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Home My WebLink About180-138 Ima ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j~ ~ Q- ._/~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type "{'~[] Other items scannable by large scanner [] Poor Quality Originals: · OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN VINCENT SHERYL~INDY DATE:?,//,~)¢~_ /S/ ~ v Project Proofing BY: ~OBIN Scanning Preparation VINCENT SHERYL MARIA WINDY ~ x30=' ~0 Stage I PAGE COUNT FROM SCANNED FILE: - PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Y~ES .~ NO BY: BEVERL'(~VINOENT SHERYL MARIA WINDY DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: t~.--~..~YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; Is~ General Notes or Comments about this file: Quality Checked {dona) 12/10/02Rev3NOTScanned.wpd . STATE OF ALASKA . REl,;t:.\Vt:.U 1 JUL 0 5 2007 ALASKA Oil AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LO%aska Oil & Gas Cons. Cammission / Anchorage 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory D GINJ DWINJ D WDSPL DWAG D Other No. of Completions Zero D Service D Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband'1 12. Permit to Drill Number Conoco Phillips Alaska Inc. 51)!2.12007 ;.1J,-0 180-138 ...-- 307-155 3. Address: 6. Date Spudded r 13. API Number clo P.O. Box 196612, Anchorage, Alaska 99519-6612 12/10/1980 50-029-20535-00-00 ...- 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/27/1980 Kuparuk 1C-03- 1583' FNL, 1165' FWL, SEC. 12, T11 N, R10E, UM 8. KB (ft above MSL): 94' 15. Field 1 Pool(s): Top of Productive Horizon: .';>" 3991' FNL, 4210' FEL, SEC. 11, T11N, R10E, UM Ground (ft MSL): Kuparuk River Unit 1 Kuparuk River Pool ~" Total Depth: 9. Plug Back Depth (MD+ TVD) 4139' FNL, 4631' FEL, SEC. 11, T11N, R10E, UM 9589 6747 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: 562173 5968656 Zone- ASP4 9700 ./ 6821 ADL 025649 " x- y- ---- 11. SSSV Depth (MD+ TVD) 17. Land Use Permit: TPI: x- 556819 y- 5966205 Zone- ASP4 Total Depth: x- 556399 y- 5966053 Zone- ASP4 N/A 18. Directional Survey DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and Drinted information Der 20 MC 25.050) N/A ft MSL 1650' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): DEL 1 BHCS 1 GR, FDC 1 CNL 1 NGT, Gyro 1 CCL, CBL 1 CCL 1 GR 22. CASING, LINER AND CEMENTING RECORD SETt'II'<IG .DEPTH MD SETTING . DEPTH 1'\1[) : .... .: .:.. reR FT. ../ GRA6E Top .. BOlTOM Top BÒlToM ·.·.SIZE ...... /. ..:.': 16" 65# H-40 Surface 80' Surface 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surface 3214' Surface 2682' 13-3/4" 1500 sx Fondu 250 sx AS II 7" 26# K-55 Surface 9675' Surface 6804' 8-3/4" 725 Sx Class 'G' 23. Open to production or injection? DYes 181 No 24. > UI!ING:;"'Wr<U/<·.<.:..· ..·i.·.. ·':../<0<> ... If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD+ TVD of Top & Bottom; Perforation Size and Number): None # 3-1/2",9.2#, K-55 8983' 8944' MD TVD MD TVD 25. . A¢I¡}. >" .......: ...: :..:::.:...::. ::..... l:"ù""'" .",.",;.:. ...: :: DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED SCANNED AUG 0 3 2007 9164' P&A with 14 Bbls Class 'G' 9118' Kick Off Plug: 17 9103' Cement Plug: 6 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: PRODUCTION FOR OIL-BsL: GAs-McF: WATER-BsL: CHOKE SIZE: I GAS-OIL RATIO: TEST PERIOD ... Flow Tubing Casing Press: CALCULATED OIL-BsL: GAs-McF: WATER-BsL: OIL GRAVITY-API (CORR): Press. 24-HoUR RATE'" 27. CORE DATA Conventional Core(s) Acquired? DYes 181 No . Sidewall Core(s) ACQuired? DYes 181 No If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 MC 250.071. f .æM-rffiìonAÞ~ i None I S"·~¡e·1 .... lRBDMS BFl AUG 0 2 2007 VERIFIED . -..~...... ~ -~.. .,.lJr I - , Form 10-407 Revised 02/2007 OR' GIN ft:tUED ON REVERSE SIDE ~\, /I! .,. z..'1.ô7 ~7~/Þ7 G- .- 28. GEOL~GIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): NAME MD TVD Permafrost Top Permafrost Base Top Kuparuk 9101' 6421' Base Kuparuk 9588' 6746' 29. FORMATION TESTS Well Teste. DYes 181 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. None Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~ Title Technical Assistant Date Oì/D~7 Kuparuk 1 C-03 Well Number 180-138 307-155 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Gary Eller, 529-1979 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only DATE JOB TYPE 08/11/06 Ann-Comm 10/18/06 SBHP/FBHP Survey (11) 10/19/06 SBHP/FBHP Survey (11) 12/25/06 Scale Inhibition 03/03/07 PPROF 03/10/07 Ann-Comm 03/12/07 Ann-Comm 03/15/07 Ann-Comm 04/01/07 Secure Well 04/02/07 Secure Well 04/03/07 Secure Well 04/04/07 Secure Well 04/06/07 Caliper 04/07/07 Caliper 04/09/07 Ann-Comm 04/21/07 Drilling Support - Capital 04/28/07 Drilling Support - Capital 04/29/07 Drilling Support - Capital 05/03/07 Drilling Support - Capital 05/04/07 Drilling Support - Capital 05/08/07 Drilling Support - Capital . . KUPARUK 1C-03A Summary of Well Operations, Pre-Rig SUMMARY OF OPERATIONS TIFL PASSED, MITOA PASSED (WC) ATTEMPTED TAG 1 BHP. ENCOUNTERED HYDRATES IN TREE. TAGGED @ 9384' RKB, EST. 163' RATHOLE. MEASURED BHP @ 9160' RKB: 2798 PSI. C sand Scale Squeeze. Pumped 10 bbls of Seawater pre-flush containing 30 gallons of WAW-5206. Pumped 36 bbls of Seawater containing 200 gallons of SCW-4004. LOG PRODUCTION PROFILE. WELL ON PRODUCTION TO TEST SEPARATOR: 150 BOPD, 720 BWPD, LIFT GAS = 360 MSCF/D. SPLITS: 100% OF PRODUCTION FROM (9100-9136). NO CROSSFLOW OBSERVED BETWEEN ZONES WITH WELL SHUT IN. LOGGED GLS ON RIH. LIFTING FROM GLM #1 (GLV) AT TIFL, ( PASSED). PRE CTD, POT-T( FAIL), POT-IC ( PASS ), PPPOT-IC ( PASS ), MITOA ( PASSED), PT & DO, MV ( FAIL ), SV ( FAIL ), & SSSV ( LOCKED OUT ). POT-T FAILED, PPPOT-T PASSED, PT & DD SV FAILED,DD MV FAILED, PT MV PASSED (PRE CTD) BRUSHED & FLUSHED TBG TO 0 NIPPLE. TAGGED @ 9378' RKB, EST. 157' RATHOLE. SET 2.75" C-A2 PLUG @ 9012' RKB. SET 3.5" SLIP STOP CATCHER @ 5493' SLM. PULLED OV & GLV @ 5399' & 2719' RKB. SET DV @ 2719' RKB. IN PROGRESS. LOADED TBG & IA WITH DSL. SET DV @ 5399' RKB. TESTED TBG 2500 PSI, GOOD. ATTEMPTED NEGATIVE TEST ON TBG, FAILED. MIT IA PASSED. PULLED CATCHER SUB & CA-2 PLUG @ 9012' RKB. IN PROGRESS. SET 2.75" CA-2 PLUG @ 9012' RKB. TBG TEST FAILED, SUSPECT DAMAGED 0 NIPPLE. PULL 2.75" CA-2 PLUG. SET 2.81" XX PLUG IN SBR @ 8947' RKB. TEST TBG TO 150 & 2500 PSI, GOOD. IN PROGRESS. SET A-2 PLUG ON 2.81" CS-LOCK IN SSSV @ 1871' RKB. TESTED TBG 2500 & 250 PSI, GOOD. PULLED 2.81" A-2 PLUG @ 1871' RKB. PULLED 2.81" XX @ 8947' RKB. IN PROGRESS. LOGGED CALIPER SURVEY FROM 9262' RKB TO SURFACE. SET 3/16" OV @ 2719' RKB. PRE-CTD, MV-PT - PASSED, MV-DD - PASSED, SV-PT - PASSED, SV-DD - PASSED SET 2.75 CAT STANDING VALVE IN D-NIPPLE @ 9012' RKB. PULLED OV FROM STA # 1 @ 2719' RKB. CIRCULATED 105 BBLS OF DIESEL DOWN TBG, UP lA, AND DOWN FLOWLINE. SET DGLV IN STA # 1 @ 2719' RKB. MIT IA TO 2500 PSI ( PASSED). PULLED CAT STANDING VALVE @ 901 MILLED D-NIPPLE AS PER PRE-CTD PROCEDURE TO 2.80"I.D.@ 8984' CTMD, ABLE TO DRIFT THRU PROFILE WITH PUMPS OFF WITH NO WEIGHT CHANGES. MILL GAUGED OUT AT 2.795" - 2.80" 0.0. RETURN IN THE AM FOR CEMENT STAGE AS . PER PROCEDURE. SPOTTED 14 BBLS 15.8 PPG CEMENT IN 7" CASING 9384' CTMD TO 9010' CTMD. / FCO'D TOC TO 9155' CTMD AS PER PROCEDURE WITH 1.5# BIO ZAN AND SLICK SEAWATER WASHING JEWELRY WHILE POOH. EST. TOC 9160' CTMD. WELL FREEZE PROTECTED WITH DIESEL TO 2500' TAGGED CEMENT TOP @ 9164' RKB. Lay in 17 ppg cement plug from 9164', wash down to 9003' with biozan. FP well with 25 ./ Bbls diesel and left well shut in with 400 WHP. TAG CEMENT AT 8993' RKB (IN TUBING). LOCATE GLM #6 AT 8871' SLM/8881, RKB FOR CORRECTION FACTOR. Page 1 . . KUPARUK 1 C-03A Summary of Well Operations, Pre-Rig DATE JOB TYPE SUMMARY OF OPERATIONS FISHED 29.5' OF 5/16 MONO CABLE. TAGGED CEMENT TOP @ 8992' RKB WI 2.65 IMPRESSION BLOCK ( IMPRESSION OF CEMENT). RAN 2.5 PUMP BAILER DOWN TO CEMENT TOP AND RECOVERED SMALL PIECES OF CEMENT AND LITTLE OS/24/07 Drilling Support - Capital BROKEN PIECES OF STRANDS. ( JOB COMPLETE ). PERFORMED 30 min SBHPS @ 8900'= 2981 psi, 150 deg F. 15 MIN GRADIENT STOP MADE @ 8800'. SET GLV @ 2719' & OV @ 5399' RKB, PERFORMED DRAWDOWN 06/13/07 Drilling Support - Capital TEST ON fA TO VERIFY SET. JOB COMPLETE. Page 2 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/18/2007 09:00 - 10:00 1.00 MOB P PRE Nordic 2 mobilizing to Kuparuk 1 C-03 Rig at Hot Water Plant at 10:00 hrs 10:00 - 00:00 14.00 MOB P PRE Rig mobilization. Camp on location at 1 C-03 at 14:00 hrs. 5/19/2007 00:00 - 06:00 6.00 MOB P PRE Nordic 2 mobilizing to Kuparuk 1 C-03. Rig is at the Kuparuk river bridge at 00:00 hrs. Crew change with rig at MPU tumout. 06:00 - 09:00 3.00 MOB P PRE Moving rig from MPU turnout to Kup 1 C-03. 09:00 - 10:15 1.25 MOB P PRE Travel from KOC to 1-03 Arrived on location at 10:15 hrs. 25 hours travel time from DS4 to 1 C-03 10:15-11:00 0.75 MOB P PRE RU to set rig mats and spotting rig in front of well. Hold PJSM with DSO and crew and backing over well. 11 :00 - 12:00 1.00 MOB P PRE Back over well. 12:00 - 15:00 3.00 MOB P PRE Rig Accetped at 12:00 hrs. Install 3-1/2" X 7-1/16" cross-over spool NU BOP's 15:00 - 18:00 3.00 MOB P PRE NU BOP's and installing SLB's Power Pack on rig Checking the bolts on the tree. They were loose to say the least. Taking on fuel and rig water. 18:00 - 18:30 0.50 MOB P PRE C/O & PJSM & THA with day crew. 18:30 - 19:30 1.00 MOB P PRE Tree & BOPE bolts are tight. PJSM prior to skiding & shiming rig center over well. Clean out WHP port flange on BOPE. 19:30 - 21 :00 1.50 MOB P PRE SLB traction motor is installed & running, LOTO has been removed. Hook up kill & choke lines. RU handy berm. Spot 110% tiger tank. Spot cuttings box. BHI is rigging up & testing down hole tools for first BHA run. Get BOPE measurements for schematic. ASRC drilling group is rigging up hardline from flowback tank to rig. 21 :00 - 23:00 2.00 MOB P PRE SLB is pulling drive plates from reel package. RU 7" lubricator w/ new o-rings to top of annular bag. Install 7" lubricator cap under RF. RU BOPE hoses. Install fuseable cap & bleed off SSV actuator to 0 psi to a bucket. Label RF, SLB Ops cab & Koomey unit BOP controls. 23:00 - 00:00 1.00 MOB P PRE Function test BOPE. Fill stack with water. Cycle swab & master to fill voidage on tree. Drain stack & pull 7" lubricator & replace cut o-ring on top of annular bag. Fill voidage again. Drain stack & pull ram door on lower BOP & repalce cut o-ring. Fill voidage again. Post permit to drill in Ops cab, Dog house & Co.Rep shack. 5/20/2007 00:00 - 03:25 3.42 BOPSU P PRE Start BOPE test. Waived by John Crisp. Chart via chart & CCAT. Full body test against SV. Test blind/shear rams on choke side. Test valves #9,#10,#11,#13, Kill HCR & manual gate valves. Test valves #3,#4,#7,#8,#11 & manual kill. Test valves #1,#2,#6,#12. Grease HCR valve. Test valves #1,#2,#5,#12 & manual kill & BOP #17 valve. 03:25 - 03:45 PRE SLB hydraulic leak on the traction motor has been fixed. Reel drive plate have been installed & torqued in place. Install reel bushings. Rig up Swaco choke & CTDS screen for PBD. Begin testing lower most 2" pipe/slip rams with test joint. Load 290 bbls of 2% KCL for milling operations into pits. 03:45 - 04:20 PRE PJSM & THA prior to lifting reel into reel house. Test 2" upper pipe/slip rams with test joint, manual choke & BOP #18 valve. Test choke HCR & manual kill. Pull 2" test joint & run 2-3/8" test joint. Test 2-3/8" pipe slip rams & kill HCR. 2" e-coil is secure in the reel house. 04:20 . 05:30 PRE Test annular bag. Install reel drive securing plates. Hook up Printed: 6/11/2007 11: 19:39 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 inner reel iron. Perform drawdown test on accumulators. BOPE test was successful. 05:30 - 12:00 6.50 RIGU P PRE Install wellhead gauges and guards. RU hardline and bulk head in reel. BHI checking tool and testing same Megged line and OK. Working to locate a FMC hand to pull BPV. Found him on Nordic 3. Changing gripper blocks from 2-3/8" to 2" Ordering out tools for cement ramp window. 12:00 - 14:45 2.75 RIGU P PRE Set stripped on well, PU injector head and lined up goose neck to injector top drive. Clean ice and snow from reel. Measured cable on winch for pulling CT across for replacement later. Installed 2" grapple in CT to pull across. 14:45 - 15:00 0.25 RIGU P PRE Held PJSM and discusses the SOP's and mitigated the hazards. 15:00 - 15:45 0.75 RIGU P PRE RU and pulled tested, OK, tighten grapple and pull CT across the pipe shed. 15:45 - 17:30 1.75 RIGU P PRE Set injector back and RU to pull BPV. Pull BPV. 17:30 - 18:00 0.50 RIGU P PRE LD BPV lubricator & equipment. PU injector & MU 7" lubricator & stab injector on well. 18:00 - 18:30 0.50 RIGU P PRE C/O with day crew. PJSM & THA prior to conduction slack management. 18:30 - 21:00 2.50 RIGU P PRE Fill coil. Pump 10 bbls of methanol into reel followed by 2% KCL w/ 2ppb bio water @ 0.5 bpm (reduce risk of bird nesting e-line). 21 :00 - 21 :20 0.33 RIGU P PRE Coil is full of water. SO, bleed off & pop off to check end of wire - ok. Stab on & reverse circulate, 3.00 bpm @ 3800 psi. E-line cable is moving, moved for -8 bbls. Stop reverse circulating, try one more time to make sure cable won't move. Cable is not moving. Stop pumping, bleed off & pop off. 21 :20 - 21 :35 0.25 RIGU P PRE Start cutting coil to find end of wire. Cut 18' of coil to find end of wire. Test e-line via meg - ok. 21 :35 - 22:00 0.42 RIGU P PRE Install coiled tubing dimple connector. Pull test to 35k. Re-check dimple connector. 22:00 - 23:30 1.50 RIGU P PRE BHI is heading up. Test e-line after UQC has been installed - ok. 23:30 - 00:00 0.50 RIGU P PRE P.T. coil connector to 4000 psi - ok. P.T. inner reel valve per AOGCC BOPE test - ok, charted via SLB. PJSM & THA prior to picking up BHA. Simultaneously, complete slack management by pumping down coil - 1 coil volume. 5/21/2007 00:00 - 01 :45 1.75 RIGU P PRE Completed slack management. Open master valve to closed BS & check for pressure. Brand new Hughes mill won't make up to BHI motor. Threads have been cut wrong. Choose another mill, 2.74" No Go 2.75" go on a 0331. MU BHI BHA to motor & mill. Stab coil onto BHA. Power up & check tools. Tag up & set depths. Divert returns (diesel) to T.T. 01:45 - 04:10 2.42 STWHIP P WEXIT Open EDC & RIH. BHI depth not reading correctly, continue in hole. BHI ops cab does not have computer access to down hole tool. Sit down @ 1881' (TRDP). Wake up BHI day crew. Reboot BHI's computers. Close EDC & bit assist our way past. Close EDC. RIH pumping min rate. 04:10 - 04:15 0.08 STWHIP P WEXIT Weight check 15.5k up, 8k down. 04: 15 - 04:35 0.33 STWHIP P WEXIT Continue RIH. VP's = 173. 04:35 - 04:40 0.08 STWHIP P WEXIT Weight check 24k up, 10.5k down. 04:40 - 04:45 0.08 STWHIP P WEXIT Continue to RIH. Take returns out to Tiger Tank (Crude). Order Printed: 6/11/2007 11:19:39AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/21/2007 04:40 - 04:45 0.08 STWHIP P WEXIT more fluids. 04:45 - 05:15 0.50 STWHIP P WEXIT Log down with CCL across GLM #2 & GLM #1. 62 bbls in Tiger Tank and getting a little gas. Tag up at 8930'. Log up with GR at 300fVhr. Not much GR character to tie-in. Closed EDC and RIH to tag at 8930'. Getting gas/oil to surface, take fluid back outside. 05:15 - 06:45 1.50 STWHIP P WEXIT Volume of pits low, ordered 290 bbl from Deadhorse via Veco. Open EDC and circulate bottoms up until cleans up and 290 bbls of new fluid arrives. 06:45 - 07:12 0.45 STWHIP P WEXIT Circulating Qp = 1.67/ 1.67 bpm at 2400 psi Density = 8.54 8.47 ppg. Holding 100 psi on wellhead. Off loading fluids. SO pump and closed EDC 07:12 - 07:35 0.38 STWHIP P WEXIT RIH and set down at 8927 ft without motor work. Worked through to 8,950 ft. PUH to 8,880 ft to log GR tie-in at 8,910 ft. 07:35 - 08:20 0.75 STWHIP P WEXIT Log from 8,880 ft to 8,950 ft Corrected -5 ft GR spike at 8,914 ft RIH and tagged at 8990 ft. PUH to 8850 ft to tie-in jewelry. 08:20 - 08:45 0.42 STWHIP P WEXIT Log CCL tie-in from 8,850 ft down to 8,990 ft. Milled down to 8,992 ft. no corrections 08:45 - 10:41 1.93 STWHIP P WEXIT RIH and tagged TOC at 8,992 ft. Milling Cement TF at 180. Qp = 1.51 / 1.52 bpm CTP 1820 / 2300 WOB = 1.5k DHWOB 0.5 3.5k Milled down to 9001 ft and to much WOB PUH and tagged at 9,000 ft (? hard cement) Drill cement at an ave of 40 fph to 9,047 ft. Wiper trip to 8,990 ft with 180 deg TF. RIH; Qp = 1.51 bpm 10:41 - 11 :36 0.92 STWHIP P WEXIT Milling cement from 9,048 ft to 9,062 ft TF at 180 deg Qp = 1.51 / 1.52 bpm 2000 psi off bottom pressure. 11 :36 - 12:00 0.40 STWHIP P WEXIT Wiper trip to 9000 ft 12:00 - 12:50 0.83 STWHIP P WEXIT Working to get it to drill. ROP at 48 fph with 3.3 k WOB Milled cement to 9090 ft and all of the ROP exceeded 40 fph and in some cases it was 50 to 55 fph 12:50 - 13:15 0.42 STWHIP P WEXIT Wiper trip to 8980 ft and back and tagged ta 9090 ft. POOH 13:15 - 13:53 0.63 STWHIP P WEXIT POOH. Open EDC and POOH. RIH to cleanout to 9,107 ft 13:53 - 14:30 0.62 STWHIP P WEXIT Drilling Cement from 9,090 ft to 9,107 ft With some restart due to stacking Average ROP > 40 fph Qp = 1.51 1.51 bpm at 2, 050/2,500 psi Vp = 413 bbls PU for wiper trip due to stacking 14:30 - 14:55 0.42 STWHIP P WEXIT Wiper trip to 9,050 ft RIH and milled out cement to 9107 ft. Talked with town on way forward Milled cement to 9107 ft at 45-50 fVhr. 14:55 - 17:30 2.58 STWHIP N CEMT WEXIT POOH to PU BOT 3-1/2" 7" Under reamer. Confirmed Tie-in (0 correction) Open EDC Changing out the override sprocket on reel POOH SO at 250 and checked flow and held PJSM 17:30 - 18:00 0.50 STWHIP N CEMT WEXIT Break off BHI tools from motor & mill. LD BHI tolls & motor & Printed: 6/11/2007 11:19:39AM . · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/21/2007 17:30 - 18:00 0.50 STWHIP N CEMT WEXIT mill. 18:00 - 18:30 0.50 STWHIP N CEMT WEXIT C/O with day crew & PJSM & THA prior to handling BHA. Perform kick drill & parted coil drill. Mill was 2.73" No·Go & 2.74" Go. 18:30 - 19:30 1.00 STWHIP N CEMT WEXIT PU & MU BOT 3 bladed under reamer & motor. Attach BHI tools & stab on to BHA with coil. Power up & check tools. Set counters. Open EDC. RIH with under reamer. Hold Pre spud meeting with night crew. 19:30 - 21:25 1.92 STWHIP N CEMT WEXIT WT Ck 25k up & 10k down. Log down for tie in from 8875ft to 8940ft. 3ft correction needed. 21 :25 - 22:40 1.25 STWHIP N CEMT WEXIT Drop past end of tubing tail. Close EDC & begin pumping to open under reamer blades. VP's = 425 bbls. 1.51 bpm in 1 1.48 bpm out @ 2161 psi fs. Seeing some motor work @ 9002' (60psi DP) 120lbs WOB. Keep ROP steady at 40ft/hr and motor work below 200psi DP. 22:40 - 23:50 1.17 STWHIP N CEMT WEXIT Pump 15 bbl sweep. Cement material coming back on shaker is mushy. 23:50 - 00:00 0.17 STWHIP N CEMT WEXIT Pump 15 bbl sweep & back ream to TT from 9040ft @ 4 ft/min. 5/22/2007 00:00 - 00:15 0.25 STWHIP N CEMT WEXIT Continue to back ream to TT. Heavy motor work @ 8993', stop pumping. Work area until clean. 00:15 - 02:15 2.00 STWHIP N CEMT WEXIT Continue to under ream. VP's = 427 bbls. Mix another pill in pit 4. 1.40 in/1.38 out @ 1975 psi fs. 200lbs WOB 02:15 - 02:25 0.17 STWHIP N CEMT WEXIT Pump 10 bbl sweep. Increase ROP, motor work is 200 psi. 02:25 - 02:49 0.40 STWHIP N CEMT WEXIT Back ream from 9080ft @ 4ft/min. 02:49 - 03:10 0.35 STWHIP N CEMT WEXIT Motor work @ 8991ft. Work down past with no problems. RIH to bottom. 03: 1 0 - 03:45 0.58 STWHIP N CEMT WEXIT 300 psi stall, stop pumping & pick up. Slow ROP down while going through perfs. Pump 15 bbl sweep. 03:45 - 06: 15 2.50 STWHIP N CEMT WEXIT Stall. Time drill from 9,119ft to 9,125.6 ft 06:15 - 07:10 0.92 STWHIP N CEMT WEXIT UR from 9125 ft. Lots stalls occurring at 9,125 ft (inside perf area 9,101 ft to 9,221 ft) Cement somewhat hard in the perf interval Qp = 1.38 1 1 .38 bpm CTP 2,223 psi Vp = 417 bbl 07:10 - 08:50 1.67 STWHIP N CEMT WEXIT Wiper trip I back reaming 9126 ft to 8,983 ft. Pumping sweep down CT Qp = 1.49bpm at 2200 1 2513psi. Reamed area at 8,991 ft several times and cleaned up on the downward movement. Pumped 10 bbl Biozan Sweep and RIH to cleanout to 9,126 ft. 08:50 - 08:56 0.10 STWHIP N CEMT WEXIT PUH to tie in at 8,908 ft 08:56 - 10:08 1.20 STWHIP N CEMT WEXIT Logged tie-in at 8908 ft and corrected -10 ft for GR. RIH and confirmed GR tie-in at 9030 ft without correction. Rih and tagged PBTD at 9,116 ft MD. POUH to 8890 to log CCL. Logged CCL from 8890 ft and tagged at 9116 ft. Open EDC Qp = 1.00 bpm, PUH. GR and CCL tied-in but the 7" casing collar ar off by 12 ft. POOH to look at the UR. 10:08 - 11 :30 1.37 STWHIP N CEMT WEXIT POOH. Having some trouble with SCR 1 Power Pack the hydraulic P-14 pump increasing speeds. Paint at 8000 ft EOP. 11 :30 - 13:45 2.25 STWHIP N CEMT WEXIT Stopped at 5,888 ft to wait for the SLB mechanic to look at the controllers for the power pack in the high gear switch. The Printed: 6/1112007 11:19:39 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/2212007 11 :30 - 13:45 2.25 STWHIP N CEMT WEXIT POOH speed goes from 80 fph to 134 fpm without making any changes to the injector or joystick. Mechanic working on SLB's hydraulic problem. PUH while SLB mechanic troublshoots the problem. Held PJSM on BHA handling. 13:45 - 15:00 1.25 STWHIP N CEMT WEXIT LD and inspected UR BHA. Recovered all 3 blades and they were in good shape. Worked out details with SLB engineer on way forward 15:00 - 16:00 1.00 STWHIP N CEMT WEXIT Spot and rig up SLB Eline. SLB reheading cable head. Gerald with SLB, spliced two logs together and came up with the correct depth presentation on the well. Used the producion log done in March of 2007 to come up with the correct tie in for the 7" casing below the WLEG 16:00 - 17:45 1.75 STWHIP N CEMT WEXIT PU injector and removed UQC and condition line for cementing. PU 6 jts of 1-1/4" CSH and 2.25" nozzle. 17:45 - 19:45 2.00 STWHIP N CEMT WEXIT RIH with Cementing BHA. Correct -7.5' to EOP flag. Tag btm at 9118'. 22k# up, 5.5k# dn weight. 19:45 - 20:45 1.00 STWHIP N CEMT WEXIT Circulate 50 bbls clean 2% KCL water. Getting some gas cut returns. Increase WHP from 100 to 250 psi. Hold PJSM to discuss cement job. 20:45 - 22:45 2.00 STWHIP N CEMT WEXIT Batch mix 6 bbls Class G 17 ppg cement. Pressure test lines to 4000 psi. Pump 3 bbls fresh water, 6 bbls cmt, 5 bbls fresh water. Displace with biozan. Avg rate: 1.13 bpm at 850 psi. IAlOA: 2821276 psi. Lay in cmt 1 :1. Pull to 8000'. Cement in v" place at 2215. Wait on cmt for 30 minutes. 22:45 - 00:00 1.25 STWHIP N CEMT WEXIT Wash cement down to 8985' with biozan. Make three passes from 8500' to 8985'. 2950 psi at 2.45 bpm. 5/23/2007 00:00 - 02:00 2.00 STWHIP N CEMT WEXIT Continue to wash cement from 8500' to 8985'. Wait on 9.2 brine from MI. 02:00 - 04:30 2.50 STWHIP N CEMT WEXIT Pull out of hole laying in 9.2 ppg brine. Wash each GLM and other jewelry. Slowly reduce WHP. 04:30 - 06:15 1.75 STWHIP N CEMT WEXIT At surface. Get off well. Unstab coil. LD CS hydril pipe. 06:15 - 07:00 0.75 STWHIP N CEMT WEXIT RU and jet stack out 07:00 - 10:40 3.67 STWHIP N CEMT WEXIT Conducted Conduct Slack Management. Cut off 240 ft 2" CT. and 4 ft wire. megged line >2000 m-ohms and conductivity at 38-42 ohms. Install dimple CTC Pulled tested to 35k (OK). Rehead cable to UQC Megged UQC IUne >2000 mohms. PT CTC to 4000 psi. 10:40 - 13:00 2.33 STWHIP P WEXIT Circulate down CT to finish slack management Install wire in packoff / rope socket PU pressure deployment lubricator. 13:00 - 14:45 1.75 STWHIP N CEMT WEXIT RU pressure deployment lubricator and 1.75 deg bend motor BHA for drilling pilot hole 14:45 - 15:30 0.75 STWHIP N CEMT WEXIT RIH and open EDC at 503 ft RIH to 2610 ft 15:30 - 20:15 4.75 STWHIP P WEXIT Install Schlumberger's CT Inspect on the level wind and install the software. 20:15 - 22:30 2.25 STWHIP P WEXIT Run in hole, testing CT Inspect system. 22:30 - 00:00 1.50 STWHIP N CEMT WEXIT Begin GR log. BHA hung up at 8909'. Pull 50k#. Able to turn tool face. Close EDC to circulate through the bit. Finally work free downhole. Acts like junk along side tools. Pick up. Unable to get up past 8889'. Able to move up and down between 8889' and 8920' only. Easier going down with no pump. 5/24/2007 00:00 - 03:30 3.50 STWHIP N STUC WEXIT Continue to work pipe. Bit is now stalled. Still able to get above Printed: 6/1112007 11:19:39AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/24/2007 3.50 STWHIP N STUC WEXIT 00:00 . 03:30 03:30 - 04:30 04:30 - 06:30 1.00 STWHIP N 2.00 STWHIP N STUC WEXIT STUC WEXIT 06:30 - 08:50 - 2.33 STWHIP N SFAL WEXIT 08:50 - 09:45 0.92 STWHIP N SFAL WEXIT 09:45 - 10:30 0.75 STWHIP N STUC WEXIT 10:30 - 12:00 1.50 STWHIP N STUC WEXIT 12:00 - 13:00 STUC WEXIT 1.00 STWHIP N 13:00 - 14:00 1.00 STWHIP N STUC WEXIT 14:00 - 17:00 3.00 FISH N STUC WEXIT 17:00 - 19:00 2.00 FISH N STUC WEXIT 19:00 - 21 :00 2.00 FISH N STUC WEXIT 21 :00 - 21 :30 0.50 FISH N STUC WEXIT 21 :30 - 23:30 2.00 FISH N STUC WEXIT 8890' or go below 8918'. Now believe we lost a piece of e-line in the hole during cement job. The e-line removed from the CS Hydrill was 175' with a very frayed end and missing seal cap. The CS hydrill BHA was 180'. We suspect e-line came out the cementing nozzle and parted while making clean out passes with coil. SLB records for the reel indicate 214' of "extra" e-line inside the coil when new. There is possibly of +/- 39' of e-line in hole. Continue to work pipe to try and wear out e-line while waiting on flopro w/lubricant. Circulate new flo pro through open EDC. Resume working pipe while circulating through EDC. Coil life less than 10%. Pull up to 80% (62k#). Able to run in hole ok to 8910' after first few max pulls. Hung up, then free again to move down hole. CT movement from 8926 ft to 8880 ft (46 ft) Working CT and orient TF to low side between 8,927 ft and 8,880 ft. (0 k down and 40k up) See the DPS sub in the tension and compression modes, orienter moves and the motor turn at min rev. SO, power pack HP hydraulic filter lost seal and sprayed hydrauilc oil on the power pack wall (contained). The seal that failed is between the filter pod and the housing. Mechanic bringing out the correct o-ring Mechanic working on HP pod on power pack Pumped 20 bbl 2.5%L776 and spotted around BHA Closed EDC and PUH to 8,890 ft and motor torqued up, SO and PUH and BHA free POOH FREE. PUH Tie-in at 8000 ft corrected -5 ft Flagged pipe at 7900 ft EOP (red) POOH, Pulled tight coming out of hole at 5,400 ft (GLM # 5) . Could have something along side of us. Pulled a little tight at 1475 ft (?) Stopped at 200 ft, Held PJSM on plan forward and way to mitigated same. PUH looking at 2" CT. no mark, Stand injector back and inspect BHA, no mark on top side, 2 marks on the bit box of the motor. Nothing in the BOP's or tree, close the MV with 18-1/2 turns. LD BHA Held PJSM on RU and running Wireline to fish the what ever is in the hole RIH with 2.73" wire grab and brush. RIH and found something just below GLM #2 and pushed down to 8889 ft Pull tight PU and POOH dragging 100 # extra wt OOH. Recovered 3 ft of cable. RIH with wireline grab #2. Work down to 8885'. Jar up to get free. POOH dragging something. Recovered 3 additional feet of cable. Redress fishing tools. Run in hole with wireline grab #3. Set down at 8918'. Could not work through. POOH. Recovered one strand only of armor wire. Haliburton crew change. Hold PJSM and discuss plan forward. MU and RIH with wireline grab #4 (smaller 00 grab). Work to get past SBR at 8918'. Apparently tagging lip inside top of SBR, possibly the slick stick. POOH. Recovered a few strands of armor only. Printed: 6/11/2007 11 :19:39 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/24/2007 23:30 - 00:00 0.50 FISH N STUC WEXIT Add a centralizer and pinch in graber prongs. Run in hole with wireline graber #5. 5/25/2007 00:00 - 02:30 2.50 FISH N STUC WEXIT RIH with wireline grab #5. Try to work through SBR at 8919'. Unable to get past. POH. 02:30 - 04:30 2.00 FISH N STUC WEXIT Shorten tool string again. RIH with wireline grab #6. Get a half foot deeper to 8920'. POH, heavy. Recovered a tight ball of wire. Estimate length at 22 feet. 04:30 - 07:45 3.25 FISH N STUC WEXIT RIH with wireline grab #7. Tag btm at 8989' (should be top of cement). POH. NO recovery. PU and RIH with 2.6" LIB and tagged at 8989 ft. POOH LIB showed some evidence of wire enbedded in the cement? PU a 2.5" pump bailer. 07:45 - 10:45 3.00 FISH N STUC WEXIT RIH with 2.5" pump bailer Recovered cement chunks and several piece of cable armorur Redress the pump bailer and rerun in the hole. Recovered very little. Held PJSM on RD Wireline 10:45 - 12:00 1.25 FISH N STUC WEXIT RD Halliburton Wireline PU Pilot mill BHA 1.75 deg motor 12:00 - 13:45 1.75 S1WHIP N CEMT WEXIT RIH with cement pilot BHA. Corrected to 7,900 ft EOP flag to 7,961 RIH pumping at min rate. 13:45 - 14:10 0.42 S1WHIP N CEMT WEXIT Logging tie-in at 8,908.5 ft to confirm depth. Corrected -1 ft to 8,947.60 ft 14:10 - 16:00 1.83 S1WHIP N CEMT WEXIT RIH Qp = 1.51 / 1.56 bpm RIH CTP 3,200 psi Flo-pro is still shearing. TF at 182.5 deg PU at 8986 ft = 20 k up and 6.8k down Tagged at 8,988.5 ft Worked up WOB to 2 to 3 k ROP averaged 17 fph with 2-3k WOB Nice to have re-bar in the cement PU at 8,998 ft and it was clean, RIH and back to drilling 16:00 - 16:40 0.67 S1WHIP N CEMT WEXIT PU and oriented TF to HS and drill from 8988 ft to 9,001 ft Qp = 1.51 / 1.50 bpm at 2970 psi off bottom Vp = 399 bbl flo-pro. TF at HS Sample. 30% cement and 70% metal, scale and some wire/cable material 16:40 - 17:15 0.58 S1WHIP N CEMT WEXIT PUH and orien TF to LS at 8985 ft 17:15 - 21:00 3.75 S1WHIP N CEMT WEXIT Dilling pilot hole 9,001.8 ft TF at 180 deg Qp = 1 .51 11 .52 bpm CTP 2,850 / 3,200 psi DHWOB = 2.50-3.50k ROP at 22 fph Sample: 95 % cement, samples cleaned up. 21 :00 - 22:45 1.75 S1WHIP N CEMT WEXIT Continue to mill pilot hole. TF: 180 deg. 2950 psi fs at 1.52 in/1.53 out. 250-350 dpsi. DHWOB: 1.5-2.0 k#. ROP: 20-25 fph. 22:45 - 23:15 0.50 S1WHIP N WEXIT Adjust TF to highside. Mill ahead to 9105'. Had a TF shift from HS to 345L at 9104.5'. Allow drill off to 2k# WOB. 23:15 - 00:00 0.75 S1WHIP N WEXIT Back ream up through pilot hole to tbg tail with HS TF. 2650 psi fs at 1 .52 in/1.53 out. Backream at 1 FPM up past ramp. 2-3 fpm back to 8980'. 22-24k# up wt. 5/26/2007 00:00 - 01 :00 1.00 S1WHIP P WEXIT Continue to backream pilot hole up to 8980'. Run in hole oriented LS. Orient through ramp to HS. Back ream ramp again at HS TF back to 9080'. 01 :00 - 01 :15 0.25 S1WHIP P WEXIT Pull up hole. Open EDC. Log GR tie in from 8910'. Add 1 ft correction. 01 :15 - 03:00 1.75 S1WHIP P WEXIT Pull out of hole. Printed: 6/1112007 11:19:39AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/26/2007 03:00 - 04:45 1.75 STWHIP P WEXIT Get off well. Unstab coil. LD motor and pilot mill. MU WFT 2.5 motor with HTC one step mill. Stab coil and test tools. 04:45 - 07:10 2.42 STWHIP P WEXIT Run in hole. Bouncing through few collar. Close EDC and circ at min rate to get through SSSV and GLMs. 07:10 - 07:40 0.50 STWHIP P WEXIT Stopped and tied in at 8,910 ft Stacking out at 8932 ft (SPR) worked by wit 180 TF. Logging Corrected -10ft 07:40 - 07:54 0.23 STWHIP P WEXIT Orient TF to HS and RIH without pump Tagged at 9105.32 ft, painted flag, PUH and stated pumps ~ 07:54 - 18:00 10.10 TWHIP P I ing win ow starting at schedule as per programmed \ <:..o3Pt Qp = 1.50 bpk and PVT at 400 bbl's. At 9,103.84 started to see WOB. 18:00 - 19:20 1.33 STWHIP P WEXIT Continue to mill window from 9106.6'. DHWOB: 3.23k#. Allow to milloff to 2.75k#. Resume time milling sequence. Got alot of weight back at 9107'. Looks like window btm. Continue to ...- time drill to 9107.3'. Window top: 9104'. Window btm: 9107'. 19:20 - 21 :45 2.42 STWHIP P WEXIT Drill ahead by weight from 9107.2 3330 psi fs at 1.53 in/out. Very slow ROP in formation (?). Stacking up to 4.5k# DHWOB. Small amount of motor work. Catch a btms up sample from 9110'. Found 5-10% formation in sample, including glauconite and siderite. PU l' and set down up to 4.5k#. Several times. Unable to make any footage or drill off any DHWOB. Estimate btm at 9110', leaving 3' of rat hole. Pump a 15 bbl hivis sweep. 21 :45 - 22:30 0.75 STWHIP P WEXIT Pull up hole to log GR tie in from 8910'. Open EDC. Log GR tie. Subtract l' correction. 22:30 - 00:00 1.50 STWHIP P WEXIT Circulate out of hole. 5/27/2007 00:00 - 00:30 0.50 STWHIP P WEXIT At surface. Get off well. Unstab coil. LD window milling BHA. 2.74" go, 2.73" no go. Good wear pattern across mill face. No damage to gauage area. 00:30 - 01:15 0.75 STWHIP P WEXIT MU window dressing BHA. (1.75 deg Xtreme with HTC 2.74" diamond blunt tip crayola, 2.74 no go/2.75 go). Stab coil. Test tools. Get on well. 01:15 - 03:15 2.00 STWHIP N DFAL WEXIT Run in hole. Circ through EDC. 03:15 - 03:30 0.25 STWHIP N DFAL WEXIT Log gr tie in from 8910'. Subtract -13 ft correction. Close EDC. 03:30 - 05:30 2.00 STWHIP N DFAL WEXIT Run in hole with pumps off, oriented HS. Set dn at 9063' PU. Circ at min rate. RIH. Set down again at 9063'. PU and orient TF to 180 deg. Increase rate to 0.5 bpm, RIH at 25 fpm. Stop at 9097. Orient TF to HS. RIH dry. Tag at 9104'. Stall. PU and repeat. Mill ahead with HS TF at 0.1 fpm. 2853 psi fs at 1.53 in/out. Stall again at 9102.2'. PU. RIH to 9102.0' Time mill ahead at 0.1' fpm. Too fast. PU and time mill from 9101.9' at 0.01 fpm. Unable to make any progess. No motor work, then a hard stall no matter how slowly we time mill. 05:30 - 07:20 1.83 STWHIP P WEXIT Pull out of hole to change dressing mills. 07:20 - 08:30 1.17 STWHIP P WEXIT Change out crayola mill to the Weatherford style The BHI carloya mill is to agreesive on the face of the mill!. The water cources are to deep and there is no transitation between the water cource base and the cutting structure face. Function Tested BOP's. PU 2.74" WFT Crayloa Mill. 08:30 - 10:05 1.58 STWHIP P WEXIT RIH with crayloa mill and 1.75deg motor 10:05 - 10:25 0.33 STWHIP P WEXIT Tied-in at 8908 ft and corrected -13 ft Close EDC Printed: 6/1112007 11:19:39AM Name: 1 C-03a 50-029-20535-01-00 207 -063 AP!# PTD: Conductor 16" 62#/ft H-40 Surface 10-314" 45.5 3-112" 9.2 #/ft L-80 ID 2.992" 7"26#/ft K-55 Prepared by Dave Hildreth Orbis Engineering !nc Houston, Texas re Diagram (6..9..07) 1 C-03a #5 Cameo KBUG DGL V #4 Cameo KBUG DGLV #3 Cameo KBUG DGL V #2 Cameo KBUG DGL V #1 Cameo K8UG DGL V Baker EL-1 SBR PBR wi 2.813" Profile Baker Model FHL Packer ID = 2.80" TOL 2-3/8" Solid Liner @ 3-1/2" 0 Nipple (2.75" No-Go) TOC tagged 5-8-2007 TOL 2-3/8" Slotted Liner @ Unique Guide Shoe (0.66" 10) @ 2-3/8" 4.41# L-80 SL T Liner @ EOC @ 9543 ft Bottom of Cement . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMM SION RECEIVED MAY 1 6 2007 WELL COMPLETION OR RECOMPLETION REP.-.foHiQ deQ6mmission 1 a. Well Status: Oil D Gas U Plugged ~ . Abandoned U Suspended D 1b. Well Clas~rzrOrage 20AAC 25.105 20AAC25.110 Development ./. Exploratory D GINJ D WINJ D WDSPL D WAG D Other D No. of Completions: Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ./ - ConocoPhillips Alaska, Inc. or Aband.: May 4, 2007 180-138/307-111/307-155 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 50-029-20535-00 - December 10, 1980 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1582' FNL, 1164' FWL, Sec. 12, T11N, R10E, UM . December 27. 1980 1 C-03 At Top Productive Horizon: 8. KB (ft above MSL): 115' AMSL 15. Field/Pool(s): 1301' FSL, 1098' FWL, Sec. 11, T11N, R10E, UM Ground (ft MSL): 55' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + 1VD): Kuparuk Oil Pool 4139' FNL, 4632' FEL, Sec. 11, T11N, R10E, UM 8993' MD /6352' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + 1VD): 16. Property Designation: Surface: x- 562172' y- 5968656 . Zone- 4 . 9700' MD /6821' TVD'" ADL 25649 TPI: x- 556847 y- 5966217 Zone- 4 11. SSSV Depth (MD + 1VD): 17. Land Use Permit: Total Depth: x- 556399 y- 5966053 Zone- 4 SSSV @ 1871' not available 18. Directional Survey: Yes D N00 19. Water Depth, if Offshore: 20. Thickness of Permafrost (1VD): (Submit electronic and printed information per 20 MC 15.050) N/A (ft MSL) 1650' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH 1VD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65# H-40 SURF. 80' SURF. 80' 24" 200 sx Penmafrost 10.75" 45.5# K-55 SURF. 3214' SURF. 2682' 13.75" 1500 sx Fondu, 250 sx AS II 7" 26# K-55 SURF. 9675' SURF. 6804' 8.75" 725 sx Class G 23. Open to production or injection? Yes D No 0 If Yes, list each 24. TUBING RECORD Interval open (MD + 1VD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 9013' 8974' cemented off perforations 9101 '-9221' MD 6421'-6500' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5GANNEDJUN o 6 2007 n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Press: Calculated OIL-BBL GAS-MCF WA TER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Conventional Core(s) Acquired? Yes I No I ./ I . Sidewall Cores Acquired? Yes I I No 1./1 . If Yes to either question, list formations and intervals cored (MD + 1VD of top and bottom of each), and summarize lithology and presence of oil, gas or water r{~¿~.. (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. l C""PLCJ:fJN 1 l..s}![f () NONE L~EDJ Fonm 10-407 Revised 2/2007 DUPLICATE CO~:rINU.E.D ON REVERSE SIDf Qt..... '. Ø1- .' .' .... Df\ ^^ ¿' L4"1 . ,. Oq..¡ J V ~ j C ¿;;.' ~ l/"J'?-'--:--- ~J> ,-.t!J.C7 :A-F~1b? Ú 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME Permafrost - Top Permafrost - Bottom MD surface 1650' TVD surface Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk Base of Kuparuk 9101' 9588' 6421' 6746' N/A Formation at total depth: Kuparuk regoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Signature Title: Phone Wells Group Enaineer Date~ Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion, Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2007 . 1 C-03 Well Events Summary . DATE Summary 3/3/07 LOG PRODUCTION PROFILE. WELL ON PRODUCTION TO TEST SEPARATOR: 150 BOPD, 720 BWPD, LIFT GAS = 360 MSCF/D. SPLITS: 100% OF PRODUCTION FROM (9100-9136). NO CROSSFLOW OBSERVED BETWEEN ZONES WITH WELL SHUT IN. LOGGED GLS ON RIH. LIFTING FROM GLM #1 (GLV) AT 3/10/07 TIFL, ( PASSED). 3/12/07 PRE CTD, POT-T( FAIL), POT-IC ( PASS), PPPOT-IC ( PASS), MITOA ( PASSED), PT & DD, MV ( FAIL ), SV ( FAIL ), & SSSV ( LOCKED OUT ). 3/15/07 POT-T FAILED, PPPOT-T PASSED, PT & DD SV FAILED,DD MV FAILED, PT MV PASSED (PRE CTD) 4/1/07 BRUSHED & FLUSHED TBG TO D NIPPLE. TAGGED @ 9378' RKB, EST. 157' RATHOLE. SET 2.75" C-A2 PLUG @ 9012' RKB. SET 3.5" SLIP STOP CATCHER @ 5493' SLM. PULLED OV & GLV @ 5399' & 2719' RKB. SET DV @ 2719' RKB. IN PROGRESS. I 4/2/07 LOADED TBG & IA WITH DSL. SET DV @ 5399' RKB. TESTED TBG 2500 PSI, GOOD. ATTEMPTED NEGATIVE TEST ON TBG, FAILED. MIT IA PASSED. PULLED CATCHER SUB & CA-2 PLUG @ 9012' RKB. IN PROGRESS. 4/3/07 SET 2.75" CA-2 PLUG @ 9012' RKB. TBG TEST FAILED, SUSPECT DAMAGED D NIPPLE. PULL 2.75" CA-2 PLUG. SET 2.81" XX PLUG IN SBR @ 8947' RKB. TEST TBG TO 150 & 2500 PSI, GOOD. IN PROGRESS. 4/4/07 SET A-2 PLUG ON 2.81" CS-LOCK IN SSSV @ 1871' RKB. TESTED TBG 2500 & 250 PSI, GOOD. 4/6/07 PULLED 2.81" A-2 PLUG @ 1871' RKB. PULLED 2.81" XX @ 8947' RKB. IN PROGRESS. 4/7/07 LOGGED CALIPER SURVEY FROM 9262' RKB TO SURFACE. SET 3/16" OV @2719' RKB. 4/9/07 PRE-CTD, MV-PT - PASSED, MV-DD - PASSED, SV-PT - PASSED, SV-DD - PASSED 4/21/07 SET 2.75 CAT STANDING VALVE IN D-NIPPLE @ 9012' RKB. PULLED OV FROM STA # 1 @ 2719' RKB. CIRCULATED 105 BBLS OF DIESEL DOWN TBG, UP lA, AND DOWN FLOWLINE. SET DGLV IN STA# 1 @ 2719' RKB. MIT IA TO 2500 PSI ( PASSED). PULLED CAT STANDING VALVE @ 9012' RKB. 4/28/07 MILLED D-NIPPLE AS PER PRE-CTD PROCEDURE TO 2.80" I.D.@ 8984' CTMD, ABLE TO DRIFT THRU PROFILE WITH PUMPS OFF WITH NO WEIGHT CHANGES. MILL GAUGED OUT AT 2.795" - 2.80" O.D. RETURN IN THE AM FOR CEMENT STAGE AS PER PROCEDURE. 4/29/07 SPOTTED 14 BBLS 15.8 PPG CEMENT IN 7" CASING 9384' CTMD TO 9010' CTMD. FCO'D TOC TO 9155' CTMD AS PER PROCEDURE WITH 1.5# BIO ZAN AND SLICK SEAWATER WASHING JEWELRY WHILE POOH. EST. TOC 9160' CTMD. WELL FREEZE PROTECTED WITH DIESEL TO 2500'. 5/3/07 TAGGED CEMENT TOP @ 9164' RKB. 5/4/07 Lay in 17 ppg cement plug from 9164', wash down to 9003' with biozan. FP well with 25 Bbls diesel and left well shut in with 400 WHP. 5/8/07 TAG CEMENT AT 8993' RKB (IN TUBING). LOCATE GLM #6 AT 8871' SLM/8881' RKB FOR CORRECTION FACTOR. ~ WeIlTvoe:PR~ API: 500292053500 SSSV Tvoe: LOCKED OUT Oria ComDletion: 12/31/1980 Anale @ TD: 48 deg @ 9700 SSSV II Annular Fluid: Last W/O: Rev Reason: Mill D NIP, CMT (1871·1872, Plua, Tag CMT 00:3.500) Reference Loa: Ref Loa Date: Last UDdate: 5/10/2007 Last Taa: 8993' TD: 9700 ftKB i ii DescriDtion Size TOD Bottom TVD Wt Grade Thread GasLil! ~ CONDUCTOR 16.000 0 80 80 6.50 H-40 landreVOummy SURFACE 10.750 0 3214 2682 45.50 K-55 Valve 1 9675 680~ (2719-2720, 00:5.313) .., Size TOD Bottom TVD ì Wt ì Grade Thread Gas UI! ... 3.500 III 0, ! " 1 Interval I TVD Zone Status Ft SPF Date Tvne Comment 1 landreVOummy __6421-650,0.-A--:¡~-?1 0lr 11201 8 112131/19~ Valve 2 (5399-5400, 00:5.313) Jil St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2719 2374 Cameo KBUG DMY 1.0 BK 0.000 0 4/21/2007 .. 2 5399 3978 Cameo KBUG DMY 1.0 BK 0.000 0 4/2/2007 GasUl! 3 6944 4968 Cameo KBUG DMY 1.0 BK 0.000 0 3/13/2005 landreVOummy 4 7852 5629 Cameo KBUG DMY 1.0 BK 0.000 0 12/31/198C Valve 3 (6944-6945, 5 8348 5959 Cameo KBUG DMY 1.0 BK 0.000 0 12/311198C 00:5.313) 6 8881 6280 Cameo KBUG DMY 1.0 BK 0.000 0 3/26/1997 ki DeDth TVD TVDe DescriDtion ID 1871 1795 SSSV Cameo 'TRDP-1 AE' ' (Locked OutT 2.813 GasUl! 8947 6322 SBR Baker EL-1 WITH OTIS 2.813" X-PROFILE 2.813 landreVOummy 8974 6339 PKR Baker FHL 3.000 Valve 4 (7852-7853, 8993 6352 PLUG CEMENT PLUG set 4/29/2007 0.000 00:5.313) III 9012 6364 NIP 2.75" Cameo 'D' NiDDle NO GO - MILLED OUT TO 2.80" ID 4/28/2007 2.800 9013 6365 TTL 2.992 9013 6365 SOS Baker 2.992 GasUl! II» Date I Note iandreVOummy 2/23/19991 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION Valve 5 (8348-8349, 4/3/20071 NOTE: SUSPECT D NIPPLE @ 9012 DAMAGED 00:5.313) GasUl! ... landreVOummy Valve 6 (8881-8882, 00:5.313) . ' SBR . (8947-8948. 00:3.500) , :' PKR (8974-8975, 00:6.156) TUBING (0-9013, 00:3.500, 10:2.992) NIP (9012·9013, 00:3.500) PLUG (8993-9384, 00:7.000) 1 C-03 KRU ConocoPhillips Alaska, Inc. . . . ~1T~1TŒ (IDif ~~~~[(~ . AI,4~KA. OIL AlQ) GAS CONSBRVATlON COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 SQftNlB MAY 0' 7 2007 Re: Kuparuk River Field, Kuparuk River oÜ Põo!:--iê':Ô3 Sundry Number: 307 -155 O.,\1J~ \t¿ Dear Mr. Eller: 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, /~ Cathy P. Foerster Commissioner DATED this ~ day of May, 2007 Ene!. nc oraoe 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate D Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 180-138 , 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20535-00 / 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? Yes 0 No 0 1 C-03 / 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 / RKB 94' ~. Kuparuk 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): 9700' 6821' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 80' SURFACE 3120' 10-3/4" 3214' PRODUCTION 9581' 7" 9675' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" K-55 9013' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER FHL pkr= 8974' SSSV= SSSV SSSV= 1871' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat May 4, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission ~resentative: 18. I he",by œ~.. the '0""0'" " ue and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Printed Name ,,~rv EIIE(f-- l Title: Wells Group~neer Signature <....:.- ~ T Phone 265-6958 Date 3\ \)1 -~ \ ~ Commission Use Only . '-.J sund~ ~Ob7 -/5 s Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test (R Mechanical Integrity Test 0 Location Clearance 0 Other: ~5t> 0 ~ "> \ "'" ",,\ V'"".. 'Ù ~ ~~ \> ~c;,. -\-- \ Subsequent Form Required: LtO, J~ÎIJ~lj APPROVED BY Date:'5 - 3 -ò7 Approved by: COMMISSIONER THE COMMISSION Form 10-403 Rev:þed 06/2006 O-R' G \ N A L 'hHliirš <-4.- ~.% Submit in Duplicat: -~~5Ji}t7 07 /¿t,» ç."3' 07 . i RECEIVED STATE OF ALASKA . fJš/ .. ALASKA OIL AND GAS CONSERVATION COMMISSION Y MAY 0 3 2007 APPLICATION FOR SUNDRY APPROV AbJaska Oil & Gas Cons. Commission 20 MC 25 280 A h . . . WeIl1C-03 Plug for Cement Ramp Exit Drilling Network: Wells Network: 10169976 10169977 Obiective: Place a 17 ppg cement plug in preparation for a CTD cement ramp window exit. Top of cement will be 9010' MD. / BackQround: The 1 C-03 CTD sidetrack was originally planned to kick off from a new style 3%" x 7" through-tubing whipstock. That whipstock was not able to be delivered in time, so 1 C-03 will be plugged back with cement to perform a cement ramp exit at 9112' MD. / Cement PluQback for Cement Ramp Exit - Issues and Potential Hazards · Hard, uncontaminated cement from the tubing tail to the KOP is essential for a successful cement ramp window. Make sure any contaminants (ex: Flo-Pro mud, Biozan, etc.) are fullv displaced from the well bore prior to placing cement. / · Expected reservoir pressure = 2800 psi = 8.3 ppg EMW. Expected reservoir temp -157 deg F. Adjust cement properties accordingly. Confirm temperature from previous SBHP surveys. · Expected formation fracturepressure = 4200 psi (0.65 p~i/ft).po not exceed fracture pressure during squeeze. · Monitor annulus pressures while pumping and bleed off as necessary. Max IA & OA pressure should be 2000 psi & 1000 psi respectively. · Minimum 10 = 2.80" milled-out D nipple at 9012' MD. Lavina in Cement Plua 1. MU slick nozzle BHA on 1 %" coil. Use standard balldrop nozzle w/ jet swirl profile and 5' stinger to CT. Pump a dart through the coil tubing to calibrate coil reel volume. 2. RIH, tag PBTD from cement operation òf 4/29/07. Circulate the hole clean with seawater or KCI water at maximum rate while waiting on cement to mix. v"" I,... "'.1'1 ~ "'l>t~ 3. RU cementers. Mix a pumpable 10 bbl of 17.0 ppg cement (5.7 bbl in 7" casing down to 9160' MD, 4.3 bbl excess). · Ultimate target TOC 9010', which is approximately at the 3%" tubing tail. If PBTD = 9160' from the cement job of 4/29/07, the 10 bbl of cement can go as high as 8520' MD in the 3%" tubing. · Bring pod up to weight and shear thoroughly. QC test cement. Send sample to lab for UCA testing. · Cement is cheap, so pump more rather than less if the odds of getting a good cement plùg are increased. 4. Pump the following down the coil: a) water spacer for PT (do not use friction reducer, J313 will clabber cement) b) 10 bbl neat 17.0 ppg cement c) 5-10 bbl of spacerwater d) 1.5# Biozan gel for cement clean out 5. Position nozzle as deep as possible as cement reaches nozzle. Take returns and allow cement top in casing to rise 50' above nozzle before beginning pulling up hole. POOH laying in cement 1:1 taking Page 1 of2 May 3, 2007 . . returns to a calibrated tank for verification. Apply backpressure as needed to maintain 1: 1 returns. Decrease pump rate and/or increase POOH speed when the leading edge of the cement reaches the tubing tail at 9012' MD. 6. When coil reaches 9010' MD and the leading edge of the cement reaches 8960' MD, shut in the backside and begin applying squeeze pressure. Stage up squeeze pressure to maximum of 1000 psi. (Note: Obtaining full squeeze pressure is not the ultimate objective, but to get an adequate cement plug for a cement ramp. Don't risk breaking down the formation trying to get a high pressure squeeze.) Do not over displace cement out the end of the coil if unable to build squeeze pressure. 7. PU out of cement to 8800' MD. Resume circulating holding backpressure as needed to maintain positive pressure on the cement. Circulate 1.5# Biozan and launch ball. Chase ball to nozzle then RIH at 1:1 jetting at max CT pressure down to 9010' (target TOC). 8. Swap to friction reduced water or 0.5# Biozan. Jet uphole at 80% running speed and max CT pressure. Wash all GLMs. Freeze protect top -2000' of well bore. Thoroughly wash the tree and BOP stack. 9. RDMO coil tubing. Page 2 0[2 May 3,2007 Gas Lift andreVDummy Valve 1 (2719-2720, OD:5.313) Gas Lift andreVDummy Valve 2 (5399-5400, OD:5.313) Gas Lift andreVDummy Valve 3 (6944-6945, OD:5.313) Gas Lift andreVDummy Valve 4 (7852-7853, OD:5.313) Gas Lift- andreVDummy Valve 5 (8348-8349, OD:5.313) Gas Lift andreVDummy Valve 6 (8881-8882. OD:5.313) SBR .---- (8947-8948, OD:35û0) PKR -- (8974-8975, OD:6.156) Perf (9101-9221) " KRU 1 C-03 ~--~~~~...- I\.CO. I ,-,-VJ L '- '-'COUlCOUl IVI LCUICUl "'''UII:--' C'\.I. . Gary, This confirms our conversation of a few moments ago regarding the process forward on this well. Since the existing perforations in the well will be covered with cement the penetration is considered abandoned. A 403 will be needed for authorization of the cementing work. Further the new penetration will now be a sidetrack so a new 401 with check for 1 C-03A will need to be submitted. CP AI should request that the existing permit be canceled. You have indicated that you are working on the 403 and that it should be delivered to the AOGCC office today. You further indicated that the pumping of the cement via service coil is the only time critical task since actual drilling is not planned for about a week. I will look forward to receiving the sundry. I should be here until at least 1630. Call or message with any questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 5/3/2007 2:52 PM: Tom - As I explained over the phone, the whipstock that was planned for well 1C-03L 1 (PTO 207-044) will not be ready in time for the spud of that well. Instead, as was identified as our contingency plan on the original PTO application, we'll place a cement plug from PBTO (-9160' MO) up to 9010' MO for purposes of a cement ramp exit. Our procedure calls for laying in 10 bbl of cement then washing back down to the tubing tail at -9010' MD. We plan to perform this operation tomorrow. Please let me know if you have any questions, and thanks for your help. J. Gary Eller Wells Engineer ConocoPhillips - Alaska .j' Lo Of )0/, ';20/17"9/ TTe ~; Cre r/Qcf.. ¡} fo/"1J' to R~ f"ltJtrecl Ilhtv 1"1tqr- Irocll/ce5 r~e ~ß1-e. hIP' qf Tqe e~/;lio/ teí!1. Tle,efo/ß¡ ~ ~~;r;¡ r/'e 7ðtff' ,''2 /lot- )er7 C(6tJ"cIo,., ed/vi 11/.'/1 ie t:ocIvcPC! 1M C1 m()AL e~d¡eIfT ¡:P1q~t?~ Nt) 'Iljl1t';¡r 'e......è7'v ,'f l1eû?~7 /' /~ work: 907-263-4172 eel!: 907-529-1979 fax: 907-265-1535 I of I 5/3/20074:00 PM · . ~1f~1fŒ (ffi~ ~~~~æ~ / AI~ASIiA. OIL AlQ) GAS / CONSERVATION COMMISSION I SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Dear Mr. Eller: sCANNED APR 1 1 2007 O-,\6Cõ \C6 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 C-03 Sundry Number: 307-111 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 fonD.. 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. DATED this 5' day of April, 2007 Enc!. . Conoc6Phillips . Gary Eller Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 April 4, 2007 RECEIVED Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 APR 0 4 2007 Alaska & Gas Cons. Commission Anchorage Subject: Application for Sundry Approval for 1C-03 (APD # 180-138) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming work on the Kuparuk well 1 C-03. We intend to lay a cement plug over a portion of the perfs up to 9160' MD. This work is in advance of the Coiled Tubing . work to be done on 1 C-03L 1, the permit to drill for which was submitted in March. If you have any questions regarding this matter, please contact me at 263-4172. Sin~ ~ ~EII~ Wells Group Engineer CPAI Drilling and Wells JGE/skad · RECEIVED (flf 4-5"07 'fI. . STATE OF ALASKA fJ-,-\ 15'"- .APR 0 4 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION . . . APPLICATION FOR SUNDRY APPROV Araska 011 & Gas Cons. Comrrnsslon Anchorage 20 MC 25.280 . 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0, Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0' Exploratory 0 180-138 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20535-00 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? Yes 0 No 0 1 C-03 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 ' RKB 94' . Kuparuk River Field 1 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): 9700' , 6821' . 9384' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 80' 80' SURFACE 3120' 10-314" 3214' 2682' PRODUCTION 9581' 7" 9675' 6804' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9101 '-9221' 6421'-6500' 3-1/2" K-55 9013' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FHL pkr= 8974' Camco TRDP-1AE SSSV= 1871' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat April 17, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission RE¡presentative: 18. I he..by œrt~o,"g ,., ae ,"" oo"ect to the be.t of my '"owtedge Contact: Gary Eller @ 263-4172 PO"," N.me aIV Eller ~ ~ Title: Wells Group Engineer '--- . Date 4--/3/07 Signature " "".. (' k /"'0.. Phone 265-6958 \ Commission Use Only I ...-.J Sund'hN~mber: 1 Conditions of approval: Notify Commission so that a representative may witness L'1 II-- 1,1 Plug Integrity 0 BOP TestR Mechanical Integrity Test 0 Location Clearance 0 Other: ~g~..;\ '~J~"'\.~,,,-...J~. ~~ ~S~. Saboe,"""t Fom Rooa,..d' LiC) ~ RBDMS 8Ft APR 1 () 2001 App, rn'edby -' {) 4 tMIS~IONER APPROVED BY Date: 1/£-61 THE COMMISSION Form 10-403 Revised 06/2900 R1 G ìN1\ L - Submit in DUPliC~ of D7 ~~~. ~.. ~ . 1 C-03 Pre-CTD Procedure . ~ ConocoPhillips Alaska, Inc. 1 C-03 Pre CTD Sidetrack Prep Drilling network: _ Wells network: The anticipated spud date for Nordic 2 to drill a single CTD horizontal lateral from weIll C-03 is April 30, 2007. Objectives: Prep well for a CTD sidetrack Pre-Rig Work Summary: 1. DHD 2. DHD 3. DHD 4. S 5. DHD 6. S 7. CT 8. CT 9. S 10.0 11. 0 12.0 13.0 (Done 8/11/06) (Passed 3/15 & 3/12/07) (Failed 3/15/07, will be replaced.) MIT -OA PPPOT-T & IC. PT Master & Swab to 5000 psi, drawdown test to 0 psi. Freeze protect; dummy off all GLMs. MIT-IA to 2500 psi. Tag fill; caliper 7" casing and 3W' tubing down to 9200' MD Mill out D-nipple at 9012' MD to 2.80" ID Lay in cement plug from PBTD to 9160' MD. Circulate clean above 9155' MD since planned set point for the top ofthe TTWS is 9125' MD. Run dummy whipstock drift (2.75" x tag top of cement. Actual whipstock and anchor are ~ 18' long. Torque wellhead bolts to spec. Bleed gas lift and production lines to zero and blind flange. Bleed IA &OA to 0 psi. Install BPV. Remove wellhouse, drill mouse hole, level pad NOTES: · Max DLS in 1C-03 is 7.5 deg/100ft at 1800' and 8.2 deg/lOOft at 8200' MD · Max deviation is 55 deg at 4100' MD · Minimum restriction is the 2.75" D-nipple at 9012' MD, but this will be milled out at 2.80" ID. Well also has 2.813" X-nipple profiles at 1871' and 8947' MD. · SCSSVat 1871' MD has been locked out March 29, 2007 Page 1 of3 . 1C-03 Pre-CTD Procedure · Coil Tubina - Prepare Well for Whipstock Objective: Mill out the D-nipple at 9012' MD to 2.80" ID. Also, place a cement plug from PBTD up to a TOC at 9160' MD. Note: · Not necessary to squeeze perfs. We're trying to abandon some of the rathole in the event that we need to place cement for a cement ramp exit if the whipstock fails. · Expected reservoir pressure = 2800 psi (10/19/06) = 8.3 ppg EMW . Expected reservoir temp ~ 1570 F. Adjust cement properties accordingly. Confirm temperature from previous SBHP surveys. · Monitor annulus pressures while pumping and bleed off as necessary. Maximum IA & OA pressure should be 2000 psi & 1000 psi respectively. Mill Out D Nipple 1. MIRU lo/,¡" coil tubing. PT BOPE to 3500 psi, conduct prejob safety meeting. Plan to circulate diesel during milling operation to reduce losses to 8.3 ppg formation. MU BRA with 2.80" DSM and 2Ys" Baker Extreme motor. 2. RIH circulating at minimum rate. Tag 2.75" D-nipple at 9012' MD. Be aware of the 2.813" X-profile at 8947' MD so as to not damage it. PU 4', establish circulation at 60 gpm (max pump rate for the motor). RIH slowly, begin milling out the nipple to 2.80" ID. lliote: The tubing tail below the FHL packer is probably not Baker-locked in place. Mill slowly to avoid backing off the tailpipe. Ifwe do accidentally back off the tailpipe however, we should have sufficient rathole to chase it to bottom.) Make several passes through the nipple to confirm that it is adequately milled out. Circulate clean, POOH. 3. LD milling BRA. Lay in Cement Plug 4. MU slick nozzle BRA; standard balldrop nozzle wi jet swirl profile and 5' stinger to CT. RIH. 5. Tag PBTD at ±9384' MD while pumping at minimum rate. PUH 10' and flag pipe. Pull up above perfs @ 9000' and circulate at maximum rate. Monitor for lo.§.ses t~{~~tion while circulating. Continue circulating while waiting on cement ~. .-::'...~t\~:: ¥. ~ iJi. ?-V'¡ 6. RU cementers. Mix a pumpable 12 bbl of 15.8 ppg cement (8 bbl casing volume, 4 bbl excess) · Target TOC 9160'. Max TOC assuming all 12 bbl stays in the casing = 9061' MD. · Prior to pumping cement, review the 24-arm casing/tubing caliper data to make sure that the completion jewelry is approximately on depth with the open-hole logs. The desired cement top is based on open- hole depth via gamma ray, not on the tubing tally. . Bring pod up to weight and shear thoroughly. QC test cement. Send sample to lab for UCA testing. 7. Pump the following down the coil: a) 5 bbl water spacer (do not use friction reducer, 1313 will clabber cement) b) 12 bbl neat 15.8 ppg cement c) 10 bbl of spacer water d) diesel March 29,2007 Page 2 of3 . 1C-03 Pre-CTD Procedure · 8. Position nozzle 10' above PBTD as cement reaches nozzle. Take returns and allow cement top in casing to rise 50' above nozzle before beginning to pull up hole. POOH laying in cement 1: 1 taking returns to open top tank for verification. Plan to place nozzle at 9061' MD (i.e. theoretical TOe) as the last of the cement exits the coil. Continue to pull up hole circulating to 9015' MD. Circulate at 9015' MD for 30 minutes. Notes: . If no cement is placed behind pipe, the 12 bbl of cement will extend 323' up the 7" casing. Strung out cement might extend up into the 3 Yz" tubing. . The PPROF of3/3/07 showed 100% of production coming from the perfs 9100' - 9136' MD. Unlikely to achieve any kind of squeeze pressure with minimal cement being placed across these perfs. Remember though, the objective is not to squeeze perfs but to plugback the rathole below the planned TOWS depth of9125' MD. 9. Swap to 1.5# Biozan sweep and launch ball to open jetting ports. Chase ball to nozzle then RIH at 1: 1 jetting at max CT pressure down to 9155' MD in order to establish TOC at 9160' MD (i.e. 5' difference allows for jetting action of coil). Make several up/down passes to make sure the 7" casing down to 9155' MD is clean. 10. Jet uphole at 80% of returns velocity and max CT pressure. Wash all GLMs. 11. Freeze protect top 2000' of well bore. Thoroughly wash the tree and BOP stack. RD CTU. cc: Wells Project Coordinator (Chaney/O'Dell) Wells Coil Tubing Supervisor Danny Venhaus Lamar Gantt Sam Johnstone CPF 1 Production Engineer March 29, 2007 Page 3 of3 . . KRU 1 C-03 1C-03 L. API: 500292053500 Well Tvpe: PROD Anqle ~ TS: 49 deq ~ 9101 SSSV Type: LOCKED OUT Orig 12/31/1980 Angle @ TD: 48 deg @ 9700 SSSV Completion: (1871-1872, Annular Fluid: Last W/O: Rev Reason: TAG 00:3.500) Reference Ref Log Date: Last Update: 10/28/2006 Loq: Last Taq: 9384' RKB TD: 9700 ftKB Last Tag 10/19/2006 Max Hole 56 deg @ 8400 GasUl! .. Date: Angle: MandreVVat.<e Casing String - Al.l. STRINGS 1 (271!t-2720, Description Size Top Bottom TVD wt Grade Thread 00:5.313) CONDUCTOR 16.000 0 80 80 6.50 H-40 SURFACE 10.750 0 3214 2682 45.50 K-55 PRODUCTION 7.000 0 9675 6804 26.00 K-55 TubinQString - TUBING GasUl! .. Size I Top I Bottom I TVD I wt I Grade I Thread MandreVValve 3.500 I 0 I 9013 I 6365 I 9.20 I K-55 I BTC 2 (5399-5400, 00:5.313) Peñorations Summary Interval I TVD I Zone I Status I Ft I SPF I Date Type I Comment 9101 - 9221 6421 - 6500 ~-4,C-3,C-~ Open 1120 I 8 12/31/198~ I Gas Lift MandrelsNalves Gas Lil! .. St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv landreVOummy Mfr Run Cmnt Vat.<e 3 1 2719 2374 Cameo KBUG GLV 1.0 BK 0.156 1211 /14/200 (6944·6945, 2 5399 3978 Cameo KBUG OV 1.0 BK 0.250 0 /13/200 00:5.313) 3 6944 4968 Cameo KBUG DMY 1.0 BK 0.000 0 /13/200 4 7852 5629 Cameo KBUG DMY 1.0 BK 0.000 0 2/31/198 5 8348 5959 Camco KBUG DMY 1.0 BK 0.000 0 2/31/198 GasUl! 6 8881 6280 Cameo KBUG DMY 1.0 BK 0.000 0 :s/26/199 landreVOummy Other plugs, equip., etc.) - JEWEl.RY Valve 4 (7852·7853, Depth TVD Type Description ID 00:5.313) 1871 1795 SSSV Camco'TRDP-1AE' (Locked Out) 2.813 8947 6322 SBR Baker EL-1 2.813 8974 6339 PKR Baker FHL 3.000 GasUl! 9012 6364 NIP Cameo '0' Nipple NO GO 2.750 landreVOummy 9013 6365 SOS Baker 2.992 Valve 5 9013 6365 TTL 2.992 (8348-8349, General- Notes 00:5.313) Date I Note P/23/199QWAIVERED WELL: IA x OA ANNULAR COMMUNICATION GasUl! .. landreVOummy Vat.<e 6 (8881-8882, 00:5.313) SBR (8947-8948, 00:3.500) PKR (8974-8975, 00:6.156) TUBING (0-9013, 00:3.500, ~ 10:2.992) NIP (9012-9013, -----'- 00:3.500) ~ ~ Perf ~ ~ (9101·9221) ~ ~ ~ ~ ~ ~ 03/20/07 Schlumbel'gel' GÜ--- NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ¡'iN? ~?, 2. ?OO/scANNED APR 0 3 2007 Company: Alaska Oil & Gas Cons CIDmm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk / '7;û -/3 Z) Well BL CD Color Job# Log Description Date 1C·03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1 E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1 E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 3S-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1 C-1 0 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 1 D-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1:-;-- . . Drill Site lA Wel 1 No. 1A-4 1A-5 1A-7 1A-9' 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date Drill Site Well No. L,o9 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Wel 1 No. 1C-1 1C-2 1C-3 lC-4 1C-5 1C-6 1C-7 1C-8 ' Lo9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 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 (~D-8 (WS-8) 5/io/78 Oil & Gas Co:,s ,. ...... Attachment Page 2 Drill Site 1H Well No. Lo9 Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ ~IQ? 12/1785~ Drill Site Well No. Lo.q Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28781 1111/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 Alaska Oil & Gas Cons. A,'~-.norage 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 !1/19/82 5/7/83 Attach.ment ~! Page 3 Drill Site Well No. Lo9 Date 1Y 1Y-1 6~6~83 10/21/83 1Y-2 6/10/83 314184 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 li~_ 5110183 ~ 11/21/83 ijl 7/ S/8m 1Y-125/25/83 1Y-135/27/83 1Y-145/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Wel 1 No. Log Date 2C-4 2/19/85 2~28~85 2C-7 10/15/84 Drill Site '2Z ' Well No. Lo9 Date ~ 7/10183 2Z-2 m : 6/24/83 7119183 2Z-3 ' 8/5/83 2Z-4 7/!2/83 2Z-6 7/27/83 2Z-7~ 7/28/83 2Z-8 8/3/83 VLF: pg: 0052 A.qchorage Drill Site lA Well No. '" 1A-4 '~lA-7 ~1A-9 ~1A-11 '~1A-12 '~IA- 14 '~1A-15 ',,1A-16A ATTACHMENT II KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~x, / 5/7/82/ 1/25/82~ '-- 3/23/83 / 1/19/83~b ~.-. 3/21/83 ,'" 318182 4/1/82 6/5/82 5/11/8z~ ~ 618182/} Dri 11 Si te Wel 1 No. Log Date '"~IB- 1 12/26/81 ~1B-2 6/25/81 '~1B-3 11/16-18/81"-~ " 3/12/82/ ~-lB-6 11/18/81~ ',~ 9/10/82/ .- ~1B-7 11/23/81 ~1B-8 12/28/81'-~ '~ 8/4/82/ ~IB-g x 6/24/82-- ~._8/__3_/84 ~ lB Drill Site 1C Wel 1 No. Log'Date 5/9/8'1 5/8/81 7/13/81 ~]/8/8~> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D "~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 RECEIVED FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. April 14, 1982 C. V. Chatterton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Enclosed is the subsequent report for Kuparuk Well lA-7 which covers the water injectivi'ty test and the reper- forations of,.the. Lower Sands. Also enclosed, per our phone conversation, are copies of the revised sub- sequent reports for Wells(?:lC-3 .:iand 1C-4, correcting surface and bottomhole locations which have not been received by your office. Sincerely Simonsen slz Attachments Sundry Notices and Reports on Wells Well Number C-3 Attachment 11-14/15-81 - Schlumberger reperforated the interval 9101'-9221' with 4 SPF, 0° phasing. 11-16-81 - the frac job resumed and formation breakdown was achieved. The formation readily took sand until mechanical problems forced many shutdowns during the job resulting in sand being left in the wellbore to a depth of 8740' MD, 361' above the top perforation at 9102'. Appro~-imately 60,000 lbs of proppant was put away into the fracture. The decision was made at this time to attempt to clean ~rac sand out of the wellbore with a coiled tubing unit. 11-20-81 - Fracmaster and Dowell on site. A cleanout was attempted using 286 bbl of diesel and 3000 gal of Nfl~O Frae sand was found at 9137' following the cleanout. A w test following the cleanout gave a rate of 1109 BPD compared to a pre-frae rate of 564 BPD. APR i 82 Oil & Gas Cons. Comm~ss~m~ SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~(] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-138 :3. Address 8. APl Number P.0.B0x 360, Anchorage, AK 99510 50- 029-20535 4. Location of Well 9. Unit or Lease Name .... Kuparuk 25649 SL 1583' FNL, 1165' FWL Sec 12 T11N, RIOE BHL 1143' FSL, 649' FWL, Sec 11, T11N, RiOE 5. Elevation in feet (indicate KB, DF, etc.) 94' KB 12. I 6 . Lease Designation and Serial No. ADL 2.~649 10. Well Number lC-3 11. Field and Pool Kuparuk River Field KlJparl)k Rivmr Oi ! Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X[] Altering Casing [] Stimulate [] Abandon [] Stimulation X[] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ..' [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.t05-170). A NOTICE OF INTENTION to stimulate Kuparuk Well 1C-3 with a fracture job was submitted on 8-27-81. The fracture design called for 96,00Q lbs of proppant and 54000 gal of gelled diesel. The job was scheduled to begin 11-10-81, however, problems were encountered which necessitate..d changing the design and scope of the frac job. A sequence of events follows: 11 -10-81 - with Dowell and Schlumberger on location and pressure tested the frac job was begun. The job was terminated after pumping 430 bbl of gelled diesel at a surface pressure of 4000 psi with no sign of formation breakdown. Indications were that the perforations were plugged restricting our pump rate into the formation. The decision was made to make a second attempt at fracturing the well using a 12% HC1 acid preflush to open the perforations. 11-14-81 - with Dowell and Schlumberger again Qn location and pressure tested a prepad of 5000 gal of 12% HC1 was pumped followed by gelled diesel. The job was again terminated when no sign of breakdown was seen with a surface pressure of 4000 psi. The decision was made to reperforate the well and try again. (SEE ATTACHMENT) 14. I hereby certify that the foregomg is true and correct to the best of my knowledge. The space for Commission Conditions of Approval, if any: Approved by. TiA~rea Op.erati o~s Enai neer COMMISSIONER the Commission Form 10-403 Date Date ., Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-138 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20535 4. Location of well at surface 1583'FNL, l165'FWL, Sec 12, TllN, RIOE, UM 9. Unit or Lease Name Kuparuk 25649 At Top Producing lnterval 1301'FSL, 1098'FWL, Sec 11, T11N, R10E, UM 10. WelINumber 1(]-3 At Total Depth 1143'FSL, 649'FWL, Sec 11, TllN, R10E, UM ll. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 94' RKBI ADL 25649 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/10/80 12/27/80 12/31/80I -- feet MSL 1 .17. Total Depth (MD+TVD)18.PlugBackDepth(MD+TVD)19. Directional SurveY9700, 6821 ' 9589' 6746' YES ~] NO [] I20' DepthwheresSsvset1871 feet MD [ 21.ThicknessofPermafrost1650, (app]:ox.) 22. Type Electric or Other Logs Run DEL/BHCS/GR, FDC/CNL/NGT, Gyro/CCL, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1F," ~5~ H-40 Surf. 80' 24" 200 sx Permafrost 10 ~/~" ~5.5~ K-55 Surf 3214' 13 3/4 1500 sx Fondu & 25( sx AS II - ~ . 7" 2F~# K-55 Surf. 9675' . 8.3/4" 72.5 sx Class ,, 24. Perforations open ~to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9101 '-9221' w/4 SPF 3 1/2" 8983' 8943' reperf'd same interval w/4 SPF ,. 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD). AMOUNT& KINDOF..MATERIAL uSED . Perf. Tnt'erval 1,800 bbl oelled diesel. 5000' oal ~2% HCl.60'OOOlbs ,., . R.111¥ ~ f~ n~,nnn.~nf r- 27. PRODucT'ioNTEST Left Sand in casino ' Date First Production I.M.ethod of Operation (Flowing., gas lift, etc.) .... '1 12/16/8 Flowing I · . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MC'F WATER~BBL CHOKE SIZE IGAS'OILRATIO 11/?~l/R1 ~.3 TESTPERIOD'J~ .'.311 105 F,4/64 · Flow Tubing Casing Pressure CALCULATED. O!L-BBL .: GAS-M,CF WATER~BBL OIL GRAVITY-APl (corr) Pres~s0 ...... 24,HOUR:RATE I~ 1109 375 · :. 28. CORE DATA ' Brief description of lithologY, porosity, fractures, appa'rent dips and presence of oil, gas or water. Submit core chips. None" " RECEIVED . . · · · MAR 1 5, 1982 . · N chorage. ~rm 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE N,AME Include interval tested, pressure data, all fluids recovered and gravity, ME,AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form. 9101 ' 6421 ' Base Kuparuk Rlver Form. 9588' 6746' I' 31. LIST OF ATTACHMENTS , · 32. I hereby certify that the foregoing is true and correct to the best of my kno~vledge Signed L ~, ~~ Title Area 0ps. E ngr. Date I~R ~ 0 ~8~ INSTRUCTIONS General: This form is designed for submitting a complete and correCt well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is.completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, Showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing toolo Item 27 Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28~ If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Bo~ Anchorage, Alaska 99510 Telephone 907 277 5637 December 22, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached find revised Sundry Notice Reports for Kuparuk Wells ':tC~3, and 1C-4 surface and bottomhole locations. Sincerely, J. S. Dayton EAS/bl Attachments Subsequent to correct ARCO A~aska, Inc. is a subsidiary of AtlanticRichfieldCompany DEC2 z, ]981 Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)C] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0.Box 360, Anchorage, AK 99510 4. Location of Well SL 1583' FNL, 1165' FWL Sec 12 T11N, RIOE BHL 1143' FSL, 649' FWL, Sec 11, T11N, RiOE 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 94' KB I ADL 25649 12. 7. Permit No. 80-138 8. APl Number 50- 029-20535 Perforate Stimulate Repair Well Pull Tubing 9. Unit or Lease Name Kuparuk 25649 10. Well Number lC-3 1 1. Field and Pool Kuparuk River Field Kunaruk R ,i'vCr Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Oi ! Poo! NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations X[] Altering Casing [] [] Abandon [] Stimulation X[-'l Abandonment [] [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A NOTICE OF INTENTION to stimulate Kuparuk Well lC-3 with a fracture job was submitted on 8-27-81. The fracture design called for 96,000 lbs of proppant and 54000 gal of gelled diesel. The job was scheduled to begin 11-10-81, however, problems were encountered which necessitated changing the design and scope of the frac job. A sequence of events follows: 11-10-81 - with Dowell and Schlumberger on location and pressure tested the frac job was begun. The job was terminated after pumping 430 bbl of gelled diesel at a surface pressure of 4000 psi with no sign of formation breakdown. Indications were that the perforations were plugged restricting our pump rate into the formation. The decision wa~=~ made to make a second attempt at fracturing the well using a 12% HCl ~,~ acid preflush to open the perforations, mm, 11-14-81 - with Dowell and Schlumberger again ~n location and pressure tested a prepad of 5000 gal of 12% HC1 was pumped followed by gelled diesel. The job was again terminated when no sign of breakdown was seen with a surface pressure of 4000 psi. The decision was made to reperforate the well and try again. (SEE ATTACHMENT) 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~- ~ _(~~ T)~brea O perati o ns The space el ~w ioTCommission J Conditions oe~f Approval if any' E n g i n e e r Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Sundry Notices and Reports on Wells Well Number C-3 At tachment 11-14/15-81 - Schlumberger reperforated the interval 9101'-9221' with 4-SPF, 0° phasing. 11-16-81 - the frac job resumed and formation breakdown was achieved. The formation readily took sand until mechanical problems forced many shutdowns during the job resulting in sand being left in the wellbore to a depth of 8740' MD, 361' above the top perforation at 9102'. Approximately 60,000 lbs of proppant was put away into the fracture. The decision was made at this time to attempt to clean frac sand out of the wellbore with a coiled tubing unit. 11-20-81 - Fracmaster and Dowell on site. A cleanout was attempted using 286 bbl of diesel and 3000 gal of ~ Frac sand was found at 9137' following the cleanout. A w test following the cleanou.t gave a rate of 1109 BPD compared to a pre-frac rate of 564 BPD. ECEiYEI) DEC,,,?... z, ]98! A!a. ska 0il & Gas Cons. Sommissio. Anchorage NORTH ~LOPE r.~GI,',EERI~,G TC' J. J. Pawelek/Ann Simonsen DATE- /~, ~/?- ~/' NELL NAME' iransmiu~d herewith are the following YL~,~r HOTE: - BLUEL!HE, · . ~- SEPIA, F - FILM, T - TAPE RECE! T ACK:~OWLEDGED . DATE' ~ PE,.e? I 1981 ~ RrTURN RECEi?T TO: ARCO ALASrCA, I~,. ~aska Oil & Gas Cons. Comml$$|O~ '" Anchorage ATTO] A,'~H SInu~is=,, - AFA/311 P.O. BOX 360 ~',e,,,~n ~ e~ ~,, 90510 ARCO A.~aska, Inc. Post Office _! Anchorag,~, ..... ~i\ ,~a 59510 Telephone ~07 277 563'7 December 11, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached please find Well lB-7, 1C-3, Sincerely, J S Dayton Area Operations Engineer EAS/bl Attachment Comm. subsequent reports 1C-4, and 1E-3. for Kuparuk P, EE[!IVED Sundry Notices and Reports on Wells Well Number C-3 At tachment 11-14/15-81 - Schlumberger reperforated the interval 9101'-9221' with 4 SPF, 0° phasing. 11-16-81 - the frac job resumed and formation breakdown was achieved. The formation readily took sand until mechanical problems forced many shutdowns during the job resulting in sand being left in the wellbore to a depth of 8740' MD, 361' above the top perforation at 9102'. Approximately 60,000 lbs of proppant was put away into the fracture. The decision was made at this time to attempt to clean frac sand out of the wellbore with a coiled tubing unit. 11-20-81 - Fracmaster and Dowell on site. A cleanout was · attempted using 286 bbl of diesel and 3000 gal of Nf~ Frac sand was found at 9137' following the cleanout. A w test following the cleanout gave a rate of 1109 BPD compared to a pre-frac rate of 564 BPD. SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address ?.0.Box 360, Anchorage, AK 99510 4. Location of Well BHL 1697' FNL, 1428' FEL, Sec 11, TllN, R10E 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. -- 94' KB I ADL 25649 12. 7. Permit No. 80-138 8. APl Number 50- 029-20535 9. Unit or Lease Name Kup~ruk 25fiZ~q 10. Well Number C-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~L~ Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A NOTICE OF I submitted on and 54000 gal however, NTENTION to stimulate Kuparuk Well C-3 with a fracture job wa.~ 8-27-81. The fracture design called for 96,000 lb of proppant 'of gelled diesel. The job was scheduled to begin on 11-10-8 problems were encountered which necessitated changing the design and scope of the frac job. A sequence of events follows: 11-10-81 - with Dowell and Schlumberger on location and pressure tested th~ frac job was begun. The job was terminated after pumping 430 bbl of gelle~ diesel at a surface pressure of 4000 psi with no sign of formation break- down. Indications were that the perforations were plugged restricting pump rate into the formation. The decision was made to make a second attempt at fracturing the well using a 12% HC1 acid preflush to open the perforations 11-14-81 - with Dowell and Schlumberger again on location and pressure tested a prepad of 5000 gal of 12% HC1 was pumped followed by gelled diese The job was again terminated when no sign of breakdown was seen with a surface pressure of 4000 psi. The decision was made to jreDerforatev~'~ the well and try again. (SEE ATTACHMENT) R~ DEC 1 5 I981 14. I hereby certify~hat the foregoing is true and correct to the best of my knowledge. ' Signed . . Tit,eArea Operations mng~~ Date The space be.l~. ' for Commission use ~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate J. J. Pawelek/Ann Simonsen Transmitted here:.;ith are the following' pLc3Cs ,, - . .... ~ :,OIE BL - BLUELTiIE, S SEP.=, F - FILM, T - TAPE DATE' ~,.._= ,-,c,UR.~:-,~'ECFi?T TO' ARCO ALAS~3~, ATT~-~' A~;~ S~:.'.n.~.~q~'~ P.O. BO:': 360 A;iCHORAO'Z, AK 99510 - AFA/31 1 RECEIVED OCT 1 6 1981 Alaska Oil & Gas Cons. Commissio~ Anchorage STAT[~ OF ALASKA ALASKA O,L AND GAS CONSERVATION COMMISSION 1. ,DRILLING WELL ~, CO~;IPLETED WELL ~ OTHER · 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-138 3. Address 8. APl Number P 0 Box 360 Anchorage, Alaska 99510 50-029_20535 4. Location of Well 9. Unit- or Lease Name Kuparuk 25649 · 10. Well Number Surface location 1583' FNL, 1165' FWL, Sec 12, TllN, R10E C-3 11. Field and Pool Kuparuk River Field 5. Elevation in feet lind,cate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 - Pool KB = 94' ADL 25650 ! 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [-] Alter Casing [] Perforations [] Altering Casing. [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other Pull Tubing [] Other I--~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each comp4etion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). .. ARCO Alaska, Inc. proposes to perform a fracture treatment on the Upper and Middle Kuparuk sands in cased well C-3. Pumping equipment will be tested to 5000 psi. A 3000'psi lubricator will be used for all wire- line work. All circulated and flowed fluids will be diverted to tanks on location. The well will be tested subsequent to the stimulation. The expected starting date is 10-22-81. __~. ~ cq:~m;t Work Reported on Form No./~ Datexl .~?,./~~/ RECEIVEI) OCT 1 6198I Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify th~3t the fore_g_omg ~s true and correct to the best of my knowledge. S,gned Title OPerati°ns Area Engineer s~_a_c.e bel~~ Com,?is_s. Lo_ ri use Con~or, s of :~'bproval. ~f any: .~"2~"~-~"'~k ~ Fo,m 10403 ;--' e ~ 7-I-E0 Date 8-27-81 t, Subsequent Work l~eported Approved Copy. on Form No./d :9¢ 3Dated/_~~~l Returned Bv Order of .__~, COMMISSIONIER the Corniness,on - - Submit "Intentions" ~ Triplicate and "Subsequen~ Reports" in Duplicate J. J. Pa;-:elek/Ann Simonsen DATE' ~- Z~- ~// WELL [:A:.;E' · · ' ~ ~-' ¢~ . Transmit~ d here;.;ith are ~n~ following · ."~ - ' T TAPE PLEASE NOTE BL - BLUELT,,c, S SEPIA, F - F~LM, - K 'n" "," :! ¢?,. ,, . TE:,~ ,.., REC£1PT AC ;,~,',LEu~,ED [_. . .... ,,:,,', i~:,. .. LC .:. . ,-')... ~-~ .,. ~ l ,? '2 ~ ,~PLEASE RETu?.;I ',LuF_...~,'T TO: ARCC ALAS~C;\, INC. Mc!mrage f ...... ' Al~oka Oil & GOS Ct)ilS, Comniission ATT!~' A~;'I S~H0;'~SE!! - AFA/3]] P.O. BOX .36O . ,~,,,.xu~..~OF_, AK °C~l 0 . . STATE OF ALASKA ALASK~'I' )IL AND GAS CONSERVATION ~. ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO A1 aska, 3. Address Inc. P.O. Box 360, Anchorage, AK 99510 4. Location of Well Surface Location: 1583' FNL, 1165' FWL, Sec. 12, TllN, R10E 5. Elevation in feet (indicate KB, DF, etc.) -- KB=94 ~ 0 12. 6. Lease Designation and Serial No. ADL 25649 7. Permit No. 80-138 8. APl Number ~29-20535 (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X[--I Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair .Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began Perf operations on 7/10/81. RU to perf, SSV failed. RD perf unit & RU WL unit & inserted valve & packoff for SSSV. SSSV began functioning properly POH with insert valve & packoff. RU to perf, test BOP & lub to 3000 psi. ~erf'd intervals 9188'-9221', 9155'-9188', 9122'-9155' & 9101'-9122' w/ Schlumberger 2 1/8" Enerjet w/4 SPF. RI'H with HP, Gradio, Spinner & temp tools. Flowed well to stabilize f/production test. Flowed @ rate of 564 BOPD. GOR=400. FTP=55 psi. Ran production logs. FBHP=1735psi. Shut in well for PBU, final SIBHP=3260. POH with PL string. Shut SSSV & secure well W.O. Gas lift installation on 7/13/81. NOTE: HP Tool set at 6276'ss RECEIYED SEP 2 9 ]98] Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~O~~ Area Operations Engineer Signed .... . . . Title The space belo~or Commission use /~ ConditiOns of Approval if any: ~/ Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 9. Unit or Lease Name Kuparuk 25649 10. Well Number C-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool TO' J. J. Pa,....'eiek/Ann Simonsen Transmi '=~/, ~' c~:~ herewith are the'follo;.:inm PLEASE tlOTE' BL - BLUELi~E, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKi~O',.,'E EDGED F'., TL'.';;. ~ I,L'u~c I ?T TO' DATE' ~::',~u ALAS!'3q, INC. ATI'i~' A~IN SIi.!ONSE~I - AFA/311 P.O. BOX 360 , ~'.~E, Ak 9c510.: A(,~ STATE OF ALASKA ~".,4 M ALASK IL AND GAS CONSERVATION C ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska Inc. 3. Address Box 360 Anchorage, Alaska Location of Well Surface location: Elevation in feet (indicate KB, DF, etc.) KB Elevation = 94 12. 99510 1583'FNL,1165'FWL, Sec. 12, TllN, R10E 7. Permit No. 80-138 8. APl Number 50- 029-20535 9. Unit or Lease Name Kuparuk 25649 10. Well Number C-3 11. Field and Pool Prudhoe Bay Field I 6. Lease Designation and Serial No. Kuparuk River Oil ADL 25649 Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate ~ Alter Casing [] . Perforations Stimulate [] Abandon [] St imulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing I-'l [] Abandonment r'"t [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Atlantic Richfield .Company proposes to perforate and flow test selected intervals within the upper .and lower Kuparuk Sands. All wireline work will be done through a 3000 psi lubricator, which will be pressure tested after being installed on the well head. All perforated intervals, test volumes, and production log runs will be reported on a subsequent report. Expected start date 5-12-81. Subsequent Work Beported No i_iuM D tca on Fo~rn · RECEJV'ED MAY - 1 1981 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commissi~n'use ~ Conditions of Approval, if any: Approved by Approved Copy FeD ur:"~ed By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NORTH SLOPE D,UL\q[FR.D,U From- J. J. Pawelek / Leo I~.sh Transmitted herewith are the follcxcing. Please note. BL - Blualine, S - Sepia, F - Film, T - Tape CEIVED ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. ]bx 360 Anch0rag.e., AK 99510 193 From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: EL - Blueline, S - Sepia, F - Film, T - Tape Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED Alasl~ 0ii & Gas Cons. Commission Aa~horage NOR/I{ SIDPE ENGINEFRING Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, From: F - Film, T - Tape STAT FILF:- /'T-- RECEIPT AC/<NOWLEDGED: E RE2URN RECEIFr TO: ARCO Alaska, Inc. Attn. Leo Lash'/ AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED FEBrl ..3 1981 Alaska 011 & Gas Cons. Commission Aschorage NORTH SLOPE ENGI_NRFRID3 Date- From: J. J. Pawelek / Leo Lash ~,. NAME: /~"~'~~ ,8-2 c~ c-$ Transmitted herewith are the following' Please note: BL - Blu~line, S - Sepia, F - Film, T - Tape j COMM I i' 4 ENG ['-ic-._~ ~oL ....... 2 G~ 3 STAT TEC STAT TEC CONFER: FILF: E REUJRN RECEIPT TO: ARCO Alaska, Inc. · Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 ARCO Oil and G~I~r' Ompany Iqorth Slope D~strict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 February 2, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 2-9 DS 3-13 DS 6-15 - DS. 15-21 DS 16-11 Kuparuk B-2 C-2 C-3 Dear Sir- Enclosed please find- l) The subsequent Sundry Notices for DS 2-9, DS 3-13 and DS 6-15. 2) The Completion Reports for DS 15-21, DS 16-11, B-2, C-2 and' C-3. Please note that the Completion Reports for DS 14-10, DS 15-10, DS 16-1, DS 16-16 and B-1 will follow shortly. Sincerely yours, ~P. A. VanDusen District Drilling Engineer PAV:sp Enclosures 'RECEIVED FEB - 1981 Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichlieldCc · ¢ i' STATE OF ALASKA ALASK ,.~'ILAND GAS CONSERVATION~'-'M~ ~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL .[~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Atlantic Richfield Company 80-138 3. Address 8. APl Number P.O. Box 360, Anchora9e, Alaska 99510 50-029-20535 4. Location of well at surface 9. Unit or Lease Name 1583' FNL, ]165' FNL, Sec ]2, T]]N, R]0E, UN Kuparuk 25649 At Top Producing Interval 10. Well Number ]30]' FSL, ]098' FNL, Sec ]], T]]N, R]0E, UN C-3 At Total Depth 11. Field and Pool ll43' FSL, 649' FWL, Sec ll, TllN, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Fi el d 94' RKB ADL 25649 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/10/80 12/27/80 12/31/80I -- feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9700MD 6821'TVD 9589MD 6746'TVD YES[~ NO[]I 1871 feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, G~vro/CCL~ CBL/CCL/GR .... 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 surface 80' 24" 200 sx permafrost t~ surface 10-3/4" 45,5# K-55 surface 3214' 113-3/4" 1500 sx Fondu 250 sx AS II 7" 26# K-55 surface 9675' 8-3/4" 725 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3N" 8983' 8943' n/a .. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · , 27. PRODUCTION TEST ,, ,, , Date First Production .. I Method of Operation (Flowing, gas lift, etc.) n/a Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASoMCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. -24-HOUR RATE ~ 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. none FEB - 19B1 N~s~ O~t & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME lnciucie intervat tested, pressure da[a, ati iluic~s recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GORo and time of each phase. T Kuparuk 9062' 6396' T Upper Sand 9100' 6421' none B Upper Sand 9142' 6448' T Lower Sand 9441' 6647' B Lower Sand 9516' 6697' B Kuparuk 9590' 6747' ., ., 31. LIST OF ATTACHMENTS ,,,' , Drilling History,, Gyroscopic Survey ,, ,~ · · ;32. I hereby certify that the foregoing is true and correct to the best of my knowledge _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well comPletion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple cOmpletion), so state in ite~ 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". [: ~r r,n 1 (3-Zl CI"/ C-3 DRILLING HISTORY Spudded well @ 2000 hrs, 12/10/80. Drld 13-3/4" hole to 3235' Ran 78 jts K-55 45.5# 10-3/4" csg w/shoe @ 3214' Cmt 10-3/4"' csg w/1500 sx Fondu & 250 sx AS II cmt. Circ 40~ sx Fondu to reserve pit - no top job required. ND d-iverter. Set & tstd 10-3/4" pkoff to 2000 psi - ok. NU & tst BOP. Tstd 10-3/4" csg to 1500 psi - ok. Drld FC & cmt to 3210'. Tstd 10-3/4" csg to 1500 psi - ok. Drld FS & 10' new form to 3245'. Tstd form to 12.4 ppg EMW - ok. Drld 8-3/4" hole to 9700'. Ran DIL/BHCS/GR, FD~/CNL/NGT. Ran 234 its 26# K-55 7" BTC csg w/shoe @ 9675'. Cmtd w/725 sx Class G cmt. Set & tstd 7" pkoff to 3000 psi - ok. Ran Gyro/ CCL, CBL/CCL/GR. Arctic packed 7" x 10-3/4" annulus w/250 sx Arctic set cmt & 115 bbls Arctic Pack. Tstd BOP's to 2000 psi - ok. Tstd 7" csg to 2000 psi - ok. Ran 288 jts 3½" tbg w/pkr @ 8943' and tbg tail @ 8983. Displaced well to diesel to tbg tail @ 8983'. Dropped ball and set pkr. Tstd 3½" tbg to 3150 psi ok. Tstd 7" x 10-3/4" annulus to 1000 psi - ok. ND BOP's. N~ and tstd tree to 3000 psi - ok. Secured well, began long term tbg tst and released rig @ 2230 hrs, 12/31/80. RECEIVED FEB - 1981 Alaska Oil & Gas Cons. Commission Anchorage 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 World Leader in Service to the Oil Industry December 29, 1980 Job #4451 North Slope Drilling: Enclosed please find our Gyro Survey on Kuparuk C-3 along with our Vertical Section and Horizontal '~iew maps. Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call 272-2496. Thank you for using Scientific Drilling International and please call again. Manager COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY F~ LINDSEY & ASSOC 9 JAN 81 KUPARUK C-3 KB ELEV 94o FT. JOB NO 4451 TRUE MEA$, DRIFT VERTICAL D ~.,,,-I ANGLE DEPTH D tl RECORD OF SURVEY SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 0 0 0 0o00 100 0 0 100,00 200 0 0 200.00 300 0 0 300,00 400 0 0 400,00 500 0 0 500,00 600 2 0 599.97 ?00 4 0 699.83 8.00 7 30 799,31 900 8 45 398,31 1000 12 0 996,66 1100 15 0 1093.89 -94,00 N O,OOE 6,00 S59,43W 106,00 S59,61W 206,00 S59,80W 306,00 S59,98W 406.00 S60,16W 505,97 S29,38W 605,83 S48,58w 705,31 S37,91W 804,31 S44,10W 902,66 S45,43W 999.89 S53.55W 1200 18 45 1189.56 1095.56 S52.95W ' O0 20 30 1233.75 1189,75 S55.10W ~,.,~JO 23 I5 1376.54 1282,54 S50.80w 1500 27 15 1466,97 1372,97 S45,91W 1600 27 30 1555,77 1461,77 S49.75W 1700 23 15 1646.10 1552.10 S55.96W 1800 30 45 1735,14 1641,14 S5.7,61W 1900 34 0 1819,58 1725,58 S57,90W 2000 39 0 1899,94 1805.94 $60,01W 2100 43 0 1975,40 1881,40 S60,41W 2200 45 0 2047.33 1953.33 560.01W 2300 47 ~5 2116.32 2022.32 S59.05W 2400 52 0 2180.75 2086.75 S59,68W 0.00 S 0.00 W 0,00 S 0,00 W 0,00 S 0.00 W 0,00 S 0.00 W 0.00 S. 0.00 W O,O0-S~-'-- .-0,00 W ~i . 1,22~ S".~ ~i~ .1,2! W. 5.27.S..//' 4,49'W" 12.55 S ~ 11,34 W 23.21S 20,61W 36,00 S 33,29 W 51,15 S 51,02 W 68,51S 74,28 W 88.24 S 101.45 W 110.68 S 131.18 W 139,01 S 163,04 W 169,87 S 197,12 W 195.73 S 231,25 W 220.57 S 269.21W 249,14 S 314,49 W 279,80 S 365.44 W 312.38 S 422.37 W 346.88 S 482.65 W 383,58 S 545,04 W 422.53 S 610.82 W CLOSURES DISTANCE ANGLE D M S 0.00 S 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 W O,O0 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 1.72 S 44 46 30 W 6.92 S 40 25 21 W 16.92 S 42 5 35 W 31.04 S 41 35 58 W 49,03 S 42 45 43 W 72,25 S 44 55 47 W 101.05 S 47 18 42 W 134.46 S 48 59 5 w 171.64 S 49 50 40 w '214,26 S 49 32 55 w 260,22 S 49 14 44 w 302,97 S 49 45 21 w 348,03 S 50 40 15 W 401.22 $ 51 36 51 W 460.25 S 52 33 3'7 W 525.33 S 53 30 48 W 594,38 S 54 17 42 W 666,49 S 54 51 47 W 742,72 S 55 19 34 W DOG LEG SEVERITY DEG/iOOFT 0.000 0-000 0,000 0.000 0.000 0.000 2.000 2.002 3.505 1.258 3,25i 3.049 3.751 1.770 2.830 4,129 0,855 ~,359 7.512 3.251 5.070 4,004 2.010 2.801 4,268 SECTION DISTANCE 0,00 O.O0 0.00 0.00 0.00 0.00 1,60 6.23 15.44 28,22 44,98 67.32 95.60 128.42 164.68 205.26 248.8~ 290,55 335.30 388.26 447.24 512,47 581.55 653.44 729,34 ARCO KUPARUK C-3 GYROSCOPIC SURVEY JOB NO 4451 JAN 81 RECORD OF SURVEY HEAS, DRIFT DEPTH ANGLE D M 2500 53 0 26~0 53 0 2: 3 52 0 28~0 52 15 2900 52 0 300O 51 3O 3100 51 15 3200 5C 30 3300 51 0 3400 52 0 3500 52 30 3600 52 45 3700 54 0 3800 54 30 3900 5a 30 4000 55 0 4100 55 30 4200 54 30 / LO 54 30 ~0 54 30 4500 54 30 4600 53 45 4700 54 0 4800 54 0 4900 53 45 5000 53 30 5100 53 0 5200 53 0 5300 53 0 TRUE VERTICAL DEPTH 2241,62 2301.80 2362.68 2424.07 2485,47 2547.38 2609.80 2672,90 2736.17 2798.42 2859,64 2920,35 2980,00 3038,43 3096,50 3154,21 3211.21 3268,57 3326,64 3384.71 3442.78 3501.38 3560,33 3619,11 3678,07 3737,37 3797,21 3857,39 3917,57 SUB SEA 2147.62 2207.80 2268.68 2330.07 2391.47 2453.38 2515.80 2578.90 2642.17 2704.42 2765.64 2826.35 2886,00 2944,43 3002.50 3060.21 3117.21 3174.57 3232.64 3290,71 3348,78 3407,38 3466.33 3525.11 3584,07 3643.37 3703.21 3763.39 3823.57 DRIFT DIREC DEG, S60,OOW S60.78W 560,88W S61.70W S61.86W 562.63W $62,81W S63.58W S64.43W S64,03W. S63.63W S63.83W S64.11W S64.33W S65.45W S65.68W S65,90W 566.58W 566.76W 567.55W S68.31W S63.71W S69,85W S70.03W S70.21W S70.41W S71.20W S71.38W S72.16W TOTAL COORDINATES 462.39 S 679.41W 501.85 S 748.85 W 540.51 S 818.12 W 578.43 $ 887.35 W 615.75 S 956.91W 652.31S 1026.41W 688.12 S 1095.85 W 723.09 S 1165.09 W 757.03 S 1234.70 W 791.05 $ 1305.17 W 825.92 S 1376.14 W 861.09 S -1447.40 W 896,30 S .'/1519.52' W' 931.59' S ...... 1592-60 W ' 966.13 S 1666.32 W 999,91 S 1740,67 W 1033,60 S 1815-61 W 1066-61 S 1890-58 W 1098-84 S 1965,34 W '1130,44 S 2040,36 W 1161,03 S 2115,81 W 1193,95 S 2189,82 W 1225,78 S 2264.02 W 1253.53 S 2340,02 w 1280.99 S 2415.98 W 1308.11 S 2491.79 w 1334.45 S 2567.46 W 1360.06 S 2643.10 W 1385.04 S 2718.96 W CLOSURES O I STANCE ANGLE D M 821.83 S 55 45 42 W 901.46 5 56 10 17 W 980,55 S 56 32 53 W 1059.24 S 56 54 4 W 1137,90 $ 57 14 22 W 1216.15 S 57 33 45 W 1293.98 S 57 52 26 W 1371.24 S 58 10 29 W 1448,30 S 58 29 10 W 1526.19 S 58 46 49 W 1604,96 S 59 1 44 W 1684.17 S 59 15 2 W 1764.17 S 59 27 55 W 1845.06 S 59 40 28 W 1926.15 S 59 53 41 W 2007.43 S 60 7 30 W 2089.20 S 60 20 51 W 2170.70 S 60 34 10 W 2251.67 S 60 47 23 W 2332,59 S 61 0 42 W 2413,43 S 61 14 40 W 2494,17 S 61 23 58 W 2574.56 S 61 34 5 W 2654,62 S 61 49 20 W 2734.57 S 62 4 0 W 2814.23 S 62 18 6 W 2893,55 S 62 32 11 W 2972.50 S 62 46 15 W 3051.41 S 63 0 20 W DCG LEG SEVERITY DEG/1OOFT 1.020 0.626 1.002 0.568 0.271 0.686 0.274 0.878 0.717 1.030 0.560 0.280 1,264 0.520 0.909 0.524 0.521 1.098 0.149 0.638 0.624 3,084 4.022 0,148 0.277 0.281 0.7O7 0,146 0-626 SECTION DISTANCE ~08.19 887.64 966.62 1045.26 1123.96 1202.30 1280.28 1357.75 1435.13 1513.35 1592.35 1671.74 1751.93 1833.04 1914.43 1996,09 2078.25 2160.16 2241.57 2322.97 2404.34 24~5,35 2646.81 2727.40 2807.71 2887.58 2967.13 3046,61 ARCO KUPARUK C-3 · GYROSCOPIC SURVEY JOB NO 4451 9 JAN 81 RECORD OF SURVEY TRUE MFAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 5400 52 30 3978.10 3884.10 571.15W 1410.09 S 2794.52 W 5c00 52 30 403B,98 3944,98 S72,55W 1434,80 S 2869,90 W / 3 52 15 4100.02 4006.02 S73.36W 1458.01S 2945.63 W 52 0 4161.42 4067.42 S73.56W 1480.48 S 3021.30 W 5800 51 45 4223.16 4129.16 573.75W 1502.61 $ 3096.79 W 5900 50 15 4286.09 4192.09 S71.10W 1526.07 S 3170.86 W 6000 50 0 4350.20 4256.20 S70.63W 1551.23 S 3243.37 W 6100 50 30 4414.14 4320.14 570.83W 1576.60 S 3315.95 W 6200 51 0 4477.41 4383.41 S70.41W 1602.29 S 3389.00 w 6300 50 0 4541.02 4447.02 S70.55W 1628.07 S 3461.73 W 3130.12 S 63 13 29 W 3208.58 S 63 26 14 W 3286.72 S 63 39 56 W 3364,53 $ 63 53 40 W 3442.08 S 64 6 59 W 3518.99 S 64 17 57 W 3595.24 $ 64 26 21 W 3671.67 S 64 34 14 W 3748.69 S 64 41 44 W 3825.46 S 64 48 43 W 6400 50 0 4605.30 4511,30 570,73W 1653.46"5 '-:j~3534,00 W .5901.68 S 64 55 35 W 6500 49 0 4670.24 4576.24 S70.85W 1678.48 $-: 3605.81 W- 3977.33 S 65 2 18 w 6600 49 0 4735.85 4641.85 S71.03W 1703.12 $ ~3677.14 w 4052.41 $ 65 8 53 W . 67.00 48 30 4801.78 4707.78 S71-18W 1727.46 S 3748.28 W 4127.19 S 65 15 23 w 6800 47 0 4869.02 4775.02 S68.51W 1752.96 S 3817.76 W 6900 46 30 4937,53 4843,53 S64.43W 1782,02 S 3884,53 W 7000 45 30 5007,00 4913,00 S64,43W 1813,07 S 3949.42 W 7100 44 15 5077.86 4983.86 S64.38w 1843.54 S 4013.05 W -' ~0 43 15 5150.10 5056.10 S64.38W 1873.44 S 4075.40 W h,~.dO 44 0 5222.49 5128.49 S66.18W 1902.29 S 4138.07 W 7400 43 15 5294.87 5200.87 S66,25W 1930.11 S 4201.21 W 7500 42 0 5368.45 5274.45 S68.53W 1956.14 S 4263.72 W 7600 42 0 5442,77 5348,77 S68,71W 1980.53 S 4326,03 W 7700 41 15 5517.52 5423.52 S69.58W 2004.17 S 4388.10 W 7800 44 0 5591.09 5497.09 S70.05W 2027.54 S 4451.66 W 7900 44 0 5663.02 5569.02 566.01W 2053.51 S 4516.07 W 8000 44 15 5734.80 5640.80 S66.98W 2081.28 S 4579.91 W 6100 45 0 5805.98 5711.98 S63.60W 2110.63 S 4643.72 W 8200 53 0 5871.53 5777.53 S65.88W 2142.81 S 4711.92 W 4200.97 S 65 20 14 w 4273.78 S 65 21 24 W 4345.70 S 65 20 29 W 4416,25 S 65 19 35 W 4485,39 S 65 18 43 W 4554,38 S 65 18 41 W 4623.36 S 65 19 30 W 4691.03 S 65 21 17 W 4757.84 S 65 24 3 W 4824.12 S 65 27 8 W 4891,64 S 65 30 46 W 4961.03 S 65 32 53 W 5030.64 S 65 33 40 W 5100.88 S 65 33 27 W 5176.27 S 65 32 44 W DOG LEG SEVERITY DEG/IOOFT 0.812 1.111 0.568 0.279 0.274 2.169 0.371 0.514 0.560 1.003 0,140 1.002 0.138 0.507 2.070 2.206 1.000 i.250 1.000 1.148 0.751 1.615 0.123 0.839 2.759 2.801 0.533 1.850 8.131 SECTION DISTANCE 3125.85 3204.80 3283.46 3361.76 ~439.77 35~7.02 3593.51 3670.15 3747.36 3824.31 3900.69 3976.49 4051.70 4126.61 4200.47 4273.29 4345.19 4415.71 4484.83 4553.81 4622.80 4690.50 4757,36 4823.69 4891,27 4960,69 5030.31 5100.54 5175.92 ARCO KUPARUK C-3 GYROSCOPIC SURVEY JOB NO 4451 9 JAN 8 1 RECORD OF SURVEY TRUE V. EAS. DRIFT VERTICAL DFPTH ANGLE DEPTH D ~4 SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES C L O S U R E $ DISTANCE ANGLE D M S DOG LEG SEVER I TY DEG/iOOFT 8300 54 0 5931,01 5837,01 S65,70W 2175.77 S 4785,~3 W 8~nO 55 30 5988.72 5894.72 S66,95W 2208.56 S 4860.02 W 6~0 54 0 6046,44 5952,44 S67,35W 2240,27 S 4935.27 W 53 15 6105.74 6011,74 S68.60W 2270,47 S 5009.91W 8700 52 0 6]66,44 6072,44 S69,13W 2299,12 S 5084.03 W 8800 51 30 6228,35 6134.35 S69,88W 2326,61S 5157.59 W 8900 50 0 6291,62 6197,62 S69,76W 2353,32 S 5230,28 W 9000 50 0 6355,90 6261,90 · S69.95W 2379,.69 S 5302.20 W 9100 49 30 6420,51 6326,51 S70,03W 2405.81S 5373.91W 9200 48 30 6486,12 6392,12 S70.O1w 2431.59 S 5444.84 W 9300 48 0 6552,71 6458,71 S70,10W 2457,04 S 5514,98 W 9400 47 49 6619.73 6525,73 S70,26W 2482.20 S 5584,80 W 9500 48 0 6686,75 6592,75 S71,18W 2506,69 S 5654.85 W 5256.66 S 65 32 57 W 5338,31S 65 33 40 W 5419.94 S 65 35 6 W 5500,38 S 65 37 12 W 5579,72 S 65 39 58 W 5658.08 S 65 43 10 W 57~5.32 S 65 46 30 W 5811,73 S 65 49 43 W 5887.86 S 65 52 57 W 5963,13 S 65 56 6 W 6037,55 S 65 59 9 w 6111,57 S 66 2 13 w 6185,54 S 66 5 35 W 9600 48 0 6753.66 6659,66 S71,36W 2530.55 S 5725,24 W -: 6259.56 S 66 9 16 W 9620 48 0 6767,04 6673.04 S71,55W 2535,28 S 5739,33 W 6274.35 S 66 10 1 W 1,007 1,724 1.523 1,098 1,293 0.679 1,502 0,140 0,502 1.000 0.502 0.190 0,533 0,136 0,681 THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD · LO 48 0 6820.57 6726,57 S71,55W 2554,09 S 5795,72 W BOTTOM HOLE CLOSURE 6333.55 FEET AT S 66 13 3 W 6333,55 S 66 13 3 W 0,000 SECT IOt'; DISTANCE 5256.30 5337.96 5419.61 5500.08 5657.87 575~.15 5811.60 5887.76 5963,06 6037,50 6111.54 6185.53 6259,55 6274.35 6333.55 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE M~ASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES C L O S U R E DISTANCE ANGLE D M S SUB SEA T KUPARUK 9062 6395,88 T UP SAND 9100 6420,51 B UP SAND 9142 6447,91 T LOW SAND 9441 6647,24 B LOW SAND 9516 6697,45 ~~. PARUK 9590 6746,97 PL~ BACK 9589 6746,30 TD 9700 6820,57 2396,44 S 2405.81S 2416.70 S 2492.49 S 2510,57 S 2528,47 S 2528,23 S 2554.09 S 5346,53 W 5373,91W 540S,83 W 5613,40 W 5666,10 W 5718,09 W 5717,39 W 5795,72 W 5859,03 S 65 51 25 W 6301,88 5887.86 S 65 52 57 W 6326,51 5919,61 S 65 54 17 w 6353,91 6141.89 S 66 3 27 w 6553.24 6197,39 S 66 6 9 w 6603,45 6252,18 S 66 8 44 W 6652,97 6251,44 S 66 8 41 W 6652,30 6333,55 S 66 13 3 W 6726,57 O KUPARUK C-3 SURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4451 FEET OF SUB SEA DEPTH. JAN 81 TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA MD-TVD DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 194 194, 100 294 294, 200 394 394, 300 494 494, 400 594 594, 500 '4 694, 600 :~','f5 794, 700 896 894, 800 997 994, 900 110O 1094, 1000 1205 1194, 1100 1311 1294, 1200 1419 1394, 1300 1530 1494, 1400 .1643 1594, 1500 1753 1694. 1600 1369 1794. 1700 1992 1394, 1800 2125 1994. 1900 2267 2094. 2000 2421 2194. 2100 '2587 2294. 2200 21 2394, 2300 2~1~ 2494, 2400 3074 2594, 2500 3233 2694. 2600 3393 2794. 2700 3556 2894. 2800 3723 2994, 2900 3895 3094. 3000 4069 3194. 3100 4243 3294. 3200 4416. 3394. 3300 ~587 3494. 3400 ~757 3594, 3500 0 0 0 0 0 0 0 1 3 6 10 16 25 36 49 58 75 98 131 173 227 293 356 420 48O 598 662 80.t 8'7.5 9.49 1022 1093 1163 0 0 0 0 0 0 0 1 2 6 . ~' 9 IT 23 33 42 54 66 63 64 6O 59 59 64 74 73 71 7O 0.00 0.00 0.00 0,00 1,07 5.01 12.10 22.81 35.62 51,15 69,44 90.48 115,63 215.:--':¥:':148,63 .'~"182.10 208.53 240.42 277.68 320,94 371,20 431,04 497.13 560.47 621.02 679,47 734,60 'ibb'0 '84 1135,51 1189.92 1242,09 0.00 0,00 0.00 0.00 1.08 4.16 10.81 20.06 32.80 51,02 75,47 104,62 136,97 172.87 211.84 249.90 299.77 360.88 437.~0 524,20 625,04 739.58 853.05 966.45 1077.48 1187,84 i299.96 i~i5~76 19'22.56 2052,36 2180,~4 2307,15 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 C-3 GYROSCOPIC SURVEY :4gASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 JOB NO 4451 FEET OF .SUB SEA DEPTH. 9 JAN 81 MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 4927 3694. 5094 3794, 5260 3894. 5426 3994. 5590 4094. 5753 4194, 5912 4294, 6068 4394. 6226 4494, 6382 4594. 6536 4694. 6688 4794. 6836 4894. 6981 4994, 7122 5094, 7260 5194, 7399 5294, 7534 5394, 7668 5494. 7804 5594, 7943 5694, 8083 5794, 8237 5894. 8409 5994. 8580 6094. 8744 6194. 8903 6294, 9059 6394. 9212 6494. 9361 6594, 9511 6694. 9660 6794, 3600 1233 3700 1300 3800 1366 3900 1432 4000 1496 4100 1559 4200 1618 4300 1674 4400 1732 4500 1788 4600 1842 4700 1894 4800 1942 4900 1987 5000 2028 5100 2066 5200 2105 5300 2140 5400 2174 5500 2210 5600 2249 5700 2289 5800 2343 5900 2415 6000 2486 6100 2550 6200 2609 6300 2665 6400 2718 6500 2767 6600 2817 6700 2866 70 67 66 66 64 63 59 56 58 :': 52 48 45 ,..- , -. 39 35 34 36 39 40 54 72 71 64 59 56 53 49 50 49 1288.41 1333.29 1375.42 1416.76 1456.30 1492,64 1529.09 1569,09 1609.19 1649.55 1687.69 1724.67 1763.12 1807.61 ..:~i 18 50 · 26 1891.14 '1930.01 1964.67 1997.24 2028.49 2065.68 2106.12 2155.33 2211,57 2265.05 2311.52 2354.14 2395.66 2434.63 2472,53 2509.31 2544.96 2436,3.6 W 2562,79 W 2688.49 W 2814,03 W 2937.88 W 3061,08 W 3179,58 W 3292.44 w 3407,95 W 3520.76 W 3631.37 w 3739.73 W 3842,01 W 3936,98 W 4026.82 W 4112,70 W 4200.35 W 4284,81 W 4368,11 W 4454.27 W 4543,38 W 4632 · 59 W 4738,?6 W 4866,79 W 4994.79 W 5116.35 W 5232.42 W 5344.44 W 5453.20 W 5557,54 W 5662.46 W 5767,43 W TO KUPA~UK C-3 ERPOLATED VALUES MEASURED DEPTH 1000 2000 3000 4000 5O0O 8000 ~000 ~"--~ooo 9000 GYROSCOPIC SURVEY JOB NO 4451 FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE VERTICAL SUB DEPTH SEA TOTAL COORDINATES 996. 902. 36.06 S 33,23 W 1899. 1805. 280.20 S 365.19 W 2547. 2453. 653.22 S 1025.92 W 3154. 3060. 1000.65 S 1740.33 W 3737, 3643, 1308.53 S 2491.64 W 4350. 4256. 1551.69 S 3243,21W 5007. 4913. 1813.56 S 3949.18 W 5734. 5640. 2081.83 S 4579.67 W 6355. 6261. 2380.77 S 5301.79 W .9 JAN 81 ~ "HORIZONTAL VIEW ARCO OIL 6 GAS KUPARUK RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' ..JAN. 12~ 1981 .. . T II N~ R I0 E , U.M. 12 ALL DEPTHS SHOWN ARE TVD 400' 800' SURFACE LOCATION IS 158:5' SNL~ 1165' EWL~ SEC. 12 T II Ny R I0 E~ U.M VERTICAL SECTION ARCO OIL & (}AS KUPARUK C-$ RADIUS OF CURVATURE (}YROSCOPIC SURVEY SCALE I" = I000' _JAN. 12~ 1981 .. .............................................. TVD = 6821' TM D = 97'00 ' ALL DEPTHS SHOWN ARE TVD 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 World Leader in Service to the Oil Industry December 29, 1980 Job #4451 North Slope Drilling- Enclosed please find our Gyro Survey o~_a~r~uk~,~X~ along with our Vertical Section and Horizontal ?iew maps. Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call 272-2496. Thank you for using Scientific Drilling International and please call again. Sincerely Manager RECeiVED FEEl - ~ ]~! Rlasl{a Oil & Gas Cons. Anchorage COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE NETHOD OF COHPUTATION COHPUTED FOR SDC BY FM LINDSEY & ASSOC 9 JAN 81 KUPARUK .~_-~~ .__' ¢-~K-~B ELEV- 94. Ff.]'_> JOB NO 4451 TRUE MEAS, DRIFT VERTICAL DEP ' ANGLE DEPTH RECORD OF SURVEY SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 0 0 0 0.00 100 0 0 100.00 200 0 0 200.00 30O 0 0 300.00 400 0 0 400,00 500 0 0 500.00 600 2 0 599.97 700 4 0 699.83 8,00 7 30 799,31 900 8 45 B98.31 1000 12 0 996.66 1100 15 0 1093.89 -94.00 N O.OOE 6.00 S59,43w 106.00 S59.61w 206.00 S59,80W 306,00 S59,98W 406.00 S60.16w 505,97 S29.38W 605.83 S48.58w 705.31 S37.91W 804.31 S44.10W 902,66 S45,43W 999.89 S53.55W 1200 I8 45 1189.56 i095.56 S52.95W l~nO 20 30 12~3.75 1189.75 s55.1ow ! ) 23 15 1376.54 1282,54 $50.80W 1~'~ 27 15 1466,97 1372,97 S45.91W 1600 27 30 1555.77 1461.77 S49.75W 1700 23 15 1646,10 1552.10 S55.96W 1800 30 45 1735.14 1641,14 S57.61W 1900 3a 0 1819.58 1725.58 S57.90W 2000 39 0 1899.94 1805.94 S60.O1W 2100 43 0 1975.40 1881.40 S60.41W 2200 45 0 2047.33 1953.33 S60.O1W 2300 47 45 2116,32 2022.32 S59.05W 2400 52 0 2180.75 2086.75 S59.68W 0.00 5 0.00 W 0.00 S 0.00 W 0.00 5 0.00 W 0.00 5 0.00 W O,OO $ 0.00 w 0.00 S O.00 w 1,22 S 1,21W 5,27 S 4.49 W 12.55 S 11,34 W 23.21 S 20.61W 36.00 S 33,29 W 51.15 S 51.02 W 68,51S 74.28 W 88.24 S 101.45 W 110,68 S 131.18 W 139,01S 163.04 W 169.87 S 197.12 W 195.73 S 231,25 W 220.57 S 269.21W 249.14 S 314,49 W~ 279.80 S 365.44 W 312.38 S 422.37 W 346,88 S 482,65 W 383.58 S 545,04 W 422.53 S 610.82 W CLOSURES DISTANCE ANGLE D M S 0.00 S 0 0 0 W 0.00 S 0 0 0 W O,CO S 0 0 0 W 0.00 S 0 0 0 W 0.00 5 0 0 0 W 0.00 S 0 0 0 W 1,72 S 44 46 30 W 6.92 S 40 25 21 W 16.92 S 42 5 35 W 31.04 S 41 35 58 W ~:9.03 S 42 45 43 W 72.25 S 44 55 47 W 101.05 S 47 18 42 W 134.46 S 48 59 5 W 171.64 S 49 50 40 W 214,26 S 49 32 55 w 260.22 S 49 14 44 w 302.97 S 49 45 21 w 348.03 S 50 40 15 W 401.22 S 51 36 51 W 460.25 S 52 33 37 W 525.33 S 53 30 48 W 594.38 S 54 17 42 W 666.49 S 54 51 47 w 74~.72 $ 55 19 34 w DOG LEG SEVERITY DEG/iOOFT 0.000 0.000 0.000 0.000 0.000 0,000 2.000 2.OO2 3.505 1.258 3.251 3.049 3.751 1.770 2.830 4.129 0.855 q,359 7.512 3.251 5.070 4,004 2.010 2.801 4,268 SECTION DISTANCE 0.00 O.O0 0.00 0.00 0.00 0.00 1.60 6.23 15.44 28.22 44.98 67.32 95,60 128,42 164,68 205,26 248,8~ 290.55 335.30 388.26 447.24 512.47 581.55 653.44 729.34 ARCO KUPARUK C-3 GYROSCOPIC SURVEY JOB NO 4451 9 JAN 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 2500 53 0 2241.62 2147,62 S60mOOW 2600 53 0 2301.80 2207.80 S60,78W 27 ' 52 0 2362,68 2268,68 S60,88W 2~ 52 15 2424,07 2330,07 S61,70W 2900 52 0 2485,47 2391,47 561,86W 3000 51 30 2547,38 2453,38 S62,63W 3100 51 15 2609,80 2515,80 $62,81W 3200 50 30 2672,90 2578,90 S63,58W 3300 51 0 2736.17 2642,17 564,43W 462,39 S 679.41 W 501.85 S 748.85 W 540.51 S 818,12 W 578.43 S 887,35 W 615.75 S '95~.91 W 652.31S 1026.41W 688.12 S 1095.85 W 723.09 S 1165-09 W 757.03 S 1234,70 W 3400 52 0 2798.42 2704.42 S64.03W- 791.05 S 1305.17 W 3500 52 30 2859.64 2765.64 S63.63W 3600 52 45 2920,35 2826.35 563,83W 3700 54 0 2980.00 2886,00 S64,11W 3800 54 30 3038,43 2944,43 S64.33W 3900 5a 30 3096,50 3002,50 S65,45W 4000 55 0 3154.21 3060.21 S65.68W 825.92 5 1376.14 W 861.09 S 1447.40 W 896.30 5 1519.52 W 931,59 S 1592,60 W 966.13 S 1666,32 W 999.91 S 1740.67 W 4100 55 30 3211-21 3117.21 S65,90W 1033-60 S 1815-61 W 4200 s4 s zs o. s w 4 o0 o s.s4 s w s4 290.= s w 4= . 45~ 54 30 3442.78 3348.78 S68-31W 1161.03 S 2115.81W 4600 53 45 3501.38 3407,38 S63.71W 1193,95 S 2189,82 W 4700 54 0 3560,3S 3466,33 S69,85W 1225-78 S 2264,02 W 4800 54 0 3619.11 3525.11 S70,03W 1253-53 S 2340,02 W 4900 53 45 3678.07 3584,07 S70,21W 1280,99 S 2415.98 W 5000 53 30 3737,37 3643.37 570,41W 1308.11S 2491.79 W 5100 53 0 3797.21 3703.21 $71.20W 1334.45 S 2567.46 W 5200 53 0 3857.39 3763.39 S71.38W 1360.06 S 2643.10 W 5300 53 0 3917.57 3823.57 S72.16W 1385.04 S 2718.96 W CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT 821.83 S 55 45 42 W 901.46 S 56 10 17 W 980.55 S 56 32 53 W 1059.24 S 56 54 4 W 1137,90 S 57 14 22 W 1216,15 S 57 33 45 W 1293.98 S 57 52 26 W 13'71,24 S 58 10 29 W 1448,30 S 58 29 10 W 1526.19 S 58 46 49 W 1604.96 S 59 1 44 W 1684,17 S 59 15 2 W 1764,17 S 59 27 55 W 1845.06 S 59 40 28 W 1926.15 S 59 53 41 W 2007,43 S 60 7 30 W 2089.20 S 60 20 51 W 2170.70 S 60 34 10 W 2251.67 S 60 47 23 W 2332,59 S 61 0 42 W 2413.43 S 61 14 40 W 2494,17 S 61 23 58 W 2574.56 S 61 34 5 W 2654.62 S 61 49 20 W 2734.57 S 62 4 0 W 2814.28 S 62 18 6 W 2893.55 S 62 32 11 W 2972,50 S 62 46 15 W 3051.41 S 63 0 20 W 1.020 0.626 1-002 0.568 0.271 0.680 0.274 0.878 0,717 1.030 0.560 0.280 1.264 0.520 0.909 0.524 0.521 1.098 0.149 0.638 0.624 3,084 4.022 0,148 0.277 0.281 0,707 0.146 0.626 SECTION DISTANCE 808.19 887.64 966.62 1045.26 1123.96 1202.30 1280.28 1357.75 1513.35 1592.35 1671.74 1751,93 1833.04 1914.43 1996,09 2078.25 2160.16 2241e57 2322.97 2404.34 2465.35 2566.08 2646.81 2727,40 2807.71 2887.5~ 2967.13 3046.61 ARCO KUPARUK C-3 GYROSCOPIC SURVEY JOB NO 4451 9 JAN 81 RECORD OF SURVEY MFAS. DRIFT DEPTH ANGLE D M 5400 52 30 5500 52 30 5~ '~ 52 15 52 o 5800 51 45 5900 5O 15 6000 50 0 6100 50 30 6200 51 0 6300 50 0 6400 50 0 6500 49 0 6600 49 0 6100 48 30 6800 47 0 6900 46 30 7000 45 30 7100 44 15 7200 43 15 7 ) 44 0 7~"~'0 43 15 7500 42 0 7600 42 0 7700 41 15 7800 44 0 7900 44 0 8000 44 15 8100 45 0 8200 53 0 TRUE VERTICAL DEPTH 3978.10 4038.98 4100.02 4161.42 4223.16 4286.09 4350,20 4414.14 4477,41 4541,02 4605.30 4670,24 4735,85 4801.78 4869.02 4937,53 5007.00 5077,86 5150.10 5222,49 5294.87 5368,45 5442.77 5517.52 5591.09 5663.02 5734.80 5805.98 5871.53 SUB SEA 3884,10 3944,98 4006.02 4067.42 4129.16 4192.09 4256,20 4320,14 4383.41 4447,02 4511.30 4576.24 4641,85 4707,78 4775-02 a843.53 4913.oo 4983e86 5056,10 5128.49 5200,87 5274,45 5348,77 5423,52 5497.09 5569,02 5640,80 5711.98 5777,53 DRIFT DIREC DEG. S71. S72. S73. S73. S73. S71. S70. S70. S70, S70, S70. S70. 571- S71. S68. S64, S64, S64. S64. S66. S66, S68. S68. S69, 570. S66. S66. S63. 565, TOTAL COORDINATES C L 0 S U R DISTANCE A D 15W 1410.09 S 2794.52 W 55W 1434.80 S 2869.90 W 36W 1458.01 S 2945.63 W 56W 1480,48 S 3021.30 W 75W , 1502,61 S 3096.79 W 10W 1526,07 S 3170,86 W 63W 1551,23 S 3243,37 W 83W 1576,60 S 3315.95 W 41W 1602.29 S 3389.00 W 55W 1628,07 S 3461.73 W 3130.i2 S 63 3208.58 S 63 3286,72 S 63 3364.53 S 63 3442,08 S 64 3518.99 S 64 3595.24 S 64 3671.67 S 64 3748.69 S 64 3825.46 S 64 73W 85W 03W 18W 51W 43W 43W 38W 38W 18W 25W 53W 71W 58W 05W OlW 98W 60W 88W 1653.46 S 3534.00 W 3901.68 3605,81 ~ 3977.33 1678.4.8 S 4 ~ · 40 . 1703.1'2 $ :3677~1 52 41 1727.46 S 3748~-28'WI' ~127.19 1752.96 S 3817.76 W 4200.97 1782.02 S 3884.53 W 4273.78 1813,07 S 3949.42 W 4345.70 1843.54 S 4013.05 W 4416.25 1873,44 S 4075,40 W 4485,39 1902.29 S 4138.07 W 4554.38 1930.11 $ 4201.21W 4623.36 S 64 S 65 S 65 S 65 S 65 S 65 S 65 $ 65 S 65 S 65 S 65 1956.14 S 4263.72 w 4691.03 S 65 1980.53 S 4326.03 W 4757.84 S 65 2004.17 S 4388.10 W 4824.12 S 65 2027,54 S 4451,66 W 4891.64 S 65 2053-51 S 4516,07 W 4961.03 S 65 208I,28 S 4579,91 W 5030,64 S 65 2110.63 S 4643.72 W 5100.88 $ 65 2142.81 S 4711.92 W 5176.27 S 65 E S NGLE M S 13 29 W 26 14 W 39 56 W 53 4O W 6 59 W 17 57 W 2621 w 34 14 W 41 44 W 48 43 W 55 35 W 2 18 w 8 53 W 15 23 w 20 14 w 21 24 w 20 29 W 19 35 w 18 ~+3 W 18 ~+1 W 19 30 w 21 .17 W 24 3 W 27 8 W 30 46 W 32 53 W 33 40 'w 33 27 W 32 44 W DOG LEG SEVERITY DEG/1OOFT 0.812 1.111 0,568 0.279 0.274 2.169 0.371 0,514 0.560 1,003 0,140 1.002 0.138 0.507 2.070 2,206 1.000 1.250 1.000 1.148 0.751 1.615 0.123 0,839 2.759 2.801 0.533 1.850 8.131 SECTION DISTANCE 3125.85 3204.80 3283.46 3361.76 3439.77 3917.02 3593.51 3670.15 3747,36 3824.31 3900,69 3976,49 4051,70 4126.61 4200.47 4273.29 4345.19 4~15.71 4484.83 4553.81 4622.80 4690.50 4757,36 4823.69 4891.27 4960.69 5030.31 5100.54 5175.92 ~RCO KUPARUK GYROSCOPIC SURVEY JOB NO 4451 9 JAN 81 RECORD OF SURVEY TRUE qEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 8300 54 0 5931.01 5837.01 S65.70W 2175.77 S 4785,23 w 8400 55 30 5988.72 5894.72 S66.95W 2208.56 S 4860.02 W 8~ 54 0 6046.44 5952.44 S67.35W 2240.27 S 4935.27 W 36~ 53 15 6105.74 6011.74 S68.60W 2270.47 S 5009.91W 8700 52 0 6166.44 6072.44 S69.13W 2299.12 S 5084.03 W 8800 51 30 6228.35 6134.35 S69,88W 2326.61S 5157.59 W 8900 50 0 6291,62 6197.62 S69,76W 2353.32 S 5230,28 W 9000 50 0 6355.90 6261.90 S69.95W 2379.69 S 5302.20 W 9100 49 30 6420.51 6326.51 S70,03W 2405.81S 5373.91W 9200 48 30 6486,12 6392,12 S70.O1w 2431.59 S 5444.84 ~ 9300 48 0 6552.71 6458,71 STO.IOW 2457.04 S 5514.98 W 9400 47 49 6619.73 6525,73 S70.26w 2482.20 S 5584,80 W 9500 48 0 6686.75 6592.75 S71.18W 2506.69 S 5654.85 w 9600 48 0 6753.66 6659,66 S71.3bW 2530.55 S 5725.24 W 9620 48 0 6767.04 6673.04 S71,55W 2535.28 S 5739.33 W THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD / 9~0 48 0 6820,57 6726,57 S71-55W 2554-09 S 5795,72 W BOTTOM HOLE CLOSURE 6333.55 FEET AT S 66 13 3 W CLOSURES DISTANCE ANGLE D M S 5256.66 S 65 32 57 W 5338.31 S 65 33 40 W 5419.94 S 65 35 6 W 5500.38 S 65 37 12 W 5579.72 S 65 39 58 W 5658.08 $ 65 43 10 W 5735.32 S 65 46 30 W 5811.73 S 65 49 43 W 5887.86 S 65 52 57 W 5963,13 $ 65 56 6 W 6037.55 S 65 59 9 w 6111.57 S 66 2 13 W 6185.54 S 66 5 35 W 6259.56 S 66 B 16 W 6274.35 S 66 10 1W 6333,55 S 66 13 3 W DOG LEG SEVERITY DEG/IOOFT 1.007 1.724 1.523 1.098 1.293 0.679 1.502 0.140 0.502 1,000 0.502 0,190 0.533 0.136 0.681 0.000 SECTION DISTANCE 5256.30 5337.96 5419.61 5500.08 5579.47 5657.87 5735.15 5811.60 5887.76 5963.06 6037.50 6111.54 6185.53 6259.55 ~274.35 6333.55 INTERPOLATED TROE VERTICAL DEPTHS, COORD.~NATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH T KUPARUK 9062 6395.88 T UP SAND 9100 6420.51 B UP SAND 9142 6447.91 T LOW SAND 9441 6647.24 B LOw SAND 9516 6697,45 D ' ~ARLJK 9590 6746.97 PL~BACK 9589 6?46.30 TD 9700 6820.57 TOTAL COORDINATES 2396.44 S ~-'- 5346,53 Jw 2405,81 S 5373,9i~-W 2416,70 S 5.403,83~W 2492.49 S ~:~~5613.40~ W 251o.57 s 5666.~0 w 2528.23 S 571~ C L 0 S U R E.. '-'~ SUB DISTANCE ANGL£. ~ SEA D i,~ .S, . 5859,03 S 65 51 25 W 6301.88 5887,86 S 65 52 ~ W 6326,51 6~ · ~919.61 S 65 54 17 w 6353.91 6141.89 S 66 3 27 ~V,' 655~.2~+ ~ ~'~ 6197."39 S 66 6 9 W 6603.45 "' 6252,18 S 66 8 44 W 6652.97 6251-:S,44 S 66 8 41 W 6652.30 6333~:'55 S 66 13 3 W 6726.57 ARCO KUPARUK · ".,lEA SURE D DEPTH C-3 GYROSCOPIC AND OTHER DATA FOR EVERY SURVEY EVEN 100 JOB NO 4451 FEET OF SUB SEA DEPTH. 9 JAN 8i MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 194 194. 294 294. 394 394. 494 494. 594 594. 694 694. 795 794. 896 894. 997 994, 1100 1094. 1205 1194. 1311 1294. 1419 1394, 1530 1494. 1643 1594. 1753 1694. 1869 1794. 1992 1894. 2125 1994. 2267 2094. 2421 2194. .-2587 2294. 2751 2394. 2914 2494. 3074 2594. 3233 2694, 3393 2794. 3556 2894. 3723 2994. 3895 3094. 4069 3194. 4243 3294. 4416 3394. 4587 3494. 4757 3594. 100 0 200 0 300 0 400 0 500 0 600 0 700 0 800 1 900 3 1000 6 1100 10 1200 16 1300 25 1400 36 1500 49 1600 58 1700 75 1800 98 1900 131 2000 173 2100 227 2200 293 2300 356 2400 420 2500 480 2600 539 2700 598 2800 662 2900 729 3000 801 3100 875 3200 949 3300 1022 3400 1093 3500 1163 0 0 0 0 0 0 0 1 2 3 4 6 9 11 13 9 17 23 33 42 54 66 63 64 60 59 59 64 67 72 74 74 73 71 70 0.00 0.00 0.00 0.00 1.07 5.01 12.10 22.81 35.62 51.15 69.44 90.48 115.63 148.63 182.10 208.53 240.42 277.68 320.94 371.20 431.04 497.13 560.47 621,02 679,47 734.60 788,86 846,11 904.46 964.91 1023.85 1080.84 1135.51 1189.92 1242.09 0.00 0.00 0.00 0.00 1.08 4.16 10.81 20,06 32,80 51.02 75.47 104.62 t36.97 172.87 211.84 249.90 299.77 360.88 437.20 524.20 625.04 739.58 853.05 966.45 1077.48 1187.84 1299.96 1415.76 1536.25 1662.39 1792.00 1922.56 2052.36 2180.14 2307.15 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 W ARCO KUPARUK C-3 '49Z }' 30"J 4 · MEASURED"DEPTH AND~OY. HF~R GYROSCOPIC SURVEY JOB NO 4451 3600 1233 /0 AZU~,41S DA?A.-'~FOR-,EVERY EVEN 1007FEET OF SUB]SEA.DEPTH. 9 2436,36 W JAN 81 TRUE MEASURED VERTICAL DEPTH DEPTH SUB MD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4927 3694. 5094 3794. 5260 3894. 5426 3994. 5590 4094. 5753 4194. 5912 4294. 6068 4394. 6226 4494. 6382 4594, 6536 4694. 6688 4794. 6836 4894. 6981 4994. 7122 5094, 7260 5194, 7399 5294, 7534 5394, 7668 5494. 7804 5594. 7943 5694. 8083 5794, 8237 5894. 8409 5994. 8580 6094. 8744 6194. 8903 6294. 9059 6394. 9212 6494. 9361 6594. 9511 6694. 9660 6794. 3600 3700 3800 3900 4000 4100 4200 4300 4400.' 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 1233 1300 1366 1432 1496 1559 1618 1674 1732 1788 1842 .1894 1942 1987 2028 2066' 2!:05 21:40 21:74 221-0 2249 2289 2343 2415 2486 2550 2609 2665 2.718 .. , i276~ 28i7 2866 70 67 66 66 64 63 59 56 58 56 54 52 48 45 39 . 39 40 72 71 59 3:~ . ~: 49 1288.41S 1333.29 S 1375.42 S 1416.76 S 1456.30 S 1492.64 S 1529.09 S 1569.09 $ 1609.19 $ 1649.55 S 1687.69 S 1724.67 S 1763.12 S i'- 1807.61 $ 1850-26 S 1891.14 S ~?~v'-1930.01 S 1964.67 $ 199.7.24 S 2028.49 S 2065.68 S 2106.12 S 2155.33 S 2211.57 S 2265.05 S 2311.52 S 2354.14 S 2395.66 S ~,!':2~34.63 :S - 2509,31S ~ 2544.96 S 2436,36 W 2562,79 W 2688,49 W 2814,03 w 2937.88 W 3061,08 W 3179,58 W 3292.44 w 3407.95 W 3520.76 W 3631.37 w 3739.73 W 3842.01 W 3936.98 W 4026.82 W 4112.70 W 4200.35 W 4284.81W 4368.11 W 4454.27 W 4543.38 W 4632.59 W 4738,76 W 4866.79 W 4994.79 W 5116,35 W 5232.42 W 5344.44 W 5453.20 W 5557,54 W 5662,46 W 5767.43 W ARCO KUPARUK C-B GYROSCOPIC SURVEY JOB NO · INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 996. 902. 36.06 S 33. 2000 1899, 1805, 280.20 S 365, 3000 2547. 2453. 653.22 S 1025. 4000 3154, 3060, 1000.65 S 1740. 5000 3737, 3643, 1308,53 S 2491, 6000 4350. 4256. 1551.69 S 3243. 7000 5007, 4913. 1813.56 S 3949, BO00 5734. 5640. 2081.83 S 4579. 9000 6355. 6261. 2380.77 S 5301. 23 W 19 W 92 W 33 W 64 W 21 W 18 W 67 W 79 W 4451 JAN 81 HORIZONTAL VIEW ARCO OIL 8~ GAS KUPARUK C-5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' ,JAN. 12~ 1981 T I! N~ R I0 E ~ U.M. !165' 2, 12, TVD = 682 I' ~ -- TMD= 9700' · e °° "~ ALL DEPTHS SHOWN ARE TVD 400' SURFACE LOCATION IS 1585' SNL~ 1165' EWL~ SEC. 12: T IIN~ R I0 E~ U.M VERTICAL SECTION ARCO OIL & GAS KUPARUK C-$ RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' dAN. 12:~ 1981 6 . TVD = 6821' T M D = 9700 ALL DEPTHS SHOWN ARE TVD sUggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~perator, Well Name and Number and Materials to be received by: /--30 Reports Date Required Date Received Remarks Comp lotion Report Yes Wel 1 .History Yes' ................ .... _Samples _--. ........ D,,o ...... ,,.., Core Description ' ~"~ o ?-I ~ , Register~ ~ey Plat ~ e 3 - . , ......... , !~cl~ation Su~ey -- ~ ........ ~.~.,~.~ ~~ ' Drill St~ Test Re. ms ~ 0,,~ ~ ~u~on T~t Re~s /~/~-7 / Digitiz~ ~ta ~ DATE: 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 SEPIA I~I~?/Fs~)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 Mul ti-shot Drill Stem Test - Test No. Dual Induction Laterolog-31~(- 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 Ca, grbon-O~yge~Log RECEIPT ACKNOWLEDGED FOR: J ' DATE' ~LEASE RETURN RECEIPT TO' RECE ¥ED JAN 1 9 1 81 BL LINE ! I FILM Alaska Oil& GasCons. Commission Anchorage ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Jerry J. Pawelek/Leo Lash WELL NAME' ~l~t)~P_~ ~-----.".~ Transmitted herewith are the following for the subject well · DATE ~I'~/~BHC Sonic/Gamma Ray t6g ~Cement Bond Log/VDL l~/&~ _ Compensated Formation Density Log ~ Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Co re 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 Ca.j~bon-O~yge~Log RECEIPT ACKNOWLEDGED FOR' SCALE XEROX BL SEPIA LINE D___ , __k__ I FILM DATE' PLEASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL// TO' m ~ ~/~,tA ~L(/~ FROM' Jerry J. Pawelek/Leo Lash m~ted herewith are the follo~n~ for the subject ~ell' BL DATE · SCALE XEROX SEPIA LINE BHc~I~,/ 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 Mul ti -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 ~yto ~orr-l~'~,o~, Perforating Record Neutron Lifetime Log Carbon-Oxygen Log / / I ~ENC~ ~ I STAr'r[e I STAT TEC I CONFER: i.FILF: _ _ FILM D l: g' r. l tl E rt RECEIPT ACKNOWLEDGED FOR: DATE: JAN 1 5 Alaska Oil & Gas Cons. Commission PLEASE RETURN RECEIPT TO: ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL TO' FROM' Jerry J. DATE' ~'~V~ ~/~, I d~'l WELL NAME' ~}~2~W-~ · /~~ransmitted herewith are the following for the subject well' Pawel ek/Leo Lash .. DATE SCALE XEROX SEP IA 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 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 ~X~ ~Q~r~t~-,~w Perforating Record Neutron Lifetime Log. Carbon-Oxygen Log / RECEIPT ACKNOWLEDGED FOR: DATE' PLEASE RETURN RECEIPT TO' RE£EIVED JAN 1 5 1961 Alaska Oil & Get, ConS. Anchorage ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman Commissioner Bobby Foster it?~~- t . Petroleum Inspector December 22, 1980 Witness BOPE Test on ARCO'S C-3, Sec. 11, TllN, R10E, UM Permit #80-138. Tuesday December 16, 1980: I traveled from Sohio's R-7 after witneSsing a BOPE test to ARCO'S C-3 to witness the upcoming BOPE test. The test began at 9:00 am and was completed at 2:00 pm. As the attached BOPE report shows there was one failure which was the upper pipe rams. These were repaired and retested. In summary, i witnessed the BOPE test on ARCO'S C-3. Note: When witnessing the BOPE test I noticed gas bubbles in the cellar. I talked, with Orvin Graff, Rowan tool pusher concerning this. He said that the bubbles began after the 10 3/4" surface had been set and cemented. I also spoke with Ken Jones, Arco drilling foreman, and he said the bubbles were occuring in the wells where the 20" conductor pipe had been cemented with ready mix Cement. He said so far the wells cemented with pump trucks showed no signs of gas bubbles. BF:mm ~ 0&G ~4 4/so STATE OF ALASKA ALAS~A OIL & GAS CONSERVATION CO~,!MISSION B.O.P.E. Ins~>cction Report Inspector Operator Well : - 3' -- Location: Sec / / T/~/R / Drilling Contractor ~~~/ Rig #~/' 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 Test Pressure Test Results: Failures Date /~'~ --/' , / Representative £f,z3_ ~..j ,~..,'~ ~_- Permit # ~O /~5 /~ :~'Caslng Set ~ /~ ft. Representat iv~~/~ ACCUMU~TOR SYSTEM Full Charge Pressur~~DO t>sig Pressure After Closure /~0 psig . 200 psig Above Precharge Attained: ~m~'o s~ Full Charge Pressure Attained: t~ min~s~ Controls: Master ~ ~ / ~__Remote~~ Blinds switch cover~ Kelly and Floor Safety Valves Upper Kelly .... / Test Pressure Lower Kelly / Test .Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ~ Test Pressure~Qmo No. Valves No. flanges ..... ~ ~' Cho~es ~'arau~caZZ~ operated choke .. ~ ~-:~J ~' ~-~s ...... R&pai'r or Replacement of failed equipment to be made within --- days and Inspector/Commission office notified. Distribution orig. - AC&GCC ~. ~: ~ >/I cc - Operator "~ ,/: ~..~ cc - Supervisor Ins ?' . ~ /~:/ December 1, 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Kuparuk 25649 C-3 Atlantic Richfield Company Permit No. 80-138 Sur~ Loc.~ 1583~FNL, 1165tFWL, Sec 12, TllN, R10E, UM. Bottomhole Loc.= 1320~FSL, 1320~FWL, Sec 11, TllN, R10E, Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classifie~ as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 anO the regulations promulgate~ thereunder' (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish an~ Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) an~ by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25649 -2- December 1, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Locai Hire Under State Leases,. the Alaska Department of Labor is being notified of the issuance of this permit to dril'l. To aid us in scheduling field work, we would appreciateyour notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the co~mission may be present to witness testing of blowout preventer equipment before ~rface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Lonnie C. { Smith BY ORDER OF THE CO~MISSION Commissioner of Alaska Oil & Gas Conservation Commission Enclosure cc.. Department of Fish & Game,-Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o eric1. ARCO Oil and Gas ~ ~pany North Slope~l[._,rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 25, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' Kuparuk Well C-3 Dear Sir' ARCO Oil and Gas Company proposes to drill the above-mentioned well with operations commencing on approximately December 15, 1980. Attached please find the Application for Permit to Drill along with the BOP stack diagram, diverter drawing, as- built survey, well-bore proximity map, horizontal projection drawing, and $100.00 filing fee. Very truly yours, ~i A. VanDusen strict Drilling Engineer PAV'sp Attachments NOV 2 6 1980 R/aska 011 & ~as Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401 REV. 9-1-78 la. TYPE OF WORK b. TYPE OF WELL OIL WELL SUBMIT .IN TRIPL (Other mstruction~ reverse side) ALASKA el L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN ,,~v ~,6 ]980 Alaska Oil & Gas Cons. Comrnissi DRILL ['~ DEEPEN I--1 Anchorage GAS SINGLE MULTIPLE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1583' FNL, 1165' FWL, Sec 12, TllN, RIOE, UM At proposed prod. zone 6230' SSs 1320' FSL, 1320' FWL, Sec ll, TllN, RIOE, UM 13. DISTANCE IN MILES AND DI~ION FROM NEAREST TOWN OR POST OFFICE* 30 miles NW of Deadhorse API 950-029-20535 6. LEASE DESIGNATION AND SERIAL NO. ADL 25649 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25649 9. WELL NO. C-3 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Kuparuk River Oi 11. SEC., T., R., M., (BOTTOM Poo HOLE OBJECTIVE) Sec ll, TllN, RIOE, UM 14. BOND INFORMATION: Oil and Gas Bond nE Statewides~etyand/o, No. 8011-38-40 (Federal Insurance Co.) 15. DISTANCE FROM PROPOSED * 3697' (surface) ]16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 1320' (prod zone) I 2560 (Also to nearest drig, unit, if any) * 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH 6755' TVD TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. , 120' (surface), 3733' (prod, zone) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 55'_+ Orig GL, 60' + Pad, 94' + RKB Amount $500,000 17. NO,.ACRES ASSIGNED 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START December 15, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65 H-40 80 + MD Cmt to surf - approx 200 ft3 13-3/4" 10-3/4" 45.5 K-55BT( 328~' + MD Cmt to surf- approx 3600 ft3 8-3/4" 7" 26 K-55BT( 9430' ¥ MD Cmt with approx 1000 ft3 primary - 233 ftj secOndary, Arctic Pack t 2300' + MD to surface Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately + 9430' MD', +6755' TVD. Selected intervals will be logged. A 20" x 2000 psi annular divert--er will be i-nstalled 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. Expected maximum surface pressure will be 2830 psig. The well will be completed with 3½" 9.2# J-55 Buttress tubing. Nonfreezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPAC,~DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive g/Ir. If proposal is to drill or deepen' ditecfionally, give pertinent data on subsurface locations and measured and true verti~l~depths.;te blowout preventer program. 24' I herebyffZ~hat ~F- °-r?°i~ True~d~°rrecU Z 'L Vgg/a' ,cae / , £ ,..,,,," ,/7 ,Tta (This space for State office use) I SAMPLES AND CORE CHIPS REQUIRED [] YES ~O DIRECTIONAL SURVEY REQUIRED ~YES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES [~r..No OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE · ~F~-~/% TITLE C~.~av.. -&ssiev. er DATE 12/01/80 APPROVED BY ~~ *See Instruction On Reverse Side ~¥' ORDER OF THE CO~MISSION ('3-5/8" 5000 PSI RSRRA BOP STACK~ J ECEIVEO NOV 2 980 Alaska 011 1 Gas Cons. Comn~ission Anchorage L~TBG [ '-' 2 ., , 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. 13-5/8" 5000 PSI pipe rams drilling spool w/choke pipe rams bl i nd rams annular ACCUHULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TINE THEN CLOSE ALL UNITS SIMULTA~E- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST l. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE~,IINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~,tAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREA',I OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RA~S. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOH SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR l0 HINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND R~'IS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI~;G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. .14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOiIEY PUMP. 15. RECORD TEST INFO~'qATION ON BLOWOUT PREVE~ITER TEST FORM SIGN A~;D SEND TO DRILLI~;G SUPE~- VISOR. 16. PERFO~,I CGiPLETE BOPE TEST ONCE A WEEK A~iD FUNCTIONALLY OPERATE BOPE DAILY. Surface Div cer System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. '20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor · ~ . " i~ ~r i I . I I I . ': '...: . :'~" ..... -'-.- ~ z,,.' ", ~ ~' : ~ , : ~ ~ ~r ~ .-. - ~-" '...: . 71'~;' ....' ' i I, , '.... · , .-.: . . '//...~~~ ~ ~ ~ ,, ~ . :~ ...- . '~ ~. ~-: ~ ~ .. ~~ · ~~-- - II ' ' . . ' ' ' .' ' "" ~,~~'~"="==': ..... ~= = ~o~,=a,~$,, ... .... ... '..,...'...:~:~.. ....... .-~~-.-.-,... . , WELL ,~ Y = 5,~68,655',~2 i HERESY CERTIFY THAT I A~ .-. . , -X = o562,172.58 PROPERLY REGISTERED AND LICENSED '";~(~'""><':;:'~LAT;'"~<':::';70"19t29'.610"~'. .... :.:-'r.'TO PRACT ! CE -'.LAND -.SURVEY I NG'"IN':':'>'~"~"~;'~"'";";'~:,:~:~:~". .................. . ..... ..... LONG 1~°2~5.08q~ THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- WELL -U~ Y = 5~68~722,O] BUILT SURVEY HADE BY HE, AND X = o562,O7.2,~8 THAT ALL DIHENSlONS AND OTHER LAT = 70 19~]'0 27]" DETAILS ARE CORRECT, AS OF: : WELL ~5 Y = 5,968,788.41' WELL g7 Y = 5,968 x: s~,~,~o x: s~], 77=f~ m_ LONG = 149°29 ~50.878'' LONG = I49o29,56.689~m~m .WELL ~8 Y = : 5,968,987.86. ~'~ WELL ~6 Y 5,968,855.O9 X = 561,872'~6'~'" X = 561,672.26 LAT = 70°19:3].598" LAT = 70o19~32.920,, LONG = 149°29'53~791'' LONG = I49o29,59.608,, ii,,., i i ii i i ii i i i i i ill i i ii ill i P _ i ii i ..... AtlanlicRichtieldCom any ~__~ ..... DATE:~,DRAWIN~..No:~.~-~: MORTH AMERICAN PRODUCING DIVISION .:.-:::? ' . ... . ...:. -ALASKA DISTRICT KUPARUK -'-. ~'7~7~ '"':~'~'~ ~'""'~'~'"~='~"'" O._TMD: PERI~ OST,. [RRGE. RNGEE TARGET}~, SURFRCE ** .i I Surface DiveSter System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. '20" bell nipple. 16" Conductor g£CEIv£D 6 ]980 .Maintenance & Operation ~ ~ 1. Upon initial installation close annular I preventer and verify that ball valves I have opened properly. J 2. Close annular preventer and blow air ~__ _ t_.hrough diverter lines every 12 hours. J 3. Close annular preventer in the event ' ~ that gas or fluid flow to surface is ~ detected. If necessary, manually over- ~ ride and close ball valve to upwind [ diverter line. ~. Do not shut in well under any circumstances. IL i i ' ." .~, .~r lb : I ~ . ' '"' ' ' '-- ~ " '~ .~ i' - ~' '~' '~' ' · ' ' ' .-. '. .... " .'/-,-'~- .? I .~-' · ,' ,r "' 1 .. ,, ... ,¢. . -" , - il ... ",~%% '- - ~ ~ -' 0 " ~ ~-/%'' "¢ '"-~, -~ ~ t~ ~ ~ ' - '" . ........... .... I .: · ' -' · ' ~ OF '' y '.'~ .' . ' [~1 - 0~ x ,~ ' ~"4q*~ . ~ - 7 _1~ 28.285 ~ : ~ ~ ~ _ .~ · :...'..."-:'[O~a = 1~°2~35.2~3'' ,, . '...' ~"-~~ ~~r .... / ......... ~ ' ~ELL ~2 Y =" 5',968,589,5~ - . '. 'L~ ~'¢~'f ~. 8~[~ .-. ~~ . ... X =. 562,271.78 . , ...,- . ~ ~,..~o. 4~H-b . o ~ ~ . ' . ' ~ ,~ '-. ..-'~ ~ ....... '- LAT = 70 19 28.95~ .. ..........:.... ..... ~.z¢.' ....... ~ ~ . . LON6 =' ]~9°29'~'2~Z0~'' '..~ .... ...~ ...: .,.':;.. :.'.:.::..L::...;-..'...~...~!~'¢?t~,~,~tt~ ,. ...... '- ". ...... ' ,. ....... ' · ' ....... : ....... : .... "' ..4'- ...... ' ~%~%%~'' ...... . . ~ELL ,¢]Y = 5,968,65F'.~2 I HEREBY CERTIFY THAT ! A~ . , -X = 562,172058 PROPERLY REGISTERED AND LICENSED - · ..: ,-. &...I...¢~. ~, ·, ..~,,-.~ ,.. ~.~'~.?. ','7~ · ";~¢~""'~'%*;'¢~z't'AT" '&""::"'~70~ 19 ~ 2 9. 6 ~ O' ' ...... :.~-'r~ T O P R A C T I C E.-'. L A N D -.S U R V E Y'I N G ''~ t N ..... ? ..... *'~'"~**¢¢.'-'"~'.'~"~*~et LONG = ]49°29~45.084'' THE 'STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- WELL .-.-~4 Y = 5,968,722.03 BUILT SURVEY MADE BY ME, AND X = 562,O72~98 THAT ALL DIMENSIONS AND OTHER LAT = 70°19~3.0.273'' DETAILS ARE CORRECT, AS OF' LONG ~49°29'47.975'' DATE WELL ~5 Y = 5,96~,788,41' WELL ~7 Y = 5,968.92~.16 X = 561,973,00 X = 561,772.83 LAT = 70°t9'3g~934'' LAT = 70°19:32.256'' LONG = 149°29~50 878" LONG = 149o29~56.689'' WELL ~6 Y = 5,968,855.O9 .WELL g8 Y = : 5,968,987.86' · X = 561, 872:;6%'''-''' 'X = 561,672.26 LAT = 70°]9~3].598'' LAT = 70°19'32 920" LONG = 149°29'53~79~'' LONG = ]49o29'59.608,, · i i i~i i i I ii I I I i i ill i I - i i AtlanticRichfieldCompany ..,,.. -- NORTH AMERICAN PRODUCING DIVISION .:. '.,?'::r',".;' ;.-. ..... -ALASKA DISTRICT- KUPARUK "- ~'/~'/~ '"'"':~'~'~ glEEL FIiELD,' WHIPSTOCk, 't / ...// ~~.~: ...... ; ........... 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CHECK LIST FOR NE]~ ?~LL PERMITS Item Approve Date (1) Fee ~/~ /~, .... ,...7~'~ (2) Loc. /~./.~. Company '(j~'~ c, 0 Yes No 1. Is the permit fee attached .......................................... / 2. Is well to be located in a defined pool ............................ ~ 3. Is a registered survey plat attached ................................ ~ 4. Is well located proper distance frcm property line ......... ~ ....... ~&~- '/ %"5. Is well located proper distance frcm other wells .................... ~Y~ ...... 6. Is sufficient undedicated acreage available in this pool ............ '~ /----, (3) AdmLn ¢~,~?~Y--" (4) Ca. sg~ 7. Is well to ke deviated ...................................... 8. Is operator the only affected p~r~y 9. Can permit be approved kefore ten---da7 wait 10. Does operator have a Ir>nd in force .......... ~ 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... (~, 13. Is conductor string provided ....................................... .~~ 14. Is enough cement used to circulate on conductor and surface ........ ~-_ _ 15. Will cement tie in surface and intermediate or production strings . ..~~ 16. Will cement cover all known productive horizons .................... 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to j~o o psig . Approval ~mc~ded: Remaffks Additional Requirements: Geology: Engin%ering: rev: 03/05/80 Well Histo.ry 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.' o. No 'special'effort has been made to chronologically organize this category of information. .o DATA [-t.j.t:',fv~A'l.' ;SPECiF1CA.IFI£'JN LENG I."H: t~90 BYTES EN'rRz B Lt~IC'F,S: T 0 SIZE REP CO!)E ENTRZ 1 6b 0 SCHLttFiBt/]RGER COMPUTING CENTEP, 10707,61310 REEL HEADEI~ LENGT~: i 32 REEL NA~E: P.C.A.L. SERV ICI),, a Af,~g: EOIT PREV1OUS REEL COM~ItNTS: LIS FORr,~Ar CUSTOmeR TAPE DATL: 8tl 1/19 TAPE HgADER O! F i. LE; OATE: 81/ t/19 102-4 B~TES EUPAR!~ C-3 NORTH SBtF~ ALASK. A DATUM SPECI.F'ICATIU.N L4bOCI~$: ENTR~ 1 2 5 6 7 9 10 11_ 1'/ 1C TOOL lbo .Ol.b Gi~ DIJ., ' D~HO CNB NPHI NRA ~ CNL NCNL CNb FCN I.~ CNL i) T ~ ~C (; P ' B RC (;~ - NGR$ THOR NGRS ttEAN NGR.S P(~TA NGRS SVuRD~ UNII$ APl AP1 API AP£ F BE~ SIZE EXP PROC SAM I~EP DEP ?T 0 0 0 0 0 4 0 0 1 68 OIti';IM · 7 , 12 46 0 0 4 0 0 1 68 OH..'qt~ 7 12 44 0 -0 4 0 0 1 ,8 GAP 1 ? 31 32 .0 0 4 0 0 I 68 IN 42 28 I 0 0 4 0 0 1 68 G/C3 ~2 44 0 O 0 4 0 0 168 PO '4~ - 68 2 0 '-0 4 0 0 I 68 u/C .~ q2 35 1 0 -- 0 4 0 0 i 68 e;~./C 42 42 -1 O ' O ~ O 0 i 68 CPS ~ 3~ 9~t 0 ~0 . 0 1 6~ US/.F 60 52 32 0 _O 4 0 0 1 68 g~P'I 31 - ;il 32 o -:0 4 o o 1 68 GAP1 31 31 32 00 4 0 0 I 68 "i O 00 ~ O 4 0 0 1 68 / ~ 31 0 0 0 -~0 ~ 0 0 168 /w 3i 0 0 0 0 4 0._ 0 168 T SHIPT 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9703.000 9700. O0() 9600.000 9590.OO0 9400.0"00~ 9300.000 9200.000 9! 00. 9000. 000 8900. 000 8800.000 ~bD 0l 7~1 )RH[) [~07 NP~I D R H (] NCNb GR V ALU E MN EM[)N I C VALUE 7i g32 (iR 97.43~ 4 [266 RHOB 2.471 504 750 ; DT , 92.000 14: 414 ~ ORAN 4. 852 1.933 GR NCNb 1913 000 ~CHL 55~ 00~ - D~ GR ]04:500 THOR l!: ll U~An ILD 3.727 I. LM ~.824 GR D},, O 0.021 .. NPBI 30.371 . RHOB NCN[, 2630-000 [~'CNL f~l 4.OO0 : DT GR 53.4~9 THOR 6. 754 URAN iLD DRHO NCNb t.160 GR ]O~615' RHt)B '762 500 DT q~156 -; ORAN i L D DRHO R 5.566 ILH 5.559 GR 0.018 NPHI 33 154 EHOB 23321000 FCNL 752]000 DT 006 2v- 9o l. .ooo oo 60.719 THOR 5:]~g ~fiN IbM 3.867 GR NPH.[ 31.299 . RHOB FCNL 608.O00 DT TliO~ 12.109 ORAN ILD 4.023 L)RHO -0.008 NCNb 1~59.000 GR 99.250 915 GR 4. :508 HR(It3 375 750 OT 1 o: 2._50 u~.An ILD 1,.847 ibm D~HU -0.006 NPHtZ '7 NCNL 158 .000 122. 875 97.438 2.471 92.000 4.852 I .i~ i.) 1.953 t L M NCaL 1361 *O00 FCNL GR I 15. 750 'tHUR 95.875 2.418 92.000 2.727 38.156 2.273 92.000 0.962 83.875 2.400 89.750 2.486 75.375 2.395 91.000 2.762 2o 592 1090 000 1 ~0: 500 ~1.844 2.230 90.188 2.i82 109.938 2.861 88.188 1.502 11~.938 .350 107.000 5.004 2.072 G~ 111.438 58.154 Ri~O~ 2.186 28~i500' D1 105.750 11.056 [iRAN 6.313 L~ 2,727 ~'CNb 338.000 THt.._t? 10.!88 RH()B DT IJRAN 115.375 2.279 108,188 4.555 MN EM(IN iC CAUl CALl lq RA'I' GR POTA CAUl NRAT GR POTA CAUl NRA~ GR PUTA CALl NRAT GR PUTA CALl NRAT GR POTA CAUl NRAT GR POTA CALl NRA'][' GR POTA CALl NRAT GR POTA CAbl GR P O T A CALl NRA'I' GR POTA VA 0.0 3.5 1.4 0.0 6.8 3.5 7.4 0.0 8.6 3.2 5.8 0.0 00 94 34 55 94 38 34 72 50 75 22 ~.594 2.773 38.15~ 0.011 9.383 2.855 ~3.875 0.017 8.656 2.963 75.375 0.010 9 2 61 0 9 2 109 0 OO8 615 844 012 (:,72 924 938 018 .1 .8 .9 .0 11 3 117 0 13 4 111 0 10 4 115 0 .2 .5 .4 .0 .1 .3 .3 .0 56 O3 3~ 2O 50 63 09 33 67 75 25 D k, P T ,N 8700 ,O0O 8600, O00 8500, ooo 84OO, O00 8300.000 8200.000 8100.000 8000,00O 7900,000 7800.000 7700.000 'VALUE /qNEMONiC .VALUE MNEMONIC VALUE ~.912 ihil 3.O02 GR 164.375 .O01 NPH.t 10,918 RHOB 2.422 1 LD ,1LO 3.207 Ib~4 3.3lt GR 140.625 DP, HO -6-006 NPHi 38~-721 < R'Hi'iB 2.324 !~CNL lt~95. 000 . ~;CNB 529.500 -. DT 10~.375 GR 150.250 ~H()R 11-797 URAN .738 IbD 3,29] I..bM 3,684 I09.4]8 D~HO 0.O00 N[HI 47.314 , 8NOB 2.354 NCNL ~65].'000 FCNL 426~500 GR 133.125 I'HOR 10.133 ORAN 7 191 ILl) ~ " · c ~ 11 ~. 875 ~,48~ ILM ~,42) GR ~039 NPHi ~,O57 ~ RHOB ~.441 DRH[) ~NL 1712.00( fCNL 588.500 : DT 107.000 . 11'7'375 THOR I2.1'09 ,- ORAN 2.2t0 ILD 2 ..455 IL!q 2.549' - GR 91.875 Di~HO 0.018 NPHI 41..260 ~ kHO~ 2.277 NCNL 1885.i'000 FCNL 484~750 ~ DT 108. 188 GR 104,~25 'tHOR 8,5 ]1 ORAN 4,922 iLD ~.297 IbM 2.992 GR 11 ' 9]8 DRHO u'006 NPHI 37'402 14o.ooo sgo.soo iLD 2.955' 1I,M 3.053 GR 161.125 ~.HU · -0.020 · N~i 4~.748 RHOB .2.371 NCNL I891.000 ' FCNL 48'6 i250 · aT 107.000 GR 155,875 TaOa 4.840 ~ U~AN 8,859 ] at{O :001 ' NPH-I .'8:477 RHOB 2.439 ~.~C aL 1926.000 ~CNL 481.500 DT 1( ].188 G R ] .~ ~, .]'75 T H.O P 8 ~ 922 U R A N .3.268 ihO 1.831 ILM 1-994' GR 165.875 iL, D ,O35 1. L~I 3.508 GR 17 625 DRHO - .002 NPBi 33.008 ~Hr}B 375 ~NL 98.188 "~ 14.344 - . - % . · . . :' · MN EMONiC / C~bI POTA CALl NRAT GR P 0 T A CALl NRAT GR POTA CAbI NRAT GR POTA CALl NRAT GR P[ITA CAbI NRAT GR P£)TA CAb[ NRA'f GR PUTA CALl NRAT GR POTA CALl NRAT GR POTA CALl NRAT GR PO~A CALl NRA'[' POTA VAb 9 0 9 186 0 10 3 1.40 0 9 3 109 O 10 3 114 0 . 3. 91. 0, 10. 3. 115. 0. 10. 3. 161. O. 10. 3. 128. O. 0 3, 105. 0, 10 ll~ 0 UE ,641 .451 ,375 .027 .695 ,859 .625 .000 .357 .~25 .033 .711 .813 .438 .014 .258 .088 .875 .028 953 494 875 017 O55 289 938 012 227 545 125 041 484 385 875 039 922 422 875 O32 .039 ,0O8 ,625 .0]0 Dt P'J.'H 760U. 000 750U. 000 7400. o00 73OO. 7200.000 7100. 000 7000. 000 6800.000 6 '700.000 ~!i,{EMO£q i C VALOE, ILD 1. 582 DRHO -0 . O17 ~C l,J I., 1783 . 000 GR i 41. O00 1 L D GR 1 423, 0 ~ 042 1~7.. 000 166:125 ~'4 NgM(~N lC VAI, iJE MNEMONIC ILN I 558 GR NP'HI 42 ~ 773 RHOB FCNL 432.250 DT THO~ t'4.383 ~ UR~N ILD GR LD NC,NL GR iLt, DR} .O NC~L I.,~D 3.469 ILM ~.4t4 0.025 NPHI 23.026 R~i. Jg 21981000 FCNL 824.560 ! 3.4.375 T~O~, 8.359 ~LN 1 639 GR NPHI 53 ~ 564 RH.OB FCNL 328. 750 THOR 7' . 4 I0 1 . 886 ILM 1 . 962 GR -0.00~ NPBI 48. 193 I660.000 FCNL 387.500 " '' ORAN 162. 750 .[HtJR 4. 590 i. 922 IBM 1.940 _ GR .o9o.ooo ecne 38 . soo _-44 2. 004 ILN 2.006 : GR 0.015 ~,PHi 40.918 I9~i .O00 ~'C-fg 1~ 496.500 DT 9 O 438 THOR 10.742 ·_ [:; C L 60 500 .... T T~OR :2.ti u~an 16D 3 . 053 I LM 2 . 867 :{)RH O 0.014 aPHi -34.180 CNL 2198.000 ' FCNL-. ' 659.500 : DT GR 74. 438 THOR 5. 559 URAN i1) LD N C N L GR 602.500 DT 10. 061 I.tRAN II,P 2.904 IbM 2. 828 GR DRdU 0 021 NPHI 36 621 RHOB NCNL '2020.000 ~C:NL' 546.000 ~; DT GR 89.813 THOR 7.953 ORAN ~LD ~.818 iLM ' 775 GR RHO ,002 ~PHi 3~.' : RHO 473 a ~ j 05.500 TflO~ ..375 U~iN VALUE !38.500 2.264 10~.~75 .516 134.250 2.324 90.~75 9.547 153.250 2.209 116.000 14.930 151.875 2.281 116.375 10.820 137.875 2.279 11.3.375 9.539 91.438 2.330 i04.188 0.427 93.125 2.363 103.750 5.207 76.938 2.328 94.188 3.893 95.375 2.338 I01.000 2.645 78.688 2.258 100.56~ 2.'170 93.875 2.246 100.188 2.762 CALl NRAT GR POTA CALl N RAT GR PUTA CALl NRAI GR POTA CALl NRAT GR PUTA CALl NRAT GR PUTA CALl NRAT GR POTA CALl NRAT GR POTA CALl. NRAT GR PUTA CALl NRAT GR PUTA CALl N RAT GR POTA CALl NRAT GR PUTA VAI,U~ i0.1 3.5 138.5 0,0 9.5 2.4 134.2 0.0 9.7 15'3.2 0.0 9.4 3.8 151.8 0.0 9.2 3.9 137.8 0.0 9.2 3.4 91.4 0.0 9.3 3.2 93.1 0.0 9.0 3.0 76.9 0.0 9.3 3.4 95.3 0.0 9.2 3.1 0.0 9.2 3.0 93.8 0.0 25 94 0O 29 78 22 50 10 42 60 50 06 42 75 23 81 ~6 75 24 42 20 38 44 91 25 10 16 25 12 13 57 75 30 42 82 88 19 81 64 75 27 [) IL P TH 6500. 000 6400. 000 63O0. 000 620O. 000 6O00.OOO 590O. 000 5~00.000 5700.000 5600.000 5500 O,J J VALUE lqNgiqON IC VALUE MNEMONIC VALUE . 2.357 ILk, 2.207 - R 57.594 -~ .00'3 NPHI' ,18.O47 RHOB 2.227 D~HO NCNL 2194.000 ~CNL 487.750 DT 114.000 GR 76.625 THOR " {1605 ' U~AN 5.207 ILD ].994 ' ILM 3.846 GR 76.688 I~R~i(] -0 005 NPHI . ~5.400 ~ ~j[]5 2.227 NCNL ~05rl~ 0()0 FCNL 587.000 ~ Dr 100.563 G~ 85.000 .IMUR 11. 38 ORAN 0.177 . ILD ~. 090 1LM g.!09 GR · 88.]13 DRHO -O'OOl NPHi 32,275 NCNL 1799 000 · FCN~ 599,500 DT .105,750 GR 89:]75 THOR 1.'~57 URAN 4.438 ~LD 3.248 ILM 3.232 '~ GR 105.500 R.O 0.O09 NPHI 36.230 ~ RBUB .2.354 CML 1788.000 FCNL 546'500 :~ DT 109.563 GR 1,09. ~ 25 THOR : 12.594 URAN 2.330 LD 85~ ILM .3.670 . GR 90.063 RHO -6;0)~ - NPHI ~ 42i725 RHOB 2,221 ~}C. N L 2000 OOO ~CNL 473,-00 D.[ 1 lb, ]'75 GR 98~56] : THOR 16-703 URAN ' -1,g26 Ii~D 8.023 ' IBM :7.910 GR 75.500 CNL GR ~HO - ~0i'4 NPHI ' 39'94I RHOB 2.244 r~C r, L ~92 ,000 FCNL 521,O00 _ t.f ~11.]75 <.;F. 10~-50<) THOR 12.8i3 : UBAN 1.715 ~O 2.688 - Ih~4 2'584 ~: GR · 8~.~38 C't~g 188~,000 FcNf. '472,000 - .000 GR 101.125 THOR 7.fl60 URAN 4.20J . . lbD ].727 [LB ~.574 GR 80.188 DRH[i 0.OI] [~P~ I. -4i.650 AH(lB 2.277 NCNL 177].000 [CNL 412.250 DT 114.563 GH 84~506 ~HOR 72793 ~ URAN 2,570 lt,D ~.443 ILN 3.28I GR · 84.438 DR~O 0 011 NPBI. . 44.531 RM(J~ 2.248 'NCNb 1934:060 ~'C-NL 468.750 : DT 111.188 GR 87.438 THOR 8.148 URAN 2.172 . iLD 4.o41 ILN 4.406 .: GR .b .500 DRHLi -0~0OO NPHI 40.625 RHO~ 2,223 NCNb 1940,000 tCNL . 5]0,000 , ~T 1!0,i88 G~. 74 2'i ~8 I~HOR 6'69~ - ORAN 2.465 - . . : ..: MNEMONIC CALl NRAT GR POTA CALl NRAT GR POTA CALl NRAT GR POTA CALl NAAT GR POTA CALl NRAT GR POTA CALl NAAT GR POTA CALl NRAI GA POTA CALl GR POTA CALk NRAT GA POTA CALl NRAT GR P O T A CALl NRA'I GR PUTA VAbUk 10.430 3.910 51.594 0.009 9.508 3.135 76.688 O.Olb 9.281 2.955 88.31] 0,028 9.609 J.189 105.500 0.023 9.813 3.564 90.063 0.026 9.664 3.227 75.500 0.014 9.703 3.402 88.813 0.017 9.17:'] 3.416 81.438 0.017 9.789 3.504 80.188 0.019 9.445 3.637 84.438 0.017 9.406 3.416 08.50O 0.016 5400 5 .~ 00 o 000 5200. 000 5100.000 5000.000 49O0.O00 4800,000 4700. 000 4600. 000 4500. 000 4i00. 000 NNL~ON lC i LO RHO CNL GR VALUE MNEMUNiC 430 GR 49~ 750 OT "9'96 :: ORAN iLD 7 016 DRBO 0:001 NCNb 1879,00~ GR 64i93 ILM ~ 074 GR ~b 000 DT CN 515. HOR ' 5.719 ' :' UR:AN :tI, D 8. 469 I~,M 7.5'7o Ga I),R,[iU 0.002 NgHI 39.014 R~OB NC. Nb 1815-000 FCNL 486'250 ' D'I GR 8 i .500 THOR 8. 141 . LIRAN DILD 12 430 ~.~o o:oo4 NCNb 1955.ooo (;~ 79.37s IbD 9.816 NCNb t9:38.000 G~ 92.813 D t.~ H 0 ~ o o ,4 NCNL 20~4,O00 GR 75 .'675 IbM . 12.2,42 GR 37~793 53~.000 : ILM '9.516 GP NPHI 36 426 R}tOB rc~h 544:$oo D~ THOR 8. 469 .... >~ iLD 5 . 0 31 DRH[! 0. 007 NPHi NCNb 17341000 FCNL GR 69 . 750 I hb .. 6.637 ~Ij~a~4hi DRHO 0. O0 ~ NCNL 1908.000 ~iCNL GR 57. 625 4.715 GR 50.391 ~ ~HL}D ~851500:DT URA, 2.436 .... N ovo 086 I h D 8. ,~ 14. I L M R. O 47 GR DT URAN DRHO NCNL GR i L D DRHO f~CNn GR 190¢.000 57,93§ tLa 7,738 GR NPHI 39.063 RHf)~ 000 PT ~'CNL 5~ '60~ " ORAN THO~ ,'. .... VAhUE 83.188 2.273 114.750 2.809 49.844 2.135 122.563 0.751 65.750 2.246 2 :ooo 981 76.875 2.375 110,375 i.325 08.875 2.262 120.000 2.004 76.125 2.365 I09.000 2.877 67.250 2.289 120.750 2.395 65.250 4.488 84 140.375 3.059 78.55] 2.299 117.565 4.840 90.688 2,068 i12,]75 1.440 MN EMON lC CALl NRAT GR PUTA CALl NRAT GR POTA CALl NRAT GR POTA CALl NRAT GR POTA CALk NRAT GR PUTA CALl NRAI: GR POTA CALl NRAT GR POTA CALl NRAi' GR PUTA CALl N RAT GR POTA CALl NRA'I' GR POTA CALl NRA'].' POTA VAb 9 3 0 9 3 49 0 9 3 65 0 9 3 76 0 0 10 0 10 3 ~7 0 9 ~5 0 10 3 48 0 9 78 0 15 0 Uh .3 .3 .1 .0 .0 .4 .8 .0 .5 .4 .7 .0 .8 .3 .8 .0 .6 .2 .8 .0 .5 .2 .1 .0 .6 .2 .0 .7 .9 .2 .0 .4 .3 .1 .0 .9 .4 .5 .0 .5 .5 ~ 9 n 0 g ~ 0 4000 :t 900.000 3 g,, O 0.000 3 700 . O 00 3600. O00 .'~ 5 0 0 . 000 3300.000 1LD DP, H(} GR I bD DJ{ H O NCNB GR i b D NC NL GR .i IJD NCNI, GR I L DP, HO N (' iq L GR l i.J!) D R H NC G k N C N !.~ D k fiu NCNB GR I hi} .I I.,D NC NL GR 1 NC 7.246 0.002 lq06.000 57.938 1.3.88:1 0.002 1906. 000 57.938 11.922 0.002 190b. O00 57.938 10.27] 0.0o2 1906. 57.932 6.04 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 7.762 -999.250 -999.250 -999.250 i0.641 -999.250 -999.250 -999.250 B 7i9 -~99'.250 2999 250 66~:2SO q. 453 -999,250 -999.250 -999.25O 5.785 -999.250 -999.250 -999.250 NPHI ~'CNb I LM NPH I t~ C N L NPHi FCNL I'HUR iLP! NPHI FCNL TMUR ILM NPHI i;'CNI, NPHI ~CNL NPH l FCNL T Ii 0 R NPHI l~ CNL ~PH I FC NL T H t')R NPHI THOR V A b iJ k e,.750 39. O6 _~ 531,. 000 4.605 14.1.33 39.063 5]!.000 4.605 10.609 ~9.063 5~1.000 4.605 9.938 39.063 531.000 4.~05 5.014 -99925.000 -999.250 -999.250 6.535 -99925.000 -9gg.250 -999.250 7.273 -99q25.000 -999.250 -999.250 11.273 -99925.000 -999.250 -999.250 8.]28 9992.::.000 -999.250 -999.250 O.O14 -99925 000 -gqg.'2So ,,999.250 5.184 -99925. I7)00 -999 250 MNLMON lC GR RHOB DT URAN GR RHOB DT RH(jB DT URAN GR. DT [,iRAN R H (.J B URAN GR DT URAN GR RHt_)~5 DT URAN GR DT URAN RHO~ URAN GR RH[Ib DT U RAN DT URAN VALUE 68.188 2.068 121.750 1.440 55.156 2.068 102.563 1.4~0 ~5.18B 2.068 139.125 1.440 48.344 2.068 137.000 1.440 53.781 -999.250 131.125 -999.25O 54.3'15 -999.250 142.000 -999.250 -999.250 129.125 -q99.250 52.438 -999.25O 130.125 -999.Z50 56.59% -999.250 1~1.375 -999.250 51.o5o -999.250 1~3.000 -999.250 -999.250 133.125 -999.250 t~INEMUNIC CALl NRAT GR POTA CALl NAAT GR P UT A CALl N R A T GR PUTA CAbI NRAT GR PUTA CALl NRAT GA PUTA CALl NRAT GR PUfA CAbl NH AT PUTA (:ALI N RAt POTA C ALI NRAT GR PU[' A CALl N RAT POTA CALl NRA'I G~ POTA VAbOb 15.594 3.56] 0.018 15.59~ 3.5~3 55.156 0.018 15.59~ 3.503 ~5.188 O.OIU 15.594 3.563 48.344 0.01~ -999.250 -999.250 53.781 -999.250 -999.250 -999.250 54.~75 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 52.43~ -999.250 -999.250 -999.250 56.594 -999.250 -999.250 -999.250 51.65~ -999.2b0 -999.250 -999.250 -999.250 I],D -999.25 DRHO -999,25~ ~CNb -99~ 2.~ }]hM -909.250 GR PHI -9092~.O00 ~Hf)B 'CNL -999 250 DT ~.c.m -9~g ~ 250 u~a~,~ VAI~UE; -999.250 -999.250 -999.250 -999.250 CAbl NRA'I' GR PUTA VALU~ -999.250 -999.250 -999.250 -999.250 I.,L.NG3 k~ i. tF LA&T f~CtJi:~l): F TI.,E 1 O24 Ol fAA ! I,EN6;IId: 132 B~'rEs sb.,p v i c~. NANE: El)IT TAPE: C(.~NTiNUATiDN NEXT TAPE i~iA~lg: DATE: 81./ 1/19