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Home My WebLink About195-1601. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9943'2110 9560' Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-545-1144 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9267' 7-5/8" 79' 121' BAKER 45 FA-36 BAKER 45 FA-36 SSSV: None 6234' 9267' 5752' 5-1/2" 16" KRU 2X-18 9374-9420' 9618-9638' 9666-9684' 9893' 5834-5868' 6020-6036' 6058-6072' 5089' 9930' Perforation Depth MD (ft): 3-1/2" 21' 5130' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025645 195-160 P.O. Box 100360, Anchorage, AK 99510 50-029-22608-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9217'MD/5714'TVD 9440'MD/5884'TVD 9459' Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3437' Burst 8/19/2025 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6273' Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:46 pm, Aug 05, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E= brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.05 14:44:16-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen 325-460 AOGCC witnessed BOP and annular test to 2500 psi. DSR-8/14/25 10-404 A.Dewhurst 12AUG25JJL 8/6/25 X RBDMS JSB 081825 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 5, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2X-18 (PTD# 195-160). Well 2X-18 was drilled and completed in 1996 as a gas lift Kuparuk producer . RWO installed a selective completion in 2010 and Coil sidetracked in 2011.The well has multiple holes in the tubing that will require a rig to pull and replace the tubing. If you have any questions or require any further information, please contact me at +907-545-1144 The 3-1/2” upper completion will be pulled from a pre-rig cut. New 3-1/2” completion including a new gas lift design, a non-sealing overshot and a stacked packer will be installed. 2X-18 Kuparuk Producer Tubing Swap PTD: 195-160 x-11Page 1 of 2 Pre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests Passed 2. DMY all GLM and leave lowest GLM open for circulating Completed 3. CMIT-TXIA 2500 psi Passed 4. Tubing cut at ~9176’ RKB above the packer. 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 2X-18. 2. Circulate well to SW. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. KWF will be used as needed if mechanical barrier does not pass 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/2500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. Install 3-1/2” Completion 6. RIH and attempt to pull tubing stub from seals a. If seals pull free complete well with new seal and stab back into seal assembly. b. If seals do not pull free continue with program below and run a stacker packer completion. 7. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 8. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 9. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 10. Land tubing hanger, RILDS, PT packoffs and set packer. 11. Pressure test tubing to 3,000 PSI. 12. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 13. Shear out SOV with pressure differential. 14. Install BPV and test. ND BOPE. NU tree. 15. Pull BPV and freeze protect well. 16. RDMO. Post-Rig Work 1. Run GLD. 2. Pull any plugs and ball/rod used for setting packer. 3. Pull catcher from 9264’ 4. Pull XX plug at 9267’ 2X-18 Kuparuk Producer Tubing Swap PTD: 195-160 x-11Page 2 of 2 General Well Information: Estimated Start Date: 8/19/2025 Current Operations: Shut-In, secured with plug below packer Well Type: Producer Wellhead Type: FMC GenIV , 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 2730 psi / 6200 TVD measured on 9/11/21 MPSP: 2110 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut. Install a new 3-1/2” completion with seals and or stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) Proposed Seal Replacement SchematicLast Updated: 15-Feb-112X-182X-18L2-02KOP 10,742', TD 11,287' MD2-3/8" slotted liner 9570'-11,136'3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco KBG2-9 gas lift mandrels TBDSeal assembly/PBR at 9200' MD3-1/2" FA-36 packer @ 9217' MD3-1/2" Camco X-nipple @ 9267' MD (2.812" min ID)3-1/2" Camco KBG2-9 "monitoring" mandrel @ 9313' (dummied)Baker Anchor seal assembly at 9440' MDBaker FA-36 packer @ 9440' MD3-1/2" tubing tail @ 9459' MD7-5/8" 29.7# L-80 shoe @ 5130' RKB5-1/2" 15.5# L-80 shoe @ 9930' RKB16" 62# H-40 shoe @121' RKBA-sand perfs 9618' - 9638' MD9666' - 9684' MDC-sand perfs 9374' - 9420' MD2X-18L1-01TD @ 10,672' MD2-3/8" slotted liner 9547'-10,672'2X-18L2TD @ 11,406' MD2-3/8" slotted liner 10,743'-11,405' 2X-18L1TD @ 11,221' MD2-3/8" sotted liner 9734'-11,221'2X-18L2-01KOP 9570', TD 10,886' MD2-3/8" slotted liner 9454'-10,622'KOP @ 9545' MD3-1/2" x 5-1/2" Gen-II whipstockKOP @ 9500' MD3-1/2" x 5-1/2" Gen-II whipstock2-3/8" liner top at 9454' MD. Includes 6' x 2.25" PBR~TOC 8760' 1995 CBT Proposed Stacker Packer SchematicLast Updated: 15-Feb-112X-182X-18L2-02KOP 10,742', TD 11,287' MD2-3/8" slotted liner 9570'-11,136'3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco KBG2-9 gas lift mandrels TBD3-1/2'' X 5-1/2" Packer (~9000)3-1/2'' X nippleNon sealing Overshot3-1/2" FA-36 packer @ 9217' MD3-1/2" Camco X-nipple @ 9267' MD (2.812" min ID)3-1/2" Camco KBG2-9 "monitoring" mandrel @ 9313' (dummied)Baker Anchor seal assembly at 9440' MDBaker FA-36 packer @ 9440' MD3-1/2" tubing tail @ 9459' MD7-5/8" 29.7# L-80 shoe @ 5130' RKB5-1/2" 15.5# L-80 shoe @ 9930' RKB16" 62# H-40 shoe @121' RKBA-sand perfs 9618' - 9638' MD9666' - 9684' MDC-sand perfs 9374' - 9420' MD2X-18L1-01TD @ 10,672' MD2-3/8" slotted liner 9547'-10,672'2X-18L2TD @ 11,406' MD2-3/8" slotted liner 10,743'-11,405' 2X-18L1TD @ 11,221' MD2-3/8" sotted liner 9734'-11,221'2X-18L2-01KOP 9570', TD 10,886' MD2-3/8" slotted liner 9454'-10,622'KOP @ 9545' MD3-1/2" x 5-1/2" Gen-II whipstockKOP @ 9500' MD3-1/2" x 5-1/2" Gen-II whipstock2-3/8" liner top at 9454' MD. Includes 6' x 2.25" PBR~TOC 8760' 1995 CBT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,646.0 2X-18 11/16/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled D&D packoff plug, set XX plug 2X-18 1/9/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: CTD LATERALS L1, L1-01, L2, L2-01, L2-01 DRILLED 2/11/2011 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 41.0 5,130.4 3,437.3 29.70 L-80 BTC-MOD PRODUCTION 5 1/2 4.95 37.1 9,930.0 6,272.6 15.50 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.3 Set Depth … 9,459.0 Set Depth … 5,897.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.3 36.3 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 489.7 489.0 8.34 NIPPLE 4.810 CAMCO DS LANDING NIPPLE 2.875 3,261.7 2,446.8 57.76 GAS LIFT 4.725 CAMCO KBG-2-9 2.818 5,631.7 3,698.8 59.48 GAS LIFT 4.725 CAMCO KBG-2-9 2.818 7,220.0 4,546.5 59.03 GAS LIFT 4.725 CAMCO KBG-2-9 2.818 8,419.5 5,162.1 54.90 GAS LIFT 4.725 CAMCO KBG-2-9 2.818 9,149.7 5,662.5 40.82 GAS LIFT 4.725 CAMCO KBG-2-9 2.818 9,200.1 5,700.6 40.88 LOCATOR 4.000 SEAL ASSEMBLY LOCATOR 2.850 9,203.5 5,703.2 40.81 PBR 4.800 POLISHED BORE RECEPTACLE 2.850 9,217.0 5,713.5 40.52 SEAL ASSY 4.000 ANCHOR SEAL ASSEMBLY 2.850 9,217.4 5,713.8 40.51 PACKER 4.560 BAKER 45 FA-36 PACKER 2.990 9,267.4 5,752.0 39.97 NIPPLE 4.180 CAMCO X-NIPPLE 2.812 9,313.2 5,787.1 39.92 PRODUCTION 4.725 CAMCO KBG-2-9 2.818 9,363.2 5,825.4 40.16 BLAST JOINT 4.250 BLAST JOINTS (2) 2.992 9,439.9 5,883.3 41.54 SEAL ASSY 4.000 ANCHOR SEAL ASSEMBLY 2.850 9,440.3 5,883.6 41.54 PACKER 4.560 BAKER 45 FA-36 PACKER 2.990 9,458.5 5,897.2 41.54 WLEG 4.500 BAKER WIRELINE ENTRY GUIDE 3.010 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,937.0 5,505.6 44.01 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8937' RKB 10/12/2022 2.992 8,952.0 5,516.4 43.63 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8952' RKB 10/12/2022 2.992 9,267.0 5,751.7 39.97 TUBING PLUG 3.5" XX plug w/25" fill extension (OAL = 45") 1/9/2025 0.000 9,390.0 5,845.8 40.77 LEAK LEAK AT 9390' RKB IDENTIFIED VIA LDL 12/31/2024 2.992 9,454.0 5,893.9 41.54 LINER TOP L2-01 Liner Top 2/9/2011 1.992 9,500.0 5,928.6 40.15 Whipstock - L2 BAKER GEN II WHIPSTOCK Baker 3.5" x 5.5" TTWS 1/29/2011 9,545.0 5,963.2 39.47 Whipstock - L1 BAKER GEN II WHIPSTOCK Baker 3.5" x 5.5" TTWS 1/13/2011 9,560.0 5,974.8 39.38 Whipstock BAKER GEN II WHIPSTOCK **ABANDONED** Baker 3.5" x 5.5" TTWS 1/6/2011 9,560.0 5,974.8 39.38 FISH BAKER SETTING ADAPTER 1/6/2011 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,261.7 2,446.8 57.76 1 GAS LIFT GLV BTM 1 1,300.0 5/28/2023 0.188 5,631.7 3,698.8 59.48 2 GAS LIFT GLV BTM 1 1,309.0 5/28/2023 0.188 7,220.0 4,546.5 59.03 3 GAS LIFT OV BTM 1 0.0 5/26/2023 0.188 8,419.5 5,162.1 54.90 4 GAS LIFT DMY BTM 1 0.0 4/8/2022 0.000 9,149.7 5,662.5 40.82 5 GAS LIFT OPEN 1 0.0 11/24/2023 1.000 9,313.2 5,787.1 39.92 6 PROD DMY BTM 1 0.0 9/18/2022 Exten ded Packi ng 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,374.0 9,394.0 5,833.7 5,848.8 C-4, 2X-18 9/20/2008 6.0 APERF 2" PowerJet HSD 60 deg. ph; Random 2X-18, 1/10/2025 8:18:09 AM Vertical schematic (actual) PRODUCTION; 37.1-9,930.0 APERF; 9,666.0-9,684.0 FRAC; 9,666.0 IPERF; 9,618.0-9,638.0 FRAC; 9,618.0 L1-01 LINER; 9,547.0-10,672.0 LINER TOP; 9,454.0 PACKER; 9,440.3 APERF; 9,394.0-9,420.0 LEAK; 9,390.0 APERF; 9,374.0-9,394.0 PRODUCTION; 9,313.2 TUBING PLUG; 9,267.0 PACKER; 9,217.4 GAS LIFT; 9,149.7 LEAK - TUBING; 8,952.0 LEAK - TUBING; 8,937.0 GAS LIFT; 8,419.5 GAS LIFT; 7,220.0 GAS LIFT; 5,631.7 SURFACE; 41.0-5,130.4 GAS LIFT; 3,261.7 NIPPLE; 489.7 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 41.00 RR Date 5/9/1996 Other Elev… 2X-18 ... TD Act Btm (ftKB) 9,943.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292260800 Wellbore Status PROD Max Angle & MD Incl (°) 60.89 MD (ftKB) 7,979.99 WELLNAME WELLBORE2X-18 Annotation Last WO: End Date 12/21/2010 H2S (ppm) 71 Date 12/27/2013 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,394.0 9,420.0 5,848.8 5,868.4 C-4, C-3, C-2, 2X-18 11/30/2009 6.0 APERF 2" Millenium HSD, 60 deg random 9,618.0 9,638.0 6,019.9 6,035.6 A-4, 2X-18 5/9/1996 4.0 IPERF 2 1/8" Enerjet, 180 deg. ph; Oriented Normal 9,666.0 9,684.0 6,057.7 6,071.9 A-3, 2X-18 9/22/2001 6.0 APERF 2 1/8" EJ PJ; +/- 90 deg ph; Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,666.0 9,684.0 1 FRAC 11/28/2003 0.0 0.00 0.00 9,618.0 9,638.0 2 FRAC 11/28/2003 0.0 0.00 0.00 2X-18, 1/10/2025 8:18:10 AM Vertical schematic (actual) PRODUCTION; 37.1-9,930.0 APERF; 9,666.0-9,684.0 FRAC; 9,666.0 IPERF; 9,618.0-9,638.0 FRAC; 9,618.0 L1-01 LINER; 9,547.0-10,672.0 LINER TOP; 9,454.0 PACKER; 9,440.3 APERF; 9,394.0-9,420.0 LEAK; 9,390.0 APERF; 9,374.0-9,394.0 PRODUCTION; 9,313.2 TUBING PLUG; 9,267.0 PACKER; 9,217.4 GAS LIFT; 9,149.7 LEAK - TUBING; 8,952.0 LEAK - TUBING; 8,937.0 GAS LIFT; 8,419.5 GAS LIFT; 7,220.0 GAS LIFT; 5,631.7 SURFACE; 41.0-5,130.4 GAS LIFT; 3,261.7 NIPPLE; 489.7 CONDUCTOR; 42.0-121.0 KUP PROD 2X-18 ... WELLNAME WELLBORE2X-18 ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5229 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 5229 2X-18 50029226080000 Pressure Temprature Survey 31-Dec-2024 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 195-160 T39936 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:12:01 -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 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-12_21099_KRU_2X-18_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21099 KRU 2X-18 50-029-22608-00 Leak Detection Survey 12-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:195-160 T37173 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.20 12:52:13 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-12_2110_KRU_2X-18_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21100 KRU 2X-18 50-029-22608-00 Caliper Survey w/ Log Data 12-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:195-160 T37173 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.20 12:48:54 -08'00' o • 41110-7- a) � I- T n _8 '0:: 0) ) 0 a o > E '^ U✓ ILrw 9 a) O L s N O qO 4-' (0 > (9 ( O�w N Y — D (0E -0-.) 11 Qa , o - rn U E v � _Y V d (0 C O .., C✓ fa 'L Y W as O a f0 Q a ..- a u 0 Q L" n n n n n n n n n N a) a O O m D a a a o. a s b. c a 4 J N 67 N' N G) d G1 01 N t. 2 wv) Vnv) v) unrn N (ncnC (0 u -C v C cf) FZ - N M Io CO n CO 00 0 ++ L C C N N N N N N N N N U -0 (0 0 }' z d c .> v et 0O C L F.- (0 C 'O N U 0 0 0 0 0 0 0 0 0 (1) Q L J J J J J J J J J - C 4- U O LU.' 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U ,- CD WIn 4) (9 a) u 0. Z • ,� v a) d N "f a N E z ,_ . Z O - . N N 0 N CO CO M M 4, ' ` 1- 00 A = CE N LO n J D 7 X m 0 0 0 N N E Z a) (a0 _ a d O N J N N N N M N N (� to Y w (0 YCO Ln ._ v v) 'I c R 3 m ar a 0 'moi n~. 0 d F- a a Q • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conse rvation Comm. January 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Whipstock Setting Record: 2X -18 Run Date: 1/13/2011 WittiNEV FEB 01 ZODU 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 2X -18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22608 -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 1 5--460 ac,(0 Office: 907- 273 -3527 Fax: 907 - 273 -3535 rafael.barretogallibdrton' com . . Date: Signed: ,5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 vatifiED FEB ( I 1 aUll RE: Whipstock Setting Record: 2X-18 Run Date: 1/6/2011 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 2X-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22608-00 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. 6 6 7- 162 0 gObt Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@hill*prioni rs1 Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 20, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting / Junk Basket / Gauge Ring: 2X -18 Run Date: 12/17/2010 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 2X -18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22608 -00 FEB 0 I all 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. / 9 c Anchorage, Alaska 99518 b J ( � Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.woo . lib err. c`a Date: Signed . • • WELL LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. November 30, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 2X -18 Run Date: 11/23/2010 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 2X -18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22608 -00 MiNED FEB tt 1 2011 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 ,95 Office: 907 - 273 -3527 _So /u Fax: 907-273-3535 0O klinton.wood @halliburton.com s cal'', i . ,- - Date: (Noska f7.1 ''-. aa3 { ,j_;". :: , 71Mi3.5;.)r •� 0`1� Signed: [ 5.--- I • 0 S WELL LOG TRANSMITTAL pRoAcTivE DINNOSTIC SERA/1M, 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 ED FEB 1 a " 130 West International Airport Road yt Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 17 2X-18 1 Report / EDE 50-029-22608-00 2) 19 6 - go 0 ) ( 0 q‘ .,/ ._ . Signed : ..._ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraoe@memonfloo.com WESSITE : wwW.MeMONIOCLCOM CADocuments and Settings \Diane Williams \Desktopqnulsmit_Conoco docx 1 • • I a Multi - Finger Caliper Lo g Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2X -18 Log Date: December 17, 2010 Field: Kuparuk Log No.: SO# 10294433 ZX70 State: Alaska I Run No.: 1 API No.: 50- 029 - 22608 -00 Pipet Desc.: 5.5" 15.5 Ib. L -80 Top Log Intvl: Surface Pipet Use: Production Casing Bot. Log Intvl: 9,622 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the CBL log dated December 5, 1995. This log was run to assess the condition of the production casing with respect to corrosive and mechanical I damage. The caliper recordings indicate the 5.5" production casing logged appears to be in good to fair condition, with a maximum recorded wall penetration of 35% recorded at an isolated pit in joint 216 (9,253') and joint 222 II (9,483'). Outside of the perforation interval, additional wall penetrations ranging from 23% to 34% wall thickness are recorded in 3 of the 225 joints logged. No significant areas of cross - sectional wall loss are recorded throughout the production casing logged. Deposits are recorded in joint 30 (1,315'), restricting the I.D. to 4.74 ". No other significant I.D. restrictions are recorded throughout the production casing logged. I A graph illustrating minimum recorded diameters on a joint-by-joint basis is included in this report. The caliper recordings indicate a bend in the surface casing at —5,290'. 1 This summary report is interpretation of data provided by Halliburton Well Services. I MAXIMUM RECORDED WALL PENETRATIONS : Isolated Pitting ( 35 %) Jt. 216 @ 9,253 Ft. (MD) Isolated Pitting ( 35 %) Jt. 222 @ 9,483 Ft. (MD) I Line of Pits ( 34%) (32 %) Jt. 223 9,492 Ft. (MD) Isolated Pitting Jt. 215 @ 9,213 Ft. (MD) Isolated Pitting ( 23 %) Jt. 177 @ 7,596 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 10 %) are recorded throughout the casing logged. I MAXIMUM RECORDED ID RESTRICTIONS : Deposits Minimum I.D. = 4.74" Jt. 30 @ 1,315 Ft. (MD) 1 No other significant I.D. restrictions are recorded throughout the casing logged. 1 Field Engineer: M. Biery Analyst: C. Waldrop Witness: L Hinkel 1 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 1 i `5-- C) 6C0(/ I • • Correlation of Recorded Damage to Borehole Profile 1 ® Pipe 1 5.5 in (45.9' - 9577.2') Well: 2X -18 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: December 17, 2010 I I II Approx. Tool Deviation 1. Approx. Borehole Profile 1 46 I 25 ill 1074 I 50 1 2142 I 75 3210 I 100 i 4278 E 1 i Li Z 125 j 5353 s 'o I 150 1 6416 I 175 7487 i 200 I 8554 I 225 9577 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 225 I I I • • I Minimum Diameter Profile Well: 2X -18 Survey Date: December 17, 2010 Field: Kuparuk Tool: UW MFC 40 No. 10003099 HAL I Company: Country: ConocoPhillips Alaska, Inc. Tool Size: Tubing I.D.: 2.75 inches USA 4.95 inches I Minimum Measured Diameters (In.) 2.75 3 3.25 3.5 3.75 4 4.25 4.5 4.75 6 11 • 16 21 26 31 36 • I 41 46 51 56 I 61 66 71 76 81 86 91 • • 96 I 101 . 106 • • 111 Z C • 116 I s 121 _ - 126 131 136 I 141 146 151 _ 156 I 161 166 171 176 _ I 181 186 191 196 I 201 206 211 216 I 221 TS I I • • I PDS Report Overview �� Body Region Analysis I Well: 2X -18 Survey Date: December 17, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 10003099 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 5.5 ins 15.5 ppf L -80 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 5.5 ins 15.5 ppf L -80 4.95 ins 5.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 2 50 ■ Penetration body MIN Metal loss body 0 50 100 I 200 1 150 100 i 50 0 51 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 225j - I 217 5 0 3 101 I Damage Configuration ( body) a 10 I 151 5 I . _ 0 1 I Isolated General Line Other Hole/ 201 Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 7) 7 0 0 0 0 Bottom of Survey = 225 • I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 5.5 in 15.5 ppf L -80 Well: 2X -18 Body Wall: 0.275 in Field: Kuparuk I Upset Wall: 0.275 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 4.950 in Country: USA Survey Date: December 17, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % pset Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 46 0 0.02 7 2 4.94 1 2 85 0 0.02 7 3 4.93 1 3 128 0 0.03 9 2 4.94 • 4 169 0 0.02 7 1 4.94 I 5 212 0 0.02 8 1 4.93 I 6 256 299 0 0.03 11 2 4.94 • • 7 0 0.03 12 2 4.93 • 8 342 0 0.03 10 2 4.94 U 9 385 0 0.02 7 2 4.94 1 I 10 429 0 0.01 5 1 4.94 11 472 0 0.02 7 2 4.95 I 12 515 0 0.01 5 2 4.96 13 559 0 0.01 5 1 4.95 I 14 600 (1 0.01 5 2 4.93 15 643 0 0.01 5 1 4.95 16 686 0 0.01 5 1 4.95 1 17 729 0 0.02 6 2 4.92 il I 18 773 0 0.01 5 1 4.95 19 816 0 0.01 5 1 4.94 20 858 0 0.01 5 1 4.94 I 21 902 0 0.01 5 1 4.94 1 22 945 0 0.02 7 2 4.96 I 23 988 0 0.01 5 1 4.96 24 1031 0 0.02 6 1 4.95 I 25 1074 0 0.02 7 1 4.95 B 26 1116 () 0.01 5 1 4.95 e I 27 1158 0 0.02 7 2 4.95 28 1200 0 0.02 7 1 4.95 V II 29 1244 0 0.02 7 3 4.93 30 1287 0 0.03 11 2 4.74 Deposits. • I 31 1330 (1 0.02 6 1 4.85 Lt. Deposits. 32 1373 0 0.01 5 1 4.91 Lt Deposits. 33 1417 0 0.02 6 1 4.94 1 34 1459 O 0.01 5 1 4.95 1 35 1502 0 0.02 8 2 4.93 • I 36 1545 0 0.01 5 1 4.94 37 1588 0 0.01 5 1 4.94 38 1631 0 0.02 7 1 4.94 • 39 1674 0 0.02 6 2 4.94 o I 40 1718 0 0.01 5 1 4.95 41 1761 0 0.01 4 1 4.93 1 42 1804 0 0.02 7 1 4.92 43 1846 0 0.01 5 1 4.91 iii I 44 1888 0 0.02 6 1 4.95 45 1932 0 0.02 7 2 4.95 46 1975 0 0.01 5 1 4.96 1 47 2016 0 0.01 5 2 4.93 I 48 2059 0 0.02 7 2 4.95 49 2099 0 0.02 7 1 4.92 50 2142 0 0.02 6 1 4.93 I Peation Body I Metal Loss Body Page 1 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 5.5 in 15.5 ppf L -80 Well: 2X -18 Body Wall: 0.275 in Field: Kuparuk I Upset Wall: 0.275 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 4.950 in USA Survey Date: December 17, 2010 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 51 2186 0.02 7 2 4.93 52 2228 O 0.02 6 2 4.94 53 2272 0 0.02 7 1 4.92 m 54 2315 0 0.02 6 1 4.94 1 I 55 2358 0 0.02 6 2 4.94 ; 56 2402 0 0.02 7 2 4.94 , 57 2443 0 0.02 6 2 4.95 58 2486 0 0.02 8 1 4.94 • 59 2530 0 0.01 5 1 4.95 I I 60 2573 0 0.01 4 1 4.94 61 2614 0 0.01 5 1 4.95 I 62 2657 0 0.01 5 1 4.93 63 2699 0 0.02 6 2 4.93 1 I 64 2741 O 0.01 5 1 4.94 65 2784 0 0.02 6 1 4.93 66 2827 0 0.01 5 2 4.94 I 67 2869 0 0.02 7 1 4.92 a I 68 2912 0 0.02 6 1 4.95 69 2955 0 0.02 6 1 4.93 70 2998 0 0.01 5 2 4.94 1 71 3039 0 0.02 9 2 4.94 • 72 3081 0 0.01 5 2 4.94 I I 73 3124 0 0.01 5 1 4.95 74 3167 (1 0.01 5 1 4.94 1 75 3210 () 0.01 5 1 4.93 76 3254 0 0.02 7 1 4.95 • I 77 3297 0 0.02 6 2 4.94 78 3340 0 0.02 7 2 4.93 79 3383 0 0.02 7 1 4.95 • 80 3427 0 0.02 6 2 4.96 1 81 3467 82 3510 0 0.02 7 1 4.94 0 0.02 6 1 4.94 83 3553 0 0.02 7 2 4.95 1 84 3595 0 0.02 6 1 4.93 85 3638 0 0.02 7 1 4.94 1 I 86 3682 (1 0.02 7 2 4.92 • 87 3725 0 0.02 6 2 4.94 C 88 3768 0 0.01 5 1 4.93 89 3812 0 0.02 7 2 4.93 e I 90 3854 0 0.01 5 1 4.95 91 3895 0 0.02 7 2 4.94 • 92 3935 0 0.02 8 2 4.94 • 93 3978 0 0.02 8 2 4.95 • I 94 4019 0 0.02 7 1 4.93 95 4062 0 0.02 6 1 4.94 96 4106 0 0.01 5 1 4.94 97 4149 0 0.02 6 I 4.94 1 98 4191 0 0.01 5 1 4.93 1 I 99 4235 0 0.03 10 2 4.95 100 4278 0 0.01 5 1 4.94 rat I Metal Loss ion Body Page 2 Penet I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 15.5 PP f L -80 Well: 2X -18 Body Wall: 0.275 in Field: Kuparuk I Upset Wall: 0.275 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 4.950 in USA Survey Date: December 17, 2010 I Joint Jt. Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 101 4321 0 0.02 7 1 4.93 102 4364 0 0.02 7 2 4.91 Iti • 103 4407 0 0.01 5 1 4.94 1 104 4451 0 0.01 5 1 4.91 105 4494 0 0.02 7 2 4.93 I 106 4537 0 0.02 6 1 4.92 107 4581 0 0.02 6 1 4.92 II 108 4624 0 0.02 7 1 4.92 1 109 4667 0 0.02 7 2 4.93 I 110 4711 0 0.02 6 2 4.93 111 4754 0 0.01 5 1 4.94 112 4797 0 0.02 6 1 4.94 1 113 4839 0 0.02 8 1 4.91 • I 114 4880 0 0.02 7 1 4.92 115 4923 0 0.02 8 1 4.92 • 116 4967 0 0.03 11 1 4.94 • 117 5010 0 0.01 5 1 4.93 1 I 118 5052 0 0.02 7 1 4.91 119 5096 0 0.02 7 1 4.93 120 5139 0 0.02 8 1 4.92 II • 121 5182 0 0.02 6 1 4.94 122 5225 0 0.03 10 1 4.95 • I 123 5269 _ 0 0.02 8 1 4.92 Bend. • 124 5312 0 0.02 9 1 4.93 • • 125 5353 0 0.03 12 2 4.91 126 5397 0 0.02 8 1 4.91 m I 127 5438 0 0.03 9 2 4.94 • 128 5479 0 0.03 9 1 4.93 • 129 5521 0 0.02 7 1 4.93 II 130 5564 0 0.03 10 1 4.93 • I 131 5607 0 0.02 6 1 4.94 132 5651 0 0.01 5 1 4.95 1 133 5692 0 0.01 5 1 4.94 1 134 5735 0 0.02 7 2 4.93 II 135 5777 0 0.02 7 2 4.94 I 136 5819 0 0.02 8 2 4.94 137 5862 0 0.02 7 2 4.93 138 5906 0 0.02 6 2 4.93 139 5949 0 0.02 6 1 4.93 II I 140 5992 141 6033 0 0.01 5 2 4.94 0 0.01 5 1 4.92 142 6073 0 0.01 5 1 4.93 I 143 6117 0 0.02 7 1 4.92 • I 144 6160 0 0.02 6 1 4.91 145 6203 0 0.02 7 2 4.92 II 146 6247 0 0.01 5 1 4.93 II I 147 6289 0 0.02 6 1 4.92 II 148 6332 0 0.02 7 1 4.93 0 I 149 6374 0 0.02 6 I 4.93 • 150 6416 0 0.02 6 1 4.94 • rat I Metal Loss ion Body Page 3 Penet 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 5.5 in 15.5 ppf L -80 Well: 2X -18 Body Wall: 0.275 in Field: Kuparuk ' Upset Wall: 0.275 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 4.950 in Country: USA Survey Date: December 17, 2010 I I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 151 6459 0 0.02 6 2 4.93 152 6502 0 0.02 8 2 4.93 • 153 6545 0 0.02 6 1 4.94 1 154 6588 0 0.01 5 1 4.92 1 155 6631 0 0.02 8 1 4.93 • I 156 6674 0 0.02 6 1 4.92 157 6717 0 0.02 6 1 4.94 1 158 6758 0 0.02 7 2 4.94 1 159 6801 0 0.02 6 1 4.94 1 I 160 6845 161 6888 0 0.02 8 1 4.93 0 0.02 6 2 4.92 • II 162 6930 0 0.02 7 1 4.93 163 6972 0 0.02 6 2 4.93 11 I 164 7015 0 0.01 5 1 4.94 165 7058 0 0.02 9 1 4.93 • 166 7101 O 0.02 8 2 4.91 1 167 7145 0 0.02 7 1 4.93 I 168 7187 0 0.01 5 1 4.92 169 7230 0 0.02 6 1 4.91 170 7274 0 0.02 6 2 4.92 1 171 7317 0 0.01 5 1 4.95 1 172 7358 0 0.02 7 2 4.94 1 I 173 7401 0 0.02 8 2 4.91 174 7444 O 0.02 7 1 4.92 • • 175 7487 0 0.02 8 1 4.92 • 176 7530 0 0.02 7 2 4.92 I 177 7572 0 0.06 23 3 4.91 Isolated Pitting. 178 7615 0 0.03 9 2 4.90 a 179 7659 0 0.03 11 2 4.92 180 7701 0 0.02 8 2 4.91 I • 181 7744 0 0.03 9 2 4.90 182 7787 0 0.02 9 2 4.91 183 7831 0 0.03 9 2 4.92 184 7870 0.03 0.03 10 2 4.92 • 185 7913 0 0.03 11 3 4.91 I 186 7956 0 0.02 6 2 4.90 187 7999 0 0.03 9 2 4.90 • 188 8042 0 0.02 6 1 4.92 1 189 8086 0 0.02 7 2 4.92 v I 190 8129 0 0.02 7 2 4.92 191 8172 0 0.02 6 2 4.90 I 192 8215 0 0.02 7 1 4.93 1 193 8259 0 0.02 6 1 4.93 a I 194 8301 0 0.03 11 1 4.90 195 8344 0 0.02 9 3 4.92 • • 196 8387 0 0.01 5 1 4.94 1 197 8428 0 0.02 8 2 4.91 11 I 198 8471 0 0.02 6 2 4.93 1 199 8513 0 0.02 8 2 4.94 200 8554 0 0.01 5 2 4.92 II Bo I Metal Loss Body I Page 4 Penetration 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 5.5 in 15.5 ppf L -80 Well: 2X -18 Body Wall: 0.275 in Field: Kuparuk I Upset Wall: 0.275 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 4.950 in USA Survey Date: December 17, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( % wall) (Ins.) (Ins.) % (Ins.) 0 50 100 201 8597 0 0.02 8 1 4.92 a 202 8639 0 0.02 7 1 4.91 • 203 8678 0 0.01 5 1 4.93 1 204 8720 0 0.02 7 1 4.93 1 I 205 8764 0 0.02 7 1 4.92 i 206 8806 0 0.03 10 2 4.90 • 207 8850 0 0.02 8 2 4.91 • 208 8893 0 0.02 7 1 4.92 209 8936 0 0.02 6 1 4.93 Iii I 210 8979 0 0.02 7 1 4.94 • 211 9020 0 0.02 7 1 4.91 • 212 9064 0 0.01 5 1 4.94 213 9104 0 0.03 10 2 4.91 • I 214 9146 0 0.03 10 2 4.91 215 9190 0 0.09 32 2 4.92 Isolated Pitting. N MI 216 9233 0 0.10 35 9 4.92 Isolated Pitting. 217 9275 0 0.04 15 3 4.91 Shallow Pitting. I E 218 9318 0 0.04 13 1 4.91 Shallow Pitting. 219 9361 0.04 0.33 100 8 4.88 Marker Ioint. Perforations. 220 9382 0.07 0.29 100 5 4.89 Marker Joint. Perforations. 221 9404 0.11 0.31 100 5 4.89 Perforations. 222 9448 0.08 0.10 35 4 4.90 Isolated Pitting. I 223 9491 0.09 0.09 34 3 4.88 Line of Pits. Lt. Deposits. 224 9534 0 0.02 9 2 4.91 • 225 9577 0 0.03 12 1 4.92 • I Penetr Metal Los io s Body I I I I I I Page 5 I I I • 0 I Js PDS Report Cross Sections I Well: 2X -18 Kuparuk Survey Date: December 17, 2010 Field: Tool Type: UW MFC 40 No. 10003099 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 5.5 ins 15.5 ppf L -80 Analyst: C. Waldrop I I Cross Section for Joint 216 at depth 9252.520 ft Tool speed = 51 Nominal ID = 4.95 _ I Nominal OD = 5.5 Remaining wall area = 92% /' Tool deviation = 39° I / I I I I I Finger = 2 Penetration = 0.096 ins Isolated Pitting 0.10 ins = 35% Wall Penetration HIGH SIDE = UP I I I I 1 • • I PDS Report Cross Sections VS. I Well: 2X -18 Survey Date: December 17, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 10003099 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 5.5 ins 15.5 ppf L -80 Analyst: C. Waldrop I Cross Section for Joint 222 at depth 9483.250 ft Tool speed = 51 Nominal ID = 4.95 I Nominal OD = 5.5 Remaining wall area = 99% Tool deviation = 41° I 1 / I I I I I I Finger = 16 Penetration = 0.097 ins Isolated Pitting 0.10 ins = 35% Wall Penetration HIGH SIDE = UP I I I 1 I I • • I PDS Report Cross Sections 1 VS Well: 2X -18 Survey Date: December 17, 2010 I Field: Kuparuk Tool Type: UW MFC 40 No. 10003099 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 5.5 ins 15.5 ppf L -80 Analyst: C. Waldrop I I Cross Section for Joint 30 at depth 1314.970 ft Tool speed = 50 Nominal ID = 4.95 I Nominal OD = 5.5 Remaining wall area = 100% Tool deviation = 32° 1 I II 1 _ I I Minimum I.D. = 4.737 ins Deposits Minimum I.D. = 4.74 ins HIGH SIDE = UP I I I I I KUP 2X -18 I ConocoPhi Ili ps y ttribtRes M tilt & MD TD A I APL'U'JJI 19001 Nile !Well Status !Edit 8011)8 61 bidet Act Biro (itF' .� "tD ''t YC . f 0292260800 KUPARUK RIVER UNIT PROD 6 7,979.99 9,943. Com iR4 Com ment lEdit Ht S(ppm) Cab I Annotator !Bid Dab l F: B4rd(tt1 Rig Rebate !Ed SSSV: NIPPLE 10 1/13,2S10 Last WO: I 41.00 5/9/1996 arm, r- r Annotation Dept) CHEM Bid Drip Annotation tart Mod t3; Bid Cate �Edit Loot Tog: SLM 9,668.0 616/211110 Rev Reason: TAO imosbor 6!1420 0 ■ _ Casing Strings iii 1) r 1 l I it ilk 11 t l I I 1 , eating Ceaenp8on Sting OD.. Siring ID... Top (rtf: B.I sot Dept! it... set Ceptn,Tvo 'At.. Sting t.. SMng ... Sting Top ill CONDUCTOR 16 15062 0.0 121.0 121.0 62.50 H40 • CONDUCTOR, Caning Deaeip0On String OD.. String ID... Top (11. .0) Sot Dept, it._' Set Depth (TvD)... Siring Wt.. String.. Sting Top TII 0.121 SURFACE 7518 6.750 0.0 5,1300 3,437.0 29.70 L-80 Cs ling Dosaripton Sting OD.. Sting ID... Top (ttl. . Di sot Copt, it.. Set copal (Tub)... siring Wt.. string... Sting Top Tll PRODUCTION 512 4.653 0.0 9,930.0 _ 6,272.6 15.50 LSO Tubing Strings NIP LE. 509 I Tubing Cemripeon String 00.. String ID... Top MK. B) Cot Dept, it... Set Dept, (TVD) ... String Wt.. Sting... String Top Ti TUBING 3 12 2.992 0.0 3569.0 2,610.1 930 LSO ABM - El h I Tubing Lb lcrlpnon string D.. String ID... Top (0) set Copt, it.. sot Dept, (Tv0)... String Wt.. Sting... sting Top Ti TUBING 2718 2.441 3,569.0 3,639.0 2,647.1 6.50 LSO ABM - Eli r Tubing De topton Siring 00.. String ID... Top (100 5) Set ropth (t... Set Dept/ (TVD)... String Wt.. Sting... Sting Top T TUBING 312 2.992 3,639.0 7,180.0 4,525.8 9.30 L-80 ABM -El TObing E9 Fnnpton String O0... String ID... Top MKS) Sot Depth (t.. Set Dept, (ND)... String Jot.. String... String Top T1 TUBING 27/8 2.441 7,180.0 7,250.0 4,562.0 6,50 LSD ABM -Eli G °V 114T,, t: • Tubing Do oeripton Sting OD.. tiring ID... Top (MCP) Set Osp4A tt... Sot Depth (T1D)... eting 'Wt.. tiring... tiring Top T I TUBING 312 2.992 7,250.0 8.482.0 5,198.1 9.30 L-80 ABM -EU0 Tubing Delcnpton tiling OD.. Sting ID... Top ittk6) tot Depth 1.. Set Dept, (Too)... Sting Vet.. Siring ... String Top T TUBING 2718 2.441 8,482.0 8,552.0 5,240.3 6.50 LSD ABM -EL O I Tubing De teripton siring OD.. String ID... Top (dkB) lot Dept, (t.. Set Depth (T413)„. Sting Wt., string... String Top TI TUBING 312 2.992 8,552.0 9,180.0 5685.6 9.30 1.00 ABM -EL E Tubing De script on Sting O0... Sting ID... Top (ttkB) tat Dept, (t.. S t L`pht Mint... siring 'snit.. - sting... sting Top - n1 .UPf!A E, TUBING 2 718 2.441 9,180.0 9,281.0 5,782.4 6.50 L-80 ABM -EUt tr ,i3p Other In Hole ( retrievable plugs, valves, pumps, fish, etc.) !edit Tap Dept, f--, Tubing I TPDI Top no (TM 5) 111861 i °i Tnoripton Comment Run Dots ID(In) 509 508.1 9.10 NIPPLE Camco 'DS' Nipple 5/61996 2.812 I c".^, • 3,601 2,626.9 58.09 GAS LIFT CAM CO /KBMM /1 /GLV /B 10.156/1334/ Comment: STAI 12/1/2003 2.347 LIFT, 1: - c"';! 7,211 4,541.9 58.92 GAS LIFT CAM CO /KBMM /l /GLV /61(!.18811352 /Comment: STA2 12/12003 2.347 8,514 5,217.1 52.06 GAS LIFT CAMCOIKBMM/1 /GLV /BKi.25/1445/ Comment: STA3 12/12003 2.347 9,212 5,709.7 40.63 GAS LIFT CAMCO /KBMM /1/0VIBK/.188! /Comment: STA4 12/12003 2.347 ,-,-', 9,255 5,742.5 39.91 ANCHOR BAKER' KB H-22' ANCHOR 5/6/1996 2.500 I 9,256 5,743.3 39.90 PACKER Baker'3AB3' PACKER 516!1996 2.531 9,270 5,754.1 40.26 NIPPLE Camco'D' Nipple NO GO 5/6/1996 2.250 9,280 5,761.7 40.15 SOS Baker 516/1996 2.441 G +A LIFT. 9,281 5,762.4 40.14 TEL 5/6/1996 2.441 a ?la I Perforations & Slots Edit Shat Rim lop (TLD) Biro (Tun) Dont Top Mt DI (GOBI i[ton) i[tOOt :Ate Dab ilk.. Type Comment 9,374 9,394 5,833.7 5,848.8 C4, 2X - 18 9202008 6.0 APERF 2" PowerJet HSD 60 deg. ph; Random 9,394 9,420 5,049.9 5,969.4 C C C-2, 11/352009 6.0 APE RF 2" Millenium HSD, 60 deg random I 2X -19 9,618 9,638 6,019.9 6,035.6 A4, 2X -18 5/3/1996 4.0 IPERF 2 118" Enerjet. 180 deg. ph; Oriented Normal G• : urr. 9,666 9,684 6,057.8 6,0722 AS, 2X -18 9/22/2001 6.0 APERF 2 118" EJ PJ; +!-90 deg ph; 9 Stimulations & Treatments ![[lit Bottom Nit Top Mil @6P Top Depth Dept, Dept, Dept (ND) (ND) os0410P. ( Bj ( B) (ttk Bj itt85) Tpe ab 3,mment 9,618.0 9,684.0 6,019.9 6,03'5.6 FRAC 11282003 A-SAND FRAC 208,00001620 CARBOLITE I 9,618.0 9,684.0 6,057.8 6,072.2 FRAC 11262003 A -SAND FRAC 208.00001620 CARBOLITE FALLER Notes: General & Safety Edit 9 % End Co 5k/1995 5!5/1995 NOTE: 1 Jt. 012 7/8 - TBG run on each side of GLM's RIPPLE, 9270 I I TTL,9,281 I -_ N.377-9739i e PEPF, 9,39. -t a II IPEP ` =i , 9,6199 ■N ■ ■ FRAC ,9b19 I ARM, = I 9b66963eThs, P Ro DUCTBR, TP -N I I STATE OF ALASKA ALASK410_ AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 1 Rug Perforations r Stimulate r Other fl Alter Casing r Pull Tubing P' Fbrforate New Pool ; Waiver r Time Extension r Change Approved Rogram r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r y 195 - 160 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22608 - 00- 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25645 "t s 2X - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool t 10. Present Well Condition Summary: Total Depth measured 9943 feet Plugs (measured) None true vertical 6234 feet Junk (measured) None Effective Depth measured 9841 feet Packer (measured) 9217, 9440 true vertical 6150 feet (true vertucal) 5714, 5884 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5089 7 -5/8" 5130 3398 PRODUCTION 9893 5.5 9930 6223 CE E Perforation depth: Measured depth: 9374'- 9420', 9618'- 9638', 9666-9684' JAN 1 0 2011 True Vertical Depth: 5834'- 5868', 6020'- 6036', 6058' -6072' geke n GAS Ons& C session it nrnnrage Tubing (size, grade, MD, and TVD) 3.5, L - 80, 9458 MD, 5898 TVD Packers & SSSV (type, MD, and TVD) PACKERS - BAKER 45 FA -36 PACKER @ 9217 MD and 5714 TVD PACKERS - BAKER 45 FA -36 PACKER @ 9440 MD and 5884 TVD Nipple - Camco DS Nipple @ 490 MD and 489 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable }} � `j1 Treatment descriptions including volumes used and final pressure: Amex JAN 2 LUl 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 107 483 742 -- 200 Subsequent to operation si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory fl Development l ° Service r Stratigraphic 15. Well Status after work: / Oil 17 Gas r VVDSPL Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r 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: none Contact Ian Toomey (a. 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature-7 . Phone: 263 -4773 Date f (7/ 0(( RBDAAS �� Subm i7 Form 10-404 Revised 10/2010 JAN 1 0 1011 4- +�_ , ub 14,, 4 KU P 2X -18 ConoaPhilhips i Attributes Max Angle & MD TD A{CS i 4� -i Wellbore APIA/WI Field Name Well Status Intl (.) MD (9160) Act Btm (ftKB) c yet?: 500292260800 IKUPARUK RIVER UNIT PROD 60.89 ( 7,97999 9,943.0 C e t � De h � H25 (ppm) Date An otffiion End Date - KB - Grd (i Rig Release Date SSSV NIPPLE 10 1/13/2010 Last WO. 12/21/2010 41 0 0 5/9/1996 __ WRM_ ..Sri -14 ,,,11t44:2I1 "" .,. _ A tatlon pt I ) o RKB End Date Annotation Last Mod End Date Last Tag: SLM 9,646.0 11/16/2010 Rev Reason WORKOVER PRE CTD Imosbor 12125/2010 HANGER,36 "" ' w Casing Strings r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. Stri Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Th d SURFACE 7 5/8 6.750 41.0 5,130.4 3,437.3 29.70 L - 80 BTC MOD -- - - : Casing Description String O String ID . Top (ftKB) Set Depth (f... Set Depth (7VD) .String Wt... String String Top Thrd 9 c PRODUCTION 5 1/2 4 653 37 1 9,930.0 6,272.6 15 50 L-80 LTC MOD Tubing Strings T b ng Descption String 0 String ID .. Top (ftKB) Set Depth (1 . Set Depth (TVD) .. String Wt... String String Top Thrd 8 TUBING n 31/2 _ 2.992 36.3 I 9459.0 589/.6 9.30 L -80 IBT -M i Completion Detai CONDUCTOR, , Top Depth - -- _ 42 -121 (TVD) Top loci r. e ` ' Top (ftKB) (ft613) (1 Item Description Comment ID (in) 36.3 36.3 -0.08 HANGER FMC GEN IV TUBING HANGER 3.500 NIPPLE, 490 489.7 489.0 8.34 NIPPLE CAMCO DS NIPPLE 2.875 lir 9,200.1 5,700.6 40.88 LOCATOR SEAL ASSEMBLY LOCATOR 3.000 It 9,203.5 5,703.2 40.81 PBR POLISHED BORE RECEPTACLE 2.850 lit GAS UFr, _ _ _ 9,217.0 5,713.5 40.52 ANCHOR ANCHOR SEAL ASSEMBLY 3.000 3,262 9,217.4 5,713.8 40.51 PACKER BAKER 45 FA 36 PACKER 2.990 9,269.0 5,753.3 40.28 NIPPLE CAMCO X- NIPPLE w /RHC BODY 2.812 '; . 9,363.2 4 5,825.4 40.16 BLAST JOINT 2.992 II 9,439.9 5,883.3 41.54 ANCHOR ANCHOR SEAL ASSEMBLY 3.000 t 9,440.3 5,883.6 41.54 PACKER BAKER 45 FA -36 PACKER 2.990 SURFACE, - -- - - - " - 41-5,130 9455.5 SR9 L2' 41.54'INLEG BAKER WIRELINE ENTRY GUIDE 3.010 Perforations & Slots 9. GAS LIFT, Z c ... Shot -.... _ 5,632 Top (TVD) Btm (TVD) Dens Top (9103) Btm (ftKB) (ftKB) (ftKB) Zone Date (ah... Type Comment 9,374.0 9,394.0 5,833.7 5,848.8 C-4, 2X -18 9/20/2008 6.0 APERF 2" PowerJet HSD 60 deg. ph; Random GAS IFT, -- 9,394.0 9,420.0 5,848.8 5,868.4 C-4, C -3, C -2, 11/30/2009 6.0 APERF 2" Millenium HSD, 60 deg random 7,220 - 2X -18 9,618.0 9,638.0 6,019.9 6,035.6 A-4, 2X -18 5/9/1996 4.0 IPERF 2 1/8" Enei)et, 180 deg. ph; Oriented Normal 9,666.0 9,684.0 6,057.8 6,072.2. A -3, 2X -18 9/22/2001 6.0 APERF 2 1/8" EJ PJ; - -90 deg ph; GAS LIFT, _... - 8,419 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ft613) (ftKB) (ftKB) (ftKB) Type Date Comment GAS LIFT, r, %" 9,618.0 9,684.0 6,019.9 6,035.6 FRAC 11/28/2003 A FRAC 208,000# 16/20 CARBOLITE 9,150 a618.01 9,684.0 6,057 8 6,072.2 FRAC 11/28/2003 A-SAND FRAC 208,000# 16/20 CARBOLITE Notes: General & Safety End Date ' Annotation 12/25/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 LOCATOR, - -_ I 9,200 PBR,9,203 ANCHOR ... - -... *'. 9,217 PACKER, 9,217 NIPPLE, 9,269 - L1' GAS LIFT, Iff 9,313 I : APERF, I • 9,374 -9,394 I i APERF, I ) -.: 9,394 -9,420 i ).. I , Mandrel Details .. 41 x ANCHOR-_ , 9,440 Top (TVD) Top Port (rVD) Inc' OD Valve Latch Size TRO Run PACKER, 9,440 - - Stn Top (ftKB) (ftKB) (1 Make Model 0n) Sere TYpe Type ( (psi) Run Date Coma -- 1 3,261.7 2,446.7 57.44 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/20/2010 WLEG,9,459 ` .f 2 5,631.7 3,698.8 59.42 CAMCO KBG -2 -9 1 INJ DMY DK -1 0.000 0.0 12/20/2010 IPERF, 3 7,220.0 4,546.5 59.03 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/20/2010 9,616 -9,638 FRAC, 9,618 1 4 ,41 89.5 5,162.1 54.90 CAMCO KBG - 2 - 9 1 GAS LIFT DMY DK - 1 0.000 0.0 12/20/2010 . ApERF, 5 9,149.7 5,662.6 41.74 CAMCO KBG - 2 - 9 1 GAS LIFT SOV DCK3 0.000 0.0 12/20/2010 9,666 FRAC. 9.666 1 "" 6 9,313.2 5,787.1 39.89 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/20/2010 _ \_,A1 « � I PRODUCTION, 3 25.10 0 TD (2%'18), 9,943 1 • • ConocoPhillips Time Log & Summary We view Web Reporting Report Well Name: 2X - 18 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/8/2010 2:00:00 AM Rig Release: 12/21/2010 8:30:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/07/2010 24 hr summary Mobilize Rig to 2X 12:00 00:00 12.00 SURPRI MOVE MOB P Continue to Mobilize Rig to 2X -18 12/08/2010 Kill Well, ND Tree, NU BOPE 00:00 01:00 1.00 MIRU MOVE MOB P Arrive location, PJSM, Lay down liner and place T -mats 01:00 02:00 1.00 MIRU MOVE MOB P Rig over well, Accept rig at 0200hrs 02:00 08:00 6.00 MIRU WHDBO KLWL P Prep well for circ kill 08:00 11:00 3.00 MIRU WHDBO KLWL P PJSM,Circ 3bpm,ICP- 340,210 bbls away 11:00 12:00 1.00 MIRU WHDBO KLWL P Load Pits with second seaweater truck 12:00 14:00 2.00 MIRU WHDBO KLWL P CIRC, 3BPM, 190PSIG,MONITOR WELL, STILL BREATHING GAS, MIX HI VIS PILL 14:00 17:00 3.00 MIRU WHDBO KLWL P PUMP 30bbI HI -VIS PILL, CHASE WITH 90bbls SEAWATER, MONITOR WELL 17:00 20:00 3.00 MIRU WHDBONUND P SET BPV PJSM, N,I EE I 20:00 23:30 3.50 MIRU WHDBO NUND P PJSM, NU BOPE, 23:30 00:00 0.50 MIRU WHDBO BOPE P RU Test Equipment, Begin BOPE Test 12/09/2010 BOPE Test, Pulled 3.5" x 2.875" Completion from cut at 9234' 00:00 04:30 4.50 SURPRI WHDBO BOPE P Test BOPE 6°4° 04:30 06:00 1.50 SURPRI WHDBO SFTY P PJSM, Pull Blanking Plug / BPV 06:00 07:00 1.00 0 0 SURPRI RPEQP1 PULL P PJSM,Screw in landing joint and attempt to un -land hanger 1 L" 07:00 08:00 1.00 0 0 SURPRI RPEQP1 PULL P Pick up on tubing, Tubing free, pull hanger to floor and circulate 1X hole volume of 8.7ppg seawater. 105k up weight (max 110k) 08:00 12:00 4.00 0 0 SURPRI RPEQP1 PULL P PJSM,POOH Laying down tubing from 9234' 12:00 00:00 12.00 0 0 SURPRI RPEQP1 PULL P Completion OOH consisting of 283 jts 3.5 ", 7jts+ 1 partial jt (14.50') of 2 7/8, 4 GLM & 1 DS Nipple 12/10/2010 Rack and Tallied 312jts PH -6 in pipe shed,Made up Baker overshot with 2 7/8 grapple, Begin single in BHA on PH -6 DP 00:00 11:00 11.00 0 0 SURPRI RPEQP1OTHR P Rack and Tally 3.5" PH6 11:00 11:30 0.50 0 0 SURPRI RPEQP1 SFTY P PJSM, Prep for BHA make up Page 1 of 9 Time Logs • Date From To `` Dur S. Depth E Depth Phase Code Subcode T Comment 11:30 13:30 2.00 0 0 SURPRI RPEQP1 PULD P Make up Baker overshot with 2 7/8" grapple to retrieve anchor seal assembly as per rep 13:30 23:00 9.50 0 7,132 SURPRI RPEQP1TRIP P Start in hole BHA on PH -6 work string to 2 7/8 stub @ 9,225' MD. 23:00 23:30 0.50 7,132 7,132 SURPRI RPEQP1CIRC P PJSM,Stop and close annular bag, begin pumping down 5.5" with seawater flo -vis w /tube 776 23:30 23:45 0.25 7,132 7,132 SURPRI RPEQP1TRIP P 85bbls away, continue to single in BHA on PH -6 23:45 00:00 0.25 7,132 7,506 SURPRI RPEQP1TRIP P ContinueTlH 12/11/2010 p Retrieved 16.05' tubing stub with anchor seal assmebly from 9220' RKB, TIH with bha #2 to mill baker pak€r 1 at 9256' MD. 00:00 02:00 2.00 7,500 9,220 SURPRI RPEQP1TRIP P ContinueTlH 02:00 03:30 1.50 9,220 9,224 SURPRI RPEQP1 FISH P Set parameters up weight 118K down weight 93K ROT 105K 2K free torque. Continue in hole to 9,220 tag fish, swallow 4' of anchor assembly to 9,224', work up to 105K down 75K, pump @ 2 bpm 370 psi. ROT 12 turns to right, work jars up to 165K, came free. 03:30 04:00 0.50 9,224 9,220 SURPRI RPEQP1CIRC P Circulate bottoms up 04:00 12:00 8.00 9,220 0 SURPRI RPEQP1TRIP P TOOH with anchor assembly, standing back PH -6 12:00 16:00 4.00 0 0 SURPRI RPEQP1 PULD P On surface with anchor assembly, anchor assembly missing slips, lay down BHA #1. Make up BHA #2 as per Baker rep. 16:00 23:30 7.50 0 9,205 SURPRI RPEQP1TRIP P Start in hole with BHA #2 23:30 00:00 0.50 9,205 9,205 SURPRI RPEQP1 MILL P Get drilling parameters 118k up / 93k down @ 2k torque 12/12/2010 Tagged top of Baker SAB -3 Packer at 9242' RKB, Milled up packer and pushed down to 9262' RKB. Circulated Bottoms Up at 2bpm , 400psig drill pipe pressure, Pumped 30bbls Flo -Vis sweep at 4bpm, 1100psig drill pipe pressure. TOOH lay down BHA#2 and Pick up BHA #3, TIH to retrieve milled packer and tail pipe 00:00 00:30 0.50 9,205 9,242 SURPRI RPEQP1 MILL P Drilling parameters established, TIH to tag top of packer 00:30 08:00 7.50 9,242 9,262 SURPRI RPEQP1 MILL P 9242' RKB, Tag top of packer, PUH begin rotating at 51 rpms pumping 1 bpm 180 ICP mill packer to 9,244' RKB, packer fell free to 9,262' RKB. 08:00 10:00 2.00 9,262 9,262 SURPRI RPEQP1 CIRC P CBU @ 2 bpm 400 psi. Pump 30 FLO -VIS sweep @ 4 bpm 1,100 psi. 10:00 10:30 0.50 9,262 8,800 SURPRI RPEQP1TRIP P TOOH from 9,262' to 8,800' RKB. 10:30 12:30 2.00 8,800 8,800 SURPRI RPEQP1OTHR P PJSM, Slip & Cut drill line. 12:30 18:30 6.00 8,800 0 SURPRI RPEQP1TRIP P Continue OOH with work string and BHA #2. 18:30 21:00 2.50 0 0 SURPRI RPEQPI PULD P Lay down BHA #2, Clean drill floor, Pick BHA #3 21:00 22:00 1.00 0 1,240 SURPRI RPEQP1TRIP P TIH with BHA #3 on PH6 DP, filling every 10 stands Page 2 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:15 0.25 1,240 1,240 SURPRI RPEQP1OTHR P Fill DP 22:15 23:00 0.75 1,240 3,155 SURPRI RPEQP1TRIP P Continue TIH 23:00 23:30 0.50 3,155 3,115 SURPRI RPEQP1OTHR P Fill DP 23:30 00:00 0.50 3,115 3,590 SURPRI RPEQP1TRIP P Continue TIH 12/13/2010 Tagged top fish packer at 9228' RKB, Continue to push packer assembly to 9643' RKB, TOOH, Packer was not retrieved, MU TIH with 4 5/8 mill shoe. 00:00 04:30 4.50 3,590 9,228 SURPRI RPEQP1TRIP P Continue TIH to 9,228', tag fish. Up weight 120K down 87K, pump 1 bpm, unable to latch fish. 04:30 07:00 2.50 9,228 9,643 SURPRI RPEQP1TRIP P Push fish to 9,643', engage fish. 07:00 14:00 7.00 9,643 0 SURPRI RPEQP1TRIP P TOOH w/ BHA #3, no fish. 14:00 16:00 2.00 0 0 SURPRI RPEQPI PULD P Lay down BHA #3, Make up BHA #4. 16:00 00:00 8.00 0 7,896 SURPRI RPEQP1TRIP P TIH w/ BHA #4 12/14/2010 Trip in with BHA #4 and washover Packer to 9,644 -ft. Circulate Hi -Vis Sweep. Trip out with BHA #4. Make -up BHA #5 to fish Packer. Start Trip in with BHA #5. 00:00 03:30 3.50 7,896 9,642 SURPRI RPEQP1TRIP P Continue TIH w /BHA#4 to tag depth @ 9,642' MD. 03:30 06:00 2.50 9,642 9,644 SURPRI RPEQP1 MILL P Set parameters Up 127K Down 93K 105 @ ROT 3K. Free torque 2 bpm @ 440 psi, milled to 9,644'MD, wash over fish several times freely. 06:00 07:30 1.50 9,644 9,640 SURPRI RPEQP1CIRC P Pump 38 bbls Hi -vis pill, CBU. Monitor well, taking fluid. 07:30 14:00 6.50 9,640 0 SURPRI RPEQP1TRIP P TOOH w/ BHA #4. Lay down same. Observe Shoe with 90 % wear Empty Boot Baskets. Recovered several small pieces of milled Packer debris and approxmitally 5 pounds of mill shavings. 14:00 17:30 3.50 0 303 SURPRI RPEQP1PULD P Make -up BHA #5 as per Baker Rep as follows: 4 11/16" Overshot w/ 3.5" Grapple, X0, Bumper Sub, Oil Jar, X0, X0, IBOP, X0, Pump- Out -Sub, 9 ea 3 1/2" PAC Drill Collars. 17:30 00:00 6.50 303 8,726 SURPRI RPEQPITRIP P TIH w/ BHA #5 and 3 1/2" PH -6 Work String from the Derrick. 12/15/2010 Finish Trip in with BHA #5. Latch Packer Fish. Trip out with BHA #5. Lay down Fish., Make up BHA #6. Trip in with BHA #6. Tag solid Fill at 9,666 -ft. Pump Hi -Vis Sweep and circulate back to surface. Returns clean. 00:00 02:30 2.50 8,726 9,612 SURPRI RPEQP1TRIP P Up Weight = 112K. Down Weight = 82K. Continue to trip in with BHA #5 and 3 1/2" PH -6 Work String from the Derrick. Page 3 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 9,612 9,644 SURPRI RPEQP1 FISH P Establish parameters as follows: Up Weight = 129K. Down Weight = 94K. Pump Rate = 2 bpm /370 psi. • Reduce Pump Rate to 1.0 bpm /170 psi. Ease in hole and tag Top of Fish at 9,644 -ft. Set down 5K. Pull up to 5K over string weight. Set back down and stack 20K on Fish. Pump pressure increased to 240 psi. Pull up to to 150K, Fish came free. Set back down and stack 20 K. Made — 6" of hole. Unable to move Fish down hole due to "fill ". 03:00 03:30 0.50 9,644 9,612 SURPRI RPEQP1SFTY P PJSM. TOOH and blow down Top Drive. 03:30 11:00 7.50 9,612 0 SURPRI RPEQP1TRIP P Blow Down Top drive. Trip out with 3 1/2" PH -6 Work String, standing back in the Derrick. On surface with BHA #5 with fish. 11:00 12:30 1.50 0 0 SURPRI RPEQP1PULD P Lay down BHA and release fish, fish total length 24.37', Top end of packer assembly folded inward, no way internal spear would latch, pictures on "S" drive. 12:30 13:00 0.50 0 0 SURPRI RPEQP1SFTY P PJSM 13:00 14:30 1.50 0 0 SURPRI RPEQPI PULD P Make up BHA #6 as follows: XO, intensifire, XO, 9 D /C's, XO, oil jars, bumper sub, bit sub, two boot subs, XO, double pin sub, 5 1/2" casing scraper, 4 3/4" bladed junk mill, total length 316.19. 14:30 18:00 3.50 0 5,640 SURPRI RPEQP1TRIP P Start in hole with BHA #6 (scraper run) on 3.5" PH -6 18:00 22:00 4.00 5,640 9,634 SURPRI RPEQP1TRIP P Continue tripping in with 3 1/2" PH -6 Work String from the Derrick. 22:00 22:30 0.50 9,634 9,666 SURPRI RPEQP1 FCO P Up Weight = 127K. Down weight = 94K. Pump Rate = 3.0 bpm /840 psi. Ease in hole and tag Fill at 9,666 -ft dpmd. Pick -up and repeat with 10k weight on Mill. Solid. Pick -up. Rotate Work String at 20 RPMs. Free spin torque climbed from 2K to 5K. About any attempt to rotate to break through top of the fill. Attempted two more time to wash through Fill. No -Joy. Abort any further attempt to uncover the fill across the perforated interval from 9,666 '- 9,684'. 22:30 00:00 1.50 9,666 9,666 SURPRI RPEQPI CIRC P Pump a 30 bbl Hi -Vis Sweep at 4.0 bpm /1,310 psi. Chase Sweep back to surface with 50% losses to the open perforations. 12/16/2010 _ Cut and Slip Drill Line. Trip out with BHA #6. Weekly BOPF Tact Rig E -Line. Gauge Hole with a 4.678" GR/Junk Basket to 9,555 -ft. Page 4 of 9 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 9,666 9,666 SURPRI RPEQP1CIRC P Finish circulating Well clean. Pumped a total of 415 bbls (2+ hole volumes). Returns clean. No solids observed. 00:45 01:00 0.25 9,666 9,666 SURPRI RPEQP1SFTY P PJSM. Tripping out of Hole. 01:00 02:00 1.00 9,666 8,740 SURPRI RPEQP1 TRIP P Start to trip out with BHA #6. Stop with 10 stands out for Rig Service. 02:00 02:15 0.25 8,740 8,740 SURPRI RPEQP1SFTY P PJSM. Discuss procedures and safety concerns for cut and slip operations. 02:15 04:00 1.75 8,740 8,740 SURPRI RPCOM RGRP P Cut and Slip Drilling Line. Check Drawworks breaks and adjust rollers. Install new Deadman bolts. 04:00 10:30 6.50 8,740 0 SURPRI RPEQP1TRIP P Continue trip out of hole with BHA #6, standing back 3 1/2" PH -6 Work String. Two stands from surface, shutdown and monitor well, well drinking, out of hole. 10:30 13:00 2.50 0 0 SURPRI RPEQPI PULD P Lay down BHA #6 13:00 16:00 3.00 0 0 SURPRI RPEQPI PULD P Clean boot baskets, clean rig floor, PJSM. Load out all Baker milling & fishing equipment. Pull wear ring. 16:00 22:00 6.00 0 0 SURPRI WELCTL BOPE P Weekly BOPE test. Function test and PT rams, choke manifold, 1aP annular to 250/3000 psi. Perform Koomey draw down test. AOGCC waived test by John Crisp on •�' 12 -15 -10 @ 07:20. 22:00 22:30 0.50 0 0 SURPRI WELCTL BOPE P Rig down Test Equipment. Pulled Test Plug. Install Wear Bushing. 22:30 23:45 1.25 0 0 SURPRI WELCTL BOPE P Nipple down Sh000ting Flange. Nipple up Flow Nipple. 23:45 00:00 0.25 0 0 SURPRI RPEQP1SFTY P PJSM to Rig up E -Line Equipment. 12/17/2010 Continue with E -Line Ops. Lo• Well with 40 -Arm Caii•er. Re -run the 4.687" GR/Junk Ba k- Run Baker Packer and attempted to set a 9,440 -ft. Voltage problems to the Setting Tool. POOH with inspect Tool String. 00:00 02:30 2.50 SURPRI EVALWE ELOG P Rig up E -Line Equipment. Pick 4.678" GR/Junk Basket and Lubricator. Pressure test Lubricator at 100 psi. 02:30 05:00 2.50 SURPRI EVALWE ELOG P Run in Hole with the 4.678" GR/JUnk Basket to 9,555 -ft with no problems. POOH empty Junk Basket. Recovered a two handfuls of black gunk. Lay down GR /Junk BAsket. 05:00 11:30 6.50 SURPRI EVALWE ELOG P Make up 40 arm Caliper with gamma ray, log casing from 9,600' to surface, check data to reveal any casing issues, casing appear to be good, lay down caliper, caliper missing one arm. Decision made to run packer assembly. Page 5of9 Time Logs • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 14:30 3.00 SURPRI EVALWE PULD P Make up packer and setting assembly as follows: Halliburton setting tool, Baker setting adapter, Baker packer, 15' pup joint, WLEG total length of packer assembly 18.76'. After making up packer assembly, decision made to rerun GR/ Junk basket, lay down packer assembly. 14:30 17:00 2.50 SURPRI EVALWE ELOG P Run in Hole with the 4.678" GR/JUnk Basket to 9,555 -ft with no problems. POOH, one piece thin metal Packer milling debris in basket. Lay down junk basket. 17:00 18:00 1.00 SURPRI EVALWE ELOG P Make up packer and setting assembly as follows: Halliburton setting tool, Baker setting adapter, Baker packer, 15' pup joint, WLEG total length of packer assembly 18.76'. 18:00 00:00 6.00 SURPRI EVALWE ELOG P RIH with the Baker 45 -FA -36 Packer Assembly. Log tie in pass to the two Short Joints between 9,404' - 9,360' and the Gamma Ray spike at 9,264'. Made a ( +) 15 -ft correction. Repeat tie in pass. Good. Log Packer into place at 9,440 -ft. Attempted to set Packer several times with No -Joy. POOH to trouble _shoot. 12/18/2010 Continue with E -Line Ops. Set Backer Packer at 9,440 -ft. pig down E -Line. Make up the Upper Packer Assembly. TIH. Sting into the Lower Packer at 9,440 -ft. Set Packer. Attempt to pressure test Packer. No-Joy. Relsease Setting Tool. 00:00 01:00 1.00 0 0 SURPRI EVALWE ELOG T Trouble shoot Logging Tool String. Found short in Cable Head. Re -tie Cable Head. Re- check. Good. 01:00 04:30 3.50 0 0 SURPRI EVALWE ELOG T RIH with the Baker 45 -FA -36 Packer Assembly, Setting Tool, and Logging Tools. Log tie in pass to the two Short Joints between 9,404' - 9,360' and the Gamma Ray spike at 9,264'. Made a ( +) 4 -ft correction. Repeat tie in pass. Good. Log Packer into place at 9,440 -ft. Set Packer. Good. Log off. POOH. Stop at 200 -ft. PJSM for rigging down. Finish POOH. 04:30 06:30 2.00 0 0 SURPRI EVALWE ELOG P Rig down E -Line Equipment. Clear and clean Floor. 06:30 08:30 2.00 0 0 SURPRI RPEQPI PULD P Lay down shooting flange, nipple up riser. Page 6 of 9 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 11:00 2.50 0 242 SURPRI RPEQPI PULD P PJSM. M/U Upper Baker Packer assembly: B -2 Hyd. setting tool, Baker 45 packer, crossover, one jt tbg, pup jt, 2.812 "X" npple w/ RHC body, pup jt, one jt tbg, pup jt, GLM w/ DV, pup jt, one jt tbg, crossover, two blast jts, pup jt, anchor seal assembly, total length of equipment left in hole 225.03'. 11:00 20:30 9.50 242 9,414 SURPRI RPCOM TRIP P TOOH w/ Upper packer assembly on PH -6 workstring. 20:30 00:00 3.50 9,414 9,433 SURPRI RPCOM PACK T Up Weight = 126K. Down Weight = 90K. Finish RIH with 98 Stands (Joint 294). Drop 1 7/16" Setting Ball. Pick -up Joint # 295. Wait on Ball to fall. Roll charge Pump to put Ball on seat. Tag the Lower Packer at 9,433 -ft dpmd /9440 -ft rkb. Sting into Lower Packer. Pull 10 K over string weight. Set back down to neutral. Pressure up to 2,000 psi. Pull up to 170K (44K over). Set back down to neutral. Pull back up to 170K and slack back off to neutral once again. Pressure up to 2,500 psi to shear ball seat in setting tool. Bleed Drill Pipe pressure to 0 psi. Pump down the Annulus and attempt to test the Packer. However, have slight flow back from the Tubing side. Check surface valve alignment. Attempt to re -test with the same results. Suspect that the Setting Tool might be leaking. Discuss a plan forward the Anchorage Engineer and Baker Packer Supervisor. Release Setting Tool. Leave Upper Packer at 9,209 -ft. Lay down Joint #295 and prep to TOOH. 12/19/2010 Trip out with Packer Setting Tool and lay down same. Pick -up Seal Assembly and TIH. Sting into the Upper Packer. Test the 5 1/2" x 3 1/2" Annulus and the Upper Packer at 3,000 psi x 30 minutes. Good test. POOH and start to lay down the PH -6 Work String. 00:00 07:00 7.00 9,209 0 SURPRI RPCOM TRIP P Trip out with Packer setting Tool. 07:00 09:00 2.00 0 0 SURPRI RPCOM PULD P On surface with setting tool, lay down same. Setting tool stroked, packer appears to be set, however back up ring missing on internal o -ring groove. Make up crossover and seal assembly to PH -6. 09:00 20:30 11.50 0 9,209 SURPRI RPEQPI TRIP P TIH w/ seal assembly on PH -6 workstring. Page 7 of 9 Time Logs • Date From To ` Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:30 1.00 9,209 9,209 SURPRI RPEQP1PRTS P Tag the top of the Upper Packer at 9,209 -ft dpmd. Install Head Pin. Sting Seal Assembly into Upper Packer and set down 10K. Rig up to test. Pressure up on the 5 1/2" x 3 1/2" Annulus to test the Packer and Casing. Tested same at 3,000 psi x 30 minures. Good. Record on chart. 21:30 22:00 0.50 9,209 9,209 SURPRI RPEQP1SFTY P PJSM. Descuss the hazards assoicated with laying down the work string. Prep to POOH. 22:00 00:00 2.00 9,209 8,240 SURPRI RPEQP1 PULD P POOH with the Seal Assemble and single down the 3 1/2" PH -6 Work String to the Pipe Shed. 12/20/2010 Single down the 3 1/2" PH -6 Work String. Single in with the 3 1/2" Gas Lift section of the Completion. Latch Anchor Seal Assembly. Shear PBR. Calculate Space -Out. Make Up Tubing Hanger. 00:00 09:30 9.50 8,240 0 SURPRI RPEQP1 TRIP P Up Weight = 110K. Down Weight = 80K. Continue to single down 3 1/2" PH -6 Work String to Pipe Shed. Off -load Pipe Shed as needed. On surface. Lay down seal assembly. 09:30 11:00 1.50 0 0 SURPRI RPEQP1 PULD P Pull wear bushing. Prep floor to run 3.5" completion, check tally. Make up PBR /Anchor assembly. 11:00 18:00 7.00 0 4,480 SURPRI RPCOM TRIP P PJSM, TIH w/ new 3.5" Gas Lift Completion as per tally. One 2.875" DS nipple, five GLM's, PBR /Anchor assembly. 18:00 00:00 6.00 4,480 9,187 SURPRI RPCOM PULD P Discuss and review present operations with Crew just rotating back from "days -off'. Present depth 4,480 -ft. Continue to single in with the 3 1/2" Gas Lift Completion from the Pipe Shed. Up Weight = 100 K. Down Weight = 75K. Tag top of Upper Packer at 9,217 -ft. Slack off and latch Anchor Seal Assembly. Latch confirmed. Shear PBR with 60K over string weight. Re -tag and make pipe with 3 -ft "stick -up ". Lay down Tag Jt (291), Jt 290, and Jt 289. Drift the Space -out Pup and the Tubing Hanger Assembly. Make -up the 2 -ft Space -Out Pup. Pick -up Jt #289. Install Tubing Hanger Assembly. FMC perform final Tubing Hanger inspection. 12/21/2010 Displace Well over to Corrosion Inhibited Sea Water. Land Completion. RILDS. Test Tubing. Test Casing. Shear SOV. ND BOP Stack. NU Tree. Test same. Freeze Protect Well. Release Rig. 00:00 01:30 1.50 9,187 9,187 SURPRI RPCOM CIRC P Circulate Well over to Corrosion Inhibited Sea Water at 4.0 bpm /620 psi. Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth' Phase Code Subcode T Comment 01:30 02:00 0.50 9,187 9,200 SURPRI RPCOM PRTS P Land Tubing Hanger with Seal Asembly Locator 3 -ft above the top of the PBR (7 -ft swallowed inside of the PBR). RILDS. Drop Ball /Roller Rod Stem (1.300" Ball. Fishing Neck = 1.750"). 02:00 05:30 3.50 0 0 SURPRI RPCOM PRTS P Rig up Lines to pressure test. Test Tubing at 3,000 psi x 30 minutes. Bleed Tubing down to 2,200 psi. Pressure test the Casing at 3,000 psi x 30 minutes. Good tests. Record test on chart recorder. Bleed IA to "0" psi. Bleed Tubing to "0" psi. Pressure back on IA to 1,700 psi. Saw SOV shear. However it appears that the SOV only partially sheared (pressure remained high with little returns. Pump down Tubing at 1.0 bpm /350. Increase to 2.0 bpm /620 psi with good returns. Swap Pump back to the IA and pump at 2.0 bpm with the pressure fluctuating between 700 and 600 psi with good returns. 05:30 06:30 1.00 0 SURPRI RPCOM PRDT P PJSM. Pull landing joint, set BPV, V / test to 1,500 psi to check plug. 06:30 11:00 4.50 SURPRI RPCOM NUND P NDBOP stack. NU tree. 11:00 12:00 1.00 SURPRI RPCOM PRTS P PJSM. Test Tree Void. 250/5000 psi for 15 mins. 12:00 13:30 1.50 SURPRI RPCOM SEQP P PJSM. Pull BPV. Install Test Plug 13:30 16:30 3.00 SURPRI RPCOM PRTS P Rig up Testing Equipment & Test Tree & Chart to 250/2500 psi for 15 mins. Pull Test Plug. 16:30 19:30 3.00 SURPRI RPCOM FRZP P PJSM with Lil' Red Services and Rig Crew to Freeze Protect Well. Test Line at at 2,500 psi. Good. Pump Diesel down the 5 1/2" x 3 1/2" Annulus at 0.75 bpm /400 psi. Final rate at 1.0 bpm /900 psi. Total diesel pumped = 60 bbls. Hook up hose to the tubing side an allow Diesel to U -Tube to Freeze Protect the tubing. 19:30 20:30 1.00 SURPRI Set BPV. Rig down hoses. Secure Cellar. Release Rig at 20:30 hrs. Prep to move off of Well. Page 9 of 9 STATE OF ALASKA DEC 0 8 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & GM Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown[:] Perforate El Re -enter spended Well ❑ 2. Operator Name: 4. Well Class Before Work: . Permit to Drill Number: COnocoPhillips Alaska, Inc. Development ❑� Exploratory ❑ 195-160/ 3. Address: Stratigraphic ❑ Service ❑ API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50- 029 - 22608 -00 Property Designation (Lease Number): . Well Name and Number: ADL 25645 2X -18 9. Field /Pool(s) uparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured \ 9943' feet Plugs (measured) feet true vertical \ 6234' feet Junk (measured) feet Effective Depth measured 9841' feet Packer (measured) 9256 feet true vertical 6150' feet (true vertical) 5694 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5090' 7 -5/8" 5130' 3398' PRODUCTION 9890' 5.5" 9930' 6223' t* �'- - 2009 Perforation depth: Measured depth: 9374'- 9394', 9394'- 9420', 9618'- 9638', 9666' -9684' true vertical depth: 5783'- 5798', 5798'- 5824', 5971'- 5986', 6009' -6023' Tubing (size, grade, measured and true vertical depth) 3.5" & 2-7/8", L-80, 9180'& 9281' MD / 5636', 5713' TVD Packers & SSSV t e, measured and true vertical d e p th) Baker SAB -3 kr ( YP p ) 9256' MD / 5694' TVD P @ Camco'DS' nipple @ 509' MD / 508' 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 Tubinq Pressure Prior to well operation 111 924 423 -- 186 Subsequent to operation 150 969 604 -- 184 13. Attachments Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development El Service ❑ Daily Report of Well Operations _X Well Status after work: Oil D Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer �z ~ ~�� Signature �1 t�' Phone: 265 -6471 Date Pre aced bv Sharon Allsu -Drake 263 -4612 Form 1 04 Revised 7/2009 Submit Original Only a 2X -18 Well Events Summary DATE SUMMARY 11/17/09 DRIFT TBG W/ 20' 2" DMY DRIF - GOOD. TAGGED @ 9637' SLM, SAMPLO OBTAINED. JOB COMPLETE. 11/30/09 PERFORMED PERFORATIONS USING 2 ", 6 SPF, TANDEM GUN IN THE C4, C3 SANDS AT A DEPTH BETWEEN 9394'- 9420'. NO CHANGE IN WHP AFTER SHOT —950 PSI. I II � �.- • _ _ KUP Angle s MD T2X-1 8 C ,��,, ✓ _ AA riJ�hll i We I�Attnb 9 Ala, Wellbore APYUWI (Field Name Well Status Intl C) MD (kK8I Act Btm (ftKB) _50029_2260800 KUPARUK RIVER UNIT PROD 60.05 6/5.98 9943.0 Comment IH2S(ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date went - - - - -- SSSVNIPPLE 180 10/12/2007 �L_as[WO: 4100 5/9/1996 Onfig -1$..1 1 - �'J PM _ _ -, _ _.. SdtemafK AquaL A Cation iDepth (ftKB) End Date Annobt Last Mod By End Dab Last Tag::: SLM L 9_,637.0 1 11/17/2009 Rev Reason: PERFORATIONS I Imosbor 12/1/2009 Casin Striir s i String OD String ID Set Depth Set Depth (TVD) String Wt String D ann ion (in) Top(... (ftKB) (ftKB) (Ibslft) Grads Stri To D Third _..__ CONDUCTOR, CONDUCTOR 16 15.062 0.0 121.0 121.0 62.50 H-40 121 SURFACE 7 518 6.750 0.0 5,130.0 3,398.2 29.70 L -80 .�, PRODUCTION 51/2 4.653 0.0 9,930.0 6,2229 15.50 L -80 -- Tubing StrinS __ NIPPLE, 509 - St ring OD Stang ID Set Depth Set Depth (ND) swing Wt String -t _T ubing Descri bn _ (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibri Gmde String Top Third TUBING 3 112 2 992 0.0 3,569.0 2,588.8 9.30 L-80 ABM -EUE TUBING 2 7/8 2.441 - 3,569.0 3,639.0 2,623.2 6.50 L -80 ABM -EUE TUBING 3 112 2.992 3,639.0 7,180.0 4,483.8 9.30 L -80 ABM -EUE TUBING 27/8 2,441 7,180.0 7,250.0 4,5173 6.50 L -80 ABM -EUE GASLIFT, TUBING 31/2 -- 2.992 7,250.0 8,482.0 5,155.1 9.30 L -80 ABM -EUE 3.601 TUBING 27/81 2.4411 8,482.01 8,552.01 5,194.31 6.50 1 L-80 ABM -EUE TUBING 1 31/21 2.9921 8,552.01 9,180.01 5,1535,81 9.30 1 L-80 ABM -EUE TUBING 1 2718 2.441 9,180.0 9,281.0 5,712.5 6.50 L -80 ABM -EUE Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) --- _ SURFACE, Top Depth' 5,130 (TVDI Top Intl T_gL(Po(B (ft KB) ( °) Description Comment Run Date ID (in)_ 509 507.91 8.73 NIPPLE Camco'DS' Nipple 5/6 /1996 2.812 3,601 2,604.5 59.87 GAS LIFT CAMCO /KBMM /l /GLV /BK/.1 5611 3 341 Comment: STA 1 12172003 _ 2.347 -- 7,211 4,498.5 60.69 GAS LI Ff CAMCO /KBMM /1/GLV/BK/.7 8811 35 2/ Comment STA 2 12/1/2003 2 GAS LIFT, rte. 8,514 5,172.3 54.31 GAS LFT I CAMCO /KBMM /l /GLV /BK /.25/1445/ Comment: STA 3 12/1/2003 2.347 7,211 9,212 5,660.1 40.71 GAS LIFT CAMCO /KBMM /1 /OV /BK/.188/ /Comment: STA4 12/112003 2.347 9,255 5,692.7 40.62 ANCHOR BAKER 'KB H- 22'ANCHOR 5/6/1996 2.500 9,256 5,693.5 40.62 PACKER Baker'SAB -3' PACKER 516/1996 2.531 4.1 9,270 5,70 40.59 NIPPLE Camco'D'Nipple NO GO 5/6/1996 2.250 v 9,280 5,711.7 40.57 SOS 'Baker 5/6/1996 2.441 . 9 1 281 5,712.5 40.57 TTL 5/611996 2.441 Perforations & Slots GAS LIFT, Shot 8,516 ToP (TV DI St. (TVD) Dens I T ftKB B (flKB (ftKB) 0"(11 Zon Drte (s Type Commen 9,374 9,394 5,783.2 5,798.4 64,2X-19 9202008 6.0 APERF 2" PowerJet HSD 60 deg. ph; Random -4 9,394 9,420 5,798.4 5,823.6 C, - C-3,C-2. 11/302009 6.0 APERF T Millenium HSD, 60 deg random 2X -18 9,618 9,638 5,970.5 5,986.4 A-4, 2X -18 59/1996 4.0 IPERF 2 118" Eneriet, 180 deg. ph; Oriented I Normal -.. 9,666 9,684 6,008.8 6,023.4 A -3, 2X -18 9/22/2001 .. 6.0 APERF 2 1/8" EJ PJ; +/ -90 deg ph; GAS 9Ir12 timul tions & Treatments _ f Min Top Max Btm :Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comm ent 9 9,68 5,970.51 5,986.4 FRAC 11/28/20031A -SAND FRAC 208,000# 16120 CARBOLITE ANCHOR. 9,684.Or 6,008.8 6,023 *FRAC 11/28/2003 -SAND FRAC 208,000# 16/20 CARBOLITE 9,255 Notes: General & Safet End Date Annobtion PACKER, 9.258 ___.�.�____ _ ._.. .__ 5!5/1995 NOTE: 1 A. of 2 7 /8^ TBG run on each side of GUM "s NIPPLE,9,270 SOS,9,280 TTL, 9,281 APERF, _ 9,374 -9,394 I APERF. 9,394 -9,420 I PERF, 9,81 &9,838 FRAC, 9,816 �- I I APERF, 80 u 9.666 -9,6 \ _ FRAC, 9,666 - I PRODUCTION,_ 9,930 \ TD. 9,943 -_ - -.. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken .. 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2X-18 Run Date: 11/30/2009 December 7, 2009 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 2X-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22608-00 lg 1~a 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.barre~~ha1,I.~,burtgn.cam _ , :_a _- - Date: . , i r ~' 9 j ~ '. I, ~ ~~', Signed: , ~ ~/ ~_ • ~/ ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 L' November 27; 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~x~g 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 corrosion inhibitor/sealant was pumped November 17, 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, Perry Klei 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) Kuparuk Field natp 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 2X-18 195-160 6" NA 6" NA 3.4 11/17/2008 2X-19 195-175 12" NA 12" NA 2.55 11/17/2008 _ ~ ~ <,,,~ __~ i ~~c~~v S~N~nber~er ~yo~ ~~ ~av8 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth h„r~~ z- ''n(~~ Well Job # Log Description NO.4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1L-23 12097405 SBHP SURVEY 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /~. © p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - '3 L((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE L. C / 09/14/08 1 1 3M-13 12096541 LDL - (~C( j VC( 09!10/08 1 1 2Z-13A 12100446 LDL ~- ('~O 'TU 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - S'oL 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE -t 09/20/08 1 1 30-15 12100452 LDL - ~ 'j Q 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o r 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY S- ~ (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 X-18 12080443 PRODUCTION PROFILE 09!30/08 1 1 1 R-34 12080444 _ GLS ~jG .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .: G ~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~r~ ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1B-16 12097426 GLS ~ - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~'~ 10/07/08 1 1 iB-04 12096552 INJECTION PROFILE 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1B-16 12096554 PRODUCTION PROFILE qC .r G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE .j~rC = 10/11/08 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. ,J • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ Exploratory ^ 195-160 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22608-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 77' ~ 2X-18 j 8. Property Designation: 10. Field/Pool(s): ADL 25645 ~ Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 9943' - feet true vertical 6234' • feet Plugs (measured) Effective Depth measured 9776' feet Junk (measured) true vertical 6096' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' ' 16" 121' " ' 121' i~~t~ ' ~ #~ ~ f` ~~~~' SURFACE 5090 7-5/8 5130 ; 3398 4.,~,,;;~ ~> ~ PRODUCTION 9890' 5-1/2" 9930' 6223' ~t Pertoration depth: Measured depth: 9374'-9394', 9618'-9638', 9666'-9684' ~~. ~ ~~~~ true vertical depth: 5783'-5798', 5971'-5986', 6009'-6023' /i~I8S~8 ~llj ~ ~da ~~"t ~ :~ ' " ; - ui 9ti !r1iSS10f~ Tubing (size, grade, and measured depth) 3.5" / 2-7/8", L-80, 9180' / 9281' MD. A[tCFCrrO~fz Packers ~ SSSV (type & measured depth) Baker SAB-3 pkr @ 9256' Camco'DS' nipple @ 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 180 844 164 -- 188 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Group Engineer Signature / rJ j~ Phone: 265-6471 Date ,~~" ,1,1p-'~~ /~•G ~c•~ ~ ~ P ared h Sharon Allsu -Drake 263-4612 Form 10-404 Revised ~ ~~ ~~~ {~ j ~~~~ ~ ^ ~ ~ A L S/ubmit Original Only '/'v/v~,~ '. ' ZX-18 Well Work Summary DATE SUMMARY 9/19/08 PUSHED /THAWED ICE PLU~ITH 40 BBL HOT DSL. DRIFTED TBG 10' x 2-1/8" STEM. TAGGED @ 9678' SLM, EST. 16' RATHOLE. READY FOR E/L. 9!20/08 PERFORATE WITH 2" POWERJET HSD LOADED 6 SPF FROM 9374-9394'. TUBING PRESSURE UNCHANGED AT 1400 PSI BEFORE AND AFTER PERFORATING. ,,, ConocaPhilii ~, j KUP Well Attributes a} ~ AI`1~'"" ''" Wcll6u~n API/UWI F~e1tl Na,uu WeIISWtus P~ucL'h~} WxN rypu .. 500292280800 KUPARUK RIVER UNIT PROD Comment F123 (ppm) Dab Annobtbn End Date . _ - ..NIPPLE 180 71112008 LastWO: 5~,emauc nct,i ~~ - Annobtion Depth (ftK8) End Date Annobtion Last Tag: 9.fi76.0 ! 6120/2008 Rev Reason: ADD PERF ~ ~ I I CONDUCTOZ - NIPPLE, GAS LIFT, 3,601 5,1 GAS LIFE, 7,211 E' ' Perfora _...--..._- tions ~ Shcl GAS LIFT i~ Top (TVD) ~ BM (iVD) I Dena , B,Sta Top (ftK8) Brm (ftK8) (ftK8) (ftK8) , Zone Date (ah... 9,374.0 9,394.0 5,783.2 5,798.4 C-4, 2X-18 9/20/2008 I 6.0 1 ~ 9,618.0 9,638.0 5,970.5 5,986.4' A-4, 2X-18 5/9/1996 ~ 4.0 / t 9,666.0 9,684.0 6,008.8 6,023.4 A-3, 2X-18 9/22/2001 6.0 _ Stimula tions & Treatments ' aeuem !Top Depth I Depth I (TVD) ~~ (TVD) GAS LIFE, r` .. ToP (ftK6) B6n (ftK8) (ftK8) (ftK8) Zone ~.~, Date 2X-18 '.I (} Mll IttK6) TD (ui:uf( (iL.. 60.05 7,675.98 9,943.0 ~Grd (ft) I Rig Raleaae Dab 41.00 I 5/9/1996 End Dab 912 112 0 08 iD 60 deg. p 180 deg. ph; Comment 01/20/06 Schlumberger NO. 3663 Schlumberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth JÂN 2 4 2006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~C4I&GasCcf~~ Field: Kuparuk þ.~ -" Well Job # Log Description Date BL Color CD 1 E-03 11144062 PROD PROFILE WIDEFT 01/14/06 1 1F-14 11144063 PRODUCTION PROFILE 01/15/06 1 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE WIDEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILEIWFL 01/13/06 1 38-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 \q~- \(cD 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE W/DEFT 01/10/06 1 2 H -0 9 11154103 PROD PROFILE WIDEFT 12/29/05 1 1 G-11 11154113 PROD PROFILE W/DEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z-13 11141242 PROD PROFILE W/DEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 PROD PROFILE WIDEFT 01/17/06 1 - 2N-339 N/A BHP SURVEY 12/01/05 1 20-04 N/A BHP SURVEY 12/03/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1 E-05 11166747 PROD PROFILE W/DEFT 12/25/05 1 2M-01 1115411 9 PROD PROFILE W/DEFT 01/19/06 1 SIGNED: '-->/f'< JllhiMfÇ;:fj'\ ~ <; I'ct ('2· h. ?n f(' êb?~~~~'tI5~ .;d4!t->! ¡¿j '--'~o DATE: 3~"-'d ') Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. '\:;""1 '::\11" 1.[:&.' I i I! I. \ ' !I! i I,.·:JJ \ I i 1 llJ~ ) I I / j ¡ ALASKA. OIL AND GJfa S I CONSERVATION COMMISSION / I November 9, 2005 )¡ II f,... 1 , ! ~~ LJ '·......,.,¡0\w< ..' '.~. -. ':, ¡ ¡.',/ ; /\" i : '1 .. /:, \ ¡ I., ; /J...I ~ Jui~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279-1433 FAX (907) 276·7542 Mr, Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. p, O. Box 100360 Anchorage, AK 99510-0360 q,c~ ":;>D \. ,,'J .... fL.. .1.,:,,'1, " . ,\'"U ~~ Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Comn1ission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2X ("KRU 2X") pad on October 7, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. BiIective October 7, 2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, f~ .~ TJ ,,-Lè'lI,iL"i t). 1'\ &¡ç¡,: James B. Regg . Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors ~". MQ'i 1 , 'l.GG3 5ÇANNE1:~" " , . Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: K H LJ _ 2X I nsp Dt 10/7/2005 Inspected by John Spaulding Interval 90 Days InspNo svsJS05 JO072 13641 Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Noble Related Insp: Reason 180-Day Src: Inspector Well Data .-. ~~ r ~-~_~~~_~!~~~~_____I~SV [~~~II~JIlt!ll~DtL ii~l TYP~~L-~ !¥~l£!:~~~~I!res _ ___L~~-;Lif~~¡~1~~~-_--~~~~~~~!~~-~~~-__-~J Well Permit Separ Set UP Test Test Test Date SI Oil, W AG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE,51 PSI PSI PSI YeslNo Yes/No 1_-.- 2X-09 - r- --i S-4 1620· '--96 70 60 ---p--T--4 --T- I-OIL--I-I2OÕ-.---900----200----Ye~- No·---u_- 2X-~IÕ- ~'_ L8~_I~?__ J~f6. 70 ---60-·-=~y_~~~~_n_~~-_L--~ -_I_-9~=___~_=1]5Ç-~IO~~_~~I}g__~=-~y~e~-=___~~_=~-~- _____u_____~_ 2X-II 1841640! 96 70 70 P P ¡ I I-OIL 1250 1200 150 Yes I Yes - - ------- --i- --¡--- -.---- -- ---- .----------- -~.-- - - ---1------ -.---- 2X-13 ]841740 96 70 55 P P I I-OIL 1050 700 150 Yes' No 2X-14 1841750 96 70 50 P P I-OIL 1300 930 180 Yes No ___. _____ ____ _. _I- _____ --___ - ---- ---- - - ----- - ___.-__'___'n_______,u_ _____u -- ,~~__'-?_ ._ 184'.760 _____ 9~___ 70 .~Q_ __I____~~. ____ ____ ___!_~()~ .______1~9.Q__ ,~~ ~OO ~<:'__ .___~o.__!ete~tedyi£~9.a~_~psi ~_.____ 2X-J6 1841720 96 70 60 P P I-OIL 1350 1000 200 Yes No ---._---------. ---- - --' --- - --------- ----~-------------- ~-- -- -----~------- - -~----.-- ------ -------- 2X-17 1951710 96 70 65 P P ¡ I-OIL 1000 600 200 Yes No __= .-_~X~~~·-_~- __~I??ßíJQ___- -.i6~t~~____-~0.__p~~~ __p.- ---=-__~=_ ~=j~~l~IL -~_ -1225___}!>O---- 200- ~- ~es ---=--.B~---l__-_=-__:=~~~~=_ _ ____ __ __~_ ___n_ - -- --- -- - --~-- ~ Comments Performance 2-12a wing leaked -unable to lest, requested repairs prior to testing again Wells Components 9 18 ------- --------- Failures ---~~-I~;e ~~te-----I ¡ 2 11.11% --_.~-- ---~----------- --------- -- .--- ~-- --- ~----._._----- .~ ( o p v I Wednesday, November 09, 2005 ) ) L ,j,J-.O ~....T' tI @~ Jï1 ~ c :1: IK\ ~ ~ @~'r 1£ ~ - U\, - ,1 ~J L0j ~IJU cW ~ ~LrU AI¡A.SIiA OIL AND GAS CONSERVATION COMMISSION I / October 25,2004 FRANK H. MURKOWSK/, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 J\nchorage,A}( 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at.~!i,~lÇ.i\R;ivertJtlit2X:('~KRU 2X"} pad on October 15, 2004. Attached is a copy of the InspecfiÒnReport. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing ftequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 100/0 failure threshold. Also noted during the Commission's inspection were unsupported flow piping and pilots on KRU 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provide ~ortu. 0 witness the SVS test. ~ Ií Smcerely, Ø~¿/,~ Daniel T. Seamount, Jr. Commissioner Attach. copy by email: Bob Fleckenstein; AOGCC Inspectors Sr:AM~¡h;T' ~¡rpV (\ II 20011. ~;z::/ ~ß ¡J ~ '~\1 ti ~ !::=m b"Ø" î ~~ ,'~,-¡ , ' ~:~ t.l 't Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv~ \DZ5{û4- Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by Jeff Jones Interval 90 Days InspNo svsJJ041019163228 Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason ISO-Day Src: Inspector ,~'~;MJ:~]_._- - ' - Well Permit Separ Set UP Test Test OiI,W AG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code GAS,CYCLE, SI PSI PSI PSI YeslNo Y eslNo 2X-03 1831090 I 2700 I 2000 1900 I P I P I W AGIN Flow piping & pilot not supported properly; loose & wobbly. 2X-08 1831140 2700 2000 1750 P P W AGIN 2X-09 1841620 98 70 50 P P 1-olL Flow piping & pilot not supported properly; loose & wobbly. 2X-I0 1841630 98 70 60 P P I-OIL '~ 2X-ll 1841640 98 70 65 P 4 I-oIL 750 900 175 No Yes IA x OA communication 2X-12A 1951760 98 70 65 P P I-oIL wing valve leaks. 2X-13 1841740 98 70 44 3 P I-oIL 2X-14 1841750 98 70 75 P P I-oIL 2X-15 1841760 98 70 55 P 7 I-oIL wing & pit valves leak. 2X-16 1841720 98 70 52 P P I-oIL 2X-17 1951710 98 70 50 P P I-oIL 2X-18 1951600 98 70 55 P P I-oIL Comments Performance The SSV on well2X-l1 failed the pressure test & will require repair. The pilot on weIl2X-13 tripped Wells Components Failures Failure Rate low & was cycled & passed a re-test. Both the wing and pit valves leaked on we1l2X-15 and the SSV could not be tested. I inspected 12 well houses. 12 24 3 12.5% ~ Monday, October 2S, 2004 /,' Mike Mooney ( { Wells Group Team Leader , Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 Cono CO Ph illi pS Phone: 907-263-4574 December 19,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2X-18 (APD # 195-160) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2X-18. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Id.~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage \StA\[NJ~lEl> ~U~~I 2 @ 2004. . ORIGINAL ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Suspend 0 Operation Shutdown D Perforate D Variance D Annular Disp. 0 Alter Casing 0 Repair Well D Plug Perforations D Stimulate 0 Time Extension D Other D Change Approved Program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 195-160/ 3. Address: Stratigraphic 0 Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22608-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 118' 2X-18 8. Property Designation: 10. Field/Pool(s): ADL 25645, ALK 2576 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9943' feet true vertical 6234' feet Plugs (measured) Effective Depth measured 9776' feet Junk (measured) true vertical 6096' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 5012' 7-5/8" 5130' 3398' PROD. CASING 9812' 5-1/2" 9930' 6223' Perforation depth: Measured depth: 9618'-9638',9666'-9684' RE C true vertical depth: 5971'-5987', 6010'-6024' E I VE D JAN 0 5 2004 Tubing (size, grade, and measured depth) 3.5" /2-7/8", L-80, 9180' /9281' MD. Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) pkr= BAKER 'SAB-3' pkr= 9256' Anchorage Cameo 'os' nipple nipple @ 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 96181-96381,96661-96841 Treatment descriptions including volumes used and final pressure: 208,000# 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI - - Subsequent to operation 143 741 249 - 177 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ 0 WDSPLD 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: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature J 1.' 11 Phone Date IZ) Z z)o:J Hi.;;J. J.// ~ Preoared bv Sharon AI/suo-Drake 263-4612 t ---> Forn 10-404 Revised 212003 . 0 RIG I N A L -- SF L SUBM M~lrf ~ ( ( ConocoPhillips Alaska, Inc. KRU 2X-18 2X-18 PROD 5/9/1996 NIP (509-510, 00:3.500) Size To Bottom TVD Wt Grade Thread 16.000 0 121 121 62.50 H-40 Gas Lift 7.625 0 5130 3398 29.70 L-80 andrelNalve 5.500 0 9930 6223 15.50 L-80 1 (3601-3602, Bottom TVD Wt Grade Thread 3569 2586 9.30 L-80 ABM-EUE 3639 2622 6.50 L-80 ABM-EUE 7180 4480 9.30 L-80 ABM-EUE 7250 4515 6.50 L-80 ABM-EUE 8482 5153 9.30 L-80 ABM-EUE 8552 5194 6.50 L-80 ABM-EUE Gas Lift 9180 5636 9.30 L-80 ABM-EUE andrelNalve 9281 5713 6.50 L-80 ABM-EUE 2 (7211-7212, ¡" Zone Status Comment I A-4 2 1/8" Enerjet, 180 deg. hasin . Oriented Normal 9666 - 9684 6010 - 6024 A-3 18 6 9/22/2001 APERF 21/8" EJ PJ; +/- 90 de h Stimulations & Treatments Interval Date T e Comment 9618 - 9638 11/28/2003 FRAC 208 000# 16/20 CARBO LITE 9666 - 9684 11/28/2003 FRAC 208000# 16/20 CARBO LITE Gas Lift Gas Lift MandrelslValves andrelNalve St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv 3 Mfr Run Cmnt (8514-8515, 1 3601 2602 Cameo KBMM GLV 0.156 1334 12/1/2003 2 7211 4495 Camco KBMM GLV 0.188 1352 12/1/2003 3 8514 5172 Camco KBMM GLV 0.250 1445 12/1/2003 4 9212 5660 Camco KBMM OV 0.188 0 12/1/2003 Other. . IOS~ø. oi;'ätc; De th TVD T e ID 509 508 NIP Cameo 'OS' Ni Ie 2.812 Gas Lift 9255 5693 ANCHOR BAKER 'KBH-22' 2.500 andrelNalve 9256 5694 PKR Baker'SAB-3' 2.531 4 9270 5704 NIP Cameo '0' Ni Ie NO GO 2.250 (9212-9213, 9280 5712 SOS Baker 2.441 9281 5713 TTL 2.441 ANCHOR Note (9255-9256, 1 Jt. of 2 7/8" TBG run on eaeh side of GLM's 00:2.875) NIP (9270-9271, 00:2.875) TUBING (9180-9281, . .... . 00:2.875, 10:2.441) FRAC (9618-9638) FRAC (9666-9684) ( ( , 2X-18 Event History. Date Comment 11/20103 JET HARD ICE PLUG IN TUBING FROM 1837' - 2550' - RIH TO 4000' AND INJECT HOT DIESEL DOWN TUBING INTO FORMATION - DISPLACED FLOWLINE WITH 15 BBLS DIESEL - READY FOR PREFRAC SLlCKLINE 11/23/03 ATTEMPT TO TAG. STUCK AT 82241. PUMP, GET FREE. RAN OUT TT TO 9662' SLM. UNABLE TO FIND TT. FINGER JAMMED WI SAND. RAN 1.9 GAUGE RING AND BRUSH WHILE PUMPING. COULDN'T GET THROUGH 1 ST SECTION OF 2 7/8. POOH RAN 2.30 GAUGE RING WHILE PUMPING DOWN ATO 9235' SLM. 11/24/03 TAGGED FILL @ 9700' RKB, 16' OF RAT HOLE, SET 2.25" CA-2 BLANKING PLUG @ 9270' RKB, REPLACED GLV'S WI DV'S @ 3601',7211' & 8514' RKB, OPEN POCKET @ 9212' RKB, IN PROGRESS [TAG, OPEN-CLOSE A SAND, GLV] 11/25/03 LOADED IIA W 167 BBL'S SEA WATER, SET DV @ 9212' RKB, PT TBG & IIA TO 3000# PULLED CA-2 BLANKING PLUG @ 9270' RKB [GLV, PT TBG-CSG, OPEN-CLOSE A SAND] 11/27/03 DISPLACED IA WI 15 BBLS DIESEL & -3 BBLS MEOH. PT IA TO 3000#. GOOD TEST. [PT TBG-CSG] 11/28/03 PUMPED A SAND RE-FRAC USING 30# LOW-GUAR SYSTEM. PLACED 208,000# 16/20 CL IN FORMATION, 10 PPA ON PERFS. DESIGNED FOR 203,000#. SAW TSO 33 MINUTES INTO JOB, PREDICTED AT 35 MINUTES. PRESSURE BUILT THROUGHOUT JOB AFTER TSO, FLUSHED JOB TO COMPLETION. 11/29/03 CLEANED FILL TO 9800' CTM WI 1.75" JETSWIRL NOZZLE USING SLICK DIESEL & DIESEL GEL (EST. 120' OF RATHOLE). . WASH PASSES MADE ACROSS MANDRELS. WELL LEFT SHUT IN AND FREEZE PROTECTED TO 25001+. [FCO] 11/30103 TAG FILL @ 9776' RKB W/2.224" CENT & SAMPLE BAILER. PULL 1" DGLV'S FROM STA #1,2,3,4. ***IN PROGRESS. 12/01/03 SET NEW GLVIS IN STA # 1 & 2. IN PROGRESS. 12/02/03 INSTALL GLV'S IN STA # 3 & 4. GIVE WELL TO BOL. Page 1 of 1 12/19/2003 PI-i,..LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 9, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2X- 18 (195-160) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation job on the KRU well 2X-18. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooncy Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4601' FNL, 241' FEL, Sec. 4, T11 N, RgE, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 518888, 5970681) 6. Datum elevation (DF or KB feet) RKB 118 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2X-18 At top of productive interval 355' FSL, 1406' FEL, Sec. 10, T11N, R9E, UM At effective depth At total depth 5070' FNL, 1126' FEL, Sec. 10, TllN, R9E, UM (asp's 523296, 5964945) 9. Permit number / approval number 195-160 / 10. APl number 50-029-22608 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 9943 feet 6234 feet Effective depth: measured 9713 feet true vertical 6045 feet Casing Length Size CONDUCTOR 121' 16" SUR. CASING 5012' 7-5/8" PROD. CASING 9812' 5-1/2" Plugs (measured) Junk (measured) Cemented 300 sx AS I 750 sx AS III, 470 sx Class G 165 sx Class G Measured Depth 121' 5130' 9930' TrueverticalDepth 121' 3398' 6223' Perforation depth: measured 9618'-9638', 9666'-9684' true vertical 5971 '-5987', 6010'-6024' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 to 9180', 2.875", 6.5#, L-80 @ 9281' Packers & SSSV (type & measured depth) BAKER 'SAB-3' @ 9256' MD. CAMCO 'DS' @ 509' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 150 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 552 77 173 544 97 Casing Pressure Tubing Pressure - 143 148 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Gas __ Suspended __ Service _Water Injector__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/r/Y'>~ ,,~j' /,¢? //'~¢7~ :/¢~ '- Title Wells Team Leader Michael Mooney Questions? Call Mike Mooney 263-4574 Date ,/¢/:/<~/ Prepared by Shat'on Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2X-18 Event History 09/21/01 09/22/01 DRIFT TBG W/18'X 2.125" WT BAR, TAGGED FILL @ 9713' RKB EST. 75' RAT HOLE, COMPLETE. [TAG] PERFORATE W/2 1/8" POWER ENERJET 6 SPF, 9666' - 9684' +/- 90 DEG PHASING, TAGGED TD @ 9700', [PERF, TAG] Page I of I 10/9/01 2X-18 WELL TEST HISTORY TEST SEP SEP TOTAL DATE LENGTH CHK PRES TEMP FTP WHT OIL WTR GAS GLG % WC FGOR TGLR SAND Apr-Il-01 03:01 14.0 176 161 108 162 32 200 78 592 482 28 Apr-24-01 13:26 23.6 176 164 108 169 32 180 70 689 581 28 Apr-29-01 06:12 21.0 176 162 107 168 29 197 76 663 585 28 May-08-01 06:39 15.1 176 177 126 178 31 167 56 613 567 25 May-19-01 10:15 17.4 176 178 113 179 36 206 85 741 618 29 550 6OO 393 278 599 2131 2751 2425 2761 2549 May-20-01 12:16 21.0 176 178 113 180 35 207 85 737 623 29 Jun-01-01 04:56 12.5 176 161 109 159 37 171 71 515 441 29 Jun-07-01 10:18 18.0 176 173 111 171 37 168 71 531 468 30 Jun-25-01 07:04 13.5 176 157 133 155 39 185 84 602 479 31 Jul-10-01 08:48 17.2 176 175 129 174 38 176 81 603 499 32 548 433 376 668 591 2521 2128 2220 2239 2343 Aug-05-01 18:03 20.2 176 152 128 151 37 150 69 499 397 32 Aug-17-01 11:58 24.0 176 146 131 146 36 153 74 511 409 33 Aug-28-01 12:01 22.9 176 149 136 152 37 227 144 657 499 39 Aug-30-01 08:37 24.0 176 150 132 151 36 177 101 586 464 36 Sep-07-01 08:49 18.0 176 148 121 146 38 161 78 542 445 33 678 666 696 69O 6O4 2275 2253 1768 2110 2270 '.!~: Sep-18;01 08:00" 19.0 176 143 123 143 36 .. .,,,~.1.50 77 552 ;"451 34 ~'Si~p~26~:°'f'08:52 25.4 ,. 176 i45 126 148 . 36 ' 173 97 . 544' :':428 .:." 36 669 667 2422 2014 10/9/01 2:50 PM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ' Commissioner T°m Maunder, P. I. SuperviSor \( Chuck Scheve; Petroleum Inspector DATE: FROM: SUBJECT: January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 2001' I traveled to the Kuparuk River Field. and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AOGCC ;Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2X-14 had a slow leak when pressure tested. This valve was serviced and I witnessed a succeSsful retest on 1-26-01. Earnie Barndt Conducted the testing today he demonstrated good test procedure and was a pleasure to work With All the wellh°uses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90'day SVS testing at 2X Pad in the Kuparuk River KRU 2X pad, 12 wells, 24 components, I failure 4.1% failure rate 15 wellhouse inspections Attachment: sVs KRU 2X Pad 1-25-01 CS unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2X Pad Separator psi: LPS 99 HPS 1/25/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2X-01 1830840 2X-02 1831'030 3750 2000 '1800 P "P ' " WAG 2X-03 1831090 2X-04 1831180 3750 2000 2000 ' P P ' WAG 2x-05 183i070 ' ' 2X-06 1831100 2X-07 1831130 37~0 2000 -'2000i P "p' wAG 2X-08 1831140 ............ 2X-09 i841620' 99 " 60 60.... P' P ...... OIL 2X-10 1841630 2X- 11 1841640 99 60 50. P P OIL , , , 2X-12A 1951760 99 60 55 ' P P OIL 2X-13 1841740 99 60: 55 P P OIL 2X-14 'i841750 99 60! 55 P ' 4 1)26/01 " 0IL , ,~ 2X-15 1841760 99 60 55! P P OIL 2X-16 184172i~ ' 99 ' 60 55 e P ....0IL 2X-17 1951716 ' 99 60 ' 60 "1; P OIL 2X-1.8 1951600 99 60 60 1{ P ' OIL 2X-19 .' 19~175}5 ........... ,, Wells: 12 Remarks: Components: 24 Failures: 1 Failure Rate: 4.17% [] 90 oar Surface Safety. on well 2X-14 had .very slow leak when pressure tested, valve to be serviced and retested by operator. 1UF 1/16/01 Page 1 of 1 SVS KRU 2X Pad 1-25-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~-:-2~ Commissioner ~,/,'/~/..-~ o, DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor John H Spaulding, Petroleum Inspector FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & 1X 1E - 8 wells, 16 components, 1 failure, 9 % failure rate, 12 well house insp. .2X - 10 wells. 20 compnents, 1 failure, 5 % failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kuparuk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GASorC¥CLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL, 1E-19 1830170 1E-20 1830050 91 ' 60 48 P P OIL 1E-21 1830020 1E-23 1821840 1E-24A 1971870 91 70 70 p P OIL 1 E-26 1821660 SI 1E-28 1821580 SI 1E-29 1821540 SI 1E-31 1971380 91 70 70 p p OIL 1E-33 1971510 1E-34 1971660 91 70 70 p p OIL 1E-36 1982130 91 70 70 p p OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [] 9o Day Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kuparuk/Kuparuk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 2X-02 1831030 2X-03 1831090 2×-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2×-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-10 1841630 96 70 65 P P OIL 2X-11 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750! 2X-15 1841760! 96 70 70 P P OIL 12X-16 1841720 2X-17_., 1951710 96 60 50 P P C~IL 2~i8:1~_-5-' ~19516001 96 60 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [~ 90 Day Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls PERMIT 95-160 95-160 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS 7088 ~/~ ARC 5 ARC 5 ~ Page: 1 Date: 05/13/98 RUN DATE RECVD -- 02/02/96 03/05/96 95-160 ARC 5 C~ 10-407 DAILY WELL OPS ~PIA ~OMPLETION DATE 02/02/96 ~.~' ,~ I ,~ ? ~ Are dry ditch samples required? Was the well cored? yes ~___~And received? yes ~_~ ~alysis & description received? Are well tests required? t~es Well is in compliance~ ~ Initial COMMENTS ~-Received? Alaska, Inc. Post Office Box 10036u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 20, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2X-18 (Permit No. 95-160)Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2X-18. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad R£C IVF_D ,JUN ~ 1 1~9~ Alaska 011 & G,.% Cor~. commission Anchorage, STATE OF ALASKA AL~,_,KA OIL AND GAS CONSERVATION COM, _;SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS r~ SUSPENDED ~ ABANDONE[~ SERVICE 2 Name of Operator ~7 Permit Number ARCO Alaska, In¢ 95-160 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22608 At Top Producing Inte~al ~ ~~ 10 Well Numar 355' FSL, 1406' FEL, Sec. 10, T11N, R9E, UM[ ~F(iF~EC, ~'~ 2X-18 At Total Depth ~ ..~( ........ ~ ~[ ~' ~ ........ h 1~' Field and Pool 211' FSL, 1279' FEL, Sec. 10, T11N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Serial No. RKB 41', Pad 77'~ ADL 25645 ALK 2576 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if of~hore 116 No. of ~mpletions 29-~t-95 03-Nov-95 09-May-96 (peCd)~ NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey ~20 Depth where SSSV set 21 Thickness of ~rmafrost 62~' TVD 9841' M D & 6150' TVD YES--~ NO ~~ NA feet MD = 1380' ss APPROX 9943' M D & 22 Ty~ Electric or Other Logs Run ARC5/GR, G~CCUCBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEM~R~O~ 16" 62.58¢ H-40 SURF. 121' 24" 300 sx AS I 7.625" 29.7~ L-80 SURF. 5130' 9.875" 750 sx AS III Lead, 470 sx Class G Tail 5.5" 15.5¢ L-80 SURF. 9930' 6.75" 165 sx Class G 24 Perforations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9281' 9256' 9618'-9638' MD 4 spf 5971'-5987'~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9618'-9638' Prop in formation 165,000~, prop in wellbore 29293~, (14200¢ of ¢20/40, 180093¢ of 27 PRODUCTION TEST Date First Production lMethod of O~ration (Flowing, gas lift, etc.) May-96~ FLOWING Date of Test lHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO June 17,1996 9 TEST PERIOD E 239 242 14 176 1013 f Flow Tubing [Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 152J 717 24-HOUR RATE ~ 6 37 ~5 37 =24° 28 CORE DATA RECEIVED JUN 2 1 199G Form 10-407 ,-, ,.,, ,.,,,.,:~v/'t-llr'!ini'":"m:~ Submil in duplicale Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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 Kuparuk C 9367' 5778' Bottom Kuparuk C 9443' 5836' Top Kuparuk A 9587' 5946' Bottom Kuparuk A 9735' 6063' JUN 2 1 1996 Alaska 0tl & ~t~, Ccns. Commission Allohorag9 Freeze protect with diesel. 31. LIST OF A'I-FACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 ~e: 6/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL-2X-18 RIG:PARKER 245 WELL ID: AK8349 AFC: AK8349 TYPE. -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD'10/29/95 START COMP' BLOCK: FINAL: WI' 0% SECURITY:0 AFC EST/UL'$ OM/ API NUMBER: 50-029-22608-00 OM 10/27/95 ( 1) TD: 121' (121) SUPV:RLM DAILY' 10/28/95 (2) TD' 121'( 0) SUPV'RLM DAILY' 10/29/95 (3) TD' 301' (180) S UP V: RLM DAILY: 10/30/95 (4) TD: 4795' (4494) SUPV'RLM DAILY' 10/31/95 (5) TD: 5140' (345) SUPV'RLM DAILY' 11/01/95 ( 6) TD: 6000' (860) SUPV'DCL DAILY: 11/02/95 ( 7) TD' 8000'(2000) SUPV:DCL DAILY' 11/03/95 ( 8) TD' 9745'(1745) SUPV'DCL DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG FROM iQ TO 2X Moved drilling and utility modules from IQ pad to KCS pad. $104,531 CUM: $104,531 ETD: $0 EFC: $104,531 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG OVER 2X-18 Move drilling module 6.1 miles from KCS pad to 2X pad. $55,541 CUM: $160,072 ETD: $0 EFC: $160,072 MW: 9.0 PV/YP: 18/26 APIWL: 6.8 DRILLING Accept rig at 1400 hrs. 10/28/95. Function test diverter system. Spud at 0500 hrs. 10/29/95. Drill 9-7/8" hole from 121' to 301' $83,487 CUM: $243,559 ETD: $0 EFC: $243,559 MW: 10.0 PV/YP: 23/22 POOH Drill 9-7/8" hole from 301' to 4795' $76,125 CUH' $319,684 ETD' $0 EFC: APIWL' 6.8 $319,684 APIWL. 7.2 MW: 10.0 PV/YP: 19/13 TOP JOB Directional drill from 4795' to 5140' Ran 7-5/8" casing to 5130' Cement casing, CIP at 0545 hrs. 10/31/95. $177,229 CUM: $496,913 ETD: $0 EFC: $496,913 MW' 8.8 DRILLING Drilling from 5150' to 6000' $86,277 CUM' $583,190 ETD: PV/YP: 4/ 5 $0 EFC' APIWL: 12.4 $583,190 MW: 9.0 DRILLING Drilling from 6000' to 8000' $76,377 CUM' $659,567 ETD' PV/YP' 1/ 7 AP IWL. 8.1 $0 EFC: $659,567 MW' 11.5 PV/YP: 26/14 APIWL: 4.8 DRILLING Drilling and MWD survey from 8000' to 9745' $98,634 CUM: $758,201 ETD: $0 EFC: $758,201 RECEIVED JUN 2 ] ]99G Alaska Oil & Gas Cons. Commission AnchoFago _ce' 6/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:2X-18 RIG'PARKER 245 WELL ID: AK8349 AFC: AK8349 TYPE: STATE:ALASKA AREA/CNTY- NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD:10/29/95 START COMP' BLOCK' FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ OM/ API NUMBER: 50-029-22608-00 OM 05/03/96 (9) TD: 9942' PB: 9841' SUPV:DEB DAILY: MOVING RIG Moving rig from 3M-27 to 2X-18 $10, 154 CUM: $768,355 ETD' MW: 0.0 DOILSW $0 EFC' $768,355 05/04/96 (10) TD: 9942' PB: 9841' SUPV:DEB DAILY: RACK & TALLY 3.5" TUBING MW: 0.0 Moved rig from 3M-27 to 2X-18. Accept rig @ 1300 hrs. 5/3/96. ND tree. NU BOPE. Test BOPE components. OK. Test 5.5" casing to 3500 psi for 30 minutes. OK. $50,341 CUM: $818,696 ETD: $0 EFC: $818,696 05/05/96 (11) TD: 9942' PB' 9841' SUPV'DEB DAILY: ND BOPE MW: 6.8 DOILSW Run 3.5" tubing witn 2-7/8" GLMs. Tag ice plug @ +/-210'. Circulate through ice plug with hot sea water. Continue circulating to warm up wellbore. Run 3.5" single completion assembly. Pressure tubing to 2500 psi and set packer. Set BPV. ND 7-1/16" BOPE. $131,126 CUM: $949,822 ETD: $0 EFC: $949,822 05/06/96 (12) TD: 9942' PB: 9841' SUPV:DEB DAILY: WELL COMPLETED - CLEANING MW: 0.0 ND BOPE. NU tree. Test tree and packoff to 500/5000 psi, ok. Secure well. Released rig @ 1200 hrs. 5/5/96. $28,020 CUM' $977,842 ETD' $0 EFC' $977,842 End of WellSummary for Well'AK8349 RECEIVED ,JUf'~ '?. '1 ]996 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~ K1(2X-18(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-18 PERFORATE, PERF SUPPORT 0506960900.7 DATE. DAILY WORK UN IT NUMBER 05/09/96 INITIAL PERFS- PRODUCER DAY 1 OPERATION COMPLETE I SUCCESSFUL YES I YES InitialTbgPress I FinalTbgPress I lnitiallnnerAnn 400 PSI 800 PSI 0 PSI KEY PERSON SWS-SCHWARTZ Final Inner Ann 0 PSI I SUPERVISOR PENROSE Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI DALLY SUMMARY PERFORATED WELL WITH 2 GUN RUNS OVER THE INTERVAL 9,618' TO 9,638' (20') W/2-1/8" ENERJET BIG HOLE PERFORATORS TO YIELD A TOTAL SHOT DENSITY OF 4 SPF, PHASED @ 180 DEG AND ORIENTED NORMAL TO THE TOP-TO-BOTTOM AXIS OF THE HOLE. TIME LOG ENTRY 17:15 SWSARRIVED. R/U. M/U GUN #1. 18:15 ARM GUN, LOAD INTO LUBRICATOR AND M/U LUB ONTO WELL. PRE-JOB SAFETY MEETING. PRESSURE TEST LINES AND EQUIPMENT TO 3500 PSI. 18:45 RIH W/GUN .#1. 19:30 19:50 20:25 ON BOTTOM. CORRECT DEPTH AND TIE IN. FIRE GUN: PERF'D INTERVAL 9,618' TO 9,638' (20') W/2-1/8" ENERJET BIG HOLE PERFORATORS @ 2 SPF, ORIENTED @ 90 DEG CW F/LOW SIDE OF HOLE. POH. CCH. ALL SHOTS FIRED. M/U GUN #2. 21:00 RIH W/GUN #2. 21:45 ON BOTTOM. CORRECT DEPTH AND TIE IN. 21:55 22:30 23:00 FIRE GUN: PERF'D INTERVAL 9,618' TO 9,638' (20') W/2-1/8" ENERJET BIG HOLE PERFORATORS @2 SPF, ORIENTED @ 90 DEG CCW F/LOW SIDE OF HOLE. (RUNS #1 AND #2 COMBINED YIELD A TOTAL SHOT DENSITY OF 4 SPF, PHASED @ 180 DEG). POH. OOH. ALL SHOTS FIRED. R/D SWS. R/D COMPLETE. WELL SECURED. MOVE OFF LOCATION SCHLUMBERGER' *********************************************************** COMPANY ARCO ALASXA~ INC. ~ELL NAmE 2X-18 LOCATION ! KUPARUK LOCATION 2 ALASXA MAGNETIC DECLINATION 27,8B GRID CONVEROENCE ANGLE 0,00 , ~ELL NUMBER I~ APl#: 50-027-2Z~08-00 A~E#: AK8347 WELL HEAD LOCAHON: LAT(N/-S) O,OO AZIMUTH ~ROH ROTARY TABLE TO TARGET i~ TIE IN POINT(TIP) : HEASURE~ DEPTH 121o00 TRUE VERT DEPTH 121,00 INCLINATION 0,00 AZIMUTH 0,00 LATITUDE(N/-S) 0,00 D!PARTUR~(£/-~) 0,00 DEP(E/-~) O.O0 ************* ANAORILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC MEASURED INTERVAL VERTICAL DEPTH D£PTH f~ f~ f~ 121.00 0,0 12!.00 ~96.32 75,3 196,32 281,46 35,1 281.45 376.94 95,5 376+87 467.48 ?0,? 467,35 TARGET ~TATION AZIMUTH LATITUDE SECTiOH IHCLN, H/:S ft' deg ~ ft 0,00 0,00 0.00 0,00 -0,52 0,82 339,16 0.50 -0.?0 0,3? ?8'.54 1,03 2,29 3,56 148.78 -1,55 11,14 7,69 150.24 -9,26 -DEPARTURE DISPLACEMENT at ~/'W ft f~ 0,00 0,00 -0.19 0,54 -0.!2 1,04 1,74 2,33 6.22 11,16 AZIMUTH' DLS deg/ deg lOOft 0,00 0,00 339.16 1,09 353,2! 1,26 131,9! 3.48 146.0~ 4,55 561.06 93,2 559.39 653,60 92,5 650,07 745,36 91,8 739,10 837.~ ~= 92.2 827,70 930,57 93,0 916,19 25+40 10.20 154.50 -22,12 43.49- I2,81 153,71 -38,71 65.37 15,16 150,60 -58,2~ ?0,55 16,94 152,64 -80,72 118.88 18,93 150.19' -105,85 12,~7 25,59 149.50 2,77 20°?4 44,01 151,58 2,83 31.34 66.17 15!.73 2.69 43,43 91,66 151,72 2,03 57,16 120,30 151,63 2,28 ' 1021,!5 1111,58 1205,81 1297.01 1389,62 90.6 1001,33 ?0.4 1084.76 94,2 1168,85 91,2 1247,16 92,6 1324.59 149.72 2!,05 140,96 -131.25 74.72 151.03 150.35 4.18 184,56 24,31 141,53 -158,44 96,53 185.53 148,65 3,61 227,00 29,25 142.?? -192,02 122.47 227,76 147.47 5,30 273,7! 32,39 144,94 -229,82 149,93 274,40 146,88 3,62 324,50 34,16 143,68 -271,09 179,58 325,17 !46,48 2,05 1484,59 1572.ii 1665,10 I758,99 185!,50 ?5,0 1401.90 87,5 1471,34 93,0 1543,28 93,9 !612,34 ?2.5 1675.97 379,65 36,85 142,06 -315,04 212,89 380,23 432,90 38,11 141,97 -357,01 245,67 433,37 491,82 40.53 142,50 -403,59 281.75 492,21 555,38 44,72 144,25 -454,63 319.65 555,75 622,49 48,35 144,22 -509,10 358,~8 622,88 145,95 3,00 145.47 1,44 145,08 2,63 144,89 4,63 144.52 3,93 1944,30 2038,90 2128,81 2405°85 2777,55 92,8 1735,92 94,6 1793,39 89,9 1844,61 277,0 1992,94 371,7 2183,22 693,29 51,15 144,44 -566,63 400.18 693,70 768,38 54,01 144,66 -627.84 443.75 768,83 842.21 56,53 145,32 -688,36 486,13 842,71 1075,92 58,72 145,68 -881.I~ 618,64 1076.66 I394,78 59,70 145,89 -1145,23 798,16 1395,93 144.77 3,02 144.75 3,03 144,77 2.87 144,93 0.~0 1'45.13 0.27 3144,!5 3511,77 3885.84 4345,42 4623,30 366,6 2369,23 367,6 2555,61 374.1 2747,43 459,6 2985,84 277,9 3!33,63 1710.28 59,32 145,49 -I406,18 2026,46 59.40 I42,67 -1662.30 2348.19 59,25 143,29 2741,03 58,2~ . 140,94 -2229,27 2976,31 57,50 143,07 -2414,69 976,21 1711,82 145,23 0,14 1161,73 2028,02 145,05 0.66 m 1355,45 2349.57 144,77 0.15 1596,67 2742,08 144,39 0.49 1741.55 2977.20 144,'20 0,70 4901,87 278,6 3279,19 5061,80 159.9 3362.03 5233.21 171,4 3452,86 5512.13 278.? 3597,58 5785.70' 273.6 3737,70 3213,80 59,50 I41,75 -2602,85 3350,53 58,10 I40,49 -2709,34 3495.67 57.90 138,79 -2820,II 3733,92 59,60 142,93 -3005,04 3968~80 58,79 140,30 -3189,23 1886,46 3214,59 144,07 0,82 !972,32 3351.21 143,95 1,10 2066.45 3496.17 143,77 0,85 2216,85 3734,26 143.58 1,41 2362.Yl 3969,07 I43,47 0,88 6252,97 2.2.,76 6899,01 7084,09 7359,.96 467,3 3982,67 369,8 4180,64 276,2 4331,37 185,i 4430,46 275,8 4571.35 4366,56 57,98 142,43 -3500,0t 4678.47 57,3I 137,84 -3739,70 4909.37 56,56 139.56 -3913,60 5065,47 58,70 140,04 -4032.98 5302,41 59,90 146,03 -4222,35 2611,15 4366.71 143.28 0,42 2811,27 4678,52 143,07 1,06 2964.07 4909,37 142,96 0,59 3064.96 .5065,47 142,77 Io17 C v r_ D Alaska Oil & G,.'~s' uo,~s." - Corr, mission ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** 7343,44 7S18o33 8282,20 INTERVAL VERTICAL TARGET STATION AZIMUTH L~TITUDE DEPTH SECTIOH IHCLN, N/-S i83.6 4664,78 5460,36 58,93 142.57 -4350,68 132,5 4732,07 5574,55 60,05 143,67 -4442,02 142.3 4803.68 5697.55 59,54 t43,79 -4541,20 281,1 4946.8! 5939.27 59,24 146,02 -4739,i0 i82,8 5042,61 6094,89 57,58 141,19 -4864,42 DEPARTURE DISPLACZHENT at AZimUTH. ft ft deg 3299,57 5460.36 !42,82 3368,10 5574,55 142.83 3440,B8 5697,56 142,85 3579,94 5939,28 I42,93 3672.24 6094,91 142,95 8376,73 8476.17 8560,73 8652,03 8749,22 8839,46 9024,52 9118,64 92!1.00 9397,27 94,5 5093,81 6174.28 56,84 139,56 -4925,62 99,4 5149,49 6256,59. 55,06 141,16 -49B9.06 84,6 5199.52 6324,73 52,38 142.06 -5042,47 91,3 5257,59 .6395,15 48,60 142,73 -5098,26 ?7,2 5323.95 6466,I4 45,27 144,36. -5155,35 . 90,2 5387,66 6530,03 44,92 144,47 -5207,32 185.1 5520,62 6658.71 43,22 142,55 -5310,80 94oi 5589,93 6722.39 41,95 141,I7 -5360,90 92,4 5659,28 6783,32 40,71 139,74 -5407.93 186,3 5800,88 6904,06 40,34 138,08 -5499o~4 3722,92 6174,29 142,92 3775,48 6256,60 142,88 3817,82 6324,73 142,a7 3860,80 6395o16 142,9~ ' 3903,00 $466.14 142.87 3740,17 6530,03 142.S9 4016,70 6656,72 - 4056,02 6722.39 142,~9 4094.&5 6783.32 142,87 4174,39 6904.06 142,80 9581,07 183,8 9851,50 270,4 SURVEY B 9943,20' 9942,20 71,7 5941,74 7021.65 39,60I37,31 -5586,46 . 6157,93 7183.49 34,21 139.91 -5708.06 IS PROJ£CT£D A? THE BIT, .6233,77 7234,98 34,21 I39,~1 -5747,50 DL$ d~q/ lOOft 1,71 1.~I 0,27 0,6? 2,43 1,64 2,23 3,28 4,19 3,64 0.40 1,17 1,68 1,69 0.61 4253,65 7021,66 142,7! 0,49 4361,22 7183,53 I42,62 2,07 4394,52 7235,03 I42,60 0.00 ARCO Alaska, Inc. Date' March 1, 1996 Transmittal Ct: 9341 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATe-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. Please acknowledge ~,~"/~X-18 Array Resistivity Compensated ~,~... / ,.~ ~-"2X-19 Array Resisting Compensated Acknowledged: ~~--~.~,//~/~ 11/03/95 11/17/95' Date' DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATe - 12O5 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 5130-9900 8718-9517.8 RECEIVED MAR 0 5 19~ Alaska Oil & Gas Cons. Commission Anchorage Clifton Posey Geology ATe - 1251 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10018 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 2/2/96 Field: Kuparuk (OH/CH) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2X-18 ¢ff~--t(o~3 95358 ARC5 951103 I I '~' I P'"'" 2X-19 qF-f?~- 95384 ARC5 951117 1 I 1/~-~ SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, inc. Date' January. 1 5, 1996 Transmittal #: 9318 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 12/05/95 12/16/95 12/04/95 12/12/95 Date: · Sharon AIIsup-Drake DS Development ATe-1 2O5 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 8500-9809 6500-,8,~545 8210~ 7594- o~ §~:~'~.Z.,~ o,¢c~ ?C,¢.° _ 4dx % ~dckson/Zuspan NSK Central Files NSK-box 69 TONY KNOWLE$, GOVERNOR ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 13, 1995 Mike Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2X-18 ARCO Alaska Inc. Permit No 95-160 Surf Loc 674'FSL, 241'FEL, Sec. 04, T11N, R09E, UM Btmhole Loc 128'FSL, 1097'FEE, Sec. 10, T11 N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be um field inspector on the North Slope pager at 659-3607. _D.av.id W. J~hnston ~ ~- ~ Chairman ~ -'" BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASrv-~ OIL AND GAS CONSERVATION COMMISSI~. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory E~ Stratigraphic Test [] Development Oil X Re-Entry [] Deepen r~ Service [~ Development Gas E] Single Zone X Multiple Zone E] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 77' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25645, ALK 2576 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 674' FSL, 241' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 230' FSL, 1175' FEL, Sec. 10, TllN, R9E, UM 2X-18 #U-630610 At total depth 9. Approximate spud date Amount 128' FSL, 1097' FEL, Sec. 10, TllN, R9E, UM 1 0/25/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I-VD) property line 2X-01 10040' MD 128 ~ TD feet 98.2' ~ 1016.7' MD feet 2560 6296' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 58.2° Maximum,surface 2022 psig At total depth (TVD) 3400 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Len~lth MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 5027' 41' 41' 5068' 3415' 750 Sx Arcticset III & HF-ERW 470 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOE 9999' 41' 41' 10040' 6296' 140SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~. ....... 'EL,) Surface ' ~;., ,, L i ~ Intermediate Production LinerOC T '1 I 1995 Perforation depth: measured Atask~ uu & Gas Cons, C0rrlrr!.jss[~ri true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [-] Refraction analysis [] Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that t~e~ foregoing'(~.,~_,,, is true and correct to the best of my knowledgeTitle Date /~ ~'~---~'~'~' Signed ~,--,~¢,_ i, Drill Site Develop. Supv. Commission Use Only Pe~it Numbe, r 12~~ IAppr°va' date Isee c°ver 'etter f°r ~',~'J~' ~ ~ -- ~ ~, ~ O <~ t (~' \-"~' C~ ~ other recluirements Conditions of approval Samples required r"l Yes J~ No Mud Icg required [-'1 Yes ,,~ No Hydrogen sulfidemeasures J~ Yes [] No Directional survey required [] Yes ~ No Required working pressure for BOPE ~ 2M ,~ 3M E~ 5M [~ 10M E] 15M Other: Original Signed By David W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2X-18 · . , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (5,068')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing t_o 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (10,040') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 5-1/2" casing to 3500 psi. Run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well 2X-18 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 1 5-40 10-12 9.5-10 +10% Drill out to wei~lht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% .. Weight up to TD 11.7 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes- Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,022 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2X-18 is 2X-01. As designed, the minimum distance between the two wells would be 98.2' @ 1016.7' MD. Annular Pumping Activities: Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2X-18 surface/production casing annulus will be filled with diesel after setting the 5-1/2" casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2X-18 be permitted for annular pumping occurring as a result of the ddlling project on DS 2X, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 2X surface casing shoes will be set _+100' vertical below the base of the West Sak into the heart of the shales. Drillin~l Area Risks: Risks in the 2X-18 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.7 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. OCT 'i 1 't995 N~,$ka. Oi~ & Gas Cons. C0mm[ssiot~ Anchorage Creat~ by. : jone.~ For: D PETP, ASH:~ Date plotted : 3-0ct-95 iPIot Rei'erence is 18 Version ,~3. ;Coordinotes are in feet reference slot ~18, ITrue Vertical Depths are reference RKB (Porker 37.21 DEG E (T0 T^g Er) 500 _ 0 500 _ - 1000_ (- ~5oo_ -- ~ 2000_ _ 0 2500_ 0 g- 3000_ 3500_ ~ 4000 5000 ARCO ALASKA, Inc. Structure : Pad 2X Well : 18 Field : Kuparuk River Unit Location : North Slope, Alaska Scale 1:2.50.00 East --> 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 ESTIMATED SURFACE LOCATION: 674' FSL, 241' FEL SEC. 4, T11N, R9E EST. RKB ELEVATION: 118' 3.00KOPTVD=300 TMD=300 DEP=O 9.00 15.OO BUILD 3 O£C / I00' 21 .oo ~ 27.00 k 33.oo k 39.00 8/ PERMAFROST TVD=1508 TMD=1608 OEP=431 %% 45.00 ~ T/ UGNU SNDS ~D=2055 TMD=2452 OEP=lO84 ~ I T~GET L0CAIION: W SAK SNDS WD=3308 1MD=4866 DEP=3134 I 7 5/8" CSG PT WD=3415 ~D=5068 DEP=3507 TABASCO SNDS WD 3522 TMD 5271 OEP 3479 ~ 230' FSL, 1175' FEL - - - [ SEC. 10, 111N, R9E TARG~ ~D=6143 MAXIMUM ANGLE 58.17 DEG SOUTH 5724 EAST 4546 CAMP. BLUE ~/D=4773 TMD=7643 DEP=5494 BEGINANGLE DROP TVD=5236 TMD=8520 DEP=6259 58.00 54.00 DROP 2 DEC / 100' 50.00 46.00 t BASE HRZ TVD=5664 TMD=9207 DEP=6774 K-1 TVD=5760 TMD=9339 DEP=6864 42.00 T/ UNIT O (EOD) TVD=5828 TMD=9429 6000 T/ UNIT C TVD=5842 TMD=9447 DEP:6934 TARGET ANGLE T/ UNIT B TVD:5906 TM0=95.30 OEP=6988 40 DEG T/UNIT A 'h/D=6014 TMD=9671 OEP:?079 e~oo TARGET - B/ KUP SND~ TVD=G14S TMD=9840 DEP=T187 TD - 5 1/2" CSG PT TVD=§295 TMD=IO04O DEP=7315 ~ ~ , , [ [ , ~ , , ~ , ~ [ ~ ~ [ t , , ] ~ ~ ~ , , ] , , [ [ 500 0 500 1000 i 500 2000 2500 30,30 3500 4000 4500 5000 5500 6000 6500 7000 7500 I · 250.00 Verficol Section on 142.79 ozimuth with reference 0.00 N, 0.00 E from slot #18 5OO _ _ 0 _ _5OO - _1000 _ 1500 2000 ('~ O - c- _2500 - 3000 I _3500 4000 V 4500 ,5000 _ _5500 _ _6000 _ TD LOCATION: 128' FSL, 1097' FEL SEC. 10, TllN, RgE iC~eoted b~ : jone~ For: D PETRASHi iOote plotted : 3-0ct-95 Plot Reference is 18 Version ~3. Coordinotes (]re in feet reference slot ~18. ;. iTrue Verticol Depths ore reference Scale 1 : 20.00 80 40 0 40 120 · ~ ~ I I I 1 °t © 4o o 40 4 701 _] 1700 80 _ 120 _ 160 200 - 24O _ 280 _ i 32O 560 _ 4O0 440 t 480 520 _ -- 560 _ 6OO 80 120 I I I I 2100 ARCO ALASKA, Ibc. Structure : Pad 2X Well: 18 Field : Kuparuk River Unit Location : Norfh Slope, Alaska Easf --> 160 200 240 280 320 ,360 400 440 480 I I I I I 9CX3 2go0 80 40 Scale 1 - 20.00 0 40 80 120 160 200 240 280 320 360 Easf > 1700 400 440 520 560 600 I I I I I I 120 -- 80 _ 40 _ _ 0 4O _ 120 _ _ 160 200 240 -- _ 280 _ 320 360 _ 400 _ _ 440 _ _ 480 _ 520 _ 560 _ 6OO 80 520 560 600 I I V !Cr~te~ ~ : Jo~: For: D PETRASH plotted : 3-0ct-95 Reference is 18 Version iCoordinetes (]re in feet reference slot ~18. Vertical Depths ore reference RKB (Porker ~245). Scale 1 : 50.00 ARC0 ALASKA, Inc. Sfrucfure : Pad 2X Well : 18 : Field : Kuparuk River Unif Location : Norfh Slope, Alaska Easf --> 200 $00 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 0 500 .. ~ 600 Cf') 700 8O0 900 1000_ 100_ 1200_ ! ] - 1300_ 09 - i i1500_ _ V 1600_ 1700 !800 1900_ _ 2000_ _ 2100_ _ 2200_ _ 2300 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 31CK) ~2300 - 3300 5oo 600 ' ' - 0 700 0 800 2500 3500 00 'x~ 900 3700 2300 200 0 ~ 2900 1300 I 500 ' ~ 4500 ~ooV 1700 2700 ilO0 2100 0 2200 I I i I I I I I I I I I ! I I I I I I I I I I I I I I I I '1 I I I 12300 200 500 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1~00 ~cole 1 - 50.00 E a s f - - > 7 5 4 3 13 5/8" 5000 PS', 3OP STACK AC(;;UM ULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. -. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE lINES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. ~NUE TESTING ALL VALVES, lINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)0 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING J'l' AND PULL OUT OF HOLE. CLOSE BliND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BliND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 11. TEST STANDPIPE VALVES TO 3(X)0 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13~$/8" - 5000 PSI ANNULAR OCT 'I 'i !S?$ .Oil .& Gas Cons. ComrnjsSiOD "~, ;Anchorage .UPARUK RIVER UNI'. 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1, MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 ,..- PERMIT CHECKLIST FIELO POOL f< /o O COMPANY INIT CLASS WELL NAME GEOL AREA PROGRAM: exp [] UNIT# dev~/ redrll [] serv [] ON/OFF SHORE OW~) ADMINISTRATION APPR D 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... . N ' 7. Sufficient acreage available in drilling unit ..... ' N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ..... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ........ N ENGINEERING REMARKS 14. Conductor string provided ............... N 15. Surface casing protects all known USDWs ........ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . ' 18. CMT will cover all known productive horizons ...... ' N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... (.Y~/ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ........... .__ ......... ~ N 26. BOPE press rating adequate; test to ~C~ psig. Y~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .~/~ 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y// N 33. Seabed condition survey (if off-shore) ........ ~/~ 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB C~mments/Instructtons: HOW/jo - A:%FORMb-%cheklist rev 03/94 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. * ALASKA COMPUTZNO CENTER SCHLUMBERGER ....... * COMPANY NAME : ARCO ALASKA, ZNC. WELL NAME : 2X - 18 FZELD NAME : KUPARUK RZVER BOROUGH : NORTH SLOPE STATE : ALASKA APZ NUMBER : 50-029-22608-00 REFERENCE NO : 95358 biS Tape Verification Lis¢ing Schlumberger Alaska Computing Center 31-JAN-1996 15:10 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/01/31 ORIGIN : FLIC REEL NAME : 95358 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2X-18, API #50-029-22608-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/01/31 ORIGIN : FLIC TAPE NAME : 95358 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2X-18, API #50-029-2260@-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2X - 18 500292260800 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 31-JAN-g6 BlT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: 630161 630161 LOGGING ENGINEER: NICOLS NICOLS OPERATOR WITNESS: MORRISON LUTRICK SURFACE LOCATION SECTION: 4 TOWNSHIP: RANGE: 9E FNL: FSL: 674 FEL: 241 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 118.00 DERRICK FLOOR: 118.00 GROUND LEVEL: 77.09 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) [ST STRING 6.750 7.625 5130.0 2ND STRING PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1996 15:10 3RD STRING PRODUCTION STRINg REMARKS: Well drilled 31-OCT through 03-NOV-95 with ARC5 only. All data was collected in two bit runs, No MAD data was collected. $ $ PAGE: **** FILE HEADER FILE NAME : EDIT .OO1 SERVICE : FLIC VERSION : ~O1CO1 DATE : 96/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5~00 FILE SUMMARY LDWg TOOL CODE START DEPTH STOP DEPTH MWD 5094.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 9777.5 9705.0 9699.5 9664.0 9650.5 9635.5 9621.5 9586.5 9584.5 9530.5 9469.5 9414.~ 9345.0 9339.0 9327.~ 931~.5 9303.5 MWD 88889.0 9778,5 9705.5 9700.0 9664.5 9650.5 9636.5 9622,0 9587 0 9584 5 9531 0 9469 5 94;14 0 9345 0 9338 5 9326 5 9310 0 9303 0 9943.0 EQUIVALENT UNSHIFTED DEPTH ~£S Tape VerificatJen Lis~ing Schlumberger Alaska Computing Center 31-JAN-1996 15:10 9283.0 9253.5 9235.5 9230.0 9166.0 9149.5 9126.0 9116.0 9~9~.5 9057,0 9035.0 9026.0 8983 5 8973 5 8963 5 8958 0 8937 5 8918 0 89~6.5 8897.5 8867.0 8810.5 8806.0 8797.0 8794.0 8772.~ 8751.0 8704.e 8667,5 8638.5 8598.0 8583.0 8511.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE 9282.0 9252.5 9234.5 9228.5 9165.0 9148.0 9125.5 9115.0 9~9M.~ 9056.0 9033.5 9025.0 8982.0 8972,0 8961.0 8956.0 8935.5 8915.5 89~3.5 8895.5 8865.0 8808.5 8803.5 8795.0 8791.0 8769.5 8748.0 8701.5 8664.0 8635.0 8595.0 8580.0 8509.0 97.5 BIT RUN NO. MERGE TOP MERGE BASE MWD 1 5~94.0 7765.0 MWD 2 7765.0 9943.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR %0 the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the CBT GR as well as a recomputed GR that normalizes the CBT GR %o OH conditions, This recomputed GR can be used in the areas %ha% the MWD GR is spiking. $ LIS FORMAT DATA PAGE: LIS Tape Verification Lis%lng Schlumberger Alaska Computing Center 31-JAN-1996 i5:10 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API APZ FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 900 09 0 1 1 1 4 68 0000000999 ROP MWD F/HR 99 999 09 0 1 1 1 4 68 9999999999 FET MWD HR 99 099 90 0 1 1 1 4 68 9999999999 GR MWD GAPI 99 999 99 0 1 1 1 4 68 0999999999 GR NEW GAPI 99 999 09 0 1 1 1 4 68 0000000009 GR CBT GAPI 99 0~0 99 0 1 1 1 4 68 0000099999 RPXX MWD OHMM 99 999 99 0 I I ~ 4 68 00000~0~00 RPX MWD OHMM 99 0~0 09 0 1 I 1 4 68 0000099999 RPS MWl) OHMM 99 999 99 0 1 1 1 4 68 ~0~00~0000 RPM MWi) OHMM 99 999 99 0 I 1 1 4 68 ~0~0~0000 RPD MWD OHMM 09 ~0 ~ ~ 1 1 1 4 68 ~00~000~00 ** DATA ** DEPT. 9942.999 ROP.MWD 49.599 FET.MWD -999.259 GR.MWD GR.NEW -999.259 GR.CBT -999.259 RPXX.MWD -999.259 RPX.MWD RPS.MWD -999.259 RPM.MWD -999.259 RPD.MWD -999.259 DEPT. 9999.909 ROP.MWD 189.999 FET.MWD 9.536 GR.MWD GR.NEW 234.688 GR.CBT 187.759 RPXX.MWD 2.864 RPX.MWD RPS.MWD 3.221 RPM.MWD 3.341 RPD.MWD 3.489 -999.259 -999.259 211.649 3.073 LIS Tape Veri~icatien Lis~ing Schlumberger Alaska Computing Center 31-JAN-1996 15:10 PAOE: DEPT. 8000.000 ROP.MWD OR.NEW -999.250 OR.CBT RPS.MWD 2.100 RPM.MWD DEPT. 7000.000 ROP.MWD OR.NEW -999.250 GR.CBT RPS.MWD 2.643 RPM.MWD DEPT. 6000.~00 ROP.MWD OR.NEW -999.250 GR.CBT RPS.MWD 3.622 RPM.MWD DEPT. 5090.500 ROP.MWD OR.NEW -999.250 OR.CBT RPS.MWD -999.250 RPM.MWD END OF DATA ** 215.217 FET.MWD -999.250 RPXX.MWD 2.187 RPD.MWD 165.000 FET.MWD -999.250 RPXX.MWD 2.605 RPD.MWD 116.471 FET.MWD -999.250 RPXX.MWD 3.677 RPD.MWD -999.250 FET.MWD -999.250 RPXX.MWD -999.250 RPD.MWD 0.517 1.9~9 2.286 0.519 2.429 2.532 0.458 3.490 3.722 -999.250 -999.250 -999.250 GR.MWD RPX.MWD GR.MWD RPX.MWD GR.MWD RPX.MWD GR.MWD RPX.MWD 138.648 2.012 85.612 2.573 86.085 3.559 7.745 -999.250 **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .0~2 SERVICE : FLIC VERSION : e¢1C01 DATE : 96/01/31 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header da%a for each bi% run in separate ~|les, BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 5~94.~ 7765.0 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 31-JAN-1996 1S:I~ $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 2-NOV-95 5.5C 5.5 MEMORY 9943.0 5094.0 7765.0 $$ .0 55.~L 60.0 TOOL NUMBER ARC5 RESISTIVITY $ ARCS-O14 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 6.750 5130.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/Q): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 9.90 36.0 9.5 10.0 2.880 2,430 79.0 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *****RUNS 1 & 2***** DISTANCE TO BIT: GR=46.2'; RES=41.3' D&I TO BIT = 85.3' RUN 1 DRILLED INTERVAL 5140' TO 7765' RUN 2 DRILLED INTERVAL 7765' TO 9943' GR SPIKES ON LOG CAUSED BY INTERMITTENT FAILURE $ PAGE: LIS Tape Ver i f i ca%i ¢,n Li s~i ng Schlumberger Alaska Compu%ing Cen%er LIS FORMAT DATA 31-JAN-1996 15:10 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOO TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 2 1 1 4 68 0000000000 ROP LWI F/HR 00 000 00 0 2 1 1 4 68 0000000000 . .. { FET LW1 HR 00 000 00 0 2 1 1 4 68 0000000000 GR LW1 GAPI 00 000 00 0 2 1 1 4 68 0000000000 RPXX LW1 OHMM 00 000 00 0 2 1 1 4 68 0000000000 RPX LW1 OHMM 00 000 00 0 2 1 1 4 68 0000000000 RPS LW1 OHMM 00 000 00 0 2 1 1 4 68 0000000000 RPM LW1 OHMM 00 000 00 ~ 2 1 1 4 68 0000000000 RPD LW1 OHMM 00 000 00 0 2 1 1 4 68 0000000000 DATA ** DEPT. 5090.000 ROP.LW1 180.000 FET.LWl 0.000 GR.LWl RPXX.LW1 208.295 RPX,LWl 780.509 RPS.LWl 1000.000 RPM.LW1 RPD.LW1 1000.000 7.732 lO00.000 LIS Tape Verificaticn Lis~ing Schlumberger Alaska Computing Center DEPT. 6000.000 ROP.LWl RPXX.LW1 3.331 RPX.LWl RPD.LWl 3.484 DEPT. 7~0e.000 ROP.LW1 RPXX.LW1 2.226 RPX.LW1 RPD.LW1 2.368 DEPT. 7765.000 ROP.LWl RPXX.LWl 1.625 RPX.LWl RPD.LW1 1.965 31-JAN-1996 15:10 86.087 FET.LWl 3.386 RPS.LWl 141.429 FET.LW1 2.324 RPS.LWl 33.000 FET.LW1 1.752 RPS.LW1 0.469 3.429 0.514 2.359 1.281 1.840 GR.LWl RPM.LWl GR.LW1 RPM.LW1 GR.LWl RPM.LW1 PAGE: 87.970 3.459 79.270 2.354 ~18.917 1.895 END OF DATA **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 00~C01 DATE : 96/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 00~C01 DATE : 96/0~/31 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA DATE LOGGED: SOFTWARE: 7719.~ 9943.0 3-NOV-95 LIS Tape Verificati¢n Lis%lng Schlumberger Alaska Computing Center 31-JAN-1996 1S:10 PAGE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 5.5C 5.5 MEMORY 9943.0 7719.0 9943.0 88 34.2 60.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ARC5 RESISTIVITY $ ARC5-014 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 6. 750 5130.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 11 48 .¢ 9.5 10.0 2.880 2.430 79.0 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *****RUNS 1A 2***** DISTANCE TO BIT: GR=46.2'; RES=41.3' D&I TO BIT = 8S.3' RUN 1 DRILLED INTERVAL S140' TO 776S' RUN 2 DRILLED INTERVAL 776S' TO 9943' GR SPIKES ON LOG CAUSED BY INTERMITTENT FAILURE $ LIS FORMAT DATA LTS Tape Verii~icat;ion Lisf~ing Schlumberger Alaska Comput;|ng Cent~er 31-JAN-1996 15:10 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT ~ 000 00 0 3 1 1 4 68 0000000000 ROP LW2 F/HR 00 000 00 0 3 1 1 4 68 0000000000 FET LW2 HR 00 000 00 0 3 1 1 4 68 0000000000 GR LW2 GAPI 00 000 00 0 3 1 1 4 68 ~00000~0~0 RPXX LW2 OHMM 00 00~ 00 0 3 1 1 4 68 ~0000~0000 RPX LW2 OHMM 00 000 00 0 3 I 1 4 68 0000000000 RPS LW2 OHMM 00 ~00 00 0 3 ! I 4 68 000000~000 (' RPM LW2 OHMM 00 000 00 0 3 1 1 4 68 0000000000 ', RPD LW2 OHMM 00 000 0~ 0 3 1 I 4 68 0000000000 ** DATA ** DEPT. 7676.500 ROP.LW2 180.000 FET.LW2 0.000 GR.LW2 RPXX.LW2 55.742 RPX.LW2 101.569 RPS.LW2 1000.900 RPM.LW2 RPD.LW2 1000.000 DEPT. 8000.000 ROP.LW2 115.116 FET.LW2 0.494 GR.LW2 RPXX.LW2 1.773 RPX.LW2 1.808 RPS.LW2 1.847 RPM.LW2 RPD.LW2 1.828 DEPT. 9000.090 ROP.LW2 180.000 FET.LW2 ~.533 GR.LW2 RPXX.LW2 2.614 RPX.LW2 2.832 RPS.LW2 2.993 RPM.LW2 RPD.LW2 3.188 6.345 1009.000 285.277 1.856 217.756 3.091 LIS Tape Verificatien'Lis~ing Schlumberger Alaska Computing Center 31-JAN-1996 15:10 PAGE: DEPT. 9943.000 ROP.LW2 RPXX.LW2 2.329 RPX.LW2 RPD.LW2 2.457 49.500 FET.LW2 2.410 RPS.LW2 0.867 GR.LW2 2.445 RPM.LW2 92.737 2.447 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/31 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/01/31 ORIGIN : FLIC TAPE NAME : 95358 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2X-18, API #50-029-2260S-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/~1/31 ORIGIN : FLIC REEL NAME : 95358 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2X-18, AP1 ~50-029-22608-00