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Home My WebLink About179-112179-112 T38888 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 15:08:49 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 9, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-07 KUPARUK RIV UNIT 1D-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/09/2024 1D-07 50-029-20430-00-00 179-112-0 W SPT 5928 1791120 1500 1658 1660 1660 1663 241 400 398 395 OTHER P Adam Earl 2/25/2024 MIT IA tested as per Sundry 323-527 post repair 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-07 Inspection Date: Tubing OA Packer Depth 350 2500 2430 2430IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240225144818 BBL Pumped:1.8 BBL Returned:1.8 Tuesday, April 9, 2024 Page 1 of 1            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. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 179-112/ 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: BiSN Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8550'feet 8075'feet true vertical 6559' feet None feet Effective Depth measured 8075'feet 7711', 7845'feet true vertical 6215' feet 5928', 6033' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55/ L-80 7880' MD 6060' TVD Packers and SSSV (type, measured and true vertical depth) 7711' MD 7845' MD N/A 5928' TVD 6033' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 323-527 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Packer Packer: Baker FHL Packer SSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 7948-8025' 6114-6175' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 80' ~~~ INJECTOR ~~ ~ measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 179-112 50-029-20430-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-07 Plugs Junk measured Length Production Liner 1099' 7298' Casing 1108' 6496' 1124' 8422' 3035' 80'Conductor Surface Production Tie Back 16" 10-3/4" 80' 3137' 2639' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:15 am, Feb 21, 2024 Digitally signed by Jan Byrne DN: OU=Wells AK, O=ConocoPhillips, CN=Jan Byrne, E =jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.02.21 08:44:28-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DSR-2/21/24 RBDMS JSB 022924 DTTMSTART JOBTYP SUMMARYOPS 10/4/2023 ACQUIRE DATA SET 1.5" X .25" OV @ 7642' RKB, PERFORM MITT TO 2500 PSI (PASSED), READY FOR E-LINE CBL. 10/6/2023 REPAIR WELL RIH W/ 2.75" CBL & GR, TOOLS TAG AT 7695' RKB, ATTEMPT TO PASS MULTPLE TIMES AT MULTIPLE SPEEDS WITH OUT SUCCES, ON FINAL ATTEMPT TOOL BECAME TEMPORARILY DETAINED, PULLED HIGH TENSION TO COME FREE, LOG UP MAIN PASS FROM 7695' TO SURFACE. DISCUSS WITH TOWN, JOB IS READY FOR SL TO ATTEMPT RE-DRIFT. 10/7/2023 REPAIR WELL DRIFT TBG W/ BOTH 2.75" & 2" X 10', TAG UP IN TBG @ 7685' RKB. SAMPLE OF SCHMOO. BAILED W/ 2.5" x 10' BAILER DOWN TO AVA CATCHER @ 7751' RKB. READY FOR E-LINE. 10/13/2023 REPAIR WELL SPOT IN FOR PRE BiSN BEAD CBL, ISSUES WITH CRANE, MECHANICS CALLED OUT FROM PRUDHOE TO FIX, CRANE REPAIRED, PREP FOR JOB START NEXT DAY *** JOB CONTINUED NEXT DAY*** 10/14/2023 REPAIR WELL PERFORM CBL WITH GR FOR PRE BiSN TREATMENT, LOG UP FROM CATCHER AT 7751' TO SURFACE, WHILE LOGGING OOH TOOLSTRING PULLED TIGHT INTO GLM AT 7642.7', ATTEMPT TO WORK WIRE AND UNABLE TO MOVE UP/DOWN, PRESSURE UP TBG TO 2500 PSI AND BLEED OFF PRESSURE MULTIPLE TIMES, PULL TO MAX SAFE PULL, UNABLE TO WORK TOOLSTRING FREE (CENTRALIZER LIKELY STUCK IN MANDREL), DECISION MADE TO ACTIVATE RELEASE DEVICE AND POOH 50' X 1.69" FISH LEFT IN HOLE, WIA = 350LBS, TOP OF FISH @ 7615' WITH 1-3/8" FN LOOKING UP READY FOR SLICKLINE FISHING OPERATION 10/15/2023 REPAIR WELL PULLED ELINE FISH @ 7675' SLM. JOB COMPLETE. 10/25/2023 REPAIR WELL DEPLOY 750 LBS / 7.70' OF BiSN BEADS IN THE 3.5" X 7" ANNULUS. READY FOR FOR ELINE. 10/28/2023 REPAIR WELL LOG GR TO FIND TOP OF BEADS FROM 7720' TO 7300' RKB, CORRELATE TO TUBING TALLY DATED 12/20/2008, CONFER WITH TOWN AND AGREE ON TOP OF BEADS AT ~7700' RKB, POOH, LD TOOLS, PU 2.625" PRT TOOL, RIH, UNABLE TO PASS 7650' CCL (7673.5' BOTTOM OF TOOL), ATTEMPT MULTIPLE TIMES AT VARIOUS RUNNING SPEEDS, NO GOOD, POOH. READY FOR PLAN FORWARD. 10/30/2023 REPAIR WELL DRIFT TBG W/ 2.80" GUAGE RING, SD @ 7704' SLM. DRIFT W/ 2.72" FLUTED CENTRALIZER, SD @ 7699' SLM. BAIL SCHMOO @ 7694' SLM WITH 2.5" DD BAILER, JOB IN PROGRESS. 10/31/2023 REPAIR WELL BAILED SCHMOO W/ 10'X2.5" BAILER FROM 7678' RKB TO 7738' RKB, DRIFT TBG TO 7738' RKB WITH 2.80" GUAGE RING. DRIFT TBG W/ 2.625" DUMMY PRT TOOL TO 7740' RKB (NO ANOMALIES OR WEIGHT SWINGS), READY FOR E-LINE 11/2/2023 REPAIR WELL RIH W/ 2.625" PRT (THERAMITE HEATER) W/ CCL, TAGGED HIGH @ CCL DEPTH 7665' RKB, BOTTOM OF TOOLS 7688' RKB, UNABLE TO GET TOOLS TO FIRING DEPTH, READY FOR SLICK LINE. 11/4/2023 ACQUIRE DATA BAILED SCHMOO, PULLED AVA CATCHER 7713' SLM. BAILED IN ATTEMPT TO PULL 2.81'' CA2 PLUG 7754' RKB. IN PROGRESS 11/5/2023 ACQUIRE DATA BAILED 16' OF INJECTION SCHMOO STARTING @ 7710' SLM, IN PROGRESS 11/12/2023 ACQUIRE DATA RECOVERED SMALL AMOUT OF SHMOO @ 7754' RKB. PULLED EQ PRONG & 2.81'' CA-2 PLUG BODY @ 7754' RKB. LDFN DUE TO WINDS IN EXCESS OF 35 MPH. IN PROGRESS 11/13/2023 ACQUIRE DATA BRUSH & FLUSH TBG DOWN TO 7900' RKB. READY FOR E-LINE 11/13/2023 REPAIR WELL LOAD WELL FOR E LINE PUMPED 70 BBLS OF SEAWATER, FOLLOWED BY 2 BBL METHANOL SPACER, FOLLOWED BY 25 BBLS DSL FOR FREEZE PROTECT JOB COMPLETE 1D-07 BiSN Repair Summary of Operations 11/14/2023 ACQUIRE DATA RIH W/ BiSN HEATER TOOL TO MELT BEADS. PLACE HEATER OVER INTERVAL: 7688' - 7708' (BEAD TOP ~7700') AND ACTIVATE. WAIT 30 MINUTES AND POOH. JOB COMPLETE, READY FOR SL 11/16/2023 ACQUIRE DATA SET CATCHER @ 7878' RKB, PULL OV FROM 7642' RKB AND REPLACE W/ DMY, CONDUCT PASSING MITIA TO 3000#, PULL CATCHER FROM 7878' RKB... READY FOR DHD 11/19/2023 ACQUIRE DATA (AC-EVAL) IA-DDT (PASSED) 11/28/2023 ACQUIRE DATA (AC EVAL) BLEED IA FOR BUR (IN PROGRESS) 12/22/2023 ACQUIRE DATA PULLED 1-1/2" DMY VLV FROM 7642' RKB, REPLACED W/ 1-1/2" OV ( 1/4" PORT ). WELL READY FOR E-LINE. 12/23/2023 ACQUIRE DATA LOG GR/CCL OVER INTERVAL 7790' - 7320' FOR PRE BISN JOB, CORRELATE TO TUBING TALLY DATED 21-DEC-2008, JOB COMPLETE (READY FOR NEXT STEPS PROCEDURE). SWAP TO 0.39" LINE & REHEAD. 1/18/2024 ACQUIRE DATA DEPLOY 750 LBS /340 KG OF BISN BEADS IN THE 7" ANNULUS. READY FOR FOR ELINE. 1/19/2024 ACQUIRE DATA BULLHEAD FLUIDS DWN TBG PUMPED 70 BBLS SWTR DWN TBG PUMPED 25 BBLS DSL DWN TBG FOR FREEZE PROTECT JOB COMPLETE 1/22/2024 ACQUIRE DATA PRESSURE TEST PCE TO 200#LP-3000#HP RIH W/ 1-7/16" CHD (1" FN), 2X-1-11/16" WEIGHT, 1-11/16" GR/CCL (OAL=21', MAX OD=1- 11/16", OAW=150#) FIND BISN BEADS ABOVE PACKER FROM 7685'-7699' (ACCORDING TO GR OVERLAY W/ SLB LOG DATED 23-DEC-2023) SRT CALLED FOR LEAK OUT OF TOP OF GREASE HEAD JOB CONTINUED 23-JAN-2024 1/23/2024 ACQUIRE DATA RIH W/ 1-7/16" CHD (1" FN), 1-11/16" SWIVEL, 2" CCL, BISN HEATER (OAL = 25', MAX OD = 2.625", OAW = 225 LBS), CCL TO EOT = 23.8', EOT STOP DEPTH = 7699' RKB, CCL STOP DEPTH = 7675.2' RKB, LARGE OVERPULLS SEEN WHILE POOH, TOOL FOUND BENT AT SURFACE, GOOD INDICATION OF HEATER WORKING, JOB IS READY FOR GR LOG OVER MELTED BiSN BEADS AT LATER DATE. 1/29/2024 ACQUIRE DATA RIH W/ GAMMA/CCL & LOG UP FROM 7838' RKB TO 7523' RKB. REPLACED OV @ 7642' RKB W/ DV. READY FOR MITIA. 1/29/2024 REPAIR WELL MIT-IA TO 3000 PSI **PASSED** SEE LOG FOR DETAILS. READY FOR DHD. 1/31/2024 ACQUIRE DATA (AC EVAL) DDT IA TO 0 PSI 1 HOUR (PASS) 2/15/2024 ACQUIRE DATA (AC EVAL) BLEED IA AND OA FOR BUR IN PROGRESS. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,011.0 1D-07 3/24/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced OV w/ DMY 1D-07 1/29/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Deploy 750 lbs / 7.70' of BiSN beads down 3.5" x 7" IA claytg NOTE: WORKOVER TO PULL/REPLACE CUT TBG TO CHECK/PULL & REPLACE 7" CSG TOP 12/21/2008 osborl 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 28.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 25.0 3,136.7 2,639.4 45.50 K-55 BTC PRODUCTION TIE- BACK 7 6.28 25.1 1,124.0 1,107.6 26.40 L-80 BTCM PRODUCTION Post WO 7 6.28 1,124.0 8,422.1 6,495.7 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 7,707.8 Set Depth … 5,925.3 String Max No… 3 1/2 Tubing Description TUBING 2008 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 22.6 22.6 0.06 HANGER 7.062 MCEVOY GEN 4 TUBING HANGER 3.030 486.7 486.7 1.60 NIPPLE 4.520 DS NIPPLE w/ 2.875" PROFILE Camco 2.875 7,642.7 5,874.7 39.00 INJECTION 6.018 Camco MMM 2.992 7,694.9 5,915.4 39.00 SEAL ASSY 4.500 GBH-22 LOCATOR SEAL ASSY Baker 2.990 Top (ftKB) 7,697.3 Set Depth … 7,797.7 Set Depth … 5,995.5 String Max No… 3 1/2 Tubing Description TUBING 1992 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 7,697.3 5,917.2 39.00 PBR 5.870 BAKER 80-40 PBR Baker 4.000 7,710.7 5,927.6 38.95 PACKER 5.980 BAKER FHL PACKER Baker 2.930 7,754.1 5,961.4 38.73 NIPPLE 4.500 DS NIPPLE w/ 2.812" Profile Camco 2.812 7,790.8 5,990.1 38.55 OVERSHOT 6.000 POOR BOY OVERSHOT Baker 3.970 Top (ftKB) 7,788.0 Set Depth … 7,880.0 Set Depth … 6,060.1 String Max No… 3 1/2 Tubing Description TUBING 1980 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC 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) 7,838.0 6,027.1 38.31 SBR 4.000 BAKER ELA-1 SBR 2.813 7,845.0 6,032.6 38.28 PACKER 6.156 BAKER FHL PACKER 2.891 7,878.0 6,058.5 38.11 NIP 4.540 CAMCO D NIPPLE NO GO 2.750 7,879.0 6,059.3 38.11 TTL 4.570 Use TT @ 7866' for Correlations & Tags. 3.015 7,880.0 6,060.1 38.10 SOS 3.500 Baker 2.992 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) 7,685.0 5,907.6 39.00 OTHER BiSN BEADS FROM 7685' TO 7699' RKB BiSN 1/22/2024 3.500 7,704.0 5,922.4 38.98 OTHER Melted BiSN beads 7704- 7707' BiSN 11/14/2023 3.500 8,075.0 6,215.2 36.63 PLUG CMT PLUG: 5 bbl Class 'G' Cement 6/16/1997 0.000 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) 7,642.7 5,874.7 39.00 1 INJ DMY RK 1 1/2 0.0 1/29/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,948.0 8,025.0 6,113.8 6,175.1 C-1, C-2, C-3, C- 4, 1D-07 6/16/1997 4.0 IPERF Zero deg. Phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,174.0 8,197.0 6,294.9 6,313.5 Cement Used as a cement plug 1D-07, 2/19/2024 5:06:44 PM Vertical schematic (actual) PRODUCTION Post WO; 1,124.0-8,422.1 Cement; 8,174.0 ftKB PLUG; 8,075.0 IPERF; 7,948.0-8,025.0 PACKER; 7,845.0 PACKER; 7,710.7 OTHER; 7,704.0 OTHER; 7,685.0 INJECTION; 7,642.7 SURFACE; 25.0-3,136.7 PRODUCTION TIE-BACK; 25.1- 1,124.0 CONDUCTOR; 28.0-80.0 KUP INJ KB-Grd (ft) 38.01 RR Date 10/30/198 0 Other Elev… 1D-07 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292043000 Wellbore Status INJ Max Angle & MD Incl (°) 48.50 MD (ftKB) 4,500.00 WELLNAME WELLBORE1D-07 Annotation Last WO: End Date 12/21/2008 H2S (ppm) DateComment SSSV: NIPPLE 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 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 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 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-01-29_23012_KRU_1D-07_GammaRay_CCL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23012 KRU 1D-07 50-029-20430-00 Gamma Ray / CCL 29-Jan-24 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: 179-112 T38459 1/31/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.31 09:58:11 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: BiSN packer repair 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: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8550 7754 5961 7754 Casing Collapse Structural Conductor Surface Production Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email: Contact Phone: 907-265-6471 Authorized Title: Well Integrity Specialist 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 10/15/2023 3.5 2EA Baker FHL packer No SSSV 8422 Perforation Depth MD (ft): 1127 7948 - 8025 7295 6114 - 6175 64967 16 10.75 80 71124 3035 80 2638 1107 80 3136 L-80 TVD Burst 7708 MD P.O. Box 100360, Anchroage, Alaska 99510 50-029-20430-00-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: Tubing MD (ft): 7710' MD/ 5928' TVD. 7845' MD/ 6033' TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 179-112 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: KRU 1D-07 jan.byrne@conocophillips.com 6600 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? 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. m n P s 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.09.22 10:30:42-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne By Grace Christianson at 1:38 pm, Sep 22, 2023 323-527 X VTL 10/04/2023 SFD 9/25/2023 DSR-9/25/23 10-404X *&:JLC 10/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 13:25:11 -08'00'10/04/23 RBDMS JSB 100523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 22, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1D-07 (PTD 179-112) to install a BiSN plug for packer repair. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Proposal Summary for 1D-07 BiSN Packer Repair History: 1D-07 has been diagnosed as having a one-way packer leak from the Baker FHL Packer at 7711’ causing the IA pressure to increase while on injecƟon. ObjecƟve: Install BiSN beads into IA and melt into a solid plug to repair the packer leak. Proposal steps: 1. Run baseline CBL survey. 2. Set up well bore for bismuth bead applicaƟon. 3. Pump ~10’ of bismuth beads down the IA onto the packer. 4. Run post bead CBL to determine bead depth. 5. Run heater to melt beads into solid plug. 6. Run post melt CBL to verify bismuth plug top at ~7707’. 7. Replace OV with DV. 8. Perform MITIA and IA-DDT. 9. BOI and perform SW MITIA. 10. 30-day monitor for long term IA-DDT. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,011.0 1D-07 3/24/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug 1D-07 5/11/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/29/2010 ninam NOTE: WORKOVER TO PULL/REPLACE CUT TBG TO CHECK/PULL & REPLACE 7" CSG TOP 12/21/2008 osborl 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 28.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 25.0 3,136.7 2,639.4 45.50 K-55 BTC PRODUCTION TIE- BACK 7 6.28 25.1 1,124.0 1,107.6 26.40 L-80 BTCM PRODUCTION Post WO 7 6.28 1,124.0 8,422.1 6,495.7 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.6 Set Depth … 7,707.8 Set Depth … 5,925.3 String Ma… 3 1/2 Tubing Description TUBING 2008 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 22.6 22.6 0.06 HANGER 7.062 MCEVOY GEN 4 TUBING HANGER 3.030 486.7 486.7 1.60 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" PROFILE 2.875 7,694.9 5,915.4 39.00 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.990 Top (ftKB) 7,697.3 Set Depth … 7,797.7 Set Depth … 5,995.5 String Ma… 3 1/2 Tubing Description TUBING 1992 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 7,697.3 5,917.2 39.00 PBR 5.870 BAKER 80-40 PBR 4.000 7,710.7 5,927.6 38.95 PACKER 5.980 BAKER FHL PACKER 2.930 7,754.1 5,961.4 38.73 NIPPLE 4.500 CAMCO DS NIPPLE w/ 2.812" Profile 2.812 7,790.8 5,990.1 38.55 OVERSHOT 6.000 BAKER POOR BOY OVERSHOT 3.970 Top (ftKB) 7,788.0 Set Depth … 7,880.0 Set Depth … 6,060.1 String Ma… 3 1/2 Tubing Description TUBING 1980 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC 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) 7,838.0 6,027.1 38.31 SBR 4.000 BAKER ELA-1 SBR 2.813 7,845.0 6,032.6 38.28 PACKER 6.156 BAKER FHL PACKER 2.891 7,878.0 6,058.5 38.11 NIP 4.540 CAMCO D NIPPLE NO GO 2.750 7,879.0 6,059.3 38.11 TTL 4.570 Use TT @ 7866' for Correlations & Tags. 3.015 7,880.0 6,060.1 38.10 SOS 3.500 Baker 2.992 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) 7,754.0 5,961.3 38.73 TUBING PLUG 2.81" CA2 plug 5/11/2023 0.000 8,075.0 6,215.2 36.63 PLUG CMT PLUG: 5 bbl Class 'G' Cement 6/16/1997 0.000 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) 7,642.7 5,874.7 39.00 1 GAS LIFT DMY RK 1 1/2 0.0 12/31/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,948.0 8,025.0 6,113.8 6,175.1 C-1, C-2, C-3, C- 4, 1D-07 6/16/1997 4.0 IPERF Zero deg. Phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,174.0 8,197.0 6,294.9 6,313.5 Cement Used as a cement plug 1D-07, 5/12/2023 7:45:27 AM Vertical schematic (actual) PRODUCTION Post WO; 1,124.0-8,422.1 Cement; 8,174.0 ftKB PLUG; 8,075.0 IPERF; 7,948.0-8,025.0 PACKER; 7,845.0 TUBING PLUG; 7,754.0 PACKER; 7,710.7 INJECTION; 7,642.7 SURFACE; 25.0-3,136.7 PRODUCTION TIE-BACK; 25.1- 1,124.0 CONDUCTOR; 28.0-80.0 KUP INJ KB-Grd (ft) 38.01 RR Date 10/30/198 0 Other Elev… 1D-07 ... TD Act Btm (ftKB) 8,550.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292043000 Wellbore Status INJ Max Angle & MD Incl (°) 48.50 MD (ftKB) 4,500.00 WELLNAME WELLBORE1D-07 Annotation Last WO: End Date 12/21/2008 H2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-07 (PTD 179-112) Report of suspect IA pressure increase Date:Wednesday, April 26, 2023 1:25:07 PM Attachments:AnnComm Surveillance TIO for 1D-07.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, April 26, 2023 11:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-07 (PTD 179-112) Report of suspect IA pressure increase Chris, KRU 1D-07 (PTD 179-112) is exhibiting suspect IA pressure increase. The well has been bleed multiple times and the IA repressurizes to near tubing pressure. The well will be shut in and freeze protected as soon as possible. The plan is to secure the well and perform initial diagnostics after which a repair plan will be developed. Any required paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 1D-07 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1D-07 2023-03-31 7.0 28 21.0 OA 1D-07 2023-04-09 1750.0 720 -1030.0 IA 1D-07 2023-04-09 750.0 219 -531.0 OA 1D-07 2023-04-17 26.0 341 315.0 IA 1D-07 2023-04-17 1.0 106 105.0 OA 1D-07 2023-04-24 842.0 378 -464.0 IA 1D-07 2023-04-25 824.0 200 -624.0 IA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.950 Top (ftKB) 25.0 Set Depth (ftKB) 3,136.7 Set Depth (TVD) … 2,639.4 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.276 Top (ftKB) 25.1 Set Depth (ftKB) 1,124.0 Set Depth (TVD) … 1,107.6 Wt/Len (l… 26.40 Grade L-80 Top Thread BTCM Casing Description PRODUCTION Post WO OD (in) 7 ID (in) 6.276 Top (ftKB) 1,124.0 Set Depth (ftKB) 8,422.1 Set Depth (TVD) … 6,495.7 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING 2008 String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 22.6 Set Depth (ft… 7,707.8 Set Depth (TVD) (… 5,925.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.6 22.6 0.06 HANGER MCEVOY GEN 4 TUBING HANGER 3.030 486.7 486.7 1.60 NIPPLE CAMCO DS NIPPLE w/ 2.875" PROFILE 2.875 7,694.9 5,915.4 39.00 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.990 Tubing Description TUBING 1992 String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 7,697.3 Set Depth (ft… 7,797.7 Set Depth (TVD) (… 5,995.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,697.3 5,917.2 39.00 PBR BAKER 80-40 PBR 4.000 7,710.7 5,927.6 38.95 PACKER BAKER FHL PACKER 2.930 7,754.1 5,961.4 38.73 NIPPLE CAMCO DS NIPPLE w/ 2.812" Profile 2.812 7,790.8 5,990.1 38.55 OVERSHOT BAKER POOR BOY OVERSHOT 3.970 Tubing Description TUBING 1980 String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 7,788.0 Set Depth (ft… 7,880.0 Set Depth (TVD) (… 6,060.1 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,838.0 6,027.1 38.31 SBR BAKER ELA-1 SBR 2.813 7,845.0 6,032.6 38.28 PACKER BAKER FHL PACKER 2.891 7,878.0 6,058.5 38.11 NIP CAMCO D NIPPLE NO GO 2.750 7,879.0 6,059.3 38.11 TTL Use TT @ 7866' for Correlations & Tags.3.015 7,880.0 6,060.1 38.10 SOS Baker 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,075.0 6,215.2 36.63 PLUG CMT PLUG: 5 bbl Class 'G' Cement 6/16/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,948.0 8,025.0 6,113.8 6,175.1 C-1, C-2, C-3, C-4, 1D-07 6/16/1997 4.0 IPERF Zero deg. Phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 8,174.0 8,197.0 6,294.9 6,313.5 Cement Squeeze 6/16/1997 Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,642.7 5,874.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/31/2008 Notes: General & Safety End Date Annotation 12/21/2008 NOTE: WORKOVER TO PULL/REPLACE CUT TBG TO CHECK/PULL & REPLACE 7" CSG TOP 11/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE1D-07, 3/25/2016 11:30:27 AM Vertical schematic (actual) PRODUCTION Post W O; 1,124.0-8,422.1 PLUG; 8,075.0 IPERF; 7,948.0-8,025.0 TTL; 7,879.0 NIP; 7,878.0 PACKER; 7,845.0 SBR; 7,838.0 OVERSHOT; 7,790.8 NIPPLE; 7,754.1 PACKER; 7,710.7 PBR; 7,697.3 SEAL ASSY; 7,694.9 INJECTION; 7,642.7 SURFACE; 25.0-3,136.7 PRODUCTION TIE-BACK; 25.1- 1,124.0 NIPPLE; 486.7 CONDUCTOR; 28.0-80.0 HANGER; 22.6 Annotation Last Tag: SLM Depth (ftKB) 8,011.0 End Date 3/24/2016 Annotation Rev Reason: TAG Last Mod By pproven End Date 3/25/2016 KUP INJ KB-Grd (ft) 38.01 Rig Release Date 10/30/1980 Annotation Last WO: End Date 12/21/2008 1D-07 H2S (ppm) Date ... TD Act Btm (ftKB) 8,550.0 Well Attributes Wellbore API/UWI 500292043000 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 48.50 MD (ftKB) 4,500.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-07 KUPARUK RIV UNIT 1D-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-07 50-029-20430-00-00 179-112-0 W SPT 5928 1791120 1500 820 830 830 830 5 5 5 5 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-07 Inspection Date: Tubing OA Packer Depth 170 2000 1970 1900IA 830 5 45 Min 1890 60 Min Rel Insp Num: Insp Num:mitGDC220709073921 BBL Pumped:1.5 BBL Returned:1.5 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:23:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 15, 2019 TO: Jim Regg ZAC SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1SIL? (� CONOCOPHILLIPS ALASKA, MC. ID -07 FROM: Guy Cook KUPARUK RIV UNIT 1D-07 Petroleum Inspector Sre: Inspector Reviewed By: P.1. Supry :r99— 99— NON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT ID -07 Insp Num: mitGDC190109065704 Rel Insp Num: API Well Number 50-029-20430-00-00 Inspector Name: Guy Cook Permit Number: 179-112-0 Inspection Date: 1/8/2019 Packer Depth Pretest Initial 15 Min 36 Min 45 Min 60 Min Well ID -o7 ' Type Inj w TVD, 5928 - Tubing 1330 13:1 - 1:30 uzv PTD 1791120 Type Test SPT Test psi 1500 - IA 130 2010 1930 1900 BBL Pumped Le ' BBL Returned: 1.6 OA s 1o .� wr us - Interval 4YRTST P/F P Notes: Testing performed with Little Red Services pump truck and analog gauges from KRU DHD. Tuesday, January 15, 2019 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, September 1, 2018 11:39 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: KRU WAG 1D-07 (PTD 179-112) Update 9-1-18 Attachments: 1 D-07 90 day TIO 8-31-18.1PG; MIT KRU 1 D-07 non witnessed 06-26-18.xlsx Chris, Last year, 1D-07 was reported for a failing MITOA. (see attached note below). The failure was due to a leak through the wellhead which was repaired, enabling a follow-up passing MITOA to be obtained. The OA has been demonstrating a very slow fall off in pressure recently (losing—200psi per month). The well continues to pass an MITOA, the most recent one being performed on June 26, 2018. At this point, it is believed that the shoe is compromised and allows for a slow pressure fall off. CPAI intends to continue to operate 1D-07 as a 'normal' well to be governed under AIO 2C. Please let us know if you disagree with the path forward. Attached is a 90 day TIO plot and recent MITOA data. Kelly Lyons/ Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED QFP 0 5 2018 F m: NSKWell Integrity Supv CPF1 and 2 Sent. onday, November 20, 2017 6:06 AM To: Walla Chris D (DOA) <chris.waIlace @alaska.gov> Cc: Senden, R. <R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophiII om> Subject: KRU WAG 1D-07 (P 79-112) Update Chris, KRU WAG injector 1D-07 (PTD 179-112) was reported ber 23`d, 2017 for a failing MIT -OA. Diagnostics indicated the inner casing pack off (IC -PO) was suspect of being the comm u tion source and after properly torqueing the inner casing lock down pins a passing IC -PO test was achieved. Following assing IC -PO test a passing MIT -OA was achieved. The well is reaching the end of the approved 30 day monitor p6rkO and has not exhibited any anomalous signs of annular communication.. At this time CPA is returning the well to 'normaYstatus. If any signs of annular communication are exhibited in the future the well will be reported at that time. Atta dare a 90 day TIO trend and 10-426 of the referenced MIT -OA. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Kelly Lyons 1 D - o 7 Regg, James B (DOA) From: NSK Well Integrity Supv CPH and 2 <n1617@conocophillips.com> Rl_w Sent: Sunday, July 15, 2018 1:18 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk MITs Attachments: MIT KRU 1 D Pad Non -Injecting 7-13-18.xlsx; MIT KRU 1 D PAD 7-13-18.xlsx; MIT KRU 2K-32 07-13-18.xlsx Attached are the MIT forms for the tests performed in Kuparuk on 7-13-18. Please let me know if there are any questions. Kelly Lyons/ Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED AUG 0 ;6 2%18 1 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg0,alaska.gov: AOGCC.lnspectors(Zljalaska.gov: phoebe. brooksCcDalaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk/ KR / 1 D Pad DATE: 07/13/18 OPERATOR REP: VanCamp/Richwine AOGCC REP: Non -Witnessed chds.wallace(cDalaska. qov i Well 1D-06 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1790950 Type Inj N Tubing 225 225 225 Type Test P Packer TVD 6288 BBLPump 2.7 IA 110 1820 1700 Interval 4 Test psi 1572 BBL Return 0 OA 200 200 200 Result F Notes: test #1 No bleed back volume. Re -Pressured IA for second test. Well 1D-06 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1790950 Type Inj N Tubing 225 225 225 225 Type Test P Packer TVD 6288 BBLPump 0.2 IA 1700 1820 1790 1780 Interval 4 Test psi 1572 BBL Return 2.7 OA 1 200 200 200 200 Result P Notes: test #2 Re -pressurized IA for second test. Well 1D-107 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001770 Type Inj N Tubing 2250 2250 1875 Type Test P Packer TVD 3675 BBLPump 3.4 IA 15 2300 180 Interyal 4 Test psi 1500 BBL Return0.9 OA Result F Notes: Single casing well. Established LLR of 1.7 gallons per min at 2300 psi Well 1D-07 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1791120 Type Inj N Tubing 550 550. 550 550 Type Test P Packer TVD 5928 BBLPump 1.7 IA 25 1815. 1730 1720 - Interval 4 Test psi 1500 BBL Return 1.7 ' OA 350 - 505 - 513 - 513 LResult P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well j Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj I Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G = Gas S = Slurry I = Industrial Wastewater N = Not Injecting TYPE TEST Codes INTERVAL Codes P = Pressure Test I = Initial Test 0 = Other (describe in Notes) 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT KRU 1D Pad Non -Injecting 7-13-18 Result Codes P = Pass F = Fail I = Inconclusive Kietk (6 -d7 i- guzo Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Monday,January 22, 2018 2:29 PM Fet, ,/,4,g To: Regg,James B (DOA) "� Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Lewis, Brian M; McKee, Garrett L; NSK Prod Engr Specialist;Targac, Gary; CPF1 DS Operators; Carlisle, William B; NSK Optimization Engr Subject: RE: Defeated LPP/SSV on CPAI well 1 D-07 & 1 D-09 Jim, The low pressure pilot(LPP) on wells 1D-07 (PTD#179-112) & 1D-09 (PTD#198-065 was returned to service and removed from the safety defeat log on 1/22/2018, as wellhead pressures have stabilized above the LPP set point of 700 psig.-1D-07 is currently injection at 4000 BWPD with a stabilized wellhead pressure at 950 psig. 1 D-09 is currently injection at 5000 BWPD with a stabilized wellhead pressure at 1040 psig. The LPP on both wells had been defeated since 1/22/2018. This notification is in accordance with "Administrative Approval No. CO No. 432D." Please let me know if you have any questions. Kind Regards, Courtney Gallo/Will Carlisle CPF-1 Production Engineer N1269@conocophillips.com Office: (907) 659-7493 Cell: (720) 318-5762 scowl From: CPF1 Prod Engr Sent:Thursday,January 18, 2018 4:10 PM To: 'Regg,James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>; Lewis, Brian M <Brian.M.Lewis@conocophillips.com>; McKee, Garrett L <Garrett.L.McKee@conocophillips.com>; NSK Prod Engr Specialist<n1139@conocophillips.com>; Targac, Gary <Gary.Targac@conocophillips.com>; 'CPF1 DS Operators' <n1275@conocophillips.com>; Carlisle, William B <Will.B.Carlisle@conocophillips.com> Subject: Defeated LPP/SSV on CPAI well 1D-07 & 1D-09 Jim, The low pressure pilot(LPP) on well 1D-07 (PTD#179-112) & 1D-09 (PTD#198-065) was defeated today, 1/18/18, after the C-WIX was swapped from Seawater Injection to Produced Water Injection service due to a mechanical failure on one of our larger turbine driven Produced Water injection pumps. This has reduced the injection capacity of our Seawater system and caused a decrease in our injection header pressure. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." 1D-07 is currently injecting 1200 BWPD ata wellhead injection pressure of 500 psig . 1D-09 is currently injecting 2500 BWPD at a wellhead injection pressure of 630 psig . The AOGCC will be notified when the injection pressure has increased to above 700 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO No. 432D." 1 • • 1Lc( 16-o7 PT's Ili/ice Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Thursday,January 18, 2018 4:10 PM To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Lewis, Brian M; McKee, Garrett L; NSK Prod Engr Specialist; Targac, Gary; CPF1 DS Operators; Carlisle, William B Subject: Defeated LPP/SSV on CPAI well 1 D-07 & 1 D-09 Jim, The low pressure pilot(LPP) on well 1D-07 (PTD#179-112) & 1D-09 (PTD#198-065) was defeated today, 1/18/18, after the C-WIX was swapped from Seawater Injection to Produced Water Injection service due to a mechanical failure on one of our larger turbine driven Produced Water injection pumps. This has reduced the injection capacity of our Seawater system and caused a decrease in our injection header pressure. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." 1D-07 is currently injecting 1200 BWPD at a wellhead injection pressure of 500 psig . 1 D-09 is currently injecting 2500 BWPD at a wellhead injection pressure of 630 psig . The AOGCC will be notified when the injection pressure has increased to above 700 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO No. 432D." Please let me know if you have any questions. Kind Regards, Courtney Gallo/Will Carlisle CPF-1 Production Engineer N1269( conocophillips.com Office: (907) 659-7493SCANNED i`jt Cell: (720) 318-5762 From: NSK West Sak Prod Engr Sent:Saturday, October 22, 2016 5:48 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael<Michael.Sullivan@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>;Targac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com>; Effiong, Michael<Michael.Effiong@conocophillips.com> Subject: Defeated LPP/SSV on CPAI well 11-102 Jim, 1 pilot(LPP) on well 1J-102 (PTD#206-110 206-111 206-112 was defeated today, 10/22/16, after the The low pressure ) Y well was returned to water injection service. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 470 BWPD at a wellhead injection pressure of 2 psig. The AOGCC will be notified when the injection pressure has increased to above 100 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com • 2 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, November 20, 2017 6:06 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU WAG 1 D-07 ETD 179-112) Update Attachments: Diagnostic MIT-OA KRU 1 D-07 10-29-17.xlsx; 1 D-07 90 day TIO trend 11-20-17.JPG Chris, KRU WAG injector 1D-07 (PTD 179-112)was reported October 23`d, 2017 for a failing MIT-OA. Diagnostics indicated the inner casing pack off(IC-PO)was suspect of being the communication source and after properly torqueing the inner casing lock down pins a passing IC-PO test was achieved. Following the passing IC-PO test a passing MIT-OA was achieved. The well is reaching the end of the approved 30 day monitor period and has not exhibited any anomalous signs of annular communication. At this time CPA is returning the well to'normal'status. If any signs of annular communication are exhibited in the future the well will be reported at that time. Attached are a 90 day TIO trend and 10-426 of the referenced MIT-OA. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 ;WELLS TEAM com Phalips • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, October 24, 2017 7:37 AM To: 'NSK DHD Field Supervisor' Cc: NSK Well Integrity Supv CPF1 and 2 Subject: RE: KRU WAG 1 D-07 (PTD# 179-112) Report of Failed MIT-OA Jan, Plan as below including up to 30 days water injection for diagnostics and monitoring is approved. Thanks and Regards, Chris Wallace,Sr.Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7t^Avenue,Anchorage,AK 99501,(907)793-1250(phone),(907)276- 7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK DHD Field Supervisor[mailto:NSKDHDFieldSupervisor@conocophillips.com] Sent: Monday,October 23,2017 6:14 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: FW: KRU WAG 1D-07 (PTD#179-112) Report of Failed MIT-OA SCANNED l'EF; 2 a ;40, From: NSK Well Integrity Supv CPF1 and 2 Sent: Monday,October 23, 2017 2:26 PM To: NSK DHD Field Supervisor<NSKDHDFieldSupervisor@conocophillips.com> Subject: KRU WAG 1D-07 (PTD#179-112) Report of Failed MIT-OA Chris, KRU WAG injector 1D-07 (PTD#179-112)failed an MIT-OA today subsequent Operations reporting that the OA pressure had fallen off after being charged. The well passed an MIT-IA and pack off tests proving the tubing and production casing as barriers. The plan is for DHD to perform a SCLD to determine leak location and evaluate reparability of the well. Once the diagnostics have been completed and a plan forward has been determined a follow up email and required paperwork will be submitted for corrective action and/or administrative approval. Attached is a wellbore schematic,TIO trend, and 10-426's. CPAI requests to leave the well online on water injection only while the diagnostic and planning stages take place (not to exceed 30 days). Please let us know if you approve of this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 1 • .- c a) ww,, lv .r w O o9Q W� W a,> N z _ .. a, co 0 O. L ,.' ? O W O r 0]Q O a v O L C rYQ 9 Z o z a0 w F' >•o o ° 40 v a ;u C w ra a),. ra T 0. Q 0 0r O us `r` r co a m co cc co CO O m u Nvr H M in ,_ I) .- O 0) N w -c "D >. > 1 N N M M N — c co al Q al Z o -0 E O >. > L N r7 a) (a O i 0 ❑ ❑ 0 ❑ 0 0 ❑ 0 0 fD al U LT L" J J J J J J J J J J = r- O 0 w w w w w w w w w w m H LL LL U. U. 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O N. a al3 l W lab NO N M M ) N O O a.+ !_ E a+` Ln a. oa Q p N U N In CM t .., C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 15 Min 30 Min 45 Min 60 Min DATE: Monday, August 04, 2014 TO: Jim Regg - (, _ t/L 4 SUBJECT: Mechanical Integrity Tests P.I. Supervisor ' l�� 7 Type Test sPT Test psi —1500 Ip 746 2810 2730 - 2720 CONOCOPHILLIPS ALASKA INC PAF P OA 9 9 1D-07 FROM: Jeff Jones KUPARUK RIV UNIT ID -07 Petroleum Inspector Src: Inspector SCANNES Reviewed By: P.I. Supry �2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT ID -07 API Well Number 50-029-20430-00-00 Permit Number: 179-112-0 Insp Num: mitJJ140715164226 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 7/13/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1D-07-_ ell I -- W 5928 2158 2145 Type In j TVD Tubing 2115 2112 TD --1791120 Type Test sPT Test psi —1500 Ip 746 2810 2730 - 2720 — Interva114YRTST PAF P OA 9 9 9 9. Notes: I well inspected, no exceptions noted. SCANNES Monday, August 04, 2014 Page 1 of 1 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 3, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: n ~_ '~ ~ i ~ ,~ ~~ ~ ; ~~~~ ~~ `~ ~1 L~ .: G~lission i~f~~:~~.~~~~e 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 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 August 1St & 2na 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. 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 Date 8/03/10 A A e n ~ i o n n ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ., _, Corrosion inhibitor Corrosion inhibitor/ sealant date ff bbls ft al 1A-26 50029221150000 1901660 SF n/a 12" n/a 2.6 8/1/2010 1A-27 50029221240000 1901800 SF n/a 27" n/a 4.3 8/1/2010 1 D-03 50029204080000 1790840 17" n/a 17" n/a 1 8/2/2010 1 D-06 50029204180000 1790960 16" n/a 16" n/a 1.7 8/2/2010 1D-07 50029204300000 1791120 17" n/a 17" n/a 4.3 8/2/2010 1L-05 50029211550000 1841230 17" n/a 17" n/a 3.4 8/1/2010 1L-21 50029220439000 1910060 17" n/a 17" n/a 4.3 8/1/2010 1L-24 50029221700000 1910660 32" n/a 32" n/a 7.5 8/1/2010 MEMORANDUM TO: Jim Regg ~ P.I. Supervisor ~~ ?(z'~~l ~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-07 KUPARUK RIV UNIT ID-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~2- Comm Well Name: KUPARUK RN UNIT 1D-07 API Well Number: 50-029-20430-00-00 Inspector Name: Bob Noble Insp Num: mitRCN10071815164 0 Permit Number: 179-112-0 Inspection Date: 7/16/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-o7 Type Inj. w TVD 5928 ~ j 324 2056 ' ~ 1964 1949 P.T.D 1791120 ~ TypeTest SPT Test psi 2056 ' OA 2 2 2 2 Interval4YRTST pn, P - Tubing 1267 1261 1263 1261 Notes: ~~~ fe~c~ -~Sa- i5c~v ps ~, °'~ a ~;;~ Thursday, July 22, 2010 Page 1 of 1 ~iu~~ • STATE OF ALASKA • M~~ ~ ~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSIO ~ ~~~ ~011ffi. Commisston REPORT OF SUNDRY WELL OPERA~I~ /tr-~h~,~„a 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q WIND to WAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ conversion ' Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 179-112 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20430-00 , 7. KB Elevation (tt): 9. Well Name and Number: RKB 101' ~ 1 D-07 8. Property Designation: 10. Field/Pool(s): ADL 25650 ' Kuparuk River Field /Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 8550' feet true vertical 6600' . feet Plugs (measured) 8075 Effective Depth measured 8076 feet Junk (measured) true vertical 6215 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" ao~ 80' SURFACE 3035' 10-3/4" 3136' 2638' ~~ - PRODUCTION L- 1124' 7" 1127 1107' PRODUCTION J- 7295' 7" 8422' 6496' ! ~J Perforation depth: Measured depth: 7948'- 8025' ' true vertical depth: 6114'- 6175' Tubing (size, grade, and measured depth) 3.5", L-80/J-55, 779 8/ 7879 MD. Packers t£ SSSV (type & measured depth) SSSV =Nipple Camco DS w/ 2.875" profile 487' Packers = (2) Baker FHL 7711' & 7845' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2757 532 1318 Subsequent to operation 5600 2671 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAGQ 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: 308-232 Contact B. Christensen/ D. Humphrey Printed Name Darrell Humphrey Title Production Engineering Specialist Signature ~ Phone: 659-7535 Date ` / , ` ~ ~ ~ 1 ~~~~ ` ~ s-~- raj Form 10-404 Revised 04/2004 ~ ~ J N L1 1 Submit iginal Only 1 D-07 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/09/09 Commenced WAG FOR Injection • STATE OF ALASKA • ~~ V t. ~ V ~ D ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ~ ~ 2009 REPORT OF SUNDRY WELL OPERATIONS 1. operations Pertormed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ as a } as h ~~ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extenson ~ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development ^ Exploratory ^ 179-112 / • 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20430-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1 D-07 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /Kuparuk Oil Pool • 11. Present Well Condition Summary: Total Depth measured 8550' feet true vertical 6600' feet Plugs (measured) 8075' Effective Depth measured 8076' feet Junk (measured) true vertical 6215' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 3035' 10-3/4" 3136' 2639' PRODUCTION 8321' 7" 8422' 6496' Perforation depth: Measured depth: 7948'-8025' true vertical depth: 6114'-6175' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7708' MD. ~~~ S wQr~C ~ ~~ ~e'~~ O.\~~` ~pC ~~~~~ ` Packers & SSSV (type & measured depth) Baker FHL pkr (2) 7711', 7845' ' ' `~ ~~~ ~ nipple 486.67 Camco DS 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 SI -- 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: 308-437 contact Brett Packer @ 265-6845 Printed Name Brett Packe=~~l/"L Signature "-~ Title Phone: 265-6845 Wells Engineer ~Z~~( 9 Date Pre red b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04!2006 ~ ~Z6~ ' ~ t-/ Submit Original my ~ ~,~/~9' " __, KUP ~ ~~ • 1 D-07 ~(~j ~O~t7~~~~~(p~ ,I Well Attributes _ Max Angle 8 MD TD - ~ Hdlbore APUUWI Freb Name ! ~ 500292043000 KUPARUK RIVER UNIT WdY Status P odhnl Type 1 d () I h1U (hN8) r tNJ LPWI rr48.50 4,500.00 Aat Birn (Ie(B( 8,550.0 Comment H2S (ppm) Dale Annotation End Date KB{irtl (R) Rig Release Dar SSSV: NIPPLE 0 ~ 7/1/2008 Last WO: 12/21/2008 38.07 10!30/1980 - - ~~~ I - ~ ~ ~~~ u. 4nnotation Depth (ftK6) End Date Annotation End Date iLastTag: 8,070.0 8!3/2006 Rev Reason: GLV C/O, PULL PLUG 1ItY1009 Casing Strings HANGER, 23 NIPPLE, Production Screw in, 61,124 SURFACE, 63,136 SEAL ASSY, 7,895 Packers, 7,711 ; ,?Y~i [ 3 f f 1 ~( r 7 l e a w ~" SACKER, 7,695 jy~ \1 IPERF, 7,998A, 625 PLUG, 8,675 Gazing Deccriplian Jlring V... SUUg ID ... Tap (la(B) ISCI Depth 11.•. Set Duplh (1l'D)... Stang YY 4.. 5l'nng ... ~lruig lop lluU CONDUCTOR 16 15.062 0.0 80.0 80.0 65.00 H-40 Casing Description String 0... String ID ... Top IRKB) Set Depth 0... Set Depth (TVD) ... String Wt... String ... SMng Top Thrtl SURFACE 103/4 9.794 0.0 3,136.0 2,638.4 45.50 K-55 Casing Deacripton String 0... String ID ... lop (flKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top ThM PRODUCTION 7 6.151 0.0 8,422.0 6,495.7 26.00 K-55 Casing Description String 0... String ID ... Top (fIKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd Prndumion Screw in 7 fi97fi 0.1 1.19d O ~ 1.107 6 26 40 L-80 67CM Tubing Strings f 1 ~ Lrrs .ription 1 n ~ ICr Top lltl Ll Sc~t L I tti (1 tier Ccpih (TJL~) t \'!t. titr nq S[r, u T p T~, rJ I IE III 1! ~ E.JE ~~,i,l Completion Details Tap Depth (Tw) Top Intl Top IRKS) IRKB) (°) Item Description Comment ID (in) 22.6 22.6 0.25 HANGER McEvov Gen 4 TBG Hander Noe: DP-1-D-S-3-NL 7 1/16 x 3 1/2 ~ 3.0~ 7,694.9 5,915.4 39.03 SEAL ASSY Seal assy w/ 2'spaceout 3.000 Tubing Description Strirg 0... Strtrrg ID ... Top (111(8) Set Depth If... Set Depth (ND)... Strirg Wt...Strtng ... String Top ThM TUBING 31/2 2.992 7.697.3 7.797.7 5.995.5 9.30 L-80 EUE 8b Completion Details Top (RI(B) op vryur (ND) IRKB) Top Intl (°) Item Description Comment ID (in) 7,697.3 5,917.2 39.01 PBR 80-00 Baker PBR 4.000 7,710.7 5,927.6 38.95 Packers 4762-7"26# FHL Packer 2.930 7,754.1 5,961.4 35.73 NIPPLE Cameo "DS" Nipple w/ 2.812" Profle 2.812 7,790.8 5,990.1 38.55 OVERSHOT Baker Poor boy Overshot 3.7501 Tubing Description Strtrg 0 TUBING Orioinal 31/2 ... String ID ... Top IftlcB) Set Depth (L_ Set Depth (TVD) ... String Wt... String ... String Top Thrd 2.992 7.788.0 7.880.0 6.060.1 9.20 J-55 BTC Completion Details Top (RNB) ,xy vvpu, (Tw) IRKB) Top Ind (°) Item Description Comment . ID (in) 7,838,0 6,027.4 38.62 SBR Baker'ELA-7' 2.813 7,845.0 6,032.8 38.55 PACKER Baker'FHL' 2.891 7,878.0 6,058.5 38.22 NIP Camco'D' Nipple NO GO 2.750 7,879.0 6,059.3 38.21 SOS Baker 2.992 7,879.0 6,059.3 38.21 TTL Use TT @ 7866' for Correlations & Tags. 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc. Tup Depth i (ND) Top inch - Top (RN,B) IRKB) (°) Descripton Comment Run Date ID Iin) ~ 8,075.0 6,215.2 36.63 PLUG CMT PLUG: 5 bbl Class'G' Cement X6116/1997 0.000 Perforations ToO IftKBI Btm IRKBI ~ Top (TVD) IRKB) Btm (ND) IRKB) Zone °Iwt Dens ~ Date lah~- ~ Type Comment Cement Squeezes Top Depth Bim DeyN i (ND) ~ (ND) ~, Top IRKB) ehn (ttKB) IRKB) i IRKB) ~ Description ~ Start Date Comment 8,174.0 8,197.0 6,2949 6,313.51Cement Squeeze l6/16/1997 Notes: General & Safety Cement, 8,174 PRODUCTION, 1,1248,422 TD, e,ss6 Mandrel Details fop Depth it iop ~. Pen (ND) Inc! OD Valve Latch Size 7R0 Runk Stn Too IRKBI IRKB) (°) Make Model On) Serv TYPe Type (in) (psi) I Run Date Comm... ':. DATE SUMMARY 1 D-07 Well Events Summary 12/15/08 RAN USIT CEMENT AND CO~SION EVALUATION LOG AND PDS CALIPER. RESULTS: TOP O UALITY CEMENT AT 2420'. CASING I GOOD CONDITION. SUSPECTED CASING LEAK AT CASING COLLAR AT 186' REFERENCED TO NORDIC 3 RKB. _ 12/1,8/08 RAN PDS CALIPER FROM 1200' SLM TO SURFACE. '""GOOD DATA***. JOB COMPLETE. 12/27/08 REPLACED SOV W/ DV @ 7643' RKB. BAILED MUD /DEBRIS @ 7788' SLM. IN PROGRESS. 12/28/08 MITT & MITIA TO 2500 BOTH PASSED. BAILED ON IBP FROM 7788' SLM TO 7830' SLM. IN PROGRESS. 12/29/08 BAILED ABOVE IBP @ 7832' SLM. RECOVERED METAL DEBRIS 8~ FILL, IN PROGRESS. 12/30/08 ATTEMPT TO RETRIEVE DEBRIS FROM 7832' SLM. IN PROGRESS. 12/31/08 PULLED 2 1/8" IBP (a~ 8040' SLM. 2 ELEMENTS STILL IN HOLE AND EST. 3, 1/2" CENTRALIZER SPRINGS MISSING. JOB COMPLETE. ~~ ~ona-cc~~illips Time Log & Summary WelNfew Web flepoi7ing Report Well Name: 1 D-07 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/14/2008 3:00:00 PM Rig Release: 12/21/2008 3:00:00 AM Time Logs D to From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/14/2008 z4 hr Summary Moved rig from 3A Pad to 1 D Pad, spotted rig and bermed up, killed well with 9.6 ppg brine, ND tree, started NU BOP. 03:00 05:30 2.50 COMPZ MOVE MOB P Moved rig off well. Hang adaptor flange in cellar. Secured 10 jts.drill pipe in pipe shed. Move rig #rom 3A-06 to CPF-3. 05:30 07:00 1.50 COMPZ MOVE MOB P Standby for Field crew changes. 07:00 15:00 8.00 COMPZ MOVE MOB P Continue to move rig from CPF-3 to 1 D pad. Arrive on location @ 1:00 m. 15:00 18:00 3.00 COMPZ MOVE MOB P Spot rig over well, set containment and set rig down. Berm up and spot tanks. Accepted Nordic 3 Rig @ 1500 hrs 12/14/2008. 18:00 19:00 1.00 COMPZ RPCOM RURD P Load pits with 9.6 ppg brine. RU hardline to kill tank. Pull BPV. Test hardline to kill tank to 3500 si. 19:00 20:30 1.50 COMPZ RPCOM CIRC P Pumped a total of 286 bbls 9.5+ ppg brine taking returns to kill tank at 4 bpm - 360 psi, shut down and shut in to monitor ressure, well dead. 20:30 21:30 1.00 COMPZ RPCOM RURD P Blow down hardline and rig down circ lines install BPV. 21:30 23:00 1.50 COMPZ RPCOM NUND P ND tree and hang off in cellar for re-use, installed test dart in han er. 23:00 00:00 1.00 COMPZ RPCOM NUND P Start NU 13 5/8" BOP. 12/15/2008 NU and test BOP, decomplete well, RU SWS and perform USIT and PDS logs from 7,690' to surface, PU RIH with RBP and test acker to test 7" cs for leaks at 1,000' increments. 00:00 02:00 2.00 COMPZ RPCOM NUND P Cont NU 13 5/8" BOP's. 02:00 05:00 3.00 COMPZ WELCTt BOPE P Pressure tested all BOPS at 250 psi low, 3,500 psi high. Witness of BOP test was waived by AOGCC Rep Chuck Scheve on 12/15/2008 at 02:00 hrs. 05:00 06:00 1.00 COMPZ RPCOM RURD P RD test equipment, pull test dart, MU landing joint and circ hose, BOLD's, pull hanger to rig floor, Up wt. 85K. Monitor well, static. 06:00 08:00 2.00 COMPZ RPCOM CIRC P Circulate bottoms up. 202 bbls. Shut down pump, monitor well, static. LD hanger and Landing jt. Mix and um 25 bbls d 'ob. l~~qa~ 9 t~f T • Time Lomas _ Date From To Dur S D th E. De th Pha e Code Subcode T Comment 08:00 14:00 6.00 COMPZ RPCOM PULD P POOH standing back, drifting and strapping 3.5" tubing in derrick. LD seal assembly and send to Baker for redress. 14:00 21:00 7.00 COMPZ EVALWE ELOG P PJSM with SWS. RU E-line. Ran USIT to and evaluate 7" casin fro,~r 7690' to surface. Logged pulling OOH and entire field went into Phase 3 conditions. PDS logging suspended until conditions improve. Pulled USIT tool to surface and tied off. 7" csg appears to be in good shape, good cement up to 2,470' MD, found bad cou ler at 180' MD. 21:00 00:00 3.00 COMPZ EVALWE WOW T SWS crew on stand-by at rig camp, rig crew doing table top drills and cleanin ri while waitin on weather. 12/16/2008 Waited on weather until 04:00, MU and RIH with PDS logging tool, POOH RD SWS, PU and RIH with RBP and test packer to 3,479' and set RBP. PU 30' and set PKR and test RBP. POOH and MU FH Test PKR and RIH to 190' and test - ood. PU 10' and test -failed. POOH w/ same. ND BOPE. 00:00 04:00 4.00 COMPZ EVALWE WOW NP SWS crew continue to be on stand-by at rig camp, rig crew doing table top drills and cleaning rig while waiting on weather, at Phase 2 weather condition at 4:00 AM. 04:00 05:30 1.50 COMPZ EVALWE PULD P PJSM with SWS, LD USIT tool, CO heads, MU PDS tool. 05:30 11:00 5.50 COMPZ EVALWE ELOG P RIH with PDS on a-line to 7,745', POOH logging to surface. RD SWS. Rack and tally 3 1/2' drill pipe and fishin tools for 7" casin cut 7 ull. 11:00 12:00 1.00 COMPZ RPCOM DHEQ P RU floor for running drill pipe. 12:00 16:30 4.50 0 3,479 COMPZ RPCOM TRIP P RIH w/RBP & Retrievamatic Packer on 3 1/2" drill i e to 3479'. 16:30 17:00 0.50 3,479 3,449 COMPZ RPCOM OTHR P Set the RBP @ 3479' to center of element. Pull 1 jt, set the test ap cker 3449'. MU head in and test RBP to 2500 si. 17:00 20:00 3.00 3,449 0 COMPZ RPCOM PULD P Break out head pin. Blow down top drive, Put 1 jt drill pipe back in string. POOH standin back drill i e. 20:00 21:30 1.50 0 180 COMPZ RPCOM TRIP P MU and RIH w/ Baker Full Bore 190' Set and test f/ 190' to _-~ 3 479' to 2 500 si for 5 minutes - test ood. Move up hole to 180' and test to 2,000 psi -lost 100 psi in 5 minutes with no ressure ain on 21:30 23:00 1.50 180 0 COMPZ RPCOM PULD P Blow down Top drive, POOH f/ 180' and la down Packer. 23:00 00:00 1.00 0 0 COMPZ RPCOM NUND P Held PJSM w/ crew. ND BOPE and ND 7 /16" 5M x 11" 3M TBG S ool. 12/17/2008 Continue to ND BOPE, TBG Spool. Pull 7" x 11" Pack off. NU BOP on 11"surface CSG Flange. MU MS Cutter and RIH to 1,102', Cut 7" CSG and Circ. Arctic Pak out 7 x 10.75" OA. POOH w/ MS Cutter. RIH w/ BHA #4 to 3,435' and Dum 600# of 20/40 sand on RBP. f'~€J€s 2 ot~ 7 • Time Logs D to From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 0 COMPZ RPCOM NUND P Continue to ND BOP and TBG Spool 01:30 03:00 1.50. COMPZ RPCOM OTHR P Remove TBG Spool and Pull pack off. 03:00 08:30 5.50 COMPZ RPCOM NUND P NU BOP and Adapter 08:30 09:00 0.50 COMPZ WELCTI ROPE P Body test BOP 250!1500 psi. RD & BD test a ui ment. 09:00 10:00 1.00 COMPZ RIGMNT OTHR T C/O wash pipe packing on Top Drive. 10:00 12:00 2.00 0 1,124 COMPZ FISH CPBO P PJSM. PU and MU Baker Multi String Cutter and RIH to 1074'. Locate 7" collars @ 1087' and 1124'. PU to 1104'. 12:00 14:30 2.50 COMPZ FISH CPBO P PJSM. RU to cut 7" casing. Pumped 75 bbls 120 deg. 9.6 ppg brine. 14:30 15:30 1.00 COMPZ FISH CIRC P Shut down pump. Start rotating @ 50 RPM kicked pumped back on @ 3 BPM 910 psi. 1200 ft/Ib torque. Cut pipe, pressure dropped to 600 psi (300 psi). Torque dropped to 750 ft/Ib. Total hot brine pumped was 191 bbls. Shut down pump. Stop rotation. 15:30 16:00 0.50 COMPZ FISH CIRC P Opened OA to kill tank. Attempted to circulate down drill i e back thru OA ressured up to 1500 psi locked down. Bleed pressure. Check all lines and valves. Attempt to circulate again, est. circulation @ 1.5 BPM 60 si pod circulation. 16:00 17:00 1.00 COMPZ FISH CIRC P RD top drive. Dropped shear out ball & rod. MU head pin. RU LRS hot oiler. Circulated hot diesel thru cut, sheared pump out sub, pumped 67 bbls 160 deg. diesel thru OA maintaining a constant temp. Staging in w/10 bbl increments w/Hot Oil. SD LRS um . 17:00 18:00 1.00 COMPZ FISH CIRC P Pumped 7 bbls 120 deg 9.6 brine w/Saf Surf-0 with rig pump down DP taking returns via the OA to kill tank. SD, em kill tank. 18:00 20:30 2.50 COMPZ FISH CIRC P Open IA and pump 200 bbls of 120 deg 9.6 brine w/Safe Surf-o pill taking returns to kill tank. Empty kill tank again. Chase with 150 bbls 9.6 ppg Brine from active its to in attem t clean u 10 3/4" from Arctic Pack. 20:30 21:30 1.00 1,104 0 COMPZ FISH TRIP P POOH f/ 1,104' and lay down MS Cutter. 21:30 22:00 0.50 0 372 COMPZ FISH PULD P MU BHA # 4 and RIH w/ Bull nose on DC's. 22:00 23:30 1.50 372 3,435 COMPZ FISH TRIP P RIH w/ BHA #4 to 3,435' 23:30 00:00 0.50 3,435 3,435 COMPZ FISH CIRC P Sot 21 LN/ft of 20/40 sand lu ov RBP ~a~e 3 of 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment _ 12/18/2008 24 hrSummarv Continue to Dump sand. POOH and spear csg and POOH laying down. MU and RIH w/ BHA #6 and scrape 10.75" to 1,104'. POOH and Run PDS Lo f/ 1,104'. MU & RIH w/ BO tool. BO CSG stub. POOH 00:00 02:00 2.00 3,435 3,435 COMPZ FISH OTHR P Continue to Dump 600 # of 20/40 sand on RBP 02:00 02:30 0.50 3,435 2,491 COMPZ FISH TRIP P POOH w/ Bull nose to 2,491' 02:30 03:00 0.50 2,491 2,491 COMPZ FISH CIRC P Circulate 1/2 of the DP (9 bbls) to Clear DP. Offload MS Cutter and Stabilizer and Load CSG E ui ment. 03:00 04:30 1.50 2,491 372 COMPZ FISH TRIP P Continue to POOH w/ Bull nose f/ 2,491' to DC's. 04:30 05:00 0.50 372 0 COMPZ FISH PULD P Stand back DC's 05:00 05:30 0.50 0 38 COMPZ FISH FISH P MU and BHA #5 Spear assy. RIH and Engage Stub @ 38'. BOLDS and Pull CSG slips free @ 57k up wt w/ 35k Block wt. Pull to riq floor and_ remove emer enc sli s. Release s ear. 05:30 09:30 4.00 38 38 COMPZ FISH OTHR P POOH laying down 27 jts of 7" 26# casing, one 17' cut off piece, and 6 centralizers. Inspected casing as we pulled it out and no signs of corrosion, no si n of hole at 186'. 09:30 10:30 1.00 38 0 COMPZ FISH OTHR P Clean rig floor from Arctic Pack. NORM test and load 7" casing on truck. Load Backer scraper and tools to ri floor. 10:30 12:30 2.00 0 1,100 COMPZ FISH TRIP P PJSM. MU 10 3/4" casing scraper and RIH to 1100'. 12:30 13:00 0.50 1,100 1,100 COMPZ FISH CIRC P Established circulation with 5 BPM, 175 psi. Circulate 146 bbls until hole clean for PDS to . 13:00 14:30 1.50 1,100 0 COMPZ FISH TRIP P Shutdown pump. Monitor well, static. POOH with scraper standing back drill i e and collars. LD BHA. 1430 17:00 2.50 0 0 COMPZ FISH SLKL P PJSM. RU slickline. RIH with PDS 10 3/4" casin cali er and GR/CCL memory tools and log 10 3/4" casig from 1104' to surface. 17:00 19:00 2.00 0 418 COMPZ FISH PULD P PU and MU Back off BHA # 7 19:00 22:00 3.00 418 1,514 COMPZ FISH CPBO P RIH w/ Back off Assv to 1,514' w/ Top slip @ 1,116' and Fill DP w/ Fresh H2O. RU Circ. lines. Held PJSM, Set Lower slip unit @ 750 psi and slack off DC wt of 12k and set Upper slip unit @ 1,250 psi. Cycle BO Unit and Break tool jt @ 1,020 psi equivalant to 7,140 ft/lbs. Cycle tool 12 times and recovered 5 full left hand turns. Release tool and drop ball. Shear out POS 1,200 si. 22:00 22:30 0.50 1,514 1,487 COMPZ FISH CIRC P Reverse out fresh water. 22:30 23:00 0.50 1,487 418 COMPZ FISH TRIP P POOH w/ BHA # 7 UP wt 60k. 23:00 00:00 1.00 418 0 COMPZ FISH PULD P Lay down Back off tool and stand back DC's. I''~ct~? & n# 7 Time Logs Date From To Dur S. De th E. De th Phase Subcocte T Comment C o d e 12/19/2008 __ ___ __ __ _ 24 hr Summary MU and RIH w/Spear assy, BO Stub and recover. RU 7" CSG equipment. MU and RIH w/ 7" CSG w/Screw in assy. Change hole over to diesel for freeze protect. Screw in and PT CSG to 2,500 psi. Drain down stub below surface flange. ND BOP Set slips and cut CSG. NU TBG head, install Pack off and test to 250/3,000 psi. NU 13 5/8 BOP and Test @ 250/3,500 psi Witness of test waived by Lou Grimaldi @ 1830 hrs on 12-18-08. MU RBP retrievin tool and RIH to 1,160'. 00:00 00:30 0.50 0 0 COMPZ FISH OTHR P Clean Rig floor, kick out tools and brin 7" cs tools. 00:30 01:00 0.50 0 0 COMPZ RIGMNT SVRG P Service rig. 01:00 01:30 0.50 0 22 COMPZ FISH PULD P PJSM, MU BHA# 8 Spear assy. 01:30 02:00 0.50 22 1,114 COMPZ FISH TRIP P JSM, RIH w/ BHA # 8 on 3 1/2 DP to 1,114' and en a e spear. Pull 2k OSW 02:00 02:30 0.50 1,114 1,124 COMPZ FISH CPBO P Continue to back out 7" stub @ 1,124' w/ 6 LH rotations. 02:30 03:00 0.50 1,124 32 COMPZ FISH TRIP P POOH to 32' 03:00 04:00 1.00 32 0 COMPZ FISH PULD P POOH la in downs ear ass and 20.65' of 7" 26# CSG stub. 04:00 04:30 0.50 0 0 COMPZ CASING PUTB P PJSM, RU CSG equipment 04:30 07:30 3.00 0 COMPZ CASING PUTB P PJSM, MU 8 3/8" OD x 7" BTC Triple connection screw in assy on 7" 26# L-80 CSG and picking up &RIH, tag top of 7" pin looking up @ 1126'. PU 2'. 07:30 09:00 1.50 COMPZ CASING CIRC P MU head pin. PJSM. RU LRS, reverse circulate 98 bbls diesel freeze protect with LRS hot oil pump truck freeze protecting OA 10 3/4' x 7". RD LRS. 09:00 10:00 1.00 COMPZ CASING PUTB P Lowered back down and tagged top of 7" pin. Screwed onto 7" casing w/7" Tri le connection screw in ass . Torque up to 10K ft/Ib. Pressure test 7" casin to 2500 si./ ood 10:00 10:30 0.50 COMPZ CASING OTHR P Break out head pin, MU trash pump and pump out diesel in 7' down below lower lock down screws. 10:30 19:30 9.00 COMPZ CASING OTHR P ND BOPE and raise stack. et , emer enc slips w/50K tension. RU Wachs cutter and make cut on 7" casing. Set BOP stack back down, remove cut off casing stub. Re-sling stack, pick up and set on stump. Install 7" packoff, NU tubing head. PT ackoff to 3000 si. 19:30 22:00 2.50 COMPZ WELCTL NUND P NU BOP stack on tubing head. Install test lug, body test BOP to 250/3500 psi. This test waived by Lou Gramaldi @ 18:30 hrs 12/18/2008. 22:00 22:30 0.50 COMPZ FISH OTHR P Pull Test plug and install wear ring 22:30 00:00 1.50 0 1,160 COMPZ FISH TRIP P PJSM, MU BHA #10, RBP retrieving tool. RIH to 1,160' 47k up wt, 47k do wt. Page ~ ofi 7 Time Logs _ Da_te_ From To Dur S. De th E. Depth Phase Code Subcode T Comment _ 12/20/2008 24 hr summary Circ. out diesel. Cont' to RIH to 3,450' & circ out sand, latch onto RBP & Release. POOH laying down DP & RBP. MU & RIH w/ 3 1/2 COMP. locate, Space out, Circ Corrosion inhibited fluid, Land hanger, RILDS, PT TBG & CSG to 3,000 si. Shear out SOV ND BOP. NU Ada ter and tree PT to 5,000 si. FP. 00:00 01:00 1.00 1,160 1,160 COMPZ FISH CIRC P PJSM, Displace diesel out from 1,160' to Tiger Tank @ 5 bpm @ 400 si and Blow down lines. 01:00 02:00 1.00 1,160 3,450 COMPZ FISH TRIP P Continue to RIH to 3,450' and tag sand. 81 k u wt, 75k do wt. 02:00 04:00 2.00 3,450 3,479 COMPZ FISH CIRC P Reverse circulate sand down to top of RBP @ 3,479' @ 5 bpm @ 510 psi. Release RBP and blow down To drive. 04:00 04:30 0.50 3,479 3,479 COMPZ WELCTL OWFF P Monitor well 04:30 07:00 2.50 3,479 0 COMPZ FISH PULL P POOH f/ 3,479' laying down DP, DC's, and RBP. 07:00 09:00 2.00 0 COMPZ RPCOM RURD P Finish unloading pipe shed. Pull wear ring. RU rig floor for running com letion. 09:00 14:00 5.00 7,681 7,681 COMPZ RPCOM RCST P TIH with completion. 14:00 15:00 1.00 7,681 7,681 COMPZ RPCOM HOSO P Sting seal assembly into the PBR/SBE while slowly pumping, when pressure increased, shut down pump. Spaced out with seals out of PBR/SBE 2'. 15:00 15:30 0.50 7,681 7,681 COMPZ RPCOM HOSO P PU & MU hanger and pups. 15:30 16:30 1.00 7,681 7,681 COMPZ RPCOM CIRC P Circulate the well full (270 bbls) of corrosion inhibited 9.6 ppg brine (1 by volume Baker Petrolite CRW-132 . 16:30 17:00 0.50 7,681 7,707 COMPZ RPCOM HOSO P RIH and land han er. RILDS. 17:00 19:00 2.00 7,707 COMPZ RPCOM DHEQ P RU chart recorder to IA and tubing. With annulus o en, PT tubin to 3000 si. for 15 min. Monitorin annulus for returns none .Bleed off tubing pressure to 2250. While holding the tubing pressure at 2250 si, PT the IA to 3000 si for 30 min . Bleed IA to 0, then bleed tubing to 0 psi. Ramp up the IA pressure and sheared SOV 1,900 si. 19:00 20:30 1.50 COMPZ RPCOM NUND P Pull landing jt. Install two-way check. ND BOPE. 20:30 23:00 2.50 COMPZ RPCOM NUND P NU Gen IV Tree adapter head 7 1/16" x 3 1/8" 5M and 3 1/8" 5M tree. TBG Hanger void @ 5,000 psi -held. Pressure test Tree 250/5,000 psi - held. 23:00 00:00 1.00 COMPZ RPCOM FRZP P PJSM, Freeze Protect well w/ 80 bbls diesel pumping @ 2 bpm @ 1,350 psi down the IA, taking returns to its. 12/21 /2008 Continue to FP, Set HBPV, Secure well, RDMO Released Nordic ri 3 released 0300 hrs on 12-21-08 ~ P~~ 6 0~ 7 Time Logs Date From To Dur _ S. De th E. De th Phase Code Subcod e T Comment 00:00 _ 01:30 1.50 COMPZ RPCOM _ _ FRZP P Continue to Freeze Protect well w/ 80 bbls diesel pumping @ 2 bpm @ 1,350 psi down the IA, taking returns to its and allow to swa to TBG. 01:30 02:30 1.00 COMPZ RPCOM OTHR P Set 3" H-BPV and secure well. SITP 0 si, SIIAP 0 si, SIOAP 0 si. 02:30 03:00 0.50 COMPZ RPCOM OTHR P RDMO and Clean and clear cellar. Release Nordic Rig 3 @ 0300 hrs on 12-21-08 12/30/08 Cf /--+-- ~ ~" ~_~ V [I~.#iilll~~~rl_ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2U-03 12080460 INJECTION PROFILE '(' Cj 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE - 12/07/08 1 1 1C-11 12114998 PRODUCTION PROFILE a 12/14/08 1 1 1 D-07 12114999 USIT ._ a 12!15/08 1 1 1 B-09 12115001 INJECTION PROFILE ~ (- ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 iC-18 12100472 INJECTION PROFILE (' ` 12/21/08 1 1 1 E-21 12115005 INJECTION PROFILE p 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE t, 3 12/24/08 1 1 a. z.. ~; u~Lnrt:~.+ ~ ~ ~ V t V t:..~ Log Description N0.5024 Company: Alaska'Oil' &'Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. / ' ~ E j ( ~. A// ~ /! / ' ~~ ~.~_...... I tli~i~~~~~~~ NO. 5005 Schlumberger -DCS .C'~ 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth i 4 A±~~ °> i ; ~ s 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE /• - f 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE q '~- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE ~- 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / '" 11/28/08 1 1 30-01 12097434 LDL -~ 'a- 11/29/08 1 1 1 E-04 12097436 LDL '1' 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE L - 11/27/08 1 1 iH-16 12096581 PRODUCTION PROFILE ~ - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C - 1 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE - 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE S- 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE ~ 12/14/08 1 1 1 D-07 12114999 USIT 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE 12/17/08 1 1 • C~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ i LL L® r :w.. Y l`/~~4 /V~/1,~/T7~4 ~ 1,, e, ~. ... jj_ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ 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 ~~ ti't, ~~~t~ ~: ~' ~(~L 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J Correlation Log 16-Dec-08 1 D-07 (run 1) EDE 2) Correlation Log 18-Dec-08 1 D-07 [run 2) EDE ~~ ~ [~ -~t a 1330 t x-331 Signed : l~ Date Print Name: 50-029-20430-00 50-029-20430-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~~i~aticharai~~Crt~a~r2tnurt[faiy.corrt WEBSITE: y~t4y4y.re~I~aYaC7rVl~ig.Ct3rrr C:\Documents and Settings\Owner\Desktop\Transmit_Conoco.docx • s v~~~ ~o ~§ ~: , ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technics! data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1 ] Caliper Report 16-Dec-0B 1 D-07 (run 1) 1 Report / EDE 50.029-20430-00 2] Caliper Report 18-Dec-08 1 D-07 (run 2) 1 Report / EDE 50-029-20430.00 ~r ~ U ~ ~3aa Signed : Date Print Name: (',~j~'i~~2 ~ n to .P~ln e PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAx: (807)245-88952 E-MAIL : ~ra~~~raz;f~ssr~c~~(~~~rr~arylassl.ce~sn WEBSITE : a31a~,rvss~ ~i~~ ar e y~~~~.~~aey~i ~,.,\ r-- C:\Documenfs and Settings\OwnetlDesktop\Tiar~smit_Conoco.docx • Memory Multi-~~r~ger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-07 Log Date: December 18, 2008 Field: Kup>aruk Log No.: 7289 State: Alaska Run No.: 2 API No.: 50-029-20430-00 Pipet Desc.: 10.75" 45.5 Ib. K-55 BTC Top Lag IntvL Surface Pipet Use: Surface Casing Bot. Log Intvl: 1,071 Ft. (MD) Inspection Type : Surface Casing Deformation & Restriction Inspection COMMENTS This caliper data is tied into surface ~ 0 This log was run to assess the general condition of the 10.75" surface casing with respect to deformation and significant I.D. restrictions. The maximum extension of the caliper fingers used to log this well is -10.5", while the maximum extension of the centralizers used is slightly smaller than the I.D. of the casing. Consequently, some of the caliper fingers are prevented from making contact with the opposite wall when the caliper shifts towards one side of the casing, which occurs during normal logging operations and more frequently in areas of increased deviation. Although full arcumferential coverage is at times unavailable, major damage, deformation and/or restrictions are still observable when present. The caliper recordings indicate no significant areas of deformation or I.D. restriction throughout the interval of 10.75" surface casing fogged. No significant wail penetrations or areas of cross-sectional wall loss are recorded. A 3-D log plot of the caliper recordings across the 10.75" surface casing logged is included in this report. ' The decrease in reported minimum diameters from -650' to 1,070' is the result of the off-center positioning of the tool towards the low side and opposite full-finger extensions as described above, not an actual reduction in diameter. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 20%) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS '' No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS ~ , No significant LD. restrictions are recorded throughout the interval logged. ~,-~ Jk~ t ~ 2DG Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: R. Overstreet ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSra~memaryfog.com Prudhoe Eay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 vs~ <~-r ~ a ~~-3aa - PDS Multi~ger Caliper 3D Log Plot ~~S -_-~' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-07 Date : December 18, 2008 Description : Detail of Calper Recordings Across 10.75" Surface Casing 1 o soo _~ - ~ - 10 8U6 510 Pu Jt 0 Pu Jt j - I Joint 1 i A II t i ~ 50 Joint 2 100 Joint 3 r Joint 4 150 Joint 5 - 200 - -- Joint 6 -- Joint 7 250 - - _- - --- j ~ . 300 Joint 8 Joint 9 350 Joint 10 ToolOff-Center 400 Joint 11 Tool Off-Center 50 _. . _ - . Joint 12 Tool Off-Center - 500 --- -- Joint 13 Tool Off~enter J i t 14 550 o n Tool Off-Center -- Jant 15 Tool Off-Center 600 __. Joint 16 Tool Off-Center 650 Jant 17 Tool Off-Center Joint 18 Tool Off-Center 700 750 Joint 19 Tool Off-Center Joint 20 Tool Off-Center 800 -- Joint 21 Tool Off-Center - 850 -~ Joint 22 Tool Off-Center - 900 Joint 23 Tool Off-Center - s Joint 24 950 Tool Off-Center ~ Joint 25 Tool Off-Center 1000 Joint 26 ToolOff-Center _- - - Joint 27 1050 - - Tool Off-Center Top of 7" Production Casing - - -- r~ • • PDS Report Overview ~,,~. Body Region Analysis Well: 1 D-07 Survey Date: December 18, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 10.75 ins 45.5 f K-55 9.794 ins 10.75 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ~ penetration body ~ metal loss body ZO 0 1 ~ 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints ana sed total = 29 pene. 0 10 19 0 0 0 loss 12 17 0 0 0 0 Damage Configuration (body ) 10 I 0 - isolated general line ring hole/pons pitting corrosion cortosion corrosion ible hole Number of'oints dama ed total = 4 0 4 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 0 9 Bottom of Survey = 27.1 100 19 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 10.75 in 45.5 ppf K-55 Well: 1 D-07 Body Wall: 0.478 in Field: Kuparuk Upset Wall: 0.478 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 9.794 in Country: USA Survey Date: December 18, 2008 Joint No. Jt. Depth (Ft.) I'r~n. Ut>sctt (Ins.) Pen. Body (Ins.) Pc n. % Mehl I oss '%, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 0 0.04 0.03 6 0 9.67 PUP .2 2 0 0.07 14 3 9.70 PUP Shallow corrosion. 1 5 0 0.06 12 2 9.72 Shallow corrosion. 2 47 0 0.04 9 2 9.69 3 88 0 0.04 9 2 9.70 4 128 0 0.05 10 2 9.71 5 169 0 0.04 9 3 9.71 6 209 0 0.05 10 2 9.71 7 250 0 0.05 10 3 9.70 8 291 0 0.05 1 1 3 9.69 Shallow corrosion. 9 333 0 0.06 13 3 9.69 Shallow corrosion. 10 373 (1 0.07 14 3 9.67 ToolOff-Center. 11 413 0 0.08 17 4 9.71 ToolOff-Center. 12 454 0 0.10 20 3 9.71 ToolOff-Center. 13 493 0.0' 0.07 15 3 9.72 ToolOff-Center. 14 534 0 0.05 11 2 9.69 ToolOff-Center. 15 572 0.02 0.04 9 1 9.65 ToolOff-Center. 16 611 0 0.09 19 4 9.58 ToolOff-Center. 17 653 0.02 0.05 11 1 9.50 ToolOff-Center. 18 694 0.02 0.05 11 1 9.47 ToolOff-Center. 19 734 () 0.07 14 1 9.45 ToolOff-Center. 20 774 0 0.08 17 1 9.40 ToolOff-Center. 21 812 0 0.08 17 2 9.42 ToolOff-Center. 22 851 0.03 0.07 14 1 9.41 ToolOff-Center. 23 893 0 0.05 11 1 9.38 ToolOff-Center. 24 933 0 0.07 15 1 9.34 ToolOff-Center. 25 969 0 0.05 10 1 9.31 ToolOff-Center. 26 1008 0 0.06 1:i 1 9.31 ToolOff-Center. 27 1049 - - ~~ 0.04 ~ X3.38 ~ Toil nff-Center. ?'.1 10(17 - 0 ,A'(r\ ~ - lu(> ~>1 ;" I'r<xiuction Casing - - - - Penetration Body Metal Loss Body Page 1 ConocoPhillips KUP .~;n-..: I~ i all o - D-o a s to ene- J SURFACE, o-a.tae IN.ECTIDN, ],643 ~, e PACKER,]845 IPERF, 7.9{5-4,025 PLUG, 8.Oi5 c~ara. 3.1 i4 PROOUCrioN. 0.8422 TD, 6,550 f 1 D-07 well Amibutes API I UWI tld W Status ccaan halitratlon (') Total Depth 5002920430 KUPARUK RIVER UNR INJ __ 1 _ 48.50 8,65_0.0_ ConRalert H2S IPPtt4 Date Amdatlon Btd Dace KB[;rouM dstartce fltl Rig Rtlealse Date NIPPLE 0 7/1/2008 Last WO: 7/102008 38.01 10/30/1980 Aaaalatiat Last Tag: DepM (RIB) 8,070.0 Bw Dtte A &3/2006 R matation ev Reason: GLV C/O, PULL BALUROD Brd Wce 81232008 Casln Strin s Casing Descrlptlon CONDUCTOR OD M 16 1 1 1 5.062 oP 1 1 0.0 Set eptlt Irt.. 80.0 stl Dept 1 11 t._ 80.0 t Iby... 65.00 Grade H-00 op Connection Gang DescryttlOn SURFACE OD flM ID 10314 9 IMI .794 lop ImBI 0.0 Sp Depot (IL.. 3,136.0 Set DepM ITVD) (R- 2,638.4 Wt flbsl._ 45.50 Grade K-55 Top Conrrctlon Casatg Deecnpdon PRODUCTION OD flM ID 7 6 ~nj .151 op ( 1 0.0 Set Depth (1t_ 8,422.0 Set DepDC ( D) /1... 6,495.7 Wt bsl... 26.00 Gratle K-65 Top Cotva n Tubin Strin s TubRtg Descrtpaon TUBING- Workover oo Ory 312 Ilttl 2.992 op (R_ 0.0 « Ifd(._ 7,7977 Set oepm ITVDI Iroce) 5,995.5 wr Obvrry 9.30 Grade l L~0 op omecdon Coen letion Details Top INCB) Rem Desralptlon Comment DIW 226 HANGER TUBING HANGER 2.992 487.5 NIPPLE Camm'DS'Nipple 3l/2'x2.875' 2.875 7,694.9 SEAL ASSV Seal Assembly Locater w/ 2' space out 2.990 7,697.3 PBR Baker'PBR' 2.980 7.770.7 PACKER Baker FHL Pala 2.930 7.754.1 NIPPLE 'DS' Nipple 2.813' 2.812 7,790.8 OVERSHOT Paar Boy Overshot w/3.625' ID 3.970 Ttlng Desaiptlan rq DIRtI TW+Itt_. StlD ( .. tlDepatl (RIB Wt op atrlectlon TUBING 312 2.992 7,788.0 7,880.0 6,060.1 920 J{i5 BTC Coen letion Details Top fIK6) Rem Desc n edmrlert ( 7,838.0 S BR Baker'ELA-1' 2.813 7.845.0 PACKER Baker'FHC 2.891 7,878.0 NIP Camcn'D' Nipple NO GO 2.750 7,879.0 S OS -- _- Baker 2.992 7.879.0 T TL Use TT @ 7866' for Carrelatiorts 8 Tags. 2.992 Other In H_ ole (Wireline retrievabl~l~s, valves, pum s, fish, etc. _ lop (RKB) Deicdptlon - - ._ .. __ _ _ __-_ Comment Run Date ~~1n~ 8.075.0 PLUG CMT PLUG: 5 bbl CFass'G' Cement 6116/1997 O.SDI) Perforafions Top (RIB) &rtt fltK61 op (T'/DI (RIB) Btm (TVD) (RIB) • zone Shat Dens Isla... wte Comment 7,948.0 8,025.0 6,113.9 6,175.3 I PERF C-1, C-2, C-3, Cam, 7 D-07 4.0 611611997 Zao deg. Phasitg Cement ueeie5 Top (RKB) &Itl ( 1 Start Dace Descrlptlon Comment 8,174.0 8.197.0 6/16/1997 Cement Squeeze Notes: General 8 Serf 13rd Dale Amotalfon 7232008 NOTE: VIEW SCHEMATIC wl9.0 Mandrel Details 8Rt Top (RIB) SN Deptlt ITtIDI (11181 Melee hbdel OD Pro Valve type Latch type Port Size IRtI 1R0 Run Ipso Run Drte Comment 1 7,642 .7 5,995.5 CA O MMM 1 12 DMV RK 0 0.0 81972008 Page 11 of 22 12/11!2008 Memory Multi-Finger Caliper Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 1 D-07 Log Date: December 16, 2008 Field: Kuparuk Log No.: 7288 State: Alaska Run No.: 1 API No.: 50-029-20430-00 Pipet Desc.: 7" 26 Ib. K-55 BTC Top Log intvl: 25 Ft. (MD) Pipet Use: Casing Bot. Log Intvl: 7,694 Ft. (MD) Inspection Type : Pre-RWO Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is cornelated to the Sch/umberger Simultaneous Compensated Neutron-Formation Density Log (dated 10-24-80). This log was run to assess the pre-RWO condition of the 7" casing with respect to corrosive and mechanical i~ ~ damage. The caliper recordings indicate the 7" casing is in good to poor condition, with a 42% wall penetration recorded in a gouge due to appear wear. Additional wall penetrations from 20% to 27°~ wall thickness due to apparent wear to the casing are recorded from -850' to 3,150'. A 3-D log plot of the caliper ' recordings from 850' to 2,500' is included in this report. No other significant wall penetrations or areas of cross-sectional wall loss are recorded. Slight buckling is recorded from 1,000' to 7,700', with indications of slight ovality due to buckling in joints 124, 127, 129, 137, 161, and 167. No significant LD. restrictions are recorded. II' MAXIMUM RECORDED WALL PENETRATIONS Apparent Wear (42%) Jt. 23 @ 912 Ft. {MD) Apparent Wear (27%) Jt. 54 ~ 2,183 Ft. (MD) ' Apparent Wear (26°~) Jt. 61 @ 2,432 Ft. (MD) Apparent Wear { 25°~} Jt. 26 @ 1,036 Ft. (MD) Apparent Wear (22%) Jt. 25 @ 973 Ft. (MD) ' MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 12%) are recorded. ',,' MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~~~ ,1AN ~ 20D9 Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: R Overstreet II , ProActive Diagnostic Sen!ices, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888j 565-9085 Fax: (281} 565-1369 E-mail: PDS:a~rr,emorylog.com Prudhoe Bay Field Of#ice Phone: (907} 659-2307 Fax: (907) 659-2314 u~~{~~ -lla l~3ad 1 _~~ PDS Multifinger Caliper 3 D Log Plot ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-07 Date : December 16, 2008 Description : Detail of Caliper Recordings Across Apparent Wear in 7" Casing 1 1 C ^ iii■■�� 41 SIMON ■■■■■■■Iii k! I■■■■SE ii■ii■oon ■■ i:�■■■i■■ rG `mons■■■ ■■■■■■ SSSS■■ � RANSOMER - 11■■■SSSSoil ,' Ill■■■■■■ �� ANNE I ';iii■■■■ IE■■■■■■ I1■■■■■■■ , SEEMS■ 5� soon loss. on ■-- lis■ii IM111■■ Correlation of Recorded Daman Pipe 1 7. in (24.6' - 7694.6') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 1D-07 Kuparuk ConocoPhillips Alaska, Inc. USA December 16, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 27 25 969 50 =ii® 1977 75 3015 D ~ v E _ Z 100 3997 s c ' Q- a, o 125 4928 150 ~ 5917 175 6908 194.1 7695 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 194.1 PDS Report Overview ~. ~. Body Region Analysis Well: 1 D-07 Survey Date: December 16, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Rngers: 40 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f L-80 6.276 ins 7.51 1 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body sr metal loss body 200 150 100 50 0 0 to I to 10 to 20 ro 40 to over 1 % 10%~ 20% 40% 85% 85% Number of ~oints anal sed rotal = 195 pene. 0 151 38 5 1 0 bss 72 121 2 0 0 0 Damage Configuration (body ) 30 20 10 0 isolah~i general hnc nng hole /puss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 49 17 8 24 0 0 Damage Profile (°~6 wall) ~ penetration body metal loss body 0 50 100 0 50 100 150 Bottom of Survey = 194.1 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.618 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ELATION SHEET 1D-07 Kuparuk ConocoPhillips Alaska, Inc. USA December 16, 2008 Joint No. )t. Depth (Ft.) I'c~n. Ul~se~t (Im.l Pen. Body (Ins.) I'en. "i~ ~le~t;il Lcs~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 25 U .01 3 I 6.29 P P 1 27 t) 0.02 7 1 6.28 2 66 l> 0.04 1 I I 6.29 Shallow A arent Wear. 3 104 t~ 0.03 9 _' 6.28 Shallow A arent Wear. 4 145 a 0.03 £3 I 6.25 5 1 3 tl 0.01 ~ I 6.28 6 223 O 0.01 :' I 6.25 7 260 a 0.04 1 1 5 6.27 S allow A arent Wear. 8 296 (I 0.01 ' <r 6.25 9 336 tl 0.01 _' 6.27 0 377 U 0.01 ~ 6.27 11 417 t I 0.02 1 6.30 12 458 t) 0.01 ~3 6. 6 13 498 O 0.03 ~ ! 6. 7 14 538 t ~ 0.01 2 I 6 25 15 573 t 1 0.01 ~' ~ 6.24 16 612 t~ 0.01 2 1 6.29 17 651 U 0.05 14 ~ 6.28 hallow A arent Wear. 18 693 a .01 3 1 6. 7 19 731 (~ 0.01 3 I 6.25 20 771 (~ 0.01 2 ? 6.28 1 813 i i 0.01 2 6.24 2 852 t ~ 0.01 Z _' 6.28 23 893 t I 0.15 42 6.24 A arent Wear. 4 9 0 U 0.02 4 I 6. 5 li h ckli 25 969 U 0.08 22 _' 6.28 A arent Wear. 26 1007 U 0.09 25 6.27 A arent We r. 27 1042 U 0.01 4 1 6.28 28 1084 t ~ 0.01 4 I 6. 8 29 1121 U 0.01 i I 6.26 Sli ht Bucklin . 30 1161 tl 0.06 15 I .29 Shallow A arent Wear. 31 1198 11 0.02 i> I 6.28 2 1238 U U.03 7 I 6.29 33 1279 t) 0.04 1 Z ~ 6.23 Shallow A arent Wear. 34 1 21 U 0.01 2 ~ 6.27 Sli ht Buckli 35 1360 t~ 0.06 17 _' 6.25 Shallow A arent Wear. 36 1401 t ~ 0.01 3 I 6. 5 37 1444 t~ 0.01 3 I 6.27 38 148 i ~ 0.03 H I 6.22 39 1522 a 0.04 1 % 6.24 Shallow A arent Wear. 40 1565 tt 0.03 7 ; 6.2 Sli ht Bucklin . 41 1607 t I 0.06 1 ii 7 6.26 Shallow A arent Wear. 42 1650 ll 0.06 17 ? 6. 5 Shall w A arent We r. 43 1689 t~ 0.06 17 ~' 6.22 Shallow A arent Wear. 44 1731 t I 0.03 7 I 6.23 45 1768 t) 0.01 -1 1 6.24 Sli ht Bucklin . 46 1811 t ~ 0.0 4 I 6.24 47 1853 a 0.05 1 3 6.22 Shallow A arent Wear. 48 1894 ~ ~ 0.02 7 6.21 49 1935 0.02 I 6.22 ,Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.618 in Company: Nominal I.D.: 6.276 in Country: Survey Date: iLATION SHEET 1D-07 Kuparuk ConocoPhillips Alaska, Inc. USA December 16, 2008 Joint No. Jt. Depth (Ft.) I'E~n. UI»c~t (InS.) Pen. Body (Ins.) Pen. °i~> ~1c~t.~l Lc,ss °i,. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 SO 100 50 977 t ~ 0.01 3 I .24 Sli h Bucklin . 1 2019 U 0.01 3 I 6.23 52 206 t) 0.03 ~) 1 6.21 Shallow A anent Wear. 5 2105 ~ ~ 0.03 i I 6.21 54 2147 U 0.10 Z 7 6.' 8 A anent Wear. 55 187 t~ 0.01 3 1 6. 3 Sli ht Bucklin . 56 2225 tl .03 i <I 6.24 57 2 63 U 0.02 7 6.23 58 306 U 0.0 7 I 6.22 59 348 t ~ 0.02 6 1 6.21 0 2389 l~ 0.03 1 6.24 Sli ht B cklin 61 430 (~ 0.09 _'(~ -1 6.23 anent Wear. 62 2472 U 0.03 I 6.1 6 2512 U 0 07 I') _' 6.20 Sha to anent Wear. 64 2555 tl 0.01 I 6.22 65 259 It 0.05 I , 6.20 hallow A anent Wear. 66 2637 U 0.03 8 I 6.21 SF ht ucklin . 67 679 a 0.02 v I 6.23 68 2 721 i ~ 0.02 6 I 6.21 69 2763 t~ 0.05 1:3 6.17 Shallow A anent Wear. 70 2803 a 0.02 t~ I 6.20 71 2845 a 0.05 I I 6.21 Shallow A anent Wear. 72 2888 t) 0.03 ti 6.21 Sli ht Bucklin . 73 2930 a 0.03 7 1 6.21 74 972 U .01 3 75 3015 t~ 0.02 E~ I 6.24 76 3058 a 0.02 6 I 6.23 77 3100 U 0.01 3 I 6.24 Sli ht Bucklin . 78 3141 U 0.08 ? 1 _' 6. 6 A anent Wear. 79 3180 i) 0.03 7 ti 6.27 80 3217 (1 0.03 tt ~ 6.20 81 3257 U 0.01 3 3 6.23 82 3295 U 0.01 ~' ~' 6. 6 51i ht Bu klin . 83 3333 l) 0.03 £3 1 6.19 84 3375 t1 0.01 3 ? 6.25 85 3414 U 0.01 I 6.24 86 3455 l1 0.01 ~ ? 6.22 87 3496 tt 0.02 ~ ~' 6.23 Sli ht Bucklin . 88 3537 t~ 0.03 7 7 .23 89 3577 U 0.01 a ' 6.26 90 3615 u 0.01 s ~' .26 91 3654 t) 0.01 1 2 6.21 92 3693 U 0.03 ti t~ 6.21 Sti ht B (in . 93 3727 t1 0.04 12 I 6.28 Shallow A anent Wear. 94 3767 a 0.01 3 ~' 6.24 95 3806 t } 0.05 14 6.24 Shallow A anent Wear. 96 3845 t~ 0.01 t ' 6.23 97 3883 t~ 0.01 ~' 6.23 Sli ht Bucklin . 98 922 U 0.01 4 6.23 99 3960 i~ 0.01 S I 6.27 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.618 in Company: Nominal I,D.: 6.276 in Country: Survey Date: ELATION SHEET 1D-07 Kuparuk ConocoPhillips Alaska, Inc. USA December 16, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ula~•? (lin.l Pen. Body (Ins.) Pen. °o ~~~t.~l I ~~s .~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 100 3997 t? 0.03 ~) > 6.26 101 4038 i? 0.04 I ' ~i 6.28 Shallow A arent Wear. 10 4075 t? 0.05 13 1 _' 6.28 Shallow A arent Wear. 103 4116 a 0.02 (~ I 6.26 li ht Bucklin . 104 4157 ti 0.01 _' I 6.19 10 4196 ! i 0.04 1 _' 6.24 Sh Ilow A arent Wear. 10 4235 a 0.01 ~ 6.25 107 4275 ~) 0.01 -1 _' 6.29 108 4 15 a 0.01 6. 5 li ht Buc in . 109 4351 t i 0.01 -1 I 6.21 110 4389 ! i 0.01 ~ ' 6. 3 Sli ht Bucklin . 111 4429 !? 0.01 3 I 6.2 Marker oint. 112 4449 U 0.01 2 I 6.24 Marker oint. 113 4469 ~? 0.01 3 4 6. 3 li ht cklin . 114 4506 U 0.01 3 6.28 Sli ht Bucklin . 115 4542 t) 0.01 4 _' 6. 7 116 4577 O 0.01 2 I 6.25 117 616 U 0.03 8 2 6.24 Sli ht ucklin . 118 4654 O 0.01 3 1 6.26 119 4694 ?? 0.01 2 6 6.23 120 47 9 ~) 0.04 1 1 1 6.27 Shallow A arent Wear. 121 4770 t) 0.01 ~ I .26 Sli ht ucklin . 122 4810 t) 0.06 16 ~ 6.25 Shallow A arent Wear. 123 4852 U 0.01 2 6.24 Sli ht Bucklin . 1 4 4 88 (i 0.02 7 £3 6 rcklin . 125 4928 t) 0.05 1.1 6.24 Shallow A arent Wear. 126 4969 U 0.01 4 -l 6.23 Sli ht Bucklin . 127 5009 t) 0.03 8 i, 6.17 Bucklin . 128 5049 t) 0.01 2 -1 6.25 Sli ht Bucklin . 129 5088 U 0.02 6 ~) 6.25 Bucklin . 130 5128 l) 0.06 15 _' 6.23 Shallow A arent Wear. 131 5168 ti 0.01 3 (, 6.23 Sli ht Bucklin . 13 5' 08 U 0.06 15 I 1 6.29 SFiallow A arent Wear. 133 5245 t) 0.05 1 3 6.24 Shallow A arent Wear. 13 5283 t) 0.01 4 _' 6.20 S i hi Bucklin . 135 5319 t) 0.01 ~ 6.25 Sli ht Bucklin . 136 5360 t? 0.03 ~ 6. 6 Sli ht Bucklin . 137 5398 ~) 0.01 ' a 6.23 Bucklin . 138 5437 i1 0.04 12 _' 6.23 Shallow A arent Wear. 139 5477 ~) 0.04 10 4 6.24 Shallow A arena Wear. 140 5517 t? 0.06 15 i 6. 4 Shallow A arent Wear. 141 5557 l) 0.07 18 c~ 6.24 Shallow A arent Wear. 142 5598 (? 0.01 3 5 6.24 Sli ht Bucklin . 143 5639 t) 0.03 8 6.26 144 5678 t) 0.01 3 ~~ 6.24 Sli ht Bucklin . 145 5719 ?? 0.07 ~'l) Iii 6.23 ShallowA arentWear. 146 5761 U 0.04 12 _' 6.25 Shallow A arent Wear. 147 5799 ?? 0.01 4 6.22 Sli ht Bucklin . 148 5839 U 0.01 2 I 6.26 149 5880 U 0.03 8 I 6.23 _ Penetration Body Metal loss Body Page 3 PDS REPORT JOINT TABI.~ Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.618 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ELATION SHEET 1D-07 Kuparuk ConocoPhillips Alaska, Inc. USA December 16, 2008 Joint No. Jt, Depth (Ft.) PE~n. Uls~~i (Ins.) Pen. Body (Ins.) Pen. °/~ Mct~il lo~~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 15 5917 U 0.01 3 I 6.19 Sli ht Bucklin . 15 5957 U 0.06 18 _' 6.27 Shallow A arent Wear. 52 5996 U 0.01 ~' 6.26 153 60 7 O 0.05 1 ~ 6. 5 Shallow A arent Wear. 154 6078 O 0.01 I 6.25 Sli ht Bucklin . 1 5 6118 O 0.05 I.1 t, 6 24 Shallow A arent Wear. 156 6157 l) .01 4 6.22 157 6198 a 0.02 6.23 Sli ht Bucklin . 158 6237 U 0.06 15 -1 6.24 Shallow A ar nt Wear. 159 6276 U 0.02 6 I 6.24 Sli ht Bucklin . 160 6315 U 0.05 14 _' 6.26 Shallow A arent Wear. 161 6354 U 0.01 2 -~ 6.23 Bucklin . 162 6396 (~ 0.01 ; - 6.25 Sli ht Bucklin . 163 6437 U 0.05 14 _' 6.25 Shallow A ar nt Wear. 164 6477 U 0.01 i 1 6.24 65 6515 U 0.01 ~ ~' 6.23 Sli ht Bucklin . 166 6555 a 0.01 ~ 6.23 Sli ht Bucklin . 167 6593 U 0.01 3 4 6.19 Bucklin . 168 6632 U .01 Z I 6.21 169 6670 t) 0.01 2 ! 6.24 170 6711 1) 0.01 2 1 .21 Sli ht Bucklin . 171 6751 O .01 _' 1 6.23 172 6787 U 0.01 ; ~) 6.27 173 6827 O 0.01 t ~ 6.19 174 6866 (~ 0.01 4 I 6.22 175 6908 U 0.02 ~ ? 6.19 Sli ht BucMin . 176 6949 a 0.02 7 6.17 177 6991 U 0.02 6 _' 6.24 178 7031 U 0.01 3 I 6. 5 179 7072 U 0.03 7 6.24 180 7113 l) .O1 ~ _' 6.2 Sli ht Bucklin . 181 7154 c ~ 0.03 _' 6.20 182 7197 U 0. I 6.21 183 7236 O 0.03 6.19 184 7278 (~ 0.01 4 6.24 185 7320 i t 0.02 - ~ 6.23 Sli ht BucMin . 186 7361 ~) .0 (> ~ 6.20 187 7 1 t) 0.03 9 Z 6.20 Shallow A arent Wear. 1 8 7442 t) 0.02 ~ _' 6.22 189 7484 t) 0.01 3 _' 6.23 190 7526 U 0.0 4 1 6.21 Sli h B ckli 191 7568 U 0.01 i 2 6.22 192 7608 l) 0.03 ~) S 6.21 Shallow A arent Wear 193 7649 l) 0.04 12 ~' 6.20 Shallow A arent Wear. 194 7691 O 0.01 4 _' 6.22 Sli h Bucklin . 194.1 7695 U 0 U U N A To of 3.5" PBR _ Penetration Body Metal Loss Body Page 4 PDS Report Cross Sections ~~ ~~ „ b'Vell: 1D-07 Survey Date: December 16, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA ~ti'o. of Fingers: 4U Tubing: 7 ins 26 ppf L-80 _ Analyst: M. Lawrence Cross Section for Joint 23 at depth 911.91 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 93 Tool deviation = 13 ° Finger 5 Penetration = 0.151 ins Apparent Wear 0.15 ins = 42% Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ Cross Sections page 1 ~~~ _ ~+~ PDS Report Cross Sections Well: 1D-07 Survey Date: December 16, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA ,ti'o. of Fingers: 4U Tubin 7 ins 26 f L-80 __ Analyst: M. Lawrence Cross Section for Joint 54 at depth 2183.35 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 98 Tool deviation = 44 ° finger 40 Penetration = 0.096 ins Apparent Wear 0.10 ins = 27% Wall Penetration HIGH SIDE = UP Cross Sections page 2 Page 1 of ~' • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 16, 2008 9:50 AM To: 'Packer, Brett B' Subject: RE: 1 D-07 (179-112) Brett, It appears that a 1500 psi test is appropriate given the stage of the workover you will be at and that the 7" rams will not be required. You will have 3 barriers between you and the reservoir. As discussed, with the inability to employ a test plug, the fluid volume that will be pressured is substantially greater than normal. Assuring that the volume needed to pump is consistent throughout the pressure tests will give you confidence in the shoe. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:].Brett.Packer@rnnocophillips.com] Sent: Tuesday, December 16, 2008 8:59 AM To: Maunder, Thomas E (DOA) Subject: Re: 1D-07 (i79-112) ~; e ~~4:~1~}~.: ~~ ~-' 4 , w ~~~ Tom, We got the results from the USIT cement bond log, and it shows the 7" production casing to be in excellent shape, other than a bad collar at 180' MD which is where we set the storm packer in the previous workover and where diagnostics indicated a leak. It appears the top of cement is around 2400' MD. So it looks like we will be running with Plan A of the procedure to just cut, pull, and replace about 240' of the 7" casing. Currently, we are running a caliper log as another verification of the casing condition. Based upon these results, plans are to set the RBP about 1000' below the top of cement and then run a test packer to verify the leak at 180' MD. It will probably be this afternoon by the time we are ready to nipple down the BOP's, remove the tubing head, and nipple up to the casing head; prior to this, 1'd like to have your approval to re-test this connection to only 1500 psi. As stated below, we will have the three barriers in place, and togs indicated a good cement jab from 2400' on down, but we still don't want to push our luck by testing above 1500 psi on that cement shoe. Please advise. Thanks! ,~ Brett ~PaclE;gr Ong ~ `Wells 'workover Engineer `Work# (907) 265-6845 Cell# (907 230-8377 From: Packer, Brett B Sent: Monday, December 15, 2008 2:28 PM To: 'Maunder, Thomas E (DOA)' Subject: RE: 1D-07 (179-112) 12/16/2008 Page 2 of /~ Tom, As a follow-up to our conversation, during the 1 D-07 workover, plans are to remove the tubing head and NU the BOP's to the casing head, to cut, pull, and replace the bad 7" casing. After breaking this connection and nippling back up the BOP's to the casing head, we need to test that connection below the blinds. Previously I had mentioned that the maximum we can test that connection to is 3000 psi due to the maximum rating of the casing head, but due to the fact that the 7" casing is set on slips and we have to remove the 7" packoff to NU the BOP's, we cannot set a plug in the casing head and will be pressuring up below the blinds against the RBP in the 7" and against the 10-3/4" surface casing shoe. This well passed a CMIT IA x OA to 1800 psi on 8/20108 following the previous workover, so we know that we have competent surface casing and a competent surface casing shoe up to 1800 psi. It is requested that we should only test the broken connection below the blinds to 1500 psi so as not to risk breaking down the surface casing shoe. At this point of the workover, we will have three barriers in place: 1. An IBP in the tubing tail @ 7865' MD w/ sand on top and a competent packer set in the 7" casing @ 7845' MD both tested to 2500 psi. 2. An RBP set in the 7" casing above the packer and below the top of cement, tested below the RBP to 2500 psi. 3. 9.6 ppg kill weight fluid in the hole. KWF is expected to be 8.8 ppg based upon a SBHP on 7/2!08 ofi 2809 psi at mid-pert (6145' TVD). The casing leak is expected to be around 185' MD, so it is likely that we wit! only be replacing a few hundred feet of 7" casing. Originally I had included changing out the lower rams to 7" rams, but since we cannot set a test plug in the casing head, we would only be able to test below these rams to 1500 psi also. Can you please advise as to whether it is necessary to install 7" rams in this scenario. Following the repairs on the 7" casing, once we re-install the tubing head, all BOP tests will be conducted to 3500 psi as per the approved Sundry. I apologize for the confusion, as this is my first workover that includes cutting and pulling production casing, so after this I should have a better handle on it. I look forward to your comments. Thanks, Brea ~~ ~Dril2ing ~ `WeQs 'workover ~En~ineer 'Work# (907) 265-6845 CeQ# (907) 230-8377 From. i~Fa+: er, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, Dec 2, 2008 8:20 AM To: Packer, Brett B Subject: RE: iD-07 (179-112) Brett, Understood. Make sure a copy of this message is at the rig. Tom Maunder, PE AOGCC 12/16/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 12, 2008 8:20 AM To: 'Packer, Brett B' Subject: RE: 1D-07 (179-112) ,~, - ~ ~(~~~ <?+"x.% Brett, Understood. Make sure a copy of this message is at the rig. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Thursday, December 11, 2008 5:00 PM To: Maunder, Thomas E (DOA) Subject: RE: 1D-07 (179-112) Tom, i just received the Approved Sundry and realized something-During this workaver, we will initially test the BOP's to 3500 psi as indicated on the Approved Sundry when the BOP stack is nippled up to the tubing head, but at some point, we are required to ND the tubing head and NU the BOP's to the casing head to either pull the 7" or run the 5-1/2" casing. This casing head has a rated working pressure of 3000 psi, so that is the maximum we will be able to test it to. Once we re-install the tubing head, we can once again test to 3500 psi as the Sundry dictates. just wanted to let you know so that you're not wondering why we only tested to 3000 psi when the Sundry says 3500 psi. Thanks, ,~ Brett 2'acker ~Dri~ng eG `GUelxr `wOfkO'Vef ~fdgYtteer `Worf,# (90T) 265-6845 CeIC'# (90T) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December li, 2008 12:32 PM To: Packer, Brett B Subject: RE: 1D-07 (179-112) Brett, I show the sundry was approved on the 11th and returned via the courier on the 12tH Tom From: Packer, Brett B [mailto:].Brett.Packer@conocophillips.com] Sent: Thursday, December 11, 2008 12:17 PM 12/12/2008 Page 2 of 2 To: Maunder, Thomas E (DOA) Subject; RE: iD-07 (179-112) Tom, J I'm just checking back with you on the status of the 1 D-07 Sundry Application to see if you had any questions. It's looking like the rig will be moving that direction either Sunday or Monday and I wanted to make sure we had an approved application before the rig starts moving. I know that you are swamped over there, so I appreciate your time looking at this. Thanks, ,~ Brett ~F'ackgr ~DrtiLTng sZ ZUeRs ~Norfor~er {Engineer ~Nork# (907) 265-6845 CeII# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 09, 2008 3:16 PM To: Packer, Brett B Subject: 1D-07 (179-112) Brett, I am reviewing the workover procedure for this well. If you do have to cut and pull, is it planned to put a shallow RBP in the 7" casing with sand on top as a "junk catcher" to protect the deeper portions of the well? BP at Prudhoe does a lot of these operations and that appears to be their standard practice. That also establishes 2 mechanical barriers between surface and the reservoir. Knock on wood, so far 1 am not aware of them having any issues cleaning off and recovering their casing bridge plugs. I look forward to your reply. Tom Maunder, PE AOGCC 12/12/2008 • a a -~ ~w~ ~ a a ~' ~ SARAN PALIN, GOVERNOR --"-"`~~ OI~ ~ ~4-7 333 W 7th AVENUE, SUITE 100 C01115L'`RQA7`IO1~T C01-II-IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brett Packer Wells Engineer ConocoPhillips Alaska Inc ~~~~~y ~ E ~~ :i ~~ 200 PO Box 100360 Anchorage AK 99510 1 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-07 Sundry Number: 308-437 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90?) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Comrrnission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. _,~J Chair DATED this ~ d/a'~y of December, 2008 Encl. Conocol~illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-07 (PTD# 179-112). Injecting well 1D-07 was drilled in October 1980. It is currently a water injector. There is an FOR expansion project on 1 D pad that will bring MI gas to the location. 1 D-07 had a workover done in July 2008 to upgrade the tubing head to allow MI injection into the well. Following the workover, the casing would not pass an MIT and downhole diagnostics determined a leak at 185' MD, suspiciously in the location of where the storm packer was set in the previous workover when the tubing head was changed out. This well needs to have casing integrity before WAG injection is allowed. This Sundry is intended to serve as a request for approval to workover the well. The objective of the proposed workover will be to pull the existing 3'/2" tubing string, run a USIT and caliper log in the 7" casing to determine cement top and casing condition. At that point, depending on the condition of the casing, we will decide to either cut and pull the bad 7" casing and replace it, or run an inner string of 5'/z" casing and re-complete the well with 3'h" tubing tubing. We believe that it is highly unlikely that we will have to run the inner string of casing. Regardless of which route is taken, we will end up with two competent barriers to allow for WAG injection. Attached is a proposed schematic(s) along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~~ Brett Packer Wells Engineer CPAI Drilling and Wells ~~Q~ STATE OF ALASKA • ~" ~ ti~ 1l ALASKA OIL AND GAS CONSERVATION COMMISSION~iai' ~ APPLICATION FOR SUNDRY APPROVALS /'~ `"'`' 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver^ Other ^ Alter casing 0 -Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ . Change approved program ^ Pull Tubing ^~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5: Permit to Drill Number: ConocoPhillips Alaska, Ina Development ^ Exploratory ^ 179-112 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-029-20430-04 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ 1 D-07 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): 12'~VC-C9_ ADL 25650 ' .RKB 101' ~ Ku aruk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8550' ~ 6600' ~ 8076' 6215' 8075' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 80' 80' SURFACE 3035' 10-3/4" 3136' 2639' PRODUCTION 8321' 7" 8422' 6496' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: ~ Tubing MD (ft): 7948'-8025' 6114'-6175' 3-1 /2" L-80 7798' Packers and SSSV Type: Packers and SSSV MD (ft): pkr = Baker'FHL' pkr = 7711' RKB pkr = Baker'FHL' pkr = 7845' RKB No SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Dec. 15, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Engineer Signature Phone 265-6845 Date ~ c~ COMMISSION USE ONLY -, Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ ~ Other: ~~~/ ~y~~ ~V ~ _~S~ Subsequent Form Required: ~~~ Approved by: APPROVED BY ~ ~ 1 COMMISSIONER THE COMMISSION Date: ~ 1 l Form 10-403 Revised 06/200 t ~ ~ ~ ~ ~ ~ ~ 1.,~. ,. ~~~ Submit in Duplicate .-- ConocoPhillips KU P well At Alaska,ln_. Aalluwl _... ... .. 50029204 Commam SURFACE. 0.3.136 INJECTION, 7.643 I NJ 48.50 Annotation End Date KBAround Dia Last WO: 7/10/2008 38.01 CONDUCTOR 16 15.062 0.0 80.0 80.0 Casing Description SURFACE OD (in) 103/4 ID (in) 9.794 Top (RKB) 0.0 Sat Depth (R... Set Depth (T" 3,136.0 2,638. Casing Description PRODUCTION OD (in) 7 ID (in) 6.151 Top (RKB) 0.0 Set Depth (R.. Sel Depth (T" 8,422.0 6,495. Tubin Strin s Tuhing Description '.OD (in) TUBING- 31/2 Workover ID (in) Top (tt... 2.992 0.0 Sat Depth (ttN... 7,797.7 Set Depth (ND) (RY 5,995.5 -_ Com letion Details Top (RKB) Item Description 1 Comment 22.6HANGER iTUBING HANGER 487.5 NIPPLE 'Camco'DS' Nipple 3 12" x 2.875" 7,694.9 SEAL ASSY Seal Assembly Locater w/ 2' space out 1 D-07 L-80 TUBING 31/2 ~ 2.992 17,788.01 7,880.0 ~ 6,060.1 ~ 9.20 ~ J-55 ~ BTC ~ Btm (ND) (ND) RKB) (RNB) (RKB) Valve Latch Slze TRO Run TYPe TYPe (in( (Pal) IPERF, 7,94e-8,025 PLUG. 8.075 Cement, 6,174 'RODUCTION. 0.8,471 TD. 8.550 ! ~ Kuparuk 1D-07 General Workover Procedure PTD 179-112 Pre-Rid Work 1. Set BPV 2. Prepare location for arrival of Workover Rig General Workover Procedure ~ E ~~ ,~ `~~ 1. Verify Sundry approval acquired ~~ ~~, ~`~ 2. MIRU Nordic #3. Pull BPV. Load hole with 9.6 ppg KWF. Set BPV. ND tree. A SBHP on 7/2/08 measured 2809 psi at mid perf which calculates to be 8.8 ppg KWF (9.2 ppg w/ 125 psi overbalance.). There is currently an IBP set at 7865' MD in the tubing tail which has passed a 2500 psi pressure test and also a drawdown test. 3. NU BOPE. Set blanking plug. Pressure test BOPS to 250/3000 psi The MASP assuming a gradient of 0.1 psi/ft is 2194 psi. 4. Pull BPV & blanking plug, pu113 ''/z" tubing. 5. RU E-line and run both USIT and caliper logs down to 7690' MD. (Just above the PBR) a. Decision depth to cut & pu117" casing or whether to run inner string of 5 ''/z" casing. 6. If Cut & Pull: a. RIH w/ multi-string cutter and cut 7" casing mid joint at determined depth. Establish casing x OA circulation. b. ND BOP and remove tubing head. Set stack back on casing head, NU BOP and test below blinds. c. MU spear and POOH laying down 7" casing. d. RIH w/ casing backoff tool, straddle 2"d connection below the cut and backoff 7" casing. e. RIH w/ spear and grab fish. f. MU new 7" BTCM L-80 casing, RIH and MU connection downhole. PT casing to 3000 psi. g. ND BOP, rough cut 7" casing, land 7" casing on slips and make fmal cut w/ Wachs cutter. h. Install packoffs and NU tubing head. NU BOP stack and test below blinds to 250/3000 psi. 7. If Inner String_of 5 '/z" casin ig s ran_ a. ND BOP and remove tubing head. Install new casing spool for 5 '/z" casing. NU BOP and test below blinds to 250/3000 psi. b. RIH w/ 5 %2" BTCM casing w/ seal assembly and stab into PBR. c. ND BOP, rough cut 5 'h" casing, land 5 '/z" casing on slips and make fmal cut w/ Wachs cutter. Install packoffs and NU tubing head. NU BOP stack and test below blinds to 250/3000 psi. 8. RIH w/ 3 'h" completion, stab into SBE/PBR, land tubing, PT tubing and IA, shear the SOV. 9. Set two-way check. ND BOPE. NU tree and pressure test 10. Freeze protect IA with diesel, pull two-way check, set BPV and RDMO workover rig Post-Rid Work 1. Pull BPV 2. Replace SOV in GLM #1 with DV. 3. If 5 '/z" casing was run, shift sliding sleeve open and load OA with diesel for freeze protect. 4. Bail CaCO3 and pull IBP 5. Return to injection. Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Tuesday, December 09, 2008 4:23 PM To: Maunder, Thomas E (DOA) Subject: RE: 1 D-07 (179-112) Attachments: 1D-07 Inj. RWO #2, Cut & Pull Csg.doc; 1 D-07 RWO #2 Proposed Schematic (Plan B).pdf Tom, I've been working on this well the past week and tweaking the procedure a little. Yes, we will set a RBP as a junk catcher in this well for the cut & pull procedure. I'm hoping this is the route we take as I don't really want to run the inner casing string. I just finished the draft procedure and modified the proposed completion for Plan B just a little. See attached: Give me a holler w/any questions. Thanks! ,7. Brett 2'acker ~flri~ng ~ ZUelCs Mlorkover Engineer `Work# (907) 265-6845 Cell# (907) 23D-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 09, 2008 3:16 PM To: Packer, Brett B Subject: iD-07 (179-112) Brett, 1 am reviewing the workover procedure for this well. If you do have to cut and pull, is it planned to put a shallow RBP in the 7" casing with sand on top as a "junk catcher" to protect the deeper portions of the well? BP at Prudhoe does a lot of these operations and that appears to be their standard practice. That also establishes 2 mechanical barriers between surface and the reservoir. Knock on wood, so far I am not aware of them having any issues cleaning off and recovering their casing bridge plugs. I look forward to your reply. Tom Maunder, PE AOGCC 12/10/2008 Rig Work RU, Kill Well, and Pull Tubing 1. Verify Application for Sundry Approval from AOGCC. 2. MIRU. Verify that pre-rig work has been completed. Rig up hardline and flowback tanks. Ensure rig is centered over the well. Hold pre-workover safety meeting 3. Pull BPV. Circulate approx 270 bbls 9.6 ppg NaCI brine down the tubing, through the GLM taking returns up the annulus unti19.6 ppg brine is returning at surface. Close the annular valve. Record SITP and SICP, confirm well is dead. If not, calculate kill weight fluid, weight up, and circulate hole full of kill weight fluid. • An IBP is set at7865' MD in the tubing tail below the bottom FHL packer which should isolate the well from the formation. A SBHP run on 7/2/08 indicated a pressure of 2809 psi at mid perf (6145' TIED) which equates to 8.8 ppg, so 9.6 ppg brine should be adequate to kill this well. 4. Insta113" H-BPV. Take a picture of the tree orientation for future reference. Make alignment marks on the tree, tubing head, casing head, and adaptor so they can be put back in the same configuration. ND and inspect tree. 5. Inspect lift threads in tubing hanger for damage (3 ''/2" EUE top connection). Install test dart in the HP- BPV. NU 11", SM BOP w/ 2 sets of 3 'h" pipe rams. Function & PT BOPE to 250/3200 psi, PT annular to 250/3500 psi. 3~~C ~ \~®C' ~ -~~ ~?~ i3~t~ • Maximum anticipated surface pressure (HASP) is estimated to be 2194 psi based upon the SBHP on 7/2/08 and using a 0.1 psi/ft gradient. (Call AOGCC 24 hours prior to testing at 659-2714 or pager 659-3607.) 6. Pull test dart &BPV w/ a dry rod. Screw into the tubing hanger with a 3 '/z" EUE landing joint and mark the pipe at the rotary table. BOLDS's on the tubing hanger. Un-land tubing hanger and pull to the floor. Measure and record the distance from the hanger to the mark on the landing joint. Lay down the hanger, etc. 7. POOH standing back the 3 %" tubing, removing all jewelry. • Max allowable pull is 166K lbs, 80% of the 3 % " 9.3# L-80 EUE tubing tension rating. • String P/U wt was 9.iK lbs., S/O wt was 73K lbs with a block wt. of 35K Ibs prior to setting the FHL packer on the previous workover when landed in 9.6 ppg brine. • Strap the 3 % "tubing. • Have all downhole equipment that leaves location NORM tested. Eauiument Disposition Tree Inspect & re-use Tubing Hanger & Adapter Inspect & re-use Tubing and Pup Joints Re-use Gas Lift Mandrel Re-install SOV and re-use DS nipple Re-use Seal Assembly Inspect, redress, and re-use. ESP Equipment%Power Cable Inspect/Centrilift to take possession of equipment for teardown. Penetrators Junk Cable Clamps Re-use if possible • • Run ZISIT and Caliper logs. Determine Leak Depth. Cut & Pull 7" Casing 1. RU E-line: a. RIH w/ USIT and evaluate 7" casing from 7690' to surface. b. RIH w/ PDS 7" casing caliper and GR/CCL memory tools and log 7" casing from 7690' to surface. c. Evaluate logs and determine cement top, casing condition, and depth to cut 7" casing. 2. RIH w/ RBP, (13) 4'/a" drill collars, and 7" retrievamatic test packer on 3 ''/z" tubing to 7650' RKB. Set RBP and release from packer. POOH one joint and set test packer. PT RBP to 2500 psi. Bleed OA to 0 psi. PT backside to 2500 psi. Monitor OA pressure to verify leak to OA_ .Release test packer and pull up hole in 1000' increments at first to isolate the casing leak to within'S' top and bottom. Leak is expected to be at 185' MD. 3. From the log evaluation, if it is determined that the casing can be cut and pulled above the top of cement, then proceed with Plan A in Step 4a, otherwise, if 5 YZ" casing is to be run, RIH w! RBP retrieving head on 3 '/z" tubing, release RBP and POOH standing back tubing, lay dawn test packer and RBP. Proceed with Plan B in Step 4b. 4a. Plan A: Cut. Pulh and Replace Bad 7" Casing. i. Ensure OA pressure is 0 psi. ND BOP and remove tubing head. MU DSA (11" SM x 11" 3M), set stack back on casing head and NU BOP. Changeout lower rams to 7", Set test plug in casing head. Test below blinds and lower 7" rants to 250/3200 psi. Pull test plug. (Call AOGCC 24 hours prior to testing at 659-2714 or pager 659-3607.) Three barriers are in place: The IBP set at 7865 ' MD has been tested to 2500 psi and passed a drawdown test, the RBP set at 7650' has_been tested to 2500 psi, and The RBP set in Step #I at 7650' RKB will have been tested to 2500 psi, the 9.6 ppg fluid is well above KWF that is expected to be 8.8 ppg; the well passed a CMIT IA x OA indicating the packer is good. MASP = 2194 psi. ii. RIH w/ 5 ''/z" OD multi-string cutter dressed for 7" casing on 3.5" IF drillpipe. Perform torque .checks. After locating collar below wf blades extended by pump, cut 7" casing mid joint @ depth determined by US[T/caliper logs. iii. Establish 7" casing x OA circulation & pump until returns are clean. iv. MU spear packoff for 7" casing, 5 '/4" OD Itco spear for 7" casing, spear extension, and spear top sub on 3 ''/z" IF drillpipe. Engage casing and pull casing and emergency slips to the rig floor. Lay down spear and ls` joint of 7" casing. POOH laying down 7" casing and number joints for later identification during inspection. • Strap and tally 7" casing. • Make notes of pipe condition, contact David Newman /Randy Barnes at 659-7869 (NSK Chem & Corr Monitoring) for inspection of casing. v. RIH w/ 7" Baker casing backoff tool on 3 '/z" IF drillpipe. Straddle the 2"d connection below the cut. Pressure cycle the tool until the 7" BTC connection turns freely. POOH w/ backoff tool. vi. RIH w/ 5 '/a" OD Itco spear for 7" casing, 5 '/4" spear extension, 8" OD spear stop sub, 6 '/<" OD Bowen bumper jars, and 3 '/z" drillpipe. Engage 7" casing stub. Apply left. hand torque if necessary to free the casing stub. POOH and lay down casing stub. vii. MU 8 '/z" OD line up guide on the bottom of the new 7" casing. RIH w/ new 7" 26# L-80 BTC- Mod casing. Tag existing casing, reverse circulate corrosion inhibited 9.6 ppg brine (1% by s _ ~ volume Baker Petrolite CRW-132) and MU connection downhole. PT casing to 500 psi. ~ MU torque for the BTC-Mod connection is usually determined by making up the first 15 joints to the makeup mark. Since this cut may be rather shallow (less than 15 joints), use the average torque value for the joints up until the connection is to be made. (Avg. make-up torque on 7" casing for 2A-OS workover was 8, 000 ft-Ibs) viii. ND BOP and raise stack. Rough cut 7" casing. LD cutoff 7" casing. Set BOP stack on traveling stump. Land 7" casing on slips w/ 40,000 lbs tension. RU Wachs cutter and make fmal cut on 7" casing. Insta117" packoff. NU tubing head. ix. NU BOP stack on tubing head. Changeout lower rams to 3 ''/z", install test plug in tubing head, test BOP below blinds and lower rams to 250/3200 psi. x. RIH w/ RBP retrieving head on 3 '/z" tubing, circulate hole clean, release RBP and POOH standing back tubing, lay down RBP. Skip ahead to running the completion. 4b. Plan B: Run Inner String of 5 %:" BTCM Casing. i. Ensure OA pressure is 0 psi. ND BOP and remove tubing head. Install 11" 3K top x btm, Type S-3, 5'/z" casing head. MU DSA (11" SM x ll" 3M), set stack on new casing head and NU BOP. Changeout lower rams to 5 'h". Install test plug in new casing head. Test below blinds and lower 5 %2" rams to 250/3200 psi. (Call AOGCC 24 hours prior to testing at 659-2714 or pager 659-3607.) Two barriers are in place: The IBP set at 7865' MD tested good to 2500 psi and passed a drawdown test, and The RBP set in Step #1 at 7650' RKB will have been tested to 2500 psi, the 9.6 ppg fluid is well above KWF that is expected to be 8.8 ppg; the well passed a OMIT IA x OA indicating the packer is good. MASP = 2194 psi. ii. MU and RIH w/ the seal assembly and sealbore extension (items 1 thru 4 in Table #1), leave this assembly in the slips. iii. PU ZXP assembly (Table #1, item 5) which has the C-2 Running Tool (Table #1, item 6) engaged into it. iv. MU inner string components (items 9 thru 16 in Table #2) to running string sticking out below the ZXP.. v. Stab inner string into the SBE. MU ZXP to the SBE. Table #1: ZXP packer, Sealbore Extension, and seal assembly Approx OD Drift ID Item Descri tion len th (ft) (in) in) (in Seal Assembly for existing 80-40 PBR, 10' long, 10 1 EUE 8rd Mod Box x'h muleshoe down. 2 Crossover'Joint, 5" LTC box x 3 '/2" EUE 8rd in 6 Baker 80-40 Sealbore Extension, 17' long, 5" LTC 17 5.87 2.980 3 pin x pin 4 Crossover Joint, 5" BTC in x 5" LTC box 6 ZXP Packer w/ hold-downs and 10' tie-back 19 4.400 5 sleeve, 5" x 7", C-2 Profile, 5" BTCM box down Items Below are Retrieved 5" C-2 Running Tool w/ Rotating Dog Sub and 11.57' 6 Hydraulic Pusher Tool, 3 ''/z" EUE Box x 2'/8" EUE above - - 1.995 Box to connect to Inner String ZXP 7 Pup Joint, 3 '/2" EUE Box x Pin 6 4.50 2.867 2.992 8 3 'h" EUE tubin to Surface XXXX 4.50 2.867 2.992 Table #2: Inner Strin Com onents Item Descri tion Approx length ) OD in ID in 9 Guide Nozzle, 2 '/4" ACME Box 0.47 2.780 0.690 10 Orifice Back Pressure Valve, 2 '/4" SP ACME Box x Pin 1.50 3.000 0.990 11 Ball Seat Sub, 2'/8" EUE Box x 2'/4" SP Pin 0.34 3.680 1.280 12 C-2 Running Tool w/ Sleeve Packoff - - - 13 Hydraulic Pusher Tool - - - vi. RIH w/ ZXP, SBE, and seal assembly at 30 ft/min. Hole conditions may warrant a different trip speed, consult w/ Drilling Foreman and/or BOT rep on location. vii. Locate existing PBR, load the well with 270 bbls corrosion inhibited brine (l% by volume Baker Petrolite CRW-132), drop ball and allow time to fall, cycle chazge pump to verify ball on seat. viii. Stab into PBR. Allow ball to re-seat. Pressure up to;2000 psi to activate the pusher tool for setting the ZXP, continue slowly pressuring up to 3500 psi to shear the ball seat sub. Bleed alt to 0 psi and rotate 15 turns to release the C-2 running tool. Table #3: Pusher Tool Pressure Ranges Shear Pressure Lower limit of sheaz ran a Upper limit of sheaz ran e Pusher Tool Activation 1974 psi 1678 psi --2270 psi Sheaz Ball Seat 3500 psi. ix. POOH standing back 3 '/~" tubing. Lay down C-2 running tool. x. MU and RIH w/'the following 5 ''/z" casing: a. 5" x 7" tie-back seal assembly (4.36" ID) b. X-over sub, 5 'h" BTCM box x 5" pin c. 5 '/z" BTCM casing to surface. xi. Locate tie-back sleeve`while slowly cycling charge pump, look for pressure increase as seals engage. Stop circulation and fully locate casing, mazk pipe at rig floor, and pull seals out of tie-back sleeve. Close the annulaz and reverse circulate 20 bbls diesel down the 5 '/z" x 7" annulus for freeze protect. Strip through the bag and fully locate 5 '/2" casing. Drain and ND BOP stack, raise stack and rough cut 5 YZ" casing. LD cutoff 5 '/z" casing. Set BOP stack on traveling stump. Land 5 ''/z" casing on slips w/ 40,000 Ibs tension (Type SB-3-N-L slips). RU Wachs cutter and make final cut on 5 '/z" casing. Insta115 ''/2" Type YB packoff. NU tubing head. xii. NU BOP stack on tubing head. Changeout lower rams to 3 'h", install test plug in tubing head, test BOP below blinds and lower rams to 250/3200 psi. xiii. Freeze protect the OOA above the leak. Open the OOA valve (7" x 10'/4" annulus), pump diesel down the OA (5 '/z" x 7" annulus) through the casing leak, taking returns out the OOA until diesel returns at surface. If leak in the 7" is at 185' as suspected, it should take <5 bbls diesel. Run & Set New Gas Lift Completion • • Drift and tally a113 % ", 9.3 ppf, L-80, 8rd EUE-Mod tubing and pups below the 2.875" nipple to 2.867 ". Above the 2.875 "nipple, drift and tally all tubing and pups to 2.91 ". • Record OD's and ID's of all auxiliary equipment on tubing detail. • Ensure seal rings are in place and replace any damaged seal rings as needed. • Apply Jet Lube Run-N--Seal dope sparingly on both the pin and box ends of tubing. • Recommended torque is 2240 ft-Ibs (max: 2800 ft-Ibs, min: 1680 ft-Ibs). These torque values are 70% of the un-modified 3 %z " 8rd EUE torque due to the AB-Mod seal ring... • Proper makeup occurs when the bottom of the pin makeup mark is flush with the top of the collar. Make up the just IS joints and determine an m~erage znal.e up torque to use otz subsequent joints. • Verb that the rig is centered over the well prior to running the completion. RIH w/ the following_3 'h", 9.3#, L-80 8rd EUE-Mod gas lift completion as follows: a) 10' Baker PBR locating seal assembly. (If S % "casing was run, use a 1 S' seal assembly w/fluted no-go spaced out to locate in the S %z " x S "crossover sub, see Diagram #1 in the appendix) b) 1 joint 3 ''/z", 9.3#, EUE 8rd w/ SCC tubing. c) Camco 3 '/z" x 1 ''/2" MMM GLM w/ 6' handling pups and SOV (1500 psi csg ~ tbg differential) installed @ 7643' MD. (If S % "casing was run, use a 3 % " x 1 " KBG-2-9) d) 3 'h", 9.3#, 8rd EUE-Mod tubing. e) 2.875" `DS' Nipple at +/- 500' MD. f) 3 'h", 9.3#, 8rd EUE-Mod tubing to surface. 2. Finish TIH w/ 3 '/~" completion. 3. Sting seal assembly into the SBE while slowly cycling charge pump, look for pressure increase as seals engage. Space out approximately 2' from fully located, mark the pipe, and pull seals out of the SBE. 4. Reverse circulate the well full (270 bbls) of corrosion inhibited 9.6 ppg brine (1% by volume Baker Petrolite CRW-132). 5. Space out the fmal completion and ensure at least one full joint of tubing immediately below the tubing hanger. 6. MU tubing hanger and land. RILDS. Finish Completion 7. RU chart recorder to IA. With the annulus open, PT tubing to 3000 psi for 15 min. Monitor annulus for returns. Bleed off tubing pressure to 2250 psi. While holding the tubing pressure at 2250 psi, PT the IA to 3000 psi for 30 min. Bleed IA to 0 psi, then bleed tubing to 0 psi. Ramp up the IA pressure to shear the SOV. 8. Pull the landing joint. Install two-way check. ND BOP Stack. • 9. NU tubing head adapter and tree.. Ensure proper orientation of the tree using alignment marks on the wellhead and picture taken prior to ND. If needed, contact the Drillsite Operator or Drillsited Lead to verify alignment prior to NU. Pressure test tree to 250/5000 psi. Test packoff to 5000 psi. Pull two-way check. 10. Freeze protect the well by pumping 80 bbls diesel down the IA taking returns up the tubing. Put the tubing and IA in connection and allow sufficient time for the fluids to U-tube. 11. Set 3" H-BPV in tubing hanger profile. 12. RDMO. Turn well over to operations via handover form. Post-Rig Work: 1. Reset well house and floor kit. Re-attach flowline. Pull BPV. 2. RU Slickline and pull SOV from GLM #1 and replace w/ DV. Bail CaC03 off top of IBP @ 7865' MD. Pu11 IBP. ~~4 l ~T~4C~~l~NrS~ 1. Schematics 2. Existin YVellhead a. T~etco 20" x 103/ " x 7s/ " x ~~~" Wellhead b. Tree/Tz.~bing Head Adaptor c. Multibowl Tubing Head d. I'etco X118 228A Hanger tiff;/MB 222 Redzrcef° Bushing e. Casing Hanger / Packoff Downhole Equipment f. ESP Equiprraenl 3. Tallies cr. Tifbing b. I iners c. Casing ~. Dir. Survey 5. Pf°oposed Completion 6. ~~ecial Tool Diaar•anas 7. ESP Best Practices a. ABC's of Pulling Submersible Equipment b. Recommended Practices (DIFA) • Well: 1 D-07 API: 50-029-20430-00 ~AC~~"ljjjjS Field: Kuparuk PTD: 179-112 2008 RWO PROPOSED COMPLETION Plan A: Cut & Pull 7" Casing WELLHEAD Lift threads: 3'/2' BTC BPV: 3" CIW H Model: McEvoy Gen 1 Retro'd to Gen 4 w U r 3 z U i~ 3 Z CONDUCTOR 16", 65 ppf, H-40 SURFACE CASING 10-3/4", 45.5 ppf, K-55 PRODUCTION CASING 7", 26 ppf, L-80 to XXX' RKB (new this workover) 7", 26 ppf, K-55 TUBING 3%", 9.3 ppf, L-80, 8rd EUE Mod, 0' - 7796' 3-1/2", 9.2 ppf, J-55, BTC, 7796' - 7879' COMPLETION A: Landing Nipple: 2.875" DS profile 500' M D B: Gas Lift Mandrel: 1-1 /2" MMM @ 7643' RKB. C: PBR, stack packer @ 7697' RKB D: Nipple: 3'/" with 2.813" DS profile @ 7754' RKB E: Poorboy overshot @ 7791' RKB. F: Nipple: 3'/2' with 2.75" D profile @ 7878' RKB. PERFS 7948' - 8025', 4 spf Last Tag: 08/03/06 Tag Depth: 8070' RKB Fill: 45' rathole TD: 8550' RKB Last Updated: 4-Dec-08 Updated by: JBP L~ Well: 1 D-07 API: 50-029-20430-00 ~` !~+~1"1C~C'~"11~~I~1S Field: Kuparuk PTD: 179-112 2008 RWO PROPOSED COMPLETION Plan B: Run Inner String of 5-1/2" Casing WELLHEAD Lift threads: 3'/2' BTC BPV: 3" CIW H Model: McEvoy Gen 1 Retro'd to Gen 4 CONDUCTOR 16", 65 ppf, H-40 NEW COMPLETION A: Landing Nipple: 2.875" DS profile 500' MD. B: Gas Lift Mandrel: 1-1/2" MMM @ 7643' RKB. SURFACE CASING 10-3/4", 45.5 ppf, K-55 PRODUCTION CASING 7", 26 ppf, K-55 INTERMEDIATE CASING 5-1 /2", 15.5 ppf, L-80 to 7697' RKB (new this workover) TUBING 3'/i', 9.3 ppf, L-80, 8rd EUE Mod, 0' - XXXX' 3-1/2", 9.2 ppf, J-55, BTC, 7796' - 7879' PERFS 7948' - 8025', 4 spf C: 5-1 /2" x 5" crossover. D: 5" x 10' tie-back sleeve. E: ZXP Packer E F: SBE G: 5" x 3-1 /2" crossover H: PBR I: FHL packer @ 7697' RKB i J: Nipple: 3'/Z' with 2.813" DS profile @ 7754' RKB K: Poorboy overshot @ 7791' RKB. L: FHL packer @ 7845' RKB. ~ M• NinnlP~ 3'/~' with ? 75" D nrnfilP (c~ Last Tag: 08/03/06 Tag Depth: 8070' RKB Fill: 45' rathole TD: 8550' RKB Last Updated: 4-Dec-08 Updated by: JBP Well: 1 D-07 API: 50-029-20430-00 Field: Kuparuk PTD: 179-112 2d'Q8 RWO PROPOSED COMPLETION Plan B: Rlun Inner String of 5-1/2" Casing WELLHEAD Lift threads: 3'/" BTC BPV: 3" CIW H Model: McEvoy Gen 1 Retro'd to Gen 4 CONDUCTOR 16", 65 ppf, H-40 SURFACE CASING 10-3/4", 45.5 ppf, K-55 PRODUCTION CASING 7", 26 ppf, K-55 INTERMEDIATE CASING 5-1/2", 15.5 ppf, L-80 to 7697' RKB (new this workover) TUBING 3'/i', 9.3 ppf, L-80, 8rd EUE Mod, 0' - ~CXX' 3-1/2", 9.2 ppf, J-55, BTC, 7796' - 7879' PERFS 7948' - 8025', 4 spf NEW COMPLETION A: Landing Nipple: 2.875" DS profile 500' MD. __ ~~~~ _T , _~:. B: Gas Lift Mandrel: 1-1 /2" MMM @ 7643' RKB. C: 5-1/2" x 3-1 /2" crossover w/ SBE, 4" I D D: CMU w/2.813" DS profile. PBR, stack packer @ 7697' RKB F: Nipple: 3'/2' with 2.813" DS profile 7754' RKB G: Po rboy overshot @ 7791' RKB. H: Nipple 3'/z' with 2.75" D profile @ 7878' R B. Last Tag: 08/03/ Tag Depth: 8070' F Fill: 45' rathole TD: 8550' RKB Last Updated: Updated by: • i ~~ h.~., -- a~: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907J 245-8952 1] Production Profile 20,Sep~08 1G172 L2 1 BL/ EDE 50-029-2315871 2] Leak Detection - WLD 27 Aug-08 1 D-07 EDE 50-029-20430-00 gp~~ {{~~ ~, , f U~c c'~ - (-(a ~ l~gY,S ~O`~ 0~0 ~ 1~9yb Signed : Date : ,~ - ~~ ~ Print Name: ~ ~r~f-, ~A ~ 1 ~n,(~s~...L PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (9071245-88952 E-NIAa : ~ds~nv3~ar~aeCe.~s~e~or~rio .~s~rr WEesrrE : ~rv~~v,~es~m~3alac~.~~ /~ C:\Documents and Settings\Owner\Desktop\Transmit_Conom.doc :7 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 5, 2008 • ~~~ SEA 1 ~ [008 Alaska Oii & C~a~ ~~~s,~ ~~m~ission Ancl~a~age Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 ,~~ ~~P ~ ~ ~~~~ Anchorage, Alaska. 99501 s~mr Dear Commissioner: Attached is the Report of Sundry Well Operations for Kuparuk Well 1 D-07 (PTD# 179-112). The purpose of the workover was to pull all of the existing 3-1/2" tubing string, upgrad to a 5000 psi tubing head for MI injection, and run a new L-80 tubing string in the well. All of this work went as planned. Since the rig left location, though, we have not been able to perform a MIT on the IA. It now communicates with the OA. We have been able to Combo MIT the IAxOA. Submittal of the 10-404 was being held until the post rig work was complete and the well was ready for injection. After discussing the situation with Mr. Tom Maunder, it was decided to submit the 10- 404 for the work that has been performed to date. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gober Wells Engineer CPAI Drilling and Wells STATE OF ALASKA • C ~ REPORT OF SUNDRYSWELL OPEIRATIONSE-`~ ~ ~ ~~08 1. O erations Performed: Abandon p ^ Repair Well ^ Plug Perforations ^ ~C~!:~d a ad Stimulate ~~~ ~C~t . ~ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ ~~aS S ~ ~ and tubing `,, Waiver Time ~~~ 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 ^ 179-112 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20430-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' - 1 D-07 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8550' feet true vertical 6600' feet Plugs (measured) 8075' Effective Depth measured 8076' feet Junk (measured) true vertical 6215' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 3035' 10-3/4" 3136' 2639' PRODUCTION 8321' 7" 8422' 6496' Perforation depth: Measured depth: 7948'-8025' true vertical depth: 6114'-6175' Tubing (size grade and measured depth) 3-1 /2" L-80 7798' MD y,~~ • uL.VJ f,,•-c, fir- ~"~-~ ~J,~J}--- /ij.~~/J/,/. ~ -.,! ~. /- f ~/r~~/ 1 , , , , . ~ l S (~ Packers & SSSV (type & measured depth) pkr-- 2 BAKER'FHL' pkr- 7711, 7845 Camco DS nipple @ 488' 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 2883 Subsequent to operation SI - -- 14. Attachments 15. Well Class after work: Copies of Logs. and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG Q 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: 308-232 contact Howard Gober @ 263-4220 Printed Name Howard Gober Title ~~ Wells Engineer Signature ~ Phone: 265-6471 Date ~/S~VC~ P2 red b Sharon Allsu Dr ke 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ ~~~ ~ L ,~ ~• s•as Submit Original Only 1 D-07 Pre-Rig and Post-Rig Well Work DATE SUMMARY 4/4/08 PRE-RWO, T -POT (PASS~T - PPPOT (PASSED), IC -POT (PASSE , IC - PPPOT (PASSED), FUNCTION TEST LDS'S 7/2/08 DRIFT FRAC SLEEVE AT 1822' RKB W/ 2.2" DRIFT. HANG UP SLIGHTLY PULLING UP THROUGH IT. TAG 8057' SLM. OBTAIN SAMPLE OF RUBBERY SCHMOO. TURN WELL OVER TO E-LINE. 7/2/08 RAN SBHP SURVEY AND SET 2 1/8" IBP. RESULTS: PRESSURE IN LUBRICATOR IS 322 PSI. TAGGED PBTD AT 8049'. SURVEY STOP AT 7987' 2809.1 PSI, 138.4 DEG F). GRADIENT STOP AT 7861' (2763 PSIA, 141.9 DEG F). MIT-IA PASSED. SET 2 1/8" IBP WITH MID-ELEMENT AT 7865'. 7/2/08 MIT-IA (PASSED ). 7/2/08 PT IBP TO 1500#; GOOD. DRAW DOWN TO ZERO; GOOD. DUMP BAIL ~3' OF CaCO3 ON TOP OF IBP. IN PROGRESS. 7/3/08 ELINE UNIT 2320 STANDBY FOR SLICKLINE TO PULL DGLV. IN PROGRESS. 7/3/08 DUMP BAIL CaCO3 ON TOP OF IBP AT 7858' ELM. ~4' OF CaCO3 ON TOP OF IBP. PULL DGLV FROM 7781' RKB. PART WIRE AT FRAC SLEEVE AT 1822' RKB. TURN WELL OVER TO SLU #696 TO FISH. 7/3/08 ATTEMPT TO PULL FRAC SLEEVE @ 1822' RKB.RECOVERED LOST TOOLSTRING WITH DV ON KOT FROM 7787' SLM.""OPEN POCKET*" 7/4/08 RAN SINGLE STRAND STRING SHOT AND 2 1/8" ER CHEMICAL CUTTER. STRINGSHOT TUBING FROM 7790-7802'. CUT TUBING AT 7800'- MIDDLE OF FIRST FULL JOINT BELOW BOTTOM GLM. DIFFICULTY PULLING CHEMICAL CUTTER ANCHORS BACK THROUGH SSSV FRAC SLEEVE. COLLAR LOG INDICATES FRAC SLEEVE IS PULLED OUT ABOVE SSSV. ALL CENTRALIZERS SPRINGS ON BOTTOM ADUSTABLE CENTRALIZER LEFT IN HOLE. VALVE CREW TO INSTALL BPV TONIGHT. 8/9/08 REPLACED 1.5" 1500# CSG X TBG SHEARED SOV FROM 7643' RKB WITH 1.5" DV. MITT PASS. PULLED 2.81" RHC PLUG BODY ON CR LOCK FROM 7754' RKB. MITIA FAIL. IN PROGRESS 8/10/08 MITIA FAILED. PULLED 1.5" DV FROM STA #1. CMIT FAILED. RESET DV STA #1. TURN WELL OVER TO DHD TO TROUBLESHOOT. 8/11/08 T POT (PASSED), T PPPOT (PASSED). IC POT(PASSED), IC PPPOT (PASSED), OA POT (PASSED), OA PPPOT(FAILED). RE-ENERGIZED OC PO. MITT (PASSED, MITIA (INCONCLUSIVE). - IN PROGRESS 8/12/08 (AC EVAL), MITIA -INCONCLUSIVE - IN PROGRESS 8/13/08 (AC EVAL) MITIA -FAILED; 8/20/08 IA X OA LLR 1 GPM (a7 3000 PSI, CMIT IA X OA -PASSED (AC EVAL) 8/27/08 RAN TECWEL LEAK DETECT LOG TO DETERMINE SOURCE OF IA x OA COMMUNICATION. RESULTS: PROBABLE LEAK FOUND AT 185' RKB. LEAK DE~ ACTIVATED AT THIS DEPTH BY BLEEDING IA TO 1500 PSI AND RE- ACTIVATED BY PRESSURING UP TO 2500 PSt. WORKOVER PROCEDURE CALLED FOR SETTING STORM PACKER AT +/- 200'. LIKELY SET 2 STANDS IN AT 185'. • C7 ConocoPhillips Time Log & Summary ~.e,~~~ wzb ~~ma,rn9 Report Well Name: 1 D-07 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/6/2008 7:00:00 AM Rig Release: 7/10/2008 4:00:00 PM Time Logs _~ ' ---_ ------- ---- - --- Date From To bur S. Depth E Depth Phase Code 5ubcode T Comment 7/06/2008 24 hr Summary MIRU and Accept Nordic Rig 3 @ 07:00 hrs on 7-6-08 pull BPV and Circ well w/ 9.6 ppg Brine. Set BPV, ND Tree and NU BOPE. Test BOPE @ 250/3,000 psi. 24 hr Notice was given to AOGCC @ 17:30 on 7-5-08 and Witness of test was waived b Bob Noble 17:35 hrs on 7-5-08. 06:00 07:00 1.00 MIRU MOVE DMOB P Move Nordic Rig 3 off 1D-113. Hang tree in cellar. Move rig f/1 D-113 to 1 D-07. Berm up cellar. Nordic Ri 3 was acce ted 07:00 hrs on 7-6-08. 07:00 08:00 1.00 COMPZ MOVE RURD P Spot cuttings box & boiler blow down box & RU hard line. 08:00 09:00 1.00 COMPZ RPCOM RURD P Load out ESP Spool & Spooler. 09:00 10:30 1.50 COMPZ WELCTL NUND P PU lubricator PuU BPV 10:30 11:00 0.50 COMPZ RPCOM -RURD P RU, circulation hoses, Test to 2500 si. 11:00 12:30 1.50 COMPZ RPCOM OTHR P Load Pits w/9.6 ppg KWF. 12:30 14:30 2.00 COMPZ RPCOM CIRC P Start well kill. IA pressure = 210 psi Tubing =0 psi OA = 60 psi. Bled OA pressure to 0. Pump 9.6 ppg KWF .Initial circ. press. 320 @ 3 BPM. Increased to 4 BPM 380 psi. Pumped 280 bbls FCP = 520 psi @ 4BPM SD monitor well, static. 14:30 17:30 3.00 COMPZ WELCTL NUND P Set HP-BPV. ND r 17:30 21:30 4.00 COMPZ WELCTL NUND P NU BOPE C/O LPR to 3.5 21:30 00:00 2.50 COMPZ WELCTL BOPE P Test BOP 250/3 000 si 7/07/2008 Continue to Test BOPE, BOLDS, Unland tbg hanger and Pull hanger to rig floor. Circ 1.5 Hole vol. Pooh la in down 3 1/2 com letion. Call out for TBG dress off tools. 00:00 02:30 2.50 COMPZ WELCTL BOPE P Continue to Test BOPE @ 250/3,000 psi and Annular @ 250/2,500 psi. Koomey Drawdown 3,000 psi - 1,950 psi After. 200 psi in 12 sec. 3,000 psi 1 minute 33 sec. 4 Bottles @ 2,150 psi. 24 hr Notice was given to AOGCC @ 17:30 on 7-5-08 and Witness of test was waived by Bob Noble @ 17:35 hrs on 7-5-08. 02:30 04:30 2.00 COMPZ RPCOM OTHR P Pull Test Dart, MU Landing jt. and BOLDS. ~_ Page 1 trf ~ • • Time Logs - - __ --_. Date From To Dur _ S De th E. De th Phase Code Subcode T Comment _ 04:30 05:00 _ 0.50 7,800 7,770 COMPZ RPCOM OTHR P Unland hanger @ 75k and Pulf up to 130k pull cut in two. Pull hanger to ri floor w/ 110k u wt. 05:00 07:00 2.00 7,770 7,700 COMPZ RPCOM CIRC P Circ. 350 bbls @ 6 bpm W! 770 psi w/ no as. Well static. 07:00 11:00 4.00 7,700 6,020 COMPZ RPCOM PULD P POOH with com letion la ring down 3 / " s. spooling control line for SSSV. 11:00 12:30 1.50 6,020 6,020 COMPZ RPCOM PULD P Break out SSSV, with stuck frac sleeve. RD control lines ooler. 12:30 22:00 9.50 6,020 0 COMPZ RPCOM PULD P Continue POOH with completion laying down 3 1/2"tubing, 7 - GLMs, and Cut TBG jt. = 17.93'. Cut was flared to 3.75" OD. 22:00 00:00 2.00 0 COMPZ RPCOM WOEQ XP Call out for 3 1/2 TBG dress off tools and wait for delive from Deadhorse. 7/08/2008 Prepare to Rih w/ 3 1/2 Dress off tools. MU BHA and Rih PU 3 1/2 9.3# eue TBG and wash down to 7,792' and dress off 3 1/2 tbg stub. Pooh to 7,522' and install Storm pkr and Rih to 165' and set. PT @ 1,800 psi. Pooh w/setting tool and ND BOPE. ND Tbg head and remove same. 7" csg grew, engage w/ spear and re land on emergency slips. Land @ 65k. Cut off fluted hanger w/ mech cutter. Dress and prepare stub for new tb s ool. 00:00 01:00 1.00 COMPZ FISH WOEO XP Load and Rack 10 - 4 3/4" Drill Collars. Wait for fishing tools to arrive. 01:00 02:30 1.50 0 340 COMPZ FISH PULD X Offload equipment and Bring to rig floor. MU and Rih w/ 6" OD x 3.563" ID sizin shoe w/inner dress off mill. 02:30 03:30 1.00 340 340 COMPZ FISH OTHR X Change over from DP equipment to 3 1/2 TBG E ui ment. 03:30 10:00 6.50 340 7,771 COMPZ FISH PULD X Rih w/ BHA #1 picking 3 1/2 L-80 tbg to 7,771'. 10:00 12:00 2.00 7,771 7,792 COMPZ FISH WASH X MU TD Gather parameters 107 up wt, 75k do wt, 90k Rot. wt w/ 2.5k free torque @ 40 rpm. Circ @ 6 bpm @ 840 psi. and wash down from 7,780' to 7,792'. 12:00 12:30 0.50 7,792 7,792 COMPZ FISH MILL X Dress up top of stub 7,792' 12:30 13:30 1.00 7,792 7,522 COMPZ FISH TRIP X Pooh from 7,792' to 7,522' 13:30 14:00 0.50 7,522 7,687 COMPZ RPCOM OTHR X MU Baker Storm Packer and Rih to 165' w/ tail @ 7,687'. Set Storm ~kr. Pooh f/ 165' w/ Retreivin head. 14:00 15:00 1.00 165 COMPZ RPCOM DHEQ P Test kr t 1 800 si d. OA is bled off, 0 si. 15:00 17:00 2.00 COMPZ RPCOM NUND P PJSM, ND BOPE. 17:00 00:00 7.00 COMPZ RPCOM NUND P Remove 11" 3 00 x ' S ool. 7" CSg Fluted hanger rose 18" above cs head. Made up spear and engaged 7" csg. Pulled up to 200k and raised csg 24". Installed emergency slips and re -landed 7" csg @ 65k on slips. Release spear and Pooh. RU watchs cutter and cut off fluted hanger and dress stub for cs ack off installation. _ ~s~~_~~ _ Page 2 csf ~ Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 7/09/2008 _ _ 24 hr Summary Install new tbg spool and pack off. NU BOPE and test pack off @ 3,400 psi for 30 minutes. Shell test BOPE 250/3,000. Rih to 165' and release Storm pkr. Pooh and lay down storm pkr and Dress off assy. MU and Rih w/ 3 1/2 Com letion. Circ corrosion inhibited 9.6 brine. 00:00 01:30 1.50 COMPZ RPCOM OTHR P Align TBG spool for MI gas injection and check Tree orientation w/ DSO 01:30 03:00 1.50 COMPZ RPCOM NUND P NU TBG S ool and BOPE. 03:00 04:00 1.00 COMPZ RPCOM SFEQ P Pump in J-Plastic and PT void between tbg spool and csg pack off to 3,400 si and hold for 30 minutes. 04:00 06:00 2.00 COMPZ RPCOM NUND P Finish NU BOPE and set Test plug. 06:00 09:00 3.00 COMPZ RPCOM SFEQ P Fill stack and shell test 250/3.000 psi. 24 hr notice was given @ 07:45 hrs on 7/7/08 for TBG replacement and Witness of test was waived by Bob Noble 07:50 hrs on 7/7/08. 09:00 10:30 1.50 0 165 COMPZ RPCOM PULD P Rih and retrieve Storm backer and Pooh and la down. 10:30 11:30 1.00 165 165 COMPZ RPCOM CIRC P CBU @ 6 bpm @ 880 psi 11:30 14:30 3.00 7,522 340 COMPZ RPCOM TRIP P Pooh from 7,522' MD 100k up wt, 75k do wt. 14:30 16:00 1.50 340 0 COMPZ RPCOM PULD P Change over to DP equipment and Pooh laying 10 - 4 3/4" OD DC's and Dress off ass . 16:00 17:00 1.00 0 COMPZ RPCOM OTHR P Change over to TBG equipment and clear tools from ri floor. 17:00 21:30 4.50 0 7,787 COMPZ RPCOM RCST P Held PJSM, Rih w/ 3 1/2 Completion 21:30 00:00 2.50 7,787 7,787 COMPZ RPCOM CIRC P RU and Circulate 130 bbls of 9.6 ppg brine w/ 1 % by vol. CRW 132, followed by 50 bbls of 9.6 ppg brine, followed by 13 bbls of 9.6 ppg brine w/ 1 % by vol. CRW 132, followed by 9.6 brine 3 b m 210 si. 7/10/2008 Locate stub and shear out overshot. Drop ball and rod, Pressure set FHL Pkr. Shear out PBR and Space out. Land hanger and RILDS. PT tbg and CSG to 2,500 psi and chart. Set TWC. Attend CPAI Safety Stand Down. ND BOPE and NU Tree. Test tree @ 250/5,000 psi. Pull TWC and Freeze protect well w/diesel. Set HBPV and Release Nordic Ri 3 16:00 hrs on 7-10-08. 00:00 00:30 0.50 7,787 7,800 COMPZ RPCOM PACK P Locate stub Ccil 7.792'. shear pins Ca) 15k, pack off pu to string wt., Drop ball and rod pressure up and set FHL packer 7,711' w/ to of PBR 7,697' 1,750 psi 95k up wt, 73k do wt. 00:30 01:30 1.00 7,800 COMPZ RPCOM HOSO P Space out and install 18' of pup jts, MU hanger and landing jt. Land completion w/ 2' of space out @ PBR w/ seals. RILDS. 01:30 04:00 2.50 COMPZ RPCOM DHEQ P RU to PT TBG and IA ~ 2,500 osi. PT TBG to 2,500 psi for 15 minutes w/ 50 psi loss. Bleed TBG to 1,750 psi and PT IA to 2,500 si w/ 250 si loss in 30 minutes. Dum TBG and shear out SOV @ 750 psi. RD test e ui ment. Page 3 cif 4 L ~~ '}CS` ~" ~~~ • Time Logs Date From To _ _Dur _ S. Depth E. De th Ph se Code Subcode _ T ___ _ _Comment 04:00 05:00 1.00 COMPZ RPCOM OTHR P Remove landing jt. and install TWC. 05:00 05:30 0.50 COMPZ RPCOM OTHR P Removing kill lines from BOPE 05:30 07:30 2.00 COMPZ RPCOM SFTY P CPAI Safety stand down 07:30 08:30 1.00 COMPZ RPCOM NUND P Continue to ND BOPE 08:30 10:00 1.50 COMPZ RPCOM NUND P Clean well head and NU Tree and Orient valves. 10:00 11:00 1.00 COMPZ RPCOM SFEQ P Test Tree 250/5,000 psi. 11:00 12:00 1.00 COMPZ RPCOM OTHR P Pull test dart, Pull BPV. 12:00 14:00 2.00 COMPZ RPCOM FRZP P Held PJSM, RU circ lines, PT Lines @ 2,000 psi and pump 110 bbls of diesel @ 1 bpm @ 100 psi ICP and 575 FCP. RD LRS. 14:00 15:00 1.00 COMPZ RPCOM OTHR P U tube for 1 hr allowing diesel to swa . RD Circ lines. 15:00 16:00 1.00 COMPZ RPCOM OTHR P Set BPV w/ 0 psi tbg and IA. 0 psi OA. Release Nordic Ria 3 no 16.02 hrs on 7!10!08 Page ~ ~f ~ - yy ~~~ KUP ~ 1 D-07 ~~~~~~t~(pSi ~ 1 , Well Attributes ` .. ... ~ ! Apl/ UWI ~30 ' O treltl Name W II Sntua Maximum Inelma[ron t-) KUPARUK RI NIT 48.50 TOIaI Ueptn (hkdi 8,550.0 ~~~ ~ Comment HZS ( .. N IPPL - O ppm) Date IAnnotadon iEnd Date KBKB-Ground~ ast WO: 7/10/2008 38.01 1/20 8 ~ ~ ig Release Date 10/30/1980 ~ ,. ,. ~~ ~~ ~ ~ _ _ _ {Annoation (Depth (RKB) End Date Annotation _ End Date ll Last Tag: ~ 8.070.0 8(32006 Rev Reas.. ~: GLV C/O, PULL BALUROD ( 8/23/2008 .. Casing Strings I Gasrng Lesenption ,4U jm( ID pn/ Top (Rh6) Set Depth {n... SM Uepth (7vUl {IL.. Wt (IOS/.. : grade Tuy c:onnectron I ~ ' I (CONDUCTOR 16 15.062 0.0 80.0 80.0 65.00 H-40~ - ~ SURFACE, 43,136 INJECTION, 7.60.1 - i-a IPERF, 7,94&6,025 -- PLUG, 6,075 Cement, 8,174 PRODUCTION, 0-6,423 rD, esso Casing Description IOD (in) ID (in) Top (RKB) Set Depth (R.. SM Depth (ND) (R.. YVt QW/... Grade Top Connection (SURFACE 1 103/4 9.794 0.0 3,136.0 2,638.4 45.50 K-55 Ceaing Description OD (in) ID (in) Top (RKB) Set Depth (R.. SM Depth (ND) (R.. Wt (Ibs/... Grade (Top Connection (PRODUCTION 7 i 6.151 ~ 0.0 8.422.0 6.495.7 26.00 K-55 i 7uhing Strings Tuning oes_ ikon oo n:,l io I:„I r.u In s~-I ovum plK... ~.I o rFm livoi In^NI wl i m~~lp sr.~d~ roe < ,«uo~ TUBING- a L~ _ i_ .. -.. ~ __ - _~_ _ ~_ Workover Completion Details Top (ttKB) (tern Descriptwn - root IfI irr 22.6 HANGER TUBING HANGER 2.99 487.5 NIPPLE Camce'DS' Nipple 3 1/2" x 2.875" _ 2.87 7,694.9 SEAL ASSY Seal Assembly Lopter wl 2'space out 2.99 Other In Hole (Wireline retrievab~ plugs, valves pumps, fish, etc.) iop Ih7cB( orz~,~v1~ ~ c`om„Kne a„~ L ~ to no7 8.075.0 PLUG _ b+/ F_ I1C% 5 bbl Class r;' Cc~~~ten1 v' f~ 1 ~.Orlp~ ~®rf01'81t10r18 I Top Btm (ND) (ND) Dens (RKB) (RKB) (RKB) (RNB) Type Zone Izho... Date Comment I 7,948.0 8,025.0 6,113.9 6,175.3 IPERF C-1, C-2, C-3, C-4, 4.0 6116/1997 Zero deg. Phasing ( 1D-07 -- Cement Sque6ze_s iop IttKNI . [itm (fucBl con Poo Descnpmn Gomnwut R.1740 r. 197.0 fi/1fi/19g7 ICmm~nt SOUeeze (TURING 3 1@ ~ 992 7,788.0 7.880.0 ~ ~fi.060.1~ ~ ~ 92n J-5s ~ arc Mandrel Details Set Depm i port Top (ND) valve Latch Size TRO Run i Stn (RKB) ~ (RKB) Make Model i OD linl I Type Type lin) (psi) ! Run Date ~I Comment 1D-07 (PTD 1791120) Report of ~ect IA x OA communication • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, September 01, 2008 5:09 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 D-07 (PTD 1791120) Report of suspect IA x OA communication Attachments: 1 D-07 schematic.pdf; 1 D-07 90 day TIO plot.jpg Tom & Jim, Page 1 of 1 Kuparuk produced wa~~r injPrt~~ ~ n_07 (PTD 1791120) has suspect IAxOA communication following the RWO. The well has not been on injection since the completion of the W an wi remain I until the production casing is repaired and a passing MITIA is obtainable. Prior to the WO, the well had a passing MITIA to 2500 psi. During the post rig work, Slickline was unable to obtain a passing MITIA. Initial diagnostics indicated suspect IAxOA communication. With the production casing having integrity prior to the WO, the inner casing packoffs were suspected since they were changed out by the rig. The packoff testing passed and a subsequent Tecwel LDL was run and identified a production casing leak @ 185'. The leak will be repaired prior to the well being returned to injection. The repair options are being discussed and the appropriate paperwork will be submitted when the path forward has been decided. Attached is a 90 day TIO plot and a schematic. Please note that the tubing pressure shown on the TIO plot is ~- water injection header pressure as the well has been SI since 06/25/08. «1 D-07 schematic.pdf» «1 D-07 90 day TIO plot.jpg» Please let me know if you have any questions. v h~ Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/10/2009 KRU 1 D-07 PTD 179-112 9/1/2008 TIO Pressures • • ~P ~\ ~onocoPhillips r~ \ - - ;Well Attributes - ------ ,.».I ,, , I --- - - -- API/UWI Field Name Well Status Maxf .... .__. .,, S0029204a0 IKUPARUK RIVER UNIT INJ ... i ,Comment H25 (ppm) Date Annotation End Data - - - ~ NIPPLE 0 7/1/2008 Last WO: 7/10/2008 ___ weu covet D-m, a/23nooe -.t e sn Am _ - scrrema~w-ncwal Annotation Depth (TtKB) End Date Annotation Last Tag: 8.070.0 8/3/2006 Rev Reason: GLV C/O. PULL BALL/ROD Casin Strin s Casing Description OD (in) ID (in) Top (ftKB) ' _ _ Set Depth (K... Set De CONDUCTOR 16 15.062 0.0 80.0 a -~! _ _, Casing Description OD (in) ID (in) Top (RKB) Set Depth (R... Set Dep ~~ SURFACE 103/4 9.794 0.0 3,138.0 2 a I Casing Description OD (In) ID (in) Top (RI(B) Set Depth (R... Set Dep `-' = I PRODUCTION 7 6.151 OA -__ 8.422.0 6 ' Tubing Strings - _ / ~ I sc - OD (i I Tub ng De pt TUBING- ~ 3 " ID (in) 'Top (tt.. Set Depth (ftK... Set Depth ITV 2.992 0.0 7,797.7 5.995. i ~ I WCrkO Vef c `, ~ .: ~ ___ Completron Details i 7op (RKB item De: ~'~ 22.6 HANGER I 487.5 NIPPLE 7,694.9 SEAL AS 7,697.3 PBR ~ 7,710.7 PACKER - '~- - 7,754.1 NIPPLE 7,790.8 OVERSH SURFACE, as'tas ~. - i ~' X.;;.~ Tubing Description C TUBING _ Com letion De , -' F Top (ftK8) Item Dea ~', - 7,838.0 --- --- - -~- SBR 7,845.0 PACKER t. --'7 _ --- _ _._ -_:~i 1 ~77 J f€ '1 F ' ~; i I _~ - . -: 4~ PACKER, 7,845 ~ -_ IPERF, 7.948-8.025 PLUG, 8,075 cement, e,n4 PRODUCTION, 0-8,422 TD. 8,550 x 2.8 /5" / 2' space out 1 D-07 Inelinatlon (°) 7otel Depth (ftK8) 48.50 8,550.0 around Distance (ft) Rig Release Date 38.01 10Y30/1980 I 8/23/2008 h (TVD) (ft.. Wt Irbsr... Gratla 7 op Connection 80.0 65.00 H-00 h (TVD) (R.. . Wt (Ibsl... Orade Top Connection ,638.4 45.50 K-55 h (ND) (tt.. . Wt (Ibs/... Oretle Top Connection ,495J 26.00 K-55 ___ D)IftKB)Wt (IbslR) Grade TopC ectlon 5 9.30 pt t t L 8C 3 1/2 2.999 17.7R8.0 I 7.880.0 I _ _6.060.1 ~ 9.20 I J-55 BTC Other In Hole (Wireline retrievabie_plugs, valves, pumper fish, Top (ftK8) Description comment _ - _ 8.075.0 PLUG ~'CMT PLUG. 5 bbl Class'G' Cemer t Perforations _ _ Top etm Shot Top Btm (ND) (ND) Dena (RKB) (RKB) (RKB) (RKB) Type Zone (sho~~~ Date 7,948.0 8,025.0 6,113.9 6,175.3 IPERF C-1, C-2, C-3, C-0, 4.0 6/16/195 1D-07 Cement Squeezes Top (ftKBl_ Btm (ftK8) Start Date ~. Descript 8174.0 ~. 8,197.0'16/16/1997 ~~Cemern Squeeze _, ___..- Notes: General & Saferi Run Dace ~ ~c ~.~ 6/16/1997 __ 3IIS --._. __ ct Depth ~ _. Port (ND) Valve Latch Size TRO Run (RKB) Make Model OD Iin) Type Type (In) (psi) 1 N0.4775 `~ ~/ Schlumberger-DCS _ !;j~' 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~y, ~~ii tt~~ ATTN: Beth _ ~ , . ~~3'~L7~111~~ ~L~~ ~ ~~~D ,; ;~~, ;. ~ _._ . ~, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE Jot 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE ~QU '~ 06/26/08 1 1 1 G-05 12080389 LDL (p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE °I' ~ t / 06/27/08 1 1 2L-327 12061715 SBHP SURVEY ~ 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / f 06/28/08 1 1 2N-323 12061716 SBHP SURVEY 1 '~f °- S 06/28/08 1 1 2X-15 12080392 SBHP SURVEY G 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - ` 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY cj- S 06/29/08 1 1 1 G-09 12080401 INJECTION PROFILE (> s-- / /(~~' 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~" --- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ a~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY "'- / 06/30/08 1 1 iD-07 12080398 SBHP SURVEY -^i 07/02/08 1 1 2N-341 12061720 SBHP SURVEY 06/30/08 1 1 3C-15 11982441 USIT - (~ / (p 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE ~ O -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 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. • • • ~~ ~ ~ ~ ~ ; ~ x , ~ ~ `~ ~ ° ~ ~ ,~~` ~ j ~ ~i~s~ ,F SARAH PAL(N, GOVERNOR ~.,. ~J ' ' t...., , , ~ (+,, t Lz z_( i.__..~, c.~ i..~ ,.......J ~1~~ ~__t ~~ ~..~~ ~ ~T ~~ AI~S~A OIIl Als~ ~~ tr`J 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'i`IOI~T COM11T15SIOr1T ~~ PHONES 907A29-14339501-3539 ' FAX (907) 276-7542 Howard Gober Wells Engineer ConocoPhillips Alaska Inc. ~~i~NE~ J~'L ~ +~ 2008 PO Box 100360 Anchorage, AK 99510 ~' `~-- Re: Kuparuk River Field, Kuparuk River, 1D-07 ~~ Sundry Number: 308-232 Dear Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Q Chair --~7 DATED this ! day of 2008 C~ Encl. ~~ ~o~ocoPhillip- Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • Y~~~I 2 '~ 2008 A~~k ~~~ ~., ~,: ~~~r:>.. ~~lnm~usi~r~ June 27, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-07 (PTD# 179-112). Injecting well 1 D-07 was drilled in October 1980. It is currently a water injector. There is a FOR expansion project on 1 D pad that will bring MI gas to the location. 1 D-07 needs an upgraded tubing head to allow MI injection into the well. Following the workover, 1 D-07 will be in WAG service. This Sundry is intended to document the service change as well as request approval to workover the well. The purpose of the proposed workover will be to pull all of the existing 3-1/2" tubing string. Then we will remove and replace the tubing head with a 5000 psi head. Anew L-80 tubing string will be run in the well. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gob r Wells Engineer CPAI Drilling and Wells ',n~ ~ STATE OF ALASKA 4' t'3tJ : ~ U ~ 2 M~ (jr~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ! v APPLICATION FOR SUNDRY APPRO~'i~ ~'~ ~ ~ ~~~~ b~s~t~.~ 20 AAC 25.280 ~"':``';=: ~~`.~;? G-. 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ ~'~~~j~tb." Time Extension ^ ~~0.GC J Change approved program ^ Pult Tubing Q ~ Perforate New Pool ^ Re-enter Suspended Well ^ ~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 179-112 ' 3. Address: Stratigraphic ^ Service 0 - 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20430-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S NO Q 1 D-07 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 i RKB 101' ~ Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8550' 6600' - 8076' 6215' 8075' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 3035' 10-3/4" 3136' 2639' PRODUCTION 8321' 7" 8422' 6496' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7948'-8025' 6114'-6175' 3-1 /2" J-55 7879' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'FHL' pkr= 7845' Camco TRDP-1 SSSV= 1822' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat July 7, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer Signature Phone 263-4220 Date tp ~,~ p~ Commission Use Onl Sundry Nu r: n '" ~ Conditions of approval: Notify Commission so that a representative may witness pC, O Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ other: ~V~L: ~~,~ ~ ~L:~ " 'tom ~~C" ~ _: Five.. ~ 2008 Subsequent Form Required: ~V~ ~,~~~~~i~~. 1~, ~,~ CC~ c;~` ~~~3;~ ~{~y'~-~ C.~sz~a~~~~~ ~ + \ i APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10 3 R vised 06/200 /~"'~ ~ { ~ ~ ~ ~ ~ Submit in Duplicate • C7 Well: 1 D-07 API: 50-029-20430-00 01"1~3Ct~~i~~1~5 Fietd: Kuparuk PTD: 179-112 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%2" BTC BPV: 3" CIW H Model: McEvoy Gen 1 Converted to Gen 4 this workover CONDUCTOR 16", 65 ppf, H-40 SURFACE CASING 10-3/4", 45.5 ppf, K-55 PRODUCTION CASING 7", 26 ppf, K-55 TUBING 3%2", 9.3 ppf, L-80, 8rd EUE Mod, 0' - 7796' (new this workover) 3-1 /2", 9.2 ppf, J-55, BTC, 7796' - 7879' (existing) 14,463' NIPPLE 3-1/2" Camco 2.75"'D' Nipple @ 7877' RKB PERFS 7948' - 8025', 4 spf E COMPLETION A: Landing Nipple: 2.$75" DS profile 500' M D B: Gas Lift Mandrel: No. MD TVD TYPE 1 7680 5904 1-1 /2" M M M C: PBR, stack packer, and poorboy overshot @ 7720' RKB D: Nipple: 3'/2' with 2.813" DS profile E: Poorboy overshot F: Nipple: 3%2" with 2.75" D profile Last Tag: 08!03/06 Tag Depth: 8070' RKB Fill: 45' rathole TD: 8550' RKB Last Updated: 26-Jun-08 Updated by: HBG Kuparuk 1 D-07 General Workover Procedure PTD 179-112 Pre-Riq Work 1. Tag fill. Obtain SBHP. MIT IA to 2500 psi. 2. Set IBP in tubing tail. Pressure test and drawdown test IBP. 3. Pull DV at 7781' RKB or punch holes in tubing at +/- 7760' RKB if unable to pull DV. 4. Chemical cut tubing at +/- 7796' RKB. 5. Set BPV 6. Prepare location for arrival of Workover Rig General Workover Procedure 1. Verify Sundry approval acquired 2. MIRU Nordic #3 3. Pull BPV. Load hole with kill weight brine. Currently assumed to be 9.8 ppg. Will use most current SBHP data from pre-rig work to determine actual kill weight fluid. Set BPV. ND tree. 4. NU BOPE. Set blanking plug. Pressure test BOPE to 250/3000 psi • The last SBHP measurement was in 2006 based on a surface pressure fall off. The extrapolated pressure was 2800 psi at 7987' MD (6145' TVD) which is mid-pert depth. The pressure is expected to be 3000 psi now. An IBP will be set in the tubing tail to isolate the formation. Kill weight fluid assuming 3000 psi BHP and a 125 psi overbalance would be 9.8 ppg. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 2385 psi.) 5. Pull 3-1/2" tubing and run new 3-1/2" tubing 6. With 7300' of new tubing run, set storm packer at +/-200'. ND BOP and tubing head. Install new Gen 4 tubing head with 5M psi top flange. Pressure test packoff to 5000 psi. NU BOP and pressure test below blind ram to 250/3000 psi. 7. Pull storm packer. Continue RIH with new 3-1 /2" completion. Locate tubing stub with poorboy overshot. Circulate in corrosion inhibited brine. 8. Drop ball and rod and set new packer. Shear PBR. Space out and land tubing. 9. Pressure test tubing to 2500 psi. Pressure test IA to 2500 psi. 10. Set 2-way check. ND BOPE. NU tree and pressure test 11. Freeze protect with diesel 12. Remove two way check 13. Set BPV and RDMO Workover rig Post-Riq Work 1. Pull BPV 2. Pull ball and rod 3. Replace SOV in GLM #1 with DV. 4. Pull RHC body. 5. Bail CaCO3 and pull IBP 6. Return to injection MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K1tì 7(zç/c~, " ' DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-07 KUPARUK RIV UNIT 10-07 111 # I J ~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,Îí3i2 Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-07 API Well Number 50-029-20430-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ0607I1I81926 Permit Number: 179-112-0 Inspection Date: 7/10/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ; lD-07 IType Inj. ¡ W ! TVD 6033 I fA ! 625 2650 2540 2520 , I : 1791120 !TypeTest : SPT I Test psi i I P.T. 1508.25 OA ! 360 500 500 500 I Interval 4YRTST P/F P V' Tubing I 1825 2000 2000 2000 Notes 2.7 bbls diesel pumped. 1 well house inspected; no exceptions noted. ;' ._ Û ._ Wednesday, July 12,2006 Page 1 of 1 .. .......... e . ConocoPIHIUp$ Alaska, Inc, e KRU 1 D-07 1D,07 ..... .... .. .... TUBING API: 500292043000 Well Type: INJ Anale @ TS: 38 dea @ 7947 (0-7879, SSSV Tvpe: TRDP Oria Completion: 10/30/1980 Anale @ TD: 36 dea @ 8550 OD:3.500, : Annular Fluid: Last w/o: Rev Reason: TAG FILL ID:2.992) Reference Loa: Ref Loa Date: Last Update: 8/1/2004 PROD U = Last Tag: 8076 TD: 8550 ftKB CASING '::1:::::::1:: Last Taa Date: 7/23/2004 Max Hole Anale: 49 dea @ 4500 (0-8422, ..",.. ;.:;.:.:.;:. basil1(Stril1( - ALL STRINGS ... OD:7.000, ". Wt:26.00) : DescriDtion Size TOD Bottom TVD Wt Grade Thread ~ CONDUCTOR 16.000 0 80 80 65.00 H-40 Gas Lift 1l:·:¡..: SUR. CASING 10.750 0 3136 2639 45.50 K-55 ,drel/Dummy PROD. CASING 7.000 0 8422 6496 26.00 K-55 Valve 1 Tubina$tril'la"TUBING '.' . .... ... (2750-2751, Size I TOD I Bottom I TVD I Wt I Grade I Thread OD:5.313) : 3.500 I 0 I 7879 I 6059 I 9.20 I J-55 I BTC Perforé1tiól'I$' SlIrrunarv' . .... '.. . ...... .. ... .... Gas Lift Illi:.,:> Interval I TVD I Zone I Status Ft I SPF I Date Type Comment ,drellDummy 7948 - 8025 I 6114 - 6175 I4,C-3,C-2,CJ 771 4 I Zero deg. Phasina Valve 2 8174 - 8197 I 6295 - 6313 I A-5 I 23 I 0 I 6/16/1997 (4661-4662, 00:5.313) Stimulati6ns& Trütments ... ... ... . '.. Interval I Date I TVDe I Comment Gas Lift 8174 - 8197 I 6/16/1997 I Cement I Used as a cement plug "'I ~¡II:¡i: :-...." Gas Lift MélndrelsNal\les ,drel/Dummy IJ .. .... ..' ..... .. .. Valve 3 St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv (5936-5937, Mfr Run Cmnt OD:5.313) 1 2750 2354 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 2 4661 3682 MMH 'PC I' DMY 1.0 BK 0.000 0 11/6/1983 Gas Lift iJ 3 5936 4561 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 ,drel/Dummy ~:,f: 4 6617 5078 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 Valve 4 5 6997 5381 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 (6617-6618, 00:5.313) 6 7402 5689 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 7 7781 5982 MMH 'PCI' DMY 1.0 BK 0.000 0 5/26/1997 OthertllilQs,e lIip;,etc.)- JEWELRY ..... .... ... Gas Lift ::::::::~:-o ] :::::::::::: Depth TVD TVDe Description ID ,drel/Dummy .¡~~1t< Valve 5 .. 1822 1692 SSSV Cameo TRDP-1 2.813 (6997-6998, 7838 6027 SBR Baker 'ELA-1' 2,813 OD:5.313) 7845 6033 PKR Baker 'FHL' 2.891 7878 6059 NIP Cameo '0' Nipple NO GO 2.750 Gas Lift Ii:::··: 7879 6059 TTL NOTE: Use TT @ 7866' for Correlations & Tags. 2.992 ,drel/Dummy 7879 6059 SOS Baker 2.992 Valve 6 8075 6215 PLUG CMT PLUG: 5 bbl Class '19' Cement 0.000 (7402- 7 403, OD:5.313) Other tlluas,. eauip.,etc.\- FRACSLEEVE ........ . .. ...... ..... > DeDth TVD TVDe I Description I ID Gas Lift III:!::'. 1822 1692 SLEEVE Made Several Attempts to Pull Frac Sleeve; Unsuccessful - last attempt on 2.300 ,drel/Dummy 11/13/97 Valve 7 (7781-7782, OD:5.313) SBR ~ (7838-7839, 00:3.500) PKR (7845-7846, 00:6.156) NIP II (7878-7879, 00:3.500) = - - Perf - - (7948-8025) - - - - - PLUG (8075-8125, OD:6.156) Perf f ~ (8174-8197) ~ ;: _. .:: .:: - - MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 1?~1 tJ-1ð~ DATE: Thursday, May 19, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLTPS ALASKA INC lD-07 KUPARUK RIV UNIT lD-07 1.' ·'Øf'",':·"'''''··'''·l':'t::,¡,~:.r·':···' \.' '. ",f ''I.,.,..'" FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV UNIT ID-07 Insp Num: mitJJ050518075013 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20430-00-00 Permit Number: 179-112-0 Inspector Name: Jeff Jones Inspection Date: 5/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lD-07 Type Inj. w TVD 6033 IA 690 2480 2440 2420 P.T. 1791120 TypeTest SPT Test psi 1508.25 OA 6 800 800 800 Interval 4YRTST P/F P Tubing 1850 1850 1850 1850 Notes: 1 well house inspected; no exceptions. 5C;,f\,NNE['J !~UG 0 9 2005 Thursday, May 19,2005 Page 1 of 1 TUBING (0-7879, 00:3.500, 10:2.992) PROD. CASING (0-8422, 00:7.000, Wt:26.00) Gas Lift ldrel/Dummy Valve 1 (2750-2751, 00:5.313) Gas Lift ldrel/Dummy Valve 2 (4661-4662, 00:5.313) Gas Lift ldrellDummy Valve 3 (5936-5937, OD:5.313) Gas Lift ldrel/Dummy Valve 4 (6617-6618, OD:5.313) Gas Lift ldrel/Dummy Valve 5 (6997-6998, OD:5.313) Gas Lift ldrel/Oummy Valve 6 (7402-7403, OD:5.313) Gas Lift ldrel/Dummy Valve 7 (7781-7782, OD:5.313) SBR (7838-7839, OD:3.500) PKR (7845-7846, OD:6.156) NIP (7878-7879, OD:3.500) Perf (7948-8025) PLUG (8075-8125. OD:6.156) Perf (8174-8197) ) ) ConocoPh¡ll¡psA.lask.a,~ .Inc~ Jr'JjJ Jr: iii ..,',:.,...:,.':,..,',:,..,.... .:~,W'·'" ~ - ___).:Ok ~~.;: ,,<r~ ,~'" . ..~~ ,y:::.-'" ....,.........'.............:..:.. . ,..' " . ;......~,.. ii- 1-.- KRU 1 D-07 1 D-07 API: 500292043000 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 8076 Last Tag Date: 7/23/2004 Casing String· ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Well Type: INJ Angle @ TS: 38 deg @ 7947 Orig Completion: 10/30/1980 Angle @ TD: 36 deg @ 8550 Last W/O: Rev Reason: TAG FILL Ref Log Date: Last Update: 8/1/2004 TD: 8550 ftKB Max Hole Anqle: 49 deg @ 4500 Size Top Bottom TVD Wt Grade Thread 16.000 0 80 80 65.00 H-40 10.750 0 3136 2639 45.50 K-55 7.000 0 8422 6496 26.00 K-55 Size 3.500 Perforåtions"Summary Interval TVD 7948-8025 6114-6175 8174·8197 6295- Thread BTC Status Ft SPF Date 77 4 23 0 6/16/1997 Type Comment Zero deg. Phasing Comment Used as a cement plug St MD TVD Man Man Type V Mfr V Type V OD Mfr 1 2750 2354 MMH 'PCI' 2 4661 3682 MMH 'PCI' 3 5936 4561 MMH 'PCI' 4 6617 5078 MMH 'PC I' 5 6997 5381 MMH 'PC I' 6 7402 5689 MMH 'PCI' 7 7781 5982 MMH 'PCI' ,O¡thêr''('pltîg·s,}ê.~uip!:;.ètê:l···~···!..J.EWE[.IR¥ Depth TVD Type 1822 1692 SSSV Camco TRDP-1 7838 6027 SBR Baker 'ELA-1' 7845 6033 PKR Baker 'FHL' 7878 6059 NIP Camco 'D' Nipple NO GO 7879 6059 m NOTE: Use TT @ 7866' for Correlations & Tags. 7879 6059 SOS Baker 8075 6215 PLUG CMT PLUG: 5 bbl Class 'G' Cement ·Öthêr:···(pïtigs,.·èqUip;'.,·Ë!tê;)···¡~¡··FRAC..·.SL;EE\(E Depth TVD Type 1822 1692 SLEEVE DMY DMY DMY DMY DMY DMY DMY Latch Port TRO Date Vlv Run Cmnt BK 0.000 0 11/6/1983 BK 0.000 0 11/6/1983 BK 0.000 0 11/6/1983 BK 0.000 0 11/6/1983 BK 0.000 0 11/6/1983 BK 0.000 0 11/6/1983 BK 0.000 0 5/26/1997 1.0 1.0 1.0 1.0 1.0 1.0 1.0 Description ID 2.813 2.813 2.891 2.750 2.992 2.992 0.000 Description Made Several Attempts to Pull Frac Sleeve; Unsuccessful· last attempt on 11/13/97 ID 2.300 ~j: ~ f (' Mike Mooney ( , Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 Cono CO Ph ¡IIi pS Phone: 907-263-4574 December 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-07 (APD # 179-112) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 0-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M.IJ/~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage S,', (1,""/iI:,., 1\ ~n~Q¡e~'~\) n~f}.n ~ Iml' l)nn~ 0 R, \ G \ N, A L ., \\.JlIf"t\W~rl~(Ç,rL, C).»HU~I {"o \!J f,,"lJJlN~ & ~ ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend 0 Operation Shutdown D Perforate 0 Variance 0 Annular Disp. 0 Alter Casing D Repair Well 0 Plug Perforations D Stimulate [2] Time Extension D Other D Change Approved Program D Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 179-1121 3. Address: Stratigraphic D Service [2] 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20430-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1 D-07 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8550' feet true vertical 6600' feet Plugs (measured) Effective Depth measured 8072' feet Junk (measured) true vertical 6213' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 1611 80' 80' SUR. CASING 3035' 10-3/411 3136' 2639' PROD. CASING 8321' 711 8422' 6496' Perforation depth: Measured depth: 7948'-8025',8174'-8197' true vertical depth: 6114'-6175', 6295'-6313' RECEIVE' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7879' MD. ""'" 0 JAN 0 5 2004 Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' pkr= 7845' AI k O' sssv= sssv SSSV= 1822' as a ,,& Gas Cons. Comm;s~inn 12. Stimulation or cement squeeze summary: AnChorage Intervals treated (measured) 78781 Treatment descriptions including volumes used and final pressure: 720 bbls of seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation - - NI A - Subsequent to operation - - 3342 - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development D Service [2] Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ [2] 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 Mik~OOney Title Wells Group Team leader Signature ) j J J- Phone Date 11./7- ZlO3 IV¡ ~ Prenared bv ;th~ron Ails-un-Drake 263-4612 . ./' j ;' ,:J,,^ L RBDMS Bfl~ JAIl 0 1 2~ Form 10-404 Revised 2/2003. \~,i, \ ~ ij (I"~ 1'-\ SUBMIT IN DUPLICATE ( ( ~PHILLIPS Alaska, Inc. KRU 1 D-O7 ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING " 1 D-07 (0-7879, '., API: 500292043000 Well Type: INJ Anale cœ. TS: 38 deç¡ @ 7947 OD:3.500, ...' SSSV Type: TRDP Oriç¡ Completion: 10/30/1980 Anç¡le @ TD: 36 deg @8550 ID:2.992) " Annular Fluid: Last W/O: Rev Reason: Fonnat Update by PROD. ImO CASING Reference Loa: Ref Log Date: Last Update: 9/4/2001 (0-8422 Last Taç¡: 8072 TD: 8550 ftKB OD:7.ooo: LastTaa Date: 1/16/1998 Max Hole Anç¡le: 49 dea cœ. 4500 Wt26.00) Casing String - ALL STRINGS, , Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 Gas Uft" SUR. CASING 10.750 0 3136 2639 45.50 K-55 landrel/Dummy PROD. CASING 7.000 0 8422 6496 26.00 K-55 Valve 1" TubimlStrina - TUBING ," ,'. .' '.'. ,,' (2b~2~~j) '.'. Size I Top I Bottom I TVD I Wt I Grade I Thread . . 3.500 I 0 I 7879 I 6059 I 9.20 I J-55 I BTC 1< ,,'. Perforations Summary... .'..'..'" '. ..'."".,....',..,.'..'."'." ...'...'.' ,,"'..,..>.... ..."'..'....'.', .." ..', Gas Uft , Interval TVD Zone Status Ft SPF Date Type Comment landrel/Dummy l" 7948 - 8025 6114 - 6175 ~,C-3.C-2,C 77 4 Zero deQ. Phasin~ Valve 2 , ,. 8174-8197 6295-6313 A-5 23 0 6/16/1997 (4661-4662, ' Stimulations & Treatments " " OD:5.313) ! Interval Date Type Comment , 8174 - 8197 6/16/1997 Cement Used as a cement pluç¡ Gas Lift j., Gas Lift MandrelsNalves "". landrel/Dummy St MD TVD Man Man V Mfr V Type V OD Latch Port TRO I Date Vlv Valve 3 Mfr Type Run Cmnt (5936-5937, ; I 1 2750 2354 MMH 'PC I' DMY 1.0 BK 0.000 0 11/6/1983 OD:5.313) ,: 2 4661 3682 MMH 'PC I' DMY 1.0 BK 0.000 0 11/6/1983 , 3 5936 4561 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 ! 4 6617 5078 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 Gas Lift , 5 6997 5381 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 landrel/Dummy ~, 6 7402 5689 MMH 'PCI' DMY 1.0 BK 0.000 0 11/6/1983 Valve4---r-'-' 7 7781 5982 MMH 'PCI' DMY 1.0 BK 0.000 0; 5/26/1997 (6617-6618, I I Oth' . ""'1 .... ~... =- t '- JEWELRY OD'5313) erÜ"uMS, e...uh".,e c. ' , . ' . . Depth TVe Type Description ID ; 1822 1692 SSSV Cameo TRDP-1 2.813 Gas Lift f" 7838 6027 SBR Baker 'ELA-1' 2.813 landrel/Dummy 7845 6033 PKR Baker 'FHL' 2.891 Valve 5 7878 6059 NIP Cameo 'D' Nipple NO GO 2.750 (6997-6998, " 7879 6059 TTL NOTE: Use TT @ 7866' for Correlations & Taas. 2.992 OD:5.313) ¡ 7879 6059 SOS Baker 2.992 , 8075 6215 PLUG CMT PLUG: 5 bbl Class 'G' Cement 0.000 . Other (plugs, equip., etc.) . FRAC SLEEVE Gas Lift Depth TVD, Type I Description ! ID landrel/~u~m~ 1822 1692 SLEEVE Made Several Attempts to Pull Frac Sleeve; Unsuccessful-last attempt on 2.300 2-a74vOe3 11/13/97 (740, I 00'5,313) I I Gas Lift I ... landrel/Dummy Valve 7 ' . (7781-7782, I I OD:5.313) I ¡ SBR I (7~~~;~5~) - .. " PKR (7845-7846, OD:6.156) NIP (7878-7879, - OD:3.500) - - - Perf - - (7948-8025) - - - -- PLUG (8075-8125, OD:6.156) Perf (8174-8197) - - ( ( 1 D-O7 Event H ¡story ~, Date Comment 11/19/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (10.5 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BE1WEEN STAGES. [HPBD] Page 1 of 1 12/11/2003 MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor DATE: October 19, 2001 FROM: Jeff Jones Petroleum Inspector Mechanical Integrity Tests Phillips Alaska Inc. 1D 1 1G Pads 1D-07, 1G-01, 1G-06 KRU KRF NON- CONFIDENTIAL ' Packer Depth ' Pretest Initial '15 Min. 30 Min. ~ · pressures monitored 30 min. & stable. w~,l ~-0~ I~e,~.l s i,,~.~l~ I*u~'n~l ! "P.T.D.i 18213'~ IType t~tI P T~t psiI 15~ Casin~ , 1280 1870 , 1860 , 1~0 No~: Pm-test pre.urns monitor~ 30 min. & stable. ~,~ ~.~ ~,n~.~ , ~'~'~'~;'1 ~ I*u~'n~l'~°° ! ~.i.D.I ~822~ffi.ll~p~t~t.i. ~ . II~tp~i ~4~ Ca~in~ 4~' 2200 2200' 2200 ~o~: pre-t~t prepares monitored aO.min. & ,table. . .... Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dunng Workover O= Other (describe in notes) Test's Details Octol~.r ~ 2.001:. I traveled to Phillips Alaska Inc.'s injection wells 1D-07, 1G-01 and 1G-06 in the Kuparuk River Field to witness 4-year MIT's. Pete Nezaticky was the PA1 representative in charge of the tests, which were performed in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable. The standard annulus pressure test was then performed, with all three wells passing the MIT's. These wells are suitable for continued injection. Each well house was inspected with no exceptions noted. S.,umm.ary: I witnessed successful MIT's on Phillips Alaska Inc.'s injection wells 1D-07, 1G-01 and 1G-06 in the Kuparuk River Field and inspected each well house. M.I.T.'s performed: 3 Attachments: Number of Failures: _0 Total Time during tests: ,6.5 hrs. CC: MiT report form 5/12/00 L.G. MIT KRU 1D, 1G Pads 10-19-01 JJ.xls 10/22/01 I STATE OF ALASKA ML AL~oKA OIL AND GAS CONSERVATION COM ~bN REPORT OF SUNDRY WELL OPERATIONS 1. Operabons Performed Operation Shutdown__ Sbmulate Pull tubing ~ Alter casing Repair well 2. Name of Operator 1 5. Type of Well Development __ ARCO Alaska, Inc. Exploratory _ 3. Address Strahgraph~c _ P. O. Box 100360, Anchorage, AK 99510 Serwce X Plugging Perforate -- Other X 6 Datum elevabon (DF or KB) RKB 30 7 Unit or Property name Kuparuk River Unit feet Locabon of well at surface 483' FNL, 601' FEL, Sec. 23, T11N, R10E, UM At top of productive ~nterval 1127' FSL, 1725' FWL, Sec. 23, T11N, R10E, UM At effecbve depth 991' FSL, 1510' FWL, Sec. 23, T11N, R10E, UM At total depth 937' FSL, 1430' FWL, Sec. 23, T11N, R10E, UM 12 Present well condition summary Total Depth measured 8550 feet true verhcal 6599 feet 8. Well number 1 D-07 9 Permit number/approval number 79-112/397-204 10 APl number 50-029-20430-00 11 F~eld/Pool Kuparuk R~ver F~eld/Oil Pool Plugs (measured) None Effechve depth measured 8 38 5 feet true verbcal 6466 feet Junk (measured) None Casing Length S~ze Cemented Structural Conductor 8 0' 1 6" 200 SX PFC Surface 31 31 ' 1 0- 3 / 4" 1500 Sx Fondu & Intermediate 250 SX AS II Producbon 8391' 7" 550 Sx Class G & L~ner 250 SX AS II Perforation depth measured 7948'-8025',81 74'-81 97' true vertical 6114'-6175',6295'-6313' Tubing (s~ze, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7879' Packers and SSSV (type and measured depth) Pkr: Baker 'FHL' @ 7845'; SSSV: TRDP-1 @ 1822' Measured depth 120' 3136' 8422' True verbcal depth 120' 2639' 6496' ORIGINAL 13 Sbmulat~on or cement squeeze summary N/A Intervals treated (measured) N/A Treatment descnpbon ~nclud~ng volumes used and hnal pressure Convert producer to WAG injector on 11/9/97. 14 Representative Daffy Average Production or Inlect~on Data Od-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 339 1 8 4 8 7 0 1450 1225 Subsequent to operation 0 0 5800 1500 220O 15. Attachments Mormng Report X Cop~es of Logs and Surveys run 16 Status of well class~flcabon as Daffy Report of Well Operabons __ Od Gas Suspended Service X 17 T'~ere~~ ~n=~'s true and correc~-~'o ~ best o-"~my knowledg'~ S,~lned// [~.~J_~._~_., ~/~..~ T,tle Wells Superintendent ?~ E L ~ ! V ~ ~,~IBMIf IN DUPLICATE . KDOS MORNING WELL REPORT'~i='QR'"i"fïö9197 . '''''':'':/',:'',:''':,.':,:.:..I..:',.-:,'.,;''':~~. ' ":, ):1:~~~~'~'Y' DR1LLSITE lD .:. : . ,:. .'. '. ."'~"""','~ . PRODUCTION I .L STATUS." .' '. {' J L!F~ 'X'OOR 'i:: "5000 ""s't' 'bÃ' -----_._--------------------------------.------~------ -----~-------~------~ -~~-_. W Z S CHOKE GAS GAS E 0 T BEANS 711 10" . INJ OPT OPT H M L N A OR we 1-128 eso CSG SSSV VOL RATE GL 'R I. L. E T ~ FTP FiT ~~ ;-:'¡"M PS I PS I STATUS ' MSCF MSCFD ROOTS S N -- -- -- ----.- ------ -.-.... -- .. - ..-. ~..._- --.-.-.. ...--.--.- ----...-- ----...- ...---- ----- ---~_. 1 B S I 0 0 0 0 C :::050? 120 TRDP .. 0 . 0 o. 0 2400 I 3 C PR 16 0 108 n (: 775 :2(J TRDP 0 0 0.0 0830 I 4 B S I 0 0 COO 20 :20 TRDP 0 0 0.. 0 2400: 0 D S I 0 0 \) (: c) 750 350 WRDP 0 0 o. 0 2400: ----- ----- TOTALS: 0 0 INJ~CTIùN WELL STATUS IN~ECTION VOLUMES 81 DA' ------ --------.-------- - --.- -.- -..- -.---.-- .-- -- --.---.- ------------ ----""-""------..----""----- ..-----. W Z S WATER RECMD GAS E 0 T 711 !O II INJ IN..J C INJ H M L N A CHOKE INJ :SG CSG SSSV METER VOL RATE L VOL R I LET h PSI rTT ~s: PSI STATUS READING BBLS BWPD S MMSCF S N -.- .-. ..... - --.... ... ..-...--. - ..........." ......-.. .... .. .............-. ..--.....-...- -----.-- ------- ------- -- --..----.....-. -...-- . 2 C S I C1 0 0 6é..O :30 MCX 0 OM 0 0 o. 000 2400: 5 C SI 0 0 0 2850 600 TRDP 0 OM 0 0 0.000 2400' 6 : SI 0 0 0 1550R 20 TRDP 0 OM 0 0 0.000' 2400 . 7 B PW 25 2200 140 1500 920 TRDP 89 5S00M 0* 0 0.000 0100 ----- ~---- ----~- TOTALS: SWI= 0 + PWI= 5800 = 5800 0 O~OOO' THE FOLLOWING FLAGS MAY APPEAR AFTER THE RECOMMENDED WATER INJECTION RATE: ~ WELL SHOULD BE WIDE or EN ~EOARDLESS OF RECOMMENDED RATE . J(.,.. WELL HAS AN OVERRIDE RATE WHICH SHOULD NOT BE CHANGED ~ WELL HAS A MAXIMUM PRESSURE OVERRIDE TARGET ~# WELL HAS A MAXIMUM' RATC OVCRRIDE TARGET' - .. . STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request- Abandon _ Suspend _ Alter casing _ Repmr well Change approved program X Operabon Shutdown_ Re-enter suspended well Plugging _ T~me extension Shmulate Pull tubing _ 2. Name of Operator ~5. Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address Strahgraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 483' FNL, 601' FEL, Sec. 23, T11N, R10E, UM At top of produchve interval 1127' FSL, 1725' FWL, Sec. 23, T11N, R10E, UM At effective depth 991' FSL, 1510' FWL, Sec. 23, T11N, R10E, UM At total depth 937' FSL~ 1430' FWL~ Sec. 23~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 5 5 0 feet true vertical 6599 feet Variance X i I Perforate Other 6. Datum elevation (DF or KB) RKB 30 7. Umt or Property name Kuparuk River Unit 8. Well number 1D-07 9. Permit number 79-112 10. APl number 5O-029-20430-00 11 Field/Pool Kuparuk River Field/ Oil Pool Plugs (measured) None feet Effecbve depth: measured 8385 feet true verhcal 6466 feet Junk (measured) None Casing Length S~ze Structural Conductor 8 0' 1 6" Surface 31 31 ' 1 0 - 3 / 4" Intermediate Produchon 8391 ' 7" Liner Perforation depth: measured 7948'-8025', true vertical 6114'-6175', Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 7879' Packers and SSSV (type and measured depth) Cemented 200 SX Perm 1500 SX Fondu & 250 SX AS II 550 SX Class G & 250 SX AS II 8174'-8197' 6295'-6313' Measured depth True vertical depth 120' 120' 3136' 2639' 8422' 64_96' RE¢I IVED Alaska 0il & Gas U0ns. L;ommiss~ Anchorags Pkr: Baker 'FHL' @ 7845'; SSSV: Camco TRDP-1 @ 1822' 13. Attachments Description summary of proposal ~ Detailed operabon program _ Convert o~1 producer to WAG ~n~ector Estimated date for commencing operation 14. November 4. 1997 O~1 16. If proposal was verbally approved Nam~f-elpprover Blair Wondzell 11/3/97 Date approved 17. I ~reb~_ertify that/t~~g~g ,s true and correct to the best of my knowledge._ Signed~,~~./~ _/"~',,~,~J_Z,.~v~ m,tle Wells Superintendent 15. Status of well classificabon as Gas BOP sketch Suspended Service WAG In!ector Condlti of approval: FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity _ BOP Test Mechamcal Integrity Test ~ Location clearance Subsequent form require Approved by order of the Commission ~;ng~nal S~gned By David W. Johnston 10- /I/'Oz.f Commissioner Form 10-403 Rev 06/15/88 Date IApproy. aI. No. SUBMI~ tN ~I~IPLICATE Attachment 1 Conversion to WAG Injection Kuparuk Well 1D-07 ARCO Alaska requests approval to convert Well 1D-07 from an oil producer to a WAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6112' and 6363' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. T STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ideehanic. I Integ~q'rest ;,j.j OPERATOR: ARCO Alaska. In¢. FIELD I UNITJ PAD KI.fPARUK ! KRU J~D DATE: ! 0/17/97 ~" .... ~ START 15 MIN 3a MIN *p TYPE PACI4ER IEQ TBG TIME I~RE 'I1ME WELL *$ ANNULUS TVD CASING TBG TEST ~ TBGi TBG I~G ~I'ART P F.~ NAME *H FLUID I&) SIZE, WT, GRADE SIZE PRESS ~ ~ CSG C~I 'IIME 1D'07 N DSL [ $T63 7'/26#/K-55 :3.5 1500 2,500 2,500 2,$0'~ 2;50.0 g:00 ! 7845 1500 3500 ..... 34,00 3590 CO~ Performed by H~il[burtra ..... .... i { ....... ............ ..... , ....... ~ , ,,, , *TUBING II~JECTION FLUID: ANNULAR FLUID:. GRADIENT: WELL TEST: P = PnOrX;cg~ wA'r'En z~ ~ 0.353 Ini~al S = ~T ~A~n I~ GL~ 4 - Ye~ M ~ ~BLE I~, ~TWA~R O, 442 Workovm ~ ~E~ON ~1~ MUD ~her ~ = N~N~C~ ~ Dlstnb~3n' odg - Well ~le ~P~ ~~ c - O~za~ c- D~se ~~ ~ S~~ c- I~m F~ MIT 3F-~ / / Drill Site lA Well No. ~ 1A-4 "~1A-5 '"'1A-7 ,~lA-9 ~1A-11 '~1A-12 '~1A-14 '~ 1A-15 'qA-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~ 5/7/82// 1/25/82'~j-- 3/23/83// 1/19/83--7 3/21/83/ 3/8/82 4/1/82 6/5/82 5111182'x. Drill Site 18 Wel 1 No. Log Date -- '"'18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"-~ '~ 3/12/82/ ~18-6 11/18/81Xx "~ 9/10/82/ ~18-7 11/23/81 '-18-8 12/28/81"% % 8/4/82/ ~iB-g ~ 6/24/82...-~ ", Drill Site 1C Wel I No. Log Date 5/9/8'1 5/8/81 7/13/81 3/9/81/ 2/26/81 11/30/81 5/19/81 5121181 Drill Site 1D Well No. Log Date '"~1D-1 1/80",> ~' 5/23/83/ "~1D-3 8/5/80 1D-4 ~7/30/80'~, ~ 8/13/80/ ~ "1D-5 6/11/81 ~1D-6 6/9/81 ~1D-7 6/8/81 ~1D-8 (WS-8) 5/10/78 ' -= . · ARCO Alaska, I( F C': :._ Eo~ 360 Anc.~crag,_ A~aoka gg510 -e ._phone 907 277 5637 Date: 9Jll/84 Transmittal No: 4719 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 "~~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2Z-7 W~8/17/84 2B-7 /~ 8/17/84 ~~/ 2B-9.. 8/17/84 ,/'~l~-9G~ 07/84 · 7 / 12-14 / 84 lB-5 "' 12/15/84 Run 1 Lynes " Lynes " Lynes Camco Camco Otis SEQUENCE OF EVENTS 8118,19184 8/17-19/84 ':" 8/17-19/84 7/08/84 Falloff Test 7/12/84 " " 12/16/84 Static BHP 1C-4 "~ 12/17/84 lC-6 12/29/84 1D-7"'"'-12/19/84 1D-4/' 12/18/84 Otis Otis Otis Otis 12/17/84 " " 12/29/84 " " 12119/84 " " 12/18/84 " " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron D&M DISTRIBUTION W.V. Pasher Alaska 0~1 & uas Cons. '~_c,nmissioP C. R. Smith Dzilling Geology G. Phillips Phillips Oil stat'~'' of Alaska Sohio Mobil J.J. Rathmell Union NSK Operations R&D Well Files ( KUPA,qJK F--3'~ I NEERI NG ~: D.W. Bose/Shelby J. Matthews ' -. Transmitted herewith are the foi lowing- PLEASE I',DTE: BL- BLUELINE, S- SEPIA, F- FILM, T- TAPE,~-~ ~~PY~. I PT AC~,O, Vl FT~F__Z): PLEASE P, ER~,I'4 RECEI PT TO: /~F3d) ALASKA, lkt:. ATTN: SHELBY J. MA-Frl- 15~,5 - ATO/1115-B P. O. BOX 100360 AI,D-tC~"~E, A]~. 99510 KUPARUK ENGINEERING TO: DATE: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 Anchorage KUPARUK ENGINLERil~G TRANSMITTAL _ TO: ~f~. ~~ FROM: are WELL NA/~tE: T~~ransmitted herewith D. W. Bose/Lorie L. Johnson the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE i£-4 RECEIPT ~/~PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class~hcatlon of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number A,RC0 Alaska, ]:nc, 79-112 3 Address 8 APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20430 4 Locatlon of well at surface 483'FNL, 601'FEL, Sec 23, T11N, R10E, UN 9 Umt or Lease Name Kuparuk 25650 AtTopProduclnglnterval 1127'FSL, 1725'FWL, Sec 23, T11N, R10E, UM 10WellNumber 1D-7 At Total Depth 937'FSL, 1430'FWL, Sec 23, T11N, R10E, UM ~ F,eld and Pool Kuparuk River Field 5 Elevation in feet (red,cate KB, DF, ftc ) 6 Lease Designation and Sermal No 101' RKB ADL 25650 Kuparuk River 0il Pool 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 15 Water Depth, ~f offshore 116 No of Completions 10/13/80 10/24/80 10/30/80 -- feet MSL] 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D~rect~onal Survey 20 Depth where SSSV set 21 Thickness of Permafrost 8550' 6599' 8385' 6466' YES [~ NO [] 1822' feet MD 1650 (approx.) 22 Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, CBL/VDL/GR/CCL, CCL/GR (rerun) 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65 H-40 Surf 80' 24" 200 sx P~.rmafrn.qt t:n .ql,rfao.~. 10 314" 45.5 K-55 Surf 3136' 13 3/4 1500 sx Fondu & 25~3 .~x AS lI 7" 26 K-55 Surf 8/~22' 8 3//~ 550 .~x Cla.~.~ P. & 2iO _~x AA [[ 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~ze and number) sIZE DEPTH SET (MD) PACKER SET (MD) '~ 1/2" 7R79' 7gt/x~ ' 7948 ' -8025 ' 8174'-8197' w/4 SPF 26 ACID, FRACTURE, CEMENT SOUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27 PRODUCTION TEST Date F~rst Production Method of Operation (Flowing, gas I~ft, etc) 12/16/81 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 6/7/81 7.1 TESTPERIOD Ii~ 66t, ?7z~ -- ~;u/4~I/z12 Flow,Tub~ng Casing Pressure CALCULATED OIL-BBL GAS-MCF WATE'R-BBL OIL'~I~AVITY-API (c~)~r) Press~l,~ __ 24-HOUR RATE * 2550 1051 -- 24.3 28 CORE DATA Br~efdescr~pt~onof Iithology, poros~ty, fractures, apparent dlps and presence of oil, gas or water Subm~tcorech~ps N/A IVIAR 1 5 1982 Form 10-407 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include ~nterval tested, pressure data, all flmds recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GORo and t~rne of each phase Top Kuparuk River Form. 7948' 6114' Base Kuparuk River Form. 8274' 6376 ' ¢ 31 LIST OF ATTACHMENTS 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge S~gned ~ T~tle Area Ops. Engr. Date 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- lng 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". I::nrm 1 I~./ll37 ilORTH'SLOPE EilGIHEERIiiG TRAilSi'.ITTAL = DATE' 9- .~- '~/ WELL . J. J. Pa',,'elek/Ann S~monsen Transm]u~d here:,:itn are the follo:,:ing PLEASE IIOTE' BL - BLUELI;IE, S - SEPIA, F - FILM, T - TAPE REC:IPT ACK;:O::LEDGFD _I/N~''' i'['_ lfi~t PLEAS: ,,~,u,.,, ECEi2T TO: ARCO ALAS}tA, INC. Ai2sk2Oil&G~sGons. CoinNllSSion ATT~' A;~N SIMO;~SEFI - AFA/311 Anahomg~ P.O. BOX 360 ,,~:~2~gc, Ak 99510 SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL Eli OTHER [] 2 Name of Operator ARCO Alaska, Inc. 3 Address P.O.Box 360, Anchorage, 4 Location of Well Surface Location: AK 99510 5 Elevation ~n feet (~nd~cate KB, DF, etc ) KB--!O1 ' 12 483' FNL, 601' FEL, Sec. 23, TllN, R10E 7 Permit No 79-112 8 APl Number 50- 029-20430 9 Unit or Lease Name Kuparuk 25650 10 Well Number D-7 11 F~eld and Pool Kuparuk River Field 6 Lease Des~gnat,on and Serial No .~--nL 25650 , ~,,n~r,,~ River o11 Check Appropriate Box To Indicate Nature of Not~ce, Report, or O~-I~-r~D-~-a .... Pr~r~l NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations ~ Altenng Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng est,mated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Began perf operations on 6/6/81 . RU, test wireline, BOP @ 3500 psi & lub @ 2840 psi. Perf'd intervals 8174'-8197', 7982'-8025', 7959'-7992' & 7948'-7959'. RIH with HP, Gradio, Spinner & Temp tools. Flowed well @ rate of 2550 BOPD. GOR= 412, FBHP=2910 psi. Ran production logs. SI well f/PBU. Final SI BHP=3133 psi. POH with PL string. Secured well on 6/7/81 NOTE: HP Tool set at 6118'ss RECEIVED Alaska Oil & Gas Cons. Commiss~or~ /~nchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned L.%. ~ T,tleArea Operati°ns Engineer The space be~ ior"'C~mm,ss,o% us/~ Cond~t~°ns of'Approval, ~f any Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate ~,O,,TII 5LCPE EilGI;,EEPT~G TP, A~IS;iiTTAL Pa,.;el c'.'/Ann Slmonsen Transml~=d horewith are the follo',.;lna' PLc'q'~.,"c I~OTE' BL - BLUELIiIE, S - SEPIA, F - PIL,.~," T - TAPE RECEIPT DATE' PLEA2= RETU2;I RECEi?T TO' ARCO ALAS}g1, INC. ATT;I: Ari:I SI;.'.OilSE~I P.O. L:O;.', $60 A:;C;:OPAGE, AK 99510 - AFA/311 RECEIVED AUG ,o Alaska OH & Oa"; Ct;ns CoH~m;S.':ion AnclK~[a9~ ,,.,r,n~ .SLC E F__.il6I; EEP,!~;G DATE' ~ ~ 0 -'"',~ ? FROM' Transmitted here;.;iti~ are the following' F - PILM, T - TAPE CE I ~T ACK;:O',':I. ED~F]O 1,'~ ~i RETUR;I P, ECE!?T TO: ARCO AI_AS~, INC. ATT~I' A~I:I SI;'n:~cF''',~,,.~,, - AFA/311 P.O. ~0;", 360 " " ~' ~ 9951 A,,C,~O,-,~G~, AK 0 DATE' AUG "-' OJ & 0," [;' I~q CuHt,II.,,....I~. ' STATE OF ALASKA ( ALASK~.)IL AND GAS CONSERVATION CO~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL ~ OTHER I-3 2 Name of Operator ARCO Alaska Inc. 3 Address Box 360 Anchorage, Alaska 4 Locat,on of Well Surface Location: 99510 483' FNL, 601' FEL, Sec 23, TllN, R10E 7 Perm,t No 79-112 8 APl Number 50- 029-20430 9. Umt or Lease Name Kuparuk 25650 10 Well Number D-7 11 F,eld and Pool 5 Elevat,on ,n feet (,nd,cate KB, DF, etc ) I 6 Lease Des,gnat,on and Ser,al No Prudhoe Bay Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or O~~ ............... NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF: (Submit m Tr~phcate) (Subm,t m Duplmate) Perforate ~N~ Alter Casmg [] Perforat,ons [] Altermg Casmg Stimulate [] Abandon [] Stimulation [] Abandonment Repa,r Well [] Change Plans [] Repairs Made [] Other Pull Tub,ng [] Other [] Pulhng Tubmg [] (Note Report multiple completions on Form 10-407 w~th a subm,tted Form 10-407 for each complet,on ) 13 Descr,be Proposed or Completed Operations (Clearly state all pertinent detads and g,ve pertinent dates, ~nclud~ng est,mated date of start,rig any proposed work, for Abandonment see 20 AAC 25 105-170) Atlantic Richfield Company proposes to perforate and flow test selected interval of 7948'-8126' (upper Kuparuk Sands) and 8311'-8329' (lower Kuparuk Sands). All wireline work will be done through a 3000 psi lubricator which will be pressure tested after being installed on the wellhead. All perforated intervals, test volumes, and production log runs will perfsrated on a subsequent report. Expected start date 5-03-81 14 I hereby certify that the foregmng ~s true and correct to the best of my knowledge rF:,~_.~%, Kuparuk Startup Director The space below for Comm,ss~on use ~ ' Date 5/22/81 Cond~uons of Approval. ~f any ~Approvedby. gY [C[(!;JE C. SMlt~ ~F°rm 10403 ev 7-1 ~0 COMMISSIONER the Comm~ss,on Date Subm,t "1 ntentlons" mn Tr,phcate and "Subsequent Reports" ,n Duphcate NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL'// ~'~,.,%~' DATE' ~,~f,, ~ransmitted herewith are the following for the subject well' i-[...~J 1 GEOL FROM' Jerr,,v ,.1. Pawelek/Leo I ? G[O~ __ WELL NAME-~kkj~([~u~ 1~-~'~' !STATTEC -- - ! J STAT TEC CC~NFER: l FILF:' ...... BL SCALE XEROX SEPIA LINE FILM DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray - Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log DATE' PLEASE RETURN RECEIPT TO- Alaska 0il & Gas Cons. Commission Anchorage ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 / ! / I RES NORTH SLOPE DISTRICT EN6INEERI~6 []~l ENO TRANSMITTAL ~ g~ I '1 3 -~~ EN~ i GEOL- 10' ~ ~ [~0~' derry d. Pa~elek/keo kash 3 9~ [ STAT TEC Transmitted herewith are the following for the subject well' FIL, F~ BL DATE SCALE XEROX SEPIA LINE FILM BHC Sonic/Gamma Ray Log iOI ;~- Cement Bond Log/VDL - -/ I Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. . .... Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray - Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density IO{~l~ Casing Collar Log ! I Perforating Record _ , Neutron Lifetime Log . Carbon-Oxygen Log ,, , RECEIPT ACKNOWLEDGED FOR' DATE' PLEASE RETURN RECEIPT TO' RECEIVED Alaska Oit & G~: rJ~ns, Commission ARCo Oi 1Af~'~r~its Company Attn- Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL DATE' FROM' Jerry, J. Pawelek/Leo Lash WELL NAME' ~J~l P ~P.-.~ D- ~ Transmitted herewith are the following for the subject well- DATE SCALE XEROX BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot t g~kqJ_~ Multi-shot Drill Stem Test - Test No. --~ Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log OMM _--- J_~__~RES E,'.~G- ~-~NO ---- [ -- L r'- ]-.STAT TEC-- .~ $..__TATTEC~ 1 htF.'----~ -- BL SEPIA LINE FILM RECEIPT ACKNOWLEDGED FOR- DATE- C/~PLEASE RETURN RECEIPT TO' RECEIYEJ) OEO- Alaf~ Oil a Gaa ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 December 1, 1980 Mr. P. A. Van Dusen District Drilling Engineer Arco Oil and Gas Comapny P.O. Box 360 Anchorage, Alaska 99510 Re: P.B.U. DS 2-1~ P.B.U. DS 11-14 P.B.U. DS 17-4 Kuparuk D-6 Kupar~ Kuparuk L~u7 Kuparuk E-8 We have checked our files and do not find Completion Reports (form 10-407) on the subject wells. ~'?e understand the report on P.B.U. DS 2-17 was waiting for a final directional survey to be received. Available information indicates the other wells have been drilled and were completed as unperforated oil wells during October, 1980. Please check your transmittals to confirm that the forms have been sent. If they have not, send the appropriate 10-407 forms at this time. Please let us know if it is necessary to delay the final reports until receipt of directional surveys on any of the wells. Sincerely, , John A. Levorsen Petroleum Geologist JAL: mm ARCO Oil and Gas~ 'npany North Slope~, tnct Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 L..j_~ES ~ NG ~ GFOL~ __1 STAT TEC - .~TAT TEC FILF: Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir: Enclosed please find: 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9,.E-8 & D-7. Very truly yours7 , ~. P. A. VanDusen District Drilling Engineer PAV:sp Enclosures ARCO 011 and Gas Company ~s a Diwslon of AtlanllcR~chfleldCompany Form P--7 SUBMIT IN DUP ,TE* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRYO Other b TYPE OF COMPLETION NEW ~ WORK DEEP-r--I PLUG r--I DIFF WELLI~ OVER [--'] EN I I BACKI I RESER O Other 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360~ Anchoraqe~ Alaska 99510 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 483' FNL, 601' FEL, Sec 23, TllN, RIOE, UM At top prod ,nterval reported below 1127' FSL, 1725' FWL, Sec 23, TllN, RIOE, UM At total depth 937' FSL, 1430' FWL, Sec 23, TllN, RIOE, UM 13 DATE SPUDDED 1~.'/13/80 18 TOTAL DEPTH, MD & TVD j19 PLUG BACK MD & TVDI20 IF MULTIPLE COMPL J 8550 MD 6599TVD 6466 TVD J HOW MANr*slngle 'ROTARY TOOLSall ffPR~)DUCING . NuparuK /~o .u TH~I~O~P~/TbON-TOP'j"BOLTT(~I~M~IJV~g~T~)*6283 TVD T Up Sand 7946 MD 6112 TVD B L Sand 8194 MD 6311 TVD B Up Sand 8028 MD 6117 TVD B Kuparuk 8258 MD 6363 TVD 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHC/GR, FDC/CNL/NGT, CBL/VDL/GR/CCL, CCL/GR(rerun) 5 APl NUMERICAL CODE 50-029-20430 6 LEASE DESIGNATION AND SERIAL NO ADL 25650 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT, FARM OR LEASE NAME Kuparuk 25650 9 WELL NO ,D-7 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay/Kuparuk River Oil 11 SEC ,T, R, M, (BOTTOM HOLE P00] OBJECTIVE) Sec 23, TllN, RIOE, UM 12 PERMIT NO 79-112 25 CASING SIZE WEIGHT, LB/FT 16" 65 26 CASING RECORD (Report all strings set In well) GRADE J DEPTH SET (MD) H-40 180' K-55 I 3136' K-55 I 8422' I I I LINER RECORD 10-3/4" 45.5 7" 26 TOP (MD) BOTTOM (MD) SACKS CEMENT* SIZE n/a 28 PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) n/a INTERVALS DRILLED BY CABLE TOOLS 23 WAS DIRECTIONAL SURVEY MADE yes HOLE SIZE J CEMENTING RECORD L AMOUNT PULLED 24"1 200 sx permafrost to surlace 13-3/4" 1500 sx fondu & 250 sx A~ctic Set II 8-3/4" 550 sx Class G & 250 sx Arctic Set II 27 TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 3½" 7879' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) n/a 30 PRODUCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) I n/a PRFLOW ESS TUBINGIICASING PRESSURE 24-HOUR CALCULATED RATE~ OIL-BBL I GAS-MCF 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) PACKER SET (MD) 7845' J WE LL'S~I (Prod u clng or shut-In) jWATER--BBL J GAS-OI L RATIO iWATER-BBL JOtuL GRAVITY-APl (CORR) ITEST WITNESSED BY 32 LIST OF ATTACHMENTS Drilling hi.story agd g~/~oscopic survey 33 I hereby cert,f~;~Z attyz inform~t,on ,s coynplete and correct as determ,ned from all available records SiGNED---~V--~..w-. ~:~M~WI~,~J~y~/ TITLE District Drilling Eng. *(See ~nstructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General This form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one ~nterval zone (multiple com- pletion), so state ~n ~tem 20, and in ~tem 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (~f any) for only the ~nterval reported in item 30. Submit a separate report (page) on th~s form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement" Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on th~s form for each interval to be separately produced. (See instruction for ~tems 20 and 22 above). 34 SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS DEPTH TRUEVERT DEPT T. Kuparuk 7946' 6112' T. Up Sand 7946' 6112' NONE B. Up Sand 8028' 6177' T. L. Sand 8159' 6283' B. L. Sand 8194' 6311' B. Kuparuk 8258' 6363' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. NONE DRILLING HISTORY KUPARUK D-7 Spudded well at 0700 hrs on 10/13/80. Drilled 13-3/4" hole to 3175'. Ran 77 jts 10-3/4" K-55 BTC csg and landed at 3136'. Cmtd csg w/1500 sx fondu cmt and 250 sx AS-II cmt. NU & tstd BOPE. Clean out csg & drld 10' new 8-3/4" hole to 3076' Tstd csg to 1500 psi & form tstd to 12.5 ppg. Displaced hole w/oii base mud. Drld 8-3/4" hole to 8550' Dropped multishot and POH. RU Schlumberger & log. Run #1 DIL/B~C/GR. Run #2 FDC/CNL/NGT. Take sidewall cores. Circ/cond hole for csg. RU and ran 210 jts 7" 26# K-55 BT&C csg to 8423'. Circ csg and cmt w/500 sx. Set pkoff and tstd to 3000 psi. Pumped 300 bbls H20 and 250 sx AS-II and 114 bbls Arctic Pack down 7" x 10-3/4" annulus. Ran gyro. Ran CBL, tool not working. Chk tools. Ran CBL/VDL/GR/CCL. Reran CCL/GR. Tstd csg to 1500 psi. Ran 252 jts 3½" 9.2# K-55 BT&C tbg and completion assy w/tail @ 7879' and pkr @ 7845'. Instl pkoff and tst to 3000 psi. Chng to diesel, drop ball and set pkr. SEt BPV and ND BOPE. NU tree and test. Monitor long term tbg tst. Released rig @ 1200 hrs 10/30/80. SCIENTIFIC DRILLING CONTROLS 700 WEST 41st STREET GYROSCOPIC DIRECTIONAL SURVEY FOR * ARCO OIL & GAS * ********************* JOB NUMBER: 4426 LOCATION' PRUDHOE BAY · SURVEY DATE: [~-ll-80 SURVEY ENGINEER: ANDY LOCHHEAD GYRO REFERANCE READING' NOO-OOF METHOD OF CALCULATION: RADIUS OF CURVATURE ***DEPTH MEASURED IN FEET*** COMMENTS: THANKS ~ ********************************** * THIS SURVEY IS CORRECT TO THE * * BEST OF MY KNOWLEDGE AND IS * * SUPPORTED BY ACTUAL FIELD DATA* * COMPANY REPRESENTATIVE * ********************************** COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTED FOR SDC BY FM LINDSEY COMPUTAT I ON & ASSOC 12 NOV 80 KUPARUK D-7 KB ELEV ~10! JOB NO 4426 FT. RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, 0 0 0 0.00 -lOi.OO N O,OOE 100 0 15 99,99 -i,O0 N?I,20w 200 0 15 199.99 98.99 S46.20W 300 0 15 299.99 198,99 S61,85E 400 0 10 399,99 298,99 N26,08E 500 1 49 499,97 398.97 Sll,05W 600 4 30 599,81 498,81 S31,03W 700 7 45 699,23 598.23 S32,08W 800 11 0 797,88 696.88 S40,07W 900 14 45 895,35 794.35 S34,32W 1000 18 10 991,23 890,23 S39.30W 1100 21 30 1085.29 984,29 S38.27W 1200 24 49 1177.21 1076,21 S37,57W 1300 27 45 1266,86 1165.~6 S40,47W 1400 31 0 1353.99 1252,99 S37,22W 1500 33 0 ]438,79 1337,79 S34.42W 1600 36 10 1521.11 1420,11 S32.82W 1700 39 15 1600,21 1499.21 S33,78W 1800 42 15 1675.96 1574.96 S34,08W 1900 45 0 1748,34 1647.34 S34.88W 2000 46 0 1818,43 1717,43 S34,53W 2100 45 10 1888.41 1787,41 S35.22W 2200 45 0 1959.02 1858,02 S34,57w 2300 44 45 2029.88 1928,88 S35,40W 2400 44 0 2101.36 2000.36 S36.52W TOTAL COORDINATES 0.00 S 0.00 W 0,16 N 0.11 W 0.07 NJ- 0.52 W 0.29 S 0,47 W 0,19 S 0,16 W 0,57 S 0,97 E 5,70 S ~ 0,99 W 14,79 S 6,57 W 27,94 S 16.15 W 45,68 S 29.62 W 68,36 S 46,59 W 94.80 S 67.84 W 125,83 S 92.01 W 160.23 S 119,89 W 198.43 S 150.65 W 241.39 S 181,66 W 288,65 S 213-08 W 339,77 S 246.66 W 393.92 S 283.09 W 450,79 S 322,14 W 509.42 S 362.75 W 568.02 S 403.59 W 626,11 S 444.10 W 683.91 S 484,56 W 740,52 5 525.62 W CLOSURES DISTANCE ANGLE D M 0.00 0,20 0.52 0,55 0,25 1,13 5.78 16.18 32,28 54,44 82,72 116,57 155.88 200.12 249.14 302.11 358.78 419.86 485,09 554.07 ""625,38 696%81 767.62 838.17 908,10 DOG LEG SEVERITY DEG/1OOFT S 0 0 0 w 0.000 N 35 35 59 W 0.250 N 81 42 18 W 0.260 S 58 5 31W 0.405 S 39 39 54 W 0.080 S 59 30 10 E 1,669 S 9 52 51 W 2,673 $ 23 57 b9 W 3,250 S 30 2 11 W 5,263 S 32 57 28 W 3,768 S 34 16 32 W 3,454 S 35 35 12 W 3.333 S 36 10 31 W 3.332 S 36 48 16 W 2.987 S 37 lZ 21W 3,362 S 36 57 46 W 2.166 S 36 26 4 W 3.219 S 35 58 41W 3.104 S 35 42 9 W 3.003 S 35 33 1W 2.779 S 35 27 14 W 1.016 S 35 23 40 W 0.900 S 35 20 54 W 0.367 S 35 19 4 W 0,481 S 35 22 2 W 0,924 SECTION DISTANCE O.OO -0.05 0,27 0.53 0.25 -0.18 5.00 15,5p 31,7d b4,02 82.30 llS~'~ 15~, 199.79 248.82 301.66 ~58.O5 418.78 483.07 552.33 623.34 694.47 765.00 o35.27 905.02 ARCO KUPARUK D-7 o ALL CALCULATIONS GYROSCOPIC SURVEY JOB NO 4426 RECORD OF SURVEY PERFORMED BY I B M ELECTRONIC COMPUTER 12 NOV 80 MEAS, DRIFT DFPTH ANGLE D M 2500 4a 0 2600 43 45 2700 4.'3 15 2800 43 0 2900 42 30 3000 42 30 3100 42 0 3200 42 0 3300 43 0 3a00 46 0 3500 47 0 3600 46 45 3700 46 45 3800 47 15 3900 47 0 4000 47 45 4100 43 0 4200 4~ 15 4300 48 15 4400 4~ 15 4500 48 30 4600 4P 0 4700 48 0 4800 47 45 4900 47 30 5000 47 0 5100 47 15 5200 47 0 53OO ~5 30 TRUE VERTICAL SUB DEPTH SEA 2173.30 2072,30 2245.38 2144,38 2317.92 2216.92 2390,90 2289,90 2464,34 2363,34 2538.06 2437.06 2612,09 2511,09 2686,40 2585,40 2760,13 2659.13 2831.44 2730,44 2900,28 2799.28 2968.64 2867.64 3037,16 2936.16 3105,36 3004,36 3173,40 3072.40 3241.12 3140.12 3308.19 3207,19 3374.94 3273.94 3441.53 3340.53 3508,12 3407.12 3574.54 3473,54 3641,13 3540,13 3708,04 3775-12 3674.12 3842.52 3741,52 3910.40 3809.40 3978.44 3877,44 4046.48 3945.48 4114.99 4013.99 DRIFT DIREC DEG, 535 S33 S34 536 536 S36 536 S35 S37 S38 S36 S36 S36 S35 S36 534 535 535 S36 S36 53~ S37 S37 S37 S37 S37 S37 5.36 S37 .53W .57W ,72W ,47W .10W ,25W .67W .82W .20W ,37W .60W ,50W ,45W ,80W ,38W .33W .62W .55W .32W .27W ,53W .55W .50W ,43W .55W .22W ,38W ,62W ,25W TOTAL COORDINATES 796.70 S 566,48 W 853.78 S 605.78 W 910,75 S 644,42 W 966,33 S 684,21W 1021.05 S 724.38 W 1075.59 S 764,25 W 1129.66 S 804.21W 1183.28 Si, 844,24 W 1237.23 S 884,91W 1292.61S 927.85 W 1350.17 S ; 971.99 W 1408.80 S: ~ 1015.45 W 1467.37 S 1058.75 W 1526.45 S 1101.87 W 1585.67 S 1145.04 W 1645.67 S 1187.61 W 1706.44 S 1230.13 W 1767.00 S 1273.45 W 1827.41S 1317.24 W 1887,54 S 1361,40 W 1947,70 S 1405,76 W 2007.25 S 1450.70 W 2066.19 S 1495,96 W 2125.06 $ 1541.08 W 2183.68 S 1586,04 W 2242,02 S 1630,63 W 2300,32 S 1675,04 W 2358.85 S 1719.14 W 2417.07 S 1762.91 W CLOSURES DISTANCE ANGLE D M 977.56 S 35 24 i046.86 S 35 21 1115.68 $ 35 16 1184,04 S 35 18 1251.91 S 35 21 1319,46 S 35 23 1386.69 S 35 26 1453.58 S 35 30 1521.12 S 35 34 1591,15 S 35 40 1663,65 S 35 45 1736.63 S 35 47 1809.46 S 35 48 1882,59 S 35 49 1955.88 S 35 50 2029,45 S 35 48 2103,61 S 35 47 2178.07 S 35 46 2252,67 S 35 47 232-1.28 S 35 48 2402,02 $ 35 49 2476,61 S 35 51 2550,90 S 35 54 2625.04 S 35 56 2,698.89 S 35 59 2'772.30 S 36 1 2845.56 S 36 3 2918.84 S 36 5 2991.67 S 36 6 5O W 24 W 55 w 0 W 12 w 44 W 50 W 25 W 25 W 16 W 0 W i W 25 W I W 59 w 12 W 47 W 5 W 4 W 11 W 24 W 19 W 57 W 29 W 42 W 40 W 5 W 19 W DOG LEG SEVERITY DEG/iOOFT 0.688 G,970 0.736 0.851 0,528 0.101 0,534 0.100 1,Olb 3,060 1.377 0,256 0.036 0.611 0,398 1,351 0.75b 0.253 0.574 0.037 0.289 0.753 0.037 0.253 0.258 0.530 0.264 0.477 0.600 S KC T I ON ulbTANCE 1111.76 1179.91 1~47,64 1315.04 1~o2.14 1448,94 1D16.40 1586.43 1658.89 1731.73 1804,42 1877.38 1950.49 2023.82 Z097,'~7 2i71. 2 2246.33 2320,77 2395,37 2469,86 2544.10 2618.20 2691.99 2765.34 2638.5~ 2911.72 2984.44 ARCO KUPARUK D-7 GYROSCOPIC SURVEY JOB NO 4426 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 12 NOV 80 MEAS, DRIFT DEPTH A~IGLE 5400 46 30 5500 46 0 5600 46 5700 45 15 5800 44 45 5900 44 0 6000 47 15 6100 42 0 6200 41 15 6300 40 10 6400 39 30 6500 3~ 30 6600 38 0 6700 36 30 6800 36 0 6900 37 0 7000 39 0 7100 41 0 7200 41 0 7300 40 30 7400 40 15 7500 3q 45 7600 39 0 7700 39 0 7800 38 30 7900 3~ 0 8000 37 0 8100 36 30 8200 36 0 TRUE V~RTICAL SUB DRIFT DEPTH SEA DIREC DEG. 4183.83 4082.83 S37.28W 4252.98 4151,98 S37.18W 4322,45 4221.45 S37,37W 4392.38 4291,38 S37,20W 4453.09 4362.09 S37.18W 4534,57 4433,57 S39.23W 4606.96 4505,96 S37.gSw 4680.53 4579,53 S38.88W 4755,28 4654,28 S40,33W 4831.09 4730,09 S40,38W 4907,87 4806,87 S41.82W 4985,59 4884,59 S42,75W 5064.12 4963.12 S41.52W 5143.72 5042,72 S42,40W 5224,36 5123,36 S43,78W 5304,75 5203.75 S45.53W 5383.54 5282,54 S47.28W 5460,14 5359,14 S46,98W 5535,62 5434,62 S48,38W 5611.37 5510,37 S48,40W 5687.55 5586,55 S48,95W 5764,16 5663,16 S50,73W 5841,46 5740,46 S53,07W 5919,17 5818,17 S53,87W 5997.16 5896,16 S53,85W 6075,69 5974,69 S56.15W 6155.03 6054.03 S56.12W 6235.15 6134.15 S56.03W 6315.80 6214.80 S55.58W TOTAL COORDINATES 2474,79 S 1806,83 W 2532,31S 1850,53 W 2589.55 S 1894,10 W 2646,42 S 1937,40 W 2?02,75 S 1980,14 W 2?57,70 S 2023,39 W 2811,63 S 2066,42 W 2864.69 S~' 2108,50 W 2915.86 S 2150.84 W 2965.57 S 2193.08 W 3013.84 S 2235,19 W 3060.39 S 2277.53 W 3106,30 S 2319,06 W 3151.31S 2359.53 W 3194.49 S 2399,92 W 3236.80 S 2441.73 W 3279,25 S 2486,31 W 3322,98 S 2533,42 W 3367.15 S 2581,93 W 3410,50 S 2630.73 W 3453,27 $ 2679.38 W 3494.72 S 2728.50 W 3533.87 S 2778.42 W 3571.33 S 2628,99 W 3608.24 S 2879.54 W 3643.75 S 2930.25 W 3677.67 S 2980,80 W 3711.06 S 3030.44 W 3744.29 S 3079,35 W CLOSURES DISTANCE ANGLE D M 3064,19 S 36 7 58 3136.41 S 36 9 29 3208.33 S 36 10 59 3~79,80 S 36 12 26 3350.50 S 36 13 40 3420,39 S 36 16 b 3489,32 S 36 18 51 3557.00 S 36 21 15 3623.31 S 36 24 49 3688.38 S 36 29 0 3752,24 S 36 33 43 3814o86 S 36 39 23 3876,49 S 36 44 57 3936.77 S 36 49 25 3995,55 S 36 54 59 4054,50 $ 37 1 46 4115,25 S 37 10 9 W 4178,57 S 37 19 18 W 4243.12 S 37 28 51W 4307,23 S 37 38 43 W 4370.83 S 37 48 27 W 4433,72 S 37 58 51W 4495.31S 38 10 31W 4556,05 S 38 23 2 w 4616,40 S 38 35 29 W ~75,82 S 38 48 20 w ~733.96 S 39 1 bO W ~791,20 S 39 14 5 W 4847,90 S 39 26 3 W DOG LEG SEVERITY DEG/IOOFT 0,022 0,503 0,137 0,755 0,500 1,241 0,961 1.31o 0,980 1.080 0.888 1,063 0,664 1,532 0,691 1,184 2.117 2,004 0,918 0,500 0,339 0.883 1.192 0.503 0,500 1.005 1,000 0,501 0,524 SECTION UlSTAi\CE 3056.~9 3129,04 3200,89 3272,28 3~42.90 3412,79 3481,76 3549,~5 3615,87 3681,09 3745,14 3808e02 3869,~9 3930e39 3989,43 40~8,72 4109 1 4238,73 4303,32 4D67,37 4~30,72 4492.81 45D4.03 4614,d3 4674,65 4733,15 4790°67 4847,59 ARCO KUPARUK D-7 GYROSCOPIC SURVEY JOB NO 4426 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 12 ROV 80 TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D ~ SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 8300 36 10 6396,61 6295.61 S55.78W 3777.50 S 3128.00 W 8340 35 45 6428.99 6327,99 S55,73W 3790.72 S 3147.41 W THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD ~55~ 35 45 6599.42 6498,~2 S55.73W 3859.81 S 3248,80 W ROTTOM HOLE CLOSURE 5045.08 FEET AT S 40 5 la Wi- CLOSURES DISTANCE ANGLE D M S 4904,48 S 39 37 36 W 4927.05 S 39 42 9 W 5045,G8 S 40 5 14 W DOG LEG SEVERITY DEG/iOOFT 0.184 1.051 SECTION DISTANCE 49u4 2 4920.~3 5045.08 ARCO KIJPARtlK D-7 GYROSCOPIC SURVEY JOB NO 4426 INTERPOLATED T'qUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUF CODE ICEASURED VERTICAL NA¢¢E DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGL~ D M S 12 NOV 80 SUB SEA T KUPARUK 7946 6112,05 B UP SAND 802R 6177,4.1 T LOW SAND R159 6282,67 B LOW SAND 819~ 6310,94 B KUPARUK 8258 6362.69 PLUG BACK 8385 6465.51 TD 8550 6599.42 3659,50 S 3687,08 S 3730.77 S 3742,53 S 3763 · 87 S 3805.80 S 3859,81 S 2953,61W 2994,74 W 3059.33 W__ 3076,28 W 3107,31 w 3168.95 W 3248,80 W 4702.74 S 38 54 25 W 6011.05 4750.06 S 39 5 3 W 6076;41 4824,75 S 39 21 9 W 6181.67 4844,59 S 39 25 10 W 6209.94 4880.79 S 39 32 30 W 6261.69 4952.41 S 39 46 5B W 6364,51 5045,0U S 40 5 14 W 6498,42 ARCO KUPARUK D-7 MEASUPED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO FEET OF ,SUB 4426 SEA DEPTH, 12 NOV 8O MEAStJRFD DEPTH TRUE VERTICAL SUB DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 201 301 401 501 702 803 906 1010 1117 122.6 133o 1~+55 1575 1701 1~34 1975 2118 2259 2399 2538 2677 2~14 2950 3085 3219 3357 3501 3647 3793 3940 4099 4239 4389 454O 201. 100 301, 200 401, 300 501. 400 601, 500 701. 600 801, 700 901. 800 1001. 900 1101. 1000 1201. 1100 1301. 1200 1401, 1300 1501. 1400 1601, 1500 1701, 1600 1801, 1700 1901, 1800 2001, 1900 2101, 2000 2201. 2100 2301. 2200 2401, 2300 2501, 2400 2601, 2500 2701, 2600 2801, 2700 2901, 2800 3001, 2900 3101, 3000 3201, 3100 3301. 3200 3401, 3300 3501, 3400 3601. 3500 0 0 0 0 0 0 2 4 9 15 25 37 54 74 100 133 173 217 258 298 337 376 413 449 484 518 555 6OO 646 692 739 788 838 888 939 0 0 0 0 0 0 2 2 5 6 12 17 2O 26 33 40 44 41 40 39 39 37 36 35 34 37 45 46 46 4.7 49 5O 50 51 0.07 0,29 0,19 0.60 5.77 14,99 28.,38 46.92 70,80 99,78 134,63 174.56 221,66 276,64 340,30 413,05 495.04 578.39 660,53 740.28 818,40 697.94 973,94 1048.23 1121.85 1193,57 1268,65 1350.76 1436, 50 1522,71 1609,51 1700.10 1790.78 1881,12 1971,75 0.52 0,46 0.15 0.97 1,03 6.70 16,52 30.46 48,56 71,71 98.73 131.66 167.63 204.76 247.00 295,99 351,99 410,83 467,58 524,76 581,46 634,88 689,73 744,12 797.87 851,75 908,83 972,42 1035,58 1098.27 1162,11 1224,94 1290,23 1356,27 1423.35 W W W E W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W ARCO KUPARUK MEASURFD DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4426 FEET OF SUB SEA DEPTH, 12 NOV 80 MEASURED DEPTH TRUE VERTICAL DEPTH SUB SEA MD-TVD DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 4689 4~3~ 49,q6 5133 5279 5425 5569 5712 5853 5992 6127 6260 6391 6520 664,6 6771 6895 7022 7154 7286 7417 7548 7676 7805 7932 8057 8182 8305 8429 370 38O 390 400 410 420 430 440 45O 460 470 480 490 5OO 510 52O 53O 540 550 560 57O 580 590 6O0 610 620 630 640 65O · 1, 1. 1. 1. 1, 1. 1. 1. 1. 1. 1. 1. 1- 1. 1. 1. 1. 1. 1. 1. 1. 1. 1' 1' 1. 1' 1. 1. 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5]00 5200 5300 540O 5500 560O 5700 5800 5900 6000 6100 6200 6300 6400 988 1037 1085 1132 1178 1224 1268 1311 1352 1391 1426 1459 1490 1519 1545 1570 1594 1621 1653 1685 1716 1747 1775 1~04 1831 1856 lBS1 1904 1928 49 49 48 47 46 46 44 43 41 39 35 33~' , 31 29 26 25 24 27 32 32 31 31 28 29 27 25 25 23 24 2060,08 S 1490,50 2147,51 S 1557.99 2234.14 S 1624.07 2319,70 S 1689.55 2405.20 S 1753.31 2489.21S 1817,69 2571.95 S 1880,40 2653,22 S 1942,52 2732,24 $ 2002.79 2807.59 S 2062,48 2878,84 S 2119.67 2945.97 S 2176.11 3009.95 S 2230,92 3069.50 S 2285,70 3127,43 S 2337.58 3182,39 S 2387.86 3235,15 S 2439,12 3288,76 S 2496.47 3347.35 S 2559.13 3404,74 S 2623,67 3460.59 S 2687.56 3514,00 S 2752.06 3562,65 S 2816.62 3610.07 S 2881.97 3654.74 S 2946,54 3696.79 S 3009.14 3738.39 S 3070.34 3779,19 S 3130.41 3820.45 S 3189.88 ARCO KUPARUK D-7 INTERPOLATED MEASURED DEPTH 1000 2000 300O 4000 5000 6000 7000 ~000 VALUES FO TR VERTI DEP R EVEN UE CAL TH 991, 1818. 2538, 3241, 3910. 4606. 5383, 6155. GYROSCOPIC SURVEY JOB NO 4426 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 890, 68,45 S 46.46 W 1717. 509,92 S 362,03 W 2437, 1075.71 S 764.09 W 3140. 1645,93 S 1187.24 W 3809. 2242.32 S 1630,23 W 4505. 2812.07 S 2065.87 W 5282, 3279,56 S 2486,01 W 6054. 3677,79 S 2980.72 W 12 NOV 80 HORIZONTAL VIEW ARCO OIL ~ GAS DRILL SITE KUPARUK D- RADIUS OF CURVATURE GYROSCOPIC SCALE I"-- I000' NOV. 13, 1980 TIIN,.RIOE, U.M. 14 ~ 23 1200 1600 ZOO0 2400 ....... 2800 3200 3600 24 TVD 6599' TMD 855d 5600 6000 6400 4000 - 4400 4800 5200 ALL DEPTHS SHOWN A RE TVD ( ( 4ool 1200 SURFACE LOCATION IS 483'SNL,601'WEL , SEC. 23 TIIN, RIOE, I~M. VERTICAL SECTION ARCO OIL & GAS DRILL SITE KUPARUK 0-7 RADIUS OF CURVATURE GYROSCOPIC SCALE I"= I000' NOV. I$~ 1980 ALL DEPTHS SHOWN ARE TVD TVD 6599' TMD 85 50' d. A, Fouch~ President Mr. Bob Hines Arco Oil & Gas Company P. O. Box 360 Anchorage, AK 99510 October 27, 1980 DeaC Mr. Hines: Re: Our Magnetic Multishot Survey Job No. MS-16690 Well D-7 (SEC23 Tll R10) Kuparuk Field North Slope, Alaska Operator: Tom McGuire Date of Survey: October 24, 1980 Please find enclosed the "Original" and one copy of our Magnetic Multishot Directional purvey on the above well. Also included are the field data sheet and film. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager Enclosures 0gc. KUD~ RUK FIELD NPRYH' '~].'6-~E, ALASKA M~GNETI¢ FULTISHOT TRUE MEASURED VERTICAL ..... DEb'TH DEPTH SPERRY ,, RECORD OF SUB, COURSE COURS SEA INCLINATION DIRECT TV-D DE~ M I N D~-G--i'~ PAGE ~ DATE OF SURVEY CCTORER 27, 1983 VERTICAL SECTICN DIRECTION S-AA-OI-OG-W 'SUN, INC. SURVEY ~,S-1 6690 FS-16E, 81 E DOG-LEG ION SE¥ RECTANGULA Z~ .... D~"G/1E O''- ~ORIH/SOUT TOTAL R COORDINATES H EAST/~EST VERTICAL SECTION 4~.00 450.00 ! 542.~0 541.96 ~' 633.00 632,74 , 724.60 723.18 .... 8~5.'~0 812,98-- 349,00 ~4o.~.~-- 531,74 622.1~ ASSUME VERTICAL TO 450 FEET O.O0 2 ,30 S '-~-A'""'3-'O "W-- ' 2.72 ....... 1'.~,~ 5 c s A5 ~0 u 2.75 5.~,~ 7 3D S 45 30 W 2.75 12.57 Zi 0 --S ~ 6"-$ b--~' ...... 3;85 ............ 22.71-S O.OO E 1,4~ W 5.63 W -23.23 ,~ {,.,nO 2,01 7.96 17.AP, 32.~7 997.00 902.79 99P.00 990.47 ] O, P,~. O0 1076,76 1PI .00 1162.35 iP. Te.dO i2A5.30 801,79 8P, 9.47 975.7F, 1~61.35 1 14 0 S 46 30 W 3.26 36.42 S ~7 o s ~F,~o u 3.~o 53.~5 s 20 o s ,+630 u 3.,~o 7~.o3 s ~5 3~ S 45 30 W 2.75 ........... f22.65"S' 37.67 76,25 . 127.14 52.36 76.66 105.50 139.19 !76.55 ~ 363.00 - ' 1546.00 IA37,06 '-1'73'h. 1326.37 1225.37 1407.11 1306,11 14l:~ 3.43 1382.43 1558.41 1457. Z~l 1632.A4 153i%'44 151.'53 S 156.87 184.27-S .......... i8'?.15 220.27 S 220.46 26t'.04 S 253.18 303.79 S 288.59 217.M3 263.95 ~11o55 362.93 _~--,1 ~?1.00 ?1~,4.00 1702.14 16,,91.14 1769.69 1668.69 1836.73 1735,73 1903,~9 1802,49 1970.11 1869.11 349.56 S 325.05 ~,' 39R.08 S 36Z+.30 k' 4AP.92 S 496,21 W 495.98 S 448.31 W 550.05 S 48,q.58 W 477 539 605 671 735 .21 .07 .76 P2P6,OO ~377.oo ~471.00 ~ 256~.00 .... eAsA.ob-- 2036.29 1935.29 2103,7~ 20C2.74 2171,57 2970,57 22~0.A1 . 2139.41 2309.71 2208.71 44 0 S 39 30 W 0.00 599.37 S 530.23 43 O S 39 30 W 1.08 6/~F..76 S 570.95 42 0 S 59 30 W 1,09 696.72 S GlO.~9 42 30 S 39 30 W .5~ 7A~.97 S 650.26 q2 ~0 S AO 30 W .72 793.G2 S Ggle08 863.29 925.2~ 9HT.SP, 10,=,0.93 2751.00 28a5.00 2936.0C 3029. [,0 2378,28 2277,28 2447.86 2346,86 2515.49 241~.49 258~.87 2483.87 --2607.3~ 250~3A 731.8e 773.3~ 813.69 854.72 867.90 1113.&4 1176.75 1237.58 1299.45 1319.31 I ~RKO OIL & GAS ! D-7 !..K Um A aU K_E.I ELI~ NORTH SLOPE, ALASKA \,. MSGNETIC ~ULTISHOT .,, RECORD OF SURVEY FAGE. 2 DATE OF SURVEY OCTCBER 275 19NO .VER]'ICAL.SECT_I.ON__DIREC.T_IOt, S-q q-.O_l-OO-'W. MS-1GGgO MS-16681 TRUE SUB CCUPSE COURSE DOG-LEG TOTAL .MEASURED ........ V ERJ-] C-/kL ..... REA ...... I NCLINA T-LQN ...... DIRE.CT. ION ....... SEV ...... RFCIANGULAR .... COORDINATES DEPTH DEPTH TVD DEG MIN EEG MIN PEG/ZOO NORTH/SOUTH EAST/WEST ) __3.~ 2._-. O 0 ....... 2~_53 n5 P 852 ...Q5____.__~..5___0 ~ 36~,00 3018,~2 2917 82 q5 0 I 3710,00 30~,3, E7 2982.87 qB 3~ga,O0 3213.69 3112,69 q5 30 .. S__.q.L_~LW ...... · 53 ..... 1 C 1 ~ · 23_.S. 88 8 · q 8_ S ql 30 W O,CO 1053,31 S 918,63 S 59 30 W ' 1.86 10R9,31 S 9q9,38 .~ 8~.O_W ........ ,~0 .......... 1 lZ6, ~5_.S ...... 987,55 S 39 ~0 W 2,27 1185,26 S 1027,09 ~70 O0 $3~2,.gq 32ql,94 q6 15 72,00 3406,95 3;505,95 q6 45 626¢,.00 3~71 ~2.1 .~3370.. ~1. q7 O, 435~,00 3533.95 3432.95 47 0 S_,,.~._3,0__~ ...... · 76 ....... 1~_9q..._70 S 1 269, S ~0 30 W 1,78 15q5,09 S 1'11,-. S 38 30 W 1.65 I59T.14 S 1353. ~ =9 .xO W .. ,82 16E0.45 S 1397. S 38 30 W .79 1702.7~ S 1~39. 1 J ..... 1807,07 S 1~58,36 S 1909.~23 S 1 9.~.~. 89 S . . VERTICAL ..... SFCTION 13q5.80 1/~z~3.05 1503,q8 1566,06 ' W . 93 ...... 226fl,3q S 1900,76 W $.__Z,_7__3_Q__ __~ . - S 39 30 W 1,52 2318,79 S 19~0,89 W , S ~0 30 W .q2 236~.50 S 1982.60 W S 39 30 W .7~ .......... ~.,52..~ .... 202q.tST_.W S QO 30 W 1.31 2~67.56 S 2,365.71 W · 7.7 ...... 2010_,.70. S__ 1700. .78 2C61,1q S 17ql, 1,62 2113.52 S 1781, ......... .7~, ..... L_.21~,. O~_$ ......... 1 820. .78 2216,75 S I860. 1~g2_,.57 W .._ 2292 1527,~5 W 23~0,63 1570.R6 W 2927.96 161~,~1 W ..... 269q,7~ ..... 1657.57 W 2561,22 55._W ..... 1957.06____ D9 W 2022.17 99 W 20 P, 9. q, 1 17 W 2157.75 51 k' 222q.77 21 W 2627.w9 05 W 2692.01+ 26 W 2757.65 83'_W ..... 2rs22'.92 ....... ~,5 W 2886.91 2952.82 3016.19 3080.92 31q6.06 . . - 3209.gl 4?_W ...... 163Q,68 .... 50 W 1695.97 55 U 17AD,GO qW_W ___ 1826,12__ 27 W 1R90.3~ OIL ~ GAS i0'7 KUP/~EUK FIELO NORTP SLOPE, ALASKA P~GNETIC MULTISHOT TRUE ,..?F~S. URED VFP~ICAL BERTH DEPTH SUB PAGE, BATE OF SURVEY OCT£BER 27, 19Rtl ....... v. -r..~ !.I.C.~ ~L SP.~.R_XrS UN,_ .INC. .......... ', RECORD OF SURVEY CCURSE COU)~$[ DOG-LEG TOTAL S_E..~.. ,.~ .I~.C_L I.,_N_.A.T.!~.N .... :__ ~D_I_~..C.T. ION ..... SEV .... R. ECT_ANGULAR_.__C.GORDINATES .. TVD DEG HIN BEG MIN DEG/~OO NOR'IH/SOUTH EAST/~EST MS-16681 VERTICAL ...... SFCTIO~ 5 ~qA2,00 4581.05 .... 5936,00 4650,63 ~22,00 621~,00 q~62,74 4480.C_5 .... 42 30 S 40 30 ~ 5q 25 = ................. . ......... l-L, 05_S .... 2106.27_ 450,9,63 0,2 O S 41 30 W ,89 2562,75 S 210,7,73 ~+619.28 41 0 S ~0 30 ~ 1.29 2609.25 S 2188.16 46B?.,74 49 36 S Al_3.O...~ ........ ,88 ......... 2655,06._S 2227,99 4761,7~ 39 30 S 5g 30 ~ 1,73 27~0,95 S 2267,23 W ..... 3272,25 g 3335,36 W 3396°89 W .. 3457,51. ~ _ W 3517.R1 63 ~8,1:) [i 493'~.24 6~50,00 5006,73 ¢492.00 5379,96 6~P5,00 5154,72 ' ~67P,O0 5230.19 4833,24 3~ 30 S 41 30 ~ 1,75 2745,02 S 2304.81 4905,73 37 30 S ~l 30 W 1.09 2787.44 S 2342,3/+ 4978,96 ~7 0 S 41 30 W ,5~ 2~29,15 S 2379,24 5053,72 36 ~ S 42 30 W 1.25 2876.26 S 2416.25 5129,1~ 35 30 S f14 ~O ~ 1,37 2909,67 S 2455,60, .5575,58 3632.17 36H7.RO 37~3,0~ 3797,41 6772,00 5307,19 ~:R65.~0 53R3,84 6957.00 50,59,08 7,051.00 5534,51 7144.00 5607.5~ 5206,19 34 30, S 45 30 W 1,23 2947.79 S 2491,76 52~.84 ~4 ~0 S 4f-~'O--~ .......... 1,72 .......... ~'~,05-S ........... 2529.96- 5358.08 35 ~5 S 49 ~0 W 1,85 3019.10 S 2569.61 ~543.~.t 51 ~ 7.].~ ........ ~..~_~ ~..W .... 2,25.. _ .. .... . 3054.7~.. s ...... 2612.88 5506.54 39 6 s 51 30 w ~.G1 3690.59 S 2657.9Q 3~51.31 3933,93 3956.69 ~012,39 4069.~7 ,'33~.00 761R.66 5681.37 5580.37 39 ~ 5755.~5 5654.45 5829.15 5728.15 5903,88 5R02,~8 5979, DO 5878, O0 38 38 38 37 15 0 30 S 5J_.3_,..0._~,~ .... p..Ol~ ...... 3.1.27_.80_S ....... .270~..73 W S 52 ~0 W .84 316,4.41 S 275].5~, W S 52..50 W .27 3199.94 S 2797.8~ U S 53 30 W ,70 3235,23 S 2P44,71 W S 55 36 W 1.39 3269.01 S 2R92.05 ',,! 412~,.75 ...... 41P, 7.63 ~245,35 4 ."*, d 3 · 28 4360.46 771 2.00 6053.82 5952.82 78¢7.06 6129.31 6028.31 7901.0(, 6204.58 6103,50 ~090.00 6S5R.12 G257.12 37 O 37 45 36 0 Z5 45 35 0 S 55 30 W ,53 3~C1,23 S 2938,94 S 56 30 W 1,02 3333,~A S 2986,75 S 56 30 W 1.86 3Z64.61 S 3033.78 S 57 30 W ,67 3~94,93 S 3080,q7 S 56 30 W ....... ~.O1 ...... 342~',56 S .... 3126.11 4416.22 0,472.62 0,527.69 45R1.94 463~. ~46 .... RIP4,Ofi ...... ~2Y~.uO 8374,00 446~,60 -'~Ani ;tic-- 6~35,2~+ 633~+,24 6513.41 6412,41 6591.9Z~ 6490.94 6670,9~ 6569,93 34 30 34 0 ~3 39 S 57 30 W .66 ~453,83 $ 3171.14 S 57 30 W .26 .34t:'2,84 S 3216.71 S 59 30 W 1,30 3510,77 $ 3262,29 S 58 30 W ,79 3537,95 S 3307,53 S 59 30 W 2,51 35hq. o21 S 3317,93 4667.33 4739.82 4791.59 4842.57 AP CD OIL & GAS D-7 KUP A RUK_EIELD NORTH SLOFE, ALASKA ~AG~'ET I C MULTISHOT TRUE SUB . MEA S U RE D--.---V-gA T-I C..AL SEA ..... DEPTH DEPTH TVD PAGE, DATE OF SURVEY OCTOBER 27, 198D _V ERT. ICA. L_S~CT_I_OH..D_IRECTION S-A 4-O1.-O0.-.W.._.____. MS-) GGg,~ $_~ LIR. E.Y._--.S U h ~ _.I N .C. ,__ __ ', RECORD OF SURVEY , COURSE COURSE DOG-LEG TOTAL I N C L.IN A.T I OL__.D IREC 1]IO N .... SEV ...... REC TAt!GULAR ...... COORD It~ATES DEG ~,I~I CEG MIN DEG/190 NORTH/SOUTH EAST/WEST MS-1GGS1 VERTICAL .... SECT I 0,',{ ', '~" ** THE £ALCULATIONS ARE BASED Ot~ THE MINIMUM RADIUS CF CURVATURE METHOD ** HORIZONTAL DISPLACEMENT = q88G.15 FEET ~Y'~s6'U'ih"'4~3-~.'~"~; .... ]~""~i~";--iJ~'~T--iiRUE)'" .. ~885,68 .... _ , ' ,.,. . ' - .., - ~ f . - SPERRY '- SUN, INC. ( . MAGNETIC MUL TISHOT FIELD DATA AND TIME SHEET NO.1 , ~ .. ' '1)S J~'- . JOB NO. , , eo" -, ~ C.~- COMPANY ~r:O DIL 'f- ,/'~ ~ . .~. DATE lð /2'/\.' . ..,.c I . ,. , .,',: STATE J!I;~rl.~ COUNTY/PARISH ,/~r""i.. ~."v,,, FIELD ~J,ø"'lnI1l: LEASE I') WELL NO. ï SURVEYED FROM .,:. ,::-~~ TO -", C,! FEE -r ,.t' " . J¡;r I ,..,. , ~ . ~-:-- A.4 ,--.....1! CLOCK NO. . ....,. 7!,: ,.. : II'~ FRAME NO. -,/ 1:;:: j MAGA¡INE NO. ","', 'Ii.~ COMPASS NO. ¡ ç'~~-:!:~ "'1rJlCENTRALIZER ~.;I _.. .' '0 ..' "'" . ' . =- COMPASS SPACING I~!I FROM BbT1:ÞMITOP If. Lo'" LENGTH OF COLLAR ~ð TYPE COLLAR ,tI,.,~.JJ-: 1- FILM LENGTH CALC. ,;: ..~/I MËÃSURED .. IIJ2 Y!ø" FIRST FLA'H :c~: :'" LAST FLASH. >~O: c.'"", , ..' ¡ -II - "''' " , ..... ':1"-,,. 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I~';~a. f' .."J. t;,1t: .. 4 " t "'7r/f11o'¥"".: ;'~"'R': I::. 1 -:, ;: "'!ø ' 17'< t) 7 " .r S'C:- \ t" ~ i) ~'1~ I ... _'Oil w", "J '- ,""7i-""~~ .,:;.t.1~; I'~ ' ~ 7" ...' !I;~..~.Z AI ~ ,'11' . d';' ......:, 1. " ..., ."' W., .., ,.: I~ð .,. ... ~ . :;" '2 ~ ..,... ' 0 Ji II PC: ~,. ".. , ,.,-:," :1 t'i';.U .. ,.... ,:~1':: t!;,zcz". ""11 ...141- J\ eJ' '," ".. . -- .: -... : :,.". , . ", "'.1 . ~ r~~~ ' , 7~ ,~:J .4;"", I ' .:....., :!'t'.......;... : ,,'Ii C" '.,..''''' ".. .:" f:' , -::I..7":...A . ~ , : ." C' l .. -'" " ,;..: :... t¡ J' :-.~ r ::~ : ,'''' ¡, "7 .,. 7¡--: :1tÞ "'i,", ,." ø;...r~- -=;0' , ~ '!"r."'."" . -= ." ... -'7:/". . ...' ..' :L II ! ~.. :: ,,21' . :",of : ':..~'.; .d' ) ... l' 1 -, ~, 5"'C'" . , ,. I' :'" o~: ðÐ J' ~:l ' q"i: ':',. I ,f., " . ~ ~ :<5' : ,... ,~~a~ø!J '! r.,/J ~ :. '.: -'~ ,." :.11 ~~/a ,,,.),\,."',:"'.'i!::=~ ".."~j,'.p ~-:-I;.I,,~ 0 ',-.. - "1' ,. ,..'7:':..',') ~.. r-., ,:4:;;, ¡:.; ;7,..~) "~-'''" ~ ~ ,J ". , ï .:J...tiM,,:an , 'Z. o! 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""I. ~ - .1,;.."'" .... ~ - ~~':J-r ~ )... ~ .,Q 1 : . '" .. ., II ... ,.:... -( :.')... .'U -..,-' ".~ ,~ .,..., :t. ':..., 4' ~l A ' . :. ~ - "f... , g. " ~ ~" , - ';'S:~Zr¿ ';l, "~.~,, ~~~.. f':~' .. 4.ßJ. .~-, ".7 "".. It. 2. '7 1!! .. .. "...... ~ . ~ - ~:2:"" ~ ~ ~ . ~,r .. ¡J '~-~~:IZ. ' _tJ.,>- ð~:~.;r . ,~- '2: 5.. '.- ,.' - ),' .~~~ ..... ' ., - '?"J : " ! ., . . . . D . -,' ., - ð,. ~J."} ... - .!tr.:.I2, () t ~ '"" . ~- -:.. ." ':' -. ï.. "" .. ,. , '"or '8!II' ~,~ r . - J... ,. ,,, , ..,'" .. ' ,,~ ., " .- . ~.. I -, 45 ~ , ., . ::. '1':~} " .. - 7:):?" "".' .... "'. ' ~ ~ - ..". f ."'" .0;" . ," ., , ~ ,- :Þ. I! '!. - ~'. ..",\ .... I 1" : - .4 2 ~ l¡ I" '.. . . ...S' ., ''1, .., , , ' ',- .. . . . ,.:> . ... - ...,.. ~ . , .. II Y"7 II -;I fJ ;.)- ,,'S~;.. I ': : - ''!o: Zf .:1..1- .J :(I( "'. t:,," - 42: '¡, . :J.'2..... t." .~., ~ , ( .. '..:J.', I ~... - 42.: ~'\ ).,-°, (" ,. ') ~. , ''':M~}. ,. - ~ ~ I.... _. , ,A,... "::' :':' ~ .._..,-~, ". I :0- W"":::þ........ '.f,.l'2.t.l- II' .~~ ;.. ''.,.~. ..!<o ' :; ~ .. C'.~ ~ ':" Co'" -, ,,"..... 2. 5 - .~ 'I: : ::;. n. ~¡ .; -' l' ~ ~ ø . , 'I ~ ~ - It': 'fI l-f! .n-'f2:~ I)!~" r.lt i: I!J.' ¡,.:." L"'~~ I . I' t. I i I I " I , :' I A-D,.rht , , \!I , I !. ~1 ' , . . . . ..,' ..' , ;. . I ' ,"".... '"» 7 ,. - -. .'. i ,. ,. 7' , 'I 1 , , ¡ , ' , '- , ' , . I. ",.... - I 1-' . r'" ,'"P 1-7: ~. ~i . " ~ a II 1,.,(.1'"... I ~ I I ":,' " " ' r " . (J. I!) " 'J .. , ' : , . , ...., ~i. , ~'- LJ. f' ^ - . '.. ~.--'f l I", ~ . f J' ,\t.,.." " . c..' : . I '. . , , . ' . I , , I : . \ " I Eastman/ , Whipstock A PETROLANE REPORT of SUB-SURF;iCE D IREC Ti ONA L SURVEY Arco Oil and Gas COMPANY Kuparuk Field, D-7 WELL NAME North Slope, Alaska LOCATI ON JOB NUMBER TYPE OF SURVEY DATE A1080D0049 SURVEY BY Mike Gates Directional Single Shot RECEIVED NOV 2 8 19~0 Rlas~ Oil & Gas Cons. Anchorage Alaska 10/30/80 November 13, 1980 Arco Oil and Gas P.O. Box 1479 Anchorage, Alaska 99501 Well Number: Pad D, Well No: 7 Location: KuparukField, North Slope, Alaska Type of Survey: Directional Single Shot Date: October 30, 1980 Method of Computation: Radius of Curvature Surveyor: ,Mike Gates Job No: A1080D0049 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot run on the atx~e mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, Jim Turnage District OperationsManager Alaska District cc: file enc. ,"~RCO OT£. AND GAG I'¢'~II ['l~ WL'I.L NO~ 7, I"IHS/I)SS JOB NOI A1.080DO049 I'(I~I-'A[(UIx f ] ~'LIi, NOI-(T~I SLOPE, ALASKA ['iHS~, 0-.~1.06 HD, SURVEY }'tY SPERRY-.SLIN, DATE F,'UN', ,30-0CT--80 - VERTICAL SE.CTION CALCULATED F OF'BSAL D~RFC"i'~ONI S--44 DEG,.~ ~ H~N,. W RECORD OF '"' ' - '" ,'.,URVEY RADIUS OF CL.R~,,ATURE HEI'I-IO0 JOR NO: A.1.080DO049 COHf:'U"i AT T [:IN 1 IME DAI IF 09; .1 5; 16 1 4-NOV-80 F AbL NO, ,'~I'ASLJI(ED I~RII:'T DRIFT COURSE VERTICAL VERTICAL. SUBSEA R I.T. C T A N G U L A R C L 0 S U R E DOGLE() I~['F"~II ANt;LF I~II'(r"CT'3'ON L. ENGTII DEF'T~I SECTION TVD C 0 0 R D I N A T E S DTSTANC[. DIRECTION SEV[.R~i I' IL E'T D h I~ M FEE l FEET FEE1 FEET FEET F' F:E r I'm ~') I)G/100F O. 0 0 0 0 O, 0o00 0.00 -101,00 0.00 0.00 0.00 0 0 0,00 4500 0 0 0 0 450 · '150, O0 0, O0 349, O0 O. O0 00 O0 O, O0 0 0 O. O0 542. 2 30 S 44 30 W c,,o. ....... 54.1.97 o.01 440.97 1.43 S 1.41 W ').OJ S 44 30 W 2.72 633. ,.~' 0 S 4~-., 30. W 91, 632.77 7.96 ~,~=~1.77 5.6.4 S 5.61 W 7.96 S 44 t, 2.. W 2,-~'7., o =;" S 7°4... 7 ¥0 oc' 45 30 W 91, 72~,''°,.= 17,86 82°..,22. . 1=,~8 S 12.&8. W 17.85 45 13 W 2.7=. ~, ,.~. 1:1. 0 S 46 30 W 91. 813.02 3o.48~. 712.02. 2°;.,-. 74 902,83 ""'2, · ., 37 801.83 ~': 45 · . - ....~ ~, . 990.51 76.66 889.51 53..1 9 9J . 1076. [:'.0 105.50 975.80 75.06 92. 1162.39 ~'-- 139.20- 1061.39 -- 96.48 907. :t4 0 S 46 30 W -.- 92° 998. J7 0 S 46 $0 W 1.089. 1181. 23 0 S 45 SO W 23.20 W 32049 S 45 34 W S.85 ~7.&4 W 59 c., .40 45 55 W 3, ,,,,.28 W 76.71 S 46 6 W 3.30 76,22 W 105,=' ,.,8 S 46 ~3 W ~.30 100,48 W 139,S0 S 46 JO W 3~29 1272. :25 50 S 45 30 W 1¥63, 2u SO S 46 30 W 1456. 51 0 S; 42 $0 W J546. $3 0 S 39 SO W :1637. 36 0 S 39 50 W 1730. S8 SO S 38 30 W J(:t'L!.1. 41 30 S 38 SO W J9.13. 44 0 S J9 30 W 2~.Q7. 45 0 ...; 39 30 W 2 1. 44 30 S 39 30 W 91o "~ 245,~5~?':176,56:~ii 1144,~5~: 122,67 S 127,13 W J76,67 S 46 1. W 91;. /1326.43'~*'217,,84,;~ .1")~R*'43.~;;,_~.~,,..~ ..... , 151.57 S 156.85 W 217.97 S 46 J W 93, ,~ 1407.16 '~'~ 97 1306 16 184 27 S " ~ ~.~,.,, . . 189.18 W o64.10 S 45 45 W . ~ ' ~ > 48~?~ 220.26 S 220 47 W 311 64 S 45 ~ W 90, 1483 48 ~t.L,~og,f,1382, , 93. 1632.49 419.04 1531.49 303.77 S 288.67 W 419.06 S 43 32 W , 55 S 325.08 91. 1702.19 477,26 -1601.19 ~. ~)W 92. 1769.75 ~,39.46 1668.75 398.07 S 364.38 W 539.66 S 42 28 W 94. 1836.79 605 14 1735.79 448 91 ~ 406 · , o .~8 W 605.47 S 42 9 W 94. 190~.55-' 671.11 1802.55 499.97 S 448,~8 W-" 671,58 S 41 '"' 2.75 3.33 3.43 ... 84 3,50 · " 77 ~.30 2.82 :1. , 06 ':13 2~194. 44 0 S 39 30 W '2286. 44 0 S S9 30 W 2379. 43 0 S S9 30 W 247.1. 42 0 S S9 S0 W 2564° 42 SO S 39 SO W 93, .1970.16 92. 2036,34 93, 2103,80 92, 2171.63 93. 2240.47 735.81 1869.16 799.52 [935.34 863.33 2002.80 925.29 2070.63 987.63 2139,47 550.05 S 489.66 W 599,36 S 530.31 W 648.76 S 571.03 W 696.72 S 610.56 W 744.97 S 650.33 W 736.42 S 41 41 W 800.29 S 4l 30 W 864.27 S 4J 21W 926.39 S 41 .1.4 W 988,89 S 41 ? W 0.54 0,00 1.08 1,09 0,54 2658. 4° SO c, . o 40 30 W 275.1. 4:! SO S 40 30 W '2845° 4'2 0 ~ 4.1 30 W '2936, 42 0 S 41 50 W M029. 41 SO S 41 SO W 94. 2309.77 ]050.98 2208.77 79J.&~2 93. 2378.34 11.13.69 2277.34 -841.39 94. 2447.92 1176.80 2346.92 889.09 91. 25J. 5.55 1237.64 2414.55 934.69 93. 2584.93 - J299,50 2483.93 981.07 691.15 W 1052.39 S 41 3 W 731.96 W 1115.2] S 4.1 I W 773.42 W 1178.41 S 4l i W 813.77 W J239.30 S 41 S W 854.80-W- 1301.23 S 41 4 W 0.72 0,00 0,89 0,00 0,54 ~I'~'CO OIL. AND GAS :'Al'i D~ WEI. L. NO: 7~ MF~S/DSS · .,(Jr.,AretJIx I-IL~L lq, NORT'H ,gLOF'E, ALASI,~A ,lOB NOt A1080DO049 COHF'[JTATION PAGE NO: .2 T I ME DA TF. ~ 09:1.5~16 14- NOV-.80 , '~ TRUE ' - '~I"ASURFD r~R~FT BRIFT COURSE VERTICAL VERTICAL. SUBSEA R E C T A N G U L. A R C L 0 S U R E DOGLEG IlL'PI'II ANGL[ I"~IRL.'CI']'ON I.ENGT~I BE[:'T~I SEC~]'ON TVB C 0 0 R D t N A T [: S DISTANCr' DIREC'IlON SEVE'RIT r'EFT I~ N D h FEET F F:E:T FEET FEET IrE'ET F'EL. ] D ~ DO/lO01 30,59. 41. 50 S 41 $0 W S~06. 41 15 G 4] 30 W 30. 2607.40 1319.36 2506.40 995.96 ~,.. -, .i.c.., / ].3,.,0.40 2,., al.67. 10].9.27 867.97 W 1321.11 S 41 4 W 888 · 56 W 1.,~,~."z~':°. 17 S 4 L =,, W 0.00 0.55 ~,106 MI; IS l J'r':. I'N POINT FROM SF'ERRY--SUN HHS FOR E/W I)SS ,"~,"-~1..1 04'2 0 S 40 0 W 205. 2795.91 1486.~4 2694.91 1~22.38 S 977.44 W 1488.34 S 41 S W ,,464. 45 0 ~; ~8 0 W ~53. 2906.88 1591.24 2805.88 .1.204.~,._ S 104J.71 W ~593.57 S 40 ,~,, W :{626 46 0 S ,.~c 0 W ~62 3020 42 1706 15 2919 42 Jv95.,,7 S 1114 85 W 1708.98 S 40 4~ W 0.61 2 .16 0.62 S934, 46 0 S 39 0 W 4400. 47 30 S S9 0 W Il'-') 4,,._4. 42' 30 G ,39 0 W 4832. 47 0 S 39 0 W · ,,,,,. 46 0 S S9 0 W 5631. 45 :~.0 ,% 40 0 W 6095. 42. 0 S 40 0 W 6402. 39 0 ,% 40 30 W 6568. 38 0 S 41 30 W 6724. ~.~6 15 S 44 0 W 308. ,,77-~4~.,. .38 1,9,:6.68 ~133.38 1468.66 S 1252.77 W 1930.39 40 ,,8 W 466, 3553,66 ,:.,~c~, 79 34= '~ '~269 ,.~.66 1732.43 S 1466.37 W ,. .70 S 40 15 W 124 S637 44 ...... 2355.86 · . ~,~o6.44 J. 803.48 S 1~23 90 W 2361.11 S 40 ~2 W ~08. /~846.5t ,:,,,2581.17,~;,-3745.51 1979.25 O 1666.24 W 2587.23 G 40 6 W 46~. '41'~ 2i 2915 72'.;? 4064i21 '~2240.25 S ....... 1877 59 W 'v~v'~.02 S ~9 58 W 336. ~ 4399.67 3155.65. 4298,67~ 2425,96 S 2030,67 W 3163.69 'S 39 56 W 464. ~ 4734,79.2~3475.67~ :~t633,79~ 2671.72 S 2236,89 W 3484.50 S 39 56 W 307. 4968.21. 3674.60 4867,21 .~.~°°-z,87 S 2365.70 W 3683.05 S 39 57 W 166. 5098.12 3777.79 4997,12 290~.86 S 2433,49 W 3787,17 S 39 b9 W 156. 5222.50 3871.91 5121.50 2970.99 S 2,197.40 W 3881.21 S 40 3 W 0.23 0.32 0.00 0,16 0.22 0.26 0.75 0,98 0,71 ~,48 ~W~,~;2. 36 SO S 46 0 W 218. 5398.02 4001.17 5297.02 3062.40 S 2588.81 W 4010.02 S 40 13 W 0.56 65. 38 0 S 48 30 W ....].23. ~5495.93 ~-4075.50 ..... 5394.93-3112o94 S -2643.48~W - 4083.91 S'40 20 W- 1.73 7253. 39 0 S 50 30 W 188. 5643.06 4191.99 5542.06 5188.94 S 2732.47 W 4199.49 S 40 36 W 0.85 750L;. 59 0 G 52 0 W 252. 5838.90 4349.31 5737.90 3288.20 S 2856.15 W 4355.44 S 40 59 W 0.37 7762. ~8 0 S 55 0 W 257. 6040.03- 450'7.09--5939.03 3383.35 S 2984.74 W 4511.73 S 41 25 W 0.82 8010. 37 0 ,S 56 0 W "~; S 8200. 3. 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L "'-.+~ I . ! Well Histo:ry Yes I J a- -I-~ð i Lo. f~ Sanples rJ - {-I- ~ ------- I ð I< Mud Log .-. rJ. (''1 --! ð i< t (" , Core Chips ¡ "",',', /1/ð .IV e. ---- '--'. 0 f, --l..... '. ¡ De . t' I Core scrJ.p J.on '--- I A f.C/ /l/CJ de t- f/ "- Registered Survey Plat I~. I 1 [....-:~ 7'.J ðl< Inclination Survey r -- .."" -L , .,.. " r, tJl,< I -Ti-i" ¡ - íI () ~L Directional Survey_\L~tf-,- ....L~_:J'P-.~,- '=.",-+e Drill Stem Test Reports f< . ~ðH~ .- Production Test Re¡x>rts ~ ..--- 0 Logs Run Yes I ( I I r- - t c¿ '""' gð () '( .. ~_... " C y€£ I~~-~I ~te ARCO Oil and Gas C",,,~mpany North Slope Jnct Post Olhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 COMM COMM RES ~_:,IG ~ 1 2GE~ 13 STAT TEC ~ONFEm - ........ FILF: Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 15-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Pemit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir' Enclosed please find' 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17-4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9, E-8 & D-7. Very truly yours~ , ~.. P. ^. VanDusen D~strict DrSll~n~ Ink,neet ?^V' sp [nclosures Ai~c,'~.ora~o C.~ ;;2,..Qi83,,017 ARCO OII and Gas Company is a DIws~on of AtlanticRichheldCompany Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE GF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20430 6. LEASE DESIGNATION AND SERIAL NO ADL 25650 OIL [~]X GAS WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, AK 99510 4. LOCATION OF WELL 483'FNL, 601'FEL, Sec 23, TllN, RiOE, UM 8. UNIT FARM OR LEASE NAME Kuparuk 25650 9 WELL NO. D-7 10 FIELD AND POOI~,,OR vruonoe pay rle~d/ OBJECTIVE) Sec 23, T11N, RIOE, UM 12. PERMIT NO. 79-112 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spud @ 0700 hrs 10/13/80. Dr113-3/4" hole to 3175'. RU & run 77 its to 10-3/4" csg. Cmt 10-3/4" csg w/1500 sx Fondu & 250 sx AS II cmt. ND BOP & diverter. Instl pkoff on 10-3/4" csg & speed head tstd to 2000 psi. NU BOPE. Drl cmt, FS, & 10' new hole to 3185'. Circ & run form tst to 12.5 ppg. Drld & surd 8-3/4" hole to 8550'. RU Schlum- berger & log. Run #1 DIL/BHC/GR. Run #2 FDC/CNL/NGT. RU & run 210 jts 7" 26# K-55 BTC csg w/shoe @ 8422', FC @ 8339'. Circ csg & cmt w/550 sx. Displ w/lO.O ppg NaC1/ NaBr. Bump plug w/2000 psi. CIP 0215 hrs 10/26/80. Set pkoff & tst to 3000 psi. Pump 300 bblSlH°050~) dwn 7" x 10-3/4" ann followed by 250 sx AS II & 114 bbls Arctic Pack. APIP @ hrs 10/26/80. Tag cmt @ 8318'. Run CBL/VDL/GR/CCL. Rerun CCL/GR. Tst csg 1500 psi. RU & run 252 its 3-1/2" 9.2# K-55 BT&C tbg w/gas lift mandrels & SSSV. Land tbg w/tail @ 7879' & pkr @ 7845'. Instl pkoff & tst 3000 psi. Chng over to diesel. Drop ball & set pkr. Set BPV & ND BOPE. NU Xmas tree & tst. Begin long term tbg tst. Release rig @ 1200 hrs 10/30/80. A .. ,,~ . / // 14. ! hereb~cll~l~ thata~e f~r~ln8 ,$~Xi~ and co~t SIONE~~' ~ ~~'TLE District Drlg Engineer gATE 11/25/80 NOTE-Re~ on this form is r~umr~ for each ~le~ar month, r~rdm~ of the ~atus of o~ratiom, and mu~ be fil~ in dupli~te with the oil and ~s con~ation comm~tt~ by the 15th of the succ~i~ month,unl~ oth~i~ dir~. NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL// FROM' Jerry J. Pawelek/Leo Lash WELL NAME' Transmitted herewith are the following for the subject well' DATE SCALE XEROX SEP IA COMM .. _ -__ 2 ~-;,;" ___ ---- -- """ -OL i-CONF~ [FILF: __ BL LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot J Multi-shot Drill Stem Test- Test No. -., Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log """EiV"D KI::L r RECEIPT ACKNOWLEDGED FOR' DATE' NOV 2 9 !980 nit & Gas Cons. Commission ........... Anchorage PLEASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. //311-FAB Anchorage, AK 99510 TO' DATE: NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL # FROM' Jerry J. Pawelek/Leo Lash NELL NAME' Transmitted herewith are the following for the subject well' _cCOMM- OMM~ I RFS~ 1ENg 2. ENG -- 3EN; ___L_4 ENG- 1 GEOL-- I/~jJ:3 G EO~--- GEO~ STAT TE~ STAT TEC- DATE SCALE _JOl 0~ BHC Sonic/Gamma Ray Log Cement Bond Log/VDL loJ &~J Compensated Formation Density Log '1ol ~ Compensated Neutron-Formation Density ~'' ' Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog-~F~ Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon;Oxygffn Log _ , RECEIPT ACKNOWLEDGED FOR: RECEIVED DATE' L~~EASE RETURN RECEIPT TO' NOV 1 9 1980 Alaska Oil & Gas Cons. Commission ARCo OilA~a~s Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 XEROX SEPIA BL LINE FILM 'A ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Hoyle H. Hamilton /~.~F Chairman/Commission~" Ben LeNorman ~ Petroleum Inspector October 20, 1980 BOPE test on Arco's Kuparuk D-7, Sec. 23, TllN, R10E, UM. Kupar, u~, R,i~,er undefined. Thursday Octo.b~,r 16 - I departed my home at 2..00 pm for a 2=30 pm showup and 3=45 pm departure via Wien flight %5 for Deadhorse arriving via Fairbanks at 6~20 pm. weather: +28CF, high over- cast, wind 15 mph from the west. Friday October 17 - BOPE tests on Arco's Kuparuk D-7 began at 6:45 am and were completed at 7~45 am. BOPE Inspection Report is attached. Tests on Arco's Kuparuk E-8 began at 10~15 pm, the subject of a separate report. ~,~a,tur~y~ 0=tober,,18 - i departed Deadhorse via Wien flight #72 at 10~20 am and ~'~'rived in Anchorage via Fairbanks at 12i~55 pm. I arrived home at 1=25 pm. Monday October 20- Don Mc Kelvey advised the check valve in the kill line was repaired and tested to 3000 psig. In summary, I witnessed successful BOPE test on Arco's Kuparuk D-7. BL;mm '* O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator , ~e--~ Location: Sec ~ T//~R/~M ~ Drilling Contractor ~~ Rig ~/F/ Representative Permit t~ _~asing Set Representative J ~A~ Location, General Well Sign General Housekeeping.. Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pressure...~/~)~2) psig Pressure After Closure /~'~ psig 200 psig Above Precharge Attained: / miL ~ .~ Full Charge Pressure Attained: ~' miL ~ ~ N2 ~~ ~~, ~O~ ~O~psig Controls: Master ~ Remote ~ Blinds switch cover~ . Test Pres sure -- Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly Test Pressure Ball Type ~ Test Pressure Inside BOP_ _~ ~(-- Test Pres sure Choke Manifold No. Valves No. flanges Adjustable Chokes / Hydrauically operated choke Test Re cults: Fa ilures Repair or Replacement of failed equipment to be made withzn Inspector/C'omm~ssion office notified. Remarks: ~/u//'O~J /~ ~~~ ~,~/~- Test Time / hrs. Test Pressure .~~ days and Dis tr ibut ion orig. - AC&GCC cc - Operator cc - Supervisor Inspector~ WELL ~I Y -- 5,959,904,19 i Go,' ~ LAT : 70 18:03 672" [ i LONG = 149°30'36.426' : , j I WELL ~ 2 Y = 5,959,784.20 j , LAT = 70 18'02.492" < , % LON~ ~ 149°30'36.424'I, :> ~ f WELL .3 Y = 5,959,664.22 T ' ' x: ~0 ~ ~ I ~ I~ 1~ LAT = 70 18[01.~12'' psat '~, ~ 23 24 .... LONG = 149°30' 36.421" < I ~ (~I~I~RIOE~UM.) WELL 4 Y = 5 959 544 23 ; : i ~ ~ : ' ~. ~ X = ~60 487{32 .'--- LON~ = 1~¢°~0~]6.~8~' i i <D6+ ~ WELL .5 Y = 5,~59,424.25 ' '~ X = 60,488.38 ~ ' ~i ~] LAT 70 17'58.951" ~ ~] LONG = 149°30'36.415' DI~ i, > I < LAT = 70 17'57.771" , ~ . LONG = 14g°30'36.413' I I O ~ I WELL ~7 Y = 5,959,184.28 D~ ~ X = ~60,490.51 ~ i ~ '~We~T ~AK$ LAT = 70 17'56.591" ~ < [ LONG = 149°30' 36. 409' WELL ~8 Y = 5,959,064.29 A X = ~60,491 .56 . LAT = 70~]7'55.411" ~CALE-l"=~OO' LONG - 149°30'36.407" ~." ~ '-~f~ PROPERLY REGISTERED AND LICENSED ~*:'49~~ '~:~. TO PRACTICE LAHD SURVEYING IN ~/~. ~ ~. C~~ /_~ ~ THIS PLAT REPRESENTS AN AS- ~,'$:-.~No ~2zz-S ..'~ ~U,L= SUrVeY ~A~ ~Y ~, A~ ~i.~,].... ....~N_ TtIAT ALL DIMENSIONS AND OTItER ,~.r~:~' ' ' ,~,~ DETAILS ARE CORRECT,AS OF : % %%~%~ DATE fl/7/Tq II II I I I I I I I II I I O.~. D~ WELL5 1,2,5,4,5,6,7,$8 LOCATION5 A6-SUILT II I II III III I I I III II I II II AtlanticRiChfieldCompany ~ DATE: DRAWING No: .OR=. AMERICA..RODUCI~G ~VlS~O. .LAS~A O~ST~,CT KUP*RUK ii ............. ~ -~ ,, ir m, September 24, 1980 ,~,'r. Hoyle Ham~ lton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' As-Built Survey Plats ':, CO ',Ah,'~ -- ~ . ' I 2 EN3C~. ,~ ~--t 1 oEoC ~ 3 GF. OL ' i STAT TEC ! STAT TEC , De ar Sir' ' '~' ~'; ~'" ' In an effort to insure that your files are complete, we hav~ attached copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those included in our or~.g~nal drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments ( Decesd)er 24, 1979 xuparuk 25650 AR~O Oi1 and Oas Company Permit Ho. Bur. Loa. J 483' SNL & 601' WEL, Sec 23t TI1H Bottonhole Loc., 1320' NSL & 1320' EWL~ Sec Mr. P. A. VanDusen District Drilling Engineer ~CO 0~I, and ~as Coe~m~y An~ozege, Alaska 99510 Dear Mr. VanOusen~ Enclosed is the approved application for permit to drill the above re£erenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitised log tn£ormatton on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as isq~rtant for the spawning or migration of anadromous £ish. Operations in these areas are sub~ec~ to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Adminis~rative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution o£ any waters of the State is prohibited by AS 46, Chapter 3~ Article ? and ~he re~ulations promulgated thereunder (Title '18, Alaska Administrative Coder Chapter ?0) and by the Federal Water Pollution Control Act, as amended. Prio= to Mr. P. A. VanDusen Kuparuk 25650 D-7 -2- December 24, 1979 commencing operatio~ you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this pernit to drill, To aid us in scheduling field work, we would appreciate your notifying th~s off,ce within 48 hours after the well is spudded. We would also like to be not£fied so that a repre- sentative of the cmnm~salon may be present to witness testing o£ blowout preventer equipment before sur£ace cas~ng shoe ts drilled. In the event o£ suspension or abandonment, please give this o£fice adequate advance notification so that we may have a Very t~uly yours, Ho~I~ H. Hamtlton Alalka 0~1 & Oas COnsolation Enclosure co~ Depa~.rtuent of F~sh & Game, Habitat Section w/o encl. Depar~nt of Environmental Conservation w/o/encl. Depar~nt of Labor! Supervisor, Labor Law Compliance Division w/o encl. HHH~vk ARCO Oil and Ga~ 'ompany Alaska Regl~ Post Ofhce Box 360 Anchorage Alaska 99510 Telephone 907 277 5637 December 17, 1979 Mr. Hoyle H. Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS D-7 Dear Mr. Hamil ton: Enclosed herewith is our Application for Permit to Drill DS D-7, the $100.00 filing fee, and the required survey plat. Very truly yours, P, A, VanDusen Di'strict Drilling Engineer PAV'ms Enclosure ARCO O~1 and Gas Company ~s a D~ws~on of AtlantlcRichfleldCompany Form 10-401 REV. 1-],-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT~?~E~..~ PERMIT TO DRILl. OR DEEPEN la. TYPE OF WORK DRILL [~ b. TYPE OF WELL OIL GAS WELL [] WELL F'~ OTHER 2 NAME OF OPEP, a~'rOR ^RCo 0il and Gas Company DEEPEN r"'l AJ2SKZI Uh Cx L; '3 , ,~,,: Anol~urage 3 ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 483' SNL~60I' WEL, Sec 23, TllN, RIOE, UM At proposed prod. zone 6100' SS, 1320' NSLli~1320' EWL, Sec 23, TllN, RIOE, UM API #50-029-20430 LEASE DESIGNATION AND SERIAL NO ADL 25650 IF INDIAN, ALLOI'IT'EE OR TRIBE NAlV[E UNIT FARM OR LEASE NAME Kuparuk 25650 WELL NO. D-7 10 FIELD AND POOL, OR WILl)CAT Prudhoe Bay Kuparuk River Oil SEC., T., R., M, (BO~OM Po0 l HOLE OBJECTI'v'E) Sec 23, TllN, RIOE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12 30 miles Northwest of Deadhorse ,~o,nt $1 00,000 15. DISTANCE FROM PROPOSED * 17. NO.ACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. 320 (Also to nearest dng, umt, if any) 20 ROTARY OR CABLE TOOLS 14. BONDINFORl~TION Oil and Gas Bond va~ Statewidesurety,nd/orNo.#8011-38-40(Fed. Ins. Co.) 16 No OF ACRES IN LEASE 4679' 2560 18 DISTANCE FROM PROPOSED LOCATION 19 PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 120' 6545'TVD Rotary 21 ELEVATIONS (Show whether DF, RT, CR, etc.) 22 APPROX DATE WORK WILL START 71' GL 2/25/80 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE~ING DE~H Quantity of cement 24" 16" 65 H-40 80±MD {Cmt to surf - approx 200 ft3 3 13-3/4" 10-3/4" 45.5 K-55BT( 3020±MD Cmt to surf - approx 36~0 ft 9-7/8" 7" 26 K-55BT( 8765±MD Cmt with approx33000 ft primary - 93 ft secondary Arctic Pack from ± 2000'MD to sur face ARCo Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately ±8765'MD,_+6545'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated with- inthe Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ~s to deepen g~ve data on present productive zone and proposed new produclmve zone. If proposal ~s to drill or deepen directionally, grove pertment data on subsurface locations and measured and true vertical depths. G~ve blowout preventer program. DATE ~_------")~"~g'J~]~ ~"--7~. 17/ Jr!9 TITLE Dist. Drlq. Engr. (Thts space for State office use) SAMPLES AND CORE CBIPS REQUIRED [] ,,'~s ~'NO DIRECTIONAL SURVEY REQUIRED ~YES [] NO CONDITIONS OF APPROVAL, IF ANY MUD LOG ~ [] YES NO OTHER REQUIREMENTS A.P.I NUMERICAL CODE PERMIT NO. 7 ?- //L APPROVAL DATE APPOVED BY ~"ff~~ _~' ~ TITLE Ch~ rm~n c/ ~ *See Instruction On Reverse Side December 24, 1979 DATE 12/24/79 W~£L :~ 1 Y = 5,959,904.19 ~- Gol' ~ LAT : S60,484.14 70618' O].672'' · {- LONG = 149°30'36.1,26. , I ~4ELL :2 Y = 5,959,784.20 ~ : pt x = ~60,485.20 I ~1~ 1~ LAT 70 18'O2.492" < , ~- LONG = 14q°30' 36.424", I > ---~- / WELL · 3 Y = $,959,664.22 ' ~ J LAT = 70 18'O1,312" DS~ ~'23 24 -- LONG = 149°30'36.421" I ~ ('I'IIIi~RIO~,UM.) WELL '~ Y = 5,959,544.23 i I ~ X = ,~60,487 32 ~ LONG 149°30'36 I '~' ~P~ ~ WELL , 5 Y = 5,959,424.25 ~ x = ~6o,488 38 > ' ~ I LAT : 70 17'58.~51" I ~1~ LONG ~ '~ : ¥ ~ WELL ,,6 Y ~ 5,959,2tO4.26 ~,11~ ~ ~ LAT 70'"17'57.771" ~!L. · LONG -- ' / WE:ST ~AK $ 'LAT = 70 17' 5~6.59 I" DEC g 0 WELL ~'8 Y = 5,959,064.29 a Alaska 0ii & b ~ * ...... , .,,,~?':fr;. X = ~60.491.56 Anohora~l~ LAT 70~7' 55.411" ~ LONG = 149 30 ~ 36.407' I ~ ,,O. '" ' ' ' :'3'~ '~ ~'1 HEREBY CERTIFY THAT I AM ' ,'/ "j~.j ~ ,'~5..~ PROPERLY REGISTERED Al'ID LICENSED TO PRACTICE LAND SURVEYING IN ~ /~t.~.""~/~t // 4~Z~./-,//t~/t¢. THE STATE OF ALASKA AND THAT. %' '"" '/','~'"~ ............. .,' THIS PLAT REPRESENTS AN AS- / ~;~ ~, ~,~t~r~ ~., BU I LT SURVEY MADE BY HE, AND ,r ..... ~" TttAT ALL DIMENSIONS AND OTttER ~ " ,,, ,., ~,.~ DETAILS ARE CORRECT,AS OF ~ ' :' ;'", .~.,:" :.C.?,.,'""~" DATE q/7/7q II D, WELLB 1,2,%,4,5,6,7,¢8 LOC..ATION5 A -I UlLT I II I AtlanticRichfieldCompany ~ DATE:- DRAWING No: "OPT" AMERICAN PRODUCING DIVISION ALASKA DISTRICT KUPARUK I Company C5~ LIST FOR NEW WELL PERMITS Yes No Is the permit fee attached .......................................... 2. Is %~_11 to ke located in a defined pool ............................. 3. Is a registered survey plat attached ................................ Is %~11 located proper distance from property line .................. ~. Is well located proper distance from other %~lls .................... 6. Is sufficient unde~icated acreage available .................................... in this ~1 ..... 7. Is well to be deviated 8. Is operator the only affected party ................................. ~. Can pe~nit be approved before ten-day ~mit ...................... i... ~~ 0. Does ~operator have a bond in force ..................... ,~. Is a conservation order needed ...................................... _2. Is administrative approval needed ................................... __ ~3. Is ~.~onductor string provided ........................................ 4. Is enough cement used to circulate on conductor and surface ......... ~? _5. Will cement tie in surface and intermediate or production strings ~ 6. I~ill cement cover all known productive horizons ..................... 7. %~11 surface casing protect fresh ~ater zones ....................... ~. Will all casing give a~equate safety in collapse, tension and barst.. '~9. Does BOPE have sufficient pressure rating - Test to %o ~ ~ Jditional Requir'~nents: Approval Reconmended: Ra~r~ Lease & Well ~No. /~ Item Ap/prove '(1) Fee (2) Loc.~~~ (3) Admin ~ (4) Casg. (5) BOPE .~6F~ JAL ~ / Engineering: r~v: 12/12/79 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. VV VV VV VV VV VV VV VV VV VV VV vu VV VV VV VV V V ~ EF.I:,.,KEE, I..I,, I.,.E HHN~RBRR VV I",P HB VV ~E P~ VV F.E RI4 V V Ei~. E!- [".EEl". H~PRRRHP VV I~. [-'. k E E k [', k PRRRRHR}~ VV EF PR HR V~/ kE HH RR EE RH Rf~ kE kkl'.El:;,Ekg R~ F, EEEEEF, EEE HH RR RR RR RR RR RR IIIIII IIilli II 1I Il II I1 iI II II 11 II IIIili 11IIII FF f~FFF~F ~F ¥¥ ¥¥ YY ~Y YY YY YY YY YY YY YY YY 000000 000000 11 000000 000000 11 O0 O0 O0 O0 1111 O0 O0 o0 00 1111 O0 O000 O0 0000 11 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 I 1 00 O0 00 O0 00 00 ! 1 0000 OO 0000 uO I 1 000o gO 00o0 O0 11 00 0o 00 O0 ! 1 00 O0 O0 O0 1 1 00000o 0o0000 I 11111 000000 000000 1 I l I 1 l ,static, USkR PCAL [10701,b11241 dOB SHIP SEO. ~ILE: DSFH:¥EPI["¥.O0~.<05.7>[10707,6.11241 CHEATED: PHIN~[EU: 1~ DEC ~0 0():54.25 gUEUE ,9~i~CHE~: /~II,E:FORT /¢OPIE~:I /SPACING:I /I,[M1T:129 /FOP~S:NURMAL ~792 DATk, I6-DEC-80 16-0EC-80 00:51:04 00:5]:59 I,tS V~,HSIIJN 15oH01 79/0 ]/26 8CHLL1MBgRGgR CO~,IP1JTING Cf, NTtR 10707~61124 F<:F, kI, HI' AI.)LR TAPE [)ATE: R0/12/lo TAPF, H [~,A D f'H I,F, NG I'tl TAPE N SI',HV lC TAPE C PRLVIU T AP I)]L H CASIN SP ~ 1)kNb V [SC FLUID A~E: 61124 E NAN[..: I:,D IT ON r]N[JATION N ti ;'4B[-,H: O1 US TAPE NA~g: tJN ~ 1, L(JGGkI) 24-OCT-80 G D~Ii.D~,~ = 10.75 I 8. 750 IN. DATE: 80/12/10 ZE = Fl, [gOT RECfJI~D~,D iN JIlL-BASE MUD / DIL & IN THE HOLE : 1NVER~IUD = 10,40 = 64,00 = 0.0 LOSS : 6.80 t'lL BHC .RUN IN COMBO F [I,k HkADEH I,ENGIH: 02 BYTES F ILk NANE: EDiT .001 HAXI~,IUM PHYSICAL RECURt) LENGTH: 1024 BYTES PR~VItJIIS f lL~, NAME: FILE COMMENTS SP ~ SFL NOr AECI]HDkD 1N OiL-BASf MUD / D1L COMPANY : ATLANTIC RICHFIELD C WELl, : ~UPAHIIK 1)=7 ~ IEL[) : KUPAHIIK C[JIJr~TY : N. STATE : ALASKA DgN~tTV : ~00. BHC HUN IN COMBO 4-)A'rA [,IJ'~"'f'~IA'I' ,%PEC I'!- ICAT.I. UN I,I~,NG TH: %70 ~,, I',! T R ¥ BLOCKS: 'IYPE 0 $1ZE 1 REP C ({ I") I~., 66 0 ~)AT~JF~ ,SPECIF ICATII)N HglJCg8: iJNlr APl AP1 API API FILE SIZE SAM HEP PHCICESS INDICATORS ? 'r 0 0 0 0 0 4 u H t~l Iq 7 12 44 0 0 4 1S 0 0 0 0 0 4 GAl-' I 42 ~1 32 0 0 t IN 42 28 1 0 0 4 G/C ] 42 41 0 0 0 4 PO 42 b8 2 0 0 4 (;/C 3, 42 35 11_ 0 0 4 C/C 42 42 1 0 0 4 CPS 42 ]~ 92 0 0 4 CPS 42 ~ ~ q ] 0 0 4 GAPI bO ]1 32 0 0 4 US/F O0 52 32 0 0 4 1 b8 1 68 1 68 1 6~ 1 68 I b8 1 68 I 68 1 68 1 68 I 68 USkt~ l)~.~[Nkl) (:ill~PtJ'l' AR.RA~' OUTPII~ IUD Al 2 OUTP!! r ILN A~I 3 OUTPIIT GH A'[ 4 ourpu'r c,~ AI 5 OUTPUT CALl AT b OUTf'I1T D~Hf} A~ 7 OUTP~]~ NPMI A'[ 8 OUTPI1T RHC)B A'[ 9 UUTPdT NRA~ A~ 10 OUTFIJT NCNL AT Il uu'rPIIT FCNL ~l 12 OUTPIIP G~ A~ 13 OUTPUT DT A~ 14 I)EI.;'I~ 8570.000 8500.000 B 100. 000 B300.000 q200.O00 8100.000 qo00.O00 7900.000 7q00.O00 7700.000 7600. 000 MNEM~JN lC II~D CALl NRAT DT i IJ D CALI NRAq[' DY llJI) CALl NRAT DT II~D CALl NRAT DI' 11413 CALl NRAT L)T lhg CALl NRAT DT CALl NRAT D T ILO CALl NRA~ DT 1 L i) CALl NRAI' UT ll,P CALl NRAT II~i) CALl NRAT Dr VALUE 1.744 8.750 3.219 105.188 2.152 8.781 3.344 104.56~ 2.0g~ 8.8J6 ].264 105.750 2 .bi5 8.836 3.488 105.188 ).941 8.90~ 2.951 96.375 5.871 9.102 2,732 90.000 42.000 8.8q~ 3.057 Ob. 000 1.542 9.469 3.058 116.000 2.311 9.27 ~J 3.459 110.188 2.225 9.086 ~.324 104.000 2.744 9.2~4 3.44~ 109.000 ~NEMONiC DRHO NCNB IBM NCNB ! LM D t4 H (3 NCNB DRHO NC N L DRHU NCNL DRH{) NCNL ILM DRHO NCNB DRHO NC{IL ILM DRHO NCNL ILM DRHO NCNL DRHU NCNL VALIJE ~ 1.981 0.089 1838.000 2.275 -0.O01 1800. 000 2.lo6 0.000 1814.o00 2.730 0.003 1761.000 4.059 -0.009 20]5.0OO 6.117 0.015 2248.000 51.500 0.033 1762.000 1 .bTO 0.031 1547.000 2.463 0.008 1644.000 2.301 0.006 1735.000 2.947 0.000 1849.0n0 MNEMONIC VALUE 1447.000 44.97l 585.500 97.~75 40.234 556.000 107.313 38.721 554.000 91.750 42.77J 536.500 88.063 32.666 685.000 67.025 29.35'~ 860.000 56.813 34.961 583.000 117.188 44.873 420.750 119.313 41.602 497.500 358.000 39.453 537.000 145.750 41.35! 522.CJ' MNEMONIC GR RHOB GR G~ RHOB GR GR RHO8 GR GR RHOB GR GR RHUO GR GR RHUO GR GR RHUB GR GR RH(JB GR GR RHtJ~ GR GR RHUB GR GR RHOB GR VALUE 129.025 2.072 1447.000 125.025 2.416 97.375 122.813 2.430 107.313 114.813 2.408 91.750 108.188 2.~12 88.063 90.250 2.402 67.688 2.813 56.813 139.815 2.336 117.188 150.375 2.379 119.313 405.000 2.355 358.000 185.375 2.377 145.750 Db, t"r H 7500. c)o0 7'1,00. 000 7]00.000 7200. 000 7100.000 7000.000 6900. 000 h~lO0,O00 6700.000 6600.000 65O0. 000 NNLMr)NIC 1LD CALl NRA1 D? 16 i) CA61 NRAT DT I L D CAI,I NkAT D? I hD CALI NRAT 01' I6D ¢A6I NRAT DT ILD CALi NRAT DT II, D CALi NRA'I' D~ 1 I~D CALI NRAI DT IhD C~61 NRAT DT II,D CALl NRAr DT I CAhI NRAT DT VALUF. 2.355 9.102 3.406 107.56~ 1.78b -999.250 -999.250 108.000 2.)69 -999,250 -999.250 107.]75 3.021 -999.250 -999.250 105.563 2.588 -999.250 -999. 250 lll.5bJ 2.]]4 -999.250 -999.250 101.18R 1.57) -999.250 -g99.250 100,000 1.44] -999.250 -999.250 112.188 1.802 -999.250 -q99.250 112,000 2.105 -999.250 -q99.250 100.750 2.512 -999.250 -999.250 101.375 MNLMUN [C DRHU NCNi-, li,M DRHO NCNb DRHO NCN~ II_,M IDRHO NCNG I[,M DRHU NCNL ILM D}~HO NCNL DRHU NCNL DRHO NCNL DRHU NC NL II,M DRHO NCNb i6M DEHL) NCNL VAL'iF, 2. 0. o 07 1951.600 2., 10 -999,c/50 -999.250 ?. '%4! -999.250 3.t31 -999.25n -999.250 2.740 -999.250 -999,250 2.289 -999.250 -999.250 1.720 -999.250 -g99.250 1.470 -99g.250 -999.250 1,845 -999,250 -999,250 2.137 999.250 '-999.250 2,527 -999.250 -g99,250 MN~M(JN1C GR NPH 1 fCN~ GR NPHI fCNb GR NPH 1 [;CNL GR "Pnl b-CNL GR NPHI G~ NPHI ~CNL GR NPHI [~CNL GR NPHi ["CNL GR v, Ph 1 FCNL GR NPHI FCNh GR NPMI ~CNL VALUE 121.~138 40.918 560.500 96.250 40.869 -999.250 118.125 52.979 -999.250 120.625 ,~5,8 lO -999.250 lb9.875 37.793 -999.250 175.J75 36,426 -999.250 137.750 37.646 -999,250 135,625 50.830 -999.250 142.625 i3.8'~6 -999.250 91 .b25 40.1 37 -999,250 85.000 39.697 -999,250 MNF.,MUN IC GR RHL1B GR GR RH()B GR RH~)B GR RHOB GR RHOB GR GR RHr)B GR GR RHUB GR GR RH00 GR RHtjB GR RHOB GR VAbUk 150.875 2.414 121.438 -999.250 -999.250 96.250 -999.~50 -999,250 118.125 -999,250 -999,250 120,625 -999.250 -999.250 169.875 -999.250 -999.250 175.375 -999.250 -999.250 137.750 -999.250 -999.250 135.625 -999.250 -999.250 142.625 -999.250 -999.250 91.625 -999.250 -999.250 85.000 6'100,000 6 ~00. 000 bTO0.O(}O 6100.000 6000.000 5900°000 5800.000 5700.000 5600.000 5500.000 5400.000 MNkM(~NIC CALl NRAT 1 CAI, i NRAT BT 1 LD CALI NPAT DT ILL) CALl NRA'[ OT I I,D CALl N R A T DT II,D CAI, i NRAr DT I LD CgLI NRAr PT ILl) CALl NRAT IIJD CALl NRAT DT II, D CAI,I 11,1) CALl NRAT DT 2 -999 -99q 95 2 -999 -999 104 2 -999 10~ 2 -q99 -999 102 2 -q99 -999 10~ -999 -999 102 3 -999 -999 100 3 -999 -999 lO2 -999 -999 109 -999 -999 109 -999 -999 111 .5~ .25 .25 .00 .34 .25 .25 . ~'1 .586 .250 .250 .000 .089 .250 .250 .000 .250 .250 .000 .438 .25n .250 .75o .260 .250 .250 .188 .b21 .250 .250 .188 ,250 .250 .375 .367 .250 .250 .5b] .145 .250 .250 MNEMONIC ILM DRHU NC N b IbM DRHO NC N L ILM DBHO NCNL ILM DRH(.J NC NL ILM DE, HO NCNL IbM DBHt) NCNL DRHU NCNL DRHO NCNL IbM DBHO NCNb ILM DRHO NCNb IbM DP, H{] NCNL 2.607 -999.250 -999,250 2.]65 -999.250 -999.250 2.627 -999.250 -99q.250 2.725 -999.250 -999.250 2.732 -999.250 -999.250 3.430 -999.250 -999.250 3.234 -999.250 -999.250 3.693 -99q.250 -999.250 3.203 -999.250 -999.250 3.402 -999.250 -999.250 3.133 -999.250 -999.250 MNkNONIC GR NPH I ~CNL NPH 1 FCNL GR NPHI t'CNL GR NPH1 ~CNL GR NPHI ~CNL GR NPHI ~CNL GR NPH1 FCNL GR NPHI ~CNL GR NPHI FCNL GR NPH1 FCNL GR NPHI FCNL VALUE 94.375 33.838 -999.250 86.938 36.133 -999.250 97.438 29.443 -999.250 101.125 31.101 -999.250 88.125 41.84b -999.250 85.938 J8.574 -999.250 79.875 31.104 -999.250 91.125 39.746 -999.250 113.4t8 38.710 -999.250 93.188 40.332 -999.250 98.750 39.160 -999.250 GR RHOB GR RHI)B GR GR RH(}B GR GR RHUB GR GR GR GR RHOB GR GR RH~)B GR GR RHOB GR GR RHUB GR GR RHOB GR GR RHUB GR VALUE -999.250 -999o250 94.375 -999.250 -999.250 86.938 -999.250 -999.250 97.438 -999.250 -999.250 101.125 -999.250 -999.250 88.~25 -999.250 -999.250 85.938 -999.250 -999.250 79.875 -999.250 -999.250 91.125 -999.250 -999.250 113.438 -999.250 -999.250 93.188 -999.250 -999.250 98.750 5 ~00.000 51 O0. 000 5000. 000 4900.000 4800,001) ~700.000 %6O0.00o 4500.000 4400. oo0 4301). o00 CALl NR AT DT £1~D CAI, I NRAT l)T [ i,D CAI,I NRAT UT CAI, I NRAT DT CALI NRAT DT 1 I~D CAI,/ II~D CALl NRAT DT bi,l) CALl N~AT I.)T II,D CALI NRAT DT ll~i) CAI, i NRAT DT IL, l) CAL'i NRAT DT VALUE J.742 -q99.250 -999.250 112,000 J.246 -999.250 -999.250 112.188 6.941 9.895 3.205 111.750 4.055 9.930 ~.5~1 111.188 ].701 9.875 3. ~177 I I 3.56_3 14.531 9.234 3.250 128.000 6.961 9.398 3.420 12J.188 5.824 9.898 3.303 170.188 15.594 9.O17 ].250 118.375 7.848 10.]sq ].322 11 ]. 375 7.449 ).59n 1 34. 375 NNEMtINIC iI~M DRHU NCNb IbM DRHU NCNb DRHt} NCNb, DRHtl NC N L DJ{HO N C N L ibm DRHU NCNb DRnO NCNb IbM D R H o NCNb I1,M DRHLI NCNb 1LM DRHO NCNL DRHO NCNL VALUE' 3.611 -999. 250 -999.250 3.227 -g99.250 -999.250 7.207 -0.002 1835.000 ].867 -0.005 1759.000 ].480 0.000 1607.000 16.141 -0.010 1855.000 6.559 -0.007 1771.000 5.469 -0.003 1712.000 15.167 -0.004 1788.000 7.645 0.012 1953.000 7.56] -0.00] 1682.000 MNE~ON1C GR NPH1 ?CNL GR NPHI ~CNL GR NPHI ~CNL GR NPHI ~CNL GR NPHI ~CNL NPHi ~CNL GR NPHI ~CNL GR NPHI FCNL GR NPH1 ~CNL GR NPHI fCNb GR NPHI FCNL VALUE 81.438 46.924 -999.250 88.003 42.041 -999.250 83.~38 36.377 600.500 75.938 41.943 546.00'3 80.06] 41.016 498.500 02.469 37.891 553. 500 57.511 40.820 522.500 ;1.188 ~8.965 499.250 58.~88 37.354 577.000 79.813 37.549 623.000 54.781 41.650 486.50O MNEMONIC GR RHOB GR GR RHUB GR GR RH(.IB GR GR RH(JB GR GR RHOB GR GR ..IR HOB GR GR RHtJB GR GR RHOB GR GR GR GR RHOB GR RHOB VALUE -999.250 -999.250 81.438 -999.250 -999.250 88.06] 101.938 2.236 83.438 9].875 2.252 75.938 107.688 2.270 86.06] 73.938 2.092 02.469 75.313 2.150 57.5J] 93.750 2.275 71.188 78.875 2.248 58.888 101.875 2.373 79.813 16.125 2.170 54.781 <;200.000 4 ! O0. 000 4000.00O ~qo0.O00 3ilO0, ~700. 000 3600. 000 3500. O00 ]400.000 ]]00.000 3200.000 tqNk bil]N Il,I) CALl NRAT DT i1~I) CALl N lq A '1 DT 1 lid CAI~I DT CAI, I NRAT DT I1~1) CAI, I NF~A7 l) T 1 L D CALl NRAT Il,l) C AL l NRAT 11,I) CALl NPAT DT II,O CALl NPAT DT ILO CALl NRAT DT 1 Iii) CAbI NRAT DT VA 1 ! 12 13 1 11 1 14 1 13 1 11 1 13 1 lb 1 1 15 1 14 L I.JE 7.38 0.19 3.43 7.56 2.25 9.39 3.39 9.10 9.32 ~.31 ] .50 8.914 0.102 3.178 8.750 2.688 9.570 {.625 3.375 5.95] 9.617 ].56~ ] .000 1.156 9.117 3.2q3 5.56~ 6.418 0.219 4.191 1.375 3.969 9.805 3.381 2.125 1.023 3.346 1.375 6.234 0.188 ].891 1.125 IbM DRH(} NCNb I) R H 0 NCNb IbM DRHIJ NCNb ibm DRHO NCNL 1LM ORHU NC N L 1bM DRHO NCNL 1LM DIRHO NCNL DRHU NCNb I LM DRHU NCNL DRHO NCNb 1bM D R H O NC NL VA'bilE 7.141 -0.004 1752.n0n 11.625 0.003 1891.000 9.219 -O.007 1796.000 8.578 -0.005 ! 742. 000 1].484 -0.012 1886.000 16.141 -0.006 1622.000 11.273 -0.006 1773.000 b.207 -0.001 1630.000 13.016 -0.020 1725.000 12.117 -0.016 1868.000 5.730 -0.001 1 392. 000 MNEMON lC GR NPH 1 FCN GR NPHI FCNL GR NPHI FCNL GR NPHI FCNL GR NPHi FCNL GR NPH1 ~CNL GR NPH1 FCNb GR NPHI FCNL GR NPHi FCNL GR NPHI FCNb GR NPHI FCNL VALUE 55.938 39.746 487.500 65.875 40.283 574.500 49.000 39.014 559.500 58.688 ~5.303 531.500 38.969 44.189 480.500 53.688 42.969 398.750 48.438 38.867 588.000 68.375 53.369 403.000 48.750 39.404 515.500 45.8'15 37.305 552.000 64.938 48.047 358.750 MNEMON lC GI~ RHUB GR GR RHI)B GR GR RHOB GR GR RHUB GR GR RHUB GR GR RHUB GR GR RHOB GR GR RHOB GR GR RHUB GR GR GR GR RHOB GR VALUE 82.188 2.234 55.938 90.000 2.219 65.875 bl.Ob3 2.072 49.000 78.625 2.258 58.688 49.875 2.047 ]8.969 74.500 2.1{1 53.688 68.438 2.176 48.438 83.250 2.178 68.375 57.531 2.055 48.750 53.219 2.098 45.875 79.750 2.133 04.938 OLPTH ]100.000 ~NF MI)NIC l ]~13 CALl NRA'[ DT 1 LD CALl NRA£ DT VALUE 9.3~7 3.758 55.000 -999.250 -999.250 -999.250 -999.250 ILM DRHO NCNL 1651 NCNL VALIJL 2000.000 -0.423 1160.000 -999.250 -999.250 -999.250 MNENON1C VALUE GR 43.781 NPHI 46.875 FCNL 331.500 GR -999.250 NPHI -qgg25.000 ~CNL -999.250 MNEMONIC GR RHI]H GR GR GR VALUF 45.406 2.100 43.781 -999.250 -999.250 -999.250 %.._ J DATA PEC(IF.D$ NIIMBL~ (Il:; ~ECIIRDS." 61 I,I.'.,NG'IH C{l" RECUHL),S: 1014 B~'I'LS i- [I,E lkAiLFI~ I,ENGTH: b2 F II.,F., NAZi".: t',l)l'l .001 f,4AXtIvlI. JM pHYSICAL RL, CI)I'-<I.) LENGTH: NF.,XT ['JI.E NAME: , 4, 4, * 4,. * t".~ IF I,F~,NG rH: Il,F, NA~E: NtA,K ]. MUN P~EV l , :, , , 4'. 1024 BYTE8 .t. * * * * * b2 B ~' TE,S ED IT ,002 PHYSICAL {-~ECLJ~D LENGTH: FI'LE NAME: 1024 I)&TA l'tllqMA~I $1.~EC1F ICATIflN I,F, NGI'}t: 90 ErITR¥ P, LUCk,S: IYPE 0 SIZE 1 REP Ct}DE ~6 DATIIM ~"'~CIF ICAT]I}N DL(ICKS: ~ NA~4F IiIIJL IIN1F APl API AP1 APl FILE SIZ~ SA~ REP PBfiCESS INDICATORS '1 D~,PT F T 0 0 0 0 0 4 I 68 2 N~I~/, 0 0 O 0 0 4 1 68 OSkR I)F, F J~kD Otl~u'l ARHAi r)LPTH ~570.000 8500.000 ~00.000 R2OO.O00 8100.000 ~000.000 7900°000 7~00.000 7700.000 7600.000 7500.000 74O0. 000 7300.000 7?00.00O 71 O0. 000 7O00. 000 6900°000 6800.000 6700.000 6600.000 6500.000 6400.000 6 ~00. 000 6200.000 6100.000 fiO00.O00 5900.000 5Roo.oon NNF r41}lq IC N IJ 1~ L NIILL 1,1 U !~ L NULL N U I~L NIJI, L NIJI, I, NI. Ji~L I',IIILI~ NIJI,L Nlll,h NIII,L NIII~L NIII~L NIILL NI.II,L NllLL NllLL N IILL NIJI,L NIILL NIJI, L NULL NIII,L N i I la L NIJ [aL NllLh VALUE 8569.500 8499.500 R 399. 500 [4299.500 8199.500 8099. 500 7999. 500 7899.50,) 7799.500 7699.500 7599. 500 7499.500 7]99.500 729g.500 7~99.500 7099.500 699g.500 tSgg.500 b7gg.50n 66gg.500 6599.500 b4gg.500 6~99.500 6299. 500 6199.500 6099.500 5999.500 5899.500 5799.500 l~[, I:, q~'W'' 5700. 000 5hO0. 000 5500. 000 5 lO0. 000 5300.000 5200.000 51 O0. 000 5000. 000 ~9()0. OO0 ~,RO0. 000 470O.O0O 4600.000 ~500.000 44OO.OOO 4300.000 4200.000 4100o000 4000.000 ]qo0.oO0 ~800.00o ]'/00.000 ~600. O00 :~500.000 ]400.000 3300.000 3200.~00 3100.000 3001.000 hill,I, NIILL N[II,L i~1 lJ L L NIJI.~I~ NIII,L, Nlil~I, f,~ Ij I,L N IILL NIILI~ I"J U l.~ L NilL{., NULL NIII~L NIJI,[, Nllhl~ ti IJ L b fl ULL NIJLL NIII.,L NIII~L NULL hi Il NIILL NIJI~L, NIIL~ VALUE 5h99.500 5599.500 5499.500 5399.,500 5.999.500 5199.500 5~)99.500 4949.500 4899.500 4'/99.500 4~qq .500 1599.500 4494.500 4399.500 4299.500 4199.500 4099.500 3999.500 ]899.500 ]'/99.500 ]699.500 ~599. 500 3499.50n ] :~99.500 3299.500 3199.500 :1099.500 3080.500 NiI~HEi:~ i']F PkC[JBIJ,S: 44 I,[..NGIH U[' BkC(.JHD,$: 1022 ],[.,NGT[t rjF LAST I~kCURi): 242 BY'rES F II, E TRAit, E[-' I,i-,NGI H: 62 ~ [l',k NAI~P]: EDIT .002 N1AX[MUM PH¥51CAL I'~'F.,CJIRI) LENGTH: FII,E HEADEP i,[-,NGTH: 62 BYTk,,S P" 1: r,F, NAME: i~ D I'I .00_~ MAX[~JJ[~ PHYB1CAI., RECI. JRD LENGTH: PREVIOUS FILl.. NAME: 1024 BYT&S , * , , , , , , , * , 1024 BiTkS D./~rA F~T SPECI~ ICATI[~,~ I,ENG'IH: qo B~ t'ES F.I',II R ~ BI,t. JCKS I 'I ¥ [; ~ 0 SIZE 1 I~EP CQDE 0 F)AI'IIM SPECI~ ICAq IlJN NAME 'Ill(iL UNIT APl AP1 AP1 AP1 FILE SIZE SAr~ REP PR{JCESS INDICATORS ~)~ PT ~ T 0 0 0 0 0 4 1 b8 NltLL 0 0 0 0 0 4 l I)EPINEI) UUIPUT ARP, AY 8570.000 ~500,000 ~400.000 t3 ~00. 000 q200.O00 RIO0,OO0 RO00. 000 7qO0.O00 7R00. 000 7700,000 7600.000 7500.000 7400.000 7~00.000 7200.000 7100.000 700O. 000 6900.000 6RO0.O00 6700.000 6~¢)0. 000 O500.000 ~ ~00. 000 ~00.000 6200.000 b 1 O0. 000 6000. 000 5900.00O 5~0().000 NIILL NIII,L NIILL N I! LL N~ILI~ N IJbL NIILL NIILL NIJbL NIII. L NIILL NIILL NIIL[, NIIbL, NIILL NI{LI~ NtJLL NIII,L N Ii L L NUI~I, NIII,L Nlll~b NilI,I., NII!~b 8569.500 8499.500 83gq. 50O 8299.500 81qq.500 8099. 500 7999.50~ 7899.500 7799.5O0 7699.500 7599.500 7499.500 739q. 50O 7299.500 7199.500 7099.500 6999.500 6899.500 6799.500 6~99.500 6599.500 0499.500 6~99.500 6299.500 0199.500 6099. 500 5q99.500 5899.500 5799.500 DEPTH 5700.000 5600.000 5500. 5400. 000 5 ~00. 000 5200.000 5100.000 5000.000 4900. 000 4~00.000 4700. 000 4690. 000 4500.000 4<[00.000 4~00.000 4200.000 4100.000 4O0O.0O0 ~9o0. 000 ~00.000 :17(10.000 ~ 6 0 O. 00 0 ~500.o00 3400.0O0 ~J 300. 000 ~200.000 ~IO0.O00 :1081. 000 m I',1E MI Jl'O IC NIJl,b HIII.,L NIII,L NIILL NIILL N IJ I~1, NtJLL NUI~I., NIILI: N l I I.~ 1, N l J L L {',{ U L b NIIL, L NIILI, NIJl,L N U 1., L NULL NULL NIIL, L NIILL NI{LL NIILL N IJ l~ L NIILL IVIILL, I'JIII,L VALUE 5 (,-., 99.500 5599.500 5499.500 5 ~99.500 5299.500 5199.500 5099. 500 4999.500 489q.sqO 4799.500 4599.500 4599.500 4499.500 4 399. 500 4299.500 4199.500 409g.500 3g99.500 ~99.500 3799.500 :{699.500 :1599.500 3499.500 ]399.500 3299.500 ]199.500 3099.500 :{080. 500 DATA RE:CtlPDS NIIMBEF (JF R~.CUt~DS: 44 .I,ENGTH tl~ RECtJRDS: 1022 I,~.NGI'H ('IF I~AST ~ECUPO: 242 I~['.NGIH: 02 l'J ~ T F.S I' Ihk NAME: EDIT .00] MAXINUt~ PH~($1CAb RECORD LENGTH: N[',XT F II,E NAME: TAPE I,ENGI'M: 1 ~2 BYTES rAPE NAMe.: ~)1124 ,SERVICE NAME: EDIT rAPE CONTINUATIUN NIJMHER: O1 NP,~T TAPE NAME: C~)MMENTS: 024 HYTE$ , , , , , , , , , , DATE: 80112110