground Injection). This represents the forth such report regarding injection operations in the Alpine Oil Pool, and the third to review a calendar year. Well WD-02, which was drilled and completed in April, 1999, continued to serve as the primary source of disposal for camp fluids. Field produced fluids were also pumped to WD-02 through June 23, 2003. Since that date, field produced water has been injected at CDI as waterflood fluid. A second disposal well, CDI-I9A, was drilled and completed in May, 2000, to provide a disposal source for Class II fluids generated during wellwork operations. 4 2003 Disposal Well Performance Report Colville River Field Class I Disposal Injection Volumes Fluid injection volumes for the 12-month period of January 2003 through December 2003 totaled 376,531 bbl. This represents a monthly average of 31,378 bbl. Cumulative injection into the Sadlerochit since the start of the project is 1,553,807 bbl. Monthly injection volumes for WD-02 are summarized in both table and plot form as Attachments 1 and 2. Injection Rates The injection pumps operate on level controls located on upstream holding tanks. Until 6/24/03, approximately 50% of the fluids injected were effluent from Alpine base camp and 50% were produced water from the field, hence injection volumes varied in response to field manpower and staffing. WD-02 monthly injection rates decreased in the last half of 2003, as produced water was rerouted to the CD 1 injection header. In late March, the well was offline for nine days during the annual EP A MIT inspection. The twin injection pumps are operated at 15-20 gpm each up to the 3,200 psi allowable injection pressure. Daily injection volume swings require additional pumping hours as required to handle the increased loads. Injection Pressures Injection pressures are monitored and recorded continuously (Attachment 2). Normal wellhead pressure when the pump is offline ranges between 800 psi and 1,000 psi. With the pumps running at 20-40 gpm, injection pressure ranges between 1,000 psi and 1,400 pst. Annulus Pressures Annulus pressures are monitored and recorded continuously (Attachment 2). When produced formation fluids are disposed of into WD-02, the hot fluids expand and elongate the tubing string, which impacts the annulus volume, increasing the annulus pressure. Plant operators bleed off fluid from the annulus as a precaution to avoid annulus pressures reaching the 1,500 psi operating limit. The annulus pressure averaged 65 psi throughout 2003. Depth Tags During the 2003 Annual EP A Inspection, slickline tagged TD on March 17, 2003 at 9,964' MD. This depth is 83' above the deepest perforation at 10,047' MD and 18' shallower than the 9,982' MD tag on 3/14/02. 5 2003 Disposal Well Performance Report Colville River Field Surveillance Logging In compliance with stipulations in Part ILc.3.b.I-3 of EP A Permit AK-1I003-A, ConocoPhillips conducted a thorough examination of the mechanical condition of the well bore through application of four surveillance logs. This work was completed in late March of 2003, under the direction of the EP A. Summaries of the surveillance log results are provided below: 1. A caliper survey was conducted in the intennediate casing. . Proactive Diagnostic Services performed the caliper survey on March 18,2003. . Two separate passes were completed for this caliper survey. . The caliper tool selected utilizes 40 independent fingers to survey the casing wall. Each finger is capable of recording a penetration as deep as 0.30". . Other than observing perforations in the injection interval, there were no recorded intervals of significant wall loss (exceeding 13%) noted. . Percent of Wall Contacted by Feelers = 21 % . Distance Between Feelers = 0.39" . Radial Measurement Accuracy = 0.01" 2. A temperature survey consisted of the following actions: .Temperatures were monitored for 2 hours to allow wellbore temperatures to stabilize. . A baseline temperature pass was performed from 7,850'- 9,880' MD approximately 2 hours after the well was shut in. . The first warm-back temperature pass was performed from 7,850' - 9,880' MD approximately 8 hours after injection stopped. .A second warm-back temperature pass was performed from 7,850' - 9,880' MD approximately 16 hours after injection stopped. . On March 25, 2003 Schlumberger returned to perform the final warm-back temperature survey over the logged interval, approximately 24 hours after the well was shut-in. . The only significant cooling anomaly noted in the surveys begins below 9,800' MD. 3. On March 23, 2003, Schlumberger ran a Water-Flow Log (WFL) in combination with a Profile Log (PFCS) in WD-02. The following is a summary of results from the WFL survey: . Logged the following stations: Station Tool Depth 1 9,449' 2 9,434' 3 9,409' 4 8,917' 5 8,902' 6 8,877' 7 9,449' 8 9,434' 9 9,409' 10 8,917' Flow Direction Up Up Up Up Up Up Up Up Up Up 6 Pump Rate 2bpm 2bpm 2bpm 2bpm 2bpm 2bpm 3 bpm 3 bpm 3bpm 3 bpm Flow Detected No No No No No No No No No No 2003 Disposal Well Performance Report Colville River Field 11 8,902' Up 3 bpm No 12 8,877' Up 3 bpm No The top perforation is located at 9,459' MD. Allowing for tool length, three stations were logged above these perforations to achieve standoff of 10',25', and 50'. The top of the Sag River is located at 8,927' MD, which corresponds to the base of the confining interval or top of the injection interval. Again allowing for tool length, three stations were logged above these perforations to achieve standoff of 10',25', and 50'. 4. A spinner survey was conducted to analyze fluid movement as it exits the casing. The following is a summary of the results from this profile. . Tied in on depth and verified tool performance. . Surveyed from packer depth to 4' above PBTD (7,850' MD - 9,880' MD) at 1.0 bpm. . Passes run included Up and Down passes at 40/80/120 fpm. . Surveyed stop counts at 2.0 bpm. . Surveyed from 9,400' MD - 9,880' MD at 3.0 bpm. . Passes run included Up and Down passes at 40/80/120 fpm. . Surveyed stop counts at 3.0 bpm. Fluid splits from the spinner survey show the fluids leaving the wellbore as shown below: Perforated Interval 9,459' -9,472' 9,514' -9,552' 9,612' -9,627' 9,702'-9,712' 9,803' -9,818' 9,837' -9,867' 9,876' -9,896' 9,900'-9,020' 10,017' -10,047' Fluid % 0% 0% 0% 0% 27% 54% 19% Covered with fill Covered with fill As shown, the spinner analysis provides quantitative results, as compared to the qualitative results of the temperature survey. Interpreted Results The oxygen activation tool (Water Flow Log) results concur with the temperature and spinner tools to indicate the following: . all fluids are being conducted from the packer to the perforated interval, . all fluids are exiting the casing within the permitted interval, and . no fluids are migrating outside the permitted interval. Furthermore, the spinner splits identify the perforation intervals below 9,800' MD as the only location of fluids exiting the wellbore. 7 2003 Disposal Well Performance Report Colville River Field Fracture Growth The surface fracture pressure of the Ivishak, as measured during the step rate test conducted April 11, 1999, is 1,984 psi. This pressure coincides with an injection rate of 1.38 BPM, or 1,987 BPD. The associated bottomhole fracture pressure extrapolated from the step test data is 6,259 psi. This equates to a gradient of 0.66 psi/ft, or fluid equivalent of 12.7 ppg. With the exception of short-term injection periods, tubing tests, and miscellaneous data spikes, the injection pressures have not exceeded the surface fracture pressure for any extended period of time during 2003. For that reason, significant fracture growth is not expected in the Sadlerochit formation. Significant Well Events The transfer of produced water to the seawater injection system is the most notable event of the past year, occurring in June 2003. Since then, produced water has primarily been injected as waterflood fluid. 8 2003 Disposal Well Performance Report Colville River Field Well work Event Summary Outlined below is a summary of wellwork events for well WD-02. 3/17/2003 PULL A-1 INJECTION VALVE & DRIFT TBG W/ 3.25' G-RING. TAG BOTTOM @ 9964' RKB . 3/18/2003 RUN A PDS CALLIPER LOG MAKING TWO PASSES, PDS REP CONFIRMED GOOD DATA. LEAVE WELL SHUT IN FOR TEMP STABILIZATION. 3/21/2003 RAN WEATHERFORD INFLATABLE, RETRIEVABLE BRIDGE PLUG. SET IRBP. TAGGED PLUG TO VERIFY GOOD SET. PERFORMED MITIAIMIT-TBG, GOOD. STATE WITNESSED BY LOU GRIMALD 3/22/2003 RIH W/ BELL GUIDE. LATCH INFLATABLE BRIDGE PLUG. POOH @ ABOUT 20 FPM. ON SURFACE, PLUG HAS ALL RUBBER 3/23/2003 RAN TEMP. SURVEY. RAN WFL STATIONS ABOVE TOP PERFS. THIS DATA PROVES THAT THERE IS NO WATER MIGRATION BEHIND PIPE. RAN INJECTION PROFILE, LOGGED UP. 3/24/2003 SHUT IN WELL & FREEZE PROTECT W/ 40 BBLS DIESEL. 06:00, 24-MAR-03. MONITOR BHP. FALL OFF, TEMP INCREASE DURING STABILIZATION. LOG BASELINE TEMP PASS 2 HRS AFTER SI 7850' -9880' MD. REPEAT W/ WARMBACK PASSES @ 8, 16,24 HRS AFTER SHUT IN. POOH. 3/25/2003 SET A-1 INJECTION VALVE. DO A CLOSURE TEST, BLEED TBG DOWN TO 400 PSI FROM 1200PSI FOR 15 MIN. GOOD TEST 9 2003 Disposal Well Performance Report Colville River Field Class II Disposal (CDl-19A) Injection Volumes Fluid injection volumes for the 12-month period of January 2003 through December 2003 totaled 31,488 bbl. This represents a monthly average of 2,624 bbl. Cumulative injection into the Sadlerochit since the start of the project is 215,493 bbl. Injection volumes for CDI-I9A are summarized on Attachment 3. Injection Rates Disposal operations for this well are manually recorded. Various trucks are utilized to transport and dispose of fluids into this well. Injection rates vary between 0.5-3 bpm, with occasional spikes as high as 3.6 bpm. There is no permanent disposal pump or piping installed at this time. Pressure and injection rate records are collected manually during disposal operations. Disposed fluids primarily include spent wellwork and flowback fluids. All fluid disposal reports and manifests are recorded and stored at Alpine. The data is displayed graphically on Attachment 4. Injection Pressures Injection pressures are monitored and recorded manually and reported to the Alpine Environmental staff. These reports are summarized in the data plot (Attachment 4). Normal wellhead pressures during disposal operations vary between 2,500 psi and 3,500 pSI. Annulus Pressures Annulus pressures are manually recorded and reported, and displayed in graphical form on the well performance plot (Attachment 4). Inner annulus pressure averaged 111 psi during 2003 and remains stable during injection periods. Depth Tags A tag on CDI-I9A occurred on 1/412003 and reportedly set down at 11,769' MD, or 44' above the deepest perforations (11,813' MD). Another tag was performed on 2120/2003 afterre-perforation and fill clean-out operations, showing a fill depth of 11,823' MD, or 10' below the deepest perforations. No other tags were performed during 2003. Surveillance Logging No surveillance logging was performed during 2003. 10 2003 Disposal Well Performance Report Colville River Field Fracture Growth Per analysis of a step rate test performed on September 17, 2000, the fracture pressure observed with diesel yields a surface fracture pressure of approximately 950 psi assuming water injection. All fluid injection to date has occurred above that pressure. However, due to fill in the well, testing was hampered. An injectivity test was performed in 2003, but no data was collected to estimate fracture height and fracture length. Significant Well Events In January of 2003, the CDI-I9A injection interval was re-perforated. Perforations were added from 11,720'-11,740' MD, 11,749'-11,763' MD, 11,463'-11,483' MD, and 11,504' -11,520' MD. A fill c1eanout was then performed in February 2003 to remove the 44' of fill observed on 1/412003 (tag at 11,769' MD). At the end of the job, mud and sand were washed from the well bore to a final depth of 11 ,823' MD, or 10' below the deepest perforations. Another re-perforation job was performed on 2/27/2003 over the two deepest sets of perforations: 11,780'-11,793' MD and 11,803'-11,813' MD. Well work Event Summary Outlined below is a summary of wellwork events for well CD 1-19A. 1/4/2003 TAGGED TD AT 11769', PERFORATED: 11720'-11740', 11749'-11763',6 SPF ADDDED l' TO THIS INTERVAL. 1/5/2003 PERFORATED: 11463' -11483' AND 11504' -11520',6 SPF 21/2" HSD 2506 HJ PERFORMED A INJECTIVITY TEST. 1.25 BPM @ 3600# INJECTION PRESSURE WITH A COLUMN OF DIESEL. 1/21/2003 SET MCX INJECTION VALVE @ 1795' RKB. 2/4/2003 PULLED 3" MCX-INJECTION VALVE. 2/8/2003 WASHED DOWN TO PBTD AT 11,850' CTM (EST. 50' OF RATHOLE) W/ FW AND DIESEL. RTNS 1:1 THROUGHOUT JOB- NO NOTICEABLE SOLIDS. CONDUCTED INJECTIVITY TEST POST-CLEANOUT; ABLE TO INJECT DIESEL 1.0 BPM (DIESEL TO 5000', FW TO TD) @ 2800 PSI. WELL FP'D W/ DIESEL. 2/20/2003 TAGGED FILL @ 11823' RKB. EST. 10' RATHOLE. 2/27/2003 PERFORATED: 11780'-11793' & 11803'-11813' WITH 21/2" HSD, 6 SPF HJ. 3/5/2003 SET MCX INJECTION SSSV @ 1795' RKB. 3/15/2003 INJECTION TEST POST ADD PERF. 11 Attachment 1 Well: WD-02 Field: Colville River Unit Pool: Alpine Oil Pool January - December 2003 Injection Summary Disposal Order: 18 API No.: 103-20285-01 Pool Code: 120036 Tubing Pressure Casing Pressure Daily Avg. Injection Total Monthly Inj. Cum Year Inj. Month Days In Max Average Max Average Liquid Gas Liquid Gas Liquid Gas Operation Pressure Pressure Pressure Pressure (BBL) (BBL) (BBL) January 31 2,467 1,217 618 101 1,190 38,347 38,347 February 28 2,759 1,224 765 111 1,321 37,000 75,347 March 23 2,975 1,186 3,520 113 1,054 32,681 108,028 April 30 2,513 1,049 309 50 1,427 42,818 150,846 May 31 2,725 1,211 394 68 1,549 48,019 198,865 June 30 2,666 1,329 469 73 1,748 52,443 251,308 July 31 1,468 921 32 25 664 20,578 271,886 August 31 2,848 1,158 505 61 1,107 34,313 306,199 September 30 1,672 1,183 130 56 599 17,965 324,164 October 31 1,731 1,207 199 54 631 19,578 343,742 November 30 1,545 973 36 30 539 16,170 359,912 December 31 1,626 971 42 34 533 16,619 376,531 Average 2,250 1,136 585 65 1,030 31,378 Attachment 2 WD-O2 Injection Performance 2500 - 3000 .r; Produced Water Routed to CD1 Injection Header - Avg Inj Press, psi -+- Avg Ann Press, psi -+- Daily Inj, bbl . 2000 - - 2500 . . ëii Co I of ~. ... I ¡ I JI I (/ "" e J . a. I I 10001 I, ~ ".1~ ,~ . ,. .. þ .,. ~'...I J - ,~V ~ .. E" ~ ' 'on .. ~ . -:}Jlf' n , ~. . { " :JJ -- . n ~ J I. "'- - . rJ II~ ' ' "M"'~. - 1000 4." . . ~, - j m: 41 - 2000 . 1500 - . . JI 41 ~ . ~ Annual EPA I ~ Inspection - 500 ~ 41 II 41 . 500 - -, . 0 ,0 1/1/03 2/1/03 3/4/03 4/4/03 5/5/03 6/5/03 7/6/03 8/6/03 9/6/03 10/7/03 11/7/03 12/8/03 Attachment 3 January - December 2003 Injection Summary Well: CDI-19A Injection Order: ISA Field: Colville River Unit API No.: 103-20294-01 Pool: Alpine Oil Pool Pool Code: 120036 Daily Avg. Tubing Pressure IA Casing Pressure Injection Total Monthly Inj. Cum Year Inj. Month Days In Max Average Max Average Liquid Gas Liquid Gas Liquid Gas Operation Pressure Pressure Pressure Pressure (BBL) (BBL) (BBL) January 4 3,500 3,437 200 77 371 1,483 1,483 February 6 3,500 3,207 300 125 354 2,123 3,606 March 5 3,800 3,334 500 167 356 1,780 5,386 April 1 3,500 3,000 800 544 290 290 5,676 May 9 3,450 3,288 300 85 334 3,010 8,686 June 9 3,300 2,872 1,000 105 369 3,320 12,006 July 5 3,450 2,893 0 0 269 1,345 13,351 August 8 3,450 2,822 0 0 479 3,830 17,181 September 13 3,450 2,815 0 0 579 7,532 24,713 October 8 3,450 3,004 200 70 400 3,198 27,911 November 4 3,450 2,888 150 106 408 1,632 29,543 December 7 3,450 2,853 50 50 278 1,945 31,488 Average 3,479 3,034 292 111 374 2,624 4000 3500 - 3000 - 2500 - 'iii Co 4i :; 2000- CII CII CD .. 11. 1500 - 1000 - 500 - '-- Attachment 4 CD1-19A Injection Peñormance . \ I . . J ~ ./ . .. ~~ 0 1/9/03 2/8/03 3/11/03 4/10/03 5/11/03 . ~-:l. 6/1 0/03 . . .1\'" :¡ - 2 ~ . ..~. ,\, ~,.- vY ~ ~ r-15 I II ~ . . 7/11/03 8/10/03 .. 9/10/03 II . [þ II - 1 .. 1- Avg Tubing Press, psi -.- Avg Inner Ann Press, psi -.- Rate, bpm - 0.5 ~ - 10/10/03 11/10/03 12/10/03 . 2.5 E Co .a 4i - CCI a: £' 0 DATA SUBMITTAL COMPLIANCE REPORT 5113/2002 Permit to Drill No. 2000400 Well Name/No. COLVILLE RIV UNIT CDI-19A Operator PHILLIPS ALASKA INC. AP1 No. MD 11956 TVD 9595 Completion Date 6/2/2000 Completion Status WDSPL Current Status WDSPL REQUIRED INFORMATION Mud Log N._Qo Samples N~o Directional Survey N_.~o 50-103-20294-01-00 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) 25 FI ELD 2855 11956 25 FIELD 2855 11956 5 FINAL 10590 11830 5 FINAL 10590 11819 5 FINAL 8500 10600 25 FIELD 2400 9500 5 FINAL 0 11832 25 FIELD 2400 9500 5 FINAL 10590 t 1819 115 11956 Log/ Interval Data Digital Digital Log Log Run OH/ Dataset Type M.~ Format Name Scale Media No Start Stop CH Received Number Comments O 8/4/2000 09689 ~2800-11956 A DR-MD OH 8~4~2000 DN-MD OH 8/4/2000 ~ J~'VL-TEM/PRES CH 6127/2000 JPERF CH 612712000 j t~SIT OH 6~27~2000 ~M' / CDR-TVD OH 814/2000 ~ INJP-TEM SRVY CH 6127/2000 ADN-TVD OH 8~4~2000 PERF CH 6~27~2000 ~/"SRVY RPT OH - 5/2/2000 BL(C) SCHLUM . Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Received? /~)/N Chips Received? ~ Formation Tops Rcccuivcd? (~/N Analysis Rcccivcd? ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Permit to Drill No. 2000400 Well Name/No. COLVILLE RIV UNIT CDI-19A Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20294-01-00 MD 11956 TVD 9595 Completion Date 6/2/2000 Completion Status WDSPL Current Status WDSPL UIC Y Compliance Reviewed By: ConocoPhillips C. Pierson Alpine Subsurface Engineer P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6112 Chris. R.Pierson @conocophillips .com March 13, 2003 .Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations CD1-19A (APD 200-040/302-396) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations .for the recent perforating operations on the Alpine well CD1-19A. If you have any questions regarding this matter, please contact me at 265-6112. Sincerely, C. R. Pierson Alpine Engineer .Alpine Subsurface CRP/skad STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _ [2. Name of Operator: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 351' FNL, 2447' FWL, Sec 5, T11 N, R51=, UM. At top of productive interval: 2251' FNL, 1004' FWL, Sec 33, T12N, R5E, UM. At effective depth: At total depth: 1639' FNL, 2099' FWL, Sec 33, T1.2N, R5E, UM. Stimulate__ Alter casing __ 5. Type of Well: Development _. Exploratory _..=. Stratagrapic .._=. Service XX. Plugging __ Perforate _X Repair well __ Other __ 6. Datum of elavation (DF or KB feet): 52.7' RKB 7. Unit or Property: Colville River Unit 8. Well number: CD1-19A 9. Permit number/approval number: 200-040 / 302-396 10. APl number: 50-103-20294-01 11. Field/Pool: Colville River Field / Alpine Oil Pool 12. Present well condition summary Total Depth: measured 11956 true vertical 9595 'Effective Depth: measured 11769 true vertical 9413 · Casing Length Size Conductor 77' 16" Sudace 2788' 9.625" Production 11912' 7" Liner Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 10 cu yds Portland Type III 114' 114' 860 sx AS III & 2825' 2393' 230 sx Class G 566 Sx Class G 11947' 9586' Perforation Depth measured true vertical 875~'-876~''899~~-9~~~'~11463~-11485~~115~4'-11522''1172~~-1174~'~11749~-11763'~11768~- 11776',11780'-11794',11800'-11813' 6692'~6699'~6868'~6876'~9116'-9138~~9156'-9173~~9366'-9385'~9394~-94~7'~9412'-942~'~9424'-9437'~9443'-9456~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, EUE 8rd @ 10792' MD Packers and SSSV (type' and measured depth) HES THB prod. Pkr @ 8670', HES THB prod. Pkr @ 10716' No SSSV, MCX injection valve @ 1795' 13. Stimulation .or cement squeeze, summary Intervals treated (measured) N/A Intervals treated (measured) Representative Daily Average ProdUction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 'Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation, N/A 1.5~ Attachments. 116. Copies of .Logs and Surveys run __ Daily Report of Well Operations _~X Oil _ Gas _ 17..I hereby certi..fy, that_the foregoing is true and. correct to the best .of my knowledge. Title ..~ ~,~ (.,,( C'7'~ Status of well classification as: Suspended __ Date w PL Service __XX oe.o 4s BFL. Date Comment ( (" CD1-19A Event History 01/04/03 01/05/03 01/21/03 02/04/03 02/08/03 02/20/03 02/27/03 03/05/03 Tagged TD at 11769'. Perforated: 11720' - 11740', 11749' - 11763', 6 spf, added 1' to this interval. Perforated 11463' - 11483' and 11504' - 11520', 6 spf 2.5" HSD 2506 HJ. Performed an injectivity test. Set 2.81" MCX injection valve #MCX-336 @ 1795' RKB. Pulled 3" MCX injection SSSV (ser # 336) f/1795' RKB complete. Washed down to PBTD at 11850' CTM w/FW and diesel. Conducted injectivity test post-cleanout. Tagged fill @ 11823' RKB, est. 10' rathole. Perforated 11780' - 11793' & 11803' - 11813' with 2.5" HSD, 6 spf HJ. All shots fired. Set MCX injection SSSV (MCX#-336) @ 1795' RKB. Closure test good. Page I of I 3/7/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _X 2. Name of Operator ConocoPhillips Alaska Inc. 3. Address P. O. Box 100360 _Anchorage, AK 99510-0360 4. Location of well at surface 351' FNL, 2447' FWL, Sec.5, T11N, R5E, UM At target (Top Alpine)) 2251' FNL, 1004" FWL, Sec.33, T12N, R5E, UM At effective depth 1749' FNL, 1934' FWL, Sec. 33, T12N, R5E, UM At total depth 1639' FNL, 2099' FWL, Sec.33, T12N, R5E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service _X_ //' Other _ Annular Injection 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-19A 9. Permit num/ber / approval number / 200-040 10. APl number 50-103-20294-01 11. Field / Pool/, . Colville River Field/Alpine Oil Pool/ 12. Present well condition summary ) Total depth: measuredI 11956 feet true vertical \ 9595 feet Effective depth: measured 11860 feet landing collar in 7" casing. true vertical 9502 feet Casing Length Size Cemented Conductor 77' 16" 10 cu.yds, Portland Type 3 Surface 2788' 9.625" 860 sx ASL3, 230 sx Class G Production 11912' 7" 566 sx Class G Measured Depth True ve~ical Depth 114 114 2825' 2393' 11947' 9586' Perforation Depth Measured True vertical Tubing (size, grade, and measured depth) 11463'-11483', 11504'-11520', 11750'-11763', 11768'-11776', 11780'-11794', 11800'-11813' 9116' - 9136', 9156' - 9171 ', 9395' - 9407', 9412' - 9420', 9242' - 9437', 9443' - 9456' 3 1/2", 9.3#, L-80 EUE 8RD @ 10792' MD Packers and SSSV (type and measured depth) HES THB Prod Packer @ 8670' MD, HES THB Prod Packer @ 10716' MCX Injection Valve @ 1795' 3. Attachments Description summary of proposal _ Detailed operations program _X BOP sketch 15. Status of well classification as: 4. Estimated date for commencing operation January 1,2003 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas ~ Suspended Service X 17. I hereby certif.,y that the foregoin!~is true ~n,~l correct to the best of my knowledge. Signedl'"/'""'--7~/~,'7 L.,. · vL.~ ,,"/-~ ~,~, · ~ /' "' -"/~ FOR COMMISSION USE ONLY I Condition~df approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance _ Mechanical Integr~ ~j~EEr~IE i ~, E ~.~s Approved by order of the Commission ~ ,/,,4~/J./'"~-,-"~ .~"~' J ...... ,.,C,,og'j~' sioner ~ Y,/Z.,,"," ,,,~ Ur.L, 0 U Date / ~/Z//~ ~--*- ~a~!ia Oil. & Gas Cons. Commiss[.o.n ~ ',~, .."~ ~ ,~'~'..~ :".. - . Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE CD1-19A Reperforate I Perforate CRU Class II Injector 1. RU Schlumberger, test lubricator. / , . . Make first run with GR/CCL tool and dummy gun. Tie in on depth with USIT. Make a jewelry log from PBTD back across the lower packer prior to perforating. Maximum gun length is 20'. Shoot the bottom interval first. Bleed the tubing pressure off prior to perforating. Bottom shots may need to be adjusted based on E-line tag. Reperforate/Perforate the following Ivishak intervals with 2-1/2" HSD 2506 RDX (0.43" ID x 13.1" penetration) charges loaded 6 JSPF on 60° phasing with the SAFE system (to avoid requirement for radio silence while perforating). Note: the bottom perforation set may be covered with fill. The last slickline tag was at 11,792' RKB. The interval 11,780'-11794' may be reperforated from 11,778 - 11,792' if the bottom ~'" two feet are covered. Open Hole Open Hole Length (MD) MD TVD * 11,463'-11,483' 9116'-9136' 20' 11,504'-11,520' 9156'-9171' 16' 11,720'-11,740' 9366'-9385' 20'new 11,750'-11,763' 9395'-9407' 13' 11,768'-11,776' 9412'-9420' 8' 11,780'-11,794' 9424'-9437~. 14' 11,800'-11,813' 9443'-9456' 13' TVD to SS correction is 56' (9,116' TVD is 9,060 SS). The entire perforated interval ranges from 9,060' SS to 9,_.400' SS. Conservation Orde, p~_~s designated that Class II fluids may be injected for purposes of dispo.~,aJ.i4~o strata that are common to and correlate with the interval between the measured depths of 8432 and 9540 feet in the Sohio Alaska Petroleum Company Nechelik No. 1 well. OConocoPhillips Alaska, Inc. CDl-19A (0-114, 0D:16.000, Wt:62.58) SSS¥ (1795-1796, 0D:2.813) PKR (8670-8671, 0D:5.875) TUBING (0-10792, OD:3.500, ID:2.992) (899O-9OOO) PKR (1O716-1O717, 0D:5.875) NIP (10776-10779, 0D:4.260) (11463-11483) (11504-11520) Perf (11750-11763) (11768-11776) (11780-~?cJ4) Perf (11000-~3) ALPINE CDl-19A APl:1501032029401 SSSV Type:] WRDP Annular Fluid:I Reference Log:I Last Tag:111788 Last Tag Date:111/28/2002 Well Type:l DISP Orig 14/22/2000 Completion:J Last W/O:I Ref Log Date:I TD:111956 ftKB Max Hole Angle:154 deg @ 2711 Angle @ TS: Ideg @ Angle @ TD:114 deg @ 11956 I Rev Reason:lTag, set Inj VIv by limO Last Update:112/8/2002 I Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURF CASING 9.625 PROD CASING 7.000 Top 0 Boffom Tubing String - TUBING Size I Top 3.500 0 Perforations Summar~ Interval TVD 8750-8760 6692-6699 8990-9000 6868-6876 11463-11483 9116-9136 11504-11520 9156-9171 11750-11763 9395-9407 11768-11776 9412-9420 11780-11794 9424-9437 11800-11813 9443-9456 114 0 2825 0 11947 TVD I Wt IGrade I 114 162.581 H-40 I 2393 136.001 J-55 I 9586 126.00 I L-80 I Thread WELDED BTC BTCM Bottom TVD Wt I Grade J Thread 10792 8469 9.30 I L-80 I EUE8RD IZone I status I Ft IsPFI I I101 4 15/ I I101 4 16 6 6 13 6 6 8 6 6 14 6 6 13 6 6 Other (plUgs, equiP.', etc.) .'JEWELRY . · · ... · Depth lTVD I Type / Description 1795 I 1702 I SSSV I MCX Iniection Valve w/1.090" orifice reset 11/28/2002 '1795 I 1702 I NIP IHES X Nipple 8670 I 6633 I PKR IHES THB Prod Packer 10716 I 8396 I PKR IHES THB Prod Packer 10778 I 8455 I NIP IHESXN Nipplew/No-Go ProfiLe 10792 I 8469 I WLEG IWireline Reentry Guide Date I Type I Comment .)3/20001 IPERF Isqz Gun; pen' date approx. Z3/20001 IPERF J Sqz Gun; pen' date approx. '4/2000 I IPERF 121/2 HSC; 60 deg ph '3/2000 I IPERF 12 1/2 HSC; 60 deg ph '3/2000 J IPERF J2 1/2 HSC; 60 deg ph '2/2000 I IPERF 121/2 HSC; 60 deg ph '2/2000 I IPERF 12 112 HSC; 60 deg ph '2/2000 I IPERF J2 1/2 HSC; 60 deg ph ID 1.090 2.813 3.875 3.875 2.750 3.125 ~CHANICAL iNTEGRITY .REPORT' -~. i£G ?,--L=A£E·· :~.?-. LL DATA Cas ing: . . -. ubin~: Hole Size Shoe: ~%R~ MD Shoe Packer TVD Annulus Press Test: r_p_%~.)Q : 15 min%%q~ ; 30 sin %%%%. -w~--CH~-NiC~-L iNTEGP.!TY- PART f2 Cement Vol,~.es :. Amt. LLuer ; Csg ; DV Cmu vol to cover perfs ,, Theoretical TOC Cement Bond Log or No) CBL Evaluation, none above perfs Production Log: Type Evaluation nco 1 SCANNED ~ - ' ...... Re: CD1-19a Disposal Options Subject: Re: CD1-19a Disposal Options ~)~-' ~~, Date: Wed, 10 Oct 2001 10:22:14 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Michael D Erwin <merwin~ppco.com>, ALP Env Coord <n1508@ppco.com>, Clifford L Crabtree <ccrabtr@ppco.com>, Carnmy Oechsli <Cammy_Oechsli@admin.state.ak. us> Mike, My initial response may not have been entirely clear. The approval is to dispose of the recovered clean out material and fluids via annular disposal on CD2 pad. I hope this clarifies the approval. Tom Maunder, PE Sr. Petroleum Engineer AOGCC Tom Maunder wrote: Mike, Thanks for your note explaining the difficulty. Due the unavailability of a disposal annulus, drilling waste was disposed of in your class II well. This attempted disposal has resulted in the well becoming plugged and you are working to clean out the well. The original solid material originated on CD2 and resulted from the drilling of CD2-15. Some additional fluid, water and diesel, used to facilitate the cleanout activity is now present in the total volume of about 900 bbls. The mixture you have is not materially different from the waste stream normally generated on the rig and normally disposed of via annular disposal. I have reviewed this request with Mrs. Taylor and we concur that your request is appropriate. She has authorized me to inform you that your request to dispose of the material you have recovered from your clean out activities is approved. This approval is valid for the duration of your cleanout operation. Please keep us informed of your progress and call if you need to discuss. Tom Maunder, PE Sr. Petroleum Engineer AOOCC >> >> >> >> Michael D Erwin wrote: Your approval is requested to permit us to take wash fluids and spud mud from CD1-19a on Pad 1 to Pad 2 for annular disposal. We are currently holding approximately 910 bbi of work fluids and mud in work tanks that have been washed out of CD l-19a over the past 2 days. Well CD1-19a is currently not taking fluids after plugging up over the weekend with spud mud injected from Doyon lg while drilling CD2-15. We need the tanks emptied in order to continue washing out CDl-19a to return it to injection service. The work fluids consist of '10% water and 30% diesel- both were wash fluids I of 2 10111101 2:55 PM Re: CDl-lga Disposal Options ·., ' ( during the cleanout process, and 60% spud mud from CD2-15. Our last efforts to inject into 1-19a failed at 4000 psi. Attempts to filter the fluids plugged the sock filters after 17 bbls. At this time our best options for disposal include continuing to work to filter fluids into our Class 1 well without plugging it off, or annular disposal which is currently in progress at Pad 2. Your understanding and prompt reply would be greatly appreciated as we have work crews standing by. Mike Envin 907/265.1478 (office) 907/240-5817 (cell) Tom Maunder <tom maunder~,admin.state.ak, us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 10/'11/01 2:55 PM Subject: CDl-19a Disposal Options Date: Wed, 10 Oct 2001 09:11:54 -0800 From: "Michael D Erwin" <merwin@ppco.com> To: tom_maunder@admin.state.ak.us CC: "ALP Env Coord" <n1508@ppco.com>, "Clifford L Crabtree" <ccrabtr@ppco.com> Tom, Your approval is requested to permit us to take wash fluids and spud mud from CD1-19a on Pad 1 to Pad 2 for annular disposal. We are currently holding approximately 910 bbl of work fluids and mud in work tanks that have been washed out of CD1-19a over the past 2 days. Well CD1-19a is currently not taking fluids after plugging up over the weekend with spud mud injected from Doyon 19 while drilling CD2-15. We need the tanks emptied in order to continue washing out CDl-19a to return it to injection service. The work fluids consist of 10% water and 30% diesel - both were wash fluids during the cleanout process, and 60% spud mud from CD2-15, Our last efforts to inject into 1-19a failed at 4000 psi. Attempts to filter the fluids plugged the sock filters after 17 bbls. At this time our best options for disposal include continuing to work to filter fluids into our Class 1 well without plugging it off, or annular disposal which is currently in progress at Pad 2. Your understanding and prompt reply would be greatly appreciated as we have work crews standing by. Mike Erwin 907/265-1478 (office) 907/240-5817 (cell) 1 of I 10110/01 9:48 AM, MEMORANDUM State of Alaska Alaska OII and Gas Consswation Commission TO: Julie Heusser--~Y~,~\.~.¥\'0~ DATE: March 30, 2001 Chairman ~ SUBJECT: Mechanical Integr~y Tests THRU: Tom Maunder ,~~' Phillips P.I. Supervisor CD1 Alpine ~t. [~A,-(~) \ Colville River Unit FROM: Chuck Scheve Alpine Petroleum Inspector NON- CONFIDEN~L Type INJ. Fluid Codes F = FRESH WATER INJ. G = GA8 INJ. ,S = SALT WATER INJ. N = NOT INJECTING Type Test ' M= Annulus Monitoring P= Standard Preesure Test R= Intm~ Racl~ve Tracer Survey D= Dilfemntial Temperature Test I= Initial Test 4= Four Year ~ W= Test dudng Workover O= 'Other (describe in nome) Tsst's ll~ails I traveled to the Phillips Alpine location and witnessed the initial _m_e.~:hanical int©grity tests on 9 injection wcll~s. All pretest pressures were observed for 1 hour+ while waiting for-i~nping cqui..pment 't0-arriVc an~d'~vCrc 'found to bc Stable. A s ~tnX~.~ awn__ulus pressure test was th= ~,ed with all 9w©l!s.~~ng~ ~_~,~intqF~.. ity'. '. .i ~_ . . , ~ ~, ~::_..~._~: ~. _~.::.-:_~::..: .. · ~ _. , .... _ ,., ..... , ........... , ....... ~,r ,.. . M.I.T.'s pertormed::.,':J[",.' '". Attachments: Number ot Failures:!:...'.0'::,"='" . Total Time 'during tests: MIT report form 5/12100 L.G. 010330-MIT Alpine-CS 414101 ' STATE OF ALASKA ('" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1~ Status of well Classification of Service Well , , Oil D Gas ~] Suspended D Abandoned D Service [~] Cuttings Disposal Well 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-040 / 300-128 / 300-111 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20294-01 4. Location of well at surface ~7.~'~..7..~T~::r~;~,.-'~-,,. L~''~'~.,~,..~-,~...,9. Unit or Lease Name 351' FNL, 2447' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385873, 5975778) ! DATE ~ V~lr-tt~ Colville River Unit At Top Producing Interval i -~'._~_:~r...~_ ;.~ i.~ '~ 10. Well Number 972' FSL, 69' FEL, Sec. 29, T12N, R5E, UM (ASP: 388714, 5982339) ~ VERIFIED '! iF,.~~ CD1-19A 1736' FNL, 3325' FEL, Sec. 33, T12N, R5E, UM (ASP: 390706, 5979599) Colville River Field 5. Elevation In feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25558, 25557 & 25558 12. Date Spudded ,13. Date T.D. Reached 14. Date C.omp., S_usp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 5, 2000 April 17, 2000 ~000,,~ I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 11956' MD / 9595' TVD 11860' MD / 9502' TVD lYES r~ No DI N/A feet MD 896' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens, GR/CCL, USIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16' 62.5# H-40 Surface 114' 24" 10 cu yds Portland Type 3 9.625' 36# J-55 Surface 2825' 12.25" 860 sx AS III LW, 230 sx Class G 7" 26# L-80 Surface 11947' 8.5' 566 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8750'-8760' MD 6692'-6699' TVD 4 spf 3.5" 10792' 8671', 10716' 8990'-9000' MD 6868'-6876' TVD 4 spf 11463'-11483' MD 9116'-9136' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11750'-11763' MD 9395'-9408' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11504'-11520' MD 9156'-9172' TVD 6 spf N/A 11768'-11776' MD 9412'-9420' TVD 6 spf 11780'-11794' MD 9424'-9438' TVD 6 spf 11800'-11813' MD 9443'-9456' TVD 6 spf. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. .,^ RECEIVED $[¢ o? 2ooo An~ge Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 10350' 6835' Base Alpine 10407' 6852' N/A 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is tree and correct to the best of my knowledge. Questions? Call Brian Robertson 265-6034 Signed ~'~', ~ Title Alpine Drillin.q Team Leader Date ~i~"~ ~' G. C. Alvorcl Prepared by Sharon AIIsup-Dralre INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none". RECEIVED Form 10-407 SEP 07 2000 Aladm Oit & Gas Cons. Commission Anchorage Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CDi-19A RIG:DOYON 19 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT BLOCK: SPUD:04/01/00 START COMP:05/21/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20294-01 04/01/00 (D1) MW: 10.0 VISC: 54 PV/YP: 45/ 0 APIWL: 20.5 TD/TVD: 2825/2393 (2825) MONITOR WELL. WT UP TO 11 PPG. SUPV:DONALD LUTRICK Move rig to CDi-19A. Spot and level rig. Ice plug in tree, thaw. Weight up mud from 9.8 to 10 ppg. 04/02/00 (D2) TD/TVD: 2825/2393 ( SUPV:DONALD LUTRICK MW: 10.0 VISC: 56 PV/YP: 12/31 0) TEST BOP APIWL: 21.0 PJSM. Dowell pumped 25 bbls diesel down tubing while taking returns out annulus to outside kill tank. Displace well to 2190' w/10 ppg mud. Had diesel returns. Bullhead 50 bbls 10.0 mud to shoe. Monitor well. weight up system to 11.0 ppg. Displace well to shoe w/ll.0 mud. Used drillers method to displace to 2190'. Bullhead 70 bbls 11.0 ppg mud. Bullhead 235 bbls 13.7 mud down tubing and annulus. Mix and pump 35 bbls 15.0 ppg mud down tubing. Monitor well. No flow out tubing. PJSM. 04/03/00 (D3) MW: 9.0 VISC: 47 PV/YP: 9/17 APIWL: 17.4 TD/TVD: 2825/2393 ( 0) BLEEDING. SUPV:DONALD LUTRICK/PAT REILLY N/D tree. N/U BOPE and test to 300/3500 psi. Pump mud down tubing take returns out annulus. Pump more mud, bleed off 10 bbls mud from annulus. Approx. flow .5 gal/min. Shut well in. Pump mud down DP. Shut well in. PJSM. Pump 10 ppg mud through choke. 200 bbls, shut in and monitor pressure. Bleed 50 bbls back, shut in. Monitor pressure. 04/04/00 (D4) TD/TVD: 2825/2393 ( SUPV: MW: 9.6 VISC: 45 PV/YP: 11/23 0) PICKING UP 5" APIWL: 16.0 DONALD LUTRICK/PAT REILL Pump 203 bbls 9 ppg mud, shut in and monitor. Bleed, shut in, and monitor pressure. RIH, tag up @ 2879', wash to 2962', packing off, pull up to 2820'. Circ and condition. PJSM. Pump cement. Pull 6 stds to 2250'. Squeeze cement. Bleed off pressure, check flow, none, open well, break circ. and circ out thick mud, dry job. RECEIVED SEP 07 2000 Alaska 0~; & Gas Cons, Commission A~chorage Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/05/00 (D5) MW: 9.7 VISC: 41 PV/YP: 9/19 TD/TVD: 3225/2647 (400) DRILLING @ 4050. SUPV: APIWL: 10.0 DONALD LUTRICK/PAT REILL L/D tubing. RIH w/HWDP. Wash from 2005' to 2015'. Test 9-5/8" casing to 2500 psi. Wash cement stringers from 2015 to 2680', drill cement from 2680' to 2855'. CBU. Drilling from 2889' to 3225'. 04/06/00 (D6) MW: 9.8 VISC: 43 PV/YP: 10/26 TD/TVD: 5853/4572 (2628) DRILLING 6400' SUPV: APIWL: 5.5 DONALD LUTRICK/PAT REILL Drilling from 3225' to 4329'. Sweep hole, CBU monitor well. Short trip to 2717'. Drill from 4329' to 5853'. Circ hole clean w/sweep. Wiper trip pull to 5377', pump out to 4900' 04/07/00 (D7) MW: 9.8 VISC: 44 PV/YP: 10/21 TD/TVD: 7713/5933 (1860) DRILLING AHEAD @ 8152. SUPV: APIWL: 4.6 DONALD LUTRICK/PAT REILL RIH. Drill from 5853' to 6925'. Lost 75% returns, pump 40 bbls LCM pill. Drill from 6925' to 6995'. Lost 110 bbls mud since losses started. Drill from 6995' to 7376'. Circ high vis sweep, check flow. Wiper trip, pump out and backream to 5850'. RIH slowly to 7376', wash and ream from 7285' to 7376'. Drill from 7376' to 7713'. Lost 150 more bbls mud. 04/08/00 (D8) MW: 9.9 VISC: 51 PV/YP: 12/21 TD/TVD: 8825/6248 (1112) DRILLING AT 9165' SUPV: APIWL: 3.9 DONALD LUTRICK/PAT REILL Drill from 7713' to 8804'. Kick while tripping drill. Circ low/high sweep. Wiper trip, pump/backream out to 7375'. P0H to 2810'. RIH to 8804', wash-ream 8710' to 8804'. Drill from 8804' to 8825'. 04/09/00 (D9) MW: 9.9 VISC: 46 PV/YP: 11/24 TD/TVD: 9992/7712 (1167) DRILLING @ 10046. SUPV: APIWL: 4.1 DONALD LUTRICK/PAT REILL Drill from 8825' to 9445'. Kick while drilling drill. Drill from 9445' to 9851'. circ lo/hi sweep, check flow. Short trip to 8330'. Wash/ream tight spot @ 9135'. Check flow. Drill from 9851' to 9992'. Spill drill. RECEIVED SEP 07 ?000 Alaska 0~I & Gas Cons, Commission An~orage (.. RECEIVED Date: 06/15/00 ARCO ALASKA INC. SEP 07 ~.0~.!0 Page: 3 Anchorage 04/10/00 (DZ0) ~W: 10.0 V'rSC: 48 PV/¥~: 11/27 A?T~T,: 3.3 TD/TVD:l1065/8732 (1073) TEST BOP SUPV: DONALD LUTRICK / BRIAN ROBER Drilling from 9992' to 11065'. Circ lo/hi vis sweep. Circ hole clean. Check flow. POH to 8700'. No problems. Check flow. Pump slug. POH. Tight spot at 5470'. Ream out OK. suspect key seat. Monitor well at shoe and BHA. 04/11/00 (Dll) TD/TVD:l1065/8732 ( SUPV: MW: 10.0 VISC: 47 PV/YP: 11/24 0) 10 STD WIPER TRIP AT 11090' APIWL: 3.3 DONALD LUTRICK / BRIAN ROBER Test BOPE to 300/3500 psi w/annular to 2500 psi. RIH. Attempt to break circ. Packed off around BHA below jars. Work pipe from 10994' to 10870'. Establish circ while reciprocating and rotating pipe from 10870' to 10775'. Pump out to 10415'. Rotate and reciprocate pipe from 10415' to 10325'. Fine sand in returns. Circ sweep. Large amount of sand in returns. 04/12/00 (D12) MW: 10.0 VISC: 47 PV/YP: 10/34 TD/TVD:l1323/8981 (258) DRILLING AHEAD @ 11381' SUPV:SCOTT REYNOLDS APIWL: 3.6 Wash and ream from 10425' to 11065'. Circulate around hivis sweep. Drill from 11065' to 11089'. Circulate around hivis sweep. Monitor well. Wipertrip to 10137'. RIH ok to 10800'. Ream to bottom. Slow reaming from 11070' to 11089'. Drill from 11089' to 11323'. 04/13/00 (D13) MW: 10.0 VISC: 45 PV/YP: 11/34 TD/TVD:l1536/9187 (213) WIPERTRIP F/11565' T/10137' SUPV:SCOTT REYNOLDS Drill from 11323' to 11536'. APIWL: 3.3 04/14/00 (D14) MW: 10.0 VISC: 44 PV/YP: 12/33 APIWL: 303.0 TD/TVD:l1692/9387 (156) SHORT TRIP FROM 11721' TO 10137'. SUPV:SCOTT REYNOLDS Drill from 11536' to 11564'. Circulate around hivis Sweep. Wipe hole from 11565' to 10130'. Back ream through tight spots from 11090' to 10890' Circulate around hivis sweep. Drill from 11564' to 11692' 04/15/00 (D15) MW: 10.0 VISC: 44 PV/YP: 12/36 APIWL: 3.3 TD/TVD:l1812/9455 (120) POOH FOR NEW BIT. SUPV:SCOTT REYNOLDS Drill from 11692' to 11719'. Wipe hole to 10140' Circulate around hivis sweep. Monitor well, static. Wipe hole to 10140'. Wash & backream from 11275' to 10808'. RIH, tag up hard @ 10833', wash & ream thru tight spot, slide thru Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 tight spot w/no pumps, hole smooth. Tag up again @ 11200', wash & ream until pipe slid thru with no problems. Hard reaming last stand to bottom. Circulate around hivis sweep. Follow sweep with mud conditioned with lubetex. Drill from 11719' to 11812'. 04/16/00 (D16) TD/TVD:l1812/9455 ( SUPV:SCOTT REYNOLDS MW: 10.1 VISC: 49 PV/YP: 12/33 0) DRILLING AHEAD @ 11881'. APIWL: 3.0 Circulate around hivis sweep. Monitor well, static. POOH to 9880' wiping out some tight spots from 11200' to 10900'. Hole fill is good, monitor well, static. Continue to POOH from 9800' to 5300'. Screw in and backream tight spots @ 6210', 5995', 5300', 5000'. Monitor well ~ shoe, static. POOH. ream from 10804' to 11770'. 04/17/00 (D17) MW: 10.2 VISC: 46 PV/YP: 13/31 APIWL: 2.9 TD/TVD:l1956/9595 (144) RIGGING UP CASING EQUIPMENT. SUPV:SCOTT REYNOLDS / PAT REILLY Continue to ream from 11770' to 11812'. Drill from 11812' to 11956'. Circ hi vis sweep, circ. Spot Soltex pill @ 11956'. POOH to 11250' swabbing hole. Pump out from 11200' to 10740', check flow. RIH smooth to 11505', pull to 11290', hole swabbing, pump out from 11290' to 10547'. POOH work through tight spot @ 6272'. Monitor well @ 6070', pump dry job. Backream from 5445' to 5415', continue to pump out to 4970'. Continue circ, pump dry job, blow down. POOH. 04/18/00 (D18) MW: 10.0 VISC: 39 PV/YP: 10/21 APIWL: 3.4 TD/TVD:l1956/9595 ( 0) RIGGING UP CEMENTING EQUIPMENT. SUPV:SCOTT REYNOLDS / PAT REILLY Continue POOH. Monitor well at shoe. Rig up to run 7" PJSM. Run 7" casing. Cir¢ casing capacity. Run 7" casing to 5678', hole taking 18 bph. CBU 2 times, losing 20 bph. Run 7" casing to 6993', hole took 15 bbls. CBU. Run 7" casing to 8946' hole took 168 bbls. Circ, losing 100 bph, spot LCM pill @ 6900'. Run 7" casing to 10848', hole took 46 bbls. Circ/recip losses= 60 bph. 04/19/00 (D19) MW: 9.0 VISC: 28 PV/YP: 1/ 3 APIWL: 0.0 TD/TVD:l1956/9595 ( 0) DRILLING CEMENT ~ 11,518. SUPV:SCOTT REYNOLDS / PAT REILLY Run 7" casing. Circ/work casing down from 11912' to 11947' and land casing, initial loss rate 60 bph. Circ/cond pump LCM sweep. PJSM. Pump cement plug. Install packoff and test to 5000 psi. 04/20/00 (D20) MW: 9.0 VISC: 31 PV/YP: 3/ 6 APIWL: 0.0 TD/TVD:l1956/9595 ( 0) 2ND PASS WITH USIT. SUPV: SCOTT REYNOLDS / PAT REILLY Continue to SLM in hole to 11472'. Wash and ream from 11472' to 11492'. Reaming @ 250 fph. '$EP 0 7 000 Alaska ~ & Gas Cons, Commission CEIVED Date: 06/15/00 ~CO ~,~S~ ~C. SEP 0 7 ~000 Page: 5 WELL SUMMARY REPORT Alaska Oil & Gas Cons. C~mm'~iOO Circulate clean. Test casing' to 3500 psi, go~. Drill' cement from 11492' to 11651'. Pump hivis sweep. Drill cement from 11651' to 11860'. tag up on float collar. Circulate hivis sweep around hole clean, losing brine over shakers - reduce pump rate and change screens. POOH to 7100'. PJSM. PU USIT tools. 04/21/00 (D21) MW: 9.0 VISC: 31 PV/YP: 3/ 6 APIWL: 0.0 TD/TVD:l1956/9595 ( 0) RIGGING UP TO PUMP DIESEL FOR FREEZE PROTECT. SUPV:SCOTT REYNOLDS / PAT REILLY RIH w/logging tools USIT. RIH w/wireline log from 11947' to 6500'. R/U to run tubing. PJSM. Run tubing. 04/22/00 (D22) MW: 0.0 VISC: 31 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1956/9595 ( 0) SUPV:SCOTT REYNOLDS / PAT REILLY Run 3.5" tubing. N/D BOPE. N/U tree and test to 5000 psi. Secure well. Release rig @ 0900 hrs. REMEDIAL AND COMPLETION OPERATIONS WELL:CDi-19A RIG:DOYON 19 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT BLOCK: SPUD:04/01/00 START COMP:05/21/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20294-01 05/21/00 (C23) TD:11956'' PB:l1860' 05/22/00 (C24) TD:11956' PB:l1860' 05/23/00 (C25) TD:11956' PB:l1860' 05/24/00 (C26) TD:11956' PB:11860' RIH W/SCRAPER ASSEMBLY MW: 9.6 KCL SUPV:SCOTT REYNOLDS PJSM. Move rig from CD1-44 to CDi-19A. Accept rig @ 1430 hrs. 5/21/00. PJSM. Set two-way check and remove tree. NU BOPE. Test BOPE to 250/2500 psi. Pull 2-way check. WLL - TOH AFTER SETTING C MW: 9.6 BRINE SUPV:DEARL W. GLADDEN TOH with 3.5" tubing (kill string). TIH with CS assy. R/U Schlum, problem, cannot get pressure test on lubricator. Could not get 3.5 x 6 VBRs to test on lubricator. Change upper rams to 4.5" x 7" VBRs. TOH W/ BAKER K1 STINGER MW: 9.6 BRINE SUPV:"DEARL W. GLADDEN RIH with gun run #1, shoot 8990'-9000'. TOH'. RIH w/Baker cement retainer and set @ 8950'. PJSM. Re-test lub, failed, RIH w/gun run #2, shot @ 8750' to 8760'. TIH w/ Baker K-1 stinger @ 8935' CIRC SWEEP AT 9223' MW: 9.6 KCLPLY SUPV:DONALD LUTRICK Pump 12 bbls mud acid into perfs. PJSM. Pump cement slurry. Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 05/25/00 (C27) TD:11956' PB:11860' 05/26/00 (C28) TD:11956' PB:l1860' 05/27/00 (C29) TD:11956' PB:11860' 05/28/00 (C30) TD:11956' PB:11860' 05/29/00 (C31) TD:11956' PB:l1860' Sting into retainer. Pump cement into bottom perfs. Pull out of retainer. Spot cement on retainer. RIH. Tag cement at 8830'. CBU. Drill out cement from 8830' to 8940'. Drill cement and cement retainer at 8950'. No cement below retainer. CUT AND SLIPM DRLG LINE A MW: 9.6 KCLPLY SUPV:DONALD LUTRICK POH. Wash out BOP stack. Function rams. RIH w/scraper to 9223'. Circ sweep. POH. RIH w/cement retainer on 3.5" DP. Set retainer at 9050'. Sting into retainer. CBU. PJSM. Spot cement on top of retainer. POH to 7842'. CBU. Squeeze away cement. Pump slug. POH W/ JUNK BASKET / GUAG MW: 9.6 KCLPLY SUPV:DONALD LUTRICK RIH, tag cement at 8388'. Drill out cement from 8388' to 9050'. Drill out cement retainer. CBU at 9119'. RIH. Circ sweep. PREP TO RUN 3 1/2" TBG MW: 9.7 KCLPLY SUPV:DONALD LUTRICK PJSM. Run 5.95" GR and JB to 10800'. Sticky at 8200'. Work free. Run USIT log from 10600' to 8500'. RIH w/scraper to 11830'. Circ and condition brine. Monitor well. Pump slug. MOVE RIG TO CD1-09 MW: 9.6 BRINE SUPV:DONALD LUTRICK RU to run tubing. PJSM. RIH w/3.5" straddle pkr completion. ND BOPE, NU tree and test to 5000 psi. PJSM. Reverse circ brine. MW: 9.6 SUPV:DONALD LUTRICK Reverse circ diesel. Set BPV. Secure. well. BRINE RECEIVE,'D SEP 0 7 !000 Alaska ~ & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(CD1-19A(W4-6)) WELL JOB SCOPE JOB ~UMBER ' CD1-19A DRILLING SUPPORT-CAPITAL 0530001632.3 DATE DAILY WORK UNIT NUMBER 06/04/00 PERFORATE & INJECTION PROFILE 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 YESI YES SWS-ELMORE CHANEY FIELD AFC# CC# Signed ESTIMATE 998C22 NKALPN4OT Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 1931 PSI 0 PSI 0 PSII 50 PSII 50 PSI DAILY SUMMARY PERFORATED INTERVAL (11463' - 11483') W/2-1/2" HSC, 35 B BH CHGS, 6 JSPF, ON 60 DEGREE PHASING. OBTAINED TEMP SURVEY. LOGGED PRESSURE STATION AT 11813'MD (SENSOR DEPTH.) PERFS WOULDNq' TAKE INJECTION. PUH TO LUBRICATOR AND PI WAS INITIATED AT MAX PRESSURE OF 4600#. WAS ABLE TO ESTABLISH INJECTION. ALSO LOGGED PRESSURE FALL-OFF FOR 60 MIN AFTER SD OF PUMPING. TIME LOG ENTRY 07:30 MIRU SWS 8305 ELMORE, TGSM, PT 3000#. 09:30 RIH W/GUN #6.20'. 10:00 TIE IN AT JEWELRY. 10:20 LU TO SHOOT 11463'-11483'. 2' ADJUSTMENT MADE TO CORRELATE SWS JEWELRY LOG TO ANADRILL MDL. POOH. 11:55 RU SWIVEL-2 WTBARS-GR-CCL-PRESS-TEMP-GRADIO-CALIPER-1.69" CFS-3.5 FBS SPINNER. 12:10 LD @ 120 FPM, BASELINE TEMP FROM 100' - TD. WHP BUILT UP TO 2700#. 14:00 TIE IN UP. 14:36 LOG PRESSURE/TEMP STATION AT 11813' SENSOR DEPTH. BEGIN PI TO SEE IF PERFS WILL TAKE INJECTION. PI .2 BBBLS DIESEL. WHP TO 3500#...STOP PI...WHP PRESSURE NOT BLEEDING DOWN. HOLD FOR 10 MIN. BD WHP TO ZERO INTO SLOP TRL. 14:57 SI BD TO SLOP TRL, CONTINUE TO LOG STATION TO MONITOR PRESSURE. 15:40 PUH TO LUBRICATOR TO REPEAT PRESSURE STATION WHILE ATTEMPTING TO PI. 16:45 TOOL IN LUBRICATOR, WHP=0#, BEGIN PI TO MAX PRESSURES OF 5000#. CYCLE PRESSURE UP/DOWN, ABLE TO SLOWLY ESTABLISH RATE OF 1.8-2 BPM @ 3300# PI PRESSURE. 17:15 INJECTION RATE FAIRLY STABLE AT 2 BPM/3300#. CONTINUE PI TO 120 BBLS AWAY. LOST 7 MINS OF DATA FROM 17:32 - 17:39 WHEN TOOL SIGNAL WAS LOST. RESTARTED LOG AT 17:39. 18:05 SD PUMP, CONTINUE TO LOG PRESSURE STATION IN LUBRICATOR FOR 60 MINUTES TO MONITOR FALL OFF. 19:06 END PRESSURE FALL OFF LOG, SHUT SWAB, BD, RD. 20:30 RDMO TO SPOT ON CD1-24. RECEtVED SEP 07 2000 Alaska 0{~ & Gas CoDs. Commiss'~n Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(CD1-19A(W4-6)) WELL JOB SCOPE JOB ~UMBER ' OD1-19A DRILLING SUPPORT-CAPITAL 0530001632.3 DATE DAILY WORK UNIT NUMBER 06/03/00 PERFORATE 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 NOI YES SWS-ELMORE CHANEY FIELD AFC# CC# Signed ESTIMATE 998C22 NKALPN4OT Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 50 PSI 50 PSI 0 PSI 0 PSII 150 PSI 50 PSI DAILY SUMMARY SWAPPED E/LINE UNIT TO .39 LINE. PERFORATED INTERVALS (11750 '- 11763') & (11504' - 11520') W/2-1/2" HSC, 35 B BH I CHGS, 6 JSPF, ON 60 DEGREE PHASING. JOB IN PROGRESS I TIME 08:30 14:50 16:45 18:00 18:15 19:45 20:45 21:00 22:15 22:45 LOG ENTRY STRIP OFF BAD .23 CABLE (9200'), VERIFY CALBE LENGTH...TOO SHORT TO USE FOR THIS JOB (10100' REMAINING LENGTH), RU .39 LINE/REBUILD BOP'S TO COMPLETE JOB. PRESSURE TEST BOPS. TEST GOOD. SHOOT THROUGH HEAD/SAFE EQUIP., BEGIN RU. RIH W/GUN 4. 13'. OK UP WEIGHT & TIE IN AT JEWELRY, CONTINUE RIH. LU AND SHOOT 11750'-11763'. POOH. RIH W/GUN 5. TIE IN TO JEWELRY. LU TO SHOOT 11504'-11520', REF JEWELRY LOG 6/2/00. THIS CORRELATES TO ANADRILL MDL LOG DEPTHS OF 11506'-11522'. LOWER PERF ZONES WERE ON DEPTH W/OPEN HOLE LOG...DEPTH ADJUSTMENTS WERE OK'D BY PAD ENGINEER. POOH. AT SURFACE, RD. RDMO. RECEIVED SEP 0 7 2000 AFa~a 0/I & Gas Co~s. Commission WELL JOB SCOPE JOB ~UMBER ' CD1-19A DRILLING SUPPORT-CAPITAL 0530001632.3 DATE DAILY WORK UNIT NUMBER 06/02/00 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 NO YES SWS-ELMORE CHANEY FIELD AFC# CC# Signed ESTIMATE 998C22 NKALPN4OT Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 0 PSI 0 PSI 0 PSII 75 PSII 75 PSI PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(CD1-19A(W4-6)) DAILY SUMMARY PERFORATED 3 BOTTOM PERF INTERVALS (11768' - 11776'), (11780'- 11794'), (11800 - 11813') W/2-1/2" HSC, 35 B BH CHGS, 6 JSPF, ON 60 DEGREE PHASING. STRANDED LINE AT 9100'. STRAIGHTENED OUT BIRDS NEST. WILL SWAP TO BIG LINE. JOB IN PROGRESS. TIME LOG ENTRY 07:30 MIRU SWS 2128 ELMORE, TGSM, PT 3000#. 09:30 RIH W/WTBAR-CCL-SAFE-GUN. 2.5"X13', 6 SPF, BIG HOLE. OAL=33'. 10:15 LOG TIE-IN PASS THROUGH JEWELRY. CONTINUE RIH TO TD. 10:40 LU AND SHOOT GUN 1 AT 11800-11813'. POOH. 11:45 RIH W/GUN 2. 14'. 12:25 CK TIE IN AT JEWELRY. RIH. 12:40 LU TO SHOOT 11780'-11794'. POOH. 13:40 RIH W/GUN 3. 8'. 14:25 TIE IN AT JEWELRY. 14:30 LU TO SHOOT 11768'-11776'. 15:40 RIH W/GUN 4. 13'. 16:00 STRANDED LINE AT 9100'. WAS ABLE TO PULL BAD SECTION BACK UP THROUGH FLOW TUBES AFTER CLOSING BOP ONE TIME. TRIED TO REPAIR CABLE, BUT WAS NOT WORKING OUT. 21:00 POOH. WILL RU BIG LINE TOMORROW. 22:30 AT SURFACE, BD LUB, RD. 23:30 RDMO. RECEIVED .$EP 0 7 , 000 Alaska 0';~ & Gas Co~s Commission Ai~c~orage _B I m .i m. I · ~ 'i . J ;J .i I i i1 ..j ~ki J iT.. J .iL..- J d J d I iL I d I d i · ~ ,~ ~ ". SURVEY CALCULATION AND FIELD WORKSHEET Job,o. 0450-00022 Sidetrack No. 1 Page 1 of 4 ![e']-' I =~t Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD -_ Well Name & No. PAD CD#1/19A Survey Section Name CD1-19A MWD BHI Rep. C MILCHAK ~ilrr~~ WELL DATA . · Target 3'VD (F'r) Target Coord. N/S Slot Coord. N/S -351.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLF] ssF] Target Description Target Coord. E/W Slot Coord. E/W 2447.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOff[-)tI 30mr-I lomEi Vert. Sec. Azim. 48.52 Magn. to Map Corr. ' 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool - Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DO) (OD) (F'r) (FT) (FT) (FT) (Per lO0 F~ Drop (-) Left (-) MWD 2773.64 53.62 25.80 2362.38 910.63 1062.76 274.91 TIE IN POINT 05-APR-O0 MWD 2827.76 52.52 25.49 54.12 2394.90 949.75 1101.76 293.63 2.08 -2.03 -0.57 6 3/4' M1/XL 1.2 DEG AKO -- 05-APR-O0 MWD 2860.41 51.54 26.52 32.65 2414.98 973.52 1124.89 304.92 3.90 -3.00 3.15 05-APR-O0 MWD 2923.21 49.71 31.04 62.80 2454.84 1019.18 1167.43 328.26 6.28 -2.91 7.20 05-APR-O0 MWD 3018.11 48.22 36.01 94.90 2517.16 1088.28 1227.09 367.74 4.25 -1.57 5.24 05-APR-O0 MWD 3112.13 47.16 38.47 94.02 2580.45 1156.45 1282.44 409.80 2.24 -1.13 2.62 05-APR-O0 MWD 3208.66 45.64 42.91 96.53 2647.04 1225.66 1335.44 455.32 3.68 -1.57. 4.60 06-APR-O0 MWD 3303.68 ' 45.18 44.05 95.02 2713.74 1293.07 1384.54 501.88 0.98 -0.48 1.20 06-APR-O0 MWD 3396.80 45.26 47.31 93.12 2779.35 1359.07 1430.71 549.16 2.49 0.09 3.50 06-APR-O0 MWD 3491.86 45.11 47.69 95.06 2846.35 1426.49 1476.27 598.88 0.32 -0.16 0.40 06-APR-O0 MWD 3587.30 44.47 50.38 95.44 2914.09 1493.71 1520.35 649.63 2.10 -0.67 2.82 06-APR-O0 MWD 3682.65 44.06 51.50 - 95.35 ' 2982.37 1560.20 1562.28 701.31 0.93 -0.43 1.17 06-APR-O0 MWD 3777.80 44.96 54.75 95.15 3050.23 1626.67 1602.29 754.66 2.57 0.95 3.42 06-APR-O0 MWD 3873.38 45.78 58.95 95.58 3117.39 1693.94 1639.45 811.59 3.24 0.86 4.39 _. -- 06-APR-O0 MWD 3968.41 45.55 59.09 95.03. 3183.80 1760.77 1674.44 869.87 0.26 -0.24 O. 15 06-APR-O0 MWD 4064.31 45.15 58.91 95.90 3251.20 1827.86 1709.58 928.35 0.44 -0.42 -0.19 ................................................... 06-APR-O0 MWD 4158.51 43.13 58.69 94.20 3318.80 1892.41 1743.5~ 984.46 2.15 -2.14 -0.23 V 06-APR-O0 MWD 4252.65 42.47 58.49 94.14 3387.87 1955.38 1776.89 1039.05 0.72 -0.70 -0.21 06-APR-O0 MWD 4349.19 42.37 57.38 96.54 3459.14 2019.62 1811.46 ' 1094.24 0.78 -0.10 -1.15 SF..P- 06-APR-O0 MWD 4443.09 42.36 56.99 93.90 3528.52 2082.18 1845.75 1147.41 0.28 -0.01 -0.42 Alaska Oii& Gas Cons. Commission --__ 06-APR-O0 MWD 4540.01 42.43 57.66 96.92 3600.10 2146.75 1881.03 1202.42 0.47 0.07 0.69 06-APR-O0 MWD 4635.17 42.69 58.12 95.16 3670.19 2210.26 1915.24 1256.94 . 0.43 0.27 0.48 -_ 06-APR-O0 MWD 4825.43 42.79 57.50 190.26 3809.93 2337.69 1984.03 1366.21 0.23 0.05 -0.33 06-APR-O0 MWD 5016.91 42.84 59.54 191.48 3950.39 2465.83 2051.98 1477.18 0.72 0.03 1.07 ' "SURVEY CALCULATION AND FIELD WORKSHEET Job,o. S,d. ack,o., Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig://19 Field ALPINE FIEL~D ~ Well Name &'No.-- -- -P-~)-#-~I~AA Survey Section Name CD1-19A MWD ....... BHIRep. CMILCHAK ~'NIP'B~ WELL DATA Target'l'VD (F"q Target Coord. N/S Slot Coord. N/S -351.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL E] ssE] Target Description Target Coord. E/W Slot Coord. E/W 2447.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) BuilcAWalk\DL per: 100ffl~ 30mE] 10m0 Vert. Sec. Azim. 48.52 Magn. to Map Corr. ' 0.000 Map North to: OTHER SURVEY DATA Survey -Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) (DD) (FT) (F'D (FT') (FT) (Per lOO FT) Drop (-) Left (-) 06-APR-00 MWD 5206.18 42.30 59.08 189.27 4089.78 2591.60 2117.33 1587.29 0.33 -0.29 -0.24 06-APR-00 MWD 5396.59 41.27 58.51 190.41 4231.76 2716.44 2183.05 1695.81 0.56 -0.54 -0.30 06-APR-00 MWD 5587.09 41.83 60.65 190.50 4374.33 2840.43 2247.01 1804.76 0.80 0.29 1.12 06-APR-00 MWD 5776.66 42.15 60.89 189.57 4515.23 2964.37 2308.94 1915.44 0.19 0.17 0.13 -_ 07-APR-00 MWD 5968.01 42.36 60.02 191.35 4656.86 3090.25 2372.39 2027.37 0.32 0.11 -0.45 07-APR-00 MWD 6156.54 42.77 59.88 188.53 4795.72 3215.25 2436.25 2137.76 0.22 0.22 -0,07 07-APR-00 MWD 6348.62 42.57 59.95 192.08 4936.95 3342.87 2501.51 2250.40 0.11 -0.10 0.04 07-APR-00 MWD 6443.72 42.15 59.79 95.10 5007.22 3405.69 2533.67 2305.82 0.46 -0.44 -0.17 07-APR-00 MWD 6539.03 44.05 60.93 95.31 5076.81 3469.42 2565.87 2362.43 2.15 1.99 1.20 07-APR-00 MWD 6729.37 43.87 60.00 190.34 5213.82 3598.68 2631.00 2477.38 0.35 -0.09 -0.49 07-APR-00 MWD 6918.48 43.36 58.82 189.11 5350.74 3726.78 2697.37 2589.68 0.51 -0.27 -0.62 07-APR-00 MWD 7014.24 43.06 58.77 95.76 5420.53 3791.29 2731.34 2645.75 0.32 -0.31 -0.05 07-APR-00 MWD 7109.61 43.31 61.25 95.37 5490.08 3855.24 2763.96 2702.27 1.80 0.26 2.60 07-APR-00 MWD 7299.57 43.26 61.35 189.96 5628.36 3982.26 2826.50 2816.52 0.04 -0.03 0.05 07-APR-00 MWD 7489.49 42. ! 1 60.71 189.92 - 5767.96 4107.95 2888.86 2929.16 0.65 -0.61 -0.34 07-APR-00 MWD 7678.37 42.82 61.00 . 188.88 5907.30 4232.53 2950.96 3040.54 0.39 0.38 0.15 08-APR-00 MWD 7870.63 43.33 60.86 192.26 6047.74 4360.76 3014.76 3155.30 0.27 0.27 -0.07 0S-APR-00 MWD 8060.95 43.11 60.00 190.32 6186.43 4488.29 3079.07 3268.66 0.33 -0.12 -0.45 ~ I1"" ~ ~ I ~ ~rr,, r~ 08-APR-OO MWD 8252.96 43.01 62.10 192.01 6326.73 4616.25 3142.53 - 3383.36 0.75 -0.05 1.09 ___ 08-APR-00 MWD 8348.05 42.34 61.74 95.09 6396.64 4678.95 3172.66 3440.23 0.75 -0.70 -0.38 ...... SEP 0 7 0e-APR-00 MVVD 8536.01 42.87 62.73 187.96 6534.98 4802.55 3232.13 3552.82 0.45 0.28 0.53 08-APR-00 MWD 8727.99 42.79 64,74 191.98 6675.78 4928~48 3289.88 3669.84 0.71 -0.04 1.05 aia~a 0ti & Gas Cons. Commi~i0n ............................................................ . ...... 09-APR-00 MWD 8917.41 42.75 65.11 189.42 6814.84 5051.87 3344.39 3786.34 0.13 -0.02 0.20 -- __ 09-APR-O0 MWI~" 9013.96 42.10 64.72 96.55 6886.10 5114.35 3372.01 3345.34 0.73 -0.67 -0.40 · SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00022 Sidetrack No. 1 Page 3 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Field A_L__P.!N_~_.F.I_E_..L_D_ ......... Well Name & No. PAD CD#1/19A Survey Section Name CD1-19A MWD BHI Rep. C MILCHAK J~lk~J~l~l~ WELL DATA Target'l'VD (FT) Target Coord. N/S Slot Coord. N/S- -351.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ri ss~ Target Description Target Coord. E/W Slot Coord. E/W 2447.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction DP) Buil~Walk\DL per: 100ft[~ 30m0 10m[1 Vert. Sec. Azim. 48.52 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical ' Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (OD) (FI') (FT) (FT) (Fi') (Per lO0 F'rl Drop (-) Left (-) 09-APR-O0 MWD 9109.77 40.58 63.24 95.81 6958.04 5175.34 3399.76 3902.21 1.89 -1.59 -1.54 09-APR-O0 MWD 9204.90 39.52 61.07 95.13 7030.86 5234.82 3428.33 3956.33 1.84 -1.11 -2.28 09-APR-00 MWD 9298.48 37.04 59.65 93.58 7104.32 5291.54 3456.98 4006.72 2.81 -2.65 -1.5.2 09-APR-O0 MWD 9393.67 34.49 59.77 95.19 7181.55 5346.12 3485.04 4054.76 2.68 -2.68 O. 13 09-AP R-O0 MWD 9489.48 31,15' 59.82 95.81 7262.06 5397.04 3511.16 4099.63 3.49 -3.49 0.05 09-APR-00 MWD 9584.65 28.03 60.58 95.17 7344.80 '5443.05 3534.53 4140.39 3.30 -3.28 0.80 09-APR-O0 MWD 9679.17 27.65 60.99 94.52 7428.38 5486.19 3556.07 4178.92 0.45 -0.40 0.43 09-APR-O0 MWD 9774.67 26.26 60.93 95.50 7513.51 5528.46 3577.09 4216.77 1.46 -1.46 -0.06 09-APR-O0 MWD 9869.63 23.97 62.02 94.96 7599.48 5567.74 3596.35 4252.17 2.46 -2.41 1.15 09-APR-O0 MWD 9965.03 21.26 61.70 95.40 7687.54 5603.43 3613.64 4284.51 2.84 -2.84 -0.34 IO-APR-O0 MWD 10059.86 20.69 61.98 94.83 7776.09 5636.46 3529.66 4314.44 0.61 -0.60 0.30 IO-APR-O0 MWD 10155.22 20.32 61.48 95.36 ' 7865.40 5668.98 3645.48 4343.86 0.43 -0.39 -0.52 IO-APR-O0 MWD 10250.88 19.56 61.85 95.66 7955.33 5700.75 3660.97 4372.57 0.81 -0.79 0.39 IO-APR-O0 MWD 10347.32 19.66 61.40 96.44 8046.17 5732.27 3676.35 4401.05 O. 19 O. 10 -0.47 -- IO-APR-O0 MWD 10442.21 19.24 59.76 94.89 8135.65 5763.17 3691.86 4428.57 0.73 -0.44 -1.73 IO-APR-O0 MWD 10537.71 18.25 59.47 95.50 8226.08 5793.28 3707.38 4455.05 1.04 . - -1.04 -0.30 IO-APR-O0 MWD 10633.08 17.46 59.00 95.37 8316.86 5822.01 3722.3'4 4480.18 0.84 -0.83 -0.49 IO-APR-O0 MWD 10728.34 16.68 60.08 95.26 8407.92 5649.46 3736.52 4504.27 0.88 -0.82 1.13 IO-APR-O0 MWD 10822.86 16.22 59.95 94.52 8498.57 5875.69 3749.90 4527.46 0.49 -0.49 -0.14 ._ IO-APR-O0 MWD 10917.99 15.84 60.14 95.13 8590.00 5901.43 3763.01 4550.22 0.40 -0.40 0.20 ~'~ ~ ! V L,.,, ~ IO-APR-O0 MWD 10987.94 15.60 60.17 69.95 8657.34 5919.99 3772.45 4566.66 0.34 -0.34 0.04 12-APR-O0 MWD 11109.67 15.18. 60.00 121.73 8774.70 5951.64 3788.56 4594.66 0.35 -0.35 -0.14 12-APR-O0 MWD 11202.65 14.97 60.69 92.98 8864.48 5975.31 3800.52 4615.67 0.30 -0.23 0.74 Alaska Oil & Gas Cons. Commission 12-APR-O0 MV~D 11297.94 - 14.66 59.86 95.29 8956.60 5999.16 3812.60 4636.83 0.39 -0.33 -0.87 ,~tl~l'~l-i~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450 X7 Sidetrack No. 1 Page 4 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/19A Survey Section Name CD1-19A MWD BHI Rep. C MILCHAK J~/'~~ WELL DATA Target TVD (F~ Target Coord. N/S Slot Coord. N/S -351.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSI-] Target Description Target Coord. EAN Slot Coord. E/W 2447.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ftl~ 30ml~ lOml-I Vert. Sec. Azim. 48.52 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey . Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (DO) (Fr) (FT) (F'r) (F'T) (Per 100 FT) Drop (-) Left (-) 13-APR-O0 MWD 11394.93 14.34 60.48 96.99 9050.50 6022.95 3824.68 4657.90 0.37 -0.33 0.64 14-APR-O0 MWD 11488.72 14.17 59.71 93.79 9141.41 6045.57 3836.19 4677.92 0.27 -0.18 -0.82 14-APR-00 MWD 11584.55 14.05 59.80 '95.83 9234.34 6068.48 3847.96 4698.10 0.13 -0.13 0.09 . 14-APR-O0 MWD 11678.46 13.88 59.98 93.91 9325.48 6090.70 3859.33 4717.70 O. 19 -0.18 O. 19 . 15-APR-00 MWD 11775.70 13.77 59.50 97.24 9419.90 6113.50 3871.04 4737.77 0.16 -0.11 -0.49 16-APR-00 MWD 11880.64 13.90 59.40 104.94 9521.80 '6138.13 3883.80 4759.38 0.13 0.12 -0.10 16-APR-O0 MWD 11956.00 13.90 59.40 75.36 9594.95 6155.91 3893.01 . 4774.97 0.00 0.00 0.00 Projected Data - NO SURVEY : · . -. V SEP 0'-' """" ~ £VVV 811/00 Sekimberger_ Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic BIrd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 377 company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-19A 20214 CDR/ADN/GR ~ ¢~.~,f ,'~,~ 000417 1 CD1-19A 20214 CDR MD 000417 I 1 CD1-19A 20214 CDR TVD 000417 I 1 CD1-19A 20214 ADN MD 00.0417 I 1 CD1-19A 20214 ADN TVD 000417 I 1 F IVED SlISNE DATE: AUG 0 4 2000 · - ~ ' .~. AJaska 0ii & Gas CoF~s. t;0mmissi01t Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) ~o~-u317. Thank~ol'age 5/20/00 Schlumberger NO. 270 Schlumberger Technology Corporation, by and through is GeoqueSt Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD '~OC~ · C~L~(~ CD1-19A 20226 USIT 000527 1 s,=.£= - - ~^~£: JUN 27 2000 ;Alaska 0ii & Gas Cats. (;0mmJssi0r; Please sign and return one copy of this transmi al to Sherrie at the above address or fax to (90.7) 561-8317.- Thank Schlumberger NO. 253 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-19A PERF RECORD W/I'EMP/PRESS 000602 I 1 CD1-19A PERF RECORD W/TEMP/PRESS 000604 I 1 CD1-19A JEWELRY W/PRESS/TEMP 000601 I 1 CD1-19A PUMP IN INJECTION PROFILE 000604 - I 1 -- ~.-~~-- trlk I ~_IL_ ! ~ I-- 1,2~ SIGN D: ' DATE: - Alaska 0ii & Gas Cons. ~0mmissi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (90.7) 561-8317. Thank you. 6115/00 Re: CD1-19A PTD 200-040 Subject: Re: CDl-19A PTD 200-040 Date: Fri, 09 Jun 2000 11:32:25-0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Michael D Erwin <MERWIN@ppco.com> Mike, I did receive the pressure test information from Brian and it is satisfactory. To my knowledge you have complied with all the requirements necessary to begin injection. We look forward to receiving the step rate information you develop as injection proceeds. Please contact me with any questions. Tom Maunder Petroleum Engineer AOGCC Michael D Erwin wrote: Tom, I believe Brian Robertson sent you the MIT results earlier this week. Assuming you did receive them, are there any other items you would like to see. Are we clear to begin injection? mike Tom Maunder <torn_maunder(~admin. state, ak. us> on 06/05/2000 03:24:39 PM To: Michael D Erwin/AAI/ARCO@Arco cc: Blair Wondzell <blair_wondzell@admin. state, ak. us> Subject: CDl-lgA PTD 200-040 Mike,' Thanks for the completion drawing. We have reviewed the USIT logs and the tubing x casing below the deep packer pressure test. We are satisfied with the information you have provided thus far. The remaining necessary piece of information in the approval process is the IA pressure test. We would appreciate receiving that information at your earliest convenience Please call Blair or myself with any questions. Thanks Tom Maunder ITom Maunder <tom maunder~,admin.state.ak, us> ~'-r-r~e-~m ~eer . Alaska Oil and Gas Conservation Commission 1 of I 6/9/001:09 PM Return phone: ;~65-60~; fax: 265.1515 To-- Tom Maunder- AoGcc Fax.- 276-7542 From.- Brian Robertson Pages: 11 Date: 06/07/00 Re: . Packer / Annulus Test- CD1-19A cc,, M. Erwin [] Urlleat X For Review [] Please Comment [] Please Reply [] Please Recycle Tem~ ; Please find attached the chart and digital output from the pressure te~t on the CDI.t~A Inner annulus. This pressure test verifies tho int~Jrity of the annulus above the upper packer, A later pressure test (pest.~g) was done through the tubing and onto the .ndersido of the lower packer. I believe that Mike Erwin has already forwarded this to you. As dleoassedy I have also attached copies of the daily reports cove~iag the remedial cementing operations. Please call if you require any further details. SCANNED OEC 200 _ _ ii ii ii i _ ill . . . .. Fh]ld ALPINE 81~ No. Country U:S~ Job DaW 6/29/2000 12:00:27 AM ~'. lull I I I i i i i iii Jun-06.,O0 16:26 Frm-ALPIflE TELE~ T-082 P,02/11 F-Ilg? ~.'ementlnR ,lob Administ~ti0n Data Client Client Rep. Well Name Field Name ~gName Dowell Phone Acq. Pr0nt End _FEm. _ .t.n,s ~ DONNIE Wrglclc CD1-~gA 19 I']RUDHOE BAY 6.~J-2434 1 .fAB/Hybrid RDA - 1 Cement Uuit SET P&~ AND TEST Channels Dmleription Acquisition Data 05/29/2000 05/2~/~000 00:] 3:30 05~,9/2.000 00:15:31 05/'29/2000 00:19:3 I OS~9/'ZOOO 00'21~32 , :,".'~:;.2 ..,,.,,~' ':"t;>" ..... 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' '" : ' ' ""¢; .... - ...... ~$~,,'., c ...... ,3-~g-~..A.,,-'., ~0~. ....... . .L.'- ..... ..).. :",,::..,.~"..'~.;.'.:,,.,= ,.:,.,.., .~;~'.~i~.,. ;'%~:.:,:./,'.. ~,~.'~.;?~.,'.:'..~.,, ~.::.,,,,,, ::.,.,: ,, . .....:,,,..~.. :,,.;... =.,,~,...,r ..... .,,::. ....... ,.,..,. ,., .,~ 0~29/2000 02:5~:2¢ i 71.24 t ].Q,3 31370 a~xt~ o. / 121.3 3]qS$ 3,218 0 050'~000 03i00:26 71,34 ............................... :"" ...... ' ................... :"~'"~';' '""~ !;.~s~ct~'(e:~n:2'~::':. ~T~:)i~'~,, ;,,'~ 2~.~, ,. :' .... '"'" :"';' ........." :~'~.~'~."'~' ", ,,;':",... ",.'~ .~ _ .,..,.,,' "- ...... . ,...' :..0~. ...',: r,..,. ...... . ,',",..,. ,..;,.....,.' :.... :..,..,~?,ii:ii.--,,, ..... ._.:..' ........ .., ._.: .....:..,:',., ..: oS~,9~ZO00 03:0:3,:26 71,34]2~.3 3356 ~,:ZJ8 : 0 ~:t~):~,'O~.~'~ .L~'~."~i'~"', i~.~i~* *.':.,'.':' .'.~ ~:~A~: ,': :,'* :. ':~ . ~,.!', :,'.,',,-' I;~L~.,........ ,.: ::,.,: .,.,..,,.,.., :, :.. ,. ,,~.,., .... 05/2~000 03:04:29 71J4 :--- ' ....... '/':'z~-~" ...... ' ' ' ............ "" '"" :'-~"::.:':,.v: ,',, ,,,. ,:,.:,:'.':.,' ,, ;.',/, 'If .:.: ~. ,,.." ;.~.:_. :' 'llt s , , ~ ..... ,. . ,,~ : ~,~,q ~3(~ 321~ .q~ ~;2~,'.~,o.$~.~.:~ ..~t,~:.,..:,: ..I~:4.~, ..... ~, ~a~.., ~,,x',~,,, ,~. ,,. ,~. ~,0,,,~,~, · ',: ~:'.. ,.,.:."., ~:'~,;.., ~, '.. , .. ' ' ':" ,,,'! .... ,';~:c,.~,.;;'-~,, ,, , ,¢,,,~,, . ., ' ')'~ .'~* ..... ~.' '~..' ', ' ,',, ...... l'" 0$/'.ZgD-LMO 0~:0(i:33 ?I,3~ 127,4 : 3352 ............................ ' 3,218 0 '"' ............. ~'"'" '"' ............. ""' ' . ~ .~ . '.,. ' :.'~. ,~ ~ ..... ~ ~ .. ,'. '. ',' ,..,.~ .. ,., _~. 4; . ,..,', ,,., ;:, ,,"% . .", ',,".: ... :.,,,~,i~,' ',.'~ ,',' :'.~,~'O~"','t'?,'~,",~'; ~ '~,7..r,, ,~' '. :.: :;:ar,~Y~.',.: .';., '.'."~ ~'.;.,~ ,. ~"~,..,,,..: ,...,,... ',, ~ .- ,, ...... ~ .... ', ,.,,, ,. . .Mn7%,~,.:;.~., ,, ,: --_ ...... :,. ...... '--'~,.~ ~.~..,,.'~/. ,,,,~,ag:, ,:, ~ ~ ,, ', .,,~'.- -' ~; ,,', _~ '.. '.,, .~,,~'..;;,':.':.'.' ~': -., ;'.. 0:5/29,r200003.10J6" 71,34 '131.S , 3342 321g ...... 0 ....................... T: .................... :~'~eT;l~:O~'~"~:~.'*i "~t~, *-'~ "U ~' ,:, :'*""~:'.'"" ',' "',",,-:'~ ....... ,'.'r- **' ,::, ,.~ -~ ~ ........ ,. -, .-., ...... ,,,,,. · . ......... ..~,: ~._ ~ ....... :,,,.~ .,L**iL,. :,,,~..,~.~.,.,.:.,...,, ,~ .,~:_..,., ~.. ;.,~.,, ~,,,~.~ .'~\,.~,,,,.,,,,..,. ,.,,,, ,,. 03/~00003:i'2:3;~ ' 71,34 133.$ 333& ' 3,211 ' ' n ........................ I ...... "'" ...... ,.OW,5? ". ' . '.f,? ;' ;-' ;. " ' 8L;."'.'::'-~'.~,: '""::: ': ,.'":;.'~*' ~,.' '-~:'.,.,'.:'.,'~"', .",,: ,,.,~, , ::..'. :, ... 0~/29~2(X)0 0.-,q.'"~4:.-17 ' '/1,34. ' j;s~,:~ 3063 .~218 0 '.,~rz~a~Q'~!'~s~,.. :,~;~::,~.;:. ,~',, ~'-. ..... .,, ,~ ,. ..... ., .,.., ....... ,.. ....... ~'. ....... ;'.; ::~,~;'~,::'~; ":"" ..... ' ..... ..o .......... .....~-., ...,'s~K..,'..%.. ;.,.: .... '" ...... ' ..... ~ . · , · .. ;= .~ ,._;...._ ,~.,. :, !..,;,,.j, ,..,., ,~....,,,.,,. ,..' ~.,.;,:,.,,; "' 1" ..' .~. :.., 05/29/2000 03. ~ 6:35' ' 71.~4 1~7.$ 1227 3118 0. : o~;,~ao~,n~,'.~,:, ~ ................. ,. ::,.'; ~,~,.. =.. .... ;..J.~,6~,. ' .~a~, ?, ::,? ,.: .-~2,-~., .~r,..-.:,.:..... .... :,.,, ~ ,,". ,:.%.,,, '.,~',,: .... ,, ... ~ ..... "--",~ .'.' ~" ' '.:.. ':. '::: .... '.'.". 0~/29/2000 03: ! 8:I7" - . "': ':" "~e,',~,~:~ ,,,,~, ~,~.,,~),~,,, ,, ~: .... ~ ~,,;~ '" ~ ~ "' -. . .......... · -._ _ _.._ · S~P A~$~N_. RECE!VED * Mark of S~tumb~' JUN 07 2O0O Alaska Oii'& Gas Cons. Commission Anchorage SCANNED DEC 1 9 200Z ,( ( Daily Completion/Workover Report ARCO Alaska, inc. · I 10~:30:00 PM ~ell. CDI-t gA Dep~ ~M~-~ I~H~S~5 ~PBTD (MO) .... s ~ .60 Top ~ Fill ' , Cuntr~ctor: D0~ON Dai~ Co~l ~87910 C~plot~o~o~et Coal Torn; W~tl C;~! $ ~Rig Name: Do~o~ 19 Int.rm.~;t. C;~: 1" e 11g.7' ,,. Pr~u;tion Liner. ... Total Est~;~ C~t $ ,, U~oming Oper;tlon;: ~.~ 9~ ¢e~.l, Teet e~u.~ ,?l~,.~n..p~.~~, e;.d I~'. ........ FLUID DATA FLUID ~SS B~ DATA EH&~ .... ORILL~OF DATA '~UD ~PG DALLY LOSS (~D18) BIT NO. BIT hO. ~CClDENT (non-~pill) ~ST BEP~'~T ~3~ BOP/DRILL KCLP~y 1 Y TST O~t~O~O ...... o~q, ~WEIGHT TOTAL LOSS (bbls} SIZE $1Z~ EMPLOYER ~ST H25 DRI~ ~T FIRE DRILL LD'EPP~ 6,t2S. ~ON 0~1~ O~9~OOO :VlSCOSI~ ....... MAKE .... ,MAKE ...... SPILL ~T CONFINE~ ~T a0~q~ H~ N .... SPACE ~O712Og0 . PV~P P~FORA~D ~PE ....... ~P~ - ~P6 FUE~ & WAT~ 412 I~G~YALS GELS C ~nd SERIAL NO SEriaL NO VOLUME (~;10.Sl FU~ USED APl WL A ~nd DEPTH OUT DEP~ OUT " ~T 5AF'~ MTG DRILL WATER d~'~'~ - I~0 2g,0 0~O00 BBL5 ....... ,.. ~., i i HTHP WL DEPTH IN DEP~ IN pOTA~L~'~A~R · V30~in INJEG~ON uSED. BBLS SOLIDS ;OOTAGE F~TAGE INJECTION ~ '" WEAriER & "' G:~.% CDI-~? PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST A~)~T S~R~E WELL .... TEMPE~TUR~""P 22' MBT PUMP NO WOB 2 ~Og 2 RATE (bpm) WIND ~EED 12 )h UNER SZ RPM ~ RPM 1 PRE'~URE (ps~) WiND DIREC~ON ~LGS ...... SPM t TFA ...... TFA INJECTION FLUTes c.~ FACTOR -F .7.& III O~n D~ael .... ;e ....... PIT VO~ GPM ~ J~T$ J~5 ~hO~ AR~ pERSONNEL t ~3ObU~ II I I I I I I It I Il :ssu ........ , ........... ii Io DALLY MUD SPS 1 BIT COST 6IT COST CON~A0~R 25 ~g2s3 I II PEfl~ONN~L :0 ~ .. TOTAL MUD SPP t- DULL O~L TOTAL VOL ~bl) MI~C PErSOnNEL s~42 III III III coo COMPANY MUD ~ GRAO~ G~E ~'- TOT'FOr~ WE~ (bbl) S~RVlCE ~ I il II I l II 917o PERSONNEL TOTAL 4~ ii i i .. ~1~ ..... 12=DO 0~:30 AM 1.50 TRIP.O~ PROD ~het POH. 01:3~ O2f0O AM g,5O OH PROD Other WaRh out oep ~ FUfl~ofl rflm~. AM OZtOO 0S:~ AM 3,0~ TRIP_IN PROD Other RIH ~ ~cra~r to AM 0$:~ OT~0O AM 2.00 CIRC PROD Other Cire etlon 09~30 AM ~.So T~IP.OUT P~OD ~he~ POH. AM Ag:30 10:30 AM t.00 g HA PROD Other GM b~ok BHA. LO Bc~r AM 10:30 03~00 PM 4,~0 TRIP IN PROD other RIH wi ~nt ~inor on ~ 1~' or. $~. No correct!on, 03tOD 04=00 PM 1,~ OTHER PRO~ O~ flu ~wivel. get fetnl~f et eGGO'. Sting into ~in.r. Te~t PM p=i below ~atnlner. 04:0B 04:30 PM 0.6Q CIRC PROD Other CBU, 04:30 0S:30 PM I.QQ CEME~ PROD Other PJ~. ~ 30 bbl~ ee~nt off lop d PM RECE!VED Daily Completion/Workover Report: CD 1 - 19A 05/2512000 SCANNED DEC 1 2002 JUN 07 000 Alaska O, & Was Cons. Commission Anchorage Page 05:3D 06:00 PM 0.$0 06;I)0 07:00 PM t.00 01','00 07:30 PM 0.50 07;30 11:30 PM 4.QQ PM _ ...... , ........ 24,00 i TRIP_OUT PROD Other ClFIC PRon Other SQZ P ROD Other SQZ PRO0 Oth~ OTHER PROI;) Other POH wi 1Z ;tt~$ tO RECE!VED JUN 0 7 2000 Alaska oil' & ~as Co,s. ~Jomm,smon Anchorage Supervisor: DONALD LUTRICK ?...'o oo ds ~ J SCANNED DEC 1 ~9 2002 Daily Completionfl orkover Report ARCO Alaska, Inc, · AFC Nc), [ OMo Ppi No I Rig Aecep!, hr= Dsye Since Acc~pVEs~: 3,41 R~ ~se. hrs~ ' _1 102:~0;~ PM ,, . W~fl: CDI.I~A Dept~ ~M~D) 11956~696 PBTO (MD) ' ~ 1eSe ~op el Fill .... ' CoN~ot: DoYeN ~i~ Co~t ~1465~6 :~pl~[Io~o~wet Co;~ Tutal Well CO~I ~4T~ O~r~fion At ~ CIr~ s~ at ~' · .......... U~omlng~peraflon=: POH. RIH ~i~er.S~a~ .. FLUID DATA FLUID LOSS B~ pATA EH&S DRIt~B~.pATA " MUO ~PE DAIly LOSS (~) BIT NO. BIT NO. ~' ACClO~ (nomspm)' ~ST BOP~lVERT KCLPLY I N TST , WEIGHT TOTAL LOSS (bblN SI~ SIZE EMPLOYER ~T H2~ DRILL ~ST F~RE DRi~ VISCO~I~ MAKB ~E S~IL~ ~T ~NFINEO 30e~ HTC , N .... SPACE 0~00 O~t~aooo ~P PERFORATED ~PE ~PE ~PE FUEL & WATER ~ 12 I~ERVALB GeLS ~1S0 SERIAL NO "' ~ SERIAL NO VELUM; (~llons) fUeL U'~'D " ~ 8760 ~OYD APl WL 8~ DEP~ OUT' DEPTH OUT ' ' ~T GAFE~ M'~G DRILL'~ATER USED, ' 200 ~o.o ~, o~_? eeLS mV3Om~ INJEC~ON U~ED - ~BL5 6.e~; CD1-27 PERSONNEL DATA HOLE V~LbME PUMP PR~ ADTIKST ADTIAST SOURCE W~LL TEMPERATURE *F ..... aezb~r III / / cm4~ MgT PUMP NO ~'~ ~B ~ ' RATE (~pm) ' WIND SPEED 0 ~b III o ~h LINER SZ RPM 1 RPM I PRESSURE (psi) WIND DIRE~ON ..a III .. . o LES SPM t TFA TFA I~G~O~ FLUIO$ CHI~ FACTOR 'F 21,Q0" o P~T VOL GPM ~ JE~ JETG ....... AR~ P~RSONNEL 1 a~OOl I I I I III I Il I I I o,., RECEIVED DAILY MUD ~P~'i ~rr ~OST BIT GOST - CON~AO~R -. JUN 07 2000 O rOr~L ~ ......... "' ' stp ? ~0~L " OU~L .... ~oT~vOL(~b0 UlSC.~~A ~7.~ ....................... L.III III III o ~orage COMPANY 'MUD ~ GRA0~ ~OE T~T ~A WELL (bbl) S~RVICE ~ I II II I I II esTs PERSONNE[ TOTAL 48 III I I ~ I I [. 12:00 Ol :~ AM 1.00 CEMENT PROD Other Pu~ 12 hms mud acid Into ~ds at .4 bpm AM 01:00 OZ:O0 AM I,O0 CEMENT PROD Other ~t acid AM 02:00 02:3Q AM 0.50 CEMENT PROD Other Inje~ 10 bbll brine, AM 02:30 04:~ AM 1,5Q CEMENT PROD Other PJSM, Pump 2 bble H20,17 bble 15,8 Murk, 2 bbl~ I1~O and 3T bble b~ ~ffg. Pull out of retainer. Spot 12 bbls POH WI 1~ side 04:00 08:0O AM 2.00 CEMG~ PROD error CBU ~ile rMmW and reciprocMe DP, $qun*M away 5.4 bbls Into top AM AM 06t30 09:00 AM 3.;0 TRIP_OUT PROD Other POH ~ DP end AM og:0o Og:30 AM 0,SO BHA PROD Other MU BHA. AM ~:30 11:30 AM Z,00 TRIP.IN PROD Other RIH to 7495% AM Oail¥ C, ompletlon/Workov.r Report: CD'-'gA 06~4~000 SCANNED DEC 1 2002 11:30 0 !.-3Q PM ~.,00 RIG8 01:30 02:30 PM 1,0fl TRIP_tN PM 02:30 03:00 PM O, S0 CIRC 03:00 03:30 PM 0,S0 TEST_(~SG ~03:30 0$;~ PM ~.so CLN_OUT 05:00 05~30 PM 0,so TE~T 05:30 fl6;30 PM 1.~ C~_OUT ~M 06:30 07:30 PM 4,R TRIP.IN PM 07:30 08t30 PM 1.~ CIRC PM 06t30 10:0O PM ~.~ O~ER PM IQ:GQ 12:09 ~ 2.~ TRIP_OUT PM PROD Other PROD Otltef PROD OOJ~v PROD OIh~r PROD Otl~or PROD Other PROD O;hm PRO0 Other PROD O~her PROD Other PROD Oth.r C~q ehd flip drl~ lin~, ~eryieo top drive. Ohang~ gosr oil ~nd fl~r, RIH, TaR ~mgflt ~ CgU. T6el ~g lO 1600 p~i, o~ Drill am ~ Il 8830' ~ 8~, T~t ~ng Io 1500 ~U 10 Drill camnt And ~ment zn~i~ wt BgsO'. No u~o~ ~1~ RIH to 117DB'. CgU T~I e~O to 25~ p~l. Bl~d lo 1440 p~; in 2 min. E~t'h ifljeell~fl reft ,~ bp~ et 1~0 pnL Monilor ~o~s. Olod lo ?00 phi fn ~O min. POH. __ . Supervisor: DONALD LUTRICK RECEIVED JUN 07 2000 Alaska O, ~ ~as uo;ls, uommission ~chorage SCANNED DEC 12D02 Dally Completion/WorkoveT Report: CD1,1gA 0,5124/2000 Page Daily Completion/Workover Report ARCO Alaska, Inc. · /~=C NO. ! Date " r Rpt No ' ~Rig AccePt- I~r5 DetyA $tr;'~o A¢¢ept/E='t: 2,~ I " Ri~ RelaGe. ~: .... 25 I~:~o~o~ p~ ,, ~ell: C~719A D~Z~ (MO~O) ~ lgS~S .... P~TO [MD) ...... 11~ Top ~ ~11 ' ,. ~' Conlrector: DOYON Dally Cost ~ C~oleUo~or~over Co~t T0~I Wall Goal $ ~Neme: Doyan 19 Inle~eO~Gt~ Csg: 7" ~ tlgd?' Pr~u~tiofl Liner: Tot~l"~sfimaie4 Coal ~ " FLUI0 pATA FLMD ~SS D~ DATA EH~- 0~ ~BOP DAT~' ~U~ ~PE DALLY LO~S [bbl~ BIT NO. BIT NO. " A~IOGNT (non-epm) " ~T eOP~DIV~RT ~ST BOP~fl~LL BRINE N T~ 0~ . WEIGHT TOTAL LOSS (bbls~ ~IZE $1~E E'MPLOYE~ ~GT H2~ oai~L ~3T Flfl~ ORI~- 9.6pp9 O~l~QO0 o~1~000 VISCOSI~ ' M~E MAKE ' SPILL ~T CONCINEO '" ~ST SPi~L DRI~ 335qc . N SPACE O~OT~OO0 PV~P '" PSR~RA~D TYPE ~" ~PE · " - -FUEL[WX~fl -- S / 4 I~ERVALS , , 26 O~O 8BLS H~P WL dE~'~ IN d~rTM IN "' POT~DL; wATER ........... m~3Omin INJGC~ON USED -BBLS souos " ~OOTAa~ FOO~Aee ' INJBC~ON'~ELL -' W~A~HER a -- 5,S% 00~-~7 PERSONNEL DATA HOLE VOLUME PUMP PR~S ADT/AST ' ADTIAST " 8~R~E wELL ~MPERATU~E"~C ...... 1 aesbm II I ,/ / CDt.isa M~T PUMP NO WOE 2 W~ ~ '" RATE (b~m~ - WIND SPEED 4, ;P~ III '~" LJNE~' ~Z RPM 1 ' RPM 1" PflE~SURE (P~ WINO DIRECTION ,LeS ........ "~PM 1 mA TFA INJGC~ON pLb~b~ CHILL FACTOR 'F la,~' I o.~. I II PISTOL GpM 2 J;TS JE~S 0 ......... 3~o~ I II I 111 I l I Ill a ..... "~ D DALLY MUD ~P5 t BIT C~ST BiT CO~T " OO~ACTO~ 24 $2~13.0~ II I P~R$ONN~L g Io ~OTAL~D" SPP ? ' ' 'ou~ ' OULL ' ' TOTALVOk(bbl) MISG PERSONNEL s41194,4~ II i I Ii III o ~mll ; iiI _ M~ ill III Ill P~R~O~L ,~ u ~ . TOTAL ,,,_ _ . 4~ 11:30 OZ :30 PM 3.00 TRIp .IN COM~ Trip I~ P~ Bak~ K,1 ~ti~ger. TIH ~ B935' AM PM 5PM = 1000P~i) 03:00 04:00 PM ~.oo CIRC COMP Othw Cir~ & Wash dn to Top M K-I Retwiner - Clepn eft any PM PM thru up~r Peril ~~.. _ $C NED DEC )[. 2002 Daily Compl etion/Wod<ov~r Report: CD 1 - 1 gA 05123/2000 JUN 0 7 2000 Ataska Oli' cor s. ( ommissjon An Omge Page 1 PM os:~e PM 07:30 PM 11 :QO PM Os:Bo PM 0.~0 CIRO C~OMP Other 07:$0 PM Z. OD EYAL COMP OmBr I t :00 PM 3.50 FVAI. COMP Other 12:Qo AM 1.P0 OTflE/~ COMP 24.00 Attempt to Fteveroe C~irL, u thru Perf- (Pumping t~n~ 7' Ann]i,,Pmmem', Io lOOOps! 'Ho ~ ~ Dm,MI - win pmfom~ LOT on IOWM pearl - O ~G BPM. 2410p~ (P~ t~ i b~-Held pm~,ure f~ 20 rain bt~d b~k to 1 ~1 -~IM Off ( ~ bbl, Unotlng from KI rbMinir - Clem U~t pi~ wmt -PvMorm LOT on -PfeBSU~ O~ la tg3~M- Pum~ 4 bbl IoMI- glfld ~ 3,6 bbl~.(NM lu~ if Iny wU I~m~d A~er ~i~Mon whh TW I~r & Well Ehgln~r H wa~ de~ pump m~ 1~ bbl~ M Mud Acid Dowell h~ on Ioeet)on into th~ i~ pn~ in howl M b~l~n~ lo--on dwn wom..- HMd PJSM ~ 'ALL~ ceMre~o~ mhd Rig ~nnii · All Hn~r~ nnd Con~n~flcy plans we~ ~M. An 'O~ TOD' divermion tank w~e p~ In~ gym=m 'if NW' - DMI will Pump 2 ~bl H2012 bWe Mud bbM H2O and ~nM wi ~7 bbl, mud (Wn~t lo Stinger) - Sting ·nd diSMeM M 4 G~iN Mud. Supervisor: "DEARL W, GLADDEN RECE!VED O ally CompleUon/Workover Report: CD 1,19A 06t2~/2000 JUN 07 2000 Alaska 0ii' & Gas Corm. Commissio. ~chorage SCANNED DEC .[ ~ 2002 P~e2 CD 1 - t9.A &~hematic Subject: CDI-19A schematic Date: Mon, 5 Jun 2000 14:29:28 -0900 From: "Michael D Erwin" <MERWIN~ppco.com> T o: tom_maunder~admin, state.ak, us, b 1 air_wondzell ~admin. state, ak. us Attached is the schematic you requested. I hope it has the depths you were hoping for. mike (See attached file: 1-19A Schematic.doc) ~ 1 -'19A Schematic.doc Name: 1-19A Schematic.doc Type: Microsof~ Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 I of 1 6/5/00 3:47 PM 5/31/00 ~?~ .oqo Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 203 Company: Alaska Oil & Gas Cons Comm -Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD .. CD1-34 ~(e~.~l, 20215 M10, CDR & iMPULSE 000503 1 CD1-34 20215 ARRAY RES. MD 000503 I 1 CD1-34 20215 ARRAY RES. TVD 000503 I 1 ' CD1-19A 20177 USIT 000421 1 I;)1: ¢'p I\i ~11 JUN 0 1 2000 SIGNED: DATE: - Alaska 0il & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax tO (907) 561-8317. Thank you. DATE: FAX ~. ~OM: RECE!VED JUN 0 1 ~000 Alaska Oil-& Gas Cons. Commission RKB - TbgHd LOS = 32.92' Cement to surface CD1-19A Completion Diagram 16" Conductor @ 114' MD cemented to surface Base Permafrost @ +1-1600 f! TVD HES 3-1/2" "X" Nipple (2.813" ID) for Model "MCX" Injection Valve (2.125" ID) at 1795' MD 1 1702'TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2825' MD/2393TVD 10.0 ppg Drilling Mud .~. -7300'- 8510'88 01 9590'.1O890'M : -8510'- 8560'88 or 10890'-1 8810'- 9460'88 or 11,205-11,875' .. ---. u- 3-1/2" 9.3 ppf L-80 EUE tubing to the WLEG with Best-O-Life 2000 pipe dope Packer Fluid: 9.6 ppg KCL brine with diesel freeze protection to 1850' Tubing tail to include 10' 3-1/2" PJ 1 Joint 3-1/2" tubing 10'3-1/2"PJ HES "XN" (2.750" 10) @ 10,778'MO 1 8456'TVO 3-1/2" 10' PJ and WLEG to 10,792'MO 1 8469'TVO HES Model THB Packer @ 8670'MO 1 6633' TVO (3.875" 10) w/4-1/2" x 3-1/2" x-overs above and below Formation Alpine Sqz perfs 8750' - 8760'MD (6636-6643' S 8990 - 9000' MD (6812-6820' S HES Model THB Packer @ 10716'MO 1 8396'SS (3.875" 10) w/4-1/2" x 3-1/2" x-overs above and below Injection perfs Tie to USIT 4/21/00 11,465' - 11 ,485'MO (9062'-9082' SS 11,506' -11,522'MO (9102'-9118' 55 11,750' - 11, 763'MO (9339'-9352' 55 11,768' - 11, 776'MO (9356'-9364' 55 11,780' - 11, 794'MO (9368'-9382' 55 11,800' - 11 ,813'MO (9387'-9400' 55 PBTD " MD, WLM 7" 26 ppf L-80 BTC-Mod to 11,947' MD 1 9586' TVD TO @11 956 MO ,....,...,....,.....,., "" I~e: CDI-19A Subject: Re: CDI-19A Date: Wed, 17 May 2000 15:56:49-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael D Erwin <MERWIN~ppco.com> Mike, Thanks for sharing your decision process with us. Blair Michael D Erwin wrote: Blair, We agreed some time back that I would provide you a letter describing the thought process leading to a completion plan for CDI-19. Attached is that file. I hope this is what you were looking for. I regret not getting this to you earlier, but this EPA report has been consuming me for the past week. Please call if you have any questions, concerns, or additions you would like to see in this letter. mike (See attached file: CDI-19 Completion.doc) Name: CDI-19 Completion. doc CDI-19 Completion.doc Type: Microsoft Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 1 ofl 5/17/00 3:57 PM CD1-19A Completion Plans Several options were considered in developing a final completion plan for CD 1-19A. This paper summarizes the key issues surrounding our proposal. Overview Colville River Unit well CD 1-19A has been recently deepened to the Sadlerochit for conversion to a Class 2 disposal well in the Sadlerochit. Its original Alpine location came in thin and poor quality, and the wellbore has been idle pending identification of an alternate use. During the cementing process on the production casing string, hole conditions dictated that the pipe be worked to bottom, following partial loss of circulation. String weight prevented us from being able to back up. The cement job encountered lost circulation problems. Cement logs indicated a competent cement job across and above the Sadlerochit and Sag River, our intended injection targets, but we interpret that cement stopped well below the Alpine. Remedy The Doyon 19 will return to this well next week to block squeeze and complete the well. A block squeeze is required to prevent water flood fluids from escaping the Alpine and traveling through the wellbore into other porouse sands or reaching the surface. The WD- 19A penetrates the Alpine Oil Pool in a highly permeable rock interval with high kh than was identified in the original wellbore, and is within the planned waterflood sweep area. We considered 3 different squeeze techniques; 1. Shoot below the Alpine and set a cement retainer. Attempt to circulate to surface. We abandoned this approach over concerns about having the Alpine flow to surface, as well as concerns over dealing with the contaminated fluids. 2. Shoot below and above the Alpine. Block squeeze through a test packer. We abandoned this approach over concerns about fracturing the cement into the wellbore rather than being able to place it across the Alpine. 3. Shoot below and above the Alpine. Set a cement retainer between the perforations' and circulate in a squeeze across the Alpine. This is the accepted method because we expect it affords the highest chance of placing quality cement across the Alpine formation. Completion Options Several completion options were considered and are discussed below; 1. Conventional completion with a single packer set +/-200' above the Sadleroehit. This concept was not acceptable because it exposes the numerous block squeeze perforations to annual MIT testing pressures. A single perforation breakdown over the next 15-20 years could lead to an expensive repair workover. And occasional problems with broken perforations is all too common in similar circumstances. 2. Conventional completion with a single packer set above the Alpine. This would protect the block squeeze perforations but would expose the Alpine Oil Pool. This 1 o method was not chosen because it would go against current AOGCC regulations which request injection packers close to the injection interval. Additionally, it exposes squeezed perforations to injection fluids. If the perforations broke down, Alpine oil and waterflood fluids could be injected into the Sadlerochit, or disposal fluids bound for the Sadleroehit could be injected into the Alpine. The fracture gradients are close enough that identification might not be apparent immediately. Unconventional completions with dual packers were considered. Sliding sleeves or gas lift mandrels could be installed in the between packers which are set near the Sadlerochit as well as above the Alpine. Sleeves would allow pressure testing of the casing between the dual packers, but this allows for leaks between the injected fluids and the Alpine if perforations broke and seals leak. Remedial procedures would be costly and complicated. The unconventional completion selected involves setting dual packers. The lower packer will be set +/-200' above the Sag River, the uppermost injection interval. The ..~packer will be set above the Alpine and covers all the squeeze perforations. The lower packer will be pressure tested prior to setting the upper packer. This ensures the lower packer is set and that mechanical integrity is achieved between the packers. The upper packer will be set and tested as well. This ensures mechanical integrity is achieved from the wellhead down to the upper packer. There will be no sleeves or leak paths between the 2 packers. This provides maximum protection to the Alpine squeeze perforations. Testing down the tubing prior to perforating assures mechanical integrity of the casing below the lower packer. With the completion chosen, future MIT testing will assess only the casing integrity down to the upper packer, which is set immediately above the Alpine formation. But since the Colville River Unit has been determined not to contain any USDW's, and there are still significant shale intervals above the Alpine, Phillips Alaska judges that adequate protection to ground water has been maintained. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Typ~'~3f request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _X ...................... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other_ Change approved program _X Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_ RKB 56' feet ~. Address Explorato~j m 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service_X_ Colville River Unit 4. Location of well at surface 8. Well number 351' FNL, 2447' FWL, Sec.5, T11 N, RSE, UM CD1-19A At target (Top Alpine)) 9. Permit number / approval number 2251' FNL, 1004" FWL, Sec.33, T12N, RSE, UM per APD - 200-040 At effective depth 10. APl number 50-103-20294-00 At total depth 11. Field / Pool 1639' FNL, 2099' FWL, Sec.33, T12N, R5E, UM per APD Colville River Field/Alpine Oil Pool ~2. Present well condition summary Total deplh: measured 11956 feet true vertical 9595 feet Effective depth: measured 11860 feet landing collar in 7" casing. true vertical 9502 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2788' 9.625" 860 sx ASL3, 230 sx Class G 2825' 2393' Production 11912' 7" 566 sx Class G 11947' 9586' CD1-19A has been temporarily suspended at the 7" casing point. The top of cement behind the 7" casing is at approximately 10450' MD. This does not cover Ihs Alpine formation. It will therefore be necessary to perforate the casing and cement above the Alpine. The well will then be completed using two permanent production packers to straddle perforations used as part of the remedial ~,cae..rnel3;t 0RI$1NAL 13. Atl~chments Description summary of proposal _ Detailed operations program ~ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: May 19, 2000 16. If proposal was verbally approved Oil ~ Gas ~ Suspended Name of approver Date approved Service X 17. I hereby cerllfy th~ the forogolng Is true and correct to the best of my knowledge. Title: Drilling Team Leader Date [,_igned _ /'./' FOR COMMISSION USE ONLY Conditions of apl:j//9~al: Notify Commission so representative may witness JApproval no. I V Plug Integrity _ BOP Test ~ Location clearance _ I Mechanical Integrity Test/~ Subsequent form required 10-~ i-APproved by order of the Commission R__nb~ff N C. hrister~sorl Commissioner Date Form 10-403 Rev 06/15/88 · ~pproved Copy Retu rnedt~(..D _, SUBMIT IN TRIPLICATE , 2. 3. 4. 5. 6. 7. , 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21, 22, 23. 24. Note: CD1-19A Program Outli~._ Move on Doyon 19. Remove the BPV and install the 2-way check. Remove tubing head adapter assembly. Install BOPE. Pressure test BOPE to 3500 psi. Recover the 2-way check. Remove the tubing hanger. Run in hole to PBTD at 11860'. Circulate the casing to viscosified 9.6 ppg KCL brine. Pull out of hole. Pressure test the casing to 3500 psi / 30 rains. R/U Schlumberger. Run 10' of 3-3/8" perforating guns. Perforate between 8990' and 9000'. POH with guns. Close the blind rams. Attempt to circulate the casing (monitoring for returns at the wellhead). Maximum pressure = 1000 psi, If successful, the squeeze plan will be modified. RIH with a cement retainer on electric line. Set the retainer at 8950', POH. Run 10' of 3-3/8" perforating guns. Perforate between 8750' and 8760'. POH with guns. R/D Schlumberger. Run the cement retainer stinger on 3-1/2" drill pipe. Sting into the retainer and establish circulation through the perforations and back into the casing, If unsuccessful, the remedial cementing plan will be modified, Clean up the outside of the casing until a maximum rate has been achieved. Circulate the mud acid treatment, With the drill string stung into the retainer, pump the cement slurry and displace with viscosified brine. Cement the outside of the casing, Pick up out of the retainer, Spot a cement plug on top of the retainer (to cover the upper perforations), Pick up 10 stands. Conventionally circulate out and dispose of all contaminated brine and cement. Rotate and reciprocate while circulating. Perform a hesitation squeeze (maximum pressure 1500 psi). POH. WOC, Make up a clean out assembly with a mill tooth bit. RIH and drill out the cement and retainer. Pressure test the casing to 1500 psi / 10 rains. POH, Run a bit and casing scraper with tandem boot baskets. Circulate the well clean. POH. R/U Schlumberger. Run the USIT log to confirm the cement quality over the 'squeeze' zone, POH, Run 3 Y~, 9.3 #, L-80 tubing with straddle packers. Land hanger, Test hanger seals to 5000 psi, UDDer packer at 8670', Lower packer at 10730'. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check, Circulate in inhibited 9.6 ppg KCL brine and diesel freeze protection. Allow diesel to U tube to freeze protect to 2000' TVD, Drop RHC ball and set the straddle packers. Pressure test the tubing and annulus separately to 3500 psi / 30 mins, Set BPV and secure well. Move rig off. A slickline unit will return to the well to remove the RHC nipple. The casing below the lower packer will then be tested to 3500 psi / 30 mins prior to perforating the injection zones. This will be done after the rig moves off location. Colville River Field Updated 5/9/00 CD1-19A Class 2 Well Completion Plan 16" Conductor at 114' KB=56' above MSL GL = 37' Elevation Cement to surface Base Permafrost at +/-1550 ft TVD 3-1/2" HES X Nipple (2.813") at 1700' TVD = 1792' MD - for possible later running of an A1 injection valve. 9-5/8" 36 ppf J-55 BTC Surface Casing 2825' MD / 2393' TVD 10.0 ppg Drilling Mud Remedial cement job 8750' - 9000' Packer Fluid: 9.6 ppg KCl Brine with 2000' TVD diesel cap Halliburton THB Packer at 8670' Top Alpine at 8988' MD Halliburton THB Packer at 10730' (< 200' MD above Sag River top) TOC from primary job at 10450' 'i ,.. ,, i', t,?=?=" ................................... ............................................ i PBTD +/- 11860' MD 7" 26 ppf L-80 BTC Mod Production Casing @ 11947' MD / 9586' TVD @ 14 deg Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 10, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Re-enter, Perform Remedial Cementing Operations and Complete: CD1-19A Dear 'Sirs: Phillips Alaska, Inc. hereby requests approval to re-enter, perform remedial cementing operations and completion operations on well CD1-19A. Please find attached form 10-403 and an outline program, including a proposed final completion drawing. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC. CD1-19A Well File Sharon AIIsup-Drake Doug Chester ATO-1054 ANO-382 .~'Re?USIT 2 logs Well CD1-19A PERMIT TO DRILl' 3-040 Subject: Re: USIT 2 logs Well CDI-19A PERMIT TO DRILL 200-040 Date: Wed, 03 May 2000 10:09:00-0800 - From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael D Erwin <MERWIN~mail.aai.areo.com> CC: Robert Crandall <bob__erandall~admin.state.ak.us> Mike, Thanks for the logs. They don't show much cement. Will look forward to your program for repair. Regards, Blair Michael D Erwin wrote: > Blair, > This log is not the final corrected version that Schlumberger has been > promising, that version will eventually arrive in your offices by paper copy I > suspect. But attached below is the most recent electronic version. I trust is > displays what we have tried to describe to you over the phone. > > We are close to finalizing our design plans for completion of this well. As a > refresher, this is the Sadlerochit disposal well we amended our Area Injection > Order to drill. Circulating problems during the primary cement job did not allow > us to circulate cement up to or across the Alpine. We believe we have excellant > containment of our injection interval. But remedial squeeze work is planned for > approx 3 weeks from now to repair the cement across the Alpine. > > Please call if any questions. > > mike > Forwarded by Michael D Erwin/AAI/ARCO on 05/02/2000 08:37 >AM > > Brian Robertson > 05/02/2000 08:29 AM > > To: Michael D Erwin/AAI/ARCO~ARCO > cc: > Subject: USIT 2 logs > > Mike, > > Attached is what I have at present. I do niot yet have electroniuc copies of the > first log, corrected for the proper acoustic impedence. Howver it came out to be > essentally ther same as this second log. > > Brian > Forwarded by Brian Robertson/AAI/ARCO on 05/02/2000 08:27 >AM > > Doyon 19 Company Man > 04/21/2000 09:24 PM > > To: Douglas K Chester/AAI/ARCO, Brian Robertson/AAI/ARCO, Michael > Ka s e cky/AAI/AR CO,AR CO > cc: > Subject: USIT 2 logs > > (See attached file: USI_Cement_O38.zip) (See attached file: USI_Cement_O36. zip) I of 2 5/3/00 10:09 AM "Re.~ 'USIT 2 logs Well CDI-I 9A PERMIT TO DRIL~' ')440 > > Name: USI_Cement_038. zip > USI_Cement_038. zip Type: Zip Compressed Data ( app l i ca t ion~x-zip-compressed) > Encoding: base64 > Description: .ZIP File > > Name: USI_Cement_036. zip > USI_Cement_O36. zip Type: Zip Compressed Data (appl i ca t i on/x - zip - compre s s ed) > Encoding: base64 > Description: .ZIP File 2 of 2 5/3/00 10:09 AM Client ................... : ARCO Alaska, Inc. Field ................ ~'...: Colville River Well ..................... : CDI-19A API number ............... : 50-103-20294-00 Engineer ................. : J Rathert Rig: ..................... : Doyon 19 State: ................... : Alaska ANADRILL SCHLUMBERGER Survey report Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.27 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 48.52 degrees [(c)2000 Anadrill IDEAL ID6 0C 07] -- -- 17-Apr-2000 12:27:21 Page 1 of 5 ORIGINAL Spud date ................ : 05-Apr-00 Last survey date ......... : 17-Apr-00 Total._accepted surveys...: 108 MD of first survey ....... : 115.00 ft MD of last survey ........ : 11956.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 17-Mar-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.85 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.84 degrees -"~' (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED MAY 02 2000 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 17-Apr-2000 12:27:21 Page 2 of 5 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 0.00 2 195.29 0.37 199.10 80.29 3 287.00 0.43 267.00 91.71 4 381.05 1.85 312.60 94.05 5 467.90 3.74 316.40 86.85 6 557.90 5.94 314.60 7 647.13. 7.48 321.50 8 736.26 8.46' 326.50 9 827.10 9.31 336.10 10 914.62 10.72 342.50 11 1004.80 14.02 346.30 12 1094.06 18.14 347.90 13 1187.71 22.79 349.20 14 1283.40 24.20 351.70 15 1378.97 24.52 359.60 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) -Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 115.00 0.00 0.00 0.00 0.00 195.29 -0.23 -0.24 -0.08 0.26 287.00 -0.75 -0.54 -0.53 0.76 381.03 -1.19 0.47 -2.00 2.05 467.77 -1,44 3.47 -4,98 6.07 90.00 557.44 -1.86 8.86 -10.32 13.60 89.23 646.06 -1.88 16.65 -17.23 23.96 89.13 734.33 -0.66 26.66 -24.46 36.18 90.84 824.09 2.48 38.95 -31.12 49.86 87.52 910.27 7.93 53.19 -36.44 64.47 90.18 89.26 93.65 95.69 95.57 16 1474.49 26.06 11.90 95.52 17 1570.23 29.78 13.90 95.74 18 1665.29 33.92 11.80 95.06 19 1760.19 38.29 13.00 94.90 20 1855.50 40.37 14.20 95.31 21 1949.67 41.53 15.70 94.17 22 2041.62 42.50 18.10 91.95 23 2140.47 43.47 20.60 98.85 24 '2236.49 45.18 27.80 96.02 25 2330.50 47.97 31.30 94.01 26 2426.64 52.05 30.40 27 2521.48 53.62 28.50 28 2616.39 53.37 28.50 29 _2710.57 ' 54.05 26.40 30 2773.64 53.62 25.80 [(c)2000 Anadrill IDEAL ID6 0C 07] 998.35 1084.10 1171.81 1259.57 1346.65 16.43 71.80 -41.55 82.96 28.29 95.90 -47.02 106.81 44.71 -127.99 -53.48 138.72 64.90 165.61 -59.79 176.07 88.66 204.83 -62.75 214.23 1433.08 118.55 245.21 -58.56 252.11 1517.66 155.00 288.89 -48.51 292.93 1598.39 195,71 337.79 -37.41 339.85 1675.05 240.89 392.38 -25.38 393.20 1748.77 290.42 451.09 -11.16 451.23 1819.89 341.85 510.71 4.77 510.73 1888.21 394.25 569.58 22.67 570.04 1960.53 453.10 633.16 45.01 634.76 2029.26 514.18 694.24 72.53 698.02 2093.89 578.74 753.59 106.24 761.04 2155.66 2212.96 2269.42 2325.17 2362.38 648.90 816.82 143.98 829.42 720.32 882.63 181.13 901.03 792.00 949.68 217.53 974.27 862.82 1017.04 252.51 1047.92 909.89 1062.76 274.91 1097.75 96.14 94.84 94.91 94.18 63.07 0.00 0.00 TIP 199.10 0.46 MWD M 224.07 0.49 MWD M 283.16 1.68 MWD M 304.84 2.19 MWD M 310.65 2.45 MWD M 314.03 1.95 MWD M 317.47 1.35 MWD M 321.37 1.88 MWD M 325.59 2.05 MWD M 329.94 3.77 MWD M 333.88 4.64 MWD M 337.32 4.99 MWD M 340.15 1.80 MWD M 342.97 3.42 MWD M 346.57 5.72 MWD M 350.47 4.0.1 MWD M 353.68 4.51 MWD M 356.30 4.66 MWD M 358.58 2.32 MWD M 0.54 · 1.61 MWD M 2.28 2.04 MWD M ' 4.07 1,98 MWD M 5.96 5.53 MWD M 8.02 4.01 MWD M 10.00 4.30 MWD M .11.60 2.30 MWD M 12.90 0.26 MWD M 13.94 1.94 MWD M 14.50 1.03 MWD M RECEIVED 2000, Alaska Oil & Gas Cons. Commission} ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth o Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 31 2827,76 52,52 25,49 32 2860,41 51.54 26.52 33 2923,21 49.71 31.04 34 3018.11 48,22 36,01 35 .3112,13 47,16 38,47 17-Apr-2000 12:27:21 36 3208,66 45,64 42,91 37 3303,68 45,18 44,05 38 3396,80 45,26 47,31 39 3491.86 45,11 47,69 40 3587,30 44.47 50.38 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Page 3 of 5 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type ' 54,12 2394,90 949,75 1101,76 293,64 1140,22 14,92 32,65 2414,99 973,53 1124,90 304,92 1165,49 15,17 62,80 24.54,84 1019,19 1167,44 328,26 1212,71 15,70 94,90 2517,16 1088,28 1227,09 367,74 1281,01 16,68 94,02 2580,46 1156.46 1282,45 409,80 1346,33 .-17.72 .. 96,53 2647,04 1225,67 1335,45 455,33 '1410,93 18,83 95,02 2713,75 1293,07 1384,55 501,89 1472,70 19,93 93,12 2779,35 1359,07 1430,71 549,16 1532,49 21,00 95,06 2846,35 1426,50 1476.27 598,88 1593,12 22,08 95,44 2914,09 1493,72 1520,35 '649,64 1653,33 23.14 41 3682,65 44,06 51,50 95,35 2982,37 1560,21 1562,29 701,31 1712,48 42 3777,80 44,96 54,75 95,15 3050,24 1626,68 1602,29 754,67 1771,12 43 3873,38 45,78 58,95 95,58 3117,40 1693,95 1639,46 811,60 1829,35 44 3968,41 45,55 59,09 95,03 3183,81 1760,78 1674,44 869,87 1886,91 45 4064,31 45.15 58,91 95,90 3251,21 1827,87 1709,58 928,35 1945,38 46 4158,51 43,13 47 4252.65 42,47 48 4349,19 42,37 49 4443.09 42,36 50 4540,01 42,43 51 4635,17 42.69 52 4825,43 42,79 53 5016,91 42,84 54- 5206,18 42,30 55 5396,59 41,27 2002,29 2058,40 2116,31 2173,33 2232,51 2290,86 2408,93 2528,38 2646,24 2764,33 24,18 25,22 26,34 27,45 28,50 29,45 30,32 31,13 31,87 32,59 33,28 34,55 35,75 36,86 37,84 58,69 94,20 3318,80 1892,41 1743,56 984,47 58,49 94,14 3387,88 1955,39 1776,90 1039,05 57.38 96,54 3459,15 2019,63 1811.47 1094,24 56.,99 93,90 3528,53 2082,18 1845,76 1147,42 57,66 96,92 ' 3600,10 2146,76 -1881,03 1202,42 :. 58,12 95.16 3670.19 2210.26 1915,25 1256,94' 57,50 190,26 3809,93 2337,69 1984.03 1366,21 59,54 191,48 3950',40 2465,84 2051,98 1477,1'9 59,08 189,27 4089,79 2591,61 2117,33 1587,29 58,51 190,41 4231,76 2716,45 2183,06 1695,81 56 5587,09 41,83 60.65 190,50 .4374,34 2840,44 2247,02 1804,77 2882,06 38,77 57 5776,66 42,15 60,89 189,57 4515,24 2964,37 2308,94 1915,44 3000,02 39,68 58 .5968,01 42,36 60,02 191,35 4656,87 3090,26 2372,39 2027,38 3120,66 40,52 59 6156-,54 42,77 59,88 188,53 4795,72 3215,26 2436,25 2137,76 3241,20 41,27 60 6348,62 42,57 59,95 192,08 4936,95 3342,88 2501,51 2250,41 3364,80 41,98 [(C)2000 Anadrill IDEAL ID6_0C_07] 2,08 MWD 6-axis 3,90 MWD 6-axis 6,28 MWD 6-axis 4,25 MWD 6-axis 2.24 MWD 6-axis 3,68 MWD 6-axis 0.98 MWD 6-axis 2,49 MWD 6-axis 0,32 MWD 6-axis 2,10 MWD 6-axis '0,93 MWD 6-axis 2,57 MWD 6-axis 3,24 MWD 6-axis 0,26 MWD 6-axis 0,44 MWD 6-axis 2,15 MWD 6-axis 0,72 MWD 6-axis 0,78 MWD 6-axis 0,28 MWD - 0,47 MWD 6-axis 0,43 MWD 6-axis 0,23 MWD 6-axis 0,72 MWD 6-axis 0,33 MWD 6-axis 0,58 MWD 6-axis 0,80 MWD 6-axis 0,19 MWD 6-axis 0,32 MWD 6-axis 0,22 MWD 6-axis 0,11 MWD 6-axis RECEIVED Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 61 6443,72 42.15 59,79 62 6539.03 44,05 60,93 63 6729,37 -43,87 60,00 64 6918,48 43,36. 58,82 65 7014,24 43,06 58.77 Course length (ft) 95,10 95,31 190,34 189,11 95,76 TVD depth (ft) 5007,22 5076,81 5213,83 5350;74 5420,54 17-Apr-2000 12:27:21 Vertical section (ft) 3405,70 3469,43 3598,69 3726,79 3791.30 Page 4 of 5 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type 2533.68 2565,87 2631,00 .. 2697,38 2731,35 3425 84 3487,80 3613,81 3739,29 3802,67 42,30 42,64 43,28 43.83 44,09 2305,83 2362,43 24'77,39 2589,68 2645,76 66 7109,61 43,31 61.25 95,37 5490,08 3855,25 2763,96 2702,28 3865,46 44,35 67 7299,57 43,26 61,35 189,96 5628,36 '3982,26 2826,51 2816,52 3990,23 44,90 68 7489,49 42,11 60,71 189,92 5767,97 4107,96 2888,86 2929,17 4114,07 45,40 69 7678,37 42,82 61,00 188,88 5907,30 4232,53 2950.97 3040,54 4237,11 45,86 70 7870,63 43,33 60.86 192,26 6047,74 4360,77 3014,76 3155,31 4364,03 46,30 3079,08 3142,53 3172,87 3232,13 3289,89 3268,66 3383,36 3440,23 3552,82 3669,85 4488,29 4616,25 4678,95 4802,56 4928,48 6186,43 6326,73 6396,64 6534,99 6675,79 4490,53 4617,65 4679,99 4803,04 4928,60 190,32 192,01 95,09 187,96 191,98 46,71 47,11 47,32 47,71 48,12 71 8060,95 43,11 60,00 72 8252,96 43,01 62,10 73 8348,05 42,34 61,74 74 8536,01 42,87 62.73 75 8727,99 42,79 64,74 76 8917.41 42,75 65,11 189,42 6814,84 5051,88 3344.40 3786,35 5051,88 48,55 77 9013,96 42,10 64,72 96,55 6886,11 5114,36 3372,01 3845,34 5114,40 48,75 78 9109,77 40,58 63,24 95,81 6958,04 5175,35 3399,76 3902,21 5175,48 48,94 79 9204,90 39.52 61,07 95,13 7030,87 5234,82 3428,34 3956,34 5235,08 49,09 80 9298,48 37,04 59,65 93,58 7104.32 5291,55 3456,99 4006,73 5291,94 49,21 81 9393,67 34,49 59,77 95,19 7181,55 5346,12 3485,05 4054,76 5346,65 49,32 82 9489,48 31,15 59,82 95,81 7262,06 5397,04 3511,17 4099,63 5397,71 49,42 83 9584,65 28,03 60,58 95,17 7344,81 5443,06 3534,53 4140,40 5443,88 49,51 84 9679,17 27,65 60.99 94,52 7428,39 5486,19 3556,08 4178,92 5487,18 49,60 85 9774,67 26,26 60,93 95,50 7513,51 5528,47 3577,09 4216,77 5529,62 49,69 4252,17 4284,52 4314,45 4343,87 4372,58 7599,49 7687,54 7776,09 7865,41 7955,33 86 9869,63 23,97 62,02 87 9965,03 21,26 61,70 88 10059,86 20,69 61,98 89 10155,22 20,32 61,48 90 10250,88 19,56 61,85 [(c)2000 Anadrill IDEAL ID6 0C 07] 5569,08 5604,96 5638,17 5670,87 5702,82 94,96 95,40 94,83 95,36 95,66 5567,74 5603,43 5636,47 5668,99 5700,75 49,78 49,86 49,93 50,00 5O,06 3596,35 3613,64 3629,67 3645,49 3660,97 0,46 MWD 6-axis 2,15 MWD 6-axis 0,35 MWD 6-axis 0.51 MWD 6-axis 0,32 MWD 6-axis 1,80 'MWD 6-axis 0,04 MWD 6-axis 0,65 MWD 6-axis 0,39 MWD 6-axis 0,27 MWD - 0,33 MWD 6-axis 0,75 MWD 6-axis 0,75 MWD 6-axis 0,45 MWD 6-axis 0,71 MWD 6-axis 0.13 MWD - 0,73 MWD 6-axis 1,89 MWD 6-axis 1,84 MWD 6-axis 2,81 MWD 6-axis 2,68 MWD 6-axis 3,49 MWD 6-axis 3,30 MWD 6-axis 0,45 MWD 6-axis 1,46 MWD 6-axis 2,46 MWD 6-axis 2,84 MWD 6-axis 0,61 MWD 6-axis 0,43 MWD 6-axis 0,81 MWD 6-axis RECEIVED 02 2000 Alaska Oil & Gas Cons. Commi~ion . ANADRILL SCHLUMBERGER Survey Report 17-Apr-2000 12:27:21 Page 5 of 5 Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 10347.32 19.66 61.40 92 10442.21 19.24 59.76 93 10537.71 18.25 59.47 94 10633.08 17.46 59.00 95 10728.34 16.68 60.08 96 10822.86 16.22 59.95 97 10917.99 15.84 60.14 98 10987.94 15.60 60.17 99 11109.67 15.18 60.00 100 11202.65 14.97 60.69 101 11297.94 14.66 59.86 102 11394.93 14.34 '60.48 103 11488.72 14.17 59.71 104 11584.55 14.05 59.80 105 11678.46 13.88 59.98 106 11775.70- 13.77 59.50 107 11880.64 13.90 59.40 Survey Projected to TD: 108 11956.00 13.90 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 96.44 8046.18 5732.28 3676.35 4401.06 94.89 8135.65 5763.17 3691.87 4428.58 .95.50 8226.09 5793129 3707.39 4455.05 95.37 8316.86 5822.02 3722.34 4480.18 95.26 8407.93 5849.47 3736.52 4504.28 94.52 8498.58 5875.70 3749.90 4527.46 95.13 8590.01 5901.44 3763.02 4550.22 69.95 8657.34 5920.00 3772.45 4566.66 121.73 8774.71 5951.65 3788.56 4594.66 92.98 8864.49 5975.32 3800.53 4615.68 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 5734.53 50,13 5765.60 50.18 5795.88 50.23 5824.76 50.28 5852.36 50.32 5878.75 50.37 5904;65 50.41 5923.32 50.44 5955.18 50.49 5979.00 50.53 95.29 8956.61 5999.17 3812.60 4636.84 6003.02 50.57 96.99 9050.51 6022.95 3824.69 4657.90 6026.96 50.61 93.79 9141.41 6045.58 3836.20 4677.92 6049.74 50.65 95.83 9234.35 6068.49 3847.97 4698.10 6072.81 50.68 93.91 9325.48 6090.71 3859.34 4717.71 6095.18 50.72 97.24 9419.91 6113'.50 3871.04 4737.78 6118.13 50.75 104.94 9521.80 6138.14 3883.80 4759.39 6142,94 50.78 59.40 75.36 9594.95 6155.92 3893.02 4774.97 6160.84 50.81 [(c)2000 Anadrill IDEAL ID6 0C 07] 0.19 MWD 6-axis 0.73 MWD 6-axis 1.04 MWD 6-axis 0.84 MWD 6-axis 0.88 MWD 6-axis 0.49 MWD 6-axis 0.40 MWD 6-axis 0.34 MWD 6-axis 0.35 MWD 6-axis 0.30 MWD 6-axis 0.39 MWD 6-axis 0.37 MWD 6-axis 0.27 MWD 6-axis 0.13 MWD 6-axis 0.19 MWD 6-axis 0.16 MWD 6-axis 0.13 MWD 6-axis O. 00 MWD RECEIVED MAY 02 2000 Alaska Oil & Gas Cram. Commission Anchorage MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CDl-19A Date Dispatche 29-Apr-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 mse@anchorage.anadrill.slb.com Fax: 907-561-8417 Log Delivery V1.1, Dec '97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATJ N FOR SUNDRY APPROVALS ~: Type of request: Abandon _ S~:~Er~X~ Operational shutdown -~'~ '~ ............................ Re-enter suspended well _ AEer c~ing _ Repair well _ Plugging _ Time e~ension _ Stimulate _ Other _ Change ~pmved program _ Pull tubing _ Valance _ Pedorate _ Annular Inje~ion ~. Name of Operator 5. Type of Well: 6. Da~m eleva~on (DF or KB feet) ~RCO Alaska, Inc. Development_ RKB 56' feet 3. Address Explomtow_ 7. Unit or Prope~ name P. O. Box 100360 Stmtig~hic ~ ~nchorage, AK 99510-0360 sewi~ ~ Colville River Un~ 4. Lo~on of well at su~a~ 8. Well number 351' FNL, 2447' ~L, Sec.5, T11 N, R5E, UM CD1-19A At arget (Top Alpine)) 9. Permit number / ~prova number 2251' FNL, 1004" FWL, Sec.33, T12N, RSE, UM per APD 200-040 At effective depth 10. APl number 50-103-20294-00 At toal.dep~ 11. Field / Pool 1639' FNL, 2099' ~L, Sec.33, T12N, R5E, UM per APD Colville River Fiel~Alpine Oil Pool 12. Present well ~ndition summa~ To~ dep~: measur~ 11956 feet tree v~ical 9595 feet E~c~ve depth: me=ur~ 11860 feet landing collar in 7" ~sing. kue verti~l 9502 feet Casing Length Size Cement~ Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2788' 9.625" 860 sx ASL3, 230 sx Class G 2825' 2393' Production 11912' 7" 566 sx Class G 11947' 9586' Per the a~ched ~mail ~rrespondence. CD 1-19A h= been temporarily suspended at the 7" ~sing point. The ~p of ~ment behind the 7" ~sing is approxima~ly 10~0' MD. This does not cover ~e Alpine formation. It will therefore be necessa~ to p~fora~ ~e ~sing ~d ~ment above the ~Alpine. Another development well (or wells) will be drilled while a fo~ard plan for cemen~ng above the Npine and for a modifi~ ~mpletion is being ~veloped. RECEIVED 0 R I GI NA L ~aAa ~1 & Gas C~s. ~mmi~n An~nr~e 13. A~chments Description summa~ of proposal _ De~iled operations program _ BOP ~6 14. Estimated ~te ~r commencing operation 15. S~tus of well classifi~tion as: April 22, 2000 16. If proposal was ve~al~ approved ~ I~ ~&~ (1 ~/~[ fO~ Oil __ Gas __ Suspended __ Name of approver Da~ approv~ Sewi~ X 17. I hereby ~ that the foregoing is tree and co~e~ to the be~ of my ~owledge. Signed TiUe: Drilling Te~ Leader Da~ of~v FOR COMMISSION USE ONLY O'ondition~ ~: NoU~ Commission ~o repre~en~tive may wi~e~ IApproval no. ~ Plug Integ,~ _ BOP Te, _ Loc, ion clearan~ --I Mech~i~l Integr~y Test _ Sub~quent form required 10- ~ ORIGINAL SIGNED. BY ~proved by order of the Commission Robe~ N. Christenson . ~.o~ commissioner Da~ Form 10-403 Rev 06/15/88 ...... SUBMIT IN TRIPLICATE Blair Wondzell <blair_wondzell@admin.state.ak.us> on 04/24/2000 02:44:40 PM To: Brian Robertson/AAI/ARCO cc: Subiect: Re: CD1-19A' Permit # 200-040' Tempora~ Suspension of Operations Brian, Please see that we get a copy of both logs. You should probably fill out a Sundry, can use this e-mail as the attachment. Regards, Blair Brian Robertson wrote: Mr. Wondzell, Further to conversations between yourself and Doug Chester on Friday of last week; please note that we have suspended operations on the CDi-19A well. We were not confident that the top of cement had covered the Alpine enought to provide isolation between the Alpine and the well 9-5/8" x 7" annulus. The cement evaluation logs indicate that there is good quality cement and cement bond up to around 10450' MD. The top of the Sag River Formation (the upper injection zone) is 10894' The temporary suspension information is as follows: 7" casing shoe: 11947' MD. PBTD: 11860' MD. TOC: 10450' MD 3-1/2" tubing was run to 2299' MD. This was hung off from a tubing hanger. The wellhead adapter was then installed prior to circulating in diesel freeze protection. The wellhead adapter / wellhead were pressure tested to 5000 psi prior to setting a back pressure valve. We decided that it was more prudent to move the rig on to well well CD1-34 while we evaluate options for cementing the 7" casing above the Alpine. We also need to determine what impact this will have on our completion strategy. Once we have collected the data and have a propsed work plan, we will contact you to enable your review and approval of the proposal. Please let me (or Doug Chester) know if this e-mail provides you with sufficient information or if it will be necessary to submit a sundry form. Regards Brian Robertson Alpine Drilling Engineer RECEIVED 25 2000 Ata~a 0il & Gm Cons. Commiss'lon An~m'~e ARCO Alaska, Inc.{" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 24, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Suspend: CD1-19A Dear Sirs: Further to telephone conversations and electronic correspondence with Mr. B. Wondzell, ARCO Alaska, Inc. hereby request approval that CD1-19A is suspended at the 7" casing point. It is intended that the well remain suspended pending design and further approval of remedial cementing operations necessary to isolate the 9-5/8" x 7" casing annulus from the Alpine formation. Please find attached form 10-403 and a copy of electronic correspondence relating to this topic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Ro ertson Senior Drilling Engineer CC. CD1-19A Well File Sharon AIIsup-Drake Doug Chester ATO-1054 ANO-382 ARCO Ah.tska, Inc, m a Submdiary of AtlanticRichlieldCornpany RECEIVED 25 2000 Alasl~a 0ii & Gas C0r~s. Commission CD1-19A: Permit # 2004)40' Temporary Suspensi~ 'Operations Subject: CDI-19A: Permit # 200-040: Temporary Suspension of Operations Date: Mon, 24 Apr 2000 11:27:51 -0900 From: "Brian Robertson" <BROBERT4@mail.aai.amo.com> To: blair_wondzell~admin.state.ak.us CC: "Douglas K Chester" <DCHESTER@mail.aai.arco.com>, "Doyon 19 Company Man" <DOYON1 ~$nail.aai.arco.¢om> , Mr. Wondzell, Further to conversations between yourself and Doug Chester on Friday of last week; please note that we have suspended operations on the CDi-19A well. We were not confident that the top of cement had covered the Alpine enought to provide isolation between the Alpine and the well 9-5/8" x 7" annulus. The cement evaluation logs indicate that there is good quality cement and cement bond up to around 10450' MD. The top of the Sag River Formation (the upper injection zone) is 10894' The temporary suspension information is as follows: 7" casing shoe: 11947' MD. PBTD: 11860' MD. TOC: 10450' MD 3-1/2" tubing was run to 2299' MD. This was hung off from a tubing hanger. The wellhead adapter was then installed prior to circulating in diesel freeze protection. The wellhead adapter / wellhead were pressure tested to 5000 psi prior to setting a back pressure valve. We decided that it was more prudent to move the rig on to well well CD1-34 while we evaluate options for cementing the 7" casing above the Alpine. We also need to determine what impact this will have on our completion strategy. Once we have collected the data and have a propsed work plan, we will contact you to enable your review and approval of the proposal. Please let me (or Doug Chester) know if this e-mail provides you with sufficient information or if it will be necessary to submit a sundry form. Regards Brian Robertson Alpine Drilling Engineer 1 of I 4/26/00 10:07 AM Re: CD 1 - 19A Subject: Re: CDI-19A ~._~ -~ O ~ Date: Tue, 04 Apr 2000 09:51:40-0800 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: John Crisp <john_crisp@admin.state.ak.us> Job_ri, Thanks for the update. The contact, especially in this case needed to come from ARCO. Thanks, Blair John Crisp wrote: > Mr. Blair, I have been talking w~ Donnie Lutrick ( Alpine Drilling > Foreman) about this well since last night. I waived witnessing their BOP > test because of the problems killing well, the timing was going to be a > problem. Donnie stated that the fluid allowed to flow back on this well > would be injected into CD1-38 that is permitted for annular injection. > It seems to me they have everything in place to allow the well to flow > back as is. Seems like an unnessacary trip for packer with these mud > weights would be more risky 0 this time than allowing the well to flow > back thru the annulus. There was a lot of water as well as diesel > injected into the disposal zone as well as drilled & processed cuttings. > It is my understanding that they need to drill this w~ 10 ppg mud to be > able to go thru Alpine into the lower injection zone or they will P&A > this well. Sounds like they got good engineer on this project, I know > they have the best Drilling Foreman. These Gentlemen are keeping me > informed & I apoligize for not contacting you about this well. Thanks > JC. 1 of 1 4/4/00 10:03 AM CD I-19A' Permit # 200-040 Program Changes (' Subject: CDI-19A: Permit # 200-040 Program Changes Date: Mon, 3 Apr 2000 14:05:25 -0900 From: "Brian Robertson" <BROBERT4~mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us CC: "Douglas K Chester" <DCHESTER~mail.aai.areo.com> Blair, Over the weekend we moved Doyon 19 back over well CDi-19. Since early Sunday morning we have been in the process of killing the well which appears to have charged zone associated with the previous 'annular' injection operation. It is estimated that the equivalent mud weight at the casing shoe depth (2393' TVD / 2825' MD) is 14 ppg. BOP's have been installed and pressure tested. The well has a tubing kill string, with the circulating depth at 2190' MD. We are presently increasing mud weight to provide the required hydrostatic pressure to allow for removal of the tubing hanger. The well has remained fluid packed at all times (i.e. no indications of gas returns from the injection zone). After stabilizing the well we would like to try and bleed off pressure from the well. It is proposed that this is done with a test packer set in the 9-5/8" casing. By bleeding off fluid we are hopeful that we may be in a position to drill the well with lower mud weight. At present it is very difficult to see how we can successfully complete the CDi-19A well program by drilling from surface shoe / sidetrack point, through the Alpine Sand to total depth in the Ivishak with 14 ppg mud weight. If 14 ppg mud is truely required to drill the well there is a very strong potential for either geting differentially stuck in the Alpine or for breaking down the Alpine, either while drilling or during the 7" cement job, which would jeopardize the integrity of the Class II well. We would propose bleeding fluid off in stages (say 100 bbl increments). After each bleed off we would close the well in to see how the pressure stabilizes and determine if removal of fluid from the well is proving beneficial. If we are able to get into the position where we can lower the required mud weight to a more manageable figure (10 - 12 ppg) we would progress with the program as it stands. We would like to give you a call this afternoon to discuss this proposed program ammendment. We would also like advise on disposal of the wellbore fluid produced back from such a bleed off operation. The fluid is being produced as part of the well construction process. However it is also previously injected drilling fluid. We would like to know if it will be possible to dispose of the fluid by annular injection. Regards Brian Robertson - Alpine Drilling Engineer 1 of I 4/3/00 2:54 PM APD for CDI-19A (' Subject: APD for CDI-19A Date: Wed, 22 Mar 2000 11:10:26 - 1000 From: "Brian Robertson" <BROBERT4@mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us, tom_maunder~admin, state.ak.us CC: "Douglas K Chester" <DCHESTER~mail.aai.areo.com>, "Sharon Allsup-Drake" <SALLSUP@mail.aai.arco.eom> Gents, You should have received the sundry requesting permission to abandon well CDi-19 prior to starting sidetracking operations on CDi-19A. I believe that the only other outstanding issue was with respect to a leak off test after drilling out of the kick off plug.We do not intend carrying out a leak off since we already have a good 14.6 ppg EMW LOT from the original well. However you did have some queries regarding injection pressures seen while injecting drilling waste into this well. Please note that this injection was done through 4-1/2" tubing run down to 2190' MD. The casing shoe is at 2825' MD / 2393' TVD. The injection data seen over the injection period was: Date Fluid Weight (ppg) Rate (BPM) Pressure Range (psi) NEAR START 4/26/99 10.2 4.0 850 - 1100 4/25 9.7 3.9 880 - 1120 NEAR END 6/2/99 9.4 3.5 860 6/2/99 6.8 3.9 800 6/3/99 9.6 3.5 1100 I can see nothing really obvious to indicate a change in formation strength over the period which we were injecting into this well. If you would like further information please let me know. Please let me know if there is any other information or you have any other comments regarding the APD prior to you being in a position to forward it on for approval. Regards Brian Robertson - Alpine Drilling Engineer. 1 of l 3/22/00 2:34 PM CASING '~ '3T and FORMATION INTEGRITY TEST Well Name: CD1-19 Date: 4112/99 Supervisor: Mike Whitele¥ Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518" 36# J-55 BTC CSG Casing Setting Depth: 2,825' TMD 2,393' TVD Hole Depth: 2,856' TMD 2,411' TVD Mud Weight: 9.6 PPG Length of Open Hole: 31' 630 630 psi EMW = 0.052 x 2411 + Mud Weight _ 9.6 PPG o.o52 x 2,411' EMW = 14.6 ppg . Pump output = .101 BPS d Pumped = 3.83 BLED BACK = 1 BBLS ITli~IE UNE ............ '--I- ...... .... ............ ...... 2.600 pd ......... ~p, ......... , r' "-;..~ .;.-L.~ ~, ~,-~; ~z I' ....... '.-:' · 'I- ..... r-..... ..... 2.4(]0 pd ........................................................ 2.300pd ....... t ............................. , ............. I ........ ~ ..................... 2.2(]0pal I ~ ........................... ~_ -- ........................... 2.100pal ..................................................... 2.000 pd- ~ .............................. I.";CO pd- --' ...... r 1.700pd ir 1,500 pli 1,400pd 1,300 pd [ j [ - -- 1.2gO pd I.lOOpll ~ ...... a~op~ - ...... t- -[ ..... !-e--II:AK-OFF TEST 7001:~1~ ;--~ - - 'p'-~ "= e; ~-~;---' * - -,,-- · ./--t - - --,*--CASING TEST -- ~oopa - r ........... _ i . _ ~ LOT SHUT IN TIME pa i - ,-- CASING TEST SHUT IN TIME 100pd ~ Op~ I.. TIME LINE 0 2 4 6 8 lO i~141618 20 22 24 26 28 30 32 34 3~ 3~ 40 42 44 46 48 50 5~ r~16~ M ~0 62 6 ~ee~u~z~e~l~u~z~ae~uwwve~ IOI0 st d d d d ~t d st ~! st st It I! It d ~1 ~l d It It II Il It II It Il It I! It It d It $! d ,! It ~1 It d l/ ~ It Il I/ k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k dd k k STROKES LEAK-OFF DATA MINUTE8 FOR LOT STROKES PRESSURE 0 stks I stks 2 stks 3 stks 4 stks 5 stks 6 stks 7 stks 8 stks 9 stks 10 stka 11 stks 12 stk$ 13 stks 14 stks 15 stks 20 stks 25 stks 30 stks 35 stks 36 stke 64_~ps! 600 psi. ,._s~_o ps!.. .__sLo psi... __sLOp.l_ .__,~,0 psi ; 580 psi 8HUT IN TIME 8HUT IN PP. E88URE CASING TEST DATA MINUTES FOR CSG TEST tt~ .......... t~O .......... ..~--_, 8HUT IN TIME 0.0 min 1.0 min 2.0 min 3.0 min 0.0 min 1.0 min 2.0 rain 3.0 min 4.0 min 5.0 rain 6.0 min 7.0 min 8.0 min 9.0 rain 10.0 min 505 psi ..._~0~0 ps! _ _490 psi_ ...!._o_.~.~L. __490 ps_i .. 4.0 rain 5._._~.0 mi_.~n ~ 6.0 min 7.0 min 8.0 min 9.0 min 10.0 min 15.0 min 20.0 min 25.0 min 30.0 min STROKES 0 stks 1 stk$ 2 stks 3 stks 4 stks 5 stks 6 stks 7 stks 8 stks 9 stks 10 stks 11 stks 12 etks 13 stks 14 stks 15 stks 16 stks 17 stks 21 stks 26 stks PRESSURE _ 40p.~_ _ ?0 sp.~_ ...~_o.e,J_ ._ sO0 650 psi _ !,~"0 ~L ,.&45~~. ..~ ~9~0 p~! 2,490 psi SHUT IN PRESSURE 2,5~0 p~i~ _2,500 ps_! _2,50° P"L, ....2,49_0 p.~?.. ............... _2,48o p.~.. NOTE: STROKES TURN TO MINUTES DURING 'SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE TONY KNOWLES, GOVERNOR ALASKA OIL A~D GAS CONSERVATION CO~L~IlSSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD 1-19A ARCO Alaska, Inc. Permit No: 200-040 Sur. Loc. 351'FNL, 2447'FWL, Sec. 5, T11N, R5E, UM Btmhole Loc. 1639'FNL, 2099'FWL, Sec. 33, T12N, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to redrill the above referenced well. No annular disposal has been requested. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours)of the 'MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~',f ~4 day of March, 2000 dlf/Enclosures ,,, , cc: Department of Fish & Game. Habitat Section w/o cncl. Depamnent of Environmental Conservation vdo encl. CD 1-19A Permit Applications - Request to Expedite Subject: CDI-19A Permit Applications - Request to Expedite Date: Wed, 29 Mar 2000 17:26:27 -0900 From: "Brian Robertson" <BROBERT4~mail.aai.arco.com> To: blair_wondzell~admin, state.ak.us CC: "Sharon Allsup-Drake" <SALLSUP@mail.aai.arco.eom> Blair - We are requesting that the AOGCC expedite processing the Permit to Drill for CDi-19A. Progress on the current CD1-41 well is much quicker than expected. would appreciate receiving the permit before Friday March 31, 2000 as we anticipate we will move to this well on Saturday. Please call if you have any questions. Thanks, Brian Robertson 265-6034 We I of I 3/30/00 8:51 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Straatigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas Single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 & 25557~ ?_~"~-~-~ ~.b 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 351' FNL, 2447' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (-- top Alpine ) 8. Well number Number 2251' FNL, 1004' FWL, Sec. 33, T12N, R5E, UM CD1-19A #U-630610 At total depth 9. Approximate spud date Amount 1639' FNL, 2099' FWL, Sec. 33, T12N, R5E, UM 04/06/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine WD-2 12,086' MD Crosses Sec. 32 to feet 365.3' @ 2946' Feet 2560 9,656' TVD feet Sec 33 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 2946' feet Maximum hole angle 53° Maximum surface 1528 psig At total depth (TVD) 4369 at psig 9656' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include ~ten~e data) 42" .16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12'.25" 9.625" 36# J-55 BTC 2788' 37' 37' 2825' 2393' Already in place 8.5" 7" 26# L-80 BTC-M 12049' 37' 37' 12086' 9656' 568 sx Class G N/A 3.5" 9.3# L-80 IBT-M 10763' 37' 37' 10800' 8447' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet June (measured) true vertical feet Casing ConductorStructural Length Size Cemented ~~ihvE TDrueVertical depth Surface Lintmeedrurmc~id°i~te 0 RIG INA L 000 Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical orage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050.requirements X 21. I hereby certify/~at the foregoing is true and correct to the best of my knowledge ...... Signed ~ Title Drilling Team Leader Date ~ ? O oo ,i Perm~ lAP, number Approval date ~ See cover letter for -- 50- /0__?>-'~-.~.2~:)'~'"~F7/"" ~/ '"'~, "O~$ Oth~_~irements Conditions of approval Samples required Yes ~ Mud raqulre(~ Yes Hydrogen sulfide measures Yes ('"~o' ~) Directional survey required ~ No Required working pressure for BOPE 2M 3M 5M 10M 15M Other, ORIGINAL SIGNED B'Y by order of _Appro~v_ed.b_y~_ __. __ D Taylor Seamount Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-19A '~" ~ Procedure . , . . 11. 12. 13. 14. 15. 16. 17. 18. Move on Doyon 19. Circulate the well (at the kill string depth of 2190') to 9.6 ppg LSND mud. Remove tubing head adapter assembly. Install BOPE. Remove BPV. Install 2-way check and test BOPE to 3500 psi. Recover the 2-way check. Unlock the tubing hanger and pull back to the rig floor. Remove the tubing hanger. M/U a crossover to 5" drill pipe. Run in hole to 3200'. Circulate and condition mud. Spot a 500', 15.8 ppg Class G cement plug from 3200' to 2700'. Pick up and circulate clean. Pull out of hole and lay down the tubing kill string. M/U the 8-1/2" drilling assembly. RIH and tag the top of the cement plug. Pressure test the 9-5/8" casing to 2500 psi. Kick off at +/- 2946' MD and drill 8-1/2" hole, as per the directional plan, to well TD in the Ivishak Formation. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Displace cement with 9.0 ppg brine. Flush the casing by casing annulus with 300 bbls fresh water and then freeze protect to 2000' TVD. BOPE test to 3500 psi. Pick up 3-1/2" drillpipe and run a 7" casing scraper to the packer-setting depth. Work the scraper. Displace the well to clean 9.0 ppg brine. Pull out of hole and lay down excess drill pipe and the casing scraper. Run a USIT log to confirm the top of cement and cement isolation above the injection zone. Run 3 Y~, 9.3 #, L-80 tubing and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Circulate in 10.0 ppg inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins Increase tubing pressure to 4500 psi to shear out the pump out sub in the tubing tailpipe Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. WD-2 will be the closest well to CD1-19A (365.3' at 2946' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will 'be 306.4' at 2946' MD. Drillin_~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. CD1-19A DRILLING FLUID PROGRAM Density PV YP Initial Gels 10 minute gels APl Filtrate PH MBT 8 Y2" hole to TD 9.6- 10.2 ppg 10 - 25 15 - 25 4-8 <18 4 - 12 cc/30 min (drilling) 9.0 - 10.0 <20 Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation while drilling through the Alpine. Maintain mud weight at or below 10.2 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. (" Colville River Field CD1-19 Temporary Suspension Schematic Suspension Date · 04/20/99 Diesel Freeze protection in annulus and tubing to 1960' TVD. I Wellhead installed with tubing hanger and BPV set and pressure ' tested to 2000 psi 16" Conductor to 114' 4-1/2" injection string at +/- 2190' MD (hung off from tubing hanger) 10.0 ppg drilling mud in hole I Plu tagged w/15 9-5/8" 36 ppf J-55 BTC Surface Casing 2825' MD / 2393' TVD cemented to surface RECEIVED I;,4AR 1 0 2000 Alaska OJ; & Gas Cons. Commissior~ Anti,age ~lbs Top of cement plug at 9988' MD / 6704' TVD (+/- 67 deg inc,) Top Alpine Reservoir at 10393' MD / 6849' TVD (+/- 70 deg inc,) Well TD at 10548' MD / 6879' TVD (+/- 75 deg inc.) Updated 3/07/00 Colville River Fielo(' CD1-19A Class 2 Well Completion Plan 16" Conductor at 1 14' KB=56' above MSL GL = 37' Elevation Cement to surface Base Permafrost at +/-1550 ft TVD 3-1/2" Camco DB-6 Top No-Go Profile (2.812"1D) at 1700' TVD -- 1792' MD - for possible later running of an A1 injection valve. 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2825' MD / 2393' TVD 10.0 ppg Drilling Mud Planned TOC at 8506' MD / 6499' TVD (min 500' above Alpine) Cement 9006' MD / 6866' TVD Packer Fluid mix: 10.0 _O_Dg NaCl/NaBr Brine with 2000' TVD diesel cap Completion Tubing Hanger XO, 4-1/2", 12.6#/ft box x 3-1/2" 9.3#/ft pin 3-1/2", 9.3 #/ft, L-80 IBT-Mod Tubing DB-6 Nipple (2.812" ID) 3-1/2", 9.3#/ft, IBT-Mod Tubing XO, 3-1/2", 9.3#/ft box x 4-1/2" 12.6#/ft pin KBH-22 Anchor Seal Assembly Baker SABL-3 Packer 4-1/2", 10' pup joint XO, 4-1/2", 12.6#/ft box x 3-1/2" 9.3#/ft pin 3-1/2" tubing joint (1) 2.813" HE$ "XN" (2.666" No-Go ID) 3-1/2" 10' X/O pup joint (FOX pin) WEG (+1- 20 deg) MD 32' 1792' TVD 32' 1700' 10800' 8447' 10844' 8489' 10860' 8504' Baker Model SABL-3 Packer (< 200' MD above Sag River top) w/KBH-22 Anchor Seal Assembly (3.875" ID) 10969' MD / 8606' TVD PBTD 12006' MD 7" 26 ppf L-80 BTC Mod Production Casing @ 12086' MD / 9656' TVD @ 20 deg Updated 3/07/00 ,. CD1-19A ( PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 N/A 9 5/8 2825 / 2393 14.2 1083 1528 7" 12086 / 9656 16.2 4368 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. 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) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x O.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2393 = 1528 psi OR ASP = FPP - (0.1 x D) · = 4368 - (0.1 x 9656') = 3403 psi Alpine CD1-19A ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT - 1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 ~,1 I'~, II ~11 ~, II '%1 ~, III II I~1 !~ III II III I III ~'~ II Ill %,, III till '~, I III II II III III III ~II III ill ~II III III I % _L. 1_. III II I I ~,~ ~:.E'~ II1_ III I .... t ""' I~ IIII I ~1 IIII ~/ II .,Alii III I ~ I I ~11 Ill ~1~ III III ~11 III I I I../' III I I ~ II III ,,, Ill IIII !1 III I1~1 II III I I~l II III I III il III I III II I III I III III III I III III III III I I II III III I I I III Ill ~ , 8 9 10 11 12 13 ' 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine;'~O1-19A Well Cementinq Requirerh~nts 9 5/8" Surface Casing run to 2825 MD / 2393' TVD. Already cemented to surface. 7" Production Casing run to 12086' MD ! 9656' TVD Cement from 12086' MD to +/- 8506' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (12086'- 8506') X 0.1268 ft3/ft X 1.4 (40% excess) = 635.5 ft3 annular volume 80' X 0.2148 fts/ft = 17.2 fts shoe joint volume Total volume = 635.5 + 17.2 = 652.7 ft~ => 568 Sx @ 1.15 ft3/sk System: 568 Sx Class G + 0.2% D046 antifoamer, 0.30% D065 dispersant, 0.30% D800 retarder and 0.25% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft~/sk CD1-19 Cement Plug: 3200' MD to 2700' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 40% excess on open hole volume. Slurry: (3200' - 2825') X 0.3941 ft3/ft X 1.4 (40% excess) = 206.9 ft3 open hole volume (2825' - 2700') X 0.4340 ft~/ft = 54.3 ft3 cased hole volume Total volume = 206.9 + 54.3 = 261.2 ft3 => 223 Sx @ 1.17 ft3/sk 223 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk System: ARCO Alaska, Inc. CD%1 19A slot %19 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 19A Version%3 Our ref : prop3843 License : Date printed : 28-Jan-2000 Date created : 21-Jan-2000 Last revised : 28-Jan-2000 Field is centred on nT0 20 37.100,w1§0 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.654,w150 55 34.526 Slot Grid coordinates are N 5975777.939, E 385872.825 Slot local coordinates are 349.99 S 2447.99 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD#1 PGMS <0-10255'>,,WD2,CD%l PMSS <0-10796'>,,24,CD#1 PMSS <0-8168'>,,35,CD91 PMSS <0-11300'>,,13,CD91 PMSS <7755-11134'>,,26,CD%1 PMSS <0-8350'>,,26PHl,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11067'>,,32PH1,CD%1 PMSS <10016 - 11136'>,,32,CD%1 PMSS <472 - 1545'>,,36PH1,CD%1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-10897'>,,3,CD91 PMSS <0-12055'>,,40,CD91 PMSS <0-7331'>,,1PH1,CD#1 PMSS <5946 - 10289'>,,1,CD%1 PMSS <384 - 14477'>,,23,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD%1 PMSS <0-10504'>,,SPH1,CD%l PMSS <9499 - 14515'>,,5,CD91 PMSS <0-10548'>,,19,CD%1 CD1-41 PH1 Version~2,,41PH1,CD#1 CD1-25 Version #6,,25,CD%1 CD1-38 Version #4a,,38,CD#1 PMSS <654 - ???'>,,38,CD#1 CD1-27 Version #7,,27,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance 28-Jun-1999 1256.2 28-Jun-1999 365.3 28-Jun-1999 1421.9 28-Jun-1999 1420.7 15-Ju1-1999 1055.9 1-Nov-1999 1802.4 4-Jan-2000 1802.4 4-Jan-2000 1386.1 25-0ct-1999 1386.1 4-Jan-2000 1694.6 23-Dec-1999 1694.6 4-Jan-2000 1782.5 4-Jan-2000 1662.6 22-Dec-1999 1662.6 23-Dec-1999 1949.2 4-Jan-2000 580.1 28-Jun-1999 2051.2 4-Jan-2000 868.0 27-Jun-1999 868.0 18-Aug-1999 1519.5 26-Aug-1999 1960.5 4-Jan-2000 1790.1 22-Sep-1999 1790.1 4-Jan-2000 2049.7 16-Nov-1999 2049.7 23-Jan-2000 1012.8 23-Jan-2000 1012.8 28-Jun-1999 0.0 26-Jan-2000 1651.8 24-Jan-2000 1715.6 13-Jan-2000 2036.9 28-Jan-2000 2034.9 17-Jan-2000 1928.0 M.D. 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946,0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946.0 2946 0 2946 0 2946 0 2946 0 2946 0 2946 0 Diverging from M.D. 9609 2946 2946 2946 10480 12000 2946 2946 2946 2946 2946 2946. 2946. 2946. 2946. 2946. 2946. 2946. 6540. 2946. 2946. 2946. 2946. 2946. 2946. 6340. 6340. 11380. 2946. 2946. 2946. 2946. 2946. 200O 2400 28OO 52OO ARCO Alaska, Inc. Structure: CD~I Well: 19A Field: Alpine Field Location: North Slope, Alaska KOP 51.95 49.00 46.48 DLS: 5.00 deq per 100 ft 44.47 45.04 EOC . 5600 K-5 40OO 4400 K-2 48.52 AZIMUTH ***Plone of Proposol*** "~ 4800 5200 ~ 5600 6OOO B~ '4"' 6400 6800 I V AVERAGE ANGLE 42.79 DEG Albion-g7 AIb;on-96 RECEIVED IVIAR 10 2000 Naska Oil & Gas Cons. Commission Anchorage HRZ 7200 7600 8OOO 8400 880O 9200 9600 K-1 TARGET ANGLE ,cu 42.7 9 [YJu- 36.90 Nuiqsut DLS: 2.00 deg per 100 ft 52.g0 30.90 Nechel[k 28.90 26.90 24.90 22.90 20.90 ,~ EOD d5 AVERAGE ANGLE 20 DEG ~ EDeen v~h~k ro - c.. P~. ~.~ 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 5600 6000 6400 5500 Vertical Section (feet) -> Azimuth 48.52 wish reference 0.00 N, 0.00 E from slot #19 A I !c,~t~ b:, b~.~t For: I~to plotted: P~t ~fa~ b ~rdinat~ are in f~ ARCO Alaska, Inc. Structure: CD#I Field: Alpine Field 0 500 600 900 1200 1500 1800 2100 2400 45OO 5gOO 36O0 35O0 5OO0 27O0 24O0 Well: 1gA Location: Noflh Slope, Alaska East (feet) -> 2700 3OeO 3300 3BOO 59130 4200 4500 4800 5100 5400 5700 TD LOCATION: J 63g' FNL, 20gg' FWL Sec. 33, T12N, RSE TARGET LOCATION: 2251' FNL, 1004' FWL SEC. 53, T12N, R5E HRZ qsut Drop TD Csg. Pt. 6000 4500 4200 3900 3600 3300 3oeo I 2700 ~ --h 2400 (1) --I- 2100 1800 1800 1500 1200 goo 0 500 KOP 5/8 6OO KOP LOCATION: 856' FSL, 2494' FEL SEC. 52, T12N, RSE 900 1200 1500 1800 2100 2400 2700 3000 3300 East (feet) -> 3600 3900 4200 4500 4600 5100 5400 5700 1500 1200 go0 6000 Cr,.ated by bmich~el For: B. Robert. on Date plotted: 28-Jon-2000 Plot Refemnr.~ i~ 1gA Vemion~3. Coardinot~ om in feet reference .lot ~lg. true Verl~c;I Del~th. ore reference RKB (Doyon ~llg). Point KOP EOC K-5 K-2 Albion-97 Albian-96 HRZ K-1 LCU Tgt- Beg. Drop Alpine UJU Nuiqsut Nechelik EOD J3 Sag River Shublik Eileen 'lv[shok TD - Csg Pt. ARCO Alaska, Inc. Structure: CD#I Field: Alpine Field Well : l gA Looaflon: North Slope, Alaska PROFILE COMMENT DATA MD 2946.00 5849.29 4829.55 5147.01 7588.76 8058.42 8447.19 8740.15 8869.59 9005.84 9005.85 9057.21 9277.74 96O9.75 0145.15 0163.10 0968.69 .25 1298.58 1 479.49 2O86.07 Inc Dir TVD North 52.81 26.33 2465.64 1186,84 42.79 60.71 3081.60 1 668.45 42.79 60.71 5801.00 1994.22 42.79 60.71 4054.00 2099.74 42.79 60.71 5826.00 2911.26 42.79 60.71 6156.00 3060.71 42.79 60.71 6456.00 3196.56 42,79 60.71 6671.00 '5293.95 42.79 60.71 6766.00 35.36.95 42.79 60.71 6865.99 3382.25 42.79 60.71 6866.00 5.382.24 41.76 60.71 6904.00 5,399.14 57.55 60.71 7074.00 5467.84 50.71 60.71 7349.00 5558.69 20.00 60.71 7852.12 5670.70 20.00 60.71 7849.00 5675.71 20.00 60.71 8606.00 5808,53 20.00 60.71 8646.00 3815.65 20.00 60.71 891 6.00 5863.75 20.00 60.71 9086.00 5894.01 20.00 60.71 9656.00 3995.52 East 335.35 770.65 1551.34 1559.41 2985.90 5252.27 3494.42 3667.97 3744.65 3825.37 5825.57 5855.50 5977.95 4159.88 4359.55 4544.89 4585.18 4597.88 4685.58 4757.54 4918.47 V. Sect 1037.57 1682.48 2335.51 2544.10 41 65.50 4465.85 4755.25 4929.76 5015.70 5106.16 5106.17 5159.94 5277.17 5458.67 5682,44 5688,44 5957.76 5971.99 6068.05 6128.55 6331.32 Deg/lO0 0,00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 ARCO Alaska, Inc.[ ~" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 09, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-19A Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill a Class 2 Waste Disposal well from the Alpine CD1 drilling pad. It is intended that the currently suspended CD1-19 well be re-entered and then re-used to drill to a new location, designated as CD1-19A. The intended start of operations on this well is April 06, 2000. It is intended that Doyon Rig 19 be used to drill the well. After plugging back CD1-19 to the 9-5/8" surface casing shoe, CD1-19A will be drilled to penetrate the injection zones in the Sag River and Ivishak Formations. 7" casing will 'then be run and cemented in place. A USIT cement evaluation log will be run prior to completing the well. The casing will be perforated after the rig has moved off to another well. Please find attached the information required by 20 ACC 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 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A drilling fluids program summary. 5. Current CD1-19 suspension diagram. 6. Proposed completion diagram. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Rober;:s~n~~/ Senior Drilling Engineer RECEIVED DAR 10 000 Naslm Oil & Gas Cons. Commission Al{(;() Ahml.,,,, hll:. i:, ,: ~;Lll~:.l,l];lly ~Ji All;ILIlll:l{ll:hliul(l(';l)llq~:lLl¥ Attachments CC: CD1-19A Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED UAR 10 2000 Alaska Oil & Gas Cons. Commission .... ;..!.? ::i!{:::{:!;~'i'' 'PAYABI2ES-...., '-'" ~i';":. Pi'0. B~ :/i 0~2776 ' "-.:..::~.-An~: hoi'a ge, -AK-" ::-995.1.0 _ 2776 : "-~'.! ~:: '..'_: ...:...ii ~ ~ :"' 'Z. i' p--~.¥-?::::?' ...:.-:::.: .:. ~,,.~.. ¢~,~, ." 2050938 01 ., . ., ... · .. MARCH 9, 2000 .73-426' : 839 .0997579 WELL PERMIT CHECKLIST COMPANY .FIELD & POOL ~.Z~/-~ ~:::~W/--INIT CLASS /~./~ <~c~ : _ ~.[~ WELL NAME ~ / - /~,~ PROGRAM: exp ADMINISTRATION 1. APPR DATE /-- Vv/J~) ~ P/-..-- GEOL AREA __._~ ENGINEERING DATE Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number..,.. ............... 4. Well located in a defined pool-~" 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ............... . . 26. BOPE press rating appropriate; test to ~' ~"~'~,,.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. dev redrll ,/ serv v/ wellbore seg ann. disposal para req UNIT#____~ ON/OFFSHORE Y GEOLOGY APPR DATE (}'ih 30. Permit can be issued wlo hydrogen sulfide measures ..... ~~_~yy NN /' , / /'2 ~,/ , . , , ,,~ 31. Data presented on potential overpressure zones ....... ,,Vo ~2,.,,,,¢.~,o~-,c~-~ ~r~ ~ ~'--,-"-Y-7.-'-~-,,~. ~ .~"~..~--~,w/-,~..o,.,-A-~/, 32. Seismic analysis of shallow gas zones ............. ,~, 33. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory only~,~ N 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N. pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlC/~,nnular COMMISSION: Commentsllnstructions: 1:3 0 Z 0 Z ---I ~,. rtl ,(' c:~nsoffice\wordian~iana\checklist (rev. 02117/00)
