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185-037
ORIGINATED TRANSMITTAL DATE: 2/19/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5270 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5270 2V-09 50029213000000 Production Profile (PPROF) 27-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-037 T40101 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.19 15:20:12 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: Tubing patch 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 8100 feet None feet true vertical 6161 feet None feet Effective Depth measured 7974 feet 7285 feet true vertical 6070 feet 5540 feet Perforation depth Measured depth 7592-7654, 7668-7875, 7682-7686, 7778-7792, 7805-7840 feet True Vertical depth 5774-5822, 5833-5838, 5843-5846,5916,5927, 5937-5963 feet Tubing (size, grade, measured and true vertical depth)3.5 L-80 7727' MD 5878' TVD Packers and SSSV (type, measured and true vertical depth)Packer Baker FHL 7285' MD 5540' TVD SSSV N/A 12. Stimulation or cement squeeze summary: N/A 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: Contact Email: Authorized Title:Contact Phone: Burst Collapse measuredPlugs Junk measured measured true vertical Packer TVD 102' 2927' 7739'8025'7Production8025' Casing MD 102' 3617' Size Conductor Surface 16" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-037 50-029-21300-00 N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025644 Kuparuk River/Kuparuk River Oil ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 3. Address: KRU 2V-09 Length 67' 3583' Sr Pet Eng:Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A N/AN/A N/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A N/A Dusty Freeborn N2549@conocophillips.com 907-659-7224Senior Well Integrity Specialist N/A t e Fra O g g l g y 6. A y G L G R h Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 1:30 pm, Jan 07, 2022 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2022.01.07 12:23:53-09'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn -00 DSR-1/10/22SFD 1/10/2022 8055 SFD 1/10/2022 VTL 01/24/2022 RBDMS HEW 1/11/2022 SFD 1/10/2022 6127 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est 31' of Rathole) 7,871.0 2/10/2020 2V-09 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull plug, Set Perm Patch, & Installed GLD 12/18/2021 2V-09 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.6 Set Depth (ftKB) 102.0 Set Depth (TVD) … 102.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.6 Set Depth (ftKB) 3,617.1 Set Depth (TVD) … 2,924.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 29.8 Set Depth (ftKB) 1,761.0 Set Depth (TVD) … 1,611.5 Wt/Len (l… 26.00 Grade L-80 Top Thread TCII Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 1,761.0 Set Depth (ftKB) 8,054.5 Set Depth (TVD) … 6,126.4 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.0 Set Depth (ft… 7,727.4 Set Depth (TVD) (… 5,877.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 32.0 32.0 0.06 HANGER 2.900 6.995 FMC TUBING HANGER 512.4 511.3 10.00 NIPPLE 2.875 4.520 CAMCO 'DS' NIPPLE 2,873.8 2,390.4 44.32 GAS LIFT 2.920 5.968 CAMCO MMG 4,557.0 3,597.0 45.72 GAS LIFT 2.920 5.968 CAMCO MMG 5,765.7 4,447.6 44.89 GAS LIFT 2.920 5.968 CAMCO MMG 6,637.2 5,070.4 44.92 GAS LIFT 2.920 5.968 CAMCO MMG 7,229.1 5,497.9 41.67 GAS LIFT 2.920 5.968 CAMCO MMG 7,254.2 5,516.7 41.53 SEAL ASSY 3.000 3.990 BAKER GBH-22 LOCATOR/SEAL ASSEMBLY 7,262.3 5,522.8 41.33 PBR 4.000 5.880 BAKER PBR 7,285.4 5,540.2 41.14 PACKER 3.000 5.970 BAKER FHL PACKER 7,365.6 5,600.7 40.21 SEAL ASSY 3.000 3.990 BAKER GBH-22 LOCATOR/SEAL ASSEMBLY 7,368.0 5,602.5 40.10 PBR 4.000 5.880 BAKER PBR 7,394.5 5,622.8 40.16 PACKER 3.000 5.970 BAKER FHL PACKER 7,478.5 5,687.2 40.02 GAS LIFT 2.920 5.968 CAMCO MMG 7,564.9 5,753.4 39.83 BLAST RINGS 2.992 4.090 BLAST RINGS (3) 7,660.5 5,826.7 40.20 BLAST JOINT 3.000 6.500 STEEL BLAST JOINT 7,696.5 5,854.2 40.45 SLEEVE-C 2.813 5.750 BAKER CMU SLIDING SLEEVE 2.813" DS PROFILE - CLOSE 4/25/13 7,712.6 5,866.5 40.47 SEAL ASSY 3.000 3.990 BAKER GBH-2 LOCATOR/SEAL ASSEMBLY STABBED INTO ORIGINAL TUBING Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,726.8 Set Depth (ft… 7,749.4 Set Depth (TVD) (… 5,894.5 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD IPC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 7,726.8 5,877.2 40.47 PACKER 4.000 6.150 BAKER FB-1 PACKER 7,730.1 5,879.8 40.47 SBE 4.000 5.000 BAKER SEAL BORE EXTENSION 7,741.1 5,888.2 40.47 NIPPLE 2.750 4.540 CAMCO D NIPPLE NO GO 7,748.6 5,893.9 40.47 SOS 2.992 4.000 CAMCO SHEAR OUT SUB. ELMD TTL @ 7737' during PPROF on 07/08/2000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,607.5 5,049.3 45.03 PATCH PERM - UPR HALLIBURTON/OWENS PERMANENT TUBING PATCH (OAL 17.08' W/ 2.25" MIN ID) UPPER SEAL @ 6608' & LOWER SEAL @ 6624' RKB. 12/18/2021 2.250 6,618.0 5,056.8 44.61 LEAK - TUBING Relay found leak @ 6618' RKB with LDL log, located12' above perm patch. 10/4/2021 2.992 6,631.6 5,066.5 44.65 PATCH PERMANENT TUBING PATCH (OAL 22.4') 10/20/2013 2.250 7,341.0 5,582.0 40.95 NIPPLE D-NIPPLE SET IN KB PACKER 9/28/2013 1.812 7,341.0 5,582.0 40.95 PACKER KB PACKER(ID corrected on 1/3/2018) 9/28/2013 1.790 7,479.0 5,687.5 40.02 LEAK - C-SAND C-SANDS PRODUCING THROUGH LEAK IN GLM #6 @ 7479' 5/28/2014 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,873.8 2,390.4 44.32 1 1/2 GAS LIFT GLV RK 0.188 1,261.0 12/18/2021 2 4,557.0 3,597.0 45.72 1 1/2 GAS LIFT GLV RK 0.188 1,259.0 12/18/2021 3 5,765.7 4,447.6 44.89 1 1/2 GAS LIFT OV RK 0.250 0.0 12/18/2021 2V-09, 12/19/2021 8:10:23 AM Vertical schematic (actual) PRODUCTION; 1,761.0-8,054.5 IPERF; 7,805.0-7,840.0 IPERF; 7,778.0-7,792.0 SOS; 7,748.6 NIPPLE; 7,741.1 SBE; 7,730.1 PACKER; 7,726.8 SEAL ASSY; 7,712.6 SLEEVE-C; 7,696.5 IPERF; 7,682.0-7,686.0 IPERF; 7,668.0-7,675.0 IPERF; 7,592.0-7,654.0 GAS LIFT; 7,478.5 LEAK - C-SAND; 7,479.0 PACKER; 7,394.5 PBR; 7,367.9 PACKER; 7,341.0 NIPPLE; 7,341.0 PACKER; 7,285.4 PBR; 7,262.3 SEAL ASSY; 7,254.2 GAS LIFT; 7,229.1 PATCH; 6,631.6 GAS LIFT; 6,637.2 LEAK - TUBING; 6,618.0 PATCH PERM - UPR; 6,607.5 GAS LIFT; 5,765.7 GAS LIFT; 4,557.0 SURFACE; 34.6-3,617.1 GAS LIFT; 2,873.8 PRODUCTION TIE-BACK; 29.8- 1,761.0 PLUG; 30.0 ftKB NIPPLE; 512.4 CONDUCTOR; 34.6-102.0 HANGER; 32.0 KUP PROD KB-Grd (ft) 34.98 Rig Release Date 3/25/1985 2V-09 ... TD Act Btm (ftKB) 8,100.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292130000 Wellbore Status PROD Max Angle & MD Incl (°) 47.36 MD (ftKB) 2,125.00 WELLNAME WELLBORE2V-09 Annotation Last WO: End Date 4/5/2011 H2S (ppm) 40 Date 12/13/2019 Comment SSSV: NIPPLE Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 4 6,637.2 5,070.4 44.92 1 1/2 GAS LIFT Patch RK Ext Pkg 0.000 0.0 5/23/2013 5 7,229.1 5,497.9 41.67 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/9/2011 6 7,478.5 5,687.2 40.02 1 1/2 PROD DMY RK Ext Pkg 0.000 0.0 8/1/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,592.0 7,654.0 5,774.3 5,821.8 C-4, C-3, C-1, UNIT B, 2V-09 4/28/1985 12.0 IPERF 120° phasing, 5" Dresser Hyperdome 7,668.0 7,675.0 5,832.5 5,837.8 UNIT B, 2V-09 4/28/1985 12.0 IPERF 120° phasing, 5" Dresser Hyperdome 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B, 2V-09 4/28/1985 12.0 IPERF 120° phasing, 5" Dresser Hyperdome 7,778.0 7,792.0 5,916.2 5,926.9 A-4, 2V-09 4/28/1985 4.0 IPERF 120° phasing; 4" Dresser Hyperdome 7,805.0 7,840.0 5,936.7 5,963.4 A-3, 2V-09 4/28/1985 4.0 IPERF 120° phasing; 4" Dresser Hyperdome Notes: General & Safety End Date Annotation 10/4/2021 Note: TBG leak found @ 6618' RKB 10/4/21 2V-09, 12/19/2021 8:10:24 AM Vertical schematic (actual) PRODUCTION; 1,761.0-8,054.5 IPERF; 7,805.0-7,840.0 IPERF; 7,778.0-7,792.0 SOS; 7,748.6 NIPPLE; 7,741.1 SBE; 7,730.1 PACKER; 7,726.8 SEAL ASSY; 7,712.6 SLEEVE-C; 7,696.5 IPERF; 7,682.0-7,686.0 IPERF; 7,668.0-7,675.0 IPERF; 7,592.0-7,654.0 GAS LIFT; 7,478.5 LEAK - C-SAND; 7,479.0 PACKER; 7,394.5 PBR; 7,367.9 PACKER; 7,341.0 NIPPLE; 7,341.0 PACKER; 7,285.4 PBR; 7,262.3 SEAL ASSY; 7,254.2 GAS LIFT; 7,229.1 PATCH; 6,631.6 GAS LIFT; 6,637.2 LEAK - TUBING; 6,618.0 PATCH PERM - UPR; 6,607.5 GAS LIFT; 5,765.7 GAS LIFT; 4,557.0 SURFACE; 34.6-3,617.1 GAS LIFT; 2,873.8 PRODUCTION TIE-BACK; 29.8- 1,761.0 PLUG; 30.0 ftKB NIPPLE; 512.4 CONDUCTOR; 34.6-102.0 HANGER; 32.0 KUP PROD 2V-09 ... WELLNAME WELLBORE2V-09 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 7, 2022 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the permanent tubing patch set across a known tubing leak at 6618’ in producer KRU 2V-09 (PTD 185-037). Please contact me at 907-265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2022.01.07 12:18:02-09'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn Date Event Summary Executive Summary Installed Owens permanent patch from 6608' to 6624' over the known tubing leak at 6618'. Passed diagnostic MIT-IA to 2510 psi and TIFL post patch installation 12/28/21 Passed TIFL post patch installation. 12/19/21 Set Owens permanent patch from 6608'-6624'. Passed Diagnostics MIT-IA to 2510 psi. 12/17/21 Brush and flush patch interval. Verify patch seal depth integrity with D&D hold finder. Passed diagnostic CMIT-TxIA to 1500 psi and passed diagnosic MIT-T to 1500 psi. 12/16/21 Pulled 1.81 CA-2 plug at 7341' 10/05/21 Pull caliper log from 7341' to surface. 10/04/21 LDL identified tubing leak at 6618'. 9/23-25/21 Failed diagnostic tubing test during Braiden head repair prep. Originated: Delivered to:22-Oct-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-25 50-029-22116-00 907415285 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-21 0 12 1D-117 50-029-22844-00 n/a Kuparuk River Packer Setting Record Field- Final 21-Oct-21 0 13 2F-14 50-029-21035-00 907412448 Kuparuk River Plug Setting Record Field- Final 25-Sep-21 0 14 2V-09 50-029-21300-00 907375358 Kuparuk RiverLeak Detect Log Field- Final 4-Oct-21 0 15 2V-09 50-029-21300-00 907429731 Kuparuk River Multi Finger Caliper Field & Processed 5-Oct-21 0 16 2V-13 50-029-21293-00 907399709 Kuparuk River Leak Detect Log Field- Final 21-Sep-21 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:10/25/2021Wd͗ϭϴϱϬϯϳϬ Ͳ^Ğƚ͗ϯϱϴϲϴBy Abby Bell at 11:08 am, Oct 22, 2021 Originated: Delivered to:22-Oct-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-25 50-029-22116-00 907415285 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-21 0 12 1D-117 50-029-22844-00 n/a Kuparuk River Packer Setting Record Field- Final 21-Oct-21 0 13 2F-14 50-029-21035-00 907412448 Kuparuk River Plug Setting Record Field- Final 25-Sep-21 0 14 2V-09 50-029-21300-00 907375358 Kuparuk RiverLeak Detect Log Field- Final 4-Oct-21 0 15 2V-09 50-029-21300-00 907429731 Kuparuk River Multi Finger Caliper Field & Processed 5-Oct-21 0 16 2V-13 50-029-21293-00 907399709 Kuparuk River Leak Detect Log Field- Final 21-Sep-21 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:10/25/2021Wd͗ϭϴϱϬϯϳϬ Ͳ^Ğƚ͗ϯϱϴϲϳBy Abby Bell at 11:08 am, Oct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igitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.10.02 15:22:25-08'00' Foxit PDF Editor Version: 11.0.0 Roger Mouser By Samantha Carlisle at 8:17 am, Oct 04, 2021 Unit RBDMS HEW 10/7/2021 SFD 10/6/2021 SFD VTL 01/24/2022 DSR-10/5/21 50-029-21300-00-00 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.10.02 15:20:32-08'00' Foxit PDF Editor Version: 11.0.0 Roger Mouser !"#$% &'())& * + & , - ./ &01 )''+ • • v66 _ a37 ti - . . ConocoPhillips T Alaska P.O. BOX 100360 NOV 10 2016 ANCHORAGE,ALASKA 99510-0360 .fix November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West'7th Avenue, Suite 100 f rf Anchorage, AK 99501 SCANNED APR `' .,J F. Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from 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. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor w • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 ( 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 2S-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 STATE OF ALASKA ALI/KA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1.OperationsAbandon I- Plug Perforations r Fracture Stimulate(i Pull Tubing r, Operations shutdown r Performed: Suspend r Perforate r ,�.. Other(- Alter Casing It Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: SC Repair F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Developmen FExploratory E 185-0370 3.Address: 6.API Number: Stratigraphi r Service I- P. P. O. Box 100360, Anchorage,Alaska 99510 50-029-21300-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025644 KRU 2V-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8100 feet Plugs(measured) None true vertical 6161 feet Junk(measured) none Effective Depth measured 7974 feet Packer(measured) 7285,7341,7395,7727 true vertical 6070 feet (true vertical) 5540,5582,5623,5877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67' 16 102' 102' SURFACE 3583' 9 5/8 3617' 2924' PRODUCTION 1731' 7 1761' 1612' PRODUCTION 6294' 7 8055' 6127' Perforation depth: Measured depth: 7592-7654,7668-7675,7682-7686,7778-7792,7805-7840 t a::I"`' 2 9 2016 True Vertical Depth: 5774-5822,5833-5838,5843-5846,5916-5927,5937-5963 AOG Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80,7727 MD,5878 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO'DS'NIPPLE @ 512 MD and 511 TVD PACKER=BAKER FHL PACKER @ 7285 MD and 5540 TVD PACKER=KB PACKER @ 7341 MD and 5582 ND PACKER=BAKER FHL PACKER @ 7395 MD and 5623 ND PACKER=BAKER FB-1 PACKER @ 7727 MD and 5877 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA swam). FEB 2 4 201/, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys {— 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation r GSTOR r WINJ r WAG E GINJ E SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-349 Contact Roger Winter Email: n1927(C7conocophillips.com Printed Name o er inter' Title: NSK Well Integrity Field Supervisor Signature Phone:659-7506 Date 7/e9 // Form 10-101 Revised 5/2015 RBDMS t L/StP L 9 1016 Submit Original Only V'T L {o/c-/« dietS6/ • • • 2V-09 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/25/16 Perform 4 pass weld to repair surface casing leak. 09/26/16 MITOA to 200 psi passed. x a � �+ ,...„,,,00* � 4 k h % ''"4 2 yk iii. yiP+'r R # v� (/) " ", _ � � a ....„,„1., t„ � to a Q E _ 4) O co � ' ` to -� Q !"a . `(I) 412 .t,U) a.. .7) r= � ,� % „�i� n N .— (� , .. , O,i,„41, -,.% ,... . ... , .i-so,.. , ,,,, � � '� Z� CO .+,—. V* q�;' 7 + » � � t V ,,-,, 0 0 V ' �3AM' ',7..t.,?;"d m . ` C. 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' .... *s•., 4,..."',,.. -- - • L „.k ,,... .., ,. .„ .,,. ,...._. ,..., ,......... ... . . . . .. , .,... .. , --itiK. „•-•••,.• ...„„,:„.- .• . . , . ....,. ... ... ... ..„,„ ,,, ..... .., ''.,,-. • .-.... ... . ... .„ .. ..„ . ...,.. .,, .. „, ...., 4.!-,,,:: .-.„-••,,..•-, •••,0 . ..,... /„.: , •.*-..,7 ,... ci .:,, . .. ... - -=*,•-' ',:i .:,. ,..,. ., .„.„,.„.......„„.„.„.„-„„..„..,,,„....„, .,„.,.... .., ,.. -•.„4 ..,, ...,,,-•,,, ••4..„„:„. •• „•,., , ••,••-•,,i,••,.,...if, - -...., .i' ,,k'-•„7,: ' -' -••.-,..:. -• ' . . -- •----'111:-.'i'' ' '- •: 4,,. . , ,.... . ., „...,...„ .... , , . ww...,...- " . .,. . „ ... , ..... ,..... ,. ...„,z ..., . ,.,, ....,,,..,....:. ..... .., , ,..-::"-• --•:.1.,,,,*',', -',-., ,. .., ,•:.-'::,51,0: -_ 40- ' t ' '' -‘ . •-•••,.:•,,,,,;,,,•;',.•,. .,...-1/4„,„, : , .0•.ii.;,..,,,,,„,,,, ••:„. , -,,,,•,,,,,•- „„. ,.. ... ,,. .... ... ..... ., .... . — . „„„,.......„.„.., . „..., ..„ ..„ . . .. . „..,,, , ...... . ., ,..- „ ...,.. .. ... . .,. ,„„ •:,,,,,,, „.... . ..,,,..,.....,„.„.„..„..;•.',,,,,'1.1';'','','„'.,'::•,.... : '.'••.,.,..1..•'.. ' ''''''''116..-• .' '. ' , . ••,..,..41,,,mg,1,--, • •-:,,, • . ..„,„.„.„ ...„ .„,„„, .•,,, „ „. .„..., .,.... „......, „„. . „.•.•,,,,,, , . . .,„„.„ ..• .. ..,„....„, 'I, :.'i•.••..,•,•,,•,,. . ,., .., . .,,.. •,,, „,„,... :„.. .••:„.,„ i# '''1',,'.•!is.,',11,F • • Pliir'/ •,, 111)-k....... ,• - ,•,‘,4, -1-1 *„...., _.., '--.;•,-,f.,„.:,,..• ,,,..;:„. -'''''ff1.1qii, •4-1'-'11''' •,'!" . „1,'1. --1 -..,,,,,,,,,,,,,.-_- ..,..:,1'. .„, , ..-'..'..A„. ... -• • S • vOF "i - THE STATE Alaska Oil and Gas :44�►`*��� OfA LASKA Conservation Commission -{ 333 West Seventh Avenue GOVERNOR BILL WALKER """ ' Anchorage, Alaska 99501-3572 >*;. O � -; Main: 907.279.1433 ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor SCANNED JUL 1 2 2016 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2V-09 Permit to Drill Number: 185-037 Sundry Number: 316-349 Dear Ms. Loveland: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0.90LA.,2K._ Cathy . Foerster Chair DATED this day of July, 2016. RBDMS L'.- JV-L.0 8 2016 II • RECEIVED STATE OF ALASKA JUN 2 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 7/7/ // APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well ' , Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing Other: SC Repair , 17 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development P u 185-0370 ' 3.Address: Stratigraphic r Service r 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21300-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA I Will planned perforations require spacing exception? Yes r No P7 KRU 2V-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025644 , Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8100 . 6161 • 7974' • 6070' . 2000 None none Casing Length Size MD TVD Burst Collapse CONDUCTOR 67' 16 102' 102' SURFACE 3583' 9 5/8 3617' 2924' PRODUCTION 1731' 7 1761' 1612' PRODUCTION 6294' 7 8055' 6127' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7592-7654,7668-7675,7682-7686,7778- 5774-5822,5833-5838,5843-5846,5916- 7792,7805-7840 ' 5927,5937-5963 3 1/2 L-80 7727 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE=CAMCO'DS'NIPPLE ' MD=512 TVD=511 PACKER=BAKER FHL PACKER , MD=7285 TVD=5540 PACKER=KB PACKER , MD=7341 TVD=5582 PACKER=BAKER FHL PACKER , MD=7395 TVD=5623 PACKER=BAKER FB-1 PACKER ' MD=7727 TVD=5877 12.Attachments: Proposal Summary ' WellBore Schematic p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p-,• Service r 14.Estimated Date for 15. Well Status after proposed work: 08/01/16 OIL r, WINJ r wDspL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLIJG E Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: MJ.Lovelandcop.com Title: NSK Well Integrity Project Supervisor Signature ' Date: G._ --/ / j.- ‘' 6 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L — Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS LL Jilt 0 8 2(16 Post Initial Injection MIT Req'd? Yes r No 1:2 Spacing Exception Required? Yes r No Subsequent Form Required: C' — 4 0 L- r) APPROVED BY , COMMISSIONERTHE COMMISSION Date: 7., 7_(6 - Approved by: 0 RptJBGa1p( jicA ppSubsin ForDupli ane Form 10-403 Revised it/2015slid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska JUN 28 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGGC June 24, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2V-09, PTD 185-037 surface casing inspection and repair. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2V-09 (PTD 185-037) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 24, 2016 This application for Sundry approval for Kuparuk well 2V-09 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines,and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and build—9' cellar or excavate if necessary. 4. Install nitrogen purge equipment for the conductor(and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Ins ector for opportunity to inspect. ph o fa o c v"" 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. P h co �a cl G t h r c p ✓ 8. Perform a low pressure MITOA(OA is cemented to surface post 2011 RWO) 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the l ellhead. 12. Remove plug(s)and/or BPV and return the well to injection. 13. File 10-404 with the AOGCC post repair. w l p h o t'D a d c V rY7 fa Well Integrity Project Supervisor 6/24/2016 - KUP PROD • 2V-09 + ConocoPhillipslib Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl E) MD(ftKB) Act Btm(ftKB) c.onuooL,wapr 500292130000 KUPARUK RIVER UNIT PROD 47.36 2,125.00 8,100.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2V-09,5/24/29143:4651 PM SSSV:NIPPLE 100 12/15/2012 Last WO: 4/5/2011 34.98 3/25/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --••-•••--•••--------- -- ---- -- Last Tag:SLM 7,843.0 5/23/2014 Rev Reason:TAG lehallf 5/25/2014 ELI , HANGER;32.9 _ .-•�•:` Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread aMI11111111IIIIIIIIIIIMIIIIMINI �� I a CONDUCTOR 16 15.062 34.6 102.0 102.0 65.00 H-40 WELDED 9 �'J Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread •/ SURFACE 95/8 8.921 34.6 3,617.1 2,924.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION TIE- 7 6.276 29.8 1,761.0 1,611.5 26.00 L-80 TCII ..AAl CONDUCTOR;34.6-102.0. h/�., +/.,►/,BACK Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;512.4 PRODUCTION 7 6.276 1,761.0 8,054.5 6,126.4 26.00 J-55 BTC Tubing Strings Tubing Description 'String Ma...I 10(in) 'Top(ftKB) 'Set Depth(It..f Set Depth(N5,877.7 9D)(...I Wt(Ib/ft).30(Grade Top EUEBrConnectiondABMOD TUBING 3 V2 2.992 32.0 7,727.41 L-80 Completion Details PRODUCTION TIE-BACK;29.8- J Nominal ID 1,761.0 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com _ (in) 32.0 32.0 0.06 HANGER FMC TUBING HANGER 2.900 GAS LIFT;2,873.8 - 512.4 511.3 10.00'NIPPLE CAMCO'DS'NIPPLE 2.875 1.1 7,254.2 5,516.7 41.53 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY 3.000 7,262.3 5,522.8 41.33 PBR BAKER PBR 4.000 7,285.4 5,540.2 41.14 PACKER BAKER FHL PACKER 3.000 SURFACE;34.6-3•617.1 7,365.6 5,600.7 40.21 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY 3.000 7,368.0 5,602.5 40.10 PBR BAKER PBR 4.000 GAS LIFT;4,557.0 1.___47,394.5 5,622.8 40.16 PACKER BAKER FHL PACKER 3.000 7,564.9 5,753.4 39.83 BLAST RINGS BLAST RINGS(3) 2.992 7,660.5 5,826.7 40.20 BLAST JOINT STEEL BLAST JOINT 3.000 GAS LIFT;5,765.7_4 47,696.5 5,854.2 40.45 SLEEVE-C BAKER CMU SLIDING SLEEVE 2.813"DS PROFILE- 2.813 CLOSE 4/25/13 7,712.6 5,866.5 40.47 SEAL ASSY BAKER GBH-2 LOCATOR/SEAL ASSEMBLY STABBED 3.000 INTO ORIGINAL TUBING GAS LIFT;6,637.2 Tubing Description I String Me...'ID(in) 'Top(ftKB) -Set Depth(ft..1Set Depth(ND)I...'Wt(Ibttt) 'Grade 'Top Connection PATCH;6,631.6, TUBING Original 31/2 2.992 7,726.8 7,749.41 5,894.5 9.30 J-55 DUE SRD IPC Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Com (in) 7,726.8 5,877.2 40.47 PACKER BAKER FE-1 PACKER 4.000 GAS LIFT;7229.17,730.1 5,879.8 40.47 SBE BAKER SEAL BORE EXTENSION 4.000 - 7,741.1 5,888.2' 40.47 NIPPLE CAMCO D NIPPLE NO GO 2.750 SEAL ASSY;7,254.2 _ PBR;7,282.3 7,748.6 5,893.9 40.47 SOS CAMCO SHEAR OUT SUB.ELMD TTL @ 7737'during 2.992 PPROF on 07/08/2000 PACKER;7,285.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE;7.341.0 Top(ND) Top Incl PACKER;7,341.01 Top(ftKB( (ftKB) CI Des Com Run Date ID(in) 6,631.6 5,066.5 44.65 PATCH 'PERMANENT TUBING PATCH(OAL 22.4') 10/20/2013 2.250 7,341.0 5,582.0- 40.95 NIPPLE D-NIPPLE SET IN KB PACKER 9/28/2013 1.812 7,341.0 5,582.0 40.95 PACKER KB PACKER 9/28/2013 2.500 PBR;7,367.9 PACKER;7,394.5 _ :_, Perforations&Slots Shot -- Dens Top(ND) 000(ND) (shots/7 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;7,478.5 7,592.0 7,654.0 5,774.3 5,821.8 C-4,C-3,C-1, 4/28/1985 12.0 (PERF 120 deg.phasing,5" UNIT B,2V- Dresser Hyperdome 09 7,668.0 7,675.0 5,832.5 5,837.8 UNIT B,2V- 4/28/1985 12.0 IPERF 120 deg.phasing,5" .all 09 Dresser Hyperdome 'PERF;7,592.0-7,654.0 I 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B,2V- 4/28/1985 12.0 IPERF 120 deg.phasing,5" 09 Dresser Hyperdome a all 7,778.0 7,792.0 5,916.2 5,926.9 A-4,2V-09 428/1985 4.0 (PERF 120 deg.phasing;4" all Dresser Hyperdome (PERF;7.668.0-7,675.0^ li I 7,805.0 7,840.0 5,936.7 5,963.4 A-3,2V-09 428/1985 4.0 IPERF 120 deg.phasing;4" Dresser Hyperdome WERE;7.692.0-7,686.0- Mandrel Inserts it st 1. atii SLEEVE-C;706.5 f N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn SEAL ASSY;7.712.6 $� 2.873.8 2,390.4 CAMCO MMG 112 GAS LIFT GLV -R-20 0.188 1,231.0 10/22/2013 2' 4,557.0 3,597.0 CAMCO MMG 11/2 GAS LIFT GLV R/20 0.188 1,238.0 10/22/2013 " 3 5,765.7 4,447.6 CAMCO MMG 1 1/2 GAS LIFT OV RDO- ' 0.188 0.0 10/22/2013 PACKER;7,7268 20 S8E;2730.1 a 4- 6,637.2 5,070.4 CAMCO MMG 1 1/2 GAS LIFT Patch 'RK Ext' 0.000 0.0 5/23/2013 I Pkg 5 7,229.1 5,497.9 CAMCO MMG 11/2 GAS LIFT DMY 'RK 0.000 0.0 4/9/2011 6' 7,478.5 5,687.2 CAMCO MMG 1 12 PROD DMY RK Ext 0.000 0.0 8/12013 NIPPLE;7,741.1 Pkg 1 Notes:General&Safety SOS;7.748.6 i End Date Annotation _ _ 12/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 8/1/2013 NOTE:DSL LDL SHOWS LEAK @ STATION 6(7478'RKB)EXT PKG DMY IPERF;7,778.0-7,792.0- --4 -a ..-- !PERE; !PERF;7,805.0-7,840.0-• PRODUCTION;1.761.0.8,054.5 A STATE OF ALASKA AV a OIL AND GAS CONSERVATION COMh...,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other Set Patch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 185-037 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21300-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25644 • 2V-09 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): LDL,CCL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8100 feet Plugs(measured) none true vertical 6161 feet Junk(measured) none Effective Depth measured 7974 feet Packer(measured) 7285,7341, 7395, 7727 true vertical 6070 feet (true vertical) 5540, 5582, 5623, 5877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 102 102 SURFACE 3582 9.625 3617 2924 RECEIVED PRODUCTION 6294 7 8055 6126 NOV 0 8 2013 AOGCC Perforation depth: Measured depth: 7592-7654, 7668-7675, 7682-7686,7778-7792, 7805-7840 True Vertical Depth: 5774-5822, 5833-5838, 5843-5846, 5916-5927, 5937-5963 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7727 MD, 5878 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7285 MD and 5540 TVD PACKER-KB PACKER @ 7341 MD and 5582 ND PACKER-BAKER FHL PACKER @ 7395 MD and 5623 ND PACKER-BAKER FB-1 PACKER @ 7727 MD and 5877 ND NIPPLE-CAMCO DS NIPPLE @ 512 MD and 511 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 230 1031 2917 -- 179 Subsequent to operation 251 851 1116 -- 189 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ' Service r Stratigraphic r 16.Well Status after work: Oil t Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Tyson Wiese(a,263-4250 Email Tyson.M.WieseCcr�conocophillips.com Printed Name T son Wiese Title Wells Engineer Signature Phone:263-4250 Date"I b/13 \' S'-\Form 10-404 Revised 10/2012 )1/ Form Submit Original Only !2// 2/ / 3 f RBEMS NOV 194 ti-- i KUP PROD 2V-09 ConocoPhiIIips r Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) Act Bim(ItKB) I.a000twtlpc 500292130000 KUPARUK RIVER UNIT PROD 47.36 2.12500 8,100.0 --- Comment I H2S(ppm) Date Annotation End Date KB-Grd(ft) "erg Release Date 20-09.10/29/20131.42.23 PM SSSV:NIPPLE 100 12/15/2012 I Last WO: 4/5/2011 34.98 3/25/1985 Verbal schematic(actual) Annotation Depth(kKB) [End Date Annotation Last Mod By End Date . - - - - - Last Tag:SLM 7,851.0 11/18/2012 Rev Reason:SET PATCH,SET PACKER w/D osborl 10/24/2013 `'1y r:'.S� NIP,GLV C/O HANGER 320 --- '1.-...-.::°:':?: Casing Strings ■■` Casing Description OD(in) ID(in) Top(ItKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread '7r.: .Ir tma,CONDUCTOR 16 15.062 34.6 102.0 102.0 65.00 H-40 WELDED 2,924.0:::.::.:.i:::.::::,:.'„::.:.::;:::.: >�J' Casing Description OD(in) ID(in) Top(RKB) 'Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 34.6 3,617.1 2,924.0 36.00 J-55 BTC .: Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION TIE- 7 6276 29.8 1,761.0 1,611.5 26.00 L-80 TCII .AA/CONDUCTOR;34.6-102.0' :: BACK •R� Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread NIPPLE;512.4 PRODUCTION 7 6.276 1,761.0 8,054.5 6.126.4 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(k..Set Depth(ND)I...Wt(lb/ft) Grade Top Connection L;; TUBING I 31/21 2.9921 3201 7,727.41 5.877.71 9.3017-80 I EUE8rdABMOD PLUG;30.0 Completion Details PRODUCTION TIE-BACK;29.6 Nominal ID 1,761.0 Top(RKB) Top(ND((RKB( Top Ind(°) Item Des Com (in) 32.0 32.0 0.06 HANGER FMC TUBING HANGER 2.900 GAS LIFT;2,873.8 - 512.4 511.3 10.00 NIPPLE CAMCO'DS'NIPPLE 2.875 ill 1 7,254.2 5,516.7 41.53 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY 3.000 7,262.3 5,522.8 41.33 PBR BAKER PBR 4.000 7,285.4 5,540.2 41.14 PACKER BAKER FHL PACKER 3.000 3.000 SURFACE;34.63,617.1- 7.365.6 5,600.7 4021 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY • 7,368.0 5,602.5 40.10 PBR BAKER PER 4.000 I. GAS LIFT;4.557.0 - 7,394.5 5,622.8 40.16 PACKER BAKER FHL PACKER 3.000 7,564.9 5,753.4 39.83 BLAST RINGS BLAST RINGS(3) 2.992 7,660.5 5,826.7 40.20 BLAST JOINT STEEL BLAST JOINT 3.000 GAS LIFT;5,765.7 ° 7,696.5 5,854.2 40.45 SLEEVE-C BAKER CMU SLIDING SLEEVE 2.813"DS PROFILE- 2.813 • CLOSE 4/25/13 7,712.6 5,866.5 40.47 SEAL ASSY BAKER GBH-2 LOCATOR/SEAL ASSEMBLY STABBED 3.000 INTO ORIGINAL TUBING GAS LIFT;6,637.2, I. ! Tubing Description I String Ma...11D(in) 'Top(RKB) Set Depth(It..I Set Depth(150)(...1 Wt(lb/ft) !Grade /Top Connection PATCH;6,63t6 '.'s TUBING Original 31/2 2.992 7,726.8 1,/494 5,894.5 930 J-55 EUE 8RD IPC i Completion Details Nominal ID Top(RKB) Top(ND)(ftKB) Top Ind(1 Item Des Com (in) 7,7266 5,877.2 40.47 PACKER BAKER FE-1 PACKER 4.000 GASUFT;7.229.1 7,730.1 5,879.8 40.47 SBE BAKER SEAL BORE EXTENSION 4.000 SEALASSY;7,25a.2 _ 7.741.1 5,888.2 40.47 NIPPLE CAMCO D NIPPLE NO GO 2.750 PBR;7262.3 ' 7,748.6 5,893.9 40.47 SOS CAMCO SHEAR OUT SUB.ELMD TTL @ 7737'during 2.992 PACKER;7.2e5.4 PPROF on 07/082000 Other In " , fevable plugs,valves,pumps,fish,etc.) NIPPLE;7,341.0 � � �i .�Top(TVD) Top Ind PACKER;7,341.01 Top(kKB) (RKB) (( Des Com Run Date ID(in)- 6,631.6 5,066.5 44.65 PATCH PERMANENT TUBING PATCH(OAL 22.4') 10/20/2013 2.250 7,341.0' 5,582.0 40.95 NIPPLE -D-NIPPLE SET IN KB PACKER 9/28/2013 1.812 7,347.0 5,582.0 40.95 PACKER KB PACKER 9/28/2013 2.500 PBR;7,367.9 PACKER;7,394.5 Perforations&Slots Shot Dens Top fTwl (ND) (shotsk Top(kKB) Btm(RKB) (RKB) (R(B) Zone Date t) Type Com GAS LIFT;7.478.5 7,592.0 7.654.0 5,774.3 5,821.8 C-4,C-3,C-1, 4/28/1985 12.0 IPERF 120 deg.phasing,5" UNIT B,2V- Dresser Hyperdome 09 7,668.0 7,675.0 5,8325 5,837.8 UNIT B,2V- 428/1985 12.0 IPERF 120 deg.phasing,5" •ae 09 Dresser Hyperdome IPERF;7.5920-7.6540- I 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B,2V- 428/1985 12.0 IPERF 120 deg.phasing,5" a 09 Dresser Hyperdome lat 7,778.0 7,792.0 5,916.2 5,926.9 A-4,2V-09 428/1985 4.0 IPERF 120 deg.phasing;4" Ilk Dresser Hyperdome IPERF;7.6680-7.675.0- Imo, 1 7,805.0 7,840.0 5,936.7 5,963.4 A-3,2V-09 428/1985 4.0 IPERF 120 deg.phasing;4" Dresser Hyperdome IPERF;7,682.0-7,686.0----_ 1 Mandrel Inserts s- - H i St C SLEEVE-C;7,696.5 '.i No Top(ND) Valve Latch Port Size TRO Run lij _ Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date SEAL ASSY;7,712.6 �' 1 2,873.8 2,390.4 CAMCO MMG 112 GAS LIFT GLV R-20 0.188 1,231.0 10/22/2013 m •c., 2 4,557.0 3,597.0 CAMCO MMG 1 1/2 GAS LIFT GLV R/20 0.188 1,238.0 10/22/2013 PACKER;7,726.8 °,4 3 5,765.7 4,447.6 CAMCO MMG 1 1/2 GAS LIFT OV RDO- 0.188 0.0 1022/2013 20 96 5 ,7,730.1 ' 4 6,637.2 5,070.4 CAMCO MMG 1 1/2 GAS LIFT Patch RK Ext 0.000 0.0 5/23/2013 Pkg II 5 7,229.1 5,497.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/9/2011 6 7.478.5 5,687.2 CAMCO MMG 1 1/2 PROD DMY RK EM 0.000 0.0 8/1/2013 NIPPLE;7.741.1 Pkg I • Notes:General&Safety SOS;7748.6 .II End Date Annotation 12/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;7,778.0-7792.0- 8/1/2013 NOTE:DSL LDL SHOWS LEAK @ STATION 6(7478'RKB)EXT PKG DMY IPERF;7,805.0-7,840.0 Y PRODUCTION;1.761.04054.5 • 2V-09 Well Work Summary DATE SUMMARY 4/16/2013 SUBSIDENCE TIFL(FAILED DUE TO PRESSURE INCREASE AND INFLOW DURING MONITOR) 4/22/2013 TAGGED @ 7840' SLM, EST 49' RATHOLE. DRIFTED TBG WITH 2.78"WRP DRIFT TO 7741' RKB; NO TIGHT SPOTS. IN PROGRESS. 4/25/2013 CLOSED CMU @ 7696' RKB. SET 2.75 CA-2 PLUG @ 7741' RKB. SET 3 1/2 AVA STYLE CATCHER ON PLUG. PULLED OV @ 5765', GLVs @ 4557'&2873' RKB. SET DVs @ SAME. IN PROGRESS.. 4/28/2013 SET DV @ 5765' RKB. ATTEMPTED TEST, IA COMMUNICATING. SET HOLEFINDER @ 6591'SLM, GOOD TBG TEST. IN PROGRESS. 4/29/2013 AFTER MULTIPLE ATTEMPTS, PULLED DV @ 6637' RKB; DIFFICULT LATCHING. IN PROGRESS. 4/30/2013 SET DV @ 6637' RKB; SET 2.81" CAT SV @ 7696' RKB; (MITT&CMIT FAILS ) RAN HOLEFINDER AND DETERMINE LEAK TO BE BETWEEN 6629' RKB AND 6793' RKB. IN PROGRESS. 5/1/2013 RAN PONY TAIL& LOCATE TBG LEAK @ 6640' RKB ( 1.5 BBLS @ 1200 PSI LEAK RATE ). FAILED CMIT. READY FOR E-LINE PENDING PROCEDURE. 5/3/2013 ATTEMPTED TO BLEED TBG & IA FOR DDT. UNABLE TO BLEED TBG BELOW 350 PSI AND IA BELOW 360 PSI. 5/6/2013 PERFORMED LDL LOG. PUMPED WATER AT 1 BPM DOWN TUBING AND FOUND LEAK IN MANDREL AT 7479'. FOUND SECOND LEAK WHILE PUMPING WATER DOWN IA AT 0.5 BPM IN GLM LOCATED AT 6637'. PUMPED TOTAL OF 36.5 BBLS OF WATER DURING LEAK DETECT. FREEZE PROTECTED IA WITH 61 BBLS OF DIESEL DOWN IA AND 20 BBLS OF DIESEL DOWN TUBING 5/10/2013 LOG GYRODATA GYRO W/CCL IN CONTINOUS MODE FROM SURFACE TO TAG AT 7696'CATCHER ASSY. DATA SENT OUT FOR PROCESSING. 5/11/2013 PULLED 2.81"CAT SV @ 7697' RKB; PULLED CATCHER& 2.75"CA-2 PLUG @ 7741' RKB. READY FOR E-LINE WRP. 5/18/2013 PLUG SET @ 7355', CCL TO MID-ELEMENT: 11', CCL STOP DEPTH @ 7344'. CORRELATED TO TUBING TALLY. READY FOR DHD. 5/22/2013 SET 2.78"CATCHER ON WRP @ 7355' RKB. PULLED DV @ 6637' RKB. IN PROGRESS. 5/23/2013 LOADED WELL WITH 157 BBL INHIB SW&76 BBL DSL. MIT T x IA 2500 PSI, PASSED. SET EXTENDED PKG DV @ 6637' RKB. T x IA COMMUNICATING. DRIFTED TBG w/2.74"x 16.3' DUMMY PATCH TO 6700' RKB. COMPLETE. 7/31/2013 PULLED 2.78"WEATHERFORD WRP FROM 7353' RKB. PERFORMED COMBINED A/C SAND SBHPS WITH DSL. JOB IN-PROGRESS. 8/1/2013 SET 2.75"CA-2 PLUG IN D-NIPPLE @ 7741' RKB. FERFORMED C-SAND ONLY SBHPS. SET 3-1/2" CATCHER @ 7686'SLM, PULLED RK-DGLV FROM ST#6 @ 7445' RKB. SET RK-DGLV WITH EXTENDED PACKING IN ST#6 @ 7741' RKB AND ATTEMPTED TO CMIT TxIA WITH LRS. RAN LDL AND OBSERVED LEAK IN ST#6 @ 7445' RKB. PULLED EMPTY CATCHER FROM 7686' SLM. JOB IN PROGRESS. 8/2/2013 PULL CA-2 PLUG FROM D NIPPLE @ 7441' RKB, MISSET 2.78"WFD WRP, PULL 2.78"WFD WRP FROM 7239'SLM, SET 2.78"WFD WRP, CENTER ELEMENT @ 7345' RKB, CCL TO MID ELEMENT IS 26.9', CCL STOP DEPTH 7318.1' RKB. LRS C-MIT TO 2500PSI, PASSED. JOB COMPLETE. 9/16/2013 (RWO): T POT-PASSED; T PPPOT-PASSED; IC POT-PASSED; IC PPPOT-PASSED; FUNCTION TEST LDS'S-ALL FUNCTIONED PROPERLY. 9/18/2013 PULL 2.78"WRP FROM 7344' RKB, BRUSH & FLUSH TUBING W/75bbls DIESEL& BRUSH W/2.70"G. RING, FOCUS ON PATCH & KB PACKER SETTING DEPTHS, RAN 34' DRIFT TO 7600' SLM, NO RESTRICTIONS (TOP SECTION 2.75"x 11', MIDDLE SECTION 2.78"x 12', BOTTOM SECTION 2.80"x 10'), JOB COMPLETE 1"'9/23/2013 RUN CALIPER F/7770' RKB TO SURFACE. READY FOR PATCH PENDING DATA. it 9/28/2013 SET CENTER OF ELEMENT OF 35 KB PACKER WITH D-NIPPLE @ 7342' RKB. CCL TO CENTER ELEMENT=31.8'. CCL STOP DEPTH @ 7310.2' RKB. SET 1.812"CA-2 PLUG IN D-NIPPLE IN PACKER @ 7342' RKB.ATTEMPTED TO CMIT-TxIA WITH LRS. LRS WILL RETURN WITH MORE FLUID. SPINNER AND TEMP SHOWS GOOD INDICATION PLUG IS HOLDING....LRS PERFORMED PASSING CMIT TO 2000 PSI. SEE ATTACHED REPORT. ' `10/1/2013 (AC EVAL)T DDT(PASSED), IA DDT(PASSED). 10/20/2013 SET PATCH FROM 6632-6652 OVER LEAKING GLM AT 6638'. LRS PERFORMED PASSING MIT-IA TO 2000 PSI. MIT-T FAILED. DHD PERFORMED PASSING IA DDT. SEE ATTACHED LRS REPORTS FOR MIT TESTS. READY FOR SLICKLINE 4, 10/21/2013 (AC EVAL) IA-DDT PASSED. 10/22/2013 SET AVA CATCHER @ 6332' RKB; PULL DV'S @ 2874', 4557', &57F— RKB; SET GLD IN SAME; PULL CATCHER. IN PROGRE 10/23/2013 PULL 1.81" CA-2 @ 7342' rcKB. COMPLETE X39`T WELL LOG TRANSMITTAL DATA LOGGED 1On0/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 26, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 y Anchorage,Alaska 99501 OCT 1 0 101:: C'L e,{1 RE: Multi Finger Caliper(MFC): 2V-09 Run Date: 9/23/2013 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 2V-09 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21300-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating %We DEC 1 201; Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: k0[ of3 Signed: 8.aztelez,,‘.._ fl F Rf k � WELL LOG TRANSMITTAL MAY 1 © 213 AOGCC To: Alaska Oil and Gas Conservation Comm. May 7, 2013 Attn.: Makana Bender 65- (31°S.1333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 �ZCJ3� RE: Leak Detection Log: 2V-09 � Run Date: 4/6/2013 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 2V-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21300-00 SCANNED MAR 1 32014 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/\G/\Z) Signed: 46• STATE OF ALASKA , s , ALASKA', AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Rug Perforations `°" Stimulate Other Alter Casing F7 Rill Tubing P;' Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat. Shutdown r Perforate Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 185 - 037 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service Y 50- 029 - 21300 -00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25644 - - 2V -09 9. Field /Pool(s): r Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8100 feet Plugs (measured) None true vertical 6161 feet Junk (measured) None Effective Depth measured 7974 feet Packer (measured) 7285, 7394, 7727 true vertical 6070 feet (true vertucal) 5540, 5623, 5877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 102 102 SURFACE 3582 9.625" 3617' 2924' PRODUCTION 8024 7" 8055' 6126' SAANNED MAY 0 b 2011 Perforation depth: Measured depth: 7592'- 7654', 7668'- 7676, 7682'- 7686', 7778'- 7792', 7805' -7840' True Vertical Depth: 5774'- 5822', 5832'- 5838', 5843'- 5846', 5916- 5927', 5937-5963' RECEIVED' Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7727 MD, 5894 TVD MA' 03 2011 Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 7285 MD and 5540 TVDigaska Oil & G c G enan i ss i wo PACKER - BAKER FHL PACKER @ 7394 MD and 5623 TVD PACKER - BAKER FB -1 PACKER @ 7727 MD and 5877 TVD Moorage NIPPLE - CAMCO 'DS' NIPPLE @ 512 MD and 511 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p 0 Service r Stratigraphic 15. Well Status after work: , w Gas r WDSPL Daily Report of Well Operations XXX GSTOR ' WINJ E WAG r GINJ SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -027 Contact Howard Gober 263 -4220 Printed Name Howard Gober Title Wells Engineering Supervisor Signature Phone: 263 -4220 Date 5/4 Form 10 -404 Revised 10/2010 RBDMS MAY 0 3 2011 �='J.��` t, ..- 5.10( Submit Original Only 14_, • �' t KUP ID 2V -09 Con coPhil i Well Attributes Max Angle & MD 1 TD , Alaskt 1r r K Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Bhp (ftKB) ) fsxio.rkh Di ps 500292130001: 'I KUPARUK RIVER UNIT JPROD 47.36 2,12500 8100.0 ' ' C me H25 (ppm) Date An etatbn End D to KB (ft) Rig Release Date SSSV: NIPPLE 45 1/17/2010 Last WO: I 4/5/2011 34.98 325/1985 A n d D otation . 'Depth (RKB) Enate Annotat on Last Mod ... End Data Last Tag: SLM I 7.815 0 j 10/8/2010 Rev Reason: WORKOVER Imosbor 4/15/2011 Casin • Strings HANGER, 32 _ - ,i Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 34.6 102.0 102.0 65 H - 40 WELDED , , Casing Description String 0... String ID .. Top (RKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String .. String Top Thrd SURFACE 95/8 8.921 34.6 3,617.1 2,924 1 36.00 J BTC Cuing Description String 0... String ID ... Top (ftKB) Set Depth (L. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 29.8 1,761.0 1,611.4 26.00 L-80 TCII TIE -BACK CONDUCTOR, Cuing Description String 0... String ID ... Top (ftKB) Set Depth O... Set Depth (TVD) ... String Wt... String ... String Top Thrd 35 PRODUCTION I 7 , 6 -151 1,761.0 8,054.5 6,126.4 , 26.00 J -55 BTC NIPPLE, 512 - Tubing Strings ° Tubing Description String 0 String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD) String Wt... IStr g Stri g Top Thrd .. TUBING 31/2 I .. 2.992 I 3 2.0 I 7,727.4 l 5,87 I 9.30 I L-80 I EUE8r4ABMOD Completion Details Top Depth (TVD) Top Inc! Nomi... PRODUCTION , Top (ftKB) (f Kei (°) Item Description Comment ID (!n) TIE BACK, 61 32 320 0.06 HANGER FMC TUBING HANGER 2.900 34AC HA 512.4 511.3 10.00 NIPPLE CAMCO'DS' NIPPLE 2.875 GAS LIFT, - 2,874 7,254.2 5,516.7 47.53 SEAL ASSY BAKER GBH -22 LOCATOR/SEAL ASSEMBLY 3.000 7,262.3 5,522.8 41.33 PBR BAKER PBR 4.000 7,285.4 5,540.2 41.14 PACKER BAKER FHL PACKER 3.000 1� 7,365.6 5,600.7 40.21 SEAL ASSY BAKER GBH -22 LOCATOR/SEAL ASSEMBLY 3.000 SURFACE, 7,368.0 5,602.5 40.10 PBR BAKER PBR 4.000 _ 35 -3,617 - ";, 7,394.5 5,622 8 40 -16 PACKER BAKER R FH FHL PACKER 3.000 it 7,564.9 5,7534 39.83 BLAST RINGS 2.992 GAS LIFT, , 7,712.6 5,866.5 40.47 S ASSY BAKER GBH -2 L STABBED INTO PROFILE 3.000 ass? TUBING 7 5 5826 7 40.20 BLAST JOINT STEEL BLAST JOINT 3.000 Il ORIGINAL GAS LIFT, '.. 5,766 Descn Ion 'String 0 ... String ID... To Set Depth L.. Set h (TVD) ... String Wt... String String T Thrd Tubing W g 9 7 (�B ) P ( 05 . 9 ... U R "°^` TUBING Ongmal 3 1/2 2.992 7,726.8 7,749.4 � 5,894.5 9 30 J -55 EUE SRD IPC 14R, Tubl Completion Details GAS LIFT, ''1 Top Depth 6,637 _ - -- •- (TVD 1 Teo Inc! Rani... To. . 6 (RKB) 11 Item Deswl•. •n Comment ID (in) 7,726.8 5,87 / 2 40.47 PACKER BAKER FB -1 PACKER 4.000 7,730.1 5,87 40.47 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT. 7,229 7,741.1 5,880 4 10.47 NIPPLE CAMCO D NIPPLE NO GO 2.750 IR SEAL ASSY, 7,748.6 5,89 , 9 40 47 SOS CAMCO SHEAR OUT SUB ELMD I I L @ 7737 during PPROF on 2.992 7,254 ..E-. - -�' _ 07/08 /2000 �, PBR, 7,262 PACKER, 7,285 - - - -_ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depill (TVD) Top Inc! Top MKS) OMB) (3 Description Comment Run Date ID (Mt 7,741.1 5,888.1 40.47 Nipple Reducer Camco NIPPLE REDUCER 11/5/1995 2.250 PBR, 7,369 - 1 Perforations & Slots Shot PACKER ,7,394 - - - - - r _ _ Top(TVD) Btrn(TVD) Dens Top (ftKB) Bkn MK,}_ (ftKB) (fUCB) Zone Date ( A. a Comment 7,592.0 7,654.0 5,774.3 5,821.7 C-4, C -3, C -1, 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser UNIT B, 2V -09 Hyperdome GAS LIFT, - 7,479 � `-- 7,668.0 7,675.0 5,832.4 5,837.8 UNIT B, 2V -09 4/28/1985 r IPERF 120 deg. phasing, 5" Dresser Hyperdome IF 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B, 2V -09 4/28/1985 r IPERF 120 deg. phasing, 5" Dresser Hyperdome 7,778.0 7,792.0 5,916.2 5,926.9 A-4, 2V -09 4/28/1985 4.0 IPERF 120 deg. phasing; 4" Dresser IPERF, Hyperdome 7,592 -7,856 - i I 1 7,805.0 7,840.0 5,936.7 5,963.4 A -3, 2V -09 4/28/1985 4.0 IPERF 120 deg. phasing; 4" Dresser 1..__ Hyperdome IPERF, Notes: General & Safety 7,668 -7,675 l - End Date Annotat n 3/1/2006 .1.J IL. PPROF IDENTIFIED C -SAND TBG LEAK @ 7631 ERF, _ - - - 7,682 - 12/8/2010 '441 L: View Schematic w/ Alaska Schematic9.0 SLEEVE, 7,697 SEAL ASSY, - 7,713 PACKER, 7,727 SBE, 7,730 ).�._ _1 _ _ - , Mandrel Details - [ -- Top Depth Top'___ -- ` -- Port (ND) Inc! OD Valve Latch SM. TRO Run Nipple Re 7,74'1 ' ' S Top (ftKB) (ftKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Can... 0741 NIPPLE, 7,741 - -- 1 2,860.4 2,380.9 44.81 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,210.0 4/10/2011 2 4,543.6 3,587.6 45.61 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,218.0 4/10/2011 S08,7,749 & 3 5,752.4 4,438.1 44.57 CAMCO MMG 1 12 GAS LIFT OV RK 0.188 0.0 4/92011 4 6,623.8 5,060.9 44.38 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/5/2011 IPERF , 5 7,215.7 5,487.9 41.90 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/9/2011 7,778-7,792 6 7,465.1 5,676.9 40.08 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/52011 IPF, ER____ 7,805 -7,8 PRODUCTION, i 1,761 -8,055 TD, 8,100 • • ConocoPhillips Time Log & Summary We[fwew Web Reporting Report Well Name: 2V - 09 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/12/2011 9:00:00 PM Rig Release: 4/4/2011 9:30:00 AM Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 03/12/2011 24 hr summary Complete planned program on 2A -06 Well. Move Nordic Rig 3 from 2A -06 to 2V -09. 11:00 16:00 5.00 MIRU MOVE MOB P Move Nordic #3 rig from 2A -06 to CPF -2. 16:00 20:30 4.50 MIRU MOVE MOB P Continue to move Rig from CPF -2 to 2V Pad. Had to stop several time while snow drifts were removed from the Access Road. 20:30 23:30 3.00 MIRU MOVE RURD P Stage rig mats. Build up ramp for double mats. 23:30 00:00 0.50 MIRU MOVE SFTY P PJSM. Prep to move rig over Well. 03/13/2011 Finish rigging up. Pull BPV. Circulate and Kill Well with 9.6 lb/gal Brine. ND Tree. NU BOP Stack. 00:00 06:00 6.00 MIRU MOVE RURD P Spot remaining around rig, return tank etc... Load pits with 9.6 ppg brine. 06:00 12:00 6.00 COMPZ WHDBO MPSP P P/U BPV lubricator. Troubleshoot issues with lubricator, issue resolved. Pull BPV and lay down lubricator. Initial pressures: TBG 400 psi IA 400 psi OA 20 psi. 12:00 13:00 1.00 COMPZ WELCTL RURD P RU circulating lines and test all surface equipment to 3,000 psi 13:00 17:00 4.00 COMPZ WELCTLCIRC P Bleed off 400 psi on tubing, start circulating out diesel. Pumped 260 bbls Of 9.6 ppg brine down tubing out IA to return tank, getting 9.6 brine back to surface with gas. Pump additional 65 bbls down tubing. Verify well dead. 17:00 18:00 1.00 COMPZ WHDBO MPSP P Set BPV 18:00 20:00 2.00 COMPZ WHDBO NUND P ND Tree. Inspect Tubing Hanger threads. Install Blanking Plug. 20:00 23:30 3.50 COMPZ WHDBO NUND P Nipple up 11" x 5K BOP Stack with 2 7/8" x 5" VBPR in top and bottom gates. 23:30 00:00 0.50 COMPZ WHDBO SFTY P PJSM. Discuss pressure testing and rigging up test equipment. Prep for BOPE test. 03/14/2011 Perform initial BOPE test. BOLDS. Attempt to pull PBR free from Pkr. RU E -Line to cut Tubing. After first cut at 7,404 -ft the Tbg still was not free. Made a second cut at 7,402 -ft. Tubing now free. RD and release E -Line. Page 1 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:30 7.50 COMPZ WHDBO BOPE P Perform initial BOPE test per n ConocoPhillips, AOGCC D 1" requirements at 250/3,000 psi. Test .6( Annular at 250/3,000 psi. Record r� tests on chart. Perform Koomey draw down test. All tests good. The State's right to witness the test was waived by J. Jones. (Note: Upper VB Pipe Rams failed test. Replace and test. Good). 07:30 08:30 1.00 COMPZ WELCTI PULD P Pull blanking plug & BPV 08:30 09:30 1.00 COMPZ RPCOM PULL P MU landing joint, MU to top drive. BOLDS. Pull up to max pull with blocks to 149K several times with no movement. Continue to work pipe, call out Haltiburton E -Line equipment. 09:30 12:00 2.50 COMPZ RPCOM ELNE T Wait on E -Line equipment. 12:00 14:00 2.00 COMPZ RPCOM ELNE T E -Line equipment on location. Spot equipment. PJSM. Pull tension on Tubing String. 14:00 18:30 4.50 COMPZ RPCOM ELNE T Rig up Lubricator and Radial Cutting Torch Tool String. RIH. Position RCT to cut in the middle of the first joint above the PBR at 7,404 -ft. Set Anchor. Fire Cutter. _ POOH with Tool String. Cutter fired. Set back E -Line. 18:30 19:30 1.00 COMPZ RPCOM PULL T Worked Tubing up to 150K (80% plus Top Drive weight). Attempt to pull 3 1/2" Tubing free at cut depth. No -Joy. 19:30 20:30 1.00 COMPZ RPCOM PULL T Continue to work to pull Tubing free. Discuss options weather to run a free -point log or to make a second cut with Anchorage Engineer. 20:30 23:30 3.00 COMPZ RPCOM ELNE T PJSM. Make up second Radial Cutting Torch. RIH. Position Cutter Z 'f at 7,402 -ft (2 -ft above the firsty n attempt). Set Anchor. Fire Cutter. Good indications this time the Tubing was cut. POOH with Tool String. Cutter fired. Set back E -Line. 23:30 00:00 0.50 7,402 7,390 COMPZ RPCOM PULL P Pick -up on Tubing. Free at 100K. Complete E -Line rig down and release Unit. 03/15/2011 Circ bottoms up. Single down 3 1/2" Completion. MU BHA #1. Single in on 3 1/2" Drill Pipe. 00:00 01:00 1.00 7,390 7,390 COMPZ RPCOM CIRC P Circulate bottoms -up with 9.6 lb/gal Brine at 5.0 bpm /640 psi. Monitor Well static. 01:00 02:00 1.00 7,390 7,390 COMPZ RPCOM RURD P PJSM. Rig up Control Line Spooling Unit. Page 2 of 27 Time Logs Date From To " Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 12:00 10.00 7,390 0 COMPZ RPCOM PULL P Begin to single down the 3 1/2" Completion while spooling single Control Line. Tubing pulling free at 100K. Number and tally Tubing. Clear Pipe Shed as needed. Lay down SSSV. Rig down Spooling Unit. Recovered all 30 Control Line Bands. Continue to single down the 3 1/2" Completion. 12:00 15:00 3.00 0 0 COMPZ RPCOM PUTB P Kick out the last row of Tubing and Jewelry from Pipe Shed. Clear Floor. OD the 3.5" Cut -Off Joint and it measured 3.5 ". Observed no bent joints or deformation on any kind on the 3.5" Tubing pulled from the Well. Found —2 -ft of thick "muck" and a small amount of corrosion build -up on the outside, near the end of the Cut -Off Joint. 15:00 15:15 0.25 0 0 COMPZ WELLPF SFTY P PSJM. Discuss Hazard of loading tools up beaver slide to rig floor. 15:15 16:30 1.25 0 0 COMPZ WELLPF PULD P Load Tools To Rig Floor. C/O Handling Equipment. Change Torque On Top Drive. 16:30 16:45 0.25 0 0 COMPZ WELLPF SFTY P PSJM. Discuss Hazard of Making up Casing Scraper Assembly 16:45 17:00 0.25 0 60 COMPZ WELLPF PULD P M/U Scraper Assembly on 3.5" Drill Pipe. BHA= 6" x 3.5" Dress of guide shoe with 2 five foot extension, and two 4 3/4" boot basket & 4 3/4" String magnet with a 7" Casing Scraper. 17:00 21:00 4.00 60 3,027 COMPZ WELLPF PUTB P RIH with Scraper Assembly. Single in with 3 1/2" Drill Pipe from Pipe Shed. Stop to Cut and Slip Drilling Line. 21:00 21:15 0.25 3,027 3,027 COMPZ RIGMNT SFTY P PJSM. Discuss the hazards and steps to Cut and Slip Drill Line. 21:15 22:30 1.25 3,027 3,027 COMPZ RIGMNT SLPC P Cut and Slip 84 -ft of Drill Line. Service and inspect Draw works. 22:30 00:00 1.50 3,027 5,026 COMPZ WELLPF PUTB P Continue RIH with BHA #1 picking up single 3 1/2" Drill Pipe Jts from the Pipe Shed to 5,000 -ft. Up Weight = 75K. Down Weight = 69K. 03/16/2011 Tag top of 3 1/2" Tbg Stump. Swallow Stump. Reverse circulate Well clean. Trip out with Drill Pipe. Rig -up E -Line. Record Caliper Log. Record Gyro Log. 00:00 02:00 2.00 5,026 7,380 COMPZ WELLPF PUTB P Continue to RIH with BHA #1. Picking up single 3 1/2" Drill Pipe Jts from Pipe Shed. Page 3 of 27 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02:00 03:00 1.00 7,380 7,396 COMPZ WELLPF FCO P Gather parameters. Up Weight = 135K. down Weight = 93K. Bring Pump on line at 3.0 bpm /330 psi. Top Drive = 30 RPMs. Wash through "Fill" down to 7,384 -ft and tag the top of the 3 1/2" Tubing Stump. Work over Stump. Had several "stalls" and over pulls to get off. Increase Pump rate to 5.0 bpm /840 psi. Increase Top Drive speed to 60 RPMs. Swallow Stump down to 7,396 -ft dpmd. Pump pressure increased to 1,520 psi when BHA bottomed out. Repeat several times with same results. 03:00 04:30 1.50 7,396 7,394 COMPZ WELLPFCIRC P Reverse Circulate at 6.0 bpm /1,200 psi. with 9.6 lb/gal Brine. Reverse in a 40 bbl Hi -Vis Sweep. Reverse Circulate Well clean at 6.0 bpm /1,030 psi. 04:30 10:00 5.50 7,394 60 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe standing back in the Derrick. 10:00 10:15 0.25 60 60 COMPZ WELLPF SFTY P OOH with Drill Pipe. PJSM. Discuss Hazard of Breaking down BHA. 10:15 11:45 1.50 60 0 COMPZ WELLPF PULD P Lay down and inspect scraper assembly. ( Tools Look Good with no damage and wear) . Seen good indication from dress off guide shoe that the shoe was over the 3.5" tubing stub. Un -load tools from rig floor. Load Shooting Nipple. 11:45 12:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Had Safety meeting with HES E -Line Crew and Rig crew. 12:00 12:45 0.75 0 0 COMPZ WELLPF ELOG P Load E -Line tools and equipment to rig floor. 12:45 16:00 3.25 0 7,390 COMPZ WELLPF ELOG P M/U and RIH with HES Caliper logging tools for 7" Casing down to 3.5" tubing stub at 7390' ELMD and Log to surface at 50 fpm. 16:00 17:30 1.50 7,390 0 COMPZ WELLPF ELOG P OOH with logging assembly. Lay down tools and download data to transfer to PDS to process. 17:30 18:30 1.00 0 0 COMPZ WELLPF ELOG P Make -up Gyro Logging Tools. 18:30 21:15 2.75 0 7,390 COMPZ WELLPF ELOG P RIH to the top of the 3 1/2" Tubing Stump. 21:15 00:00 2.75 7,390 400 COMPZ WELLPF ELOG P Start to record Gyro Data from the Tubing Stump back to surface. 03/17/2011 Record and evaluate RCBL. Run String Shot. RD E -Line. RIH and set Baker RBP. Dump Sand and tag same. POOH. ND BOP Stack. Prep for Hydratight operations. 00:00 01:00 1.00 400 0 COMPZ WELLPF ELOG P Complete Gyro Log (good data recorded). Lay down Gyro Tool String. Make -up RCBL Tool String. 01:00 02:30 1.50 0 7,390 COMPZ WELLPF ELOG P RIH with RCBL Tool String to 3 1/2" Tubing Stump. Page 4 of 27 • • Time Logs Date + From To ` Dur S. Depth E. Phase Code Subcode T Comment 02:30 06:00 3.50 7,390 0 COMPZ WELLPF ELOG P Begin recording Cement Bond data at 55 - ft/min from the Tubing Stump back to surface. Down Toad data. Discuss with Town on depth for string shot on 7" collar. 06:00 06:15 0.25 0 0 COMPZ WELLPF SFTY P E -Line crew & Rig crew change out. PJSM on next steps for string shot. 06:15 09:00 2.75 0 1,768 COMPZ WELLPF ELOG P M/U and RIH with string shot assembly. Tie -in and correlated to HES RCBL, made string shot across 7" CSG collar at 1768' ELMD. RDMO, E -Line. 09:00 10:00 1.00 0 0 COMPZ RIGMN1OTHR P PJSM. Service Top Drive and Blocks. 10:00 10:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Loading tools up Beaver Slid. 10:15 10:30 0.25 0 0 COMPZ WELLPF PULD P Load RBP and Tools to Rig floor. 10:30 12:30 2.00 0 1,200 COMPZ WELLPF MPSP P Make up BHA (7" Model "G" Lock -Set RBP w/ Model L Retrieving Head) on 3.5" Drill Pipe down to 2,750' DPMD. 12:30 13:30 1.00 1,200 1,200 COMPZ WELLPFSFTY T Had Safety Stand -down with Rig Crew and Drilling Support Crew. Discuss Near Miss that happened on location. 13:30 15:30 2.00 1,200 2,747 COMPZ WELLPF MPSP P Continue to TIH with RBP on Drill pipe. 15:30 15:45 0.25 2,747 2,747 COMPZ WELLPF MPSP P Set 7" RBP at 2747' DPMD. e 15:45 20:00 4.25 2,747 2,705 COMPZ WELLPF PRTS P Rig up Testing Equipment and Test RBP to 3,000 psi with 9.6 ppg brine. Perform drawdown test to zero psi. Dumping sand (25 sacks) down drill pipe on top of RBP. Wait for Sand to fall. Tag Top of Sand at 2,705 -ft dpmd. Good. 20:00 21:00 1.00 2,705 0 COMPZ WELLPF MPSP P Trip out with 3 1/2" Drill Pipe and Baker Running Tool. Lay down Running Tool. 21:00 21:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM to Nipple Down the BOP Stack. 21:15 23:00 1.75 0 0 COMPZ WHDBO NUND P Nipple Down BOP Stack and set back on Stump. 23:00 23:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM. Discuss the hazards and operations using the Hydratight Equipment. 23:15 00:00 0.75 0 0 COMPZ WHDBO RURD P Rig up Hydratight Equipment. 33/18/2011 Control Casing growth w /Hydratight Equip. ND Tbg Head. Pull Pack -Off. Spear Csg. Pull Casing in tension and re -set Casing Slips. NU BOP Stack and install 7" Pipe Rams. RIH with Baker MS Cutter and cut 7" Casing. Spear Casing and confirm Casing is free. Circulate out Arctic Pack. Page 5 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ WHDBO NUND P Finish rigging up. Control 7" Casing growth with the Hydratight Equipment. The initial 100 psi used on the first tool cycle indicated that the 7" Casing is not in much compression. Total cycles = 3 at 100 psi. Total Casing growth 1 3/8" inches. 01:30 02:00 0.50 0 0 COMPZ WHDBO RURD P Rig down Hydratight Equipment. 02:00 02:30 0.50 0 0 COMPZ WHDBO NUND P Pull 7" Pack -Off. 02:30 03:00 0.50 0 0 COMPZ WELLPF PULL P Pick -up 5 3/4" ITCO Casing Spear. Plant Spear. Pull 3" of remaining compression out of casing string. Pull an additional 3" to Re -set 7" Casing Slips and leave Casing with 20K tension pulled. Release Spear and lay down same. Total Compression Growth 4 3/8 ". (Note: Did not need to cut 7" Casing with the WACHS Cutter. Casing did not grow enough). 03:00 03:30 0.50 0 0 COMPZ WELLPF SFTY P Attempted to safe out Cellar to allow Welder to tack -weld Slips. LEL readings too high. Several reading were taken with the same results. Abort welding. 03:30 10:00 6.50 0 0 COMPZ WHDBO NUND P Nipple up BOP Stack with CMT flow cross. Install 7" Pipe Rams in lower Gate. Fill stack with 9.6 ppg Brine and Perform Hydrostatic test on BOP Break. ( Called AOGCC " Chuck" and discuss the operations at this stage of the Job.) BOP is now considered a Diverter. 10:00 10:15 0.25 0 0 COMPZ WELLPF OTHR P Confirm Lines to the Kill Tank and Open Top Tank are clear. 10:15 10:45 0.50 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Loading and Making up BHA. 10:45 12:00 1.25 0 282 COMPZ WELLPF PULD P M/U BHA #3. 5.5" Multi string cutter with 6" Stabilizer and 3.5" Pump out sub on (9) D /C. Inspected Cutter blades before TIH. 12:00 14:00 2.00 282 1,739 COMPZ WELLPF TRIP P TIH with String Cutter assembly on Drill Pipe. Stop at 1732' DPMD, check torque at 40 RPM, 500 psi and 1.3K free torque, Up Wt =65k down wt =65k. Continue in hole and located 7" Casing collar at 1761' DPMD while pumping at 60 spm rfj), w/330 psi, PUH 22' to 1739' nPMr) to make CSG cut. Start Making at 40 RPM, 2k Torque and 59 SPM, 520 psi, increase to 72 SPM, 660 psi, increase to 100 SPM, 670 psi, and final psi 580# at 110 SPM. Saw good indication of cut. Page 6 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T - Comment 14:00 15:45 1.75 1,739 1,730 COMPZ WELLPF CIRC P Start circulating Hot Seawater at 4 bpm, at 930 psi. Load 7" x 9 5/8" CSG and let hot seawater soak while TOOH. Observe well for gas and flow. Seeing a trace of gas by to kill tank. Circulate another 50 bbls of seawater down Drill pipe up 7" x 9 5/8" csg. Well looks good. 15:45 18:00 2.25 1,730 0 COMPZ WELLPF TRIP P PJSM. Blow down Top drive.TOOH standing back Drill pipe. Lay down Cutter Assembly. Recovered Knives complete. Observe expected normal wear pattern on Knives. 18:00 19:00 1.00 0 0 COMPZ WELLPF PULD P Pick -up 5 3/4" ITCO Casing Spear. Plant Spear in 7" Casing. Pick -up on 7" Casing. Casing free at 110K String Weight. 19:00 00:00 5.00 0 0 COMPZ WELLPF CIRC P PJSM. Note wind direction and stage Vac Trucks accordingly. Begin Arctic Pack recovery from the 9 5/8" x 7" Annulus. Pump 200 bbls of heated Diesel at 3.0 bpm /230 psi. Shut down and let "soak" for —30 minutes. Resume pumping the remaining 50 bbls of heated Diesel. Continue pumping 140 bbls of hot Sea Water at 4.0 bpm /200 psi. Let soak while Vac Truck suck out Open top Tank to make room for remaining returns. 03/19/2011 Finish Arctic Pack recovery. Split BOP Stack and pull 7" Csg Slips. Lay down 7" Casing. Set Test Plug and remove the 7" Pipe Rams. Install 2 7/8" x 5" VBPR. Also had to replace the Blind Rams due to failed pressure test. Tested Rams and body breaks at 250/3,000 psi. Pick up and run 9 5/8" Casing Scraper to the top of the 7" Stump . 00:00 02:30 2.50 0 0 COMPZ WELLPF CIRC P Finish flushing any remaining Arctic Pack from the 9 5/8" x 7" Annulus with Sea Water at 4.0 bpm /260 psi. Blow down Top Drive. 02:30 05:00 2.50 0 0 COMPZ WHDBO NUND P PJSM. Suck out BOP Stack. Split and lift Stack. Pull Casing to Rig Floor. Remove 7" Casing Slips. Set BOP Stack back down and make up Flange break. 05:00 11:00 6.00 1,739 0 COMPZ WELLPF PULL P PJSM. Discuss laying down Casing. Rig up Casing handling equipment. Lay down 7" 26/lb J -55 BTC Casing. Pulled a total of 39 Joint with one cut Joint ( 21.59 feet) for a total length of 1,713 Feet. Recovered 18 Centralizer from 7" Casing, and none lost. Joint 31 had a small bend on the Pin end, the rest where all in good shape. 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Kicking out CSG, and laying down CSG equipment and Installing test plug. Page7of27 . • 111. Time Logs Date From To Dur S. Depth, E. Depth Phase Code Subcode T Comment 11:15 12:00 0.75 0 0 COMPZ WELLPF PULD P Lay down CSG equipment. Kick out 7" Casing from Pipe shed. Load tools for next run. 12:00 14:00 2.00 0 0 COMPZ WHDBO MPSP P PJSM. Install Test Plug. Drain Stack. Remove 7" Rams and Instal VBR's. 14:00 16:30 2.50 0 0 COMPZ WHDBO BOPE P Pressure Test BOP Break and Ram, Body. 250/3000 psi VBPR and BOP body test, OK. However, the Blind Rams now leak. The State's right to witness the test was waived by C. Scheve. 16:30 21:00 4.50 0 0 COMPZ WHDBO BOPE T Change out Blind Rams and test at 250/3,000 psi. Good test. 21:00 21:30 0.50 0 0 COMPZ WELLPF PULD P Pick up BHA # 5, 9 5/8" Casing Scraper. 21:30 00:00 2.50 0 1,739 COMPZ WELLPF TRIP P Trip in with 9 5/8" Casing Scraper /Bull Nose on 3 1/2" Drill. Pipe. Stopped at 1,150 -ft due to pushing Arctic Pack ahead of the Casing Scraper and causing the Drill Pipe over -flow. Circulate out Arctic Pack at 4.0 bpm 110 psi. Lost 30 bbls during circulating. Continue in hole. At 1,380 -ft set down on an obstruction. Screw Top Drive in Drill Pipe and bring pump on at 1.0 bpm/ 60 psi. Continue in hole washing /pushing the obstruction ahead with 10 -15 K down weight and 60/250 psi pump pressure. Obstruction would fall away intermittently. At 1,679 -ft obstruction cleared up. However found obstruction again at 1,733 -ft just before expected top of 7" Casing stump at 1,739 -ft. Tagged Stump. 03/20/2011 Circ out remaining Arctic Pack. POOH with Csg Scraper. RU E -Line. Record Caliper Log and a Gyro Log. RD E -Line. RIH with Tandem String Mills to gauge the 9 5/8" Csg and a Tapered Mill to gauge inside the 7" Casing. Circulate Well with hot Sea Water to continue to clean -up Arctic Pack. POOH . 00:00 01:30 1.50 1,739 1,738 COMPZ WELLPF CIRC P Mix and pumped a 20 bbl Hi -Vis Sweep. Circulate Well and clean up remaining Arctic Pack at 4.0 bpm /200 psi. Recovered some more Arctic Pack. Also saw some small pebbles and gravel pieces in the returns. Lost only 2 bbls during this circulation. Blow down Top Drive. 01:30 03:00 1.50 1,738 0 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down Casing Scraper BHA. Empty Boot Baskets. Booth Boot Baskets were full of small pieces of gravel. 03:00 03:15 0.25 0 0 COMPZ EVALWE SFTY P PJSM. Discussed the hazzards with rigging up the E -Line equipment. Page 8 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 03:15 07:00 3.75 0 1,692 COMPZ EVALWE ELOG P Install shooting Nipple. Rig up Halliburton E -Line equipment. Make up PDS 40 -Arm Caliper and Memory Qamma Ray Tool. RIH. Log from the 7" Casing Stump at 1,692 -ft back to surface. Set down with logging tools at 1692' elmd. 07:00 11:00 4.00 0 1,692 COMPZ EVALWE ELOG P PJSM. Rig up Gyro Tools on E -Line and RIH to 1692' elmd and log to surface and down load data. 11:00 12:00 1.00 1,692 0 COMPZ EVALWE ELOG P OOH. PJSM. Rig down E -Line equipment and lower down beaver slid and Release E -line Crew and Unit. 12:00 12:15 0.25 0 0 COMPZ WELLPFSFTY P PJSM. Discuss Hazard of loading baker tools to rig floor and making up BHA. 12:15 13:30 1.25 0 0 COMPZ WELLPF PULD P Load Baker Tools to Rig Floor 13:30 14:30 1.00 0 714 COMPZ WELLPF RURD P Make Up Baker BHA. 6 1/8" x 3 1/2" Tapered Mill and a 8 1/2" Upper String Mill with Jars, Boot basket and magnet. 14:30 15:15 0.75 714 1,739 COMPZ WELLPF TRIP P TIH to top of 7" CSG Stub.Work 6 1/8" x 3 1/2" Tapered Mill down inside 7" to clean any fill or junk from around 7" CSG stub. 15:15 18:00 2.75 1,739 2,128 COMPZ WELLPF WASH P Up Wt = 65k Down Wt =65. Work 6 1/8" x 3 1/2" Tapered Mill down inside 7" to clean any fill or junk from around 7" CSG stub. Target Depth w/ Mill is 2128' ft inside 7" CSG Stub. Circulating pressure 200 to 240 psi @ 5 BPM. Had no problems passes through 9 5/8" Casing. Tagged small pebbles and gravel thru out the 7" CSG while rotating and cirulating down to target depth of 2128' ft. Lose 10 bbls while circulating out 7" casing. 18:00 18:30 0.50 2,128 2,128 COMPZ WELLPF CIRC P Pump a 20 bbl HI -Vis Sweep and chase back to surface with hot Sea Water at 10.0 bpm /880 psi. Lose another 10 bbls while circulating Sweep around. No more losses after while was circulated over to Seawater. 18:30 21:00 2.50 2,128 0 COMPZ WELLPF TRIP P Trip out standing back 3 1/2" Drill Pipe and 4 3/4" Drill Collars. Lay down the BHA. Empty Boot Baskets. Both Baskets were full of cement chunks and gravel. 21:00 00:00 3.00 0 0 COMPZ WELLPF PULD P Clear and clean Floor. Bring BHA #7 components to the Floor. Begin making up the Casing Back -Off BHA Assembly. Page 9 of 27 • Time Logs Date From To Dur S. Depth E. Depth : Phase Code Subcode T Comment 03/21/2011 24 hr Summary MU Csg Back -Off Tool. RIH and loosen Csg Collar at 1,761'. POOH. Perform weekly BOPE. MU Dummy Drift with ES- Cementer. RIH to top of Csg Stump. POOH. RIH with Spear and complete backing off the Csg Collar. POOH and lay recovered Csg Stub. test. 00:00 01:00 1.00 0 0 COMPZ WELLPF PULD P Finish Making up BHA #7, Casing Back -Off Tool. 01:00 02:30 1.50 0 1,761 COMPZ WELLPF TRIP P Trip in with BHA #7 and 3 1/2" Drill Pipe from the Derrick. Fill Drill Pipe every 5 Stands on the way in. Enter the top of the 7" Casing Stump at 1,739 -ft dpmd. Continue RIH. Position the Power Section of the Back -Off Tool to straddle the 7" Casing Collar at 1,761 -ft. 02:30 04:00 1.50 1,761 1,761 COMPZ WELLPF FISH P Pressure up to 350 psi. Slack off and set Lower Anchor. Bleed Pressure. Pull up and find neutral section. Pull Tension and pressure up to 800 psi and set Top Anchor. Mark Pipe and Rotary Table. Pressure up on Back -Off Tool. Observe initial Collar break at 620 psi. Initial torque required to break Collar loose = 3,720 ft/Ibs. Continue to cycle Back -Off Tool per Baker Fisherman. Total Cycles = 12. Total back -off turns at surface = 4.5. Open Pump- Out -Sub. 04:00 08:00 4.00 1,761 0 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe. Lay down BHA. Clear and clean Floor. 08:00 09:30 1.50 0 0 COMPZ WHDBO MPSP P PJSM. Pull Wear Ring. Set Test Plug and PT Plug. 250/3000 psi. 09:30 15:00 5.50 0 0 COMPZ WHDBO BOPE P Perform Weekly BOP test 250/3000 O psi. Test Waived By AOGCC. /. (Chuck & Matt) (t 15:00 15:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Making Up BHA for Dummy Drift Run. 15:15 17:30 2.25 0 350 COMPZ WELLPF PULD P Pick Up and Make Up Dummy Drift Run BHA. Triple Connect and 7" PUP Joint and 7" HES ES Cementer. 17:30 18:30 1.00 350 1,734 COMPZ WELLPF TRIP P Trip in with the Dummy Drift Run BHA on 3 1/2" Drill Pipe. Up Weight = 65K. Down Weight = 65K. Stop just above the 7" Casing Stump. Encountered no problems. 18:30 19:00 0.50 1,734 1,734 COMPZ WELLPFCIRC P Pump a 20 bbls Hi -Vis Sweep. Circulate back to surface with Sea Water at 8 bpm /110 psi. Recovered small slugs of Arctic Pack. 19:00 20:00 1.00 1,734 0 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down Jars and Bumper Sub. Stand back Dummy Drift assembly in Derrick. 20:00 20:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss hazards for the next BHA. Page 10 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 22:00 1.75 0 1,761 COMPZ WELLPF TRIP P Plck -up 5 3/4" ITCO Spear. RIH on 3 1/2" Drill Pipe. Up Weight = 65K. Down Weight = 65K. Plant Spear in the 7" Casing Stump at 1,739 -ft. Rotate to the left a total of 10 turns to complete back -out of the Casing Collar at 1,761 -ft. Initial torque = 1K. 22:00 22:30 0.50 1,761 1,761 COMPZ WELLPF CIRC P Pump a 20 bbls Hi -Vis Sweep and chase back to surface with Sea Water at 10.0 bpm/700 psi. Recovered more slugs of Arctic Pack. 22:30 00:00 1.50 1,761 0 COMPZ WELLPF TRIP P PJSM. Trip out with 3 1/2" Drill Pipe. Lay down Spear. Lay down recovered 7" Stub with pin end. Length = 22.00 -ft. (Note: 7" Collar looking up at 1,761 -ft). 03/22/2011 Install 7" PRs in lower BOP Gate.Test pipe rams and door seals. RU to run 7" Csg. Rijn 7" Csg as designed Tie Csg into original String at 1,761'. Pull test and pressure test. NU Cmt Head. RD Csg equipment. RU Cementers. Cmt Tie -Back Csg per Program. WOC. N/D BOPE & install CSG head 00:00 01:00 1.00 0 0 COMPZ RIGMNT SVRG P Clear and clean Floor. Service Top Drive and Blocks. Grease Draw works. Grease Pipe Skate and ready for picking -up Casing. 01:00 01:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM. Discuss hazards with installing Test Plug and changing BOP Rams. 01:15 05:00 3.75 0 0 COMPZ WHDBO BOPE P Pull Wear Bushing. Install Test Plug. Remove 2 7/8" VB Pipe Rams. Install 7" Pipe Rams. Test BOP body breaks and 7" Pipe Rams at 250/3,000 psi. Good test. The State's right to witness test was waived by C. Scheve. Pull Test Plug. 05:00 06:00 1.00 0 0 COMPZ WELLPF PULD P PJSM. Clear Rig Floor. Make Up 7" Casing Handling Equipment. Crew Change Out. 06:00 06:30 0.50 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Making Up and Running 7" Casing. Pinch Points, Safe Working Area, Line Of Fire, Proper Torque On Casing. 06:30 08:30 2.00 0 1,761 COMPZ WELLPF RNCS P Make up and RIH with Baker Triple- Connection w/ Short Skirt, PUP and Type 'H' Cementer on 7" 26 #, L -80, TCII Casing with a 1 Centralizer per- Joint. Running 10,000 ft-lbs of MU torque on each joint of 7" Casing. Note: Box Looking Up / Pin Looking Down. 08:30 08:45 0.25 1,761 1,761 COMPZ WELLPF RNCS P On Depth at 1,761' with 7" Casino, and ES Cementer. Up Wt =75k and Down Wt =75k. Screw into Casing Collar looking up with 7" Tie -Back String w/ 10,000 ft -Ibs. Pulled 50k over to 125K and set slips. Page 11 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode -T Comment 08:45 09:30 0.75 1,761 1,761 COMPZ WELLPF PRTS P Rig up Testing Equipment and PT CSG to 2000 psi, for 15 mins, then 2500 psi for 15 mins and Chart on the recorder. 09:30 11:00 1.50 1,761 1,761 COMPZ WELLPF RURD P RD GB &R Casing Equipment and Remove from Rig Floor. RU SLB Cementers Equipment. Make Sure Flow -Cross is rig up right for another path for cement if needed. 11:00 11:30 0.50 1,761 1,761 COMPZ WELLPF SFTY P PJSM. ASRC Truck Driver, Super Sucker Operator and Vac Truck Driver. PJSM with SLB Cementers. 11:30 12:00 0.50 1,761 1,761 COMPZ WELLPFCIRC P Line Up Rig Pump and Pressure Up to 3500 psi and Open up' ES' cementer. Cementer Open at 3330 psi. Continue circulating (— 90 deg F ) Seawater @ 4.5 bpm at 90 psi down 7" CSG up 9 5/8" Surface CSG. 12:00 13:00 1.00 1,761 1,761 COMPZ WELLPFCMNT P Completed Pumping Seawater. Line Up SLB Cementers. Pump 5 bbls of Fresh Water ahead at 3 bpm, 140 psi ( SLB Pump ) shut down and shut in treating iron and PTcement LI^ lines to 3000 psi. Batch up and start 7r 1 pumping15.7 lb/gal Arctic -Sett r Cement at 4 bpm, 260 psi on the SLB Pump, 60 psi on Wellhead. Pump a total of 78.5 bbl of 15.71b /gal Arctic -Set Cement, Shut down and Launch Closing Plug. Pump 1 more bbl on top of closing plug and a 5 bbl Fresh Water Spacer. 13:00 14:00 1.00 1,761 1,761 COMPZ WELLPF CMNT P Started chasing Cement and plug to' ES cementer. At 118.5 bbls Total Pumped, seen cement to surface, Lower rate to 1.3 to 1.5 bpm at 240 psi, pump addition 2 bbls at surface until good clean cement was seen. Closed OA valve and started squeezing cement into 9 5/8" casing leak. Continue pumping until Closing Plug bump at 142 bbls total Pumped at 2150 psi and held solid. ( 142 bbls - 118.5 = 23.5 bbls - 2 bbls at surface = 21.5 bbls Estimated Cement behind pipe. Final Circulating Psi 600#.) 14:00 14:45 0.75 1,761 1,761 COMPZ WELLPF CMNT P Rig Down SLB cement equip nt and released SLB crew. Rig down HES cement Head. 14:45 17:00 2.25 1,761 1,761 COMPZ WELLPF WOC P WOC 4 hours to Achieve 500 psi compressive strength. Clean Cellar and Rig Floor of un- needed equipment. Prep to ND BOPE. 17:00 17:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard and next task. Page 12 of 27 0 Time Logs Date From To Dur S. Depth E. -Depth Phase Code Subcode T , Comment 17:15 19:45 2.50 0 COMPZ WELLPF NUND P ND BOPE & cement cross CPmPnt Top was seen right below the OA- Port Outlet. (Picture in the folder) 19:45 21:00 1.25 COMPZ WHDBO NUND P Install slips, R/U Wachs cutter and cut 7" CSG. 21:00 22:30 1.50 COMPZ WELLPF NUND P Install new TBG head, install & test packoff to 3000 psi for 10 minutes, good. 22:30 00:00 1.50 COMPZ WHDBO NUND P N/U BOPE 03/23/2011 Con't to NU BOPE. Change 7" LPR's to 3 1/2 VBR's. Shell Test and Test LPR's w/ 3 1/2 Test jt to 250/3,000 psi. Pull test plug. Set wear ring. MU 6 1/8" Drilling assy, RIH to TOC at 1,663 -ft. Begin drlg f/ 1,663 -ft to 1,748 -ft, Drill up wiper plug f/ 1,748 -ft to 1,749 -ft. Chase to top of sand at 2,694 -ft. CBU . PT 7" to 3,000 psi for 15 minutes. POOH w/ drlg assy. PU 6 1/8" Concave mill and RIH to 2,694 -ft. Dry drill on junk. POOH and PU Reverse circ. Junk Basket - RIH to 2,694 -ft - Tool didn't show to function properly - POOH and inspect. 00:00 02:45 2.75 0 0 COMPZ WHDBO NUND P Continue N/U BOPE. Remove 7" Ram's and Install VBR's in lower set. 02:45 04:00 1.25 0 0 COMPZ WHDBO BOPE P Test BOPE Connection & new ramsp to 250/3000 psi. 04:00 06:00 2.00 0 0 COMPZ WELLPF PULD P BOPE test complete & test plug is pulled. Load Tools for Milling Assembly. Kick -Out Un -used 7" CSG and Un- needed equipment from rig floor. 06:00 06:15 0.25 0 0 COMPZ WELLPF SFTY P Crew Change Out. PJSM. 06:15 07:30 1.25 0 314 COMPZ WELLPF PULD P Make up Drilling Assembly. 6 1/8" Mill tooth bit, (2) 4 3/4" Boot Baskets, Bit Sub, 4 3/4" String Magnet, 4 3/4" LUB. Bumper Sub, 4 3/4" Oil Jars. 07:30 08:15 0.75 314 1,663 COMPZ WELLPFTRIP P PJSM. TIH w/ Drilling Assembly on Drill Pipe Down to Top Of Cement. 08:15 08:45 0.50 1,663 1,748 COMPZ WELLPFMILL P Tagged TOC at 1663' dpmd, P/U and Establish Parameters: 65k Up Wt, 62k Down Wt, 65K ROW, 4 bpm at 130 psi. Free Torque 1.5k, 2 to 5K WOB. Start Drilling Cement Down to Closing Plug @ 1748'ft. 08:45 10:30 1.75 1,748 1,759 COMPZ WELLPF MILL P Drilling on Closing Plug, Parameters:65K ROW, 4 bpm at 130 psi. 5 to 10K WOB. 10:30 12:00 1.50 1,759 2,694 COMPZ WELLPFMILL P Done Drilling Closing plug, Start chasing Remaining Junk down to top of sand. While pushing Junk to sand top, had to rotate 2 stands down. Sat Down at 2694.0 PUH to 2660' ft. 12:00 12:30 0.50 2,694 2,660 COMPZ WELLPFCIRC P Circulate 30 bbl High -Vis Sweep and CBU at 4 bpm, 200 psi. Had small amount of rubber pieces, brass shavings in sweep. 12:30 12:45 0.25 2,660 2,660 COMPZ WELLPF PRTS P Pressure test 7" CSG to 3000 psi, for 15 mins. 12:45 13:15 0.50 2,660 314 COMPZ WELLPFTRIP P PJSM. TOOH with 6 1/8" Mill tooth bit Drilling Assembly Page 13 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 13:15 14:45 1.50 314 0 COMPZ WELLPF PULD P Lay Down Drilling Assembly & Remove 6 1/8" Bit. Had about 1 gallon of rubber, metal shaving and cement inside boot basket. 14:45 15:30 0.75 0 315 COMPZ WELLPF PULD P PJSM. Make up Milling Assembly. 6 1/8" Concave Junk Mill, (2) 4 3/4" Boot Baskets, Bit Sub, 4 3/4" String Magnet, 4 3/4" LUB. Bumper Sub, 4 3/4" Oil Jars. 15:30 17:00 1.50 315 2,694 COMPZ WELLPF TRIP P TIH, with Milling Assembly down to top sand at 2,693ft and dry drill debris at 2,694 -ft. 73k up wt, 69k dn wt. 17:00 18:00 1.00 2,694 2,694 COMPZ WELLPF MILL P Dry drill on junk on top of sand, ROT wt 75k, Rotating at 60 rpm's w/ 2k torque. 18:00 20:00 2.00 2,694 0 COMPZ WELLPFTRIP P POOH w/ BHA # 11(6 1/8" OD Concave Mill assy), lay down and clean out boot baskets. 20:00 21:30 1.50 0 2,694 COMPZ WELLPFTRIP P MU and RIH w/ BHA #12 (5 3/4" Reverse Circ. Junk Basket assy) to 2,694 -ft. 80k up wt, 69k dn wt. 21:30 22:00 0.50 2,694 2,694 COMPZ WELLPF CIRC P Circulate 1 DP volume (20 bbls) at 5 bpm at 380 psi. Drop .875" Ball and circulate at 5 bpm at 500 psi, never saw ball seat. Attempt to function RCJB on top of sand - not able to flush sand from below tool. 22:00 22:30 0.50 2,694 1,678 COMPZ WELLPFTRIP T POOH from 2,964 -ft to 1,678 -ft. Pump 10 bbl hi visc sweep (Thinking ball setting in void in BHA - Jars, LBS, etc.) Circulating at 5 bpm at 440 psi. 22:30 23:30 1.00 1,678 0 COMPZ WELLPFTRIP T POOH from 1,678 -ft. to RCJB and inspect ball and jets from topside. 23:30 00:00 0.50 0 325 COMPZ WELLPFTRIP T RIH to 325 -ft. with ball on seat. 03/24/2011 Made 2 runs w/ RCJB to 2,698 -ft. Unable to make hole. RIH w/ 6 1/8" Concave mill and dry mill on junk on top of sand plug to 2,701 -ft. Made 2 runs with RCJB till hole was clean to 2,750 -ft. (Body of RBP). RIH w/ RBP retrieval head and Change well over from sea water to 9.6 ppg Brine at 2,745 -ft. 00:00 02:30 2.50 325 2,694 COMPZ WELLPFTRIP T Continue to RIH from 325 -ft to 518 -ft. Test RCJB at 6 bpm at 500 psi. POOH and break down jetting system and inspect. Found ball on seat. Center jet is a 16/64" and the 3 outside jets vary from 12/64" to 14/64 ". MU and set in hole. Function test - found to be jetting fine while circulating at 5 bpm at 300 psi. RIH to 2,694 -ft. 80k up wt, 69k dn wt. 02:30 03:00 0.50 2,694 2,704 COMPZ WELLPF CIRC P Circulate down at 8 bpm at 1,250 psi, Rotating 25 rpm at 2k free torque - seen 3k on bottom torque, clean out 2,704 -ft. Page 14 of 27 Time Logs Date r From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 03:00 04:00 1.00 2,704 0 COMPZ WELLPF TRIP P POOH and inspect boot baskets and RCJB - recovered 1 gal of sand and misc pieces of aluminum. 04:00 06:00 2.00 0 2,698 COMPZ WELLPF TRIP P MU and RIH w/ same BHA to 2,698 -ft. 80k up wt 69k dn wt. 06:00 06:30 0.50 2,698 2,700 COMPZ WELLPF CIRC P Tag up at 2,698 -ft. Circulate down at 8 bpm at 1,250 psi, Rotating 25 rpm at 2k free torque - seen 6k max torque, increase rpm to 60 rpm and increase pump rate to 9 bpm at 1,430 psi - clean out 2,700 -ft. Pulling 25 to 50k osw of 80k before pulling free. Made decision to POOH and PU 6 1/8" Concave mill again and dry mill on junk - possibly knocked sleeve remanent from ES Cementer. 06:30 07:30 1.00 2,700 0 COMPZ WELLPF TRIP P PJSM. B/D Top Drive, POOH f/2,700 ft. 07:30 08:00 0.50 0 315 COMPZ WELLPF PULD P Lay Down BHA, clean magnet and boot baskets, and junk basket. Both where empty. M/U BHA. 6 1/8" OD Concave Junk Mill, 4 3/4" Boot Basket x2, 4 3/4" String magnet w/ jars, Drill Collars on Drill Pipe. 08:00 09:00 1.00 315 2,698 COMPZ WELLPF TRIP T TIH to TOS and set down at 2698 ft, Up Wt =80k down Wt =69k. 09:00 10:00 1.00 2,698 2,701 COMPZ WELLPF MILL T Est Parameter, ROT wt 75k at 60 RPM, 2k Torque, dry drill on objects down to 2701 ft. 10:00 10:15 0.25 2,701 2,610 COMPZ WELLPF CIRC T POOH to 2610 ft and Circulate to Make sure BHA is clear. Blow down Top drive. 10:15 10:30 0.25 2,610 2,610 COMPZ WELLPF SFTY T PJSM. Discuss Hazard for POOH. 10:30 12:00 1.50 2,610 315 COMPZ WELLPF TRIP T POOH From 2610 ft. Magnets and Boot Baskets Where Clean. 12:00 12:15 0.25 315 0 COMPZ WELLPF PULD T PJSM. Lay down Milling Assembly. 12:15 12:30 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of Making Up RCJB Assembly. 12:30 13:15 0.75 0 325 COMPZ WELLPF PULD P MU and RIH w/ BHA. (5 3/4" Reverse Circ. Junk Basket assy) to 2,701 -ft. 80k up wt, 69k dn wt. Change out Jets on the RCJB. 13:15 14:30 1.25 325 2,698 COMPZ WELLPF TRIP P TIH with RCJB clean Assembly. 14:30 15:45 1.25 2,698 2,741 COMPZ WELLPF CIRC P Set down at Sand top at 2698 - ft, Set parameter, Up Wt =80k, Down Wt =69, ROT Wt 75k. Start Circulating down @ 10 bpm, 1800 psi, staying 10 feet from RBP. Pump 25 bbl High -Vis Sweep 9 bpm at 1,840 psi. and CBU. 15:45 18:00 2.25 2,741 0 COMPZ WELLPF TRIP P PJSM. Blow down Top Drive. POOH with RCJB Assembly. Clean out Boot basket and RCJB recover large piece of billet from ES Cementer Page 15 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 0 2,746 COMPZ WELLPF TRIP P PU and MU BHA #16 (RCJB assy) and RIH to 2,746 -ft. 80k up wt, 69k dn wt. 20:00 20:30 0.50 2,746 2,750 COMPZ WELLPF CIRC P Circulate down at 8 bpm at 1,450 psi, Rotating at 5 rpms with 2k free torque to 2,750 -ft with 3k max torque increase. 20:30 22:00 1.50 2,750 0 COMPZ WELLPFTRIP P Blow down Top drive and POOH from 2,750 -ft. Break down BHA #16 and recovered small pieces in boot basket and RCJB was empty. 22:00 23:30 1.50 0 2,745 COMPZ WELLPF TRIP P MU "G" Plug retrieval tool assy and RIH on 3 1/2 DP to 2,745 -ft. 73k up wt, 65k dn wt. 23:30 00:00 0.50 2,745 2,745 COMPZ WELLPF CIRC P Pump 30 bbls hi visc sweep and displace well from above RBP from sea water to 9.6 ppg KWF at 8 bpm at 640 psi. 03/25/2011 Enaaae and release RBP. POOH, MU and RIH w/ 5 3/4 Overshot assv to 7.389=ft Slip & out drilling line. Engage fish and Begin working Seal assy stung into PBR. Jar lightly, gain movement, Upper FHL released - loosing fluid. Secure well, slip and cut 320 -ft of drill line. 00:00 00:30 0.50 2,745 2,749 COMPZ WELLPF MPSP P Circulate down at 1 bpm at 70 psi, engage nad release RBP at 2,749 -ft. Allow elements to relax. and monitor well. 00:30 02:30 2.00 2,749 0 COMPZ WELLPFTRIP P POOh with RBP from 2,749 -ft. and lay down same. 02:30 04:00 1.50 0 0 COMPZ WELLPF OTHR P Remove all un- needed BHA equipment from rig floor and Bring up BHA #17 (5 3/4" Overshot run equipment) Wash out BOP stack with swizzle stick and magnet. 04:00 04:30 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with Baker fishing hand and rig crew on assembly of BHA #17 04:30 05:15 0.75 0 318 COMPZ WELLPF PULD P PU and MU BHA #17 (5 3/4" Overshot assy) and RIH to 318 -ft. 05:15 06:45 1.50 318 7,370 COMPZ WELLPF TRIP P RIH with BHA #17 from 318 -ft to 7,370-ft 06:45 07:00 0.25 7,370 7,370 COMPZ RIGMNT SFTY P PJSM. Discuss hazard Of Slipping and Cutting Drilling Line. 07:00 09:15 2.25 7,370 7,370 COMPZ RIGMNT SLPC P Routine Slip & Cut Drilling Line. 09:15 10:45 1.50 7,370 7,370 COMPZ WELLPF CIRC P Reverse Circulate 20 bbl High -Vis sweep Around at 6 bpm, 1000 psi, Follow By 9.6 ppg Brine to surface. Page 16 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 14:00 3.25 7,370 7,388 COMPZ WELLPF FISH P Done Pumping Sweep. RIH and Set Down at 7382.0, POOH and set Parameters. Up Wt =140k, Down Wt =90, ROT Wt =115k at 60 RPM, 5k Torque, 3 bpm at 260 psi. Rotate several times over stub. Stop rotating and Engage 3.5" Stub with grapple at 7388 ft. POOH to 175k and let jars fire, and straight pull to 180k, Continue to jar until 3.5" TBG is free. 14:00 14:15 0.25 7,388 7,378 COMPZ WELLPF FISH P Able to move 3.5" TBG up hole 10 feet after Jarring on stub 75 times at 175k. Let Jar's cool off for 15 mins. 14:15 18:00 3.75 7,378 7,378 COMPZ WELLPF FISH P Return back to Jarring on Stub. 18:00 20:30 2.50 7,378 7,350 COMPZ WELLPF FISH P Continue to work packer assy from 7,389 -ft to 7,317 -ft. Hanging up at various depths - seems to be the selective string on the hook. Hole began taking fluid - 60 bbl /hr losses. Appears that the packer has released. Find broken strand on drilling line. Set Slips with overshot at 7,350 -ft. 20:30 21:00 0.50 7,350 7,350 COMPZ RIGMNT SLPC T Held PJSM on slip and cut. 21:00 00:00 3.00 7,350 7,350 COMPZ RIGMNT SLPC T Slip and cut 336 -ft of 1 1/8" Drill line. Monitoring well on trip tank - losses continue at 60 bbl /hr. 03/26/2011 POOH to 7,090 -ft Secure well. Build surface fluid volume, waiting on fluid to come from Dead horse - Rig move in process at Kuparuk river. Continue to keep hole full with adequate surface volume. Condition KWF from 9.6 ppg to 9.2 ppg. Con't to have hi fluid losses. Drop KWF from 9.2 ppg to 9.0 ppg. POOH f/ 7,090 -ft to 6,995 -ft. Swabbing - Call out Slick line to pull ball and rod. 2 bbl /hr losses. POOH f/ 6,995 -ft to 6,897 -ft - still swabbing. 00:00 01:00 1.00 7,350 7,090 COMPZ WELLPF TRIP P POOH with fish from 7,350 -ft to 7,090 -ft. 160k up wt. Secure well. 01:00 06:30 5.50 7,090 7,090 COMPZ WELLPFCOND T Build surface volume of 9.6 ppg KWF while monitoring well on trip tank. Waiting for 600 bbls of 9.6 ppg NaCI to arrive from Dead horse. 06:30 09:00 2.50 7,090 7,090 COMPZ WELLPF COND T One load ( 290 bbls) of 9.6 ppg KWF on Location. Condition KWF to 9.2 ppg. 09:00 12:00 3.00 7,090 7,090 COMPZ WELLPFCIRC T Start Circulating 9.2 ppg KWF around to load well, at 2.0 bpm, 310 psi. Very Little return back to pits, losses 80 %, Tried to load Annular, no luck. Drop ball & rod, circulate a 4 bpm, 980 psi, continue to ciruclate until 9.2 ppg KWF at surface. . 12:00 13:00 1.00 7,090 7,090 COMPZ WELLPF OWFF T Monitor well. Losses at 50 %. 13:00 14:00 1.00 7,090 7,090 COMPZ WELLPFCOND T Condition KWF in Pits.Lowerto 9.0 Dog from 9.2 Dog. 14:00 15:00 1.00 7,090 7,090 COMPZ WELLPF CIRC T Circulate 9.0 ppg down drill pipe up 7" annular to surface at 6 bpm, 960 psi. Page 17 of 27 1 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:00 15:30 0.50 7,090 7,090 COMPZ WELLPF OWFF T Monitor well. 30 min Losses at 44% . 15:30 16:30 1.00 7,090 7,090 COMPZ WELLPF TRIP P Start POOH, standing back Drill Pipe. 16:30 17:30 1.00 7,090 6,995 COMPZ WELLPF OTHR T Unable to Continue to POOH, due to swabbing condition. Call Out S -Line to pull ball & rod from circulating sub. RU for slick line to tie into drill string. 17:30 18:00 0.50 6,995 6,995 COMPZ WELLPF SLKL T Standby for Slickline to arrive to pull ball and rod from circ sub in fishing BHA to allow KWF to pass thru fish - prod. packer elements are swabbing in the well. Slick line on location - spot equipment. 18:00 18:30 0.50 6,995 6,995 COMPZ WELLPF SFTY T Held PJSM with HES Slick line crew on RU of equipment and operational hazards. 18:30 22:30 4.00 6,995 7,000 COMPZ WELLPF SLKL T RU Slick line and MU 2.5" slip socket w/ 3/4" slips. RIH as of 21:00 hrs to 6,678 -ft. to retrieve ball and rod. RD Slick line. 22:30 23:00 0.50 6,995 6,995 COMPZ WELLPF OWFF T Monitor well. 2 bbl /hr losses. 23:00 00:00 1.00 6,995 6,995 COMPZ WELLPF TRIP T Held PJSM, POOH from 6,995 -ft. to 6,897 -ft. Swabbed back 3.5 bbls, Attempt to bullhead fluid past TBG plug - pressured up TBG x IA to 300 psi in 6 strokes. Dump TBG in attempt to surge debris off TBG plug - No luck. RIH f/ 6,897 -ft to 6,995 -ft. Atempt to surge again - no luck. 03/27/2011 Spot 50 bbls 9.8 ppg brine through circ holes. Run back to 7,389 -ft. RU Slick line bail off TBG plug - Discuss options with Town Eng. - Continue bailing fill. RD slickline. RU E -Line. 00:00 01:30 1.50 6,995 6,995 COMPZ WELLPF OTHR T Continue to reciprocate pipe from 6,995 -ft to 6,897 -ft in attempt to wash off packing elements. Spot 50 bbls 9.8 ppg NaCI thru circ holes at 6,678 -ft. 01:30 02:00 0.50 6,995 6,995 COMPZ WELLPF OWFF T Monitor well for fluid loss - Zero losses. 02:00 03:00 1.00 6,995 7,378 COMPZ WELLPF TRIP T RIH w/ Fish from 6,995 -ft 170k up wt, 95k do wt . Seen 15k slack off wt at 7,317 -ft and continue to RIH to 7,389 -ft, Seen 10k overpull at 3 -ft off bottom. PU and set in slips at 7,378-ft. 03:00 04:00 1.00 7,378 7,378 COMPZ WELLPF OTHR T Dispatch Slick -line. 04:00 04:45 0.75 7,378 7,378 COMPZ WELLPF SLKL T Slick -line on location. Crew check at rig camp & rig Floor. PJSM with Rig Crew. 04:45 06:15 1.50 7,378 7,378 COMPZ WELLPF SLKL T MIRU SLU. Load Lubricator to Rig Floor. Make Up .108 wire, 15' of 1.25 stem, OJ, HJ, and LSS. 06:15 07:30 1.25 7,378 7,378 COMPZ WELLPF SLKL T Slick -Line RIH w/ 5' of 1.5 Drive Down Bailer. Sat down at 7425' SLM. Worked Down to 7429' SLM. POOH w/ tools ( Bailer Full Of Returns) Page 18 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 7,378 7,378 COMPZ WELLPF SLKL T M/U and RIH with 10' of 1.5 Drive Down Bailer. Sat down at 7429' SLM. Worked Bailer ( DID NOT MAKE ANY HOLE) POOH with Tools. Bailer Half Full Of Returns. 09:00 10:15 1.25 7,378 7,378 COMPZ WELLPF SLKL T RIH with Same Tool Assembly. Sat Down @ 7429' SLM, Worked Bailer Not Making any Hole ). Pressure up TBG to 510 psi, Continue to work Bailer w/ same Result. Bleed down TBG and POOH. Bailer Packed Off w/ Fill. 10:15 11:30 1.25 7,378 7,378 COMPZ WELLPF SLKL T MU and RIH w/ 3' STEM and 2.0 gauge, tagged Pump Out Sub at 7072' SLMD -9' = 7063' RKB. POOH w/ Tools ( Fill is at Top of PBR ) 11:30 12:45 1.25 7,378 7,378 COMPZ WELLPF SLKL T Switch Over to 13' Of 1.5 Stem, KJ and LSS. RIH w/ 10' x 1.75 Pump Bailer. Sat Down at 7429' SLM. Worked Bailer, and POOH w/ Tools. Bailer half Full of Returns. 12:45 13:45 1.00 7,378 7,378 COMPZ WELLPF SLKL T MU and RIH w/ Same tool assembly. Sat down at 7429' SLM, Worked Bailer and POOH w/ Tools. ( Bailer Empty ) 13:45 15:00 1.25 7,378 7,378 COMPZ WELLPF SLKL T RIH w/ 1.70 CENT, 3' stem, AND 1" pOKER pRONG. sAT DOWN @ 7429' slm. bEAT DOWN w/ no movement and never pulled a bind. POOH w/ Tools ( Chisel Tip of Prong is Flat as If Hitting Metal ) 15:00 16:15 1.25 7,378 7,378 COMPZ WELLPF SLKL T Add 5' of Stem and RIH w/ KJ, 2" Bruch, and 1 3/4 Sample Bailer. Sat down @ 7429' SLM and Unable To Get by. POOH w/ Tools. 16:15 17:30 1.25 7,378 COMPZ WELLPF SLKL T RIH w/ KJ, Bow spring cent, and 1.69 Swage. Sat down at 7429' SLM at 7429' SLM and Unable to get by. Further review of tally in Rig Reps office indicate at top of Catcher Sub. 17:30 20:00 2.50 COMPZ WELLPF SLKL T RDMO, Slick -Line. 20:00 00:00 4.00 COMPZ WELLPF ELOG T PJSM. MIRU E -Line and Spot Equipment. Rehead E -Line. RU Tool and RIH w/ CCL Logging Tools. 03/28/2011 Correlated w/ ccl and RIH w/ RHP - punch hole at 7,429 -ft. E -Line stuck. Pull out of rope socket. POOH. RDMO E -Line. POOH w/ Selective assy to 2,962 -ft. Extension for weekly BOP test requested at 0800 on 3/28/11. Written approval from Guy Schwartz at 1642 on 3/28/11. Page 19 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:30 6.50 COMPZ WELLPF ELNE T Continue to POOH w/ CCL. Add Radial TBG punch and RIH to 7,409 -ft. Correlate and Punch hole at 7,429 -ft. POOH to 7,375 -ft. and hung up. Had to pressure up and un stick tools. Continue to make multiple attempts to POOH - Stuck tool string multiple times - Pull out of rope socket. POOH w/ E line - signs shows to be at rope socket. RD E line equipment. 06:30 07:00 0.50 7,718 7,718 COMPZ WELLPF SFTY P Held PJSM with rig crew on circulating and monitoring the well 07:00 07:30 0.50 7,718 7,718 COMPZ WELLPF CIRC P Establish circulation w/25 bbls pumped at 4 bpm at 440 psi. Monitor well on trip tank for 30 minutes. Losses at 60 + BPH. 07:30 10:30 3.00 7,718 7,622 COMPZ WELCTL OWFF T PJSM. POOH with 1 Stand from 7380 RKB, Monitor well, Well starting to FLow. Shut UPR's and Close Choke, showing 90 psi on choke. Circulate Thru gas buster at 2 bpm, 120 psi unitl 9.0 ppg brine is seen at surface. 10:30 11:00 0.50 7,622 7,622 COMPZ WELCTL COND T Condition Fluid in pit from 9.0 ppg to 8.7 ppg. 11:00 12:00 1.00 7,622 7,622 COMPZ WELCTL CIRC T Circulate 8.7 ppg brine around at 4 bpm. ICP 490 psi, FCP= 300 psi. 12:00 12:30 0.50 7,622 7,622 COMPZ WELCTL OWFF T Monitor well. Lose 23.6 bbls for 30 mins or .78 BPM. 12:30 13:00 0.50 7,622 7,622 COMPZ WELCTL OWFF T Lose 46 bbl for 1 hour or .76 BPM. Load Storm Packer to Rig Floor. 13:00 13:15 0.25 7,622 7,622 COMPZ WELLPF SFTY P Hold PJSM. Discuss hazard of MU Storm Packer and Well Condition. 13:15 14:30 1.25 7,622 7,622 COMPZ WELLPF OWFF T Remove Hoses from TIW Valve. Open Well and Monitor well. Well Still U- Tubing. 14:30 15:15 0.75 7,622 7,662 COMPZ WELLPF PLUG T MU and RIH with 7" 26# Storm Packer, Set Below Casing Head _ 15:15 15:45 0.50 7,662 7,662 COMPZ WHDBO BOPE T Rig Up Testing Equipment and Test UPR's, TIW and Choke Manifold Valve 5,6 and 2. 250/3000 PSI for 5 mins Each. 15:45 16:15 0.50 7,662 7,662 COMPZ WELLPF PLUG T Rig Down Testing Equipment. Pull and Lay Down 7" Storm Packer. 16:15 16:30 0.25 7,662 7,662 COMPZ WELLPF SFTY P PJSM. Discuss Hazard of TOOH with Drill Pipe and 3 1/2" Completion, and well Control Issue. 16:30 00:00 7.50 7,662 2,962 COMPZ WELLPF TRIP P POOH from 7,662 -ft w/ 3 1/2 Drill Pipe and 3 1/2 8rd Selective Completion to 2,962 -ft. 75k up wt, 65k do wt. Displaced hole w/ 346 bbls for 60 stands pulled. 03/29/2011 Continue to POOH w/ Selective assy. MU and RIH w/ 6 1/8" Bit assy. Set Storm Packer. Conduct weekly BOP Test. Page 20 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 2,962 644 COMPZ WELLPF TRIP P POOH from 2,650 -ft w/ 3 1/2 Drill Pipe to BHA and Fish (3 1/2 Selective) 01:30 04:00 2.50 644 144 COMPZ WELLPF PULL P POOH with Fishing BHA and lay down 180 -ft of 3 1/2 8rd Selective Completion to Blast Joints. 04:00 08:00 4.00 144 53 COMPZ WELLPF PULL P Break Down 91 -ft of 3 1/2 8rd x 3 1/2 FL4S Tubing w/ Carbide rings from 144 -ft to 53 -ft. All carbide rings recovered. Had to break a few at surface ( <10) to remove them from the tubing. 08:00 08:30 0.50 53 0 COMPZ WELLPF PULD P Continue OOH laying down 1 - Brown Steel Blastjt, 1- Camco MMG -II GLM, 1 -pup joint and locator seal assembly. 08:30 09:30 1.00 0 0 COMPZ WELLPF RURD P Clear and clean Floor. Un -load Plpe Shed. Rig up to handle 3 1/2" Drill Pipe. 09:30 13:00 3.50 0 7,062 COMPZ WELLPF TRIP T Make -up a 6 1/8" Cone Bit. Trip in with 3 1/2" Drill Pipe from the Derrick to 7,062 -ft. Up Weight = 140K. Down Weight = 93K. 13:00 13:30 0.50 7,062 7,112 COMPZ WELLPF PACK P Pick -up Baker 7" Storm Packer and set 50 -ft. 13:30 14:30 1.00 7,112 7,112 COMPZ WHDBO MPSP P Pull Wear Bushing. Install Test Plug. Ready test equipment. 14:30 00:00 9.50 7,112 7,112 COMPZ WHDBO BOPE P Perform weekly BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. Test Annular at 250/3,000 psi. Test Gas Alarms. Perform Koomey draw down test. Record all pressure test on iC chart. The test was witnessed by J. Crisp. 03/30/2011 Finish weekly BOP Test. Bleed gas. Bullhead kill Well. Clean out down to hard tag at 7630'. Swap well to 9.2 ppc NaCI brine. TOOH. 00:00 02:00 2.00 7,112 7,112 COMPZ WHDBO BOPE P Finish BOPE testing. 02:00 02:30 0.50 7,112 7,112 COMPZ WHDBO RURD P RD test eqpt. Pull test plug and set wear bushing. 02:30 03:00 0.50 7,112 7,112 COMPZ WELLPF SFTY P PJSM for release /retrieval of storm pkr. TIH to release storm pkr. 03:00 03:30 0.50 7,112 7,112 COMPZ WELCTI KLWL T Stab into storm pkr. Close bag and PU to release storm pkr. 570 psi on IA. Line up to vent gas to Tiger tank. Lines frozen to open top and Tiger tanks. Divert to bleed gas slowly through Po -Boy degasser. 03:30 04:30 1.00 7,112 7,112 COMPZ WELCTI KLWL T MU top drive to start seawater down DP while continue venting gas from IA (300 psi). Can't pump down DP. Relief valve not sheared. Troubleshoot while continue to bleed IA to 0 psi. Page 21 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 04:45 0.25 7,112 7,112 COMPZ WELCTL KLWL T Utilize top drive to shear pins and gain circulation down DP. Begin displacement of DP ( — 52 bbls) with seawater. IA is 210 psi when re- released storm pkr. 04:45 05:00 0.25 7,112 7,112 COMPZ WELCTL KLWL T Poor Boy degasser burped while bleeding IA and pumping down DP. Notified KRU Security and DSO in order to assess volume. 05:00 07:30 2.50 7,112 7,112 COMPZ WELCTL KLWL T Thaw lines to Tiger and open top tanks. Prep to bullhead Well with Sea Water. 07:30 09:30 2.00 7,112 7,112 COMPZ WELCTL KLWL T PJSM. IA = 390 psi. Bleed gas. IA down to 160 psi. Bring pump on line at 7 bpm @ 450 psi ICP. Bullhead 300 bbls down IA. FCP = 1100 psi at 7 bpm. 09:30 10:30 1.00 7,112 7,112 COMPZ WELLPF KLWL P PJSM release storm pkr. Observe 130 psi on DP. Circulate DP volume of seawater (8.7 ppg) down DP to clear gas (4 bpm @ 500 psi) 10:30 11:00 0.50 7,112 7,062 COMPZ WELLPF MPSP P LD storm pkr. 11:00 12:00 1.00 7,062 7,630 COMPZ WELLPF FCO T TIH w/ DP from 7062 - 7254' MD. Wash from 7254 - 7630' MD. Tag up. Up wt 140K, SO 95'. Circulate at 4 bpm @ 450 psi. 12:00 13:30 1.50 7,630 7,630 COMPZ WELLPF CIRC T Circulate crude and gas back to Tiger tank at 6 bpm @ 750 psi. 13:30 14:00 0.50 7,630 7,630 COMPZ WELLPF FCO T Attempt to work past 7630' MD. No progress. Continue to get oil and gas in returns. Well is not stable w/ seawater (8.7 ppq). 14:00 15:00 1.00 7,630 7,630 COMPZ WELLPF CIRC T Circulate BU at 4 bpm @ 450 psi. Monitor well. 12 bbl /hr losses. 15:00 20:00 5.00 7,630 7,542 COMPZ WELCTL KLWL T TOOH from 7630' to 7542'. Continue monitor well. Weight up fluid to 9.2 ppg. AOGCC waived right to witness test of annular and valves (2, 5, and 6) - John Crisp. 20:00 22:00 2.00 7,542 7,542 COMPZ WELCTL KLWL T Close annular. Pump 9.2 ppg brine down DP at 2 bpm @ 240 ICP taking returns to Tiger tank from IA. 294 bbls pumped w/ 224 bbls in Tiger tank. FCP at 3 bpm = 260 psi. 22:00 22:30 0.50 7,542 7,542 COMPZ WELCTL OWFF T Blow down TD. Monitor well. Well taking 11.1 bbls /10 min (66.6 bph) static losses. 22:30 00:00 1.50 7,542 5,512 COMPZ WELLPF TRIP T TOOH f/ 7542' MD w/ 3 -1/2" DP. 5512' at midnight w/ 105K up wt and 78K SO. 03/31/2011 TOOH w/6 1/8" Bit. Test Annular and Valves 2, 5, and 6. RIH with a 3 1/2" x 10' MS Pup Jt and a 6 1/16" String Mill. Worked through the tight spot at 7,630'. Continue RIH and "NO -GO" the Mule Shoe in the XO at 7,714' dpmd. Circulate Well Clean TOOH. MU and begin TIH w/ Lower Completion on 3 -1/2" Drill Plpe. 00:00 03:30 3.50 5,512 0 COMPZ WELLPF TRIP T Continue TOOH w/ 6 -1/8" bit. Page 22 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:45 1.25 0 0 COMPZ WHDBO MPSP T OOH. Losses steady while TOOH @ 66.6 bph. 6 -1/8" bit intact with no indicating marks. PJSM to pull wear ring and set test plug. Perform same and RU test eqpt to test Annular and choke valves 2,5, and 6 as per AOGCC. 04:45 05:15 0.50 0 0 COMPZ WHDBO BOPE T Test Annular and choke valves 2,5, and 6. Good tests. Record on Chart. 05:15 05:45 0.50 0 0 COMPZ WHDBO MPSP T RD test eqpt. Unseat test plug. Monitor well. Pull test plug and insert wear ring. 05:45 10:30 4.75 0 7,714 COMPZ WELLPF TRIP T PJSM. Make up BHA #19, 3 1/2" x 10 -ft Mule Shoe Pup Joint and a 6 1/16" String Mill. Trip in with 3 1/2" Drill Pipe to 7,630 -ft. Tagged up at the same spot that the 6 1/8" Bit tagged up at. Up Weight = 150K. Down Weight = 95K. Bring Pump on line at 4.0 bpm /500 psi. RPMs = 25. RTW = 115K. Free Torque = 5K. Wash and rotate through tight spot in —5 minutes. Continue down and encountered a few other minor "bobbles ". No -Go with the end of the Mule Shoe tagging the 5" x 3 1/2" XO at 7,714 -ft dpmd. 10:30 12:00 1.50 7,712 7,712 COMPZ WELLPF CIRC T Mix and pump a 35 bbl HI -Vis Sweep. Chase back to surface with 9.0 Brine at 6.0 bpm /1,000 psi. Returns clean. Loss rate during circulation at 1 bpm. Blow down Top Drive. 12:00 16:30 4.50 7,712 0 COMPZ WELLPF TRIP T PJSM. Trip out standing back 3 1/2" Drill Pipe in Derrick. 16:30 18:30 2.00 0 0 COMPZ WELLPF PULD T Lay down 4 3/4" Drill Collars. Off load Drill Collars and Baker Fishing Tools. Ready floor to run lower completion. 18:30 21:15 2.75 0 352 COMPZ RPCOM PULD P MU and RIH lower completion - GBH-22 locator, sliding sleeve w/ RHC body, 3 -1/2" Blastjt, 3 -1/2" 9.3 #/ft L -80 IBT -Mod w/ blast rings, 3 -1/2" x 1 -1/2" Camco MMG GLM, Baker FHL, and PBR w/ X -overs and spacer pipe. 21:15 00:00 2.75 352 3,067 COMPZ RPCOM RCST P Top of lower completion at rotary table. PJSM. TIH w/ lower completion on 3 -1/2" DP. 3067' MD at midnight w/ 75K up wt and 65K SO. 1054 bbls loss to formation on 31 Mar. 04/01/2011 RIH w/ lower completion. Locate seal bore. Pump corrosion inhibited brine. Spaceout. Set packer. Pkr /Csg test failed. POOH. PU and RIH w/ Baker Retrievamatic Pkr to 7,345. Set pkr and test IA and below. Start TOOH. Stop TOOH to circulate 9.6 ppg NaCI brine to kill well. Page 23 of 27 s • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:45 2.75 3,067 7,527 COMPZ RPCOM RCST P Cont TIH w/ Lower Completion Section on 3 1/2" Drill Pipe from the Derrick. 02:45 03:15 0.50 7,527 7,708 COMPZ RPCOM RCST P 145K up wt and 93K SO w/ two stands left. 03:15 03:45 0.50 7,708 7,713 COMPZ RPCOM RCST P Locate top of seal assembly at 7707.7' MD and btm at 7713.4' MD 03:45 04:30 0.75 7,713 7,705 COMPZ RPCOM RCST P PU 2' out of seal assembly & circulate in — 25 bbls CI 9.0 ppg NaCI brine 04:30 05:30 1.00 7,705 7,713 COMPZ RPCOM RCST P Finish displacement (30 bbls actual) of CI 9.0 ppg NaCI brine. Break out jt to drop ball & rod. SO to btm out in seal assembly. PU to string wt + 6 ". Wait — 10 mins for ball & rod to l fall. Pressure up to 2500 psi on DP to set Baker FHL pkr. Positive indication of pkr set on surface. Bleed pressure off DP. Close pipe rams and line up to test and chart PT of IA to 3000 psi. 05:30 07:30 2.00 7,713 7,713 COMPZ RPCOM DHEQ P Monitor Packer /(;asingtest and observe a steady pressure loss down to 1,500 psi x 30 minutes. Bleed IA down to "0" psi. Open Pipe Rams. Re- pressure back -up on the Drill Pipe against the Packer setting Ball /Rod. This time take pressure up to 3,050 psi x 10 minutes. Drill Pipe pressure holding "rock- solid ". Bleed Drill Pipe pressure down to "0" psi. P Kit Close Pipe Rams. Re- pressure back up on IA to 3,000 psi. Once again, It observed a steady pressure fall -off. However not a fast as the first test. Discuss finding with Anchorage Engineer. 07:30 08:45 1.25 7,387 7,375 COMPZ RPCOM CIRC T Shear PBR. Pull Seal Assembly above top of Packer (7,387 -ft). Circulate and condition wellbore with 9.0 ppg NaCI at 5.0 bpm/700 psi. Total volume pumped = 250 bbls. 08:45 10:15 1.50 7,375 7,387 COMPZ RPCOM DHEQ T Sting back into the PBR. Close Pipe Rams. Re -test the Packer /Casing to 3,000 x 30 minutes. Once again the pressure fall -off was gradual down to 1,700 psi. Discuss results with Anchorage Engineer and develop a plan forward. 10:15 13:30 3.25 7,387 0 COMPZ WELLPFTRIP T Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down the Baker Seal Assembly. 13:30 18:00 4.50 0 7,345 COMPZ WELLPFTRIP T PJSM. Bring Baker Retrievamatic Packer to floor. Make -up same. Run in hole on 3 1/2" Drill Pipe. Up wt 130K and SO 92K. Set pkr at 7345' MD. Page 24 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 18:00 20:00 2.00 7,345 7,345 COMPZ WELLPF DHEQ T RU to PT. Test IA above pkr at 7345' _ MD to 3000 psi. Good test (30 min test = 60 psi loss). RU to test below pkr down DP to 3000 psi. Test failed (3000 psi to 1750 psi in 10 mins and down to 1300 psi in 30 mins). Bleed off pressure. 20:00 20:30 0.50 7,345 7,255 COMPZ WELLPF TRIP P PJSM. Unseat pkr. Begin TOOH sideways w/ pkr on 3 -1/2" DP. 20:30 22:30 2.00 7,255 7,255 COMPZ WELCTL CIRC T Well burped 1/2 bbl while TOOH. Stop and circulate hole volume (rate limit of 3 bpm through Baker Retrievamatic Pkr). Close pipe rams due to gas bubbling at surface. 22:30 00:00 1.50 7,255 7,255 COMPZ WELLPF CIRC T Monitor well after circulating 210 bbls 9.0 ppg NaCI brine. Trip tank gain of 3/10 bbl in 15 mins. Start circulating again while weighting up to 9.6 ppg NaCI brine. 04/02/2011 Circulate and condition Well with 9.6 lb/gal Brine. Monitor. POOH sideways w/ 3 -1/2" Drill Pipe. Test upper pipe rams and choke valves as per AOGCC. Begin TIH w/ 3 -1/2" GL completion. 00:00 04:00 4.00 7,255 7,255 COMPZ WELCTL CIRC T Continue wt up fluid to 9.6 ppg NaCI while circulating 9.0 ppg NaCI. 04:00 06:00 2.00 7,255 7,255 COMPZ WELCTL KLWL T Start 9.6 ppg NaCI down DP to circulate and kill well. Monitor Well. Observe a 1 bbl Trip Tank gain in 30 minutes. 06:00 11:30 5.50 7,255 7,255 COMPZ WELCTL KLWL T Continue to monitor Well. Skim oil from pits and condition to 9.6 lb/gal. Circulate Wellbore at 3.0 bpm /325 psi one more time with 9.6 lb/gal Brine. Returns weight 9.6 lb/gal. Monitors Well static x 30 minutes (Ball /Rod on seat and Packer set). 11:30 20:00 8.50 7,255 0 COMPZ WELLPF TRIP P POOH with Test Packer and 3 1/2" Drill Plpe. Single down Drill Pipe in Pipe Shed. Monitor hole fill. 20:00 21:00 1.00 0 0 COMPZ WHDBO BOPE T LD Baker Retrievamatic Pkr. Pull wear ring and set BOPE test plug. Test pipe rams and choke valves 2, 5, and 6 to 3000 psi as per AOGCC regulations. 21:00 22:00 1.00 0 0 COMPZ WHDBO MPSP T Finish PT. Good test (5 min low = 300 psi and 5 min high = 3025 psi) Insignificant leakoff. PJSM. Clear floor of test eqpt. Pull test plug and wear ring. PJSM. Prep to run 3 -1/2" GL completion. 22:00 00:00 2.00 0 1,240 COMPZ RPCOM RCST P PJSM. Begin TIH w/ 3 -1/2" GL completion. 04/03/2011 Finish running 3 -1/2" GL letp ion• Locate PBR spot CI 9.6 ppg NaCI brine. Spaceout 2' from fully located. Set Baker FHL pkr, shear PBR, space out, and land tbg hgr. RILDS. PT tubing to 3000 psi. Bleed tubing to 2000 psi. PT IA to 3000 psi. Shear SOV. Set BPV, ND BOPE, and NU 3 -1/8" tree. 00:00 03:30 3.50 1,240 1,240 COMPZ RPCOM RCST P 1240 ft at midnight. PU 48K lbs and SO 50K lbs. Continue TIH w/ 3 -1/2" GL completion. Page 25 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 07:00 3.50 1,240 7,368 COMPZ RPCOM RCST P Finish running the 3 1/2" GL completion. Pick -up Joint #227. Bring on Charge Pump at 60 psi. Continue in hole. Observe Seal Assembly entering the PBR at 7,368 -ft. Pressure increased to 250 psi. Pick -up Joint #228 and and "NO -GO" with 14.5 -ft in. Pull out of the PBR. 07:00 08:30 1.50 7,340 7,340 COMPZ RPCOM CIRC P Spot 15+ bbls of Corrosion Inhibited Brine around the Seal Assembly and the bottom of the Completion. 08:30 09:30 1.00 7,366 7,263 COMPZ RPCOM PACK P Sting back in and space -out 2 -ft from "NO -GO ". Pressure up to 2,100 psi on the Tubing and begin to set the FHL Packer at 7,286 -ft. Slack off 10K on Packer. Bring pressure up to 2,500 psi and hold for 5 minutes to complete Packer setting. Bleed pressure down to 1,000 psi. Pick -up on tubing and shear the Seal Assembly free from the PBR ar 7,263 -ft. with 27K over -pull. Lay down Joints 228, 227, and 226. Add a 3 1/2" Space -out Pup Joint. Pick up joint 226. Make -up Tubing Hanger Assembly. Pick up Landing Joint. Bring Charge Pump on at 60 psi. Ease in hole saw Seal Assembly enter the top of the PBR at 250 psi. 09:30 10:00 0.50 7,263 7,355 COMPZ WHDBO THGR P Land Tubing Hanger with 7.70 -ft "stick -up" and 14.12 -ft of Seals stung inside of the PBR. RILDS. 10:00 12:30 2.50 7,355 7,355 COMPZ RPCOM PRTS P Rig up test equipment. Pressure up on the Tubing at 3,000 psi x 15 minutes. Good. Bleed pressure down to 2,000 psi. Pressure up on the IA to 3,000 psi to test the Packer and Casing x 30 minutes. Good. Bleed pressure from the IA to "0" and then the Tubing to "0 ". Pressure back up the IA and observe the SOV shear at 2,200 psi. Pump a barrel through the sheared valve to confirm communications. All tests recorded on Chart. Rig down test equipment. 12:30 16:30 4.00 0 0 COMPZ WHDBO NUND P Install BPV. Nipple down BOP Stack. Wash Stack and Annular. Set back on Stump. 16:30 18:00 1.50 0 0 COMPZ WELLPF SFTY P Day crew safety /ops mtg for upcoming Ignik Sikumi #1 well 18:00 19:30 1.50 0 0 COMPZ WELLPF SFTY P Night crew safety /ops mtg for upcoming Ignik Sikumi #1 well 19:30 22:00 2.50 0 0 COMPZ WHDBO NUND P Continue ND BOPE. Camp leaves location @ 2100 hrs. 22:00 23:15 1.25 0 0 COMPZ WHDBO NUND P NU 3 -1/8 tree Page 26 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 0 0 COMPZ WHDBO NUND P WH orientation OK'd by L. Suiter (2V DSO). Prep to pull BPV. 04/04/2011 Pull BPV. Test tbg hgr void and tree (250/5000 psi). Displace IA and tbg w/ diesel. Set BPV w/ lubricator. Secure Cellar. RDMO. Rig release at 0930 hrs. 00:00 00:30 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV and set tree test plug 00:30 02:30 2.00 0 0 COMPZ WHDBO PRTS P PT tbg hgr void (250 - 5 min and 5000 - 15 min). Good test. Test tree (250 - 5 min and 5000 - 5 min). Good test. 02:30 04:45 2.25 0 0 COMPZ WELLPF FRZP P RD test eqpt. PJSM. RU LRS to displace down IA through SOV @ -7230' MD taking returns from tbg. Begin displacement ( -258 bbls diesel). ICP @ 4 bpm w/ -90 psi choke pressure is -800 psi. 04:45 05:30 0.75 0 0 DEMOB WELLPF RURD P Finish displacement (280 bbls diesel). FCP @ 1.5 bpm w/ -550 psi choke pressure is -600 psi. Hold pressure on well -600 psi. RD LRS. 05:30 06:00 0.50 0 0 DEMOB WHDBO MPSP P Set BPV w/ lubricator. 06:00 09:30 3.50 0 0 DEMOB WELLPF DMOB P Finish RDMO. Rig release at 0930 hrs - 04 April 2011 Page 27 of 27 2V -09 Well Work Summary .DATE SUMMARY 2/20/11 SET 2.72" X 87" CATCHER ON WO@ 7450' RKB. ATTEMPT TO CMIT, NO aCESS. SUSPECT SOME GAS IN THE IA. PULL DV @ 7380' RKB. RECOMMEND CIRCULATING OUT WELL PRIOR TO DHD STEP. 2/22/11 LOADED TBG & IA WITH 260 BBLS OF DIESEL. CMIT TO 3000 PSI PASSED. BLEED TBG & IA TO 0. BLEED OA FROM 60 TO 40 PSI, ALL GAS. 4/9/11 PULL BALL/ ROD @ 7685' SLM, REPLACE SOV @ 7230' RKB W/ DV, PULL DV'S @ 5767', 4558' ' P6 s RKB, SET OV © 5767' RKB. IN PROGRESS. W 4/10/11 PULL DV @ 2875' RKB, SET GLV'S @ 4558', 2875' RKB, TEST TBG, PASS, PULL RHC FROM k 5 CMU © 7697' RKB, PULL 2.75" UPPER HALF OF NIP - REDUCER INSERT @ 7741' RKB. IN PROGRESS. 4/11/11 ATTEMPT TO PULL LOWER HALF OF 2.75" NIP - REDUCER. BAIT SUB AND BULLDOG SPEAR STILL IN HOLE. 4/12/11 ATTEMPT TO PULL LOWER HALF OF 2.75" NIP - REDUCER @ 7741' RKB. BAIT SUB, BULLDOG SPEAR STILL LATCHED INTO NIP - REDUCER, IN PROGRESS. 4/20/11 WENT INTO RECOVER A NIPPLE REDUCER, AFTER SEVERAL JARRING ATTEMPTS A WEIGHT CHANGED WAS NOTICED AND THE COIL WAS FREE, POOH TO SEE WHAT WAS RECOVERED, BULLDOG BAIT SPEAR WAS RECOVERED BUT THE NIPPLE REDUCER WAS NOT RECOVERED. JOB COMPLETE, TURNED WELL OVER TO DSO 4/22/11 PULLED 2.25" NIPPLE REDUCER @ 7741' RKB. TAGGED @ 7771' SLM. OPENED CMU @ 7697' RKB. COMPLETE. WELL LOG C-Aiv`S TRANSMITTAL PROACTIVE DIACINOSiiC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 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 V ��, Anchorage, AK 99518 . M Fax: (907) 245 -8952 1) Caliper Report 19 - Mar 2V -09 1 Report / EDE 50 -029- 21300 -00 2) RECEIVED Signed : Date : APR :5 9 2011 Print Name: 4= ovea er w ,a =s PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 C:\Documents and Settings\Diane Williams \Desktop \CPAI_Transmit.docx I • • I lb MON- Memory Multi- Finger Caliper Log Results Summary I i C ompany: ConocoPhillips Alaska, Inc. Well: 2V -09 Log Date: March 19, 2011 Field: Kuparuk Log No.: 10144 State: Alaska I Run No.: 2 API No.: 50-029-21300-00 Pipet Desc.: 9.625 in. 36 lb. J-55 BTC Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 1,670 Ft. (MD) I Inspection Type : Buckling & Corrosive & Mechanical Damage Inspection COMMENTS : U This caliper data is tied into the top of surface casing @ 0 ft. I This log was run to assess the condition of the 9.625 in. surface casing with respect to subsidence induced buckling and corrosive and mechanical damage. The caliper recordings indicate slight buckling at —1,000 ft., restricting the I.D. to 8.63 in. (999 ft.). The I caliper recordings indicate intermittent areas of heavy deposits, restricting the I.D. to 5.88 in. at 1,652 ft.. Log plots of the centered and off - center caliper recordings across the surface casing logged and a graph illustrating minimum recorded diameters on a joint-by-joint basis are included in this report. Caliper recordings indicate ovality, with a maximum I.D. and Minimum I.D. difference of 0.40 in. recorded in joint 9 at l 376 ft.. The caliper recordings indicate the interval of 9.625 in. surface casing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, or areas of 1 cross - sectional wall loss recorded throughout the interval logged. This is the second time a PDS caliper has been run in this well and the first time the 9.625 in. surface casing has been logged. I MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 11 %) are recorded throughout the interval logged. I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 10 %) are recorded throughout the interval logged. I MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 5.88 in. Jt. 39 @ 1,652 Ft. (MD) III Heavy Deposits Minimum I.D. = 6.30 in. Jt. 29 @ 1,215 Ft. (MD) Heavy Deposits Minimum I.D. = 6.78 in. Jt. 32 @ 1,345 Ft. (MD) Heavy Deposits Minimum I.D. = 7.87 in. Jt. 26 @ 1,105 Ft. (MD) Heavy Deposits Minimum I.D. = 8.02 in. Jt. 30 @ 1,261 Ft. (MD) 1 I Field Engineer: E. Gustin Analyst: HY. Yang Witness: L. Hinkel I ProActive Diagnostic Services, Inc, / 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 I hisC 031-- a on) a I I • • Correlation of Recorded Damage to Borehole Profile 1 . Pipe 1 9.625 in ( -0.0' - 1626.6') Well: 2V -09 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: March 19, 2011 1 I . Approx. Tool Deviation ■ Approx. Borehole Profile I 1 5 I 5 163 1 10 379 I 15 595 a 1 . U. E c 20 810 a o p 1 25 1024 1 30 1239 I 35 ■ 1454 I 39 1627 I 0 50 100 Damage Profile ( wall) / Tool Deviation (degrees) Bottom of Survey = 39 I I I I • • PDS Multifinger Caliper 3D Log Plot L7 Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2V -09 Date : March 19, 2011 I Description : Detail of Centered Caliper Recordings Across 9.625" Casing Logged Comments Depth Maximum I.D. 3 -D Log (Centered) Image Map (Centered) I I 1ft:900ft 5.7 inches Minimum I.D. 9.7 282° 0° 90° 180° 270° 0° I I 5.7 inches 9.7 I Nominal I.D. . 5.7 inches 9.7 — 'a ■ Pup .- mmorio Joint 1 — I Joint 2 50 - --- - I Joint3 100 - - -''- I MENIMMIM I I Joint 4 ----■ 150 — 3 I Joint 5 1 i 200 1 Joint 6 I Ovality 250 Joint 7 I Ovality i t Joint 8 300 I I Ovality Joint 350 Ovality •iuu Joint Ovality 10 400 ♦♦u♦♦i Joint 11 111111 O IF vality 450 — ----t IIIIIIIIIIMMIZ Joint 12 ______I MNSMINIMS Ovality M 111 . 11111111 500 — MMINIIM[. r Joint 13 ....a R Ovality ������ 14 I • • 550 �■■■��■��� � � Joint 14 -i � Ovality = - ---- � a� Joint 15 600 -NI ' Oval ----- - p` Joint 16 650 .1�= fJf�� ���r>I►I■N 1 Oval ity ��� ISM 1 Joint 17 700 11=1111111111111 e DIM 111111111111111MMIMMIllit OM Ovality ---_ a Joint 18 ���� RI-U I Ovality 750 MIDI �M��MMNII i I i Mil Joint 19 ----_m rite MEI Ovality 800 ��IM����DII E� ���■MIMM�rIM� Joint 20 - = =---- tl � I Ovality ��1M� ������ 850 �������DAi�EN �■����1i� /IMMI Joint 21 -.----� '-MI IM����M�D1��NI 900 1111111111111111111111111111=111110,111111111 Joint 22 ------- MIIMIIMIMIIIIIIMMIILTIMMBI ' ���M�NI�r �� �M��■r■IM�tU I 95Q �1•..���NMM3� Joint 23 --�-���f �1�� � -� Joint 24 ��IE� Slight Buckling 1000 ---- Min. I.D. = 8.63" 111111111111111•11111111111111111111[4=1•11 -m111111111111111•11111111111111111111[4=1•11 ' 11■����s1;aw •1=i��■���iIMI� Joint 25 1050 ����� 1 11•11111111•11111M1111111=1111 , ��� �� Joint 2s Heavy Deposits Min. I.D. = 7.87" 1 100 Joint 27 ••---�� =N 1150 —MN ,. Joint 28 =-- v iii Joint 29 1200 Heavy Deposits �� �� d� � �+ i Min. I.D. = 6.30" ---��- r I Joint 30 1250 Heavy Deposits ----IIi I Min. I.D. = 8.02" ----111EA-R I • . Joint 31 1300 a Joint 32 Heavy Deposits 1350 I Min. I.D. = 6.78" ,' 1 I- Joint 33 - S I 1400 Joint 34 1 1450 Joint 35 1 1500 1 4. Joint 36 1 r I r 1 1550 — Joint 37 [ _ i , I Joint 38 1600 i 1 Joint39 I Heavy Deposits 1650 - ■ I Min. I.D. =5.88" I 5.7 Nominal I.D. inches . 9.7 Minimum I.D. I 5.7 inches 9.7 Comments Depth Ma ximum I.D. 3 -D Log (Centered) Image Map (Centered) I NW - • r - ■tivex -, . 1ft 5.7 inches 9.7 282° 0° 90° 180° 270° 0° I 1 I I I I I I 1 • • I 14,3s- PDS Multifinger Caliper 3D Log Plot � — Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2V -09 Date : March 19, 2011 1 Description : Detail of Off- Center Caliper Recordings Across 9.625" Casing Logged Comments Depth Maximum I.D. 3 -D Log (Off - Center) Image Map (Off - Center) 1ft:900ft 5.7 I inches Minimum I.D. 9.7 0° 0° 90° 180° 270° 0° R 5.7 inches 9.7 I 5.7 Nominal I.D. inches 9.7 MEI s>i�a �s -- 0 E i _ 1011 MENEM= — Nu. 4 at I a Joint 2 I Joint 3 , 100 — - - - +- - - - -- $ I , , Joint 4 - 150 -• ------i -------I Joint 5 i ,, 200 1 , Joint 6 � -■ i 1111M111.1=1111111 Ova1Ry -- - -IIN- 250 --�--r1�M ; , I Joint 7 ------iUR - - A Ovality -- -�yyi� .. MR„ - 11111111k1 300 — Joint 8 =Mit II Ovality -Ili -_ -■ 1 - - - -.# Joint9 350 - - -III I Ovality -- --II II - - -- MAIM Joint 10 __-- - - - /fit -- - - -IRIF I Ovality 400 - --- -MIti ti --- - --IAI - IMMI=111111111•Mtili Joint 11 - - --1 ®I I Ovality 450 ----tit --- - 1111 --- - -. Joint 12 -- - - - -ti I Ovaiity 500 -- -- - - -t 6111111111==11111■1111 Joint 13 i , Ovality IIIIMMIIIIIMM - 1 • • 550 Joint 14 �, .,�. as Ovality - �����E i m 4 Joint 15 600 ��IMEit Mal _ el I Ovality M= Joint 16 650 fIM [fir= ,; , ry Ovality ___ - 4 111111111111===111111111% 4* Joint 17 700 ill III I Ovality 1111111 `' , Joint 18 ���� � 1 Ovality 750 ___u1 El =111111111111R .1 MEI , Joint 19 j 1 MIIIIIIrAa __En Ovality 800 =Mil MI :M� .. Joint 20 ------`1 O vality OI I 850 firm Joint 21 M��MMM� 900 11111111111•11=11, alio, ies.. M��� «. Joint 22 limmmommlitQ. .... ....rdi= 7, L 950 �.� - '"�", Joint 23 ------11p1 I Joint 24 g --- Slight Buckling 1000 1 Min. I.D. = 8.63" -- MI t4 M1��M =�1qq.1, - ��-��1fl) .w-- -- Iraill Joint 25 1050 11111111111 �all ��� =E +��• �M Joint 26 11111111MMIN11111111111LI-EI ��. "_^ BM rw, Heavy Deposits ,� Min. I.D. = 7.87" 1100 —A I ..41 IM______III! - ,rm .... Joint 27 -------1t 1150 M1111111111111111=11111111111111E#' III IIMIIIIIIMINIENIVI MM MIIIIIIIIIIIII[ Joint 28 ------n 1200 ������E�... . Joint 29 ������ ,,a Heavy Deposits ������� Min. I.D. = 6.30" ----- • Joint 30 1250 IIIIMMIIIIIIMA M =1111111111F Heavy Deposits P Min. I.D. = 8.02" M��EM— , . k * -...1 MUNI I 1 • • Joint 31 1300 — — — — - - - Joint 32 44 .d .. , x • - • . Heavy Deposits 1350 i u , ,¢ Min. I.D. = 6.78" " Joint 33 I 1 1400 _ _ Joint 34 t.., 1» ._ I 1450 - . - 0 Joint 35 -— +Y •, C 1500 - - :2 .0 ° Joint 36 , ::1: , I 1550 Joint 37 Irti . b :,. a 1 _t .; 1600 " Joint 38 I s A , * .,.... ,w"« Joint 39 t. Heavy Deposits 1650 " s Min. I.D. = 5.88'. 1 1 1 si. 5.7 Nominal I.D. inches 9. Minimum 1.0. 1 I 5.7 inches 9.7 Comments Depth Maximum I.D. 3 -D Log (Off- Center) Image Map (Off- Center) 1 1f :900ft 5 .7 inches 9.7 0° 0° 90° 180° 270° 0° 1 I I I I I I I I • • r 14‘-1 Minimum Diameter Profile I Well: 2V -09 Survey Date: March 19, 2011 Field: Kuparuk Tool: UW MFC 40 Ext No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches r Country: USA Tubing I.D: 8.765 inches I Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 1 I 2 I/ 4' 5 1 6 I. r 7 8 9 r 10- 12 I I 13 r , 14 ,5 16 ' 17 ' I S 18- I 1 9 , . z 20 C - II I a 21 II 22 I 23 24 - I 25 26 - 27 . 1 I 28 ' 29 30 31 � i ' r 32 r 33 I 34 t 35 j I 37 III I 38 , I 39 I I I • • I PDS Report Overview S,, Body Region Analysis I Well: 2V -09 Survey Date: March 19, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 9.625 ins 36 ppf J -55 BTC 8.765 ins 9.625 ins 6.0 ins 6.0 ins I Penetration(% wall) ri Da mage Profile (% wall) 50 Penetration body Metal loss body 0 50 100 40 0 30 20 10 0 10 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 40) I 40 0 0 0 I 20 Damage Configuration ( body ) I I 30 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole rill C I Number of joints damaged (total = 0) 0 0 0 0 0 Bottom of Survey = 39 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 9.625 in 36.0 ppf J -55 BTC Well: 2V -09 Body Wall: 0.430 in Field: Kuparuk I Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: March 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset I oss et Body % I.D. Comments (% wall) (Ins.) (Ins.) `ice (Ins.) 0 50 100 0.1 -0 O 0.05 11 5 8.76 Pup ■ 1 5 ) 0.05 11 2 8.69 2 48 0 0.04 9 2 8.72 3 77 0 0.05 11 3 8.70 4 121 0 0.03 6 1 8.71 1 5 163 0 0.04 10 .3 8.74 • 6 206 0 0.04 10 5 8.68 Ovality. ■ 7 250 0 0.05 11 10 8.61 Ovality. 8 292 0 0.05 11 0 8.70 Ovality. I 9 336 0 0.05 11 6 8.63 Ovality. ■ 10 379 0 0.05 11 6 8.65 Ovality. ■ 11 422 0 0.05 11 7 8.63 Ovality. 1 12 465 0 0.04 10 6 8.67 Ovality. ■ I 13 509 0 0.04 10 4 8.67 Ovality. • 14 552 0 0.05 11 5 8.66 Ovality. ■ 15 595 0 0.05 11 5 8.65 Ovality. ■ 16 638 0 0.05 11 7 8.64 Ovality. ■ 17 680 0 0.05 11 5 8.66 Ovality. 18 723 0 0.04 9 3 8.70 Ovality. 19 767 U 0.05 11 8 8.56 Ovality. 1 20 810 0 0.05 11 6 8.60 Ovality. ■ 21 853 0 0.04 10 7 8.62 ■ III 22 896 0 0.05 11 4 8.60 23 939 0 0.04 9 6 8.65 24 982 0 0.04 10 5 8.63 Slight Buckling. ■ 25 1024 0 0.04 10 5 8.67 • I 26 1068 0 0.04 10 4 7.87 Heavy Deposits. ■ 27 1111 0 0.04 10 3 8.65 • 28 1154 0 0.05 11 4 8.63 ■ 29 1 196 0 0.04 10 3 6.30 Heavy Deposits. I 30 1239 0 0.03 6 4 8.02 Heavy Deposits. 31 1282 0 0.04 9 2 8.67 Lt. Deposits. 32 1326 0 0.02 5 2 6.78 Heavy Deposits. 33 1368 0 0.03 6 2 8.67 34 1410 0 0.03 6 1 8.70 I 35 1454 0 0.03 6 2 8.67 Lt. Deposits. 36 1497 0 0.04 9 3 8.68 Lt. Deposits. 37 1541 U 0.03 6 3 8.36 Lt. Deposits. 38 1584 U 0.04 9 5 8.56 Lt. Deposits. I 39 1627 0 0.03 8 4 5.88 Heavy Deposits. I Penetration Body Metal Loss Body I I I Page 1 I 1 1 • • 1 PDS Report Cross Sections I Well: 2V -09 Kuparuk Survey Date: March 19, 2011 Field: Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: HY. Yang I I Cross Section for Joint 39 at depth 1652.210 ft Tool speed = 47 Nominal ID = 8.765 ' Nominal OD = 9.625 Remaining wall area = 100% Tool deviation = 37° I I I I I I 1 Minimum I.D. = 5.881 ins Heavy Deposits Minimum I.D. = 5.88 ins HIGH SIDE = UP I I I I I • • PDS Report Cross Sections Well: 2V -09 Survey Date: March 19, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: HY. Yang I Cross Section for Joint 29 at depth 1215.470 ft Tool speed = 46 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 100% Tool deviation = 30° I I I I I I Minimum I.D. = 6.298 ins Heavy Deposits Minimum I.D. = 6.30 ins HIGH SIDE = UP I I I I I I • • I PDS Report Cross Sections 1 tS I Well: 2V -09 Survey Date: March 19, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: HY. Yang I I Cross Section for Joint 9 at depth 376.030 ft Tool speed = 43 Nominal ID = 8.765 I Nominal OD = 9.625 � �` Remaining wall area = N/A Tool deviation = 7° ' I r I I I / I ,, I Minimum I.D. = 8.635 ins Ovality Minimum I.D. = 8.635 ins HIGH SIDE = UP I I I I I I I.- 1 KUP ConocoPhillips = \ Attributes ogle & MD TD Alaska, In - W enro bo APW WI Field name Well Status Inc/ ( °) MD (MB) 2V -09 Act Elba (MB) attp, 500292130000 KUPARUK RIVER UNIT PROD 47.36 2,125.00 8,100.0 w" Comment H2S (ppm) Date Annotation End Date KB-Ord (IQ Rig Release Date I Wet Conk, Schein 1/21/2011 10 54 AM SSSV: LOCKED OUT 45 1/17/2010 Last WO: 34.98 3/25/1985 - 2V-09 Schematic 1 /2011 Annotation Depth (R1B) Entl DDate Amotatlan Last Mod ... End Date _. Last Tag: SLM 7,815.0 10/8/2010 Rev Reason: WRP RKB DEPTH Imosbor 1/21/2011 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR (QC) 16 15.062 34.6 102.0 102.0 65.00 H -00 WELDED I/ Casing Description String 0... String ID ... Top (RKB) Set Depth (C.. Set Depth (ND) ... Ming Wt... String ... String Tap Dud E(QC) 95/8 8.921 34.6 3,617.1 2,924.0 36.00 J BTC Casing Description String 0... String ID ... Top (RKB) Set Depth p... Set Depth (TVD) ... String Wt... String. String Top mrd CONDUCTO PRODUCTION(QC) 7 6.151 31.0 8,054.5 6,1264 26.00 J BTC (DC), 35-102 SAFETY v o Tubing Strings 1,911 Tubing Description Stung 0... String ID ... Top (RKB) Set Depth p... Set Depth (TVD)... String Wt... String ... String Top met I TUBING 3 1/2 2.992 0.0 7,749.0 5,894.1 9.30 J-55 8RD EUE )PC i Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT. F Top Depth 2,169 3 (ND) Top Ind Top (RKB) i B) (1 Description Comment Run Date ID (le) 1,911.0 1,716.1 45.34 SAFETY VLV Baker'FVL' (LOCKED OUT 1/22/2004) 4/30/1985 2.812 (ac), 353 2,169.0 1,893.1 46.28 GAS LIFT CAMCO/KBUG/1 /GLV/BK/.25/1379/ Comment BROKEN 1/2/1996 2.875 SURFACE °� LATCH STA 1 ,617 3,642.0 2,942.1 43.76 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 2 10/9/2010 2.875 GAS LIFT. 3,642 4,494.0 3,553.2 45.57 GAS LIFT CAMCO/KBUG/1 /GLV/BK1.25/1351 /Comment: BROKEN 1/2/1996 2.875 LATCH STA 3 GAS LIFT, 4,906.0 3,842.3 46.89 GAS LIFT CAMCO/KBUGI1 /DMV /BK/ / /Comment STA 4 10/10/2010 2.875 4.494 5,347.0 4,151.0 45.39 GAS LIFT CAMCO/ICBUGI1 /DMY /BKI // Comment: STA 5 11/22/1995 2.875 5,760.0 4,443.7 45.80 GAS LIFT CAMCO /KBUGI1 /DMY /BK/ // Comment STA 6 1/24/2004 2.875 GAS LIFT, 1 6,173.0 4,738.3 44.26 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA7 10/10/2010 2.875 4,908 8,616.0 5,055.3 . GAS CAMCO /KBUGI1 /DMY /BK/ // Comment: STAB STA 10/10/2010 2.875 7,. 5,349.9 • 43 89 GAS LILIFT FT /GlDMY /BK/ // omme 5/22/1990 2.875 Gns 5347 1 7,380 0 5,611.7 39.87 GAS LIFT CAMCO /MMG- 2/15 /DMY /RK/ / /Comment: CAMCO KBUl / C nt: STA 9 10 1/23/2004 2.920 7,420.0 5,642.3 39.65 PBR Baker 4/30/1985 3.000 GAS LIFT, ` 7,433.0 5,652.3 39.86 PACKER Baker'FHL' PACKER 4/30/1985 3.000 11/19/2010 0.000 7,472.0 5,682.2 39.97 PRODUCTION CAMCO/ MMG - 2/1.5 /CV /RKP / / /Comment: OPEN STA 11 12/24/2008 2.875 5.760 7,450.0 5,665.3 40.01 PLUG WRP CA RKB DEPTH G AS LIFT 6,173 I 7,543.0 5,736.6 39.87 PRODUCTION CAMCO /MMG- 2/1.5/DMY BROKE/RK/ // Comment: 11/28/1989 2.875 CLOSED STA 12 GAS LIFT, } 7,639.0 5,810.5 40.46 PATCH 21' Merle Tbg Patch; Set 11 /6/95 11/6/1995 2.375 6.616 7,689.0 5,848.5 40.47 PATCH 21' Merle Tbg Patch; Set 11/6/95 11/6/1995 2.375 GAS LIFT, l 7,706.0 5,861.4 40.44 PRODUCTION CAMCOl MMG- 2I1.5 /PATC WRKI / /Comment: CLOSED 11/6/1995 2.875 7,oze STA 13 GAS LIFT, 7,727.0 5,877.4 40.45 PACKER Baker'FB -1' PACKER 4/30/1985 4.000 7 ' 0 7,741.0 5,888.0 40.46 NIPPLE Camco 'D' Nipple NO GO 4/30/1985 2.750 7,741.0 5,888.0 40.46 NIPPLE Camco NIPPLE REDUCER 11/5/1995 7250 POP. 7.420 } ( REDUCER 7,748.0 5.893.4 40.46 SOS Comm 4/30/1985 2.992 PACKER. 7. 433 .' 7,749.0 5,894.1 40.46 TTL ELMD TTL @ 7737' during PPROF 06 07 /08/2000 4/30/1985 2.992 Perforations & Slots PLUG, 7,450 Shot Top (TVD) Btm (TVD) Dens PRODUCTION. Top (MB) Bun (RKB) (RKB) (RKB) Zone Date Isl Type Comment 7,472 7,592.0 7,654.0 5,774.3 5,821.9 C-4, C -3, C -1, 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser I UNIT B, 2V -09 Hyperdome i PRODUCTION, 7.543 7,668.0 7,675.0 5,832.5 5,837.9 UNIT B, 2V -09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser Hyperdome 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B, 2V -09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser Hyperdome PERF, 7.C7,654 7,778.0 7,792.0 5,916.2 5,926.9 A -0, 2V - 09 4/28/1985 4.0 IPERF deg. phasing; 4" Dresser PATCH. 7A09 Hyperdome Hyperdome I ? ees -7 a7s 7,805.0 7,840.0 5,936.8 5,963.4 A3, 2V -09 428/1985 4.0 IPERF 120 deg. phasing; 4" Dresser IPEUF.� 1111 7,805.0 Notes: General & Safety IPERF. fi End Date Annotaton 7.682 -7 se 3/1/2006 NOTE: PPROF IDENTIFIED C-SAND TBG LEAK @ 7631' I PATCH, 7,680 12/8/2010 NOTE: View Schematic w/ Alaska Schemalic9.0 7 PRO DU C ,7 ON, Vi I I PACKER, 7.727 , ii ,_ Mandrel Details Top Depth Top Port i Bee NIPPLE, 7,741 (ND) Ind OD Valve Latch Size TRO Run NIPPLE Sur Top (RKB) IRK81 ( °) Make Nadel (In) Sery Type Type (in) Owl) Run Date Com... REDUCER, 1 2,169.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,379.0 12/1996 Brok... 7.741 Latch SOS, 7,748 1111 2 3,641.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/9/2010 i .---. 3 4,493.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,351.0 12/1996 Brok... TTL, 7,749 Latch 4 4,908.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 IPERF, 5 5,346.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/22/1995 7,778 - 7,782 III III IPERF. 6 5,760.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/24/2004 Mil MI I 7.805 7 6,173.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 PRODUCTION 8 6,615.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 lncl e,o� Gol> : 9 7,027.9 F'a93AM�3• -RUG 1 GAS LIFT DMY BK o.O±16Tcn 1 011 , 422/1990 ■ I I KUP • 2V -09 ConocoPhillips AO Co omWtifp4 KBQd P4 Rig Release Dare ' -- Well COn60. -2V -091/21/20111054: 33 AM _ 34.98_ - 3/25!1985 Schematic -Actual — i CONDUCTOR 7 (OC), 35 -102 SAFETY VLV, : p 1 1.911 - I GAS LIFT, 1 2 .169 1 I SURFACE J IOC), 35-3,617 GAS LIFT. 3,642 T I GAS LIFT. 4.494 GAS LIFT, 4,908 I GAS LIFT. 5,347 i GAS LIFT, E I 5.760 f GAS LIFT. 6,173 GAS LIFT. I 6.616 GAS LIFT. I 7,028 GAS LIFT, .380 I PBR, 7.420 I! PACKER, 7,433 I PLUG, 7,450 PRODUCTION. 7.472 7.472 I PRODUCTION, 7.543 PERF, 7,592 -1654 I PATCH, 7,639 PERF, 7,868-] 875 III 1111 IPERF, 11111 all 7.682 -7,686 PATCH, 7,689 PRODUCTION. I 7,706 �. —. 0 0 PACKER. 7,727 Mandrel Details I NIPPLE. 7,741 ' Top (N Top Port 1 (ND) InG OD Valve Latch Size TRO Run NIPPLE S61 Top (MB) I BI ( °) Make model (In) gen. type Type (in) (psi) Run Date corn... REDUCER i 10 7,379.9 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.0 1/23/2004 741 1111 11 7,471.8 CAMCO MMG-2 1 1/2 PROD CV RKP 0.000 0.0 12/24/2008 Open SOS. 7746 tJ 12 7,543.2 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 1128/1989 Closed I BROKE TTL. 7.749 13 7,706.6 CAMCO MMG-2 1 12 PROD PATCH RK 0.000 0.0 11/6/1995 Closed PERF, 78-7 792 ill 1111 IPERF, ill IN I 7.805 -7.840 PRODUCTION IOC), 31 - 8,055 NH . Gober Page 12 of 32 March 2, 2011 TD, 8,100 • - 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 2V -09 Run Date: 3/27/2011 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 2V -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21300 -00 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 OfsS --q Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Pte N 0 7 0 Signed : (-\_, 3 _ • • Page 1 of 1 III Regg, James B (DOA) From: Nordic 3 Company Man [n1433 @conocophillips.com] Sent: Saturday, April 02, 2011 5:57 AM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Gober, Howard; Cawvey, Von; CPA Wells Supt; Senden, R. Tyler; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Nelson, Erik Q Subject: 2V -09 (PTD #185 -037) use of BOP on 01 April 2011 Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, we are issuing notification of BOPE use on Nordic 3 in a written report. Date, Time of BOPE Use: 01 April 2011 - 2030 hrs Well /Location /PTD Number: 2V -09 / Kuparuk River Unit / 185 -037 / Sundry #311 -027 Rig Name: Nordic 3 Operator Contact: Erik Nelson / Lee Hinkel — (907) 659 - 7446 - N1433(a�conocophillips.com Operations Summary: After testing the 7" casing string with a Retrievamatic Packer we began to trip out of the hole with the 3 -1/2" DP. After pulling one stand the driller /floorhands noticed some bubbling in the well. In order to condition the well for continued tripping operations the driller closed the pipe rams on the BOPE at 2030 hrs on 01 April 2011 and began circulating. After circulating a hole volume the rams were opened to observe the well. There was a 3/10 bbl pit gain during this monitoring so the pipe rams were closed and circulation began again while the fluid was weighted up to 9.6 ppg NaCI brine in order to facilitate further tripping operations. BOPE Used: Upper pipe rams and choke manifold valves 5, 6, and 2. Reason for BOPE Use: Control flow of fluids from the wellbore due to gas entrained within fluid. Actions Taken /To Be Taken: After circulating around the 9.6 ppg NaCI brine we will monitor the well for a no -flow test. We will then continue with our TOOH with the drill pipe and Retrievamatic Packer. Once on surface, we will set a test plug and test the BOPE components that were utilized. We will be able to keep the well loaded with 9.6 ppg NaCI brine during the test by allowing it to feed into the well via the ✓ casing valve. Please let us know if you have any questions or if you require more information. Thanks, Nordic Rig 3 Erik Q. Nelson / Lee Hinkel Office 907 - 659 -7446 Fax 907 - 659 -7566 ar APR 0 7 201; 4/4/2011 Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, April 01, 2011 11:08 AM To: 'Gober, Howard' Subject: RE: 2V -09 (PTD #185 -037) Completion Change Howard, You can proceed under the current sundry #311 -027 with the plan you outlined below. If you find the casing doesn't test above your set depth of 7345' and we will need to discuss a new plan and possible change to sundry. Guy Schwartz ,, APR 0 6 2O1 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Friday, April 01, 2011 11:00 AM To: Schwartz, Guy L (DOA) Subject: 2V -09 (PTD #185 -037) Completion Change Guy, We need to make a change to the completion as lined out in the Sundry #311 -027 for 2V -09 (PTD #185 -037). As we have discussed several times this week, the original plan was to leave the existing packer in the hole and stack a packer. Last Friday we inadvertently released the packer, but we did recover the entire selective completion. Last night we ran a new selective completion with a blast joint covering the B sand perfs and with blast rings covering the C sand perfs. A sliding sleeve and 1 gas lift mandrel were added to the selective completion to aide in flow control. Above the selective equipment we ran a FHL packer and PBR. Early this morning we set the packer at -7395' RKB. We were unable to test the 7" casing after setting the packer. The packer was set above the previous packer set depth but below the bottom gas lift mandrel depth for the previous completion. We speculate there may be some pitting in the 7" casing that is preventing a good packer set. Our plan is to run a test packer to -7345' RKB. We will be able to test above this point to confirm that the casing is good. That would confirm that there is a small leak in the packer run last night. We would then run a stack packer above to isolate the leaking packer. Seals will be stabbed into the PBR we ran last night with a new packer /PBR run 2 jts higher at -7287' RKB. Please confirm that this plan is acceptable and that we can continue forward under Sundry #311 -027. I know we had many discussions about pulling the selective which was not in the original Sundry application. Please confirm that running a new selective to give C sand isolation was acceptable as well. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 4/1/2011 Page 1 of 3 • • Schwartz, Guy L (DOA) From: Gober, Howard [ Howard .Gober @conocophillips.com] Sent: Tuesday, March 29, 2011 9:39 AM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Nordic 3 Company Man; CPA Wells Supt; Cawvey, Von Subject: RE: 2V -09 (PTD #185 -037) BOP Test and Well Control Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, 1 am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 3/28/11 0800 Well /Location /PTD Number: 2V -09 /Kuparuk River Unit/185- 037 /Sundry #311 -027 Rig Name: Nordic 3 Operator Contact: Howard Gober 907 - 263 -4220 howard.gober @conocophillips.com Operations Summary: The rig had inadvertently released the top packer of the selective completion. We were unable to pull out of the hole with the fish because the well was swabbing. A hole was shot below the packer to provide a bypass point for fluid around the packer. At 0730 on 3/28/11 the rig had a pre job safety meeting. The possibility of gas below the packer was discussed. The rig pulled 1 stand and monitored the well for flow. Flow was observed and the Upper pipe rams were closed. The well was shut in against the upper pipe rams, TIW valve, and choke valve #'s 5, 6, and 2. Valve #2 was then opened against a closed choke. The gas bubble was circulated out through the choke without incident. BOPE Used: Upper pipe rams, TIW valve, Choke manifold valves 5,6, and 2. Reason for n or ROPE Use: Control flow of fluids from the wellbore due to gas below the upper packer. Actions Taken /To Be Taken: After the well was shut in, the gas bubble was circulated out. A storm packer was set just below the casing head. The upper pipe rams, TIW valve, and choke valves 5, 6, & 2 were tested to 250/3000 psi. This test occurred at 1515 -1545 on 3/28/11. The storm packer was pulled and the drillstring and fish were pulled out of the hole. A full BOP test will be completed once we are on bottom with a cleanout assembly. This is expected to be the afternoon of 3/29/11 (today). This is the full BOPE test that an extension was granted on 3/28/11 at 0805 by Bob Noble. Please contact me if you need further information. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, March 28, 2011 8:17 PM To: Gober, Howard Subject: Re: 2V -09 (PTD #185 -037) BOP Test and Well Control 3/29/2011 4 • Page 2 of 3 • Howard, There is a guidance bulletin that outlines the BOP reporting requirements . Your email notice below covers most of the needed reporting and will suffice until we can talk in the morning . p g Guy Sent from my iPhone On Mar 28, 2011, at 4:43 PM, "Gober, Howard" < Howard .Gober @conocophillips.com> wrote: Guy, 1 just want to confirm that we are ok on the well control notification as well. Please call if you have any questions. FYI - We have completed the component tests and are preparing to pull out of the hole. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 -263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.govl Sent: Monday, March 28, 2011 4:42 PM To: Gober, Howard Cc: CPA Wells Supt; Cawvey, Von Subject: Re: 2V -09 (PTD #185 -037) BOP Test and Well Control Howard, As per our phone conversation , your BOP Testing plan as outlined is approved as well as extension for the full BOPE test. Guy Sent from my iPhone On Mar 28, 2011, at 3:32 PM, "Gober, Howard" < Howard .Gober @conocophillips.com> wrote: Guy, The Nordic 3 Company Man spoke with Bob Noble this morning about an extension for our BOP test due today (3/28/11). The reason for the request is that we currently have a fishing string in the hole with an open circ sub above the overshot. The fish appears to be the entire selective completion. We had to bail some salt and fill out in order to 3/29/2011 Page 3 of 3 shoot holes below the packer. This was done so that we could pull tubing without swabbing the hole. Due to the open perforations I want to have pipe in the hole for the BOP test, but I would rather have a competent work string without perforations, open circ sub, an E -Line fish, and a WRP set in the tubing below the overshot. The next BHA will have much lower possibility of plugging off with solids or salt. Bob Noble granted the extension. Subsequently, we started to pull out of hole with the drill pipe and we started to see flow on the annulus. The upper pipe rams were shut in, and gas was circulated out through the choke. Bob Noble was notified of the well control situation. The most likely cause of the flow was gas below the packer that began migrating up hole. We have been loosing fluid to the formation, so it was not a underbalanced condition. The rig had discussed the possibility of gas under the packer and was fully prepared evidenced by their quick response. We are currently setting a test packer so we can pressure test the components that we used during the well control circulation. Once these components are tested, we will pull out of the hole with the fish and lay it down. Then we will run in hole with a clean out BHA. Prior to cleaning out any fill, we will set a storm packer and do a full BOP test. Please confirm that the BOP extension as discussed above is approved and that the AOGCC has been properly notified of the well control event. As always, please call with any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 3/29/2011 • Page 1 of 1 Regg, James B DOA From: Gober, Howard [ Howard .Gober @conocophillips.com] Sent: Wednesday, March 30, 2011 2:06 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Nordic 3 Company Man; Cawvey, Von; CPA Wells Supt; Senden, R. Tyler; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Nelson, Erik Q Subject: 2V -09 (PTD #185 -037) Use of BOP Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 3/30/11 0300 Well /Location /PTD Number: 2V -09 /Kuparuk River Unit/185- 037 /Sundry #311 -027 Rig Name: Nordic 3 Operator Contact: Howard Gober 907 - 263 -4220 howard .goberCu�conocophillips.com Operations Summary: The rig completed the weekly BOP test. We had drill pipe in the hole and had set a storm packer. Since the storm packer was in the hole 13.5 hours, gas built up underneath the storm packer. This condition was discussed and expected. The annular was closed at 0300 on 3/30/11 prior to releasing the storm packer. The drill string was screwed into the top drive and the packer was released. The annulus had 570 psi on it once the storm packer was released. The gas was bled off initially through the gas buster and then out to the tiger tank. We bullheaded seawater into the well to displace any remaining gas. BOPE Used: Annular preventer and Choke manifold valves 5, 6, and 2. Reason for BOPE Use: Control flow of fluids from the welibore due to gas below the storm packer. Actions Taken /To Be Taken: After the well was shut in, the gas was bled off initially through the gas buster and then out to the tiger tank. Any remaining gas was swept from the welibore by bullhead seawater down the well into the formation. We will finish our cleanout and POOH with the drill sting. Once on surface, we will set a test plug and test the BOP components that were utilized. We will be able to keep the well loaded with seawater during the test by feeding seawater into the casing valve. Please let me know if you have any questions or if you require more information. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. Vi APR 4 Lug 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 3/31/2011 . • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 30, 2011 2:20 PM To: 'Gober, Howard' Subject: RE: 2V -09 (PTD #185 -037 Use of BOP Howard, Thanks for the BOP usage report. It fulfills the regulatory requirement for reporting BOP usage events. Good job on anticipating gas under the storm packer after the BOP test. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) AP 444 -3433 (cell) 5tAMED From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Wednesday, March 30, 2011 2:06 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Nordic 3 Company Man; Cawvey, Von; CPA Wells Supt; Senden, R. Tyler; Packer, Brett B; Toomey, Ian (Baker Oil Tools); Nelson, Erik Q Subject: 2V -09 (PTD #185 -037) Use of BOP Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 3/30/11 0300 WeII /Location /PTD Number: 2V -09 /Kuparuk River Unit/185- 037 /Sundry #311 -027 Rig Name: Nordic 3 Operator Contact: Howard Gober 907 - 263 -4220 howard.gober @conocophillips.com Operations Summary: The rig completed the weekly BOP test. We had drill pipe in the hole and had set a storm packer. Since the storm packer was in the hole 13.5 hours, gas built up underneath the storm packer. This condition was discussed and expected. The annular was closed at 0300 on 3/30/11 prior to releasing the storm packer. The drill string was screwed into the top drive and the packer was released. The annulus had 570 psi on it once the storm packer was released. The gas was bled off initially through the gas buster and then out to the tiger tank. We bullheaded seawater into the well to displace any remaining gas. BOPE Used: Annular preventer and Choke manifold valves 5, 6, and 2. Reason for BOPE Use: Control flow of fluids from the wellbore due to gas below the storm packer. Actions TakenITo Be Taken: After the well was shut in, the gas was bled off initially through the gas buster and then out to the tiger tank. Any remaining gas was swept from the wellbore by bullhead seawater down the well into the formation. We will finish our cleanout and POOH with the drill sting. Once on surface, we will set a test plug and test the BOP components that were utilized. We will be able to keep the well loaded with seawater during the test by feeding seawater into the casing valve. Please let me know if you have any questions or if you require more information. Thanks, 3/30/2011 • Page 2 of 2 • Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 CeII Howard_Gober @conocophillips.com 3/30/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 17, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 - OAR 3 () 2C RE: String Shot Record: 2V -09 Run Date: 3/17/2011 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 2V -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21300 -00 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. (�3 S r Anchorage, Alaska 99518 /`� Office: 907 - 273 -3527 Fax: 907-273-3535 , . J /`5 klinton.wood@halliburton.com REi i Date: 0,A Signed: (1, JJ Gm ifitrAt • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 18, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 tAiPAN.EDIAAR 3 02011 RE: Radial Cement Bond Log: 2V -09 Run Date: 3/17/2011 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 2V-09 Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21300 -00 Cement Bond Log 1 Color Log 50- 029 - 21300 -00 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 / $ - Cj 3 ,90515 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: MAP ?91 Signed: O.-. ,A4440 CAI Sta Ow. , 7::.),mrnimIlzit Anciampa • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 15, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAR ` C 2F 'f RE: Tubing Cut Record: 2V -09 Run Date: 3/14/2011 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 2V -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21300 -00 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 „90 <S Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.woo. l' Date: _ Signed: f f «r' N a ,7 lB',3 razi11tlG • WELL LOG TRANSMITTAL PROAcIivE DiA SERV CES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 r (907) 659 -5102 \AAR 3 ZQ RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MU) 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 J Q/ Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 d � � - o3 _®ff,94( ( .7 1] Caliper Report 15- Mar-11 2K -19 1 Report / EDE 50-103-20118-00 C . 2) Caliper Report 16- Mar -11 2V -09 1 Report/A. 2, Signed : Date : ma 2 3 ? "lji Print Name: comminkr Anthoraci3 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 88952 E - MAIL : pdsanchorac a cCr memorvioq.com WEBSITE : www.rrtemorvlog.corrt I I C: \Documents and Settings\Diane Williams \Desktop \CPAI_Transmit.docx ' • • Memory Multi- Finger Caliper • s Log Results Summary ' Company: ConocoPhillips Alaska, Inc. Well: 2V -09 Log Date: March 16, 2011 Field: Kuparuk ' Log No.: 10298764 ZX70 State: Alaska Run No.: 1 API No.: 50- 029 - 21300 -00 Pipet Desc.: 7" 26 lb. J -55 BTC Top Log Intvll.: Surface Pipet Use: Casing Bot. Log Intvll.: 7,686 Ft. (MD) ' Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : ' This caliper data is correlated to the SBL CBL dated 21- April -1985. This log was run to assess the condition of the casing with respect to corrosive and mechanical damage. The caliper recordings indicate the interval of 7 inch casing logged appears to be in good condition with respect to corrosive and mechanical damage. A maximum recorded wall penetration of 22% is recorded @ ' 7,375 ft. and no other significant wall penetrations, or areas of cross - sectional wall loss are recorded throughout the interval logged. An area of deposits is recorded at the very bottom of the log (7,385 ft.) with a minimum recorded ID of 5.94 inches. A 3 -D log plot of the interval of interest (7,142 ft. to 7,386 ft.) is included in this report. This summary report is interpretation of data provided by Halliburton Well Services. ' MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (22 %) Jt. 172 @ 7,375 Ft. (MD) ' No other significant wall penetrations (> 17 %) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: ' No significant areas of cross - sectional wall loss (> 2 %) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: ' Deposits Min ID= 5.94 ins. Jt. 172 @ 7,385 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing and liner logged. 1 1 ' Field Engineer: M. Biery Analyst: J. Thompson Witn ess: L. Hinkel ProActive Diagnostic Services, Inc. / 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 ' / 6 5 - - c . ) - 3 .g-b606l I 0 0 PDS Multifinger Caliper 3D Log Plot I (--- , ) Company : ConocoPhillips Alaska Inc Field : Kuparuk Well : 2V -09 Date : March 16, 2011 I Description : Caliper Recordings Across Interval of Interest Comments Depth Max. Pen. ( %) Max. I.D. (ins.) 3-0 Log Image Map I 1ft:180R 0 100 6 7 360° 0° 90° 180° 270° 0° M. 1.D. (ins.) 6 7 1 i6 Nominal I.D. (ins.) 7 I � • 7150 - ...... ......_ _...:_. I 7160 II Jt.167 .ice 7170 I 7180 ' I i, 111111111r a 7190 7200 ± - = — Jt. 168 -_. I 7210 • I 7220 I I I I 7230 1 • ' " '" 1 7240 ..c I 7250 . _ Jt.169 —_ I T I I 0 • I 7260 ■ ■Hill• ■■ - ■■11111■■ ■ ■ ■■ ■■*ira ■■■ ■ ■■ ■■Irlalf■■■■■■ ■ ■tJll■ ■ ■ ■ ■■ 7270 ■■Ell \ ■■■ ■ ■■ — ■ ■C� ■ ■■ '■■ . .. - ■ ■!Q ■ ■ ■ ■ ■■ „. I - 4 ",,,-_. 7280 ■■ ■ ■ ■ ■ ■■ ■ ■IEEE ■ ■ ■ ■■ ,-- ■ ■f Ili ■ ■ ■ ■ ■ � ■■EII•■ ■ ■ ■■ • ■ ■•J1• ■ ■ ■ ■M 7290 IIMIIIIMIIIMIIMMI ■■iJl■ ■ ■ ■■■■ ■■111la ■■■■■■ Jt.170 ■ ■!II! ■ ■ ■ ■ ■■ f I 7300 ■ ■i111• ■ ■ ■ ■ ■■ ■■E41 ■ ■■■■■ ',� ■ ■E111• ■ ■ ■ ■■ ■ ■Eller■ ■■■ I ■ ■!1!t ■ ■ ■ ■■ ■■l11U■ ■ ■■■ 7310 ■■i11■ ■■■■■ Ent y■■■■ NMI Iu�■■■■� - 1 ■■iir� ■..■ 7320 1 1111111111111 ■ ■ ■ ■ ■ ■■ ■ ■• ■��I� ■ ■ ■ ■■ ■■i1E!■■■■■M 7330 ■■•1a'a1■ ■■■■■ ■ ■t1l ■ ■ ■ ■ ■■ ■ ■!Il ■ ■ ■ ■ ■■ Jt.171 j ■■•Il ■■ A 7340 ■ ■f Ili■■■ ■■ ■ ■lif!■■ ■■■ - ■ ■UJLU■■ ■ ■■ ■■NJf!■■■■■ I .11111/111.111111111111 7350 .1.11.11111.1.11.111111 ±.. 1 ■■•1la■■■■■ ■ ■ill!■■■■■ ■ ■•JI ■ ■ ■ ■ ■■ ■■ill!■■■■ I 7360 - ■■[iIi•■■■■ — ■ ■!Il■ ■ ■�� IF M in ■■•Ji!■ ■■■■ II MN DEEM I Jt.172 7370 ' ■■Ell a•■■■ ■ ■ I EI■ ■■■■ ID = 5.94" ■ ■wlli ■ ■ ■■ ■■ Vl<!.!■ ■ ■■ : -- Winn - 7380 OM � . I 6 Nominal I.D. (ins.) 7 Min. I.D. (ins.) I s Comments Depth Max. Pen. ( %) 7 Max. I.D. (ins.) 3-0 Log Image Map I ' 1ft:180ft 0 1006 7 360° 0° 90° 180° 270° 0° I I I • • Correlation of Recorded Damage to Borehole Profile I a Pipe 1 7 in (36.5' - 7360.2') Well: 2V -09 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: March 16, 2011 I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 36 I t 25 1077 50 2159 I 75 3249 a I 45 E Z s II 6 Q 0 100 4260 p I 125 5320 I . 1 150 6405 r 172 7360 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 172 I I I • • I PDS Report Overview ,.. Body Region Analysis I Well: 2V-09 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 40 Hal No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7 in 26 ppf J -55 BTC Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7 ins 26 ppf J -55 BTC 6.151 ins 7 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 I 150 100 50 0 I 0 to 20 to 40 to over r 20% 40% 85% 85% 51` Number of joints analysed (total = 172) I 171 1 0 0 I Damage Configuration ( body ) C 1 0 101= r 5 I I 0 Isolated General Line Other Hole / 151 Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 4) 4 0 0 0 0 Bottom of Survey = 172 I I 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2V -09 Body Wall: 0.425 in Field: Kuparuk I Upset Wall: 0.425 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.151 in USA Survey Date: March 16, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 36 1) 0.03 7 1 6.25 2 76 O 0.02 4 I 6.23 • 3 120 1) 0.03 6 1 6.24 • 4 164 0 0.04 9 0 6.24 • 5 208 0 0.02 5 I 6.24 i I 6 251 0 0.03 6 I 6.24 7 295 O 0.01 3 1 6.25 1 8 338 0 0.01 4 1 6.24 9 382 0 0.01 3 0 6.26 I 10 424 0 0.01 3 1 6.26 11 467 0 0.03 7 1 6.23 12 511 0 0.03 7 1 6.25 U 13 554 0 0.02 5 1 6.24 1 I 14 598 O 0.01 3 0 6.26 I 15 641 0 0.02 5 1 6.24 16 685 O 0.04 9 1 6.24 11 17 729 0 0.04 10 1 6.22 U I 18 772 0 0.03 6 1 6.24 19 815 0 0.01 3 1 6.24 1 20 859 0 0.02 4 1 6.24 O 21 903 0 0.02 5 1 6.26 1 22 946 0 0.03 7 1 6.26 • I 23 990 U 0.02 6 1 6.26 24 1033 0 0.03 6 1 6.26 1 25 1077 0 0.02 4 1 6.26 26 1121 () 0.02 5 I 6.26 1 I 27 1164 0 0.02 5 1 6.24 28 1207 0 0.01 4 1 6.23 29 1249 0 0.02 4 1 6.26 1 30 1292 O 0.01 4 1 6.26 I 31 1336 0 0.01 3 1 6.25 I 32 1378 0 0.02 4 1 6.25 33 1421 0 0.02 4 1 6.23 34 1464 0 0.02 4 1 6.25 1 35 1508 0 0.02 5 1 6.27 i I 36 1551 O 0.03 7 1 6.23 • 37 1594 0 0.02 4 1 6.24 • 38 1638 0 0.02 4 1 6.25 1 39 1681 0 0.02 5 1 6.28 I 40 1725 0 0.02 5 1 6.24 41 1769 0 0.01 4 1 6.26 1 42 1812 0 0.01 3 1 6.25 I 43 1856 (1 0.02 5 1 6.26 I 44 1900 0 0.01 3 1 6.25 I 45 1942 O 0.02 5 I 6.28 46 1986 0 0.02 5 1 6.28 I 47 2029 0 0.01 2 1 6.26 I 48 2073 0 0.01 3 1 6.26 I 49 2115 50 2159 0 0.01 3 1 6.27 0 0.02 6 1 6.25 rat Body I I Metal Loss ion Body Page 1 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2V -09 Body Wall: 0.425 in Field: Kuparuk I Upset Wall: 0.425 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.151 in USA Survey Date: March 16, 2011 I Joint Jt. Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Iris.) (Ins.) % (Ins.) 0 50 100 I 51 2203 0 0.02 4 1 6.25 52 2246 0 0.02 5 1 6.23 53 2290 0 0.04 9 1 6.23 54 2334 0 0.02 5 1 6.25 I 55 2377 56 2421 0 0.03 6 1 6.23 0 0.03 7 1 6.26 57 2464 0 0.02 5 1 6.25 58 2508 0 0.03 , 6 1 6.22 59 2551 0 0.03 8 2 6.23 I 60 2595 0 0.02 4 1 6.24 61 2639 0 0.02 5 1 6.25 62 2682 0 0.02 5 1 6.22 63 2726 0 0.03 6 1 6.21 1 64 2770 0 0.03 7 1 6.23 65 2813 0 0.02 6 1 6.25 66 2856 0 0.03 6 1 6.25 67 2900 0 0.02 5 1 6.26 I 68 2944 0 0.03 7 1 6.25 69 2987 0 0.02 6 1 6.27 70 3031 0 0.02 5 1 6.24 71 3075 0 0.03 7 1 6.26 72 3118 0 0.02 5 1 6.26 L I 73 3162 O 0.02 6 1 6.24 74 3205 0 0.03 7 1 6.24 75 3249 0 0.03 8 1 6.25 76 3293 0 0.02 5 1 6.25 I 77 3336 78 3380 0 0.02 5 1 6.25 0 0.02 4 1 6.23 79 3423 0 0.01 3 0 6.28 80 3464 O 0.01 2 0 6.28 I 81 3505 0 0.01 3 1 6.27 82 3546 0 0.01 3 0 6.28 83 3582 0 0.01 3 1 6.29 84 3618 0 0.01 3 0 6.30 85 3659 0 0.02 4 0 6.27 I 86 3699 0 0.02 4 1 6.28 87 3736 0 0.01 3 1 6.29 88 3772 0 0.02 5 1 6.27 89 3813 O 0.02 5 1 6.28 I 90 3854 0 0.02 4 0 6.27 91 3894 0 0.02 4 1 6.27 92 3934 0 0.02 4 1 6.28 93 3975 0 0.01 3 1 6.28 I 94 4014 0 0.02 4 1 6.28 95 4055 0 0.02 4 0 6.29 96 4095 0 0.03 8 1 6.21 97 4139 0 0.03 6 1 6.25 I 98 4182 0 0.01 3 0 6.28 99 4223 0 0.01 3 0 6.28 100 4260 0 0.02 5 1 6.28 II Prat Meta Loss ion Body I Page 2 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26.0 ppf J -55 BTC Well: 2V -09 Body Wall: 0.425 in Field: Kuparuk I Upset Wall: 0.425 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.151 in USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 101 4301 0 0.01 3 0 6.28 102 4342 0 0.02 4 1 6.27 I 103 4382 0 0.01 3 1 6.27 I 104 4422 0 0.01 3 1 6.29 I 105 4461 0 0.01 3 1 6.28 106 4500 (1 0.01 2 0 6.29 107 4541 0 0.01 4 0 6.28 i 108 4581 0 0.02 5 1 6.26 109 4624 0 0.02 5 1 6.25 i I 110 4667 0 0.01 3 1 6.25 I 111 4711 0 0.01 3 1 6.2 7 1 112 4755 0 0.02 6 1 6.25 113 4798 0 0.02 4 1 6.26 I 114 4842 0 0.02 5 1 6.25 115 4885 0 0.02 5 1 6.24 1 116 4928 0 0.03 8 1 6.25 • 117 4972 0 0.03 6 1 6.26 I 118 5015 0 0.03 6 1 6.25 119 5059 0 0.03 7 1 6.26 120 5103 0 0.02 5 1 6.23 • 121 5146 0 0.02 5 1 6.25 122 5190 0 0.02 4 1 6.24 1 I 123 5233 0 0.01 3 1 6.25 124 5277 0 0.02 4 1 6.25 125 5320 0 0.02 5 1 6.25 i 126 5364 0 0.02 4 1 6.27 i I 127 5407 0 0.01 3 0 6.26 128 5451 0 0.01 3 1 6.25 I 129 5495 0 0.01 3 1 6.25 130 5538 0 0.03 6 1 6.25 0 131 5582 0 0.01 4 1 6.28 132 5625 0 0.02 4 1 6.27 133 5669 0 0.01 3 1 6.25 I 1 I 34 5713 0 0.02 4 1 6.25 I 135 5756 0 0.03 6 2 6.25 136 5799 0 0.04 8 1 6.24 • 137 5843 0 0.04 9 1 6.24 II • 138 5886 0 0.03 6 1 6.22 • 139 5929 0 0.05 11 1 6.22 l• I 140 5973 0 0.04 9 1 6.23 • 141 6016 0 0.03 7 I 6.24 • III 142 6060 0 0.03 6 1 6.22 143 6103 0 0.03 7 1 6.24 • I 144 6146 1) 0.03 8 1 6.21 145 6189 () 0.03 7 1 6.25 II • 146 6231 0 0.02 5 1 6.25 1 147 6274 0 0.02 5 1 6.23 I 148 6318 0 0.03 6 1 6.25 149 6362 0 0.03 7 1 6.25 • 150 6405 0 0.04 9 1 6.21 I Petrtb0n Body Metal Loss Body Page 3 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26.0 ppf J -55 BTC Well: 2V -09 Body Wall: 0.425 in Field: Kuparuk I Upset Wall: 0.425 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.151 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/t) wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 151 6449 0 0.02 4 1 6.25 152 6491 0 0.02 5 1 6.25 153 6534 0 0.02 4 1 6.27 154 6577 0 0.02 5 1 6.24 1 155 6621 0 0.03 7 1 6.24 I 156 6664 0 0.03 6 1 6.23 I 157 6708 0 0.02 6 1 6.23 II 158 6751 0 0.02 5 1 6.23 159 6795 0 0.03 7 1 6.25 I 160 6838 0 0.02 5 1 6.24 161 6882 0 0.03 6 1 6.24 1 162 6925 0 0.02 6 1 6.24 1 163 6969 0 0.02 6 1 6.24 I 164 7013 0 0.07 17 1 6.25 Shallow Pitting. (1 165 7056 0.03 6 1 6.24 NE II 166 7100 0 0.03 6 1 6.22 V 167 7143 0 0.07 17 1 6.25 Shallow Pitting. NM I 168 7186 0 0.02 6 1 6.24 169 7229 0 0.05 12 1 6.24 Shallow Pitting. IN 170 7273 0 0.03 6 1 6.26 1 171 7317 U 0.03 7 1 6.24 Im 172 7360 0 0.09 22 1 5.94 Isolated Pitting. Lt. Deposits. no I Penetrat Metal Loss ion Body I 1 1 I I I I Page 4 I I • • 1 PDS Report Cross Sections Well: 2V -09 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 40 Hal No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 ' Tubing: 7 in 26 ppf J -55 BTC Analyst: J. Thompson 1 1 Cross Section for Joint 172 at depth 7375.470 ft Tool speed = 49 ' Nominal ID = 6.151 Nominal OD = 7 Remaining wall area = 99% Tool deviation = 40° 1 1 1 1 1 Finger = 13 Penetration = 0.093 ins Isolated Pit 0.09 ins = 22% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 I s • I PDS Report Cross Sections I Well: 2V -09 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 40 Hal No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7 in 26 ppf J -55 BTC Analyst: J. Thompson I I Cross Section for Joint 172 at depth 7384.570 ft Tool speed = 49 Nominal ID = 6.151 _ I Nominal OD = 7 Remaining wall area = 100% Tool deviation = 40° �. 1 I I 1 c , , I I I Minimum I.D. = 5.940 ins Deposits Min ID = 5.94 ins HIGH SIDE = UP I I I I I € KUP 2V -09 ConocoPhillips 104 Attributes Mingle &MD TD Wellbore APl/UWI Field Name Well Status Intl (°) MD (RKB) Act Biro (RIB) conoa,r+,ap: 500292130000 KUPARUK RIVER UNIT PROD 47.36 2,125.00 8,100.0 " ° Comment H2S (ppm) Date Annotation End Date KBihr! (R) Rig Release Date SSSV: LOCKED OUT 45 • °• Wet Confi¢ -20 -09 1/21/201110'.54'.33 AM - - - - - - - m - - -- - - __- schematic - Actual Annotation Depth (flIB Elutl Dat Ann 1/17/2010 otation W 34.98 3/25/1985 Las[ WO: last Mod ... End Date Last Tag: SLM 7,815.0 10/8/2010 Rev Reason: RP RKB DEPTH Imosbor 1/21/2011 Casing Strings Casing Description String 0... String ID ... Top (p03) Set Depth (f... Set Depth (TVD)... String Wt... Stung... Stung Top Thrd „ CONDUCTOR (QC) 16 15.062 34.6 102.0 102.0 65.00 H WELDED i Casing Description String 0._ String ID RIB ... Top () Set Depth (L.. Set Depth (ND) ... String Wt.. String ... Stung Top Thrd SURFACE(QC) 95/8 8.921 34.6 3,617.1 2,924.0 36.00 J BTC Siring Casing Description 0... String ID ... Top (1KB) Set Depth (L.. Set Depth (ND) ... Siring Wt... String... String Top Thrd CONDUCTOR PRODUCTION (QC) 7 6.151 31.0 8,054.5 6,126.4 26.00 J BTC (OM. 35 -102 SAFETY Tubing Strings 1.911 Tubing Description String 0_. String ID... Top (I MB) ! Depth (f._ Set Depth(TVD)... Skiing WL.. Stri ng... Strin Top Thrd i TUBING 3 1/2 2.992 0.0 I 7,749.0 I 5, 894.1 I 9 I J - 55 8RD EUE IPrC Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 2 169 (ND) Top Ind Top (RIB) (RKB) (°) Desaipdon Comment Run Date Si Or4 I 1,911.0 1,716.1 4534 SAFETY VLV Baker'FVL' (LOCKED OUT 1/22/2004) 4/30/1985 2.812 2,169.0 1,893.1 46.28 GAS LIFT CAMCO/ KBUG /1 /GLV /BK/.25/1379/ Comment: BROKEN 1/2/1996 2.875 SURFACE J LATCH STA 1 (OC), 35 3,642.0 2,942.1 43.76 GAS LIFT CAMCO/KBUG/1/DMYBK/// Comment: STA 2 10/9/2010 2.875 GAS LFT, 3 3,842 4,494.0 3,553.2 45.57 GAS LIFT CAMCO/KBUG/1 /GLV /BK/.25/1351/ Comment BROKEN 1/2/1996 2.875 LATCH STA 3 I GAS LIFT, 4 3,842.3 46.89 GAS LIFT CAMCO /KBUG/ 1/DMY/BK// /Comment: STA4 10/10/2010 2.875 aria 5,347.0 4,151.0 45.39 GAS LIFT CAMCO/KBUG/lIDN1Y /BK!! / Comment STA 5 11/22/1995 2.875 5,760.0 4,443.7 45.80 GAS LIFT CAMCO /KBUG/1 /DMY /BKJ // Comment STA 6 1/24/2004 2.875 GAS LIFT, 6,173.0 4,738.3 44.26 GAS LIFT CAMCO/KBUG/1/DMY/BK/ /!Comment: STA 7 10/10/2010 2.875 4 908 I 6,616.0 5,055.3 43.89 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 8 10/10/2010 2.875 7,028.0 5,349.9 43.73 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 9 GAS LIFT, 5,347 ) 7,380.0 5,611.7 39.87 GAS LIFT CAMCO/MMG-2/i.5IDMY/RK/l/ Comment STA 10 5/22/1990 2.875 1/23/2004 2.920 7,420.0 5,642.3 39.65 PBR Baker 4/30/1985 3.000 GAS LIFT, 7,433.0 5,652.3 39.86 PACKER Baker 'FHL' PACKER 4/30/1985 3.000 i 5,780 7,450.0 5,665.3 40.01 PLUG WRP @RKB DEPTH 11/19/2010 0.000 Gas LFT 1 8.8 7,472.0 5,682.2 39.97 PRODUCTION CAMCO /MMG- 211 .5 /CV /RKP /// Comment OPEN STA 11 12/24/2008 2.875 0 .179 7,543.0 5,736.6 39.87 PRODUCTION CAMCO /MMG- 211.5/DMY BROKE/RK/ / /Comment: 11/28/1989 2.875 CLOSED STAl2 GAS LFr, 16 i 7,639.0 5,810.5 40.46 PATCH 21' Merla Tbg Patch; Set 11/6/95 11/6/1995 2.375 7,689.0 5,848.5 40.47 PATCH 21' Melia Tbg Patch; Set 11/6/95 11/6/1995 2.375 GAS LIFT. 7,706.0 5,861.4 40.44 PRODUCTION CAMCO/ MMG- 2/1.5/PATCH/FiK/ /l Comment CLOSED 11/6/1995 2.875 7.028 ( STA 13 GAS LIFT, 7,727.0 5,877.4 40.45 PACKER Baker 'FB -1' PACKER 4/30/1985 4.000 7.380 7,741.0 5,888.0 40.46 NIPPLE Camco'D' Nipple NO GO 4/30/1985 2.750 i . 7,741.0 5,888.0 40.46 NIPPLE Camco NIPPLE REDUCER Camco 11/5/1995 2.250 PBR, 7,420 I I 7,748.0 5,893.4 40.46 SOS REDUCER 4/30/1985 2.992 PACKER. 7 433 _ _ _ 7,749.0 5,894.1 40.46 TTL ELMD TTL @ 7737' during PPROF on 07 /08/2000 4/30/1985 2.992 PLUG, 7,450 Perforations & Slots ' Shot Blm(ND) Dens PROWC _ Top (f903) Dim CBI IRKBI 0003) Zone Date Oh- type Comment 7,472 - 7.592.0 7,6546 5,774.3 5,821.9 C -4, C -3, C-1, 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser UNIT B, 2V -09 Hyperdome i PRODUCTION, 7.5543 I 7,668.0 7,675.0 5,832.5 5,837.9 UNIT B, 2V -09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser 43 Hyperdome 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B, 2V-09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser Hyperdome IPERF' 7 7,792.0 5,916.2 5,926.9 A4, 2V -09 4/28/1985 4.0 IPERF 120 de phasi 4" Dresser 7.592 -7,656 9' n9' PATCH, 7.639 Hyperdome 7,805.0 7,840.0 5,936.8 5,963.4 A -3, 2V -09 4/28/1985 4.0 IPERF 120 deg. phasing, 4" Dresser IPERF, Hyperdome 7,888-7,875 N otes: General & Safety End Date Annotation IPERF 3/1/2006 NOTE: PPROF IDENTIFIED C - SAND TBG LEAK 7631' 7682 - 7.686 � @ PATCH, 7689 I 12/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PRODUCTION. I., 7,706 I It I PACKER. 7,727 i Mandrel Details Top Depth Top Port NIPPLE,7741 ITt/D) Inc! OD Valve Latch Size TRO Run NIPPLE Stn Top (RKB) (RKB) I Make Model (in) sery Ty Type On) (Psi) Run Date can.. REDUCER. ;11.111t 1 2,169.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,379.0 1/2/1996 Brok... ,7x1 ■ Latch SOS 7,748 El 2 3,641.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/9/2010 i 3 4,493.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,351.0 1/2/1996 Brok... TTL, 7 749 Latch 4 4,908.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 7,na I 5 5,346.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/22/1995 IPERF. 6 5,760.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/24/2004 7,806 7 6,173.0 9 7,027.9 CAMCO KBUG ra44AM(R5 it$UG 1 GAS LIFT DMY BK 0.000 0.0 10/70/2010 8 6,615.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 TD, 8,100 PRODUCTION (oc).31a.o55� H. Gober 1 GAS LIFT DMY BK 0.0[0 2 0.6 S'22/1990 I II KUP 2V -09 ConocoPhillips Ca.oaoniap4 - -' -- ^ ^- KB-Grd (ft) Rig Release Date I • -- well COnba: -2v -09 1/21/201110 54 33 PM 34.98 3!25/1985 Schematic - Actual J I CONDUCTOR (SC), 35 -702 02 SAFETY VLV. o f 1,911 I GAS LIFT, 2,169 I SURFACE ,J L (DC), 353617 GAS LFT, 3,842 I GAS LIFT. }. 4,494 GAS LIFT, 4.908 E I GAS LFT, 5,347 [ GAS LFT. } 5.760 I GAS LFT. 1 6,173 GAS LFT, 6.616 II GAS LFT, 7.028 : r GAS LFT, 7,380 PPR.7420 I I 1 PACKER. 7,433 _ • I PLUG, 7,450 LI Mk PRODUCTION, 7,472 I PRODUCTION, I 7543 PERF, I 7,592 -7,854 PATCH, 7.639 -7075 706s-7075 • 7.68 -7 PERF .686 I . _ PATCH. 7889 - . PRODUCTION, I II c 7,706 g I PACKER, 7.727 Mandrel Details Top Depth Top Port I NIPPLE. 7.741 (TVD) ICI OD Valve Latch Size 7R0 Ow) NIPPLE $hl Top es) Ind) (1 Make Mpael PM sent Type 1 YPe (In) Ip51) Rtn Date CpR_ 0.0 1/23/2004 REDUCER, 7 CAMCO MMG2 1 112 GAS LIFT DMY RK 741 11 7,471.8 CAMCO MMG-2 1 1/2 PROD CV RKP 0.000 0.0 12/24/2008 Open SOS, 7,744 12 7,543.2 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 1128/1989 Closed I TTL, BROKE 7.749 �_ 13 7,706.6 CAMCO MMG2 1 12 PROD PATCH RK 0.000 0.0 11/6/1995 Closed IPERF, 7,778-7,792 IPERF. 7805-7.840 P ROC ION i , 1 1' 3DU1 -6.66 NH. Gober Page 12 of 32 March 2, 2011 TD, 6,100 1 • • SITEE iii [F ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Howard Gober 6 VVI Wells Engineer �� 3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99501 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2V -09 Sundry Number: 311 -027 Dear Mr. Gober: 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 holi or weekend. Sinc 1 1 Mk / . ■ orman m -• ' sioner DATED this ''day of February, 2011. Encl. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 1, 2011 ta sp,s �►�liS -9 ff tjskin Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2V -09 (PTD 185 -037). 2V -09 was originally completed in 1985. The well is a selective single gas lifted producer completed in the Kuparuk A and C sands. The well has been impacted by surface subsidence. A MIT of the outer annulus failed on 4/26/10. Since the well has exhibited minor IAxOA communication, gas lift was discontinued. Unfortunately, the well is not able to produce without the help of artificial lift. The well was freeze protected and shut in on 10/8/10. A plug was set on 11/19/10 to isolate the reservoir, and the well is awaiting a rig workover. The condition of the well is as follows: Tubing — can be drifted. Plug set at 7450' RKB isolating the reservoir 7" Casing — CMIT TxIA passed 7/11/10 9 -5/8" Casing — MIT -OA failed. Hole estimated to be at 264' RKB The shut -in bottom hole pressure was measured on 11/2/10 with the A and C sands both open. At the mid point of the A sand perfs the SBHP was measured at 2560 psi. Utilizing this SBHP, KWF is estimated to be 8.7 ppg with a 125 psi overbalance. The MASP is 1966ssi based upon • the SBHP. The objective of this workover is to replace the tubing, cut & pull a portion of the 7" casing, re -run • new 7" casing, and circulate cement into the 9 -5/8" x 7" annulus. The 7" casing work is not required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. If you have any questions or require any further information, please contact me at 263 -4220. Sincerely, Howard B. Gob r Wells Engineer CPAI Drilling and Wells STATE OF ALASKA ALASKO AND GAS CONSERVATION COMMISSI1 a 4).11 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well por Change Approved Program Suspend r Rug Perforations r Perforate r' Pull Tubing F Time Extension Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing 1' Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 185 -037 3. Address: Stratigraphic r Service 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50- 029 - 21300 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 2V -09 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25644 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8100 • 6161 7974' 6070' 7450' Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 102' 102' SURFACE 3582 9.625" 3617' 2924' PRODUCTION 8024 7 8055' 6126' Perforation Depth MD ( 7592' - 7654', Perforation Depth ND (ft): 5774'- 5822', Tubing Size: Tubing Grade: Tubing MD (ft): 7668' 7675', 7682' 7686', 7778' 7792', 7805 5833' 5838', 5843' - 5846', 5915 5927', 5937 3.5 J - 55 7749 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER 'FHL' PACKER MD= 7433 TVD= 5652 PACKER - BAKER 'FB -1' PACKER MD= 7727 TVD= 5877 SSSV - BAKER 'FVL' (LOCKED OUT 1/22/2004) MD= 1911 TVD= 1716 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: r Detailed Operations Program BOP Sketch r Exploratory Development ,, Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2011 Oil Gas WDSPL fl Suspended 16. Verbal Approval: Date: WINJ l` • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263 -4220 Printed Name Howard Gober Title: Wells Engineer Signature Phone: 263 -4220 Date Z/1 i I Commission Use Only Sundry Number: ✓ ✓ ✓✓ ✓� I — Conditions of approval: Notify Commission so that a representative may witness Elsa P� 1pi I, 0 Plug Integrity BOP Test Mechanical Integrity Test "" Location Clearance 1 Or 3000 5 40P o s 1 --- Other: t- i t 2Soo psi h �n l : 'RIO glt i,? fi 0fis, Cr 'ssion Subsequent Form Required: l 0 _NQLI it APPROVED BY "11`5- 11 //( Approved by: MOMS COMM! - - - THE COMMISSION Date: d Form 10 -403 Revised W 1 k o Ltit'4 R I G I N A L. z' , Subm in Duplicate i024/1/ 2V-09 Expense Rig ense -09 Ex Ri Workover • (PTD #: 185 -037) Current Status The well is currently shut in awaiting a workover to replace the tubing and to proactively repair the 7" • production casing. This well is located in an area with surface subsidence. A plug has been set to isolate the reservoir. The production casing is competent based on a passing CMIT to 2525 psi on 7/11/10. The surface casing has a leak estimated to be at -264'. Scope of Work Pull the tubing, proactively cut & pull a portion of the 7" casing, re -run new 7" casing, circulate cement into the 9 %" x 7" annulus, and run new 3 -1/2" tubing. General Well info MASP: 1966 psi Reservoir pressure/TVD: 2560 psi / 5,940' TVD Mid A sand pert Wellhead type /pressure rating: FMC KRU Gen 3, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams IA / OA Status: CMIT TxIA to 2500 passed on 7/11/10, OA leak estimated at 264' RKB Well Type: Producer Estimated Start Date: March 1, 2011 Production Engineer: Mike Balog / Evan Reilly Workover Engineer: Howard Gober (263 -4220 / howard.gober @conocophillips.com) Pre -Riq Work 1. RU slickline. Set catcher sub on WRP at 7450' RKB. Pressur RP-to 3000 psi. Pull DV at 7380' RKB and leave pocket open. 2. Bleed Tubing, IA, and OA to 0 psi. 3. Set BPV. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Load tubing and IA with 8.7 ppg brine through open DV at 7380' RKB. Verify well is dead by watching for flow from the tubing and IA for a minimum of 30 min. KWF requirement is 8.7 ppg based on a SBHP taken at mid A sand perfs on 11/2/10. Set BPV. ND tree. Install blanking plug in hanger threads. NU 11" 5M BOP and adapter spool. Pressure test BOP including annular to 250/3000 psi. Maximum potential surface pressure is calculated to be 1,966 psi based upon the SBHP obtained on 11/2/10 and using a 0.1 psi /ft gas gradient. 3. Pull blanking plug and BPV. Pull tubing out of PBR and circulate hole clean. Pull and lay down tubing. A. If tubing does not pull free, set tubing in tension. RU E -line and cut tubing at +/- 7,400' RKB (between bottom GLM and PBR). POOH laying down tubing. 4. Run 7" scraper on drillpipe to top of PBR. Circ hole clean. POOH. 5. RU E -Line: Run caliper log, gyro survey, and cement bond log in 7" casing from PBR to surface. Based on cement top, determine depth of 7" collar to back off following casing cut. RIH and fire string shot across that collar. RD E -Line. 6. Set RBP or IBP below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. 7. RIH w/ muleshoe on drillpipe and spot 50' of sand on top of RBP /IBP. POOH. 8. ND BOP. Install long all- thread bolts on wellhead. Begin ND tubing head allowing 7" casing to grow. ✓ • 2V -09 Expense Rig Workover (PTD #: 185 -037) -Proposed Procedure Continued - 9. Remove tubing head and packoffs. Spear 7" csg and pull in tension and re -land in slips. Tack weld slips to casing. RU Wachs cutter and cut off casing so it does not interfere with BOP stack. 10. NU 11" 5M BOP on casing head. BPPE is now considered adiverter_due to surface casing leak syspected to be at -264' RKB. A pressure test cannot be performed on the BOP at this time. 11. RIH w/ multi- string cutter and cut 7" casing above TOC. 12. Spear casing and circulate out Arctic Pack in the 9 -5/8" x 7" annulus using hot diesel followed by hot seawater. 13. POOH laying down 7" casing. 14. Set test plug and test BOP to 250/3000 psi. 15. Run 9 -5/8" casing scraper to top of 7" stub. Circulate clean. 16. RU E -Line: Run GR, caliper, and gyro in 9 -5/8" casing. RD E -Line. 17. Run back off tool and back off casing stub. 18. Run tandem string mills to gauge the 9 -5/8" csg for the ES cementer. 19. Make a dummy drift run for the 7" casing & ES cementer. 20. Spear and recover backed off 7" casing stub. 21. Change lower pipe rams to 7 ". Pressure test BOP to 250/3000 psi.-" 22. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. PT casing to 3000 psi. 23. Open ES cementer and pump cement into 9 -5/8" x 7" annulus. Close the IA once cement returns at surface and squeeze cement into SC leak. Continue to pump cement until plug closes cementer. WOC. 24. ND BOP, pull 7" casing in tension and land in slips. Cut excess 7" casing and install packoff. NU new tubing head. 25. NU 11" 5M BOP, change out lower pipe rams to VBR's. PT rams and break to 250/3000 psi. 26. Drill out cement and ES cementer down to top of sand. Pressure test casing to 2500 psi. 27. RIH w/ reverse circulating junk basket and string magnets to clean up wellbore. 28. RIH w/ retrieving tool on work string. Release RBP /IBP and POOH. 29. RIH with seal assembl without seals stack sacker, PBR, and new 3 -1/2" tubin•. Circulate well full of corrosion inhibited fluid. Stab into PBR, drop ball & rod, and set packer. Shear PBR. Space out and land hanger. Pressure test tubing and IA to 3000 psi. Shear SOV. 30. Set 2 -way checK(ND BOP. NU tree and pressure test. 31. Pull 2 -way check. Freeze protect well. Set BPV. 32. RDMO Nordic 3. Post Riq Work 1. RU Slickline: Pull ball and rod. Pull SOV and run new gas lift design. Pull RHC body. Pull catcher ✓ sub and WRP at 7450' RKB 2. Return well to production. ~ KU P . 2V -09 3 Conoc 11 {fit _Well Attributes Max Angle & MD TD i 1tY,` Wellbore APUUWI Field Name Well Status Inc! ( °) IMD (ftKB) Act Btm (ftKB) 40npcQt916it ; ' 500292130000 KUPARUK RIVER UNIT PROD 41.36.1. 2,12500 8,1000 Comment IH2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV: LOCKED OUT I 45 1/17/2010 Last WO: 34.98 3/251985 R Cn 11210/01118s4;33 mom- ' -- __ -_ - - SN>k9a6ic AGlual _. AM _ � Annotation Depth (ftKB) End Date (Annotation Last Mod ... End Date Last Tag: SLM 7,815.0 10/8/2010 Rev Reason: WRP RKB DEPTH Imosbor 1/21/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. 'String Top Thrd i CONDUCTOR (QC) 16 � 15.062 34.6 102.0 102 0 65.00 H WELDED _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) .. String Wt... String .. String Top Thrd SURFACE (QC) 9 5/8 8.921 34.6 3,617 1 2,924.0 36.00 J BIC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... ,. Stri ng Top Thrd CONDUCTOR__ PRODUCTION (QC) 7 6.151 31 0 8,054.5 6,126 4 26.00 J I BTC (QC), 35 -102 SAFETY VLV, Tubing Strings - _ -. 1,911 :: Tubing Des iption (String 0 String ID ._ Top (ftKB) Set Depth (f_- 'Set Depth (TVD) String Wt String Str ng ... 'String Top Thrd TUBING 31/2 2.992 0.0 77490 1 1 5894.1 9 .30 1 J55 8RD EUE IPC Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 2,169 (TVD) Top Inc! Top(t6C65 (ft") (°) Description Comment Run Date ID (in) 1,911.0 1,716.1 45.34 SAFETY VLV Baker 'FVL' (LOCKED OUT 1/22/2004) 4/30/1985 2.812 2,169.0 1,893.1 46.28 GAS LIFT CAMCO /KBUG/1 /GLV /BK/,25 /1379 /Comment: BROKEN 1/2/1996 2.875 (00), 35 - SURF3,817 ACE _ _ ` LATCH STA 1 _ 3,642.0 2,942.1 43.76 GAS LIFT CAMCO /KBUG/1 /DMY/BK/ // Comment STA 2 10/9/2010 2.875 GAS LIFT, i.. 3,642 4,494.0 3,553.2 45.57 GAS LIFT CAMCO /KBUG /1 /GLV /BK/.25 /1351 /Comment. BROKEN 1/2/1996 2.875 LATCH STA 3 4,908.0 3,842.3 46.89 GAS LIFT CAMCO /KBUG/1 /DMY /BK// /Comment: STA4 10/10/2010 2.875 GAS LIFT, 4,494 5,347.0 4,151.0 45.39 GAS LIFT ''CAMCO /KBUG/1 /DMY /BK/ // Comment STA 5 11/22/1995 2.875 5,760.0 4,443.7 45.80 GAS LIFT CAMCO /KBUG/1 /DMY /BK// /Comment STA 6 1/24/2004 2.875 GAS LIFT. 4 sob 6,1173.0 73.0 4,738.3 44.26 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment STA7 10/102010 2.875 875 6,616.0 5,055.3 43.89 GAS LIFT CAMCO /KBUG/1 /DMY /BK// /Comment STA8 10/10/2010 2.875 '' 7,028.0 5,349.9 43.73 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment STA9 5/22/1990 2.875 GAS LIFT, 5,347 7,380.0 5,611.7 39.87 GAS LIFT CAMCO /MMG- 2 /1.5/DMY/RKU/ Comment STA 10 1/23/2004 2.920 7,420.0 5,642.3 39.65 PBR Baker 4/30/1985 3.000 GASLIFT,_ i - 7,433.0 5,652.3 39.86 PACKER Baker'FHL' PACKER 4/30/1985 3.000 5,760 5,665 �_�.. 7,450.0 .3 40.01 PLUG WRP @ RKB DEPTH 11/192010 0.000 GAS LIFT, . 7,472 0 5,682.2 39.97 PRODUCTION CAMCO /MMG - 2/1.5 /CV /RKP /// Comment OPEN STA 11 12/24/2008 2.875 6'173 7,543.0 5,736.6 39.87 PRODUCTION CAMCO /MMG- 2/1.5/DMY BROKE/RK/ // Comment 11/28/1989 2.875 CLOSED STA 12 GAS LIFT, ::: 7,639.0 5,810.5 40.46 PATCH 21' Merle Tbg Patch; Set 11/6/95 11/6/1995 2.375 6,816 i',, 7,689.0 5,848.5 40.47 PATCH 21' Meda Tbg Patch; Set 11/6/95 11/6/1995 2.375 GAS LIFT, . . 7,706.0 5,861.4 40.44 PRODUCTION CAMCO/MMG -2/1 Comment: CLOSED 11/6/1995 2.875 7,020 STA 13 GAS LIFT, ,.. 7,727.0 5,877.4 40.45 PACKER Baker 'FBA' PACKER 4/30 /1985 4.000 7'300 7,741.0 5,888.0 40.46 NIPPLE Camco'D' Nipple NO GO 4!3011985 2.750 7,741.0 5,888.0 40.46 NIPPLE Cameo NIPPLE REDUCER 11/5/1995 2.250 PBR, 7,420 REDUCER 7,748.0 5,893.4 40.46 SOS Cameo 4/30/1985 2.992 PACKER, 7,433 7,749.0 5,894.1 40.46 TTL ELMD TTL @ 7737' during PPROF on 07/08/2000 4/30/1985 2.992 Perforations & Slo LA/ • , PLUG, 7,450 -- Shot Top (TVD) Btm (TVD) Dens PRODUCTION, Top (RKB) Ban (ftKB) (RKB) (ftKB) Zone Date )nh -- Type Comment 7,472 4 7,592.0 7,654.0 5,774.3 5,821.9 C-4, C -3, C -1, 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser ■ ■" UNIT B, 2V -09 Hyperdome PRODUCTION, - 7,668.0 7,675.0 5,832.5 5,837.9 UNIT B, 2V -09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser 7,543 _ Hyperdome 7,682.0 7,686.0 5,843.2 5,846.2 UNIT B, 2V -09 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser Hyperdome IPERF, 7,592 - 7,654 . 7,778.0 7,792.0 5,916.2 5,926.9 A 2V 428/1985 4.0 IPERF 120 deg. phasing; 4" Dresser PATCH, 7,639 - -...6 - Hyperdome - r ;'. 7,805.0 7,840.0 5,936.8 5,963.4 A - 3, 2V 4/28/1985 4.0 IPERF 120 deg. phasing; 4" Dresser IPERF, •- ' «s Hyperdome 7.668 - 7.675 f • Z-1 _ -. -_.. 1. ___ _..... Notes: General & Safety End Date iL Annotation _- - - - -- -- 7,6827656 3/1/2006 I NOTE PPROF IDENTIFIED C -SAND TBG LEAK @ 7631' 12/8/2010 NOTE: View Schematic w/ Alaska Schematic9. PATCH, 7,688 PRODUCTION, 7,706 ' PACKER, 7,727 -- Mandrel Details ' . --. Top Depth Top I _ Po, . S °`,,, . NIPPLE, 7,741 '( (TVD) Inc! OD V l e Latch S TRO Run NIPPLE %% Stn Top (ftKB) (ftKB) _1 ") Make Model (in) se. v _ Type Type ('n) (Pe)) Run D to Can... REDUCER, 1 2,169 CAMCO KBUG 1 GAS LIFT GLV BK ,4250 1,379.012/1896 Brok... 7,747 Latch SOD 7740 51. 2 s L a (4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/9/2010 I 3 4,493.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,351.0 12/1996 Brok... TTL, 7,749 - ,, Latch _ 4 4,908.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 IPERF, 5 5,346.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/22/1995 a . 7,778 -7,792 ` IPERF, 6 5,760.1 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/242004 7,805 - 7,e40 - 7 6,173.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0 0 10/102010 PRODUCTION ' 8 6,615.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2010 (OC),37 �,_, I 9 7 CAMCO KBUG 1GAS LIFT DMY BK 0.000 005/22/1990 70 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 22, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2V -09 Run Date: 11/19/2010 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 2V -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21300 -00 UEC 13 N10 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 -n r klinton.w n com Date: Signed: 8s 6 GO • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2V-09 Run Date: 7/9/2010 • July 16, 2010 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 2 V-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21300-00 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 rafael.barreto ~ r Date: ~ ~ S- 03'~ ~~9~l~/ sill '~ €~. ,~ Signed: • • Page 1 of 1 Regg, James B (DOA) (~i D ~ g5 -~ ~ ~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, April 16, 2010 6:10 PM ~~~ ¢~~~I to To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2V-09 (PTD 185-037) Report of suspect SC leak Attachments: 2V-09 schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 2V-09 (PTD 185-~7) has a suspected surface casing leak at approximately 264'. The TIO is 200/1290/90. Currently the well is under evaluation for further action. Attached is a 90 day TIO plot and schematic. 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: ~ R Cf j, °i ~f ~'~i 4/19/2010 KRU 2V-09 PTD 185-037 4/16/2010 TIO Pressures Plot 3000. zoo. 3000. 300~J. ~- 3000. 0. 0. 0. 0. 0. n. 0. SC 3000 2700 2400 2100 1000 1500 1200 9D0 6DD 300 n WELL NAME WLKRU2V-09 - - r- ~- f _ _**# 1. - A _ *t t t 4r~- k ~ lam- _~t PLOT START TIME MINOR TIME 08-JAN-10 11:19 MAJOR TIME WEEK PICK TINE: TiG NINE DESCRIPTION WL2V-09-CHOKE FLOW TUBING CHOKE SCRATCH 55 FLOW TUBING PRESSURE SCRATCH_55 FLOW TUBING TEMP AI-P2V5002-09 GL CASING PRESSURE SCRATCH_55 INNER ANNIJLUS PRES SCRATCH_55 OUTER ANNULUS PRES PL.(YI DIIRATI:ON PL(h' EtdD 'I'iME ~~ +02160:OO:Ot1 HRSOB-APR-10 11:19 0 11:17:3 2 ~~~~~ ~ ~hF.TQF' >>>>~>> i.A'tEST PREY WELL DRILLSITE WELL ??????? 2v 0 9 ??????? NEXT WELL ??????? ??????? ENTRY 'T'YPE OPERATOR ??????? ~ OPERATOR VERIFIED ?7?7??? ~ SYSTEM AUTO ENTRY ??????? ~ BOTH u u ~_, ~ --'~, KUP 2V-09 ! ~~ ~QCtOCt~PFtl~~l S ~ Well Attributes ___ __ _ ax Angle 8 MD STD ~ Wellbore APIIUWI Field Name Well Slatun Incl1 ! MD tItK6! Act Btrn (ftKB) '~''`I""1 ! 500292130000 KUPARUK RIVER UNIT PRODUCING 46.80 2,100.00 8,100.0 Comment HYS (ppm) Date Annotation Entl Date KB-Grd (k) Rig Release Date "' SSSV: LOCKED OUT 90 1/13/2009 Lasf WO: 34.98 3/25/1985 Well on(i '. ~ J-OJ 6125120093'.36'.58 PM - scnemalic ~ AcWel Annotation Depth (kK8) End Date Annontion last Mod By End Date 7 ~ Last Tiangg: SSLM 7,805.0 6/24/2009 Rev Reason: TAG SLM. EST_ 5' RATHOLE Mplwj 6/2612009 CONDUCTOR, ~ g I ~ 3 I ~ ~ Ca9 tI' n g^ -~ StritinlOD r Str(i^ ID rep rfncBl Sa(ttKBlth Set DI~pKg'ND) S;IbsMtl t Gratle Strinn Too Thrd ' 102 9 SAFETY VLV, 1,911 GAS LIFT, 2.189 SURFACE, 3,617 GAS UFT, 3.642 GAS LIFT, 4,494 GAS LIFT, 4,900 GAS LIFT, 5,347 GAS LIFT, 5,760 GAS LIFT, 6,173 GAS LIFT, 6,816 GAS LIFT, 7,028 GAS LIFT, 7,380 PBR, 7,420 PRODUCTION, 7,543 IPERF, • 7,592-7,fi54 PATCH, 7,fi39 IPERF, 7,668-7,675 IPERF, • 7,682-7,686 PATCH, 7,689 PRODUCTION, 7,708 1 ~O~ _~a -,7 } 1 r ~-,] Tubing_Strin ' String OD ' Sring ID Set Depth Set Depth (TVO) Strang Wt ' Jtring (in) (in) Top (ttKB) (kKB) (ftK8) (Ibsl7t) ~ Grade String Top Thrd 31/2 2.992 0.0 7,749.0 5,9002 9.301,)-55 8RD EUE IPC UI Jewel : Tubin Run & Retrievable, Fish_ etc.)_ ~ Top Incl (°) Description Comment Run Date ID (in) TCH STA 1 rMCO/KBUG IMCO/KBUC~ TCH STA 3 STA 12 STA 13 i 1f:~Ba1T PACKER, 7,727 4 NIPPLE, 7,741 NIPPLE REDUCER, ],741 t 305, 7,748 j TTL, 7,749 IPERF, - 7,778-7,792 IPERF, 7,805-7,840 ~ " PRODUCTION. 8,055 TD, 8,100 REDUCER 1 7,7491 5,900.2 40.46~TTL ELMD TTL @ 7737 during PPROF on 07/U6lL000 ~a7sunydD z.aaz Perforations 8 Slots _ _ __ _ _ --- - -- -- Shot Top (TVD) Btm (TVD) Dens Top (kKB) Btm (kKB (kKB) (kKB) lone Data (sh..• T Pe Comment 7,592 7,654 5,780.4 5,828.0 C-4, C-3, C-1, 4/28/1985 12.0 IPERF 120 deg. phasing, 5" Dresser UNIT B, 2V-09 Hyperdome 7,682 7 Notes: General & " fl ,; i , _.. {{ pp ~~ . NO. 5005 Schlumberger -DCS • 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 _ Attn: Christine Mahnken ~t~:"', ~ r; r~r ATTN: Beth ~= ;~R ~ .,, ° ;~~.t~ ~ ~'~~„~;, .F 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 12/17/08 Well Job # Log Description Date BL Color CD 2X-10 11978476 PRODUCTION PROFILE / - / 08/17/08 1 1 V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-O6A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE ~ '~- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE ~- 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / 11/28/08 1 1 30-01 12097434 LDL -Q 11/29/08 1 1 1E-04 12097436 LDL T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE ~ - 11/27/08 1 1 iH-16 12096581 PRODUCTION PROFILE ~ - _ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE L - j 12/02/08 1 1 iG-O6 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE - 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE I 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE "' ~ 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE „_, ~ = 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~~~ ,~U G ~ ~ 200$ Dear Mr. Maunder: r1 LJ Enclosed please find a spreadsheet with a list of wells from the Kuparulc field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from 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. The cement was pumped June 30, July 4, and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ ,,~~ - ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field • 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7!4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10!2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20!2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 2V -09 (PTD 1850370) OA SCP question/report . Jim, Thanks for the notification that the AOGCC inspector found the OA of gas lifted producer 2V-09 (PTO 1850370) at 1040 psi on 3/1/07 during SVS testing with no waiver posted at the wellhead. / The well trend plot and annular communication history has been reviewed. The current T/I/O pressures are 194/1278/980. The OA reading is a daily manual entry. The OA is being bled about once a month to keep it below the 1000 psi limit. It is right at the maximum limit and needs to be bled again. The weep is very minor and has not reached the point of requiring a waiver yet but will be added to our list of wells to keep an eye on for potential future problems. In addition to bleeding the well down, the inner / casing packoffs will be tested and lock down screws torqued as needed. Attached is a 90 day T/I/O plot and a schematic. ,..,/ ~....., ..~ . ."'>\' '~':t¡ . ; . Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com SCANNED MAR 2 7 2007 «2V-09.pdf» «2V-09 90 day TIO plot 3-16-07.gif» ,. . ...., ....... ",.....'.... .--'.' Content-Description: 2V-09.pdf 2V -09.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 2V-09 90 day no plot 3-16-07.gif 2V-09 90 day TIO plot 3-16-07.gif Content-Type: image/gif Content-Encoding: base64 1 of 1 3/20/2007 10:46 AM 2V-0990 ¡ 0:46 AM . . KRU 2V-09 API: 500292130000 Well Type: PROD Angle @ TS: 40 dea ((¡) 7592 SSSV Type: LOCKED OUT Orig Completion: 3/25/1985 Angle @ TD: 41dea((¡)8100 SSSV Annular Fluid: Last W/O: Rev Reason: RESET OV (1911-1912, Reference Loa: Ref Loa Date: Last Update: 7/27/2005 00:3.500) Last Tag: 7885 TD: 8100 ftKB Last Tag Date: MaXHole~2100 DescriPtion Size Top Bottom TVD Wt Grade I Thread CONDUCTOR 16.000 0 102 102 65.00 H-40 SUR. CASING 9.625 0 3617 2930 36.00 J-55 I PROD. CASING 7.000 0 ~ 6133 ~ 0 J-55 I Tubina Strlotl :';¡¡U.BING Size I Top Bottom I TVD I Wt I Grade Thread 3.500 0 7749 I 5900 I 9.30 I J-55 8RD EUE IPC -\'1 Interval TVD Zone Status Ft SPF Date Type Comment 7592 - 7654 5780 - 5828 4,C-3,C-1,U~ 62 12 4/28/1985 IPERF 120 deg. phasing, 5" Dresser B Hyperdome 7668 - 7675 5838 - 5844 UNITB 7 12 4/28/1985 IPERF 120 deg. phasing, 5" Dresser Hyperdome 7682 - 7686 5849 - 5852 UNITB 4 12 4/28/1985 IPERF 120 deg. phasing, 5" Dresser Hvperdome 7778 - 7792 5922 - 5933 A-4 14 4 4/28/1985 IPERF 120 deg. phasing; 4" Dresser Hyperdome 7805 - 7840 5943 - 5969 A-3 35 4 4/28/1985 IPERF 120 deg. phasing; 4" Dresser I Hyperdome . St MD TVD Man Mfr Man Type V Mfr V Type VOD latch Port TRO Date Vlv Run Cmnt 1 2169 1897 Cameo KBUG GLV 1.0 BK 0.250 1379 1/2/1996 11 2 3642 2948 Cameo KBUG GLV 1.0 BK 0.156 1279 1/25/2004 3 4494 3560 Cameo KBUG GLV 1.0 BK 0.250 1351 1/2/1996 (2) 4 4908 3848 Cameo KBUG GLV 1.0 BK 0.188 1310 1/24/2004 5 5347 4157 Cameo KBUG DMY 1.0 BK 0.000 0 11/22/1995 6 5760 4449 Cameo KBUG DMY 1.0 BK 0.000 0 1/24/2004 7 6173 4744 Cameo KBUG GLV 1.0 BK 0.250 1412 1/24/2004 8 6616 5061 Cameo KBUG OV 1.0 BK 0.250 0 7/10/2005 9 7028 5356 Cameo KBUG DMY 1.0 BK 0.000 0 5/22/1990 10 7380 5618 Cameo MMG-2 DMY 1.5 RK 0.000 0 1/23/2004 1. Broken Latch 2. Broken Latch PBR Production Mandrels/Valves (7420-7421, St MD TVD Man Mfr Man Type V Mfr V Type VOD latch Port TRO Date Vlv 00:3.500) Run Cmnt PKR 11 7472 5688 Cameo MMG-2 CV 1.5 RKP 0.000 0 2/13/2005 Ooen (7433-7434, 12 7543 5743 Cameo MMG-2 DMY 1.5 RK 0.000 0 11/28/1989 Closed 00:6.151) BROKE 13 706 5868 Cameo ~ PATCH 1.5 RK 0.000 0 11/6/1995 Closed ... Depth TVD Tvpe Description ID 1911 1719 SSSV Baker 'FVL' LOCKED OUT 1/22/2004 2.812 7420 5649 PBR Baker 3.000 7433 5658 PKR Baker 'FHL' 3.000 7727 5884 PKR Baker 'FB-1' 4.000 7741 5894 NIP Cameo 'D' Nipple NO GO 2.750 .... 7741 5894 NIPPLE Cameo; Set on 11/5/95 2.250 REDUCER Perf - - 7748 I SOS Cameo 2.992 (7592-7654) - - 7749 rL 2.992 - - . ': . - - Perf Depth TVD I Type Description ID (7668-7675) ........ ........ 7639 5816 PATCH 21' Merla Tbg Patch; Set 11/6/95 2.375 . .... .... 7689 5855 I PATCH 21' Merla Tba Patch; Set 11/6/95 2.375 Perf . . (7682-7686) .... ..... - - PATCH (7689-7710, 00:2.750) PKR (7727-7728, 00:6.151) TUBING (0-7749, 00:3.500, 10:2 992) Perf ....... ..... (7778--7792) -- --- Perf . (7805-7840) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1343' FSL, 110' FWL, Sec 8, T11N, R9E, UM ' At top of productive interval 1252' FNL, 1374' FEL, Sec 8, T11N, R9E, UM At effective depth 1105' FNL, 1174' FEL, Sec 8, T11N, R9E, UM At total depth 1057' FNL, 1108' FEL, Sec 8, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 81 0 0 true vertical 6166 OR!G feet feet 6. Datum elevation (DF or KB) RKB 1 O9 7. Unit or Property name Kuparuk River Unit 8. Well number 2V-09 9. Permit number/approval number 85-37 10. APl number 50-029-21300 -11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7 9 7 4 true vertical 6070 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 5 8 2' 9. 625" Intermediate Production 8024' 7" Liner Perforation depth: measured 7592'-7654', true vertical 5779'-5826', Cemented Measured depth True vertical depth 250 Sx CS II 102' 940SXCS III& 3617' 410 Sx CS I, Top Job w/121 Sx CS I 305 Sx Class G & 8 0 5 5' 250 Sx CS I 102' 2929' 6132' 7668'-7675',7682'-7686',7778'-7792',7805'-7840' 5837'-5842', 5848'-5851', 5921'-5931', 5941'-5968' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7749' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 7433' & Baker FB-1 @ 7727'; SSSV: Baker FVL @ 1911' RECEIVED 13. Stimulation or cement squeeze summary Stimulate "A" Sand interval on 11/26/95. Intervals treated (measured) 7778'-7792',7805'-7840' Treatment description including volumes used and final pressure Pumped 143 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp was 4600 14. Representative Daily Average Production or Injection Date, Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 854 858 2 1433 236 Subsequent to operation 1 4 8 0 1248 325 554 284 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ ~ ~c~ Title Wells Superintendant Date Form 10-404 Rev 06/15/88 SUBMIT Ii~ DUP'LICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ . K1 (2V-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2V-09 FRAC, FRAC SUPPORT 1 1 19951355.2 DATE DAILY WORK UNIT NUMBER 11/26/95 "A" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O NoI (~) Yes (:~ No DS-YOAKUM CI-/~AI~EY /f Initial Tbq Press Final Tba Press Initial Inner Ann Final Inner Ann ~ Initial Ou['er An'n J Final Ou~nn 930 PS! 1 000 PSI 1560 PSI 1500 PSI! 125 PSI /// 25 PS! DALLY SUMMARY "A" SAND FRAC COMPLETED, 143000 LBS OF PROPPANT BEHIND PIPE WITH 11.1# @ PERFS. LEFT 3,.'.'.'~65 LBS OF 12/18 PROPPANT IN TBG.TREESAVER FAILED TOWARDS END OF JOB AND SCREENED OUT TOP TO BTM. MAX PS! 4600 PSI. TIME 06:30 09:00 10:30 11:20 12:35 14:30 16:00 17:00 LOG ENTRY MIRU DOWELL EQUIP, HOT OIL UNIT, AND VAC TRKS. FOUND ONE OF FRAC TANKS OF SEAWATER AT LOW TEMP. MOVED HOU OVER AND HEATED TANK. HELD SAFETY MTG(14 PEOPLE ON LOCATION) SET TREESAVER AND PT'D HI-PRESS LINES TO 7000 PSI, FAILED TEST DEPRESSURED AND REPAIRED LEAK. RE PT'D TO 7000 PSI, HELD GOOD. RU HOU TO 7" AND PT'D BACKSIDE HARD LINE TO 4000 PSI. PUMP CONDITION 50# DELAY-XL GW AND STRAIGHT SEAWATER @ 15 BPM, VOLUME 317 BBLS, PROPPANT USED 2101 LBS OF 20/40. MAX PS! 3600 PSI, ENDING PSI 3300 PSI. ISIP 2020 PSI, S/D FOR CLOSURE. PUMP DATA FRAC 50# DELAY-XL GW AND STRAIGHT SEAWATER @ 15 BPM, VOLUME 169 BBLS, MAX PSI 3600 PSI, ENDING PSI 3500 PSI. ISIP 2064 PSI, S/D FOR CLOSURE. PUMP FRAC 50# DELAY-XL GW @ 15 BPM, VOLUME 1524 BBLS, MAX AND ENDING PSI 4600 PSI. TREESAVER FAILED TOWARDS END OF JOB AND SCREENED OUT TOP TO BTM WITH 12/18 PROPPANT. 174364 LBS OF PROPPANT PUMPED DURING THIS STAGE. STARTED TO CLEAR LINES AND RD DOWELL EQUIP. DEPRESSURED 7" TO 1500 PSI AND DISCONNECTED HOU. TOTAL PROPPANT PUMPED DURING JOB 176465 LBS(166165 LBS OF 12/18 PROPPPANT AND 10300 LBS OF 20/40 PROPPANT). TOTAL SLURRY VOLUME PUMPED 2011 BBLS. MAX PSI REACHED AT SCREEN OUT 4600 PSI. 143000 LBS OF PROPPANT BEHIND PIPE WITH 11.1 # @ PERFS. LEFT 33465 LBS OF 12/18 PROPPANT IN TBG. PULLED TREESAVER(ALL CUPS RETURNED) RU HOU TO FLOWLINE AND FREEZE PROTECTED W/20 BBLS OF DIESEL. RD COMPLETE, WELL SECURED AND NOTIFIED DSO OF STATUS. uaY o 7 1996 Oil & Gas Cons. SERVICE COMPANY - SERVICE APC-LABOR APC-PUMPING APC-TRUCKING DIESEL DOWELL-STIMULAT1ON HALLIBURTON LITTLE RED HOT OIL TOTAL FIELD ESTIMATE DAILY COST I ACCUM TOTAL I1. Operation Performed: Operation Shutdown . stimul'ate ~- Pull tubin.g L. '" [5. T)~pe of Well~' ' 2. Name of Operator Alter casing . . Repair well ~ Development X I ARCO Alaska. Inc, ~ Exploratory _ ~3. Address ~ Strafigraphic _ IP. O. Box 100360, Anchorage, AK 99510 [ Sedco 14~ LOcation of well ~t surface ' -- 1343' FSL, 110' FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1252' FSL, 1374' FEL, Sec. 8, T11N, R9E, UM At effective depth 1182' FSL, 1279' FEL, Sec. 8, T11N, R9E, UM At total depth 1057' FNL, 1108' FEL, Sec. 8, T11N, R9E~ UM '~2. Present well"condition summary Total Depth: measured 79 74' feet true vertical 61 67' feet STATE OF ALASKA A~ OIL AND GAS CONSERVATION ~MI~:~ION REPORT OF SUNDRY WELL OPERATIONS Plugging .. , Perforate , , Plugs (measured) NONE ,, Other 6, 'Datum'elevation (DF or KB) _ 109' RKB feet 17. Unit or Property name ' Kuparuk River Unit '~'. Well 'number ....... 2V-09 ,, 9. Permit number/aPproval number 85-37 .... 10. APl number 5o-029- 213,00 11. Field/Pool Kuparuk,, River ,Oil Pool /' ,,, Effective depth: measured 7773' feet Junk (measured) true vertical 5918' feet NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 102' 16" 3617' 9 5/8" 8055' measured 7840'-7805', true vertical 5969'-5943', Tubing (size, grade, and measured depth) Cemented Measured depth 250 Sx CS II 1 02' 940 Sx CS III & 3 61 7' 410 Sx CC I 7" 305 Sx Class G 8 0 5 5' 61 3 3' True vertical depth 102' 2930' 7792'-7778', 5933'-5922', 7686'-7682', 5852'-5849', 7675'-7668', 5844'-5839', 7654'-7592' 5828'-5780' Packers and SSSV (type and measured depth) Baker FB-1 prk ,,~, 7715' and Baker FHL pkr, @ 7421', B..aker .FVL-SSSV @ 1 ... i3. StimUlatiOn or cement squeeze summar~ r'~ ' /~' Refracture stimulated A Sand with 49,200 bls of 16/20 mesh ISP and 11,500 bls 12/18 ISP. Intervals treated (measured) 7840'-7805', 7792'-7778' Treatment description including volumes used and final pressure , Well Service Report including volumes and pressures attached. ~l.lc/~n.~$-w/$. Col'nm,...,_ i4'. " RePresentatiVe Dai'l¥ Average Production or In!ection Dat~ ..... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 441 269 5 1350 Subsequent to o.p, eration, .... 1 4 0116. Statu~ of weil classification as: "' ~ 5. Attachments 1 ~ 7 0 9 - 0 - 1 3 5 0 / Copies of Logs and Surveys run~ ~ Water Injector Daily Report of Well Operations. X ~ oil X Gas .. Suspended . 17. I'here/~ce~tify that the foregoing is true and '~'(~rrect {(~ the b~st of my knoWledge," ' Signed ' Title Form 10-404 Rev 09/12/90 200 220 ,, Service , Date SUBMIT IN DUPLICATE ARCOAlaska, Inc '~ ~ ,~ubsidiary of Atlantic Richfield Compan, WELL IPBDT CO:'-'rqACTOR RE~/~RKS WELL SERVICE REPORT FIELD- DISTRICT- STATE tOPERATION AT REPORT TIME DAYS ,//3 7 \.; U I-"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I Signed _ knot'I ~/~/ ~ j~-j J ARCO Alaska, Inc. Post Office ~o× A~chorage~ Alaska ~elephone 907~:~ ....... 12t 5 May 10, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2V-09 Stimulate May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer RECEIVE ) 1 5 ]99,n ,?~iaska.Oil & Gas Cons. Commission ~ Anch0rag~ CC: J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments A,.. ,SKA OIL AND GAS CONSERVATION ~ '~ION APPLICATION FOR SUNDRY APSROVALS0 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Time extension _ Stimulate _~_ Change approved program _ Variance _ Perforate __ Other _ 6. Datum elevation (DF or KB) Repair well _ Plugging Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic 99510 Service 4. Location of well at surface 1343' FSL, 110' FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1252' FNL, 1374' FEL, Sec. 8, T11N, R9E, UM At effective depth 1182' FSL, 1279' FEL, Sec. 8, T11N, R9E, UM At total depth 1057' FNL, 1108' FEL, Sec. 8, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 7974' true vertical 6167' feet Plugs (measured) feet NCI~E Effective depth: measured 7773' feet Junk (measured) true vertical 5918' feet ~ Casing Length Size Structural Conductor 1 0 2' 1 6" Surface 361 7' 9 5/8" Intermediate Production 8 05 5' 7" Liner Perforation depth: measured 7840'-7805', true vertical 5969'-5943', RKB 109 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2V-09 9. Permit number ,.. 85-37 10. APl number 5o-029-21 300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVEi;' Cemented 250 Sx CS II 1 0 2' 1 0 2' 940 Sx CS III & 361 7' 2930' 410 Sx CS I 305 Sx Class "G" 8 0 5 5' 61 3 3' 7686'-7682', 5852'-5849', 7792'-7778', 5933'-5922', Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 with tail @ 7738' Packers and SSSV (type and measured depth) MAY 1 5 ]9.% .::~.~faska.0ii A Gas Cons. C0mmissi0r~ Measured depth' '.,xk ~l~/~0vl'~aI depth 7675'-7668', 5844'-5839', 7654'-7592' 5828'-578O' Baker FB-1 pkr @ 7715' and Baker FHL pkr @ 7421', Baker FVL-SSSV @ 1900' 13. Attachments Description summary of proposal _ Detailed operation program X. BOP sketch X Refrac A Sand with 49,200 lbs of 16/20 sand & 11,500 lbs of 12/18 sand. (Proc. and Wellbore Attached) 14. Estimated date for commencing operation ~ 15. Status of well classification as: Mav. 1990 I Oil X Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17' I he"~~ify,~at the f°reg°ing is true and c°rrect t° the best °f mY kn°wledge' ~t(~.G~, Si~lned ' [AJ~~ Title ,~--,,~ ~hfL ~,~,/'~_~'~-$ · Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test m Subsequent form require ORIGINAL SIGNED BY Approved by the order Commission LONNIE C. SMITH Commissioner IlAppr°val N,,~'~-~"~'z Date Form 10-403 Rev 05/03/89 Approved Copy Returned SUBMIT IN TRIPLICATE APl R 500292130000 SPUD DATE: 03/17/85 KUPARUK WELL 2V-09 AD[. LEASE: 25644 COMPLE¥1ON DATE: 04/30/85 PERMIT #: WORKOVER DATE: 85-37 · SURFACE LOCATION: 1343'FS1., 110'FWL, SEC8,T11N,RgE TOP OF KUPARUK: 1252'FNL,1374'FEL, SECS,T11 N,RgE TD LOCATION: 1057'FNL,1108'FEL, SEC8,T11 N, RgE NI clepl~ are MD-RKB to top of equipm~t unlee~ olherwi~ holed SIZE ORIGINAL RKB: 109 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5~ H-40 102 9~625' 36# J-55 3617 7' 26# J-55 8055 3.5· 9.3# J-55 7738 TUBING SPOOL: 33 WELLTYPE: PRODUCER LINER DETAILS · WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.812' 1900 SBR BAKER PBR 3' 7408 PKR BAKER FH 7421 PKR BAKER FB 7715 N~ CAMCO 'D 2.75" 7729 SHROUT CAMCO 7737 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 47 HOLE ANGLE THRU KUP: 40 LAST TAG. DATE: PATHOLE: ~- 5 ' FISH/OBSTRUCTION: PBTD: PBTDSG: deg deg L PAD ELEVATION: 78 STN 1 2 3 4 5 6 7 8 9 10 11 12 13 INTERVAL 7592.7654 7668-7675 7682-7686 7778-7792 7805-7840 DEPTH 300 2100 7~$ · . : ::;'.."_ !: .. GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2158 CAMCO KBUG 1" 3630 CAMCO KBUG 1 · 4482 CAMCO KBUG 1" 4897 CAMCO KBUG 1. 5335 CAMCO KBUG 1' 5748 CAMCO KBUG 1' 6161 CAMCO KBUG 1' 6604 CAMCO KBUG 1 · 7016 CAMCO KBUG 1' 7368 CAMCO MMGII 1.5" 7460 CAMC, O MMGII 1.5" 7531 CAMCO MMGII 1.5' 7695 CAMCO MMGII 1.5" PORT SIZE DV .DV ~ ~v .DV .DV ~r G~v .DVBROKE .DVBENTL ZONE C- PERFORATION DATA FT SPF PHASE COMMENTS 62 12 120 DA5" HYPERDOME 7 12 120 DAS' HYPERDOME 4 12 120 DAS'HYPERDOME' 14 4 120 DA 4' JUMBOJET2 REVISION DATE: 09/01/8g REASON: D. Bundy / T. Johns 5/9/90 Page 3 Kuparuk Well 2V-09 'A' Sand Re-Fracture Procedure Charge Code: K81042 1. Obtain an A&C Sand combined 24 hour well test. PLEASE NOTE: A Sand Only Testina Steps 2 through 4 should be completed well in advance of refrac to allow for stabilization of A Sand only well production and C Sand only reservoir pressure. 2. MIRU Slickline unit. RIH with gauge ring. Tag fill. Last tag Performed 3/30/90 found fill at 7863' RKB, indicating that 23 feet MD of rathole exists below lowest A Sand perfs. If less than 15 feet of rathole exists, consult with Operations Engineering to determine if a CTU cleanout is necessary. 3. Dummy GLVs at 2158', 4897', 6161', 7016', and 7368' RKB, and dummy C Sand CV at 7460' RKB 4. Fill annulus with diesel and pressure test. 5. Set standing valve in D nipple at 7729' RKB. Pressure test tubing. Remove standing valve. RDMO. 6. Obtain two 24 hour A Sand only well tests. PLEASE NOTE: Two Petredet Gauae~ Step 7 should be performed the day before the refrac to minimize the length of time the Petredat gauges are downhole. Petredat Gauge Settings below assume gauge is run downhole 20 hours prior to the . . pumping of the frac job. Pressure Rate # of Pressure Delta Time Temp Rate {'sam.oles/Hr) Measurements This Rate ~Hrs~ ~'samoles/Hr~ 1 20 20 1 240 288O 1 2 24 1 144 144 1 Replace DV from C Sand Mandrel (GLM#11) at 7460' RKB with 1.5" Petredat gauge configured outward to record C Sand reservoir pressure. Replace DV from gas lift mandrel (GLM # 10) at 7368' RKB' with 1.5" Petredat gauge configured inward to record tubing pressure. Set standing valve in D nipple at 7729' RKB. Pressure test tubing with Petredat gauges downhole. Remove standing valve. RDMO. D. Bundy / T. Johns 5/9/90 Page 4 . 10. 11. 12. 13. 14. 15. 16. Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check proppant for fines due to handling. Obtain a sample of the proppant and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Install "Tree Saver" with maximum mandrel I.D. Hold 3500 psi on the annulus during the entire job. Pump fracture treatment per the attached schedule. Recommended maximum surface treating pressure is 6000 psi. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 4500 psig Fracture Gradient = 0.70 psi/ft (@ A Sd = 5908' TVD) Tubing Friction = 289 psi/1000 ft (@ T.T. = 7778' MD) If surface treating pressure approaches 6000 psi, reduce treating rate to determine cause of pressure increase and maintain reduced rate if necessary. Rig down frac equipment. Leave well shut in over night. MIRU Slickline Unit. Pull 1.5" Petredat gauges at 7460' RKB and 7368' RKB and replace with dummy valves. Tag fill with blind box. RDMO. Follow attached flowback schedule. After well has completed flowback, obtain 24 hour well test. If gas lift is required to help flow back well, a separate procedure will be sent. KUPARUK WELL 2V-09 'A° SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 5/2/90 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME DESCRIPTION BBLS BPM ~ DESCRIPTION LBS STG/CUM HIT PERFS BBLS 1 GW PRE-PAD 80.0 25 0 - - 0 80/ 80 25.0 20 0 -- 0 25/ 105 20.0 15 0 -- 0 20/ 125 15.0 10 0 -- 0 15/ 140 10.0 5 0 -- 0 10/ 150 2 SUCK DIESEL PREFLUSH 69.0 25 0 69 / 219 ....... SHUT DOWN FOR ISIP - TUBING AND PERF FRICTION CALCULATIONS - FRACTURE CLOSURE PRESSURE MEASUREMENT ............ 3 GW PAD 412.5 25 0 16/20 LW CERAMIC 0 413 / 632 4 GW wi2 PPG 27.6 25 2 16/20 LW CERAMIC 2316 301 662 5 GW wi4 PPG 38.2 25 4 16/20 LW CERAMIC 6426 45 / 707 6 GW wi6 PPG 43.5 25 6 16/20 LW CERAMIC 10958 55 / 762 7 GW wi8 PPG 44.3 25 8 16/20 LW CERAMIC 14899 60 ! 822 8 GW wi10 PPG 34.7 25 1 0 16/20 LW CERAMIC 14570 501 872 9 GW w/12 PPG 22.9 25 1 2 12/18 LW CERAMIC 11532 35/ 907 TAIL IN 1 0 SUCK DIESEL FLUSH 67.0 +SV 25 0 - - 0 67/974 TOTAL GELLED 2% KCL WATER = TOTAL DIESEL ADDED TO FRAC FLUID = TOTAL FRAC FLUID = TOTAL SUCK DIESEL = Stages 1 through 9, excluding Stage 2, are Gelled Water. 742.3 BBLS 31.4 BBLS 773.7 BBLS 136.0 BBLS +SV 16/20 LW CERAMIC PROPPANT = 12/18 LW CERAMIC PROPPANT = TOTAL LW CERAMIC PROPPANT = 49168 LBS 11532 LBS 60701 LBS Stage 2 is a Diesel Preflush prior to ISIP shut down to provide for an easier ambient start up following the shutdown. Stages I and 3 are Gelled Water with 40 Ibs/1000 gal silica flour and enough breaker for a 6 hour break. Stages 4 through 9 are Gelled Water with 6 hour breaker and without silica flour. Stages I through 5, excluding Stage 2, will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densometer. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained above 100° F on the surface. Recommended maximum surface ffeating pressure is 6000 psi with 3500 psi on the annulus. If surface pressure increases, reduce treating rate to determine cause of pressure increase. Maintain reduced rate if necessary. 69 288 701 731 776 831 891 941 976 SUNDRY NOTICE - WELL 2V-09 NO BOP WILL BE UTILIZED DURING THIS PROCEDURE BOTTOM HOLE PRESSURE (6200' SS) = 3800 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS . MEM,ORANr)UM Stat'- of Alaska ~S~S~~IL AND GAS CONSERVATION C6,~,~ISSION ton TO: C.V. DATE: June 3, 1987 Chairm~~' F~ t5 NO.: D. BDF. 4 ] THRU: FROM' Lonnie C.. SmithieS% Commissioner / TELEPHONE NO.' SUBJECT: Safety.Valve Test ARCO KRU 2V-9 Kuparuk River Field Bobby Foster~%D .... ~' Petroleum Inspector Saturday, Mjy 16/_~987: The safety valve test began at 8:30 a.m. -A~hd'~W~s Co6-~i~ude--d~:00 a.m. As the attached safety valve report shows, the SSSV tested o.k. In summary, I witnessed the successful retest of the SSSV on ARCO's 2V-9. Attachment 02-001 A ( Rev 10-84) Well ___pt.,1.,o~ tLC ~ IP FP Test IP FP Test PI ULo~ No. High L-- TBG TI~ ~7 ~/~ i i i ii i i i ii i i ii ii i ii i i ~ ii .... . ,,, ~, r .,, ~, ,, ,, , , , , ,, , , , , , , ,, ~ ,~ , , , ~ , - . , , ,, , , . , ,,, ,t , , , _, ~ , , , , .. ~ , · ,,,,,c,, ,, ,, , , , , . , ,, ,, , , , , , . · , ,, , ,, ,, ,,,,, ~ , ,,~ , ,., ,. ~ , · , ,. ,,., . - _ _ = _ , .. ,, [ ,, , , ,., · ; ,u . , : 11, " , , l, 11 - ,, , , i ,, il,,~ ~ - , ...... , , ,. l, 111 - , ..... , i , · 11 , il 11 i , - :~ 11 ,. , . , 11 R~rks: , i ., ,, , i ,i., ,. i , , , . . , i ,I,I, , , . " ' " . ,, ........... ,, , ....... ,. ,. . ., I , '" '' Il. .I,I I , ~ I , ARCO Alaska, Ir Post Offic,. ,.,~x 100360 Anchorage? Alaska 99510-0360 Telephone 907 276 1215 bATE: 09-19-85 TIiANSMITTAL NO: 5360 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEitING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF '£~tI~ TRANSMITTAL. SCHL/ CBL 'S 04-26-85 RUN #2 7600-8842 04-26-85 RUN #1 5500-8018 04-16-~5 kUN #1 6095-9046 03-02-85 J{UN #1 3650-6690 04-21-85 RUN gl 5595-7888 04-21-85 ~UN #1 5~95-7383 04-25-85 RUN 91 5900-7818 04-25-85 RUN 91 7500-9123 FINAL, PRINTS/ ~-.~ 1Q_i~/ ~ ~J 1Q-2,~~ '° ~g 'lQ-4 / ~'"2U-3 J . '~%/2V-9 ~ ~ 2V-10 ¢' '"'-"~ '2V- 11 / ~ 2V_l 2/" RECEIPT ACKNOWLEDGED: SPAE B. CURRIER CHEVRON D & bi DIbTt<!BUT1ON: DI{ILLING*DL W. PASHEK L. JOHNSTON EXXON MOBIL P~ilLLIPS OIL NSK CLERK*BL J. I~AThMELL DATE: ,..-.., , ..... .......... STATE OF AL~SKA'*BL SOhiO /SE UNION K. TU LIN/VAULT* FI LM ARCO Alaska, Inc. is a Subsiciiary of AtlanticRichfieldCompany ARCO Alaska, Inc..~'-~ Post Office E. 100360 Anchorage, Aiask~ 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 TI{ANSMI?TAL NO: 5341 RETUP, N TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEkING KECORDS CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING IT~]S. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. CASED HOLE LOGS (FINALS): ~'~lQ-15/ 'CBL 6/12/85 8000-8745 iQ-l-- CCL & PERFORATING RECORD 4/16/85 2V-9--- COMPLETION RECORD 4/25/85 7525-7800 ~2H-15-~ COMPLETION RECORD. 4/13/85 6998-7438 2H-2--- CCL & PERFORATING RECORD 4/24/85 2H-14--- CCL & PERFORATING RECORD 4/23/85 ~2h-16-- CCL & PERFORATING RECORD 4/19/85 ~lR-9~ PERFORATING RECORD 8/3/85 7800-8000 ~lB-2 -~ PACKER SETTING RECORD 6/5/85 7290-7820 ~lA-9~ PACKER S~TTING RECORD ~/15/85 6700-6950 2H-13-- COMPLETION RECORD 4/!7/~5 7434-7650 ~IR-10~ PERFOkATING KECORD 8/5/85 8300-8550 ~2Z-8-~ COMPLETION RECORD 4/27/85 8920-9030 ~3B-11_- CET 7/5/85 65~0-9i00 RECEIPT ACKNOWLEDGED: · DISTRIBUTION: BPAE DRILLING* $~. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON JdOBIL PHILLIPS OIL D &..'M NSK CLEP~K* J. RATHMELL ~ t~l,~ ~ '~ ,, DATE':' ...... ~,, ~- '- ....... ~ STATE OF UNION K.TULIN/VAULT ARCO Alaska, Inc Post Office E 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 12, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2V-5 2V-13 2V-9 2X-9 2V-11 2Z-2 2V-12 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L56 Enclosures RECEIVED b~l 6, ~as C0~Is. C0~jSsJ0B Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _AND GAS CONSERVATION Ct. ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-37 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21300 , 4. Location of well at surface 9. Unit or Lease Name 1343' FSL, 110' FWL, Sec.8, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1252' FNL, 1374' FEL, Sec.8, TllN, RgE, UM 2V-9 At Total Depth 1i. Field and Pool 1057' FNL, 1108' FEL, Sec.8, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKB[ ADL 25644 ALK 2575 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions 03/17/85 03/23/85 03/25/85*I N/A feet MS L/ 1 17. Total Depth (MD+TVD) ;18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8100 ' MD , 6166 ' TVD 7974'MD,6070'TVD YES [~X NO [] 1911 feet MDI 1400' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/Cal/SP, CET/GR, CBL, Gyro "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 surf 102' 24" 250 sx CS II 9-5/8" 36.0# J-55 Surf 3617' 12-1/4" 940 sx CS Ill & 410 sx iS I Performed top job w/121 sx CS I 7" 26.0# J-55 Surf 8055' 8-1/2" 305 sx Class "G" & 250 ,'.x CS I ! 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7805' - 7840' 3-1/2" 7749' 7433' & 7727' 7778' - 7792' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7682' - 7686' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7668' - 7675' W/12 spf, 120° phasing 7710' - 7712' 100 sx Class "G" 7592' - 7654' See attached Addel~dum. dated 7/26/8~5, for frae 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 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-APl (corr) Press. 24-HOUR RATE 28. CORE DATA , Brief description of lithology, porosity, fraCtures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ,, Form 10-407 * NOTE: Tubing was run and the wel 1 perforated on 4/30/85. GRU11/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7590' 5777' N/A Base Upper Sand 7653' 5826' Top Lower Sand 7771' 5915' Base Lower Sand 7930' 6036' 31. LIST OF ATTACHMENTS 3?. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ )~~t.~ Title Associate Engineer Date. ~-//-8~' 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, 'Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 4/08/85 4/09/85 5/23/85 2V-9 Arctic Pak w/250 sx CS I, followed by 59 bbls Arctic Pak. Arctic Pak tst well w/40 gal diesel. Frac well in 8 stages w/283 bbls gelled diesel, 750# of 100 mesh & 11,300# of 20/40 mesh. · ' ' iing S~per'intendent · Date ARCO Alaska, In,' Post Office ,.~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-20-85 TRANSMITTAL NO: 5294 RETURIq TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND FINAL PRINTS / SCttLUMBERGER CET/CEMENT EVALUATIONS (ONE * OF EACH) 'J2Z-8 ~ CET LOG 04-2 6-85 "-~2V-9'"' CET LOG 04-25-85 '°2H-14--~CET LOG 04-0 5-85 -O1R-7/CEMENT EVALUATION -06-19-85 HEREWITtt ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. i{UN #1 8400-9208 RUN #1 7000-7893 RUN '~1 7400-8700 RUN %1 4500-7033 FINAL PRINTS / SCHLUMBERGER CBL'S -{ONE * OF EACH) 3B-1z~ 05-06-85 HUN #1 5040-7563 '·2U-11-~05-03-85 RUN #1 ..... 8423 2U-10~' 05-03-85 RUN #1 5500-6963 ~2U-9 -' 05-02-85 RUN ~i 5850-8089 ~1Q-16/05-27-85 RUN #1 4290-7018 ~<ECEIPT ACKNOWLEDGED: {PAE CURRIER ~HEVRON ~ & M DISTi<IBUTION: DRILLING*~L W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL ,~ ~.~ ~,~(ms. Cor:·lm!ssl0ri' STATE OF ALASKA*BL SOHIO /SE UNION K. TU LIN/VAU LT* FI LMS ARCO Alaska, lnc, '.:! Post Office Box 10{3360 Anchorage, Alaska 99510-0360 Telephone 007 276 1215 DATE: 06-24-85 TRANSMITTAL NO: 5227 RETURN TO: ARCO ALASKA, INC. KU PARUK OPERATIONS RECORDS CLERK ATO-1!!SB P.O. BOX 100.360 ANCtIO~'~AGE, AK 99510 ENGINEERING F~d~SM ITT ED RECEIPT AND KUPARUK 1B23~ 04-21-85 PBU BOTH SD. CAMCO 1C-4~ 04-25-~5 SBHP EOT[{ SD. CAMCO 1!!-3,,, 03-06~-85 PBU BOTH SD. CAMCO lQ-1,. 05--~6-85 SBHP 'A' SD. CAMCO !Q-2-- 05-26-85 SBHP 'A' SD. CAMCO 1Q-3~ 05-!~-85 SBHP 'A' SD. CAMCO 1Q-4~ 05-14-85 SBHP BOTH SD. CAMCO 1Q-5~ 06-06-85 SBHP 'C' SD. CAMCO lQ-6-. 04-23-85 SEHP CAMCO !Q-7., 04-17-85 SBHP 'A' SD. CAMCO iQ-8--~ 04-03-85 SBHP 'A' SD. CAMCO 2A-2x, 05-~7 ~5 SBHP '~' - -~ ~, SD. OTIS 2A-4m 05-11-85 -SBIIP · 'A' SD. CAMCO 2C-5~ 04-23-85 PBU 'A~ SD. BAKER NORTH SLOPE 2C-9~ 04-06-85 SBttP 'A' SD. OTIS 2C-!0\ 04-40-85 SB]IP BOTH SD. OTIS 2C-1i,~ 03-29-85 SB!tP 'A' SD. OTiS 2C-12x 03-26-85 SB!'iP 'C' SD. OTIS 2C-14,~ 04-23-85 PBU 'A' SD. OTIS & BAKER tlEREWiTH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF TIIIS TRANSMITTAL. WELL PRESSURE REPORT ENVELOPE DATA 2G-!~ 04-29-85 FBHP 'A' SD. CAMCO ~-1 05 -~ ~ -8 . -~- ,, --~ 5 o??? ???????? CAMCO 2H-!~ 05-27-85 SI3HP 'A' SD. OTIS 2H-2~ 05-23-85 ???? ???????? CAMCO ~'I-3,. 05-~3-85 Cn,T~ 'A' -, - ~ .... SD. OTIS -.~- x 05-23-85 SB!iP 'A' SD OTIS ~ 05 8-85 SBHP 'A' SD OTIS 2V-!0'~ 05-17-85 SBHP 'A' SD. OTIS _ - ~O ~A ~V-1!'- 05-17-85 SB:i~ ' SD. OTIS 2V-!2-- 05-14-85 SBHP OTIS 2X-2-- 0G-!6-85 SB!tP BOTH SD. OTIS 2X-2-. 06-14-85 SBHP BOTH SD. OTIS 2X-5~ 06-!2-$5 SDHP BOT!t SD. OTIS -~Z-6% 04-08-85 SD!iP 2Z-7- 04-2 ~' o5 ~BU EOTit SD -Z-8-~ 04-01-85 SEtlP BOTH SD. >~ECEIPT ACKNOWLEDCED: _ PAE* . CU~xlEii Di STR-iEUT'iON - -- ---- DRILL-NG W. PASHER MOBIL* PIIILLIPS OIL* . ~ ~i,~LL NSk CLERK J R~.~ * o. ooo... 'Al,.ska- , Oil & BAKr.'.~ ~O~It S~OPg .. ~chorg~ OTIS DATE: . STAT~"bi~"' AL!4 SKA* SOIiIO* K TULIN AR CO J Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-2 4-85 TFJtNSMITTAL NO: 5227 RETURN TO- ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1!ISB P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AJD R,~TURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK WELL PRESSURE REPORT ENVELOPE !B-3 \ 04-21-85 PBU BOTH SD. IC-4,~ 04-25-$5 SBHP DOT[{ SD. !H-3 ~, 03-06'-85 ?GU BOT,'I SD. 1Q-i-, 05-2 6-85 SBHP 'A ' SD. !Q-2-, 05 ~6-85 SBHP 'A' SD. 1Q-3-~ 05-+$-~5 SEHP 'A' SD. 1Q-4x 05-14-85 SBHP BOTH SD. lQ-5,, 06-06-85 SBHP 'C' SD. lQ-6-. 04-23-85 SDHP lQ-7 -, 04-17-85 SGi!P 'A' SD. lQ-8--, 04-03-85 SBHP 'A' SD. 2A-2x, 05 '~7 o5 SBHP "~' ~ SD 2A-4 ~ 05-11-85 S~H2 'A' SD. 2C-5~ 04-23-85 PBU 'A: SD. 2C-9" 04-06-85 SGttP 'A' SD. 2C-!0\ 04-40-85 SBItP BOTIt SD. 2C-1i\ 03-29-85 SB!tP 'A' SD. 2C-12x 03-26-35 SDHP 'C' SD. 2C-!4X, 04-23-85 PBU 'A' SD. 2G-!~ 0~-29-85 ' FBHP 'A' 'SD. 2H-1 ~ 05-23-85 ???? -???????? 2[{-1~- 05 ~7-85 SUHP 'A' SD --~-, · . 2H-2~ 05-23-'85 ???? ???????? 2!I-3-. 05-23-85 SBIIP 'A' SD. 2!'!-4,, 05-23-85 SE!I? 'A' SD. 2V'9'- 05-18-85 SEHP 'A' SD. 2V-!0'~ 05-17-85 SBi!P 'A' SD. 2V-lz - 05-12-85 SB:t~ SD. 2V-!2- 05-14-85 SBHP 2X'2 0o-.6-85 S,3II~ BOTii SD. 2X-2-, 06-14-85 SEHP BOT~'I SD. 21,[-5' 06-12-~5 SEll? BOTH SD. 2Z-6" 0'4-08-85 SrJ!lP 2Z-7'- 0,1-23-85 P '.'3 U EOTtl SD. 2Z-8~ 04-01-85 SE[IP GOTH SD. ~ECEIP'2 ACKNOWLEDCED: DATA CAMCO CAMCO C AMC 0 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS C AMC O BAKER NORTH SLOPE OTIS OTIS OTiS OTIS OTIS & BAKER CAMCO CAMCO OTIS CAMCO OTIS OTIS OTIS OT IS OTIS OTIS OTIS OTIS OTIS .~x NOTH SLOPE OTIS . DATE: Alaska ARCO Alaska, Inc. Post Office; ]00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 Mr. C. V. Chatterton CommissiOner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports and gyroscopic surveys for the following wells' 2U-8 2V-9 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/LI03 Enclosures RECEIVED JUN2 ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfieldCompany STATE OF ALASKA -~ ALASKA _ AND GAS CONSERVATION C~ ,vllSSION WELL COMI LETION OR RECOM LETION REI ORT AND LOO 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-37 31 Address 8. ~PI Numbe; P, 0. Box 100360, Anchorage, AK 99510 50- 029-21300 4. Location of well at surface 9. Unit or Lease Name 1343' FSL, 110' FWL, Sec.8, TllN, R9E, UM !-~';[~[~_~[ Kuparuk River Unit ._ At Top Producing Interval t VE~IF~D ~ 10. Well Number 1252' FNL, 1374' FEL, Sec.8, T11N, RgE, UM iSurf._~l~ 1 2V-9 . .. At Total Depth B.H.j~ ~ 11. Field and Pool 1057' FNL, 1108' FEL, Sec.8, T11N, RgE, UN~-----; Kuparuk River Field ~'. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 109' RKBI ADL 25644 ALK 2575 , 12. Date Spudded. 03/1. 7/85 13. Date T.D. Reached03/23/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re } 16' N°' °f C°mpleti°ns03/25/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8100 ' MD , 6166 ' TVD 7974'MD,6070'TVD.. YES []~X NO []I 1911 feet MD 1400' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/GR/Cal/SP, CET/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ........ 16" 62.5# U-40 Surf 102' 24" 250 sx CS II 9-5/8" 36.0# J-55 Surf 3617' 12-1/4" 940 sx CS III & 410 sx :S I Performed top job w/121 ~x CS I .... 7" 26.0# J-55 Surf 8055' 8-1/2" 305 sx Class "G" & 250 .'.x CS I , , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7805' - 7840' 3-1/2" 7749' 7433' & 7727' 7778' - 7792' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7682' ' 7686~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7668' - 7675' w/12 spf, 120° phasing 7710' - 7712' 100 sx Clas~ "(i" 7592' - 7654' .. , 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (~orr) '" Press. ;24-HOUR RATE ~ ..... '28. CORE DATA ........ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REC[IV[D JUN 2 Alas:., :.~ , Form 10-407 * NOTE: Tubing was run and the well perforated on 4/30/85 TEMP/WC31 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' 29. 30. 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. Top Upper Sand 7590' 5777' N/A Base Upper Sand 7653' 5826' Top Lower Sand 7771' 5915' Base Lower Sand 7930' 6036' 31. LIST OF ATTACHMENTS W~.!l Hi$~-nry ]~3nm. l,,dlng ~nmpl~.~inn d~.t~il.~); Cyrn~m. opie Survey f2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ _~~ Title Associate Engineer Date _/I 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 ~nd 24: If this well is completed for separate production f. rom more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 · 't.~;CO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prep-re and submit the "Initial Repo~t" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603988 County, parish or borough North Slope Borough LeaseADL 25644 or Unit ITitle Completion IState Alaska IWell no. 2V-9 WWS #1 API 50-029-21300 Operator ARCO Alaska, Inc. SpuddadorW.O. begun IDate ]Hour Complete 4/26/85 1230 hrs. Date and depth as of 8:00 a.m. 4/26/85 4~27/85 thru 4/29/85 Complete record for each day reported I^RCO W.,. 56.24% Prior status if a W.O. 7" @ 8055' 7898' WLM PBTD, RIH w/pkr on 3½" DP 10.3 ppg NaCl/NaBr Accept rig @ 1230 hrs, 4/26/85. ND tree, NU & tst BOPE. RIH w/CET/GR, log f/7893'-7000' WLM. RIH w/4", 4 SPF, 90° phasing sqz gun. Perf @ 7710'-7712' WLM. RIH w/RTTS. 7" @ 8055' 7962' DPM PBTD, RIH w/compl string 10.3 ppg NaC1/NaBr RIH w/Howco Champ pkr to 7460' DPM. Pmp 100 sx Cl "G" cmt @ 15.8 ppg w/.8% D-60, .2% D-46 & 3% KCl. Sqz perfs. SIDPP @ 2500 psi. CIP..@ 1430 hrs, 4/26/85. Unseat pkr. Rev circ, POOH, WOC. RIH w/bit, drl cmt to 7848', broke through. Tag cmt @ 7899'. Drl cmt to 7903'. Wsh & rm f/7903' to FC @ 7962'. Tst ann to 2000 psi; OK. Circ to cln brine. POOH, LD DP. RU DA, RIH & perf w/4" JJ II, 120° phasing, 4 SPF f/7805'-7840', 7668'- 7675' & 7592'-7654', POOH. Rn JB/gage ring. RIH & set Bkr FB-1 pkr @ 7715'. RIH w/3½" compl string. RECEIVED '" ~o~. ' Alaska Cii & Gas (;OHS. Commissi(~:C]c{ ~/2J5 The above is correct Signature F'or form preparation and d[etril~tlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ,, 5/25/85 Title Drilling Superintendent ;. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603988 County or Parish Lease or Unit Title North Slope Borough ADL 25644 Completion State Alaska Well no. 2V-9 WWS #1 AP1 50-029-21300 Operator A.R.Co. W.I. rl'otal number of wells (active or inactive) on this Icost center prior to plugging and ARCO Alaska, Inc. 56.24% Jabandonment of this well Spudded or W.O. begun Date IHour I Prior status if a W.O. Complete 4/26/85 ! 1230 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 4/30/85 7" @ 8055' 7962' DPM PBTD, RR 7.2 crude & diesel Cont RIH w/3½" compl string. Lnd tbg. Set Bkr FHL pkr. Tst tbg. Shear off PBR. Re-lnd tbg. ND BOPE. NU & tst tree to 250/5000 psi. Pull BPV. Displ well w/30 bbls diesel, followed by crude. Shear out sub. Set BP¥. RR @ 0100 hrs, 4/30/85. SSSV @ 1911.43' -Retrv Pkr @ 7433.24' - Perm Pkr @ 7726.78' "D" Nipple @ 7741.14' -Btm Tailpipe.@ 7749.43' Old TO New TD I PB Depth 7962 ! DPM ?BTD 1 Released rig Date ~Kind of rig 0100 hrs. 4/30/85 J Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Pr. od'~cing method ' Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production o,~4e~,, ~, ~G~per day Pump size, SPM X length Choke size T.P. O.P. Water % GOR Gravity ¢~1~1~) ~fectlve date ........ klaska 0ii & 6as 6ohs. ',ommission The above i ....... t ,Anch0ra~e Signature I Date ITitle M4/_~ ~.~,~,~./ 5/25/85 For form preparation and distril~ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Field Accounting cost center code State Alaska Well no. 2V-9 District County or Parish Alaska Lease orU.it North Slope Borough Kuparuk River ADL #25644 Auth. or W.O. no. JT t e I AFE 603988 Drill, Complete & Perforate Parker 191 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 3 / 17/85 Date and depth Complete record for each day reported as of 8:00 a.m. 3/23/85 thru 3/25/85 3/26/85 API 50-029-21300 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our J Prior status if a W.O. I 0630 Hrs. 9-5/8" @ 3617' 8100', (0'), Rn'g 7" Wt. 10.2, PV 24, YP 16, PH 9.0, WL 6.0, Sol 10 Drl & surv 8½" hole to 8100', C&C, short trip to 3617', TOH. RU Schl, log DIL/SFL/FDC/CNL/GR/CAL/SP f/8097'-6000', C&C, TOH f/7". RU & begin rn'g 7" csg. 6557', 44.7°, N54-1/4E, 5019.65, 3945.51, 2256.72N, 3236.21E 7055', 43e, N53-1/4E, 5378.79, 4289.85, 2460.72N, 3514.43E 7406', 40.3°, N52-1/4E, 5641.06, 4522.78, 2601.92N, 3700.11E 7857', 40-3/4e, N52-3/4E, 5983.88, 4815.35, 2780.32N, 3932.60E 8100', 39.6°~ N56-1/4E, 6169.54, 4972.09, 2870.84N, 4060.59E 7" @ 8055' 8100', (0'), RR 10.3 ppg NaC1/NaBr Rn 187 jts+ 1 marker it, 7", 26#, J-55 BTC csg w/FS @ 8054.51' (btm), FC @ 7973.86' (top). Cmt w/305 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31 & 1% D-6. Displ w/lO.3 ppg NaC1/NaBR, bump plug. ND BOPE, set slips, NU wellhead. Damaged pack-off seal, replace same & tst to 3000 psi; OK. RR @ 2400 hrs, 3/25/85. Old TD Released rig New TD PB Depth 8t00' (3/24/85) Kindofrig Date 3/25/85 2400 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas 'Test time Production Oil on test Gas per day . · . · · .'Pump size, SPM X length· ·Chok'e size T.P. C.P. Wate~ % G(~R .Gravity Allowable Effective date corrected The above is correct Signature /~ JDate ITitle ,~J~ ~..~~ 4/10/85 Drilling Superintond~t:~' ~- ~ i For form preparati .... d dMtribution, "~ L] '~. E I V [,,,, J.,~~/ F h see Procedures Manual, Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C ,-.,...,..a UiI & Gas Cons. Commissio. Number all daily well history forms consecutively 2"'"" as they are prepared for each well. Olvl~on of AtlanllcRIchfleldComplny ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth, or W.O. no. AYE 603988 Parker 191 ICounty. parish or borough North Slope Borough Lease or Unit Tme ADL #25644 Drill, Complete & Perforate IStete Alaska Well no, 2V-9 API 50-029-21300 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded ARCO W.I. 3/17/85 0630 Hrs. Date and depth as of 8:00 a.m. 3/18/85 3/19/85 3/20/85 3/21/85 3/22/85 Complete record for each day reported 56.24% aW,O. 16" @ 102' 1778', (1676'), DD Wt. 9.5, PV 17, YP 16, PH 9.5, WL 14.5, Sol 8 Accept ri$ @ 2000 hrs, 3/16/85. NU diverter sys. Spud well @ 0630 hrs, 3/17/85. Drl, DD & surv 12¼" hole to 1778'. 309', Assumed vertical 467', 7.1°, N64.25E, 466.60 TVD, 9.61VS, 3.94N, 8.95E 920', 23.1°, N53.25E, 900.44 TVD, 133.92 VS, 64.91N, 117.61E 16" @ 102' 3635', (1857'), RIH Wt. 9.8, PV 17, YP 22, PH 9.5, WL 12.0, Sol 6 Drl & surv 1778'-3635', C&C, 20 std short trip, rm back to btm. t712', 40.6°, N63.25E, 1577.69 TVD, 540.35VS, 288.89N, 457.36E 2175', 47.1°, N57.25E, 1901.94 TVD, 869.79VS, 450.34N, 745.18E 2846', 44.5°, N52.25E, 2371.71TVD, 1348.32VS, 727.56N, 1135.66E 9-5/8" @ 3617' 3635', (0'), Tst BOPE Wt. 9.8, PV 17, YP 15, PH 9.0, WL 12.4, Sol 6 TOH. RU & rn 83 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3617', FC @ 3527'. Cmt w/940 sx CS III, followed by 410 sx CS I. Displ using rig pmps, bump plug. Did not circ cmt to surf. CIP @ 2015 hrs, 3/19/85. Perform top job w/121 sx CS I. NU & tst BOPE. 3155', 43.7°, N56-1/4E, 2593.61TVD, 1563.35 VS, 853.17N, 1310.14E 3570', 44.6°, NSO-1/4E, 2891.38 TVD, 1851.05 VS, 1026.04N, 1541.65E 9-5/8" @ 3617' 4145', (510'), Drlg Wt. 9.1, PV 9, YP 6, PH 9.0, WL 14, Sol 4 Tst BOPE. TIH to 3527', tst csg to 1500 psi. DO FC, hard cmt, FS + 10' new hole to 3645'. Conduct formation tst to 12.5 ppg EMW. TOH, PU DD, DD & surv 8½" hole to 4145'. 3879', 43.3°, N50-1/4°E, 3113.84 TVD, 2064.50 VS, 1163.16N, 1706.53E 9-5/8" @ 3617' 6119', (1974'), TIH Wt. 9.4, PV 27, YP 16, PH 9.0, WL 8.0, Sol 6 DD & surv 8½" hole to 6119'. 4312', 43.6°, N52-1/4E, 3428.18 TVD, 2361.71VS, 1349.54N, 1938.75E 5148', 45.2°,'N54-1~/4E,' 40181.35 T.VD~"2954.38 VS, 1694.9'5N,~ 2419.54E. 6040', 44.4°, N56L1/4E, 4651.21TVD, 3582.95 VS, 2050.00N, 2938.22E The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 4/10/85 Drilling Superintendent AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. S UB.$ URFA CE DIRECTIONAL SURVEY ~] UIDANCE I~ONTINUOUS [-~'] OOL Company ~ ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2V-9 (1343' FSL~ 110' FWL. S8. TllN. RqF,: UH) KUPARUK. NOt, TH SLOPE- AT,AREA Job Reference No. 70458 Lo(j~ed By: MCBRIDE RECEIVED J O N 2 5 AlasKa 0il & Gas Cons. C0mmJssio. Anchora§e Date · 23-MA¥- 1985 Computed By: STEVENS fOR ARCO ALASKA, ZNC' 2V-9 KUPARUK NORTH S60P£,AbASKA SURVEY DA~I 22-APR-85 £NGINE~RI MCBRIDE' ME?HnDS OF CONPUTAT[ON TO06 60CATIONI TANGENT[Ab° averaged deviation and azimuth ~NTERPObA~ION~ LINEAR V£RTICAb SECTIONI HORIZ. D[8~ PRO~£CTED ONTO k ~ARGET A~ZNUTH OF NORTH 55 D~G 48 NZN EAST ARCO AbASKA, XNC, DATE OF SURVEy ;v.~ ~;~ NORTH SbOPE:,ALA6KA £NGZNEERI ~CSRID~ INTERPOLATED VALUES FOR EVEN XO0 FEET OF ~EASURED DEPTH TRU£ SUB-SSA COUR$~ VgRTTCA~ D~O~G R£CTANGU~AR CO0~D~NATES'HORZ~' DEPARTURE 0.00 ½8~.oo 300.00 O0 400 O0 500 O0 600 O0 ?00 O0 800 O0 900 O0 1400 1500 1600 1700 1~00 1900 0 O0 -t09 O0 100 O0 200 O0 597 7~ 54 881 50 O0 ~ ~o~ O0 1233 t404 O0 1488 O0 ~567 O0 164! O0 0 0 · -9 O0 0 10 91 O0 0 21 ~91 O0 0 4! ~90 87 4 23 ~90 16 9 488 27 12 4~ ~84.95 ~6 59 79,54 20 25 72,50 22 53 992 64 863 64 25 44 37 952 ~7 28 53 112 gO 30 54 32 16 15 34 28 91il 60 .91 45 45 2000.00 1780 2100 O0 1849 O0 1917 O0 19~6 O0 2057 O0 2127 ~269 O0 2341 O0 2413 2200 2300 2400 2500 2600 2700 2800 2900 3000 O0 2485 O0 2557 O0 2629 O0 27Ol O0 2773 O0 2845 O0 2916 O0 ~988 O0 ~061 O0 31~3 3300 3400 35O0 3600 3700 3800 3900 30 1671,30 46 20 03 ~740.03 46 49 45 1808.45 46 36 86 1~77.86 45 25 22 1948,22 45 8 2018.89 89 45 3 58 2089,58 44 49 8~ 2160,82 44 21 42 2232,42 44 16 Og 2304,08 44 q 69 2807 80 287~ O! 2952 53 3024 05 43 47 32 43 35 89 43 37 74 44 13 4O 44 13 09 44 16 69 44 7 80 43 ]0 O1 43 9 53 43 29 ,iIo.oo .o.o~ ~ ODo.oo o oD [ o,oo ~ ~ ~.~ o.o? ~ o.o, I 8 ~lo.o, ,o o.,, i Io 65 ~ ; ~:I~ 46 32 ~:lfO,67 i 0 96 ~ 1.26 49 92'87 59 43,05 ~ 83,03 93,53 62 5e £ 129,67 2? e3,82 1i3,41 = . 37 130,14 60 ,?o.,, ,,,.,,"°.'° ,o},, 266,54 369,5t t2 203,45 308,49 56 29 ~ 42,.24 232.57 ~ ~ 369.54 N 55 30 475.96 ~2 26~.t? 398.50 477.0! 450,54 55 604.74 3~4,29 510o79 1 43 58 43 N 639.24 54 423e95 N 702.56 [ 74?,97 58 53 1106.33 N 40 634,93 990,84 1046,7R 1246.47 ~ tl ~ ~ 1316.42 ~ 47 ~ 1316.19 719.5{ i102.39 ' 55 1386,00 1385.85 0 761.62 1157.99 N 52 44 803 54 o o, l~s~ ~ 40 84S 40 ~ 1268 32 ~'5'4 25 ~, ~ x~t ~o x~ o? X662 25 ? 930 45 ~ '3?? 44 ['662 25 ~ 54 £ 1731 72 1431 47 1731 72 45 _ 1149 42 N ,647 57 , 2008 89 N 55 5 E ! 93. 13 N 1700 77 E 2077 54 N 54 56 N 50 {8 ~ 2008 94 37 ~ ~o ~ ~ ~o?? ~ o COMPU?ATION DA~EI 23-HAY-85 PAGE '2 ARCO ALASKA, ZNC, DAT~ Or SURV£¥t 22-A~R-85 2V-g KE~b¥ BUSHZNG EbEVA?ZONI: 109.00 KUPARUK NORTH SLOPE,ALASKA ENGINEERS MCbRiDE [NTERpOLATED VALUES FOR EVEN 100 FEET OF M~A~URED DEPTH TRUE SUB-SEA COURSE VERTTCAb DOGbEG RBCTANGUbAR COORDINATES HORZZ.~ DEPARTURE MERSUR£D YERTICAL VERT~CAb DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EA$T/HES~ DIST.: AZIMUTH ~22.38 2355 8& 4500°00 3562.63 345,.63 59 44 2498.12 29 t442.34 ~ 2037.7? t481.75 4900.00 3841.45 373~o45 45 38 30 2782.91. ~601.56 2276.3! 2783 27 N 54 52 5000 O0 3911 3802.55 45 21 N 54 54 2854.22 85 1642,27 2334.86 2854,58 54 54 31 ~ 2925.26 '6;3.35 ~ ~ '9~5,64 5100 O0 399! $87~.9! 45 ~3 t7 2392,84 31 3067.29 2500.84 ~ ~ 54 3067,70 5400 O0 4103 21 4084.21 2 49 ~ 3205.05 3279.69 5600 O0 4334 56 4225.56 44 58 ~ 42~ 3420.70 !~ t964.39'884'9' ~ '684.40 3280.08 5700 O0 4405 25 4296.25 44 50 ~ 55 41. ~ 3350.41 1924,82 2742,79 ~ ~ 54 3350~79 54 5800 O0 4476 33 4367,33 44 42 ~ 55 48 2800.94 3421,13 54 5900 O0 4547 47 4438.47 44 36 55 48 ~ 3491.03 38 2003,88 ~ 2859.07 i '491.40 69 44 ~ 47 356i 23 30 2043 31 .29t7 16 3561 59 54 59 363t 20 21 6100 O0 4690 4,81o,4 44 ~i ~ [ ;~ ~ 6300 O0 4833 4724 78 44 6400 O0 4905 65 4796 65 44 47 ~ . ,4 s3, ,8 21 5, 55 6500 O0 4977 27 486~.27 44 2~ ~ 30 3909 66 30 2242 3[ ~ 3203 18 ; 39t0 03 660000 504846 493. 4445 21 397986 22 2283'3 320033 398025 54 ~ !! 4050 67 6?00 O0 5119 45 5n10.45 44 44 54 4050 ~6 6800 O0 5190 74 5081 74 44 21 N 53 41 ~ 4120 ,5 2365 68~ 33,4 08~ 4120 79 ~ 54 57 ' 6 N £ 4190 46 418999 54 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5334 O0 5407 O0 5481 O0 5555 O0 56tl O0 5708 O0 5784 O0 586 O0 593~ O0 6013 44 ~I~.44 43 32 N 5i 34 ~ 4259.36 40 .40 42 47 N 5 20 E 4327.69 2 5372.12 42 11 N 52 51 E 4395.18 9 5446079 41 9 N 52 12 £ 4461,59 ~ 5522.51 40 18 , 5t , E 4526.75 5599.03 39 56 N 5 0 E 4590,95 95 5675.95 39 47 N 53 1) E 46~.77 38 575~.]8 40'28 N 53 ~5 E 47 .18 49 5828.49 40.20 N 53 1 ~ 478~.00 5i 5904,51 40 31 N 53 56 E 484 ,94 ~ 03 47 0 75 0 9O 0 0 ~ 0 64 0 O0 2448,~! ~ 3486,18 4259, 2488 354t 13 1 · . 4328.22 I ~ 55 86 . 3647, 4462.22 ~ i 52 2569 ~650 Og , . 3749 ~ 4591.72 ~ i~ i 2688 84 3800 59 · . 4655, 2803. ,957.15 E 4849.87 ~ ~ 40 i 2V q KEL BUSHIN b 109 O0 FI KUPaRUK NORTH SbOPE,ALASKA ENGXNEERI MCBRXDE ZNTERPObATED vAbuE$ FOR EVEN 100 r£ET OF MEA&URED DEPTH TeU~ SUB-SEA 0 R ~ V TCR ~OG EG RECTANGUbRR COORDZNATE& HORZZei DEPARTURE ~RXTY AZIMUT SEV H ON AZ NOTH ~ TlO DEPTH DEPTH DEPTH DEG MXN DE~ MTN FEET DEGtiO0 FEET FEET FEET, DEG'MXN 8000 O0 6099.52 5980.~ 40 3! N 51 56 E 4~½~.89 0.00 2842.~ N 4009.58 E 49t4'~ N 54 40 E 8100:00 6165,52 6056, 40 31 N 5 56 B 4 .84 0.00 2880' N 4062.2~ 49?9. N: 54 39 E CO~PUTATX~N DATEZ 23-MAY-85 RC.~ AbASKA, ThiO. KUPARUK NORTH SLOPE,ALASKA 109,00 IrT ZNTERPOLATED VALUES ¥OR EV£N lO00 FEgT OF MEASUREO DEPT TRUE SUB-SEA COURSE MEASURED V£RTXCAL VERTTCAL DEVTATZON AZX UT DEPTH DEPTH ~EPTH DEG MtN DEGM H VERTTCAL DOGLEG RECTANGULAR COORDZNATE5 HOR'XZ,~ DEPARTURE SECTION SEVERITY NORTH/SOUTH EA3T/W~ST DXST,! AZZMUTH FEET DEC/lO0 FEET FEET IrEET DEG MXN 0 O0 0 O0 -109 O0 0 0 N 0 0 E lO00 200g 300 4OOO 5000 6000 7000 8000 O0 91 O0 O0 ~91 O0 4618 O0 6059 4 86~ 15 44 N 5 E 50 ½70 · 1455 4? N 52 44 ~ 0 O0 ¢2 ~2 0 2~ 0 89 0 0 O0 30 O~ O0 0 1642 2045 2448 2842 000E N 145 N 639 Ol N 917 N ~486 2t N 400g 0 O0 N 0 3~ 1 18~E 4259 68 E 4914 N 59 N 54 49 E. N545' ] N 54 [C 86 N 54 55 E 85 N 54 40 E COMPUTATION DA~I 23-MAY~65 2¥-9 BUSHZN KUPARUK NORTH SbOPE~AbASKA ~#G~NE~R; MCSRXDE ZNTERPObATED VALUES FOR gVEN tOO F£ET OF SUB-SEA DEPTH TRUE SUB-SgA COUR$£ VgRT~CAb DOGbEG RECTANGUbAR COORDINATE6 HORZg', DEPARTURE o Go o GO -~o~ Go o o 9 O0 9 O0 'lO0 O0 0 25 GO ~o~ oo ~o~ oo ~oo oo o ~ ~ ~ o ~ ~ o ~ ~oo~ . · ~o~ ,~ ~o~ GO ~oo GO 35.30 ~ 66 O2 6,2, 609 O0 SOO O0 · ?~ O0 35 64 65~97 59~30 GO~oo 82t.~5 809 O0 ?00 O0 54 55 9~ 47, 101,20 t60 O~ t309 O0 200 O0 ~, 4~~ 43 43 6~ 2' ~ 482 65 ~ 573 62 ~00 O0 ~ 309, 1897 26 1709 O0 600 O0 45 44 ; 67 64 40 354. 593 30 674 25 58 2041 ~4 i809 O0 IO0 46 700 77; ~ ~ 778 1! ~ 58 49 E 42 ' 02 · 402. 665 75 2*54 2309.00 2~00.00 44 16 ~ 84 2894: 24090 O0 2300,00 44 lO ~ 5547 ~ St,* 3449:64 2~09.00 2700.00 44 5~ E . 3589.27 2909,00 2800.00 44 It , ,00 43 28 4423°$2 3509.00 3400°00 45 tO 456&~65 3609~00 3~00o00 45 4710,13 3709,00 3~00.00 45 46 4853.~0 3809.00 3~00.00 45 47 PAGE 5 * 109.00 FT 756 53 884 50 58 47 839, 58 08~,4215 · [ · . ·48 N 57 999 , 57 1154.~; 382,05 56 40 766. 55 ARCO AbASKA, 2V-9 KUPARUK NORTH COMPUTATION DATEI 23-MAY-85 PAGE 6 DATE OF SURV£¥I 22-APR-85 KELb¥ BUSHING ;bEVATIONI log,o0'rT ENGINEERI HCiRXDE XNT£RPO~ATED VALUES FOR ~V£N 100 FEE~ OF 8UB-$~A DEPTH 3909 O0 33100 O0 45 2~ O0 .45 It 4009 33 4209 88 4309 ~8 4409 94 4509 40 4609 37 47O 5t ¢80~ O0 O0 40OO O0 4i00 O0 4200 O0 4300 O0 4400 O0 4500 O0 45 19 O0 45 2 O0 ~45 0 O0 44 48 O0 44 40 O0 44 34 O0 44 18 O0 44 N 64 55 £ 265i, . 54 31 £ 295~.,5 N 55 lq E 3053.44 N 55 45 E 315],99 N 55 44 g 3254,17 N 55 4~ ~ 3354,14 N 55 49 F 345),06 N 55 49 £ 355l,69 N 55 37 £ 3649.62 N 55 4 E 3746. 38 0 31 0 31 0 6 ! 0 ? 5 4996 5136 5260 5422 5563 5705 5645 5986 6126 6265 6404 66 4909 500! 78 530 ]7 540~ ~6 $709 37 $80¢ g O 4600,00 44 7 0 4900.00 44 :00 5000.00 44~6 ·'00 5100,00 44 15 O0 5200.00 43 54 O0 5300.00 42 46 ~ ~00.00 40 7 ! 0 5600,00 39 56 0 5?00,00 39 57 N 54 47 E 3643 N54 29 E 3940 N 54 6 ~ 4039 N 55 41 E 4138 N 53 38 E 4235 N 53 20 ~ 4329 N 5~ ~.E 4420 ~ 51.~ E 450? N ~2 1 £ 4591 ~ 53 2! E 4674 0 88 0 ii 6544 6685 6825 R~CTANGUbAR COORDTNA~£$ HORIZ, DEPARTURE NOR H/SOUTH EAST/WES{ DIS~'::': FEgT FEET FE~ DEG'NXN ., '699 ,~0 ~ ?5 2952.94 ,,,s.o?[ ' ~ 54 18~4 2580.45 2017 2909,26 i 3552 04 ~ 54 2093 N 2990. 3649.~I 2148 N 3069... 3746. 55 0 23?6 E 4136 64 2598 M 3684 32 Z 4508 2650 58 N 3750 4{ B 4592 2700 8& N 3816 76 £ 46?5 72 N 56 g 49~5 09 , 0 2751.39 N 3885.~ E 4846 894. 6009. 5900.00 . 2801. N 3954. · . . ..... . , 2680.46 N 4062.22 £ 4979. ;3 ARC~ AbASKA~ TNC. 2V-9 KUP~RUK NORTH SLOPE,ALASKA TOP UPPER SAND BASE tIPPER SAND TOP bOWER SAND BaSE bOWER SAND P~TD TOTAb O£PTH COHPUTATInN DA~EI 2]?HAY-8$ PAGE DATE Olr SURVEY1:22-AP_R-85 KELb¥ BUSHZNG E:bEVA~']:ONI 109,00 r~ ENGINe:ER S HC'BRZ, DE ZNTERPObATED VAbUE& FOR CHOSEN'HORZZON& NEASURED DEPTH ~ELOW KB 7590,00 765 777~0000 0 79 6100 O0 25 6 6 5777. 5 6 5825.!i 57~6 59~5, 5806 6036. 5927 6069, 5960 6t65,52 6056' ,27 N 39 . 52 28 ,46 N 406 ,22 ARCO AbASKA, INC, 2V'9 KUPARUK NORTH SbDPE~ALASKA MARKER MEASURED DEPTH BEbOW KB DATE OF SURV~¥1'22-APR~B5 SURFACE bOOk,ION ORIGIN= 1343' FSb~ !tO' Fdb. SEC . ?liN. 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OPERATOR, WELL N~[E ~ND" NuMB ER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report y~ Well Hist°ry Samples Mud Log Core Chips Core Description RegSstered Survey Plat / Inclination Suruey Directional Survey Drill Stem Test Reports Production Test Reports Log Run Digitized Data ARCO Alaska, I, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 3-85 TRANSMITTAL NO:5197 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B 'P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS OPEN HOLE/SCHLUMBERGER (ONE * OF EACH LISTED.) 2U-8 2D-1 5" DIL/SFL-GR 03-24-85 RUN #1 3617-8089 2" DIL/SFL-GR 03-24-85 RUN #1 3617-8089 5" DEN/NEU-GR (PORO) 03-24-85 RUN #1 5700-8064 2" DEN/NEU-GR (PORO) 03-24-85 RUN #1 5700-8064 5" DEN/NEU-GR (RAW) 03-24-85 RUN #1 5700-8064 2" DEN/NEU-GR (RAW) 03-24-85 RUN #1 5700-8064 CYBERLOOK 03-24-85 RUN #1 5700-8064 5" D!L/SFL-GR 10-23-84 RUN #1 3477-6694 2" DIL/SFL-GR 10-23-84 RUN #1 3477-6694 5" FDC/CNL-GR (PORO) 10-23-84 RUN #1 6000-6654 2" FDC/CNL-GR (PORO) 10-23-84 RUN #1 6000-6654 5" FDC/CNL-GR (RAW) 10-23-84 RUN #1 6000-6654 2" FDC/CNL-GR (RAW) 10-23-84 RUN #1 6000-6654 5" BHC SONIC 10-23-84 RUN #1 6000-6684 2" BHC SONIC 10-23-84 RUN #1 6000-6684 CYBERLOOK 10-23-84 RUN #1 6000-6654 5" DIL/SFL-GR 03-28-85 RUN #1 3025-6934 2" DIL/SFL-GR 03-28-85 RUN #1 3025-6934 5" DEN/NEU PORO 03-28-85 RUN #1 3025-6910 2" DEN/NEU PORO 03-28-85 RUN #1 3025-6910 5" DEN/NEU RAW 03-28-85 RUN #1 3025-6910 2" DEN/NEU RAW 03-28-85 RUN #1 3025-6910 CYBERLOOK 03-28-85 RUN #1 6590-6880 5" DIL/SFL-GR 10-27-85 RUN 2" DIL/SFL-GR 10-27-85 RUN 5" DEN/NEU PORO 10-27-85 RUN 2" DEN/NEU PORO 10-27-85 RUN 5" DEN/NEU RAW 10-27-85 RUN 2" DEN/NEU RAW 10-27-85 RUN CYBERLOOK 10-27-84 RUN RECEIPT ACKNOWLEDGED: BPAE *DRILLING-BL B. CURRIER L. JOHNSTON CHEVRON MOBIL D & M*-BL W. PASHER EXXON PHILLIPS OIL *NSK CLERK-BL *J. RATHMELL-BL #2 2469-6748 #2 2469-6748 #2 2649-6722 #2 2649-6722 #2 264~Fr672~ #2 61 DATE: *STATE Q~' ALA SOHIO ~'~ oi/~ ~/st UN ION *K. TULIN/VAUL5 "1~r~6~' ¢°r~r~iSS;ot; ARCO Alaska, Inc. ' Post Office Bu^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2V Pad Wells 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, · Gruber Associate Engineer JG/tw GRU6/LI02 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PHASE ~-AS-BUILT WELL-~ ' *hru 16 LOCATED R9E, U M. LOCATION 5® · · · · 'N 09 17 ~ROTRACTED S788~ T tN, _-: ~, OF HORIZONTAL & VERTICAL iS ',,"h MENTS 2V NORTH & 2V MID. AS PER L~_ , -33,3' WELL 9 t': J6,048 36 x: 5C 8,701.86 Pod Elev. 79.7 I0' FWL WELL I0 Y: 5,965,988.41 x: 508,702.10 Pod Elev. 79.6 I0' FWL WELL II Y: 5,965,92_8.39 X= 508,7C2.06 Pod Elev. 79.8 09' FWL WELL 12 Y: ~ 365 e68 49 X: 508,702.16 Pod Elev 80.0 09' FWL WELL 13 ¥= 5,965,868.44 x= 508,4t I 94 Pod Elev. 79.-3 8 I' FEL WELL 14 Y= 5,965,928.44 X= 508,412.00 Pod Elev. 79.9 81' FEL WELL 15 WELL 16 Y: 5,965,988.35 X: 508,412-.01 Pod Elev. 80.0 80° FEL Y: 5,966,045.45 <: 508,412.01 Pcd Etev. 79.8 80' F EL · , , Long 0.3 Elev 74.E 1,545' FSL Lot. 70°19~05 Long 149°55'46 056'' 0 G Elev. 74.E 1,285' FSL Lct 7~o 19'05 Long t4~055'46 C59'' O.G. Clev. 74.C 1,225' FSL Lat. 70° 19'04.68 ~' L:n;. !49°55'46.c58' 0 G Elev. 74.0 1,163' FSL Lot. 70© 19' Long. ~ 49°55'54.5~~'' O.G. Elev. 73.2 1~ 163' FSL Lat. 70c'19 05.2~4 Long. !49c55' O.G. Elev. 73.2 I ,~23' FSL Let. 70°19'05.863'' Long. 149°55'54 52!" O.G. E!ev 73.3 1,283' FS L Lat. 70°19'06454'' Long. 149° 55'54.5t9'' O.G. Elev 755 I ,343' FSL */49th · . ~~ ~ HEREBY CE~T'cY 'HA-! AM PROPERL'¢ REGISTERED AND '"'~~ LICENSEE) TO PRAC-"ICE LAND SURVEYING IN THE STATE OF · .. UNDER MY D!RECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF 9-12,3-19-85 13-t6~ .3-25-85 ARCO Alaska, Inc. ?. :,,- DRILL SITE 2V ha :"~ CONDUCTOR AS- BUILT LOCATIONS Drawn By' VE Dwg. NO, NSK9.05.222d4 ARCO Alaska, Inc. ~"~ Post Office Bo..,)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the March monthly reports for the following wells- 1Q-3 2u-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 1 6 1 85 Alaska Oil & Gas Cons. CornnlisslOl~ Anchorage ARCO Alaska, Inc. is e Subsidiary of AtlanlicRichfieldCompany - ' .... STATE OF ALASKA -~ ALASKA L.._ AND GAS CONSERVATION CO,_ ,vllSSION MONTHLY REPORT OI= DRILLING AND WORKOVER OPERATIONS · Drilling well)~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-37 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21300 4. Location of Well atsurface 1343' FSL, 109' FWL, Sec.8, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB 6. Lease Designation and Serial No. ADL 25644 ALK 2575 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2V-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. Ma rch ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0630 hfs, 03/17/85. Drld 12-1/4" hole to 3635'. Ran, cmtd, and 9-5/8" csg. Drld 8-1/2" hole to 8100'TD (03/23/85). Ran logs. Ran & cmtd 7" csg. = 7974'. Secured well & RR @ 2400 hfs, 03/25/85. tstd PBTD 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 102'. Cement record not available at time. 9-5/8", 36.0#/ft, J-55, BTC esg w/FS @ 3617'. Cmtd w/940 sx CS Ill & 410 sx CS I. Perforated top job w/121 sx CS I. 7", 26.0#/ft, J-55, BTC csg w/FS ~ 8055'. Cmtd w/305 sx Class "G". this 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/FDC/6NL/GR/6al/SP f/8097' - 6000' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECE !¥ED APR t 6 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED NOTE--Repor~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 'TEMP'MRlz 5 Submit in duplicate ARCO' Alaska, Inc:''~ Post Office ~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ,:. r, ,:_ ~.-'.l.]; T H F.:ETURN ONE ~g.~'~hD F'Y CF TAPES (ONE-TAPE F'LI'~_, .... T!.-!!."£ T,F-'_:.AN2iffT'"TA{_, , .. M EMORAN OUM State of Alaska TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATION COMbIISSION C. Vf~. ~terton DATE: March 26, 1985 Lonnie C Smith Commissioner Bobby Foster~>~ Petroleum Ind'~ector FILE NO: D.BDF. 20 TELEPHONE NO: SUBJECT: Witness BOPE test on ARCO' s 2V-9, Sec. 8, TllN,R9E,UM, Permit No. 85-37. Wednesday, March 20, i985: The BOPE test began at 5:45 am and was ~0n-Ci~d~e=d'~t'-Tql~5~-am~ k~ the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 2V-9. Attachment 02-00IA(Rev. 10/79) O&8 f~4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Location: Sec ~ T/~/R g~- Drillin~ Contractor. , _ , _ Location, General OA~"' Well SignOX General Housekeeping '~"~ Rig ~X Date ~-~. O - ~' e resen a ve ? Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio BOPE Stack Annular Preventer / Pipe Rams ~_. Blind Rams / Choke Line Valves / H. C.R. Valve / Kill Line Valves ~ Check Valve / . Test Pressure ~~Casing Set @ ~/? ft. Ri ~,/e~t Representative l:/~/~/>/~5~'' ACCUMULATOR SYSTEM Test Results: Failures Full Charge Pressure ~'~"eO psig Pressure After' Closure/ ~ .~%5 psig Pump incr. clos. pres. 200 psig .... min~o sec. Full Charge Pressure Attained: ~ min/g5 sec. N2 ~ ~ ~;'" ,~.....,,'L~ psig Controls: Master ~_~ 5 / Remot.e~~Blinds switch cover ~. Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold~~ Test Pressure _~ No. Valves ,,/~t No. flanges Repair or Replacement of failed equipment to be made within Adjustable Chokes ~ Hvdrauically operated choke / , Test Time / Y~"~ hrs. days and Inspector/ Commission office notified. Remarks: Distribution orig. - A0&GCC cc - Operator cc - SuPervisor March 7, 1985 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unft 2V-9 ARCO Alaska, Inc. Permit No. 85-37 Sur. Loc. 1343' FSL, 109' F%YL, Sec. 8, TllN, R9E, UM. Btmhole Loc. 1169' FNL, 1098' FEL, Sec. 8, TllN, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill' the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of.drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the~spawning or migration of anadromous' fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. 'Kewin Kuparuk River Unit, 2V-9 -2- March 7, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~ truly yours, C. V. Chat~er~°n' Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COFR,~ISSION lc Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc-'~i Post Office. ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 6, 1985 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2V-9 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2V-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on March 11, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/LST/tw Alaska oil & ~as Cons. Conimissi0[~ Anchora§e PD/L54 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION C,.,MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE E~(x MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1343' FSL, 109' FWL, Sec.8, T11N, R9E, UN At top of proposed producing interval 1393' FNL, 1427' FEL, Sec.8, T11N, R9E, UN At total depth 1169' FNL, 1098' FEL, $ec.8, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 109', PAD 78' 6. Lease designation and serial no. ADL 25644 ALK 2575 9 Unit or lease name Kupa ru~X~r 10. Well number -" 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1098' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8082' MD, 6168' TVD feet ±2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 44 Ol(see20AAC25.035 (c) (2) 15. Distance to nearest drilling or completed iV-8A well ~° @ _~l~.O'Tv~feet 18. Approximate spud date 05/11/85 770! 310! psig@--Sl0L° F ... Surface psig@ 6024__ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole 8-1/2" Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER -- Grade Coupling H-40 Wel ~ J-55 BTC] HF-ERW ! HF-ERW Length MD TOP TVD 80' 36' 136' I MD BOTTOM TVD 116' I I 116' 355/+' I 2912' (include stage data) ~ 200 cf 950 sx AS III & 3519' 35' 135' I ] 350 sx Class G I 8048' 34' 134' 8082' I 6168' 300 sx Class G I ARCO Alaska, Inc., proposes to drill a Kuparuk River Fie]d development well to approximately 8082'MD (6168'TVD). Selected intervals will be ]ogged. A 20", 2000 psi annular diverter wil] be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It wi]l be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (18.~00 psi for annular). Expected maximum surface pressure is 2701 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is ca]culated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be ]eft in uncemented annuli through the permafrost interva]. 2V-9 will be %~¢ away from 2V-8A at ~t~o'Tvo There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be ]eft with a non-freezing fluid during any interruptions in the disposa] process. (see attached sheet). 23. I hereby certify that the foregoing is true and correct to the best of my knowledge Th e space by To~/~ Cs ?o n~u se---. CONDITIONS OF APPROVAL Samples required [~YES ~] NO Permit number APPROVED BY Form 10401 Rc.v 7-1-~0 Mud log required ~YES J~NO Approval date L .-o (L~T[ PD/PD54 ~ I Directional Survey required APl number ~YES []NO 50- O'7-- ~ -~7_i SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE March 7, 1985 Submit in triplicate PERMIT TO DRILL 2V-9 The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEiVE Alaska Oil & Anchor~go ............ ' ............................... : ...... TD .... (LOGG[NG PT) -- TVD=61~8 T~D=808~ 'ROP( .TARGET NORTH SURFACE'. LdCATION!i 1343' ESL It- ' t : ~ -t FEE' 'Ti J : TARGET L( [ ON ~ 1320, ENL. 1320 FEL SEC, 8. TIINi RgE:' '~ ! : ' !" ' ?' i" "' ' J · ~ : i ' ! J "/ ~ ;' ; t : , ' !t ''~ .l~'t ,~ . , ~ ~ . : ~ , . ' t ~ i : . ~ _ . ' J i . I ; , ' .... P AD' PROPOSEI~ i . . . ............. ~. -- 6 Surface Oiverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. #, 20" 2000 psi drilling spool w/lO'' side outletso / 5. 10'~ ball valves, hydraulically actuated~ w/lO~' lines to reserve pit. Valves to open automatically upon closure of annul ar preventer. &. 20" 2000 psi annular preventer. 7. 20" bell n~pple. Maintenance & Ooeration · ... · Upon initial ~nstallation close annular preventer and verify ~hat ball valves have opened properly. Close annular preventer and blow air through dtverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow :o surface is detected. If necessary~ manually override and close ball valve to upwind diverter line.. Do not shut tn well under any circumstances. 16" Conductor 7 6 mi ,> 11 ' ~ F 3, ii' - ~ODD P... X 13-5,'8'-- 5DC~PS[ 'SPACI~ SPCa,. 4. 13-5/8" - ~ I~! PIPE RAMS 5, 15-5/8" - 5C:C~ PS3 DR.~LL[NG SPCX:L K~LL 6, 13-5/8' - 5000 PS[ ~ P.A~'~VP:I:PE RAlu6 ON TCP, ?. 13--5/8'. - 5C~ PS! ~ / A ATC CAPAC1TY ,TEST . '!.O-ECK N,Z:) FIL.L ._~?O__~M.LAT(:R R~~IR TO F:'RCPER LEVEL t'fITH HYERN.LIC FLUID, 2. ~ THAT ACCLIdJ~AT~ ~ 1500 PS! EON'~TREAM CF' TIE REGM_A?CR,. 3, ~EVE T]I~E., TI-EN Q_CSE ALL t.J~TS S:[M. JLTAhE~Y AND I;~ TIE TINE N~ ~ EEI~IN]NG AFTER 4 3 2 ,,.I 13. 14. !;5--5/8' BOm sTACK TEST. !. FILL BOP STACX NO O-EKE t~r~NIFCLD WITH ARCTIC DIESEL. 2. Q-ECI( THAT ALL LCCX DI~ SCRE~ ]N t, ELU-EAD AR[ FULLY I;ETRACTE~ SF_AT TEST PLUG IN t~TH ~ING JT ~ ~ IN L~ O. OSE ~ P~-VENTE~ A~ WAN. IN. K]LL AN3 L]hE VALVES ADJACENT TO Ba:) STA(:X. ALL O'TI..EE 4. P;;~SD..I~ UP l'O 250 ~ I-ELD FC~ i0 ~N. O;F=A~ F'I~:SD.I~ TiDC~:~p_.,~ AND I-ICLD FC~ I0 t~N. ELEED I::~_c~__-c~ TO 0"F%'1~. - L];I~ VALVES. C:LCI~ TC:P PIPE ~ AND HCR VALVES CN KILL AND ~ TEST TO 250 PS] ~ 3N STEP WITH A 250 PS3 LOW AND 3000 I~! Ii]GM. TEs'r AS ~N STEP 4. D3 NIT I:~c'~ TES'T Al,,h' ~ THAT N:Tr A F'U..L CL~ PC~]T]V~ SF..Ak O-O<F_. _~n.~Y FI~NCI'~ lES1 O..i~ES THAI DD NDi FULJ.Y 0..__ · 8. CPEN TOm PIF~ P~ AND CLC~E BOTT~ PIPE P,~ TEST BCrF'FC~ PIPE ~ 'To 250 P~l AND 5000 g. CPEN BOTTOM PIPE RA~ ELAC~ CXYT RL~NG Jl'. N'~ lO. CL__n~_ BLII',D P. NelS AND TEST TO 250 PS:[ AI~ 30130 I~N~FII. D AND LZNES ~ FU..L CF hZI,,i-F~EZING FLUZD. SIT ALL YALVl~ IN I~LL]NG 12. TEST S'TANI:::PZPE VALVES.. KELLY, I~LY CCX:X~ DRILL PIPE SAFETY VALV~ AN3 INSIDE: Ea:' TO 250 P~! FDR~ SI~ ~~TO~ILLI~~VI~ ~y 'TI.~]~EAFTI~ FI.~IC~Y OPERATE !~ I~ILY. 51 OO84OO i~.V I :' CHECK LIST FOR NEW WELL PERMITS Company ..... /~v'"C,~ Lease & Well No. /(/'~, ~A ITEM APPROVE DATE (1) Fee /~2 thru 8) 1. Is e e 6. 7. 8. (3) Admin (~ ..... 9. (.~9.~ Zhru .12) 10. (10 and 1-2) 12. (13 thru 21) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. (5) BOP E ~/f~. ~.~-/. (22 th~u 26) YES the permit fee attached ......................................... · ........ ~ ..... ~ .... NO Is well to be located in a defined pool ............................. Is well located proper distance from property line ...... Is well located proper distance from other wells ........ Is sufficient undedicated acreage available in this pool Is well to be deviated and is wellbore plat included .... Is operator the only affected party ..................... Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed eeeeeeeeee®e~eeeeeeeeeeeeeeeeeeeeee Is the lease number appropriate Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig ..~? Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ Additional Remarks: REMARKS o mm Geology: H~__~_ LCS WVA.,/~.'~_~L JrT / rev: 10/29/84 6.CKLT Engineering: BEW ~ HJH .~ POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. L.,lW~ ~,,1 [ i i iii ii;.] ii! [:.]i PR F:',V iOU S T&PZ CO~IM.~NTS : MN '~'N ,CO ,',IT ','ZN T S UNIT TYP6 000 T¥PE 0 0 O: C ,A T E OOO 0 O0 CA'TE 015 097 007 003 S l Z E 055 065 055 O65 055 COOE LDP: .,_. 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