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185-190
Imag~YProject Well History File ge 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/~¢>'_~_'~.j/~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: D Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ,~ OVERSIZED (Non-Scannable) [] Other: -" · -: '[3. Logs of various kinds NOTES: [] Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si · OTA PAGES BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning Stage BY: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES __ NO IF NO IN STAGE '!~ PAGE(S) DISCREPANCIES WERE FOUND: YES __ NO DA'rE:././ 0 .~/S/ ~ RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Coil Tubing Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service '~.' Name of Operator 7. Permit Number Phillips Alaska Inc. 185-190 302-080 ~. Address ' 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21416-00 4. Location of well at surface i"~~~ 9. Unit or Lease Name 420' SNL, 1402' WEL, SEC. 14, T12N, R09E, UM , Kuparuk River Unit At top of productive interval 1334' NSL, 1168' WEL, SEC. 11, T12N, R09E, UM At total depth 10. Well Number 3C.04 1730' NSL, 1144' WEL, SEC. 11, T12N, R09E, UM 5~ Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Kuparuk River Oil Pool RKB - 85' ADL 025629 '~. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'I'VD) 119. Directional SurveyI 20. Depth where SSSV set121. Thickness of Permafrost 7670 6864 ETI 7568 6791 FTI [] Yes [] No] N/A MDI 1380' (Approx.) 22. Type Electric or Other Logs Run ;23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 16" 60.5# H-40 Surface 100' 24" 183 sx CS II .i0-3/4" 45.5# J-55 Surface 2445' 13-1/2" 1050 sx PF 'E', 380 sx PF 'C' 7" 26# J-55 Surface 7650' 8-1/2" 380 sx PF 'E', 250 sx 'G', 250 sx PF 'C' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.3#, L-80 7213' 7028' & 7245' MD -I-VD MD -I-VD (Top of Window) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7234' - 7236' Punched Holes in Tubing 7222' Set Cement Retainer, then P&A with 16.1 Bbls Class 'G' 7212' Set (Top of) Whipstock 27. 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-BBL GAs'MCF WATER'BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE ,,28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. No core samples were taken. JUH 1 3 20O2 Alaska Oil 8, Gas Cor~s. 6omm~smo~, Anchorage ' ' Form 10-407 Rev. 07-01-80 Submit In Duplicate JUN I Z~ 2N~ 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Top Kuparuk C 7102' 6458' Bottom Kuparuk C 7199' 6527' Top Kuparuk A 7381' 6657' Bottom Kuparuk A 7514' 6753' RECEIVED · .JLJi'J 'J 5 2002 Alaska Oil & Gas Cons. G0rnm~ss~o~: Anchorage 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the fore, going is true and correct to the best of my knowledge Signed TerrieHubb,e ,~~ ~ Title TechnicalAssistant Date 3C-04 185-190 302-080 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval 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. 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 '!6 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 2'1: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: 3C-04A Rig Accept: 04/21/02 Field: Kuparuk River Unit Rig Spud: 04/25/02 APl: 50-029-21416-01 Rig Release: 04/29/02 Permit: 202-057 Drilling Rig: Nordic #1 PRE-RIG WORK 12/31/01 POT-T PASSED, PPPOT-T PASSED, POT-lC PASSED, PPPOT-IC FAILED. 01/08/02 MITOA PASSED. 03~08~O2 TAGGED FILL AT 7474' RKB, EST. 26' RATHOLE. SHUT CMU AT 7231' RKB. PULLED GLV AT 6208' RKB. 03109102 SET DV'S AT 2992', 4900', 6208' RKB. DRIFTED TUBING WITH WEATHERFORD 2.7" x 25' DRIFT TO X/O AT 7241' RKB. SET 2.31" XXN PLUG AT 7262' RKB. LEFT OPEN GLM AT 6960' RKB. 03/10~02 LOADED IA WITH SEAWATER AND DIESEL CAP. PRESSURE TEST TUBING AND CASING TO 2500#. GOOD TESTS. OPENED CMU AT 7231' RKB. 03/11/02 DISPLACED TUBING WITH 100 BBLS KCL AND 20 BBL DIESEL CAP. 03/31/02 TUBING PUNCHER - INTERVAL 7234' - 7236'. ATTEMPTED TO RIH WITH EZSV PLUG, PLUG BEGAN TO SET IN TREE. POOH. 04/01/02 SET BAKER H-1 CEMENT RETAINER TOP AT 7222'. REPLACED DV AT 7072' RKB WITH :~A" PORTED CHECKED CV. CONFIRMED VALVE IN POCKET. 04/04/02 PUMPED 16.1 BBLS OF 17 PPG CLASS 'G' CEMENT. PUMPED 5.5 BBLS THROUGH CEMENT RETAINER SET AT 7222' INTO STRADDLE SECTION OF 3-1/2" x 7" ANNULUS; WELL LOCKED UP TIGHT. REMAINDER OF CEMENT THEN LAYED ON TOP OF RETAINER AND DRESSED DOWN TO 7120' CTM. WELL FREEZE PROTECTED TO 2300' WITH DIESEL. 04/07/02 TAGGED CEMENT AT 7120' RKB, REPLACED CV W/DV AT 7072' RKB. PRESSURE TEST TUBING TO 2500#, HELD. 04/11/02 MILLED CEMENT TO TOP OF BAKER H-1 CEMENT RETAINER AT 7222'. NUMEROUS CLEAN-UP PASSES MADE THROUGH MILLED SECTION. WELL LEFT LOADED W/SEAWATER AND DIESEL CAP TO 2300'. PRESSURE TESTED TUBING TO 1500 PSI, HELD 15 MINUTES, BLED OFF. 04/12/O2 DRIFTED TUBING WITH WEATHERFORD DRIFT 25' 3" x 2.70" TO 7215' WLM. 04/13/02 E-LINE TAG TD POST MILL (PRE-CTD). CCL COLLAR LOG DRIFT AND TAG. NO PULLS OFF BO'II'OM. CORRELATE TO SWS PPROF 10-23-01. TAG 7220' MD ELM. 04118/02 MITIA- PASSED. PHILLIPS PETROLEUM CO. Page 1 of 12 Operations Summar Report Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4/21/2002 00:00 - 03:30 3.50 MOB P PRE Continue move from 3H-16a. Move onto 3C Pad at 0220 hrs. Move over tree and set down. FLP 200, GL 200 03:30 - 07:30 4.00 BOPSUF P DECOMP Accept rig at 0330 hrs 4/21/2002. Remove tree cap. NU BOPE. Meanwhile spot & berm flowback tanks, upright & slop tank. 07:30 o 08:30 1.00 BOPSUF P DECOMP Held pre-spud/pre-operations start-up safety meeting with day crew. Discussed recent 3H-16A hi/lo-lights. Reviewed scope, objectives, critical issues, risks & contingencies of 3C-4A DOCTD operations. Stress adherence to procedures, HNHM & good communication. 08:30 - 11:00 2.50 BOPSUF P DECOMP PJSM. Install work platform around BOP stack. Open up & visually inspect lower 2-3/8" & 2" combi pipe/slip rams for wear/deformation. Rams in good condition. 11:00 - 18:30 7.50 BOPSUF P DECOMP PJSM. Pressure tested BOPE to 4500psi as per drilling permit. Witnessing of test waived by State Rep Chuck Scheve. 18:30 - 19:30 1.00 BOPSUF N SF^L DECOMP BOPE test completed, but noticed hydraulic fluid leaking from annular cap. Begin removal of same. Fill upright tank w/220 bbls 12.6 ppg KWF 19:30 - 20:15 0.75 BOPSUF.P DECOMP Prespud mtg given by D. Venhaus to nite crew covering same topics above 20:15 - 22:45 2.50 BOPSUF N SFAL DECOMP Continue removal of annular cap and repair same. Reinstall and retest w/test jt at 2500 psi for 30 min. Meanwhile investigate "noise" in power pack traction motor. Fin unload Iowboys of misc tools. Unload KVVF and send back to MI due to too high ph 22:45- 23:00 0.25 CLEAN = DECOMP Safety mtg re: slack management procedure 23:00 - 00:00 1.00 CLEAN = DECOMP Fill CT w/4 bbls mud to displace 2 bbls diesel from end of CT Cut off CTC 4/22/2002 00:00 - 04:30 4.50 CLEAN = DECOMP Stab injector on well. Rev 41 bbls mud 2.6/4000 and slack stopped moving at 7 bbls. Replace packoff Unstab. Cut off CT in +/-5' lengths and find e-line at 42'. Rehead. PT CTC and inner reel valve at 4000 psi 04:30 - 05:00 0.50 CLEAN P DECOMP Circ CT volume of mud the long way 2.2/3875 05:00- 05:15 0.25 CLEAN P DECOMP Check well for pressure=O. MV=20, SW=20. PVT 200 05:15- 06:10 0.92 CLEAN P DECOMP MU milling BHA. Test voltage, ok 06:10 - 06:50 0.67 CLEAN P DECOMP RIH w/BHA #1 to 2227'. 08:50- 08:15 1.42 CLEAN N DF^L DECOMP SHT coiltrack & observe short somewhere in system. Open up eline bulkhead @ reel & check electrical connections ~ nothing amiss, could supply good voltage to bulkhead. Suspect e-line, i UQC or downhole tool problem. Close up e-line bulkhead. 08:15 - 08:55 0.67 CLEAN N DF^L DECOMP !POOH BHA#1 to check for short in e-line system. 08:55 - 10:00 1.08 CLEAN N DF^L DECOMP iTag up at surface. Break off UQC & R/B injector. Tested downhole tools & tools tested OK. Openned up UQC & found fluid ingress into e-line core (probably from reverse circ during slack management). 10:00 - 10:10 0.17 CLEAN N DFAL DECOMP Freeze protect exposed CT with 2 bbls diesel. Meanwhile rectified DS pump pressure transducer & installed new mother board for DS main computer. Looks like an "electronics' field day ..... 10:10 - 14:15 4.08 CLEAN N DFAL DECOMP Cut 60' of CT/e-line in 5' stages & still found fluid in e-line. Cut additional 15' before seeing dry e-line core. Carried out continuity tests on e-line from BHI unit ~ getting inconsistent readings. Retry from collector bulkhead - OK. M/U bulkhead & Printed: 4r-'JOt2002 3:18:10 PM PHILLIPS PETROLEUM CO. Page 2 of 12 Operations Summa Report Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From To Hours Activity Code NPT Phase Description of Operations 4/22/2002 10:10- 14:15 4.08 CLEAN N DFAL DECOMP meg-test from BHI unit ~ still getting inconsistent readings. Suspect electrical grounding or some sort of anomaly @ bulkhead after M/U. 14:15 - 18:30 4.25 CLEAN N DFAL DECOMP Cut 8' coil (83' total cut now). M/U BHI CTC. Pull test to 20k - OK. M/U UQC. Meanwhile re-open bulkehead, re-wired & retested. Finally got good condutivity tests from e-line to bulkhead to collector to BHI unit. 18:30-19:15 0.75 CLEAN P DECOMP MU 2.3 BHI motor w/ 2.74 DPI bit on BHI BHA. RIHw/opress deployment freely if bit below no-go ring. POOH and hangs up in stack, but can be worked thru MU 2.3 BHI motor w/2.74 HYC D100 bicenter on BHI BHA. RIH/POH w/o press deployment, clean. PT BHI CTC @ 3000 psi 19:15- 22:00 2.75 CLEAN P DECOMP Safety mtg (new Nordic crew) re: pressure deployment of BHA Practice pressure deployment w/Hycalog bit on 2.3 BHI motor w/60 psi induced WHP. Notice BHI CTC has Iow pressure leak-retest and failed 22:00 - 23:30 1.50 CLEAN P DECOMP Safety mtg re: pressure undeployment of BHA Practice pressure undeployment w/same assy/conditions 23:30- 00:00 0.50 CLEAN N SFAL DECOMP Replace O-ring in CTC 4/23/2002 00:00- 00:30 0.50 CLEAN N SFAL DECOMP Fin fix O-ring seal failure on BHI CTC. PT 20k, 3000 psi 00:30- 01:10 0.67 CLEAN N DFAL i DECOMP MU milling BHA (2.80" D331, 1.0 deg motor) 01:10-01:40 0.50 CLEAN N DECOMP RIHw/BHA#2(#1RR). PVT125. 10 ppg mud has mixed w/ .WB fluids so saved everything and calc 9.69 ppg system when blended 01:40- 02:30 0.83 CLEAN P DECOMP Continue RIH 02:30- 03:10 0.67 CLEAN P DECOMP Start pump at 7150'. Begin logging down at 150-300'/hr 1.5/3260/60L 03:10 - 04:10 1.00 CLEAN P DECOMP Tag and stall at PBD at 7232' CTD at 60L. Corr to 7222.0' PVT 151 Backream to 7200' while orient 90 deg to left. RIH 3'/min to 7222'. Repeat 3 times to catch 4 quadrants. Compare BHI log to SWS PPROF 10/23/01 and depths within a foot after correction (35.0' bit to gamma) 04:10- 05:10 1.00 CLEAN P DECOMP POOH for WS MW=9.66 avg 05:10- 05:40 0.50 CLEAN P DECOMP LD motor and mill. PVT 125 05:40 - 06:15 0.58 STWHIP ~ WEXIT Crew change & PJSM on M/U whipstock assy. 06:15 - 06:45 0.50 STWHIP ~ WEXIT M/U 3-1/2" TIW LSX whipstock to coiltrack & scribe tools. IRA tag to TOWS is 5.2' 06:45 - 09:00 2.25 S'I-WHIP 3 WEXIT Test coiltrack - OK. Open EDC & RIH whipstock BHA#3 @ 0.3bpm/750psi. Wt chk @ 5000' ,,- 15.5k. Continue RIH to 6200'. 09:00 - 09:35 0.58 STWHIP P WEXIT Log CCL @ 16fpm from 6200' to 6750' ~ looks like we're @ 17' shallower (did not correct). 09:35 - 09:50 0.25 STWHIP P WEXIT Continue RIH. Wt chk @ 7000' ~ 21.5k. Continue RIH to 7020'. 09:50 - 11:10 1.33 STWHIP P WEXlT Log GR tie-in @ 100fph from 7020' to 7160'. Correlated w th !CCL & made -3' correction to CTD. 11:10 - 11:25 0.25 S'I'WHIP P WEXIT RIH slowly & tag cmt retainer @ 7222.'7 with 300lbs. PUH, orient TF to 165R & RBIH to 7221.4' (1.3' above retainer). 11:25 - 11:30 0.08 STWHIP P WEXIT Close EDC. Pump @ 0.4bpm to 3400psi & set/release whipstock. TOWS @ 7212.7'. 11:30 - 12:45 1.25 STWHIPiP WEXIT Open EDC & POOH @ 1.1bpm & 2000psi. 12:45 - 13:10 0.42 STWHIP P WEXlT Tag up at surface. L/D whipstock running BHA. Printed: 4/30/2002 3:18:10PM PHILLIPS PETROLEUM CO. Page 3 of 12 Operations Summa Report Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC I Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4~23~2002 13:10 - 14:20 1.17 STWHIP P WEXlT M/U & scribe window milling BHA #4 with Wll 2.5deg fixed motor & 2.8" HCC DSM. 14:20 - 15:00 0.67 STWHIP P WEXlT RIH with window milling BHA#4. 15:00 - 15:05 0.08 STWHIP P WEXlT Tagged up on Gas Lift Mandrel at 2992'. Close EDC and bring pump on to try and work through. 15:05- 15:25 0.33 STWHIP P WEXIT Continue RIH 15:25 - 16:15 0.83 STWHIP P WEXIT Tagged up on another Gas Lift Mandrel @ 6200'. Orient to High Side and work down. Tag another at 6814'. 16:15 - 17:15 1.00 STWHIP N SFAL WEXIT Dowell pump Trips shorted out by NC Mechanic Repairing Gen #2. WO Dowell ET to come out and fix Pump Trips. Dowell Standards will not allow them to pump without Pump Trips. 17:15 - 17:45 0.50 S'I-WHIP ~ WEXIT Fin RIH. Dry tag TOW and corr-5.1'. Orient to desired TF 17:45 - 19:45 2.00 STWHIP ~ WEXIT Park at 7212.0', flag CT, and begin time milling the 3-1/2" tubing at 9 min/0.1' MW 9.69 'in' PVT 148 19:45 - 20:40 0.92 STWHIP ~ WEXIT 7213.3' 1.5/3360/165R 20:40 - 00:00 3.33 STWHIP ~ WEXIT 7214.0' 1.5/3370/170R Finally got a little wt loss and diff. Assume this is the 7". Pull stretch up 1' to 7213.0' and start time milling 7" casing by schedule 7213.0' 1.5/3210/174R 16.7k 7214.2' 1.5/3350/160R 9.2k 4/24/2002 00:00 - 02:40 2.67 STWHIP P WEXIT Continue time milling window from 7214.2' 02:40 - 03:25 0.75 STWHIP P WEXlT 7216.3' 1.4/3330/170R 6.7k PVT 140 03:25 - 04:30 1.08 STWHIP P WEXIT Exit of 7" occurred at 7217.0' Drill 10' of formation at 10-20'/hr 1.4/3240/170R 8.5k PVT 138 MW 'in' 9.67 ppg. Official window is 7213-7217' Probably the first window (definitely the first two string window) ever drilled without one stall! 04:30 - 04:40 0.17 STWHIP P WEXlT 7227.0' PUH backreaming 22k 1.4/3130 PV'I' 134 A few bobbles at 7217' and 7214'. See flag on depth at 7212' mill depth 04:40 - 05:00 0.33 STWHIP P WEXIT Park at 7200', SD pump, SI @ choke and monitor for 10 min, no press Open choke and monitor for flow 10 rain, none (good call Dan). BHI annular press correct for MW in hole 05:00 - 05:25 0.42 STVVHIP ~ WEXIT Ream window area w/one pass, clean, w/TF at avg 175R 1.5/3325. Open EDC. PVT 133 (all losses have been over shaker-metal shavings plugging 21 O's) 05:25 - 06:30 1.08 STWHIP P WEXIT POOH. Kick while tripping drill. Overpull at 6960' (GLM) 06:30 - 07:15 0.75 S'I'WHIP P WEXIT Tag up at surface, standby for no-flow test. No flow after 1/2 hour. Kick pumps on, well bore full. Took no fluid in 1/2 hour. 07:15 - 07:40 0.42 STWHIP~ P WEXIT Safety meeting prior to c/o BHA. 07:40 - 08:25 0.75 S'I'WHIP P :WEXIT Lay down motor from window milling BHA. Mill recovered in gauge, with some wear on gauge diamonds, and swirl pattern on face of mill. 08:25 - 09:50 1.42 STWHIP P WEXlT RIH with BHA #5 to dress window. 09:50 - 11:00 1.17 S'I-WHIP P WEXlT Tag up at flag, set depth to 7212', orient to 165R, close EDC, kick on pumps to 1.5 bpm, 1.5 out, pit vol 134 bbls. 3130 psi free spin at surface. Downhole free spin pressures, Annular Pressure=3764 psi, Inner Pressure = 4325 psi. 11:00 - 11:40 0.67 STWHIP 3 WEXlT Update at 11:00. On first down reaming pass thru window. At 7214.3'. Started seeing work right at 7212.0'. There was considerable work at 7214.1', and has been slow going since. 1.5/1.5/3120 psi, 134 bbls pit volume. Printed: 4/30/2002 3:18:10 PM PHILLIPS PETROLEUM CO. Page 4 of 12 Operations Summa Report Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4~24~2002 11:40 - 12:50 1.17 STWHIP p WEXlT Stopped seeing motor work at 7216..2', RIH tag up 7225', PU and back ream, still holding 165R tool face. Ream up and down at + and - 30 degrees from 165R. Did not see any motor work on any reaming passes after first down pass. 12:50 - 13:30 0.67 S'I'WHIP P WEXIT Dry drift window 2 times. Did not see any overpulls, or loss of weight. POOH for build section BHA. Pit vol = 134 bbls when trip OOH started. 13:30 - 14:15 0.75 SI'WHIP P WEXIT Stop at 3800' for choke/driller practice. Practice technique for maintaining a constant BHP when drilling. (New choke operator). 14:15 - 15:00 0.75 STWHIP P iWEXIT Continue POOH. 15:00 - 15:20 0.33 STWHIP P WEXIT Standby at surface for no flow check prior to doing BHA swap. No flow or loss observed. 15:20 - 16:35 1.25 S'I'WHIP P WEXIT Tag up, lay down BHA #5. Mill gauged at 2.78". PU BHA #6. 16:35- 16:40 0.08 S'I'WHIP N DFAL WEXIT RIH with build section BHA. (BHA #6). Shallow hole test failed. Apparent short in e-line system. PU to check out. 16:40 - 18:15 1.58 STVVHIP N DFAL VVEXIT Troubleshoot system. Found short in upper quick connect. BHI suspects water leaking out of cable conductor, and will need to cut cable and reahead. SVVS indicates that slack management is scheduled every 5 trips in the hole. Four trips have been made since last SM. Rig up to pump SM prior to building new cable head. 18:15 - 20:00 1.75 STWHIP N DFAL WEXIT Wait on SWS to bring new boots to location to attempt to keep wire dry while pumping slack management. Nordic gen #3 is sick due to hours/antifreeze in oil (supplies power to ops cab/BHI/MI/camp). Will swap to rig generators tomorrow. Requires rig electrician to wire leads to BHI unit 20:00 - 21:30 1.50 STWHIP N DFAL WEXIT PJSM. Stab onto well. Reverse circ 2.2/4100 two CT volumes by procedure. E-line quit moving at 2.5 bbls. Cut CT and found end of wire after 13'. Cut additional 9' CT (22' total) after finding first 9' of wire wet. Test and still no continuity so assume bulkhead 21:30 - 00:00 2.50 STWHIP N DFAL WEXIT Position reel and tear down bulkhead connection. Pull 3' slack and reconnect jumper. Put it back together 4/25/2002 00:00 - 01:45 1.75 STWHIP N DFAL WEXIT I Rehead collector end. PT 20k, 4000 psi. Check well for press, .none, hole full 01:45 - 02:00 0.25 STVVHIP N DFAL WEXIT Safety mtg re: pressure deployment 02:00 - 04:00 2.00 DRILL N DF^L PROD1 MU drilling BHA using pressure deployment on dead well with induced 100 psi. Found SL had jumped sheave and kinked. Cut off 70' and rehead. PT @ 1000~ (max pull) 04:00-04:20 0.33 DRILL N DFAL PROD1 RIH 100'. Open EDC. Circ CT volume to fin slack management. Test tool 04:20 - 05:40 1.33 DRILL P PROD1 RIH w/BHA #7 (2.3 deg motor, Hycalog bi bit) 05:40 - 06:15 0.58 DRILL Ip PROD1 Log down from 7150' 0.4/1050 PVT 134 Corr-8.0'. RIH thru window clean (and logging) at 165R. Close EDC. Tag at 7226.1' 06:15 - 06:30 0.25 DRILL P PROD1 Try to start drilling at 60L and motor in a bind. Ream hole to get started 1.5/3220/90L. Start new mud down hole 06:30 - 07:10 0.67 DRILL N DFAL PROD1 7726', 1.5/1.5/3160 psi. Getting very weak stalls, and no ROP. Free spin; CTP=3160 psi, IP=4100 psi, AP=3773 psi. SI pumps, AP=3422, IP=3427, WHP=0. Try cycling the EDC open then closed. Kick pumps on Free spin CTP=3230 psi at 1.5 bpm. RIH, get 200 psi motor work, will not drill off. Open Printed: 4/30/2002 3:18:10PM PHILLIPS PETROLEUM CO. Page 5 of 12 Operations Summary Report Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4~25~2002 06:30 - 07:10 0.67 DRILL N DFAL PROD1 EDC, establish circ pressure with EDC open. CTP=2873 psi, AP=3778 psi, IP=3808 psi. Shut EDC Free spin; CTP=3630 psi, IP=4364, AP=3808 psi. Tag bottom and put 200 psi extra CTP. Will not drill off. PU and free spin = 3750 psi. BHA not behaving normally. SI pumps, open EDC, continue mud swap. Will POOH after mud to bit and examine BHA for a washout. Note-Mud swap in progress, probably reason for changing free spins, but why won't it drill? 07:10- 07:30 0.33 DRILL N DFAL PROD1 Morning pre tour safety meeting. 07:30- 08:30 1.00 DRILL N DFAL PROD1 POOH 08:30 - 08:45 0.25 DRILL N DFAL PROD1 Tag up at surface, stand by for no flow test. Confirm no flow, and well did not take any fluid. 08:45 - 11:50 3.08 DRILL N DFAL PROD1 Troubleshoot BHA #7. PT CTC to 4000 psi, ok. Stack 500~ weight on CTC, PT again to 4000 psi, all is ok. Lay down BHA, PT to 3000 psi, passed ok. Examine motor. The bit was in perfect shape, no obvious signs of washouts in BHA. Motor turned easily by hand??? BHI indicates that this is the normal condition with extreme motors. Change out motor and EDC. Check BHA electrically. Found orienter not working. Change out orienter. Last good functional orienter is now in BHA. Re check BHA electrically. All passed ok. 11:50- 12:10 0.33 DRILL N DFAL PROD1 RIH with BHA#8. 12:10 - 12:15 0.08 DRILL N DFAL PROD1 Shallow hole test @ 725'. with EDC closed CTP=3437 free spin, AP=498 psi, IP=952 psi, all at 1.5 bpm. Shut down pumps, open EDC, CTP=2780 psi, AP=483 psi, IP=508 psi, rate=1.5 bpm. 12:15- 13:30 1.25 DRILL N DFAL PROD1 RIH with BHA#8. 13:30 - 13:45 0.25 DRILL N DFAL PROD1 Discussion with BHI, SVVS, BP about best way to proceed with drilling high dogleg interval just outside window while minimizing strain on orienter. (Last orienter available in Alaska at this time). 13:45 - 16:15 2.50 DRILL N !RREP PROD1 Dry tag at 7229.5', make -4.5' correction to 7225', last tag on last run after tie in. Generator 3 (SWS-Nordic) just went down. Waiting on electrician to get power to BHI unit from rig generator. 16:15 - 16:30 0.25 DRILL P PROD1 7225', Start drilling. Free spin 3850 psi 1.5/1.5, AP=4154 psi, IP=4647 psi. ROP=25 fph, Pit vo1=342 bbls. 16:30 - 17:00 0.50 DRILL N DFAL PROD1 Attempt to orient off bottom. Can't orient. Pick up into casing, 3erform some BHI magic, and orienter apparently works. 17:00 - 17:40 0.67 DRILL P PROD1 Attempt to return to drilling. Orient to 265 deg. Ease BHA down in open hole. Free spin CTP=3700 psi, AP=4120 psi, IP=4540 psi, 1.5/1.5. Run down from 2' outside window at 2 fpm. Tag up start drilling at 7225'. TF265 deg~~ properly in casing, but Iooki?_,,,Q~window. 1.5/!.5 CTP~3 ps_'.~ __.pit vo!=34_2__bbls. 17:40 - 17:45 0.08 DRILL P PROD1 7 ' lng ahead. 1.5/1.5/4100 psi. Drilling with 300 psi ~ back pressure on well now. Pump pressure 4700 psi. Trips .~ ~ ~ " set at 5000 psi. We are at the ragged edge with respect to ~.-~ pump pressure when drilling. There is room for only 300 psi · "~ additional motor work prior to hitting trips. Pick up to orient. Printed: 4/30/2002 3:18:10 PM Reference: 185-190 The preceding pages identify pages 1 of 12, 2 of 12 and et cetera, but only pages 1 through 5 are scanned. To alleviate any questions, pages.6 to 12 are not applicable to this Well File History. ( R~U I~ermffs ~o ur., omce Subject: KRU permits to BP office Date: Thu, 7 Mar 2002 15:19:05 -0900 From: "Dan Venhaus" <dvenhaus@ppco.com> To: tom_maunder~admin.state.ak.us CC: JohnsoMO@bp.com, "Michael B Mooney" <mmooney@ppco.com>, "R Marty Lemon" <rmlemon@ppco.com> Tom, The Kuparuk CTD program starting up in April consists of 3 wells: 3H-16A, 3C-04A, and 3M-29A. Well 3H-16A's permit was submitted by Phillips and has been approved. This well is a combination rotary/CTD sidetrack with the rotary part completed in November 2001 with Phillips' Nordic 3 rig. Wells 3C-04A, 3M-29A (and the 3H-16A extension) are to be drilled solely with BP's Nordic 1 CTD unit. BP's CT drilling serviCes are being provided to the operator Phillips vi~Se~rvic,e operation. As such, Phillips. authorizes the delivery ol~lil~d 3M-29A permits to BP (Terry Hubble)~ Phillips does request that BP provide a copy of the approved permits. If you need anything else, let me know. Dan Venhaus Phillips Alaska, Inc. .. CT Drilling Engineer 263-4372 work 230-0188 cell - - Forv~arded by Dan Venhaus/PPCO on 03~07~2002 02:36 PM .... "Johnson, Mark O" <JohnsoMO(~BP.COm> 03~06~2002 07:14 AM To: Dan Venhaus/PPCO@Phillips cc: Subject: KRU permits to BP office Dan, I was talking to Tom Maunder this morning. It does not look like he make a DOCTD meeting today and he will get back with me on an alteri~ate date. Tom needs a e-mail from you authorizing delivery of the Phillips operated well permits to the BP office (even though they originated from me) Content 1) Please send KRU CTD sidetrack permits to BP office (normal Terrie Hubble address) 2) Background on why they need to go to BP. (CTD is a shared service (BP & Phillips) with the rigs operated by BP, but sidetracking KRU wells.) 1 of 2 3/7/02 4:52 PM K[~U laerm~ to BP office 3) Throe well program in 2002 (list well names). Thx MOJ 2 of 2 3/7102 4:52 PM PHILLIPS ,Inc. 3c,04 ~ A Subsidia~ of PHILLIPs PETROLEUM COM~&NY Gas Mandre~NaNel (2992-~93, 0D:&018) Descript 0n ~--"-~e ] Top BoSom [ -~D Wt Grade ~hread CONDUCTO~ 16.000 ! 0 I 100 100 ~ 62.50 H~0 SURFACE ~0.755 ~ ~ [ ~ [ 2445 I 4550-~:5~ 1 OD:&018) Size Top Bottom ~ ~D ~ Wt Grade ~ Thread G~U8 lnte~al ~D ~ Zone Status Ft SPF Cate ~ypeI Comment Ma~relNaive 7175-7201 65~529 ~C-~i~B - 26 12 [ 10/3/~5 ~P~RF 5" Csg gun;120 d~"~ ~2"~4-- 6674-6688 A-3 (5~ ~ [ ~6/96 RPERF~I)~"~J;~80de~ph+-90 rJ-/ - ~fr ~ Type L I i _' Run I 1 / 2992 29921 Camco ~ MMM i / GLV 10 ~ RK ~ 0188 t303 82896 ~ 3 J'6~8~ 58~q~amco F MMM I [-GEV 10 RK 0~ 1336 ~ [~_~ ~ ~4 6605 6100~ Camco MMM i ~ DMY~ ~00~ ~5 F ~_.[ 6960 6355 Camco MMM " I OV 1.0 0~~'~ 6(6~6~1, Str'MD l~DI Man Man VMfr 'VType VODILatch Po~ TRO= Date '~ Vv o~:~0~> IMfr Type / i/: Run (70~4-7015, ~ff~L~D L T~e ~ Description I ID ~ i 7028 ~ 6404 PKR ~F~FHL' J 3 000 (717&7281) (7282-7263, ID:2.992) S"i'AI'E OF ALASKA COMIV~ION ALASKA~L AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVAL Return Approved to BP CT Drilling 1. Type of Request: 2. Name of Operator Phillips Alaska Inc. 12. Sa Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 420' SNL, 1402' WEL, SEC. 14, T12N, R09E, UM At top of productive interval 1334' NSL, 1168' WEL, SEC. 11, T12N, R09E, UM At effective depth 1659' NSL, 1147' WEL, SEC. 11, T12N, R09E, UM At total depth 1730' NSL, 1144' WEL, SEC, 11, T12N, R09'~, UM, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 7670' feet 6864 feet 7568 feet 6791 feet Length Plugs (measured) Junk (measured) Size 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum ElevatiOn (DF or KB) RKB = 85' 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3C-04 9. Permit Number 185,190 10. APl Number 50- 029-21416-00 11. Field and Pool Kuparuk River Oil Pool 100' 2445' 7650' Cemented 16" 183 sx Coldset II 10-3/4" 1050 sx PF 'E', 380 sx PF 'C' 7" 380 Sx pF 'E', 250 sX Class 'G', 250 sx pF 'C' Perforation depth: measured 7175'- 7201', 7400' - 7424', 7435' ~ 7448' ' true vertical 6510' - 6529', 6671' - 6688', 6696' - 6705' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 7268' MD TVD 100' 100' 2~4~ 2445' 7650' 6850' RECEIVED Alasi~a Oil & Gas Coos. Commission Packers and SSSV (type and measured depth) Baker 'FHL' packer at 7028'; Baker 'DB' packer at 7245'; 3-1/2" Camco DS Landing Nipple at 500' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation Mamh 12, 2002 16. If proposal was verbally approved Name of approver Date Approved contact Engineer Name/Number: Mark Johnson, 564-$666 [] Detailed Operations P.r.~gram. I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Prepared By Name/Nurnbec Terrie Hubble, 564.4628 17, I hereby certify Signed Mark Johnson correct to the best of my knowledge Title CT Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test '~.. Location clearance ~ Approval NO....~t.)O( ' (~ Mechanical Integrity Test Subsequent form required 10- {'t,(~)~'"'~ ' order of the Commission Original Signed By Commissioner Date Form 10-403 Rev. 06/15/88 ~' ~=?l'~'~l?ll~'~k'l /~, I ~"~! ~,]~<'/~'"~/:J,V ~'P Submit U IL3/I I L Tally Length Depth Baker =HE 7 15' 7046 Camco GLM 20.1' 7084 2its 3-1/2" 62.63* 7104' tbg ELM 7029' 7036' 7067 7087 GLM 3C 04 P&A Schematic detai & proposed 3C ' -O4A Sidetrack et TOC near GLM at 7067' ELM } of 2 3/8" sidetrack liner at -7130' 3-1/2" Blast 31 4' 7167' 7150' Joint 3-I/2" Blast 307 7198' 7181' Joint C sand pe~o~tions 7175'-7201' ELM 3 1/2" tubing x 7" casing annulus filled with t7 ppg cement from tubing tail plug to near GLM at 7067" at--7220' ELM 3-1/2" PUP Jt 20.3' 722¢ 7212' EZSV cement retainer at 7230' ELM Baker CMU 3,82' 7249' 7232' Circulation holes 7238~7240' ELM 3~t/2" Pup Jt 6.11 7253' 7236! 3-112" x 2-7/8" XO 1 82' 7259' 7242' Baker Locator sub 1,0' 7261~ 7244' Baker DB Packer 365' 7262' 7245' Baker SBE 4, 35' 7266' 7249' Baker XO 0,65' 7270' 7253' 2-7/8" Pup Jt 8.11' 7271' 7254' Otis XN Nippte 1.10' 7279' 7262' 2-7/8" Pup Jt 4.06' 7280' 7263' 2-7/8" Tail 7285" 7268' Tubing tail plug set at 7262' ELM Proposed 3C.O4A Sidetrack 2 3/8" 4.6~¢ STL L-80 pre~driited liner MOJ 2/27/02 564~5666 o~ce 240~803~ cell A-ser~d Perforations 7400' - 74,¢~' ELM 00000 O0000 6 4 3 2 COILED TUB].NG UNIT 80P EOUIPHENT 1. 5000 PSI ?" W~LLHr. AD CONNECTOR IrLANG£ 2. 5000 PSI 4 1/16" PIPE RAUS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUffiNG BOX 4 3 , N]REL),NE, BOP EOiU ] PHENT 1. ~>OO0 PSI 7" WELLHEAD CONN£C1OR rLANG ~. 50D0 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" fLOW TUBE PACK-Orr STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 420' FNL, 1404' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1381' FSL, 1165' FEL, Sec. 11, T12N, At effective depth 1660' FSL, 1149' FEL, Sec. 11, T12N, At total depth 1731' FSL, 1146' FEL, Sec. 11, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 7 6 7 0 true vertical 6 8 6 3 feet feet 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit 8. Well number 3C-04 9. Permit number/approval number 85-190 10. APl number 50-029-21416-00 1 1. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 7 5 6 8 true vertical 6790 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 241 0' 9 - 5 / 8" Intermediate Production 7617' 7" Liner Cemented Measured depth True vertical depth 183 Sx CS II 1 00' 1050 Sx PF E & 2445' 380Sx PFCw/100SxPFCtopjob 380 Sx PF E & 7650' 250 Sx Class G, & 250 Sx PFC 100' 2445' 6849' Perforation depth: measured 7175'-7201', true vertical 6509'-6527', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7267' Packers and SSSV (type and measured depth) 7400'-7424' 6670'-6687' 7435'-7448' 6695'-6704' ...':, eR ] $ 1997 Pkr's: Baker FHL @ 7028' & Baker DB @ 7245'; SSSV: None, nipple @ 500' 13. Stimulation or cement squeeze summary Ala$~.a .0il & Gas Cons. C0[~m[ss Reperforate "A3" sand on 8/6/96 Anch0rag~ Intervals treated (measured) 0RI61NAL 7404'-7424' Treatment description including volumes used and final pressure Perforated using 2 1/8" EJ w/ BH charges, 4 SPF, 180° phasing, +/- 90° f/ Iow side, fp was 400 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 179 87 I 1150 135 Subsequent to operation 179 87 I 1150 135 15. Attachments . Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10;404 ~ev 06/15/8~ Title Wells Superintendent Date 4-(~- 9"/ SUBMIT IN DUPLICATE ARCO Alaska, Inc. ,.. ~' ~,~KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3C-04(W4-6)) WELL JOB SCOPE JOB NUMBER 3C-04 FRAC, FRAC SUPPORT 0804961337.4 DATE DAILY WORK UNIT NUMBER 08/06/96 RE-PERF 'A3' SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes (-~ No (~) Yes ~ No SWS-BAILEY PAIGE FIELD AFC~ COif DAILY COST AOOUM COST Si¢~_.e c~ (] .__.~. ESTIMATE KM1417 230DS36CL $10,064 $12,101 - Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann 1 Final Outer Ann 400 PSI 400 PS! 1250 PSI 1250 PSI1 275 PSI[ 275 PSI DAILY SUMMARY. REPERF 'A3' SAND F/7404'-7424' (REF GR DATED 8/27/85) USING 2-1/8" EJ W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED +/- 90 DEG F/LOWSIDE TIME LOG ENTRY 13:00 MIRU SWS. HELD SAFETY MTG. 14:00 FINISH IR/U---GET RADIO SILENCE---ARM 2 1/8" EJ BH, 20', 2SPF 14:15 P/T TO 2500 PSI--RIH WITH GUN-CCL-2" HD WT--90 DEG ORIENTATION AT 2 SPF AND 0 DEG PHASING. 15:00 TIE IN TO SWS CET LOG DATED 9/22/85--STOP AT 7399.7' TO SHOOT FROM 7404 TO 7424'--- SHOT AND HAD POSITIVE INDICATION AT SURFACE. DEPTH INITIALIZED TO ZERO AFTER STOPING AT PERF STOP DEPTH. HAD NEGATIVE DEPTH WHILE POOH. 15:45 AT SFC WITH DESCENT #1--ARM DESCENT #2 16:00 P/T TO 2500 PSI 16:15 RIH W/2 1/8" EJ BH GUN ORIENTED AT270 DEG--2 SPF 17:00 TIE-IN AND SHOOT 7404' TO 7424' WITH 270 DEG ORIENTATION AT 2 SPF.---POOH. 18:00 CCH---START R/D 19:00 'FINISH R/D---LEAVE LOC. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $45.00 HALLIBURTON $0.00 $972.00 LR-~LE RED $0.00 $1,020.00 SCHLUMBERGER $10,064.00 $10,064.00 TOTAL FIELD ESTIMATE $10,064.00 $12,101.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Addres's P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service Location of well at surface 420' FNL, 1404' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1381' FSL, 1165' FEL, Sec. 11, T12N, R9E, UM At effective depth 1660' FSL, 1149' FEL, Sec. 11, T12N, R9E, UM At total depth 1731' FSL, 1146' FEL, Sec. 11, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7670 6863 feet feet 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit 8. Well number 3C-04 9. Permit number/approval number 85-190 10. APl number 50-029-21416-00 1 1. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 7 5 6 8 true vertical 6 7 9 0 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' I 6" Surface 241 0' 9 - 5 / 8" Intermediate Production 7617' 7" Liner ._ Cemented Measured depth True vertical depth 183 Sx CS II I 00' 1050 Sx PF E & 2445' 380Sx PFCw/100SxPFCtopjob 380 Sx PF E & 7650' 250 Sx Class G, & 250 Sx PFC 100' 2445' 6849' Perforation depth: measured 7.175'-7201', true vertical 6509'-6527', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7267' Packers and SSSV (type and measured depth) Pkr's: 7400'-7424', 6670'-6687', 7435'-7448' 6695'-6704' Baker FHL @ 7028' & Baker DB @ 7245'; SSSV: None, nipple @ 500' 13. Stimulation or cement squeeze summary Refracture "A" sands on 8/23/96 0RI61NAL Intervals treated (measured) 7400'-7424', 7435'-7448' Treatment description including volumes used and final pressure Pumped 77.4 M lbs 20/40 and 12/18 ceramic proppant into formation, fp was 7200 psi. 14. Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 41aska 0il & 6as Cons. Corem Anchorage Tubing Pressure Prior to well operation · · Subsequent to operation 179 87 1 115O 228 176 72 1203 135 161 15, Attachments . Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404(JRev 06/1~'/88 Title Wells Superintendent Date 4-9-9'7 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~ WELL SERVICE REPORT ~' K1(3C-04(W4-6)) WELL JOB SCOPE JOB NUMBER 3C-04 FRAC, FRAC SUPPORT 0804961337.4 DATE DAILY WORK UNIT NUMBER 08/23/96 'A' SAND RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOP2~j 6 (~) Yes O No (~) Yes O No DS-GALLEGOS P. ENR(~,,,/ FIELD AFC# CC,~ DALLY COST ACCUM COST Signg¢~'/,,~ .,~//~ ESTIMATE KM1417 230DS36CL $92,450 $132,472 Initial Tbq Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I/P1'n"al Outer Ann 470 PSI 0 PS! 150 PSI 500 PSII. 0 PSIr 600 PSi DALLY SUMMARY RE-FRAC'D 'A' SAND - SCREENED OUT EARLY W/77,403 LBS PROPPANT BEHIND PIPE AND 16,894 LBS LEFT IN WELLBORE @ 8 PPA. USED 8,519 LBS OF 20/40 AND 81,778 LBS 12/18 PROPPANT. TIME LOG ENTRY 08:30 MIRU DOWELL PUMPING EQUIP AND APC/LRS SUPPORT EQUIP. WORK UP AND QC FLUIDS. PRESSURE UP BACKSIDE TO 500 PSI. 10:25 HOLD PRE-JOB SAFETY MEETING, PRIME PUMPING EQUIP. REPAIR LEAKY TRANSDUCER. SET TREE SAVER, PRESSURE UP BACKSIDE TO 1,500 PSI. PRESSURE TEST LINES TO 10,000 PSI. 11:15 PRESSURE UP BACKSIDE TO 3,300 PSI. START PUMPING BREAKDOWN/CONDITIONING STAGE. PUMP 101 BBLS 50# DELAY XL GW @ 15 BPM, FOLLOWED BY 99 BBLS STRAIGHT WATER FLUSH. 11:30 FINISH BREAKDOWN/CONDITIONING STAGE, S/D. FFP = 4,615 PSI, ISIP = 3,400 PSI. MONITOR WHP. 12:00 WHP = 1,600 PSI. START PUMPING DATAFRAC. PUMP 59 BBLS 50# DELAY XL GW @ 5 BPM FOLLOWED BY 15 BBLS STRAIGHT WATER @ 5 BPM AND FLUSHED W/50 BBLS STRAIGHT WATER @ 10 BPM. 12:20 FINISH DATAFRAC, S/D. FFP - 4,400 PSI, ISIP - 3,608 PSI. MONITOR WHP. 14:13. START PUMPING FRAC. PUMP 74 BBL PAD: 50# DELAY XL GW @ 5 BPM. 14:25 INCREASE RATE TO 10 BPM AND PUMP 51 ADD'L BBLS OF PAD. 14:30 ADD 2 PPA 20/40 PROPPANT AND PUMP 100 BBLS @ 10 BPM. 14:42 SWITCH TO 12/18 PROPPANT AND PUMP 400 BBLS @ 10 BPM WHILE RAMPING PROP CONC FROM 2 PPA TO 8 PPA. 15:20 HOLD 12/18 PROP CONC FLAT @ 8 PPA AND PUMP @ 10 BPM. 15:30 S/D. SCREENED OUT W/63 BBLS OF FLAT 8 PPA 12/18 PROPPANT PUMPED. RDMO DOWELL AND APC/LRS. 18:00 WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $150.00 APC $1,600.00 $6,840.00 ARCO . $277.00 $582.00 BAKER OIL TOOLS $0.00 $1,310.00 DOWELL $88,263.00 $102,422.00 HALLI BURTON $0.00 $5,854.00 LI-i-rLE RED $2,310.00 $5,250.00 SCHLUMBERGER $0.00 $10,064.00 TOTAL FIELD ESTIMA'I;E $92,450.00 $132,472.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3C-04(Permit No. 85-190) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 3C-04. The original 2-7/8" selective single completion was pulled and the wellbore was cleaned out. A 3-I/2" x 2-7/8" selective single completion was re-run. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Petroleum Engineering WSI/skad FEB 1 4 1996 Alaska Oil & Gas Cons, Commission Anchorage ORIGINAL STATE OF ALASKA "-"~ ALASH,~ OIL AND GAS CONSERVATION COMMIL,..,ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS F-I SUSPENDED r--] ABANDONED r--[ SERVICE [---] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 85-190 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 --~- 50-029-21416 4 Location of well at surface .I,,C~T~ ~[ 9 Unit Or Lease Name 420' FNL, 1402' FEI_, Sec. 14, T12N, R9E, UM · ~t Kuparuk River Unit At Top Producing Intervalti~,~,--~~' 10 Well Number , 3C-04 At Total Depth ~ 11 Field and Pool 1731' FSL, 1146' FEL, Sec 11, T12N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 85'I ADL 25629 ALK 2562 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions Au~tust 16, 1985 August 27, 1985 22-Dec-95 (recompleted)I NA feet MSLI 2 17 Total Depth (MD+TVD) 18 Plug Back DepIh (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thlckness of permafrost 7670' MD & 6863' TV D 7568' MD & 6790' TVD YES [._J NO IX]I NA feet MDI = 1380' ss APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE wrr GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 60.5# H-40 SURF. 100' 24" 183 sx CS II 10.75" 45.5# J-55 SURF. 2445' 13.5" 1050 sx PF "E" & 380 sx PF "C" 7" 26# J-55 SURF. 7650' 8.5" 380 sx PF "E", 250 sx Class G, & 250 sx PF "C" I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET !MD) 3.5" 7259' 7046' 7175'-7201' M D 12 spf 6509'-6528' TVD 2-7/8" 7285' 7262' 7400'-7424' MD 4 spf 6670'-6687'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7435'-7448' MD 4 spf 6695'-6704"I'VD DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED A' sands 16000# of 20/40, 130107# of 12/18 123607# behind pipe, 22500# of 10 ppa in tb[l, left 10 ppa of 12/18 @ perfs 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORiCINAL Alaska Gl & Gas Cons Form 10-407 Submit in duplicale Rev. 7-1~80 CCNTINUEDON REVERSE SIDE 29 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7102' 6458' Bottom Kuparuk C 7199' 6527' Top Kuparuk A 7381' 6657' Bottom Kuparuk A 7514' 6753' FEB 1 4 1996 Alaska Oil & Gas Cons. Comrnissim~, Anchorage 31. LIST OF AI-rACHMENTS Daily Drilling History 32. I hereby certif~ that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/9/96 t . ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3C-04 RIG:NORDIC WELL ID: 998477 AFC: 998477 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/16/85 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ OM/ API NUMBER: 50-029-21416-00 OM 12/13/95 (1) TD: 7670' ?B: 7568' SUPV:DEB DAILY: 12/14/95 (2) TD: 7670' PB: 7568' SUPV: DEB DAILY: 12/15/95 (3) TD: 7670' PB: 7568' SUPV:DEB DAILY: 12/16/95 (4) TD: 7670' PB: 7568' SUPV:DEB DAILY: 12/17/95 ( 5) TD: 7670' PB: 7568' SUPV:DEB DAILY: 12/18/95 (6) TD: 7670' PB: 7568' SUPV:DEB DAILY: 12/19/95 ( 7) TD: 7670' PB: 7568' SUPV: DEB DAILY: RU TO PULL VR PLUG MW: 0.0 Move rig from 3C-13 to 3C-04. Accept rig @ 0100 hfs, 12/13/95. $19,600 CUM: $39,200 ETD: $0 EFC: $39,200 TESTING BOPE MW:10.3 Load tubing with 8.5+ ppg sea water. Shut-in and monitor well, Freeze protect flowline. Kill well with 10.3 ppg mud. Monitor well - no flow, no loss. Well dead. Set BPV. N/D tree. NU BOPE. Test BOPE. $33,613 CUM: $106,426 ETD: $0 EFC: $106,426 CBU & ClRC OUT GAS CUT MU MW: 0.0 Pull 2-7/8" tubing hanger. RIH with FTA #1. Tag and catch top of fish @ 6987'. $38,037 CUM: $182,500 ETD: $0 EFC: $182,500 RIH WITH FTA %3 MW:10.4 POH with FTA %1 and fish. Recovered all fish thru first tubing cut. RIH with FTA %2. Tag fish @ 7130' and latch up on fish. POH with FTA %2. Recovered all fish thru second tubing cut. RIH with FTA %3. $38,837 CUM: $260,174 ETD: $0 EFC: $260,174 POH WITH FTA %4 MW:10.5 RIH with FTA %3. Tag top of fish tubing stub @ 7211'. Latch onto fish. Work pipe and jar, attempting to free fish. POH with FTA %3. RIH with FTA %4. Wash down over top of fish @ 7211' to sand fill @ 7250', wash out fill to 7261', ream and wash out fill to packer @ 7275' (25' fill). POH with FTA %4. $34,588 CUM: $329,350 ETD: $0 EFC: $329,350 RIH WITH FTA#6 (PACKER MI MW:10.5 POH with FTA %3. POH with FTA %4. RIH with FTA %5. Latch onto top of tubing stub @ 7211' and pulled seals out of 'WD' packer. POH with FTA #5 and fish. Recovered +/-25' stub of 2-7/8" tubing. Tubing was buckled. RIH w/FTA %6. $33,603 CUM: $396,556 ETD: $0 EFC: $396,556 PUMP SLUG FOR POH MW:10.6 RIH with FTA %6. Mill on 'WD' packer. POH with FTA#6. RIH with FTA #6. Mill on packer, packer came free and moved down hole. Chased packer down to 7331' $34,816 CUM: $466,188 ETD: ~0 EFC: $466,188 Date: 2/9/96 ARCO ALASKA iNCORPORATED WELL suMMARY REPORT Page: 2 12/20/95 (8) TD: 7670' PB: 7568' sUPV: BP DAILY: 12/21/95 (9) TD: 7670' PB: 7568' sUPV: BP DAILY: 12/22/95 (10) TD: 7670' PB: 7568' sUPV: BP DAILY: 12/23/95 (11) TD: 7670' PB: 7568' sUPV: BP DAILY: End of WellSummary for We11:998477 MW:10.4 RIH w/CLEANOUT ASSY RIH with spear. POH with fish. Recover packer RIH with cleanout BHA. $0 EFC: $532,916 $33,364 CUM: $532,916 ETD: MW:10.5 late well POH w/SWS WL ' Wash and ream to 7555'. Bit stopped - hard Circu clean. Recovered large amount of frac sand RIH with guage ring and junk basket to 7350'. RIH and set packer with top $0 EFC: $598,164 @ 7245' $32,624 ~UM: $598,164 ETD: MW:10.5 POH w/CLEANOUT ASSYPOH Run 3-1/2" completion- Hit ice plug @ 178'. w/completion assy. RIH with casing scraper. Circ thru approx. 50' of ice. POH. $0 EFC: $748,266 $75 051 CUM: $748,266 ETD: , MW: 0.0 RIG RELEASED jewelry, sting into perm. packer and RIH with tubing and space out. Pressure tubing to 2500 psi for 1/2 hour to set pkr. Test tree to 250/5000 psi for 15 min. Test packoff to 5000 psi. Freeze protect annulUs. Secure well. Rig released @ 0600 hrs. 12/23/95. $0 EFC: $1,106,820 $179,277 CUM: $1,106,820 ETD: FEB 1 4 199G Alaska Oil & Gas Cons, Oommissio~ Anchorage STATE OFALASKA 0 Ii~ ! G } ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 420' FNL, 1402' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1381' FSL, 1165' FEL, Sec. 11, T12N, R9E, UM At effective depth 1658' FSL, 1149' FEL, Sec.11, T12N, R9E, UM At total depth 1731' FSL, 1146' FEL, Sec. 11, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3C-04 9. Permit number/approval number 85-190 10. APl number 50-029-21416 11. Field/Pool Kuparuk River Oil Pool Length 69 2414' 7670' 6863' 7568' 6790' Size 1 6" 9 5/8" 7619' 7" measured feet feet feet feet 7175'-7201', 7400'-7448' true vertical 6509'-6528', 6671 '-6705' Plugs (measured) Junk (measured) Cemented Measured depth 183 Sx CS II I 00 1050 Sx PF E & 2445' 380 Sx PFC 380SxClassPFE& 7650 250 Sx Class G & 250 sx PFC True vertical depth 100 2445' 6827 Tubing (size, grade, and measured depth) 2-7/8 .... J-55 w/ tbg tail at 7313 Packers and SSSV (type and measured depth) Camco HRP @ 7013', Otis WD @ 7284', Camco SSSV @ 1816' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7400'-7448' Treatment description including volumes used and final pressure See attached RECEIVEO BEP 2 ? 1991 Alaska Oil & 6as Cons, Comml t t 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -250- -125- 0 1100 -250- -125- 0 1100 Tubing Pressure 110 110 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as.' Water Injector__ Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,~ned '/~~~)' ~ Title ~-/~ 0~ Fnrm I n-4134 R~.v n.q/1P/.qn RDate ~ '-~-~[ "" ~/ I IRMIT IN r31 Ipl I~,ATI: WE'LL" ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company PBDT 'RACTOR REMARKS FIELD- DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPORT IDAY~ iDATE SEP 2 ? t99i Alaska 0il & ~las Cons. 7~ncn0rag. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ' 1 Weather i Temp. i Chill Factor Visibility I Wind Vel. Report , °F ' °F miles I I Signed knots! ARCO Alaska, Inc. Post Office Box 1003.80 Anchorage, Alaska 99510-03,30 _~eiephone 907 276 i215 August 8, 1988 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-4 Core Descriptions Dear Mr. Chatterton' Enclosed are copies include with the Well call me at 263-4944. of the 3C-4 Core Descriptions (Ugnu & West Sak) to Completion Report. If you have any questions, please Sincerely, J. Gruber Associate Engineer JG'hf Enclosures cc' 3C-4 Well File GRU14/020c ARCO Alaska, Inc. is a Subsidiary of At]anticRichfieldCompany ARCO ALASKA, INC. KRU 3C-4 CORE CHIP DESCRIPTIONS(WEST SAK) DEPTH(MD) DESCRIPTION SEC. 14, T12N, R9E, U.M. CONFIDENItAL 3270 3273 3276 3279 3282 3285 3288 3291 3294 3297 3298.5 3304 3307 3310 3313 3316 3319 3322 3325 3327 3330 3333 3336 3339 3342 3345 3348 3351 3354 3357 3361 3364 3367 3370 3373 3376 3379 3382 3385 3388 3391 3394 3397 3400 3403 3406 3¢09 3414 SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, CEMENTED WITH'CALCITE, NO POROSITY, NO OIL STAIN SANDSTONE, CEMENTED WITH-CALCITE, NO POROSITY, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, POROUS, NO OIL STAIN .. SANDSTONE, POROUS, NO OIL STAIN SANDSTONE, SILTY, CLAYEY, SOME POROSITY, NO OIL STAIN SANDSTONE, SILTY, CLAYEY, SOME POROSITY, NO OIL STAIN SANDSTONE, SILTY, CLAYEY, SOME POROSITY, NO OIL STAIN SANDSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, NO OIL STAIN MUDSTONE, SANDSTONE, SOME POROSITY, SOME OIL STAIN MUDSTONE, SANDSTONE, SOME POROSITY, SOME OIL STAIN MUDSTONE, SANDSTONE, SOME POROSITY, SOME OIL STAIN MUDSTONE, SANDSTONE, SOME POROSITY, SOME OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN MUDSTONE, SILTSTONE, SOME POROSITY, SOME OIL STAIN SILTSTONE, SOME POROSITY, NO OIL STAIN SILTSTONE, SOME POROSITY, NO OIL STAIN SILTSTONE, SOME POROSITY, NO OIL STAIN SILTSTONE, SOME POROSITY, NO OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, SILTY, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, CLAYEY, SOME POROSITY, OIL STAI~ SILTSTONE, CLAYEY, SOME POROSITY, OIL STAI E~E~\'/ED SANDSTONE, POROUS, OIL STAIN MUDSTONE, SILTY, SOME POROSITY, OIL STAIN AUG1"' MUDSTONE, SILTY, SOME POROSITY, OIL STAIN Alas~ Oil & ~s Cons. Gom~'iss'~°~i 3420 3423 3426 3429 3432 3435 3438 3440 3443 3446 3449 3452 3455 3458 3461 3464 3467 3470 3471 3475 3478 3481 3484 3487 3490 3493 3496 3499 3503 3506 3509 3512 3515 3518 3521 3523 3525 3528 3531 3534 3536 3539 3542 3545 3548 3549 3552 3555 3558 3561 3564 3565 3567 SILTSTONE, MUDSTONE, MUDSTONE, SANDSTONE, SANDSTONE, SILTSTONE, SANDSTONE, SILTSTONE, SILTSTONE, MUDSTONE, SILTSTONE, SILTSTONE, SILTSTONE, MUDSTONE, SILTSTONE, SILTSTONE, SANDSTONE, SANDSTONE, SILTSTONE, SANDSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, MUDSTONE, MUDSTONE, SANDSTONE, SANDSTONE, SANDSTONE, SANDSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SANDSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SILTSTONE, SANDSTONE, SANDSTONE, SANDSTONE, SANDSTONE, SANDSTONE, SILTSTONE, MUDSTONE, SANDSTONE, MUDSTONE, SOME POROSITY, OI ANDSTONE, SOME PO ANDSTONE, SOME PO POROUS, OIL STAIN POROUS, OIL STAIN LITTLE POROSITY, POROUS, OIL STAIN SANDSTONE, POROUS SANDSTONE, POROUS L STAIN ROSITY, ROSITY, SOME OIL SOME OIL NO OIL STAIN , OIL STAIN , OIL STAIN ILTY, SOME POROSI SANDY, POROUS, OI SANDY, POROUS, OI SANDY, POROUS, OI OME POROSITY, NO SANDY, SOME POROS SANDY, SOME POROS POROUS, OIL STAIN POROUS, OIL STAIN SANDSTONE, SOME P POROUS, OIL STAIN TY, L STAIN L STAIN L STAIN OIL STAIN ITY, SOME ITY, SOME SOME OIL STAIN OIL STAIN OIL STAIN STAIN STAIN OROSITY, SOME OIL STAIN CLAYEY, POROUS, OIL STAIN CLAYEY, POROUS, OIL STAIN CLAYEY, POROUS, OIL STAIN CLAYEY, SOME POROSITY, SOME OIL STAIN CLAYEY, SOME POROSITY, SOME OIL STAIN SOME POROSITY, NO OIL STAIN SOME POROSITY, NO OIL STAIN POROUS, OIL STAIN POROUS, OIL STAIN SILTY, CLAYEY, POROUS, OIL STAIN SILTY, CLAYEY, POROUS, OIL STAIN SANDY, POROUS, OIL STAIN SANDY, SOME POROSITY, SOME OIL STAIN SANDY, SOME POROSITY, SOME OIL STAIN SANDY, CLAYEY, SOME POROSITY, SOME OIL SANDY, SOME POROSITY, SOME OIL STAIN CLAYEY, LITTLE POROSITY, NO OIL STAIN CLAYEY, LITTLE POROSITY, SOME OIL STAIN CLAYEY, LITTLE POROSITY, SOME OIL STAIN POROUS, OIL STAIN CALCITE CEMENTED, LITTLE POROSITY, SOME CALCITE CEMENTED, LITTLE POROSITY, NO SOME POROSITY, NO SOME POROSITY, NO POROUS, OIL STAIN POROUS, OIL STAIN SILTY, POROUS, OIL STAIN SILTY, POROUS, OIL STAIN SILTY, POROUS, OIL STAIN CLAYEY, SOME POROSITY, NO OIL SOME POROSITY, NO OIL STAIN SILTY, POROUS, OIL STAIN SILTY, LITTLE POROSITY, NO OIL STAIN STAIN OIL STAIN OIL STAIN STAIN OIL STAIN OIL STAIN ARCO ALASKA, INC. KRU 3C-4 CORE CHIP DESCRIPTIONS(UGNU) DEPTH(MD) DESCRIPTION SEC. 14, T12N, R9E, U.M. CONFIDENTIAL 2793 2796 2799 2802 2805 2808 2811 2814 2817 2820 2824 2827 2830 2833 2836 2839 2842 2846 2849 2852 2855 2858 2861 2864 2867 2870 2873 2875 2881 2884 2887 2890 2893 2896 2899 2902 2905 2908 2911 2914 2917 2920 2923 CLAY, NO OIL STAIN SILT, CLAYEY, LITTLE POROSITY, NO OIL STAIN SILT, CLAYEY, LITTLE POROSITY, NO OIL STAIN SILT, CLAYEY, LITTLE POROSITY, NO OIL STAIN SILT, CLAYEY, LITTLE POROSITY, NO OIL STAIN SAND, SILTY, CLAYEY, POROUS, NO OIL STAIN SILT, SAND, CLAY, POROUS, NO OIL STAIN SILT, SAND, CLAY, POROUS, NO OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, NO OIL STAIN SAND, POROUS, NO OIL STAIN SAND, POROUS, NO OIL STAIN SAND, POROUS, NO OIL STAIN COAL, NO OIL STAIN COAL, NO OIL STAIN MUD, SILTY, COAL, NO OIL STAIN SAND, SILT, CLAY, SOME POROSITY, SOME OIL STAIN CLAY, NO OIL STAIN SILT, CLAY, SAND, SOME POROSITY, NO OIL STAIN SAND, POROUS, OIL STAIN SAND, SILT, SOME POROSITY, SOME OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SILT, CLAY, SOME POROSITY, NO OIL STAIN COAL, NO OIL STAIN SAND, SILTY, CLAYEY, SOME POROSITY, NO OIL STAIN. CLAY, NO OIL STAIN SAND, POROUS, OIL STAIN SAND, CLAYEY, COAL, SOME POROSITY, SOME OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, NO OIL STAIN SAND, SILT, SOME POROSITY, NO OIL STAIN SILT, CLAY, SOME POROSITY, NO OIL STAIN SAND, POROUS, NO OIL STAIN CLAY, NO OIL STAIN SILT, SOME POROSITY, NO OIL STAIN SAND, CLAYEY, SOME POROSITY, SOME OIL STAIN SAND, POROUS, NO OIL STAIN ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date': January 28, 1988 Transmittal #: 7067 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. -'~ 3C-16 -~2U-15 ~ 1L-7 ~'p'lE-27 PBU Bottom-Hole Pressure Survey Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) KOE Falloff Analysis KOE Falloff Analysis 12-10-87 50-029-21416 8-26-87 FBHP 'A' Sand 7-3-87 Static 'C' Sand 12-21-87 Both Sands 12-31.-87 Both Sands Receipt Adknowledged: DISTRIBUTION: D & M State of Alaska Chevron Date: Mobil SAPC Unocal ARCO AJaska !:~c s ,~ $~_~src~, o! A:i,~ntjcR~ch!~eldCompan¥ ARCO Alaska, Inc, ~--. Date: March 11, 1986 Internal Correspond~e~0.~ce Subject: Documentation Request-Plugends For The State Of Alaska From W. Sak 3C-4 From/Location: T..'~~Gorup-i 0 0 To/Location: Barb Durfee @ 1' Intervals DEPTHS COMMENTS DEPTHS COMMENTS .. 2790.95-2797.95 2799.95-2808.95 2810.95-2831.75 2833.95-2875.2 2878.95-2913.95 2915.95-2923.95 .2925.95-2927.5 3270.85-3298.2 3301.85-3303.75 3305.25-3356.8 3358.3-3414.15 ~3417.35-3564.75 ~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office BOX- 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO: John Boyle DATE: AK Oil & Gas Conserv. Comm. 3001 Porcupine Drive Anchorage, Ak 99501 OPERATOR: ARCO SAMPLE TYPE: Plugends NAME: Mar. 20, 1986 W. Sak 3C-4 NUMBER OF BOXES: 1 Box See Attached List SHIPPED BY Paleo Lab Tech UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: PALEO LAB, ABV-100 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 3, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-4 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3C-4. questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw If you have any GRU13/L04 Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , , 2. Name of Operator 7. Permit Number ARCO A1 aska, ! nc. 85-190 3. Address - 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21416 4. Location of well at surface 9. Unit or Lease Name /+20' FNL, 1402' FEL, Sec.1/+, T12N, RDE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1381' FSL, 1165' FEL, Sec. 11, T12N, RDE, UM 3C-4 At Total Depth 11. Field and Pool 1731' FSL, 1146' FEL, Sec. 11~-T12N, RDE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etC.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25629 ALK 2562 12, Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/16/85 08/27/85 08/28/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PiugBackDepth(MD+TVD) 19. OirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 7670'MD, 6863'TVD 7568'MD, 6790'TVD YESI-~X - NO[] 1816 feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, RFT, DIL/SFL/GR/Cal/SP, FDC/CNL, CET, GCT, GST 23. CASING, LINER AND CEMENTING RECORD · i SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 60.5# H-40 Surf 100' 2/+" 183 sx CS II 10-3//+" /+5.5# K-55 Surf 24/+5'" 13-1/2" 1050 sx PF "E" & 380 s: PF "C" Top job performed w/10t sx PF "C" 7" 26.0# J-55 Surf 7650' 8-1/2" 380 sx PF "E", 250 sx lass G, & 250 sx PF "24. Perforations open to Production (MD+TvD of Top and Bottom and 25. TUBI'NG RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7400' - 7/+2/+' w/4 spf 2-7/8" 7312' 7013' & 7285' 7/+35' - 7448' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7175' - 7201 ' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addeldum, dated 12/11/85 for frac data. . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I " Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO iTEST PERIOD ~ FIo~ Tubing CaSing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAV'ITY-API (corr) Press. '24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chipsl To be submitted when received from Geology Dept. i''~, ~" ? , ..' ': ~ ("~."3 [~il~, b(.):~',lili:.~,;b,'' (j.,( , . ..~, .-~ Form 10~{07 * NOTE: Tubing was run and the well was perforated 10/14/85. GRU12/WC15 Submit in duplicate - _ · · NAME '" Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C ' ' 7168:- 6504' SHUT-IN Base Kuparuk C 7200' 6527' DEPTH PRESS Top Kuparuk A 7389' 6662' Base Kuparuk A 7512' 6750' 3301' 1427 psi . 3307' 1430 psi : 3384' 1483 ps~ 3384' ..... 3384' 1484 psi 3/~34 ' ..... 3/+27 ' 3425 ' 1510 ps i 3495' .~ 3493' 1572 psi 3543 ' 1612 psi 3372' 1477 psi 3371 ' ..... 3384' 1476 psi 3371' 1469 psi 3288' 1417 psi · 31. LIs:T OF ATTACHMENTS ' · Addendum . · 32. I hereby-certify that the forego!rig is true and correct to the best of my knowledge Signed (~~ ~ Title Associate Engi neet Date // INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) 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". ADDENDUM 11/04/85 3C-4 Frac well w/203 bbls diesel, 1008# 100 mesh & 1500# 20/40 sand @ avg rate of 17 BPM, 4900 psi. Drillin§ ~uperintendent Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-4 Dear Mr. Chatterton- Enclosed is a Well Completion Report for the subject well. have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L113 Enclosure I f you ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany .----- STATE OF ALASKA "-" ALASKA .... L AND GAS CONSERVATION CC., !MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS I'-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-190 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21416 4. Location of well at surface 9. Unit or Lease Name 420' FNL, 1402' FEL, Sec.14, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1381' FSL, 1165' FEL, Sec. 11, T12N, R9E, UM 3C-4 At Total Depth 11. Field and Pool 1731' FSL, 1146' FEL, Sec. 11, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB 'I ADL 25629 ALK 2562 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ,15. Water Depth, ifoffshore 116. No. of Comp.etions 08/16/85 08/27/85 08/28/85wI IN/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7670'MD, 6863'TVD 7568'ND, 6790'TVD YES I~X NO []I 1816 feet MD 1700' (approx) 22. Type Electric or Other Logs Run D I L/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, RFT ~ D I L/SFL/GR/Cal/SP, FDC/CNL, CET ~ GCT, CST 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE imoP BO'I'TOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 60.5# H-40 Surf 100' 24" 183 sx CS II 10-3/4" 45.5# K-55 Surf 2445' 13-1/2" 1050 sx PF "E" & 380 s; PF "C" Top ,~ob performed w/10( sx PF "C" 7" 2'6.0# J-55 Surf 7650' 8-1/2" 380 sx PF "E", 250 sx (',lass G, & 250 sx PF" 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) 7400' - 74241'~,w/4 spf 2-7/8" 7312' 7013' & 7285' 7435 ' 7448 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7175' - 7201 ' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (C°rr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. To be submitted when received from Geology Dept. Form 10~07 * NOTE: Tubing was run and the well was perforated 10/14/85. TEMP2/WC60 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - ~EoLoGIC-MARK~R~ ' ~ ' : .... F~)R~ATIONTESTS:': NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7168'. 6504' 5HUT-IN Base Kuparuk C 7200" 6527' DEPTH PRE55 Top Kuparuk A -7389' 6662' Base Kuparuk A 7512' 6750' 3301' 1427 psi 3307' 1430 psi 3384' 1483 psi 3384' 3384' 1484 psi 3434' ..... 3427' ..... 3425' 1510 psi 3495 ' 3493' 1572 psi 3543' 1612 psi 3372' 1477 psi 3371 ' 3384' 1476 psi 3371 ' 1469 psi 3288' 1417 psi 31. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ .~~, Title Associate Engineer Date /~°-~"~' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Oil and Gas Company Daily Well History-Final Rel:~rt InSlll,~¢liona: Prepare and submit the "Final R~t~II" on the first Wednesday after allowable has Oeen assigned or well is Plugged. Abandonsd, or Sold. "Final Rel~rt" should be submitted also when operations are suspended for an indefinite or aopreciable length of lime. On workovsrs when an offiCial test is not required upon completion, report completion and representative test data in Olocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District klask~ IAccounting State cost center COOLS Field Kuparuk River Auth, or W.O. no. AF~- 604844 ICounty or Parish Lease or Unit Title North Slope Borough ADL 25629 Completion · _ a~aska IWell no. 3C-4 Roll'N 4 Operator I AR.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date Complete API 50-029-21416 W.I. ~rot&l number of wells (active or inactive) on this ~co~t center prior to Plugging and 56.24% labandonment of thi, well i Hour }Prior statul il S W.O. 10/12/85 [ 1330 hrs. Date and depth as of 8:00 a.m. 10112/85 thru lO/14/85 lO/15/85 Complete record for each day reported 7" @ 7618' General RU. 7" @ 7650' 7568' PBTD, TT @ 7312', RR Diesel Accept rig @ 13~0 hfs, 10/12/85. NU & tst BOPE. RU Schi, pelf w/5" gun, 12 SPF f/7175'-7201' & w/4" gun, 4 SPF f/7400'-7424' & 7435'-7448'. Make JB/gauge ring run. RIM w/WP pkr, set @ 7276' WLM, RD Schl. RIH w/2-7/8" compl string & ind. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. ER @ 1145 hfs, 10/15/85. Tail @ 7312', SSSV @ 1816', pkrs @ 7013' & 7285'. Old TI:) Released rig 1145 hrs. Classifications (oil. gee, etc.) Oil Producing method Flowing Potential test data tNew TO Oar's ' I PB Oepth ].0/15/85 [{Kin~ of rig IType completion (single. dual. etc.) SinBle Qfficial reservoir name(J! ' Kuparuk Sands 7568' PBTD Rotary WEll no. Date ~eserv0ir Producing Interval Oil or gas Test time Proauct~on - ~ .... ~ , ¥ ~..~ ,;mD size, SPM X length Choke ,i~. T.,. C.~. Water % GOR Gray,t, ~_),A{;6w~e~"") ~q~ ~EHectiv, date corrected .~ ~ ,_. . The above is correct '" Signature I Date tTitle fz2~ ~~J ,. II-t~-~g Drillin~ Supe;intenden~ For form preparation and di~ribution, see Procedures Manual, Section 10, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 12-05-85 TRANSMITTAL NO: 5469 ~TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING kECO~S CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 O~ANSMITTED HE1-LE~ITh~ AlxE THE FOLLOWING ~;CEIPT AND R3JTUi~ ONE SIGNED COPY OF THIS TRANSMITTAL. -NAL PRINTS/ SCHL/ CEMENT LOGS/ ONE * OF EACH ITEMS. PLEASE ACKNOWLEDGE ~-1~:~ CET/CEL 09-09-85 RUN #1 7288-~429 ~,-2~ CET/CEL 09-08-85 RUN %1 7988-9183 ~-24/ CET/CEL ~10-19-85 RUN %2 8439-8830 ~,-3~-''' SQUEEZE/ CEMENT F~TNR P~ECO~ 10-09-~5 RUN ~1 7050-7250 ~-3~, CET/CEL 09-22-85 RUN ~1 5331-7402 ~,-3 (POST SQUE]JZE%2) CET/CEL 10-11-85 RUN ~3 6740-7164 ~-14~-" SQUEEZE/ CEMENT RTNR RECORD 10-12-85 RUN #1 8800-9000 ¢-!5'~''' CET/CEL 09-23-85 RUN# 1 6530-8016 ~-12 ~- SQUEEZE/ CEl~JNT RTNR RECORD 09-24-85 RUN %1 8750-9000 IZ-12'~'SQUEEZE/ CEMENT RTNR RECORD 09-26-85 RUN %2* 8700-9000 ~EASE NOTE--THIS LOG SHOULD nE LABELED AS RUN %2. THE CORRECTION CAN BE WRITTEN IN. THANK YOU. 2EIPT'. ~ACKN OWLEDGED: DATE: ... Alaska 0ii & ~as Cons. Commission DISTRIBUTION: _E . DRILLING*BL W. PASHER ~gT~TE OF CUR/{iEK L. JOHNSTON EXXON SOHIO VRON' MOBIL PHILLIPS OIL .UNION M NSK CLERK*BL J. RATHMELL ALA SKA~ BL'~~ VAULT / ~0' FI LM S ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-4 Dear Mr. Chatterton- Enclosed is a Well Completion Report for the subject well. have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L113 Enclosure If you ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-4 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 3C-4. Tubing details will be submitted when the well has been completed. Also, I have not yet received the Core Description. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Associate Engineer JG/lt GRU12/L01 Enclosure RECEIV['D Alaska Oil & Oa.s 00~..~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ---.. STATE OF ALASKA ._:. ALASKA _AND GAS CONSERVATION CC VIISSION 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. 85-190 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510-0360 50- 029-21416 9. Unit or Lease Name 4. Location of well at surface 420' FNL, 1402' FEL, Sec.14, T12N, R9E, UM At Top Producing Interval 1381' FSL, 1165' FEL, Sec. 11, T12N, RgE, UM CATIONS Kuparuk River Unit / vERIFIED 10. Well Number I Surf--~---- 3C-4 At Total Depth IB. H. ~ 11. Field and Pool 1731' FSL, 1146' FEL, Sec. 11, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB I ADL 25629 ALK 2562 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. [ 15. Water Depth, if offshore 116-N°'°fC°mpleti°ns 08/16/'85 08/27/85 08/28/85 I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7670'MD, 6863'TVD 7568'MD, 6790'TVD YES I~X NO [] N/A feet MD 1700' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, RFT, DIL/SFL/GR/Cal/SP, FDC/CNL, CET, GCT 23. CASING SIZE 16" 10-3/4" CASING, LINER ANDCEMENTIN( 711 WT. PER FT. 60.5# 45.5# 26.0# GRADE H-40 K-55 J-55 SETTING DEPTH MD TOP BOTTOM Surf 100' Surf 2445' Surf 7650' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None HOLE SIZE 24" 13-1/2" 8-1/2" RECORD CEMENTING RECORD 183 SX CS II 1050 sx PF "E" & 380 s Top fob performed w/10( 380 sx PF "E", 250 sx AMOUNT PULLED PF "C" sx PF "C" :lass G~ & 250 sx PF "~" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A Date First Production Date of Test Flow Tubing Press. Hours Tested Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FORIOIL-BBL TEST PERIOD II~ IOIL-BBL CALCULATED 24-HOUR RATE GAS-MCr GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE IGAS'OILRATIO lOlL GRAV TY-API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. To be submitted wheD received from Geology Dept. ,~,ECE/vED ~?-, ~-_ ~- Form 10-407 TEMP2/WC24 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ;i:-~: ?- ~ : i~ GEoLOGIc M:ARKEi~'~; '- ~' : ; :~- _:~:~.:i' ' "" ' FdRMATION TESTS' . - NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT.'DEPTH GOR, and time of each phase. Top Kuparuk C 7168' 6504' SHUT-IN Base Kuparuk C 7200' 6527' DEPTH PRESS Top Kuparuk A 7389' 6662' Base Kuparuk A 7512' 6750' 3301' 1427 psi I 3307' 1430 psi 3384' 1483 psi 3384' ..... 3384' 1484 psi 3434' ..... 3427' 3425' 1510 psi 3495' ..... 3493' 1572 psi 3543' 1612 psi 3372' 1477 psi 3371 ' 3384' .1476 psi 3371 ' 1469 psi 3288' 1417 psi 31. LIST OF ATTACHMENTS Well History, Gyroscopic Survey (2 copies) 32. I hereby certify'that the foregoing is true and correct to the best of my knowledge Signed ~ Title Associate Engineer Date / INSTRUCTIONS General: .This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion)-, so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc Post Office .._,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DA?E: 10-15-85 TRANSMITTAL NO:5398A XETURN TO: ARCO ALASKA, INC. KU PAF, UK-OPERATIO[~$ RECORDS CL E lqK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGiNE'SRING TRANSMITTED Hi:RL%;IT[! ARE ?tie FOLLO~,;ING ITEMS. PLEASE ACKNONLEDCE RECEIPT A~D RETUi{/~ ONE SIGNED COPY OF THI~ TRANSMITTAL. OPEN HOLE FINALS/ SC}iL/ ONE * OF CA(Sit \ PORO PORO I~.~ RA~-~ 08-30-85 RUN #1 4355-9584 08-30-85 RUN %1 4355-9584 0~-30-85 .~UN #1 4500-9558 08-30-85 RUN ~1 4500-9558 0~-30-~5 RUN %1 4500-9558 08-30-85 RUN %1 4500-9558 0~-31-85 RUN %1 ~900-8550 08-31-85 RUN ~I 4500-9520 0~-31-85 RUN ~1 4500-9520 RAW PORO PO Rd RAW PO Rd PORU 08-27-85 RUN ~2 6000-7570 0~-27-85 RUN ~2 2440-7593 0~-27-~5 ~UN %2 2440-7593 08-27-85 RUN ~2 2440-7593 0~-27-85 I{UH #2 2440-7593 08-27-85 RUN #2 2440-7619 08-27-~5 RUN #2 2440-7619 0~-31-85 RUN %1 8710-9403 08-31-85 RUN ~1 8550-942,3 0b-31-85 i~UN ~1 ~550-9426 08-31-85 RUN #1 8550-942.~ 08-31-85 RUN #1 8550-9426 08-3 !-~5 RUN ~1 2390-9452 0~-3!-85 RUN #i 2390-9452 ~<ECEiP'f ACKNOWLEDGED: bPAE B C U kk.,.'''~ C [iEVkO N D & M*HL D I L'i'I(£D Ll','-r O]'~: D,,... LL i i,~(.;* fi,:, ~," PASHER JOHNSTON ~ ....... '~" b:OB~ L PHILLIPS OiL CL E R!-'.* bL J. ~JL.'i ,~ ';" !" DA'IJqM;;ka O~ ~: ~. STATE OF 'Ai~AS'KA*:3L bOillO UNION ~{ATliMELL* DL . VAULT/AHO* ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany NEW PROJECTS ENGINEERING TRANSMITTAL [~ dP L -~q ~ TO: DATE: FROM: L. K. SMITH/P. S. BAXTER WELL NAME: ~"~,-~C-~/ TRANSMITTED HEREWITH ARE THE FOLLOWING: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: PATSY S. BAXTER ATO/507 P. O. BOX 100360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-4 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3C-4. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L115 Enclosure ELEIVED bas Co~s. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA .... -- ALASKA.~ ~AND GAS CONSERVATION CO ,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-190 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21416 4'. Location of well at surface 9. Unit or Lease Name /+20' FNL, 1/+02' FEL, Sec,14, T12N, RgE, UN (approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3C-q At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 86' RKB ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/16/85 08/27/85 08/28/85 N/A feet MS L N/A 17. Total Depth (MD+TVD) 76701 MD 181Plug Back Depth (MD+TVD)19. Directional Survey 75681 MD _ YES [] NO []X I20' Depth where Sssv ,etN/A feet MD I21' Thickness °f Permafr°st1700' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, RFT, D IL/SFL/GR/Cal/SP, FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 60.5# H-40 Surf 100' 2~" 183 sx CS II 10-3/4" /+5.5# K-55 Surf 2445' 13-1/2" 1050 sx PF "E" & 380 s: PF "C" Top job performed W/IOI) S~; PF "(;" 7" 26.0# J-55 Surf 7650' 8-1/2" 380 sx PF "E"~ 250 sx :lass G, & 250 sx PF ,,i , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDa~"a~! OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. To be submitted when received from Geology Dept. RECEIVED Alaska Oii& (~.;~s C0ris. / ..... Form 10-407 TEMP2/WC24 Submit in duplicate Rev. 7-1-80 , CONTINUED ON REVERSE SIDE ..... , '~ ....... ~_ ,.. .... . ....... , : ..... · ............. -,:; !,:;:'i E~.RMA.r.i,0N.:~ZE~:T~._.,., . . ,~ ,~ . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT, DEPTH GOR, and.time of each phase. N/A RFT data to be submitted when received. .. . .. I' . 31. LIST OF ATTACHMENTS None 32. I he~el~y certify that the foregoing is true and correct to the best of my knowledge Signed. {~~ .~ ~/L,~ Title A$$oc' ate EI3g~ 13ee r Date ~- Z~S~' /// ., INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office B,... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-4 Dear Mr. Chatterton: Enclosed is a copy of the 3C-4 core description to include with the Well Completion Report dated 10-16-85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/sw GRU 1 / 14 Enclosure cc: 3C-4 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ... ARCO ALASKA, INC. WELL KUPARUK 3C-4 KUPARUK RIVER FIELD WEST SAK FORMATION CORE ANALYSIS DATA DECEMBER 1985 FILE 96509 ._ CONFIDENTIAL CONFIDENTI/ L 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 December 6, 1985 Ms. Renee Boyer Arco Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: 'COre Analysis' Data Well Kuparuk 3C-4 Kuparuk River Field West Sak Formation File ~6509' Dear Ms. Boyer: Herewith are porosity, air permeability, fluid saturation and apparent grain density data, as well as overburden porosity and air permeability data on core material recovered from your West Sak Formation, Kuparuk River Field, Well Kuparuk 3C-4, Alaska. The c~re was recovered utilizing a 5-1/4" fiberglass core barrel, in the presence of a water base drilling fluid. Core oil gravity supplied by the customer was 18°API. The core was received at our Anchorage, Alaska office frozen, and was maintained in a frozen condition. Upon receipt, 6 one foot long samples of whole diameter core were cut at intervals supplied by the customer and sealed in their original fiberglass barrels. The core was then slabbed length- wise (2/3 to 1/3), photographed in color and UV light, and gamma logged. Samples were cut for routine core analysis (2 each foot) and for the State of Alaska (1 each foot). The routine core analysis samples were wrapped with teflon tape ana jacketed in a metal sleeve. The samples were individually extracted with toluene for a minimum of 16 hours, placed in a gang extractor and extracted with chloroform-methanol-azeotrope for 48 hours, followed by an additional 8 hours with fresh azeotrope. The samples were then dried at 150° F. for 12 hours, followed by vacuum drying for 8 additional hours at 150° F., cooled in a desiccator to room temperature and weighed. E 120.51 RiVERA ROAD- SANTA FE SPRINGS, CA 90670-2289 'Ms. Renee Boyer December 6~ 1985 The porosity was determined by the Archimedes method and air permeability was determined using a flow tube type permeameter, having a closing pressure of 300 psi. Helium porosity and air permeability were also determined on each sample at 1,~000 psi simulated reservoir stress. -.;. We sincerely appreciate this opportunity to be of service and trust these data prove beneficial in the development of this reservoir. Sincerely, PTS: dh PETROLEUM TESTING SERVICE, INC. Peter T President COMPANY Arco ALaska' Inc. CORE BARREL 5 1/4" FibergLass SLeeve MUD TYPE Water Base ,, PETROLEUM TESTiNG SERVICEr iNC. CORE A~ALYSIS WELL FIELD COUNTY STATE · PAGE ~ FiLE No. 6509 DATE November 27, 1985 West Sak 3C-4 Kuparuk RJver~ West Sak ALaska DEPTH FEET PERCENT md. RATIO OIL WATER ....o... CORE NO. 6 (3270 - 3298.5) : REC. (3270 - 3298.45) ARCHIMEDES Air SATURATION % PORE SPACE POROSITY PermeabiLity ....................... TOTAL 3270.3 29.5 4.3 0.00 0.0 93.4 93.4 3270.85 29.3 1.9 0.00 0.0 96.7 96.7 3271.3 27.4 1.4 0.00 0.0 97.5 97.5 3271.9 28.0 3.3 0.00 0.0 91.5 91.5 3272.2 27.2 2.6 0.00 0.0 96.6 96.6 3272.6 28.4 19. 0.00 0.0 92.3 92.3 32~.25 30.5 10. 0.00 0.0 96.3 96.3 32~.75 27.8 2.2 0.00 0.0 97.6 97.6 3274.25 27.2 2.7 0.00 0.0 95.9 95.9 3274.75 27.3 1.3 0.00 0.0 95.9 95.9 3275.25 27.7 3.9 0.00 0.0 92.6 92.6 3275.8 27.8 9.8 0.00 0.0 94.1 94.1 3276.25 28.6 3.5 0.00 0,0 94.6 94.6 et SIMULATED ' RESERVOIR STRESS APPARENT .SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY PermeabJtty gm/cc psi PERCENT md.' ...o..... ..0.o... ...o..o. 2.75 1000 26.6 1.4 2.76 1000 26.3 0.5' 2.74 1000 24.2 0.5 2.74 1000 24.8 0.7 2.75 1000 24.6 0.? 2.74 1000 26.2 5.3 2.75 1000 27.0 2.8 2.74 1000 24.2 0.5 2.74 1000 24.7 0.7 2.74 1000 25.7 0.5 2.73 1000 24.7 1.3 2.7'5 1000 24.6 2.2 2.T5 1000 25.8 2.1 DESCRIPTION ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm stty-ctst/fm stty-ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm stty-ctst/fm stty-ctst/fm COHPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE~INC, CORE ANALYSIS UELL West Sak ,3C-4 PAGE .2 ;FILE No. 6509 ,DATE November 27~ 1985 ARCHIMEDES Air SATURATIOH ~ PORE SPACE DEPTH POROSIlY Permeability 0/~ ....................... . FEET PERCENT md. RATIO OIL WATER TOTAL · CORE NO. 6 (CONTINUED) (3270 - 3298.5) : REC. (3270 - 3298.45) .....--.-................... .... .. .................................. 3276.85 28.7 5.7 0.00 0.0 91.9 91.9 3277.3 28.5 2.3 0.00 0.0 96.3. 96.3 3277.85 30.0 7.3 0.00 0.0 93.1 93.1 3278.25 29.1 4.8 0.00 0.0 92.8 92.8 3278.75 30.2 5.4 0.00 0.0 95'.0 95.0 3279.25 29.9 4.7 0.00 0.0 95.2 95.2 3279.75 31.4 20. 0.00 0.0 94.9 94.9 3280.25 31.9 27. 0.00 0.0 93.7 93.7 3280.9 31.5 34. 0.00 0.0 95.4 95.4 3281.15 31.2 20. 0.00 0.0 94.0 94.0 APPARENT SAND GRAIN "DENSITY gm/cc at SIHULATEO .RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY PermeabJ[ty psi PERCENT md. ........ ........ ........... 2.74 1000 25.8 3.4 2.74 ~000 25.7 1.7 2.73 1000 27.2 4.3 2.72 1000 26.1 3.2 2.76 1000 26.7 3.6 2.72 1000 26.6 3.9 2.72 1000 28.0 6.8 2.72 1000 28.6 12.0 2.72 1000 28.4 12.0 2.73 1000 27.6 6.2 3281.8 35.2 90. 0.00 0.0 90.5 90.5 2.7'5 3282.3 36.4 30. 0.00 0.0 90.9 90.9 2.75 3282.9 37.3 242. 0.00 0.0 89.0 89.0 2.74 3283.35 34.2 38. 0.00 0.0 92.2 92.2 2.74 3283.95 33.9 49. 0.00 0.0 89.2 89.2 2.73 3284.35 34.5 34. 0.00" 0.0 91.2 91.2 2.76 3284.8 32.4 19. 0.00 0.0 93.7 93.7 2.75 3285.25 32.1 1.2 0.00 0.0 96.6 96.6 2.79 3285.8 44.8 1340. 0.08 5.7 70.4 76.1 2.70 1000 32.1 63.0 1000 33.0 14.0 SAMPLE FAILED 1000 31.0 11.0 1000 30.1 11.0 1000 32.0 14.0 1000 29.7 8.4 1000 29.9 0.7 1000 39.3 831.0 DESCRIPTION stty-c[st/fm s[ty-c[st/fm sIty-c[st/fm catc-stty-ctst/fm ca[c-s[ty-c[st/fm ca[c-s[ty-c[st/fm ' ca[c-s[ty-c[st/fm catc-stty-c[st/fm S[ty-c[st/fm s[ty-c[st/fm stst/fm s[st/fm stst/fm catc-ctst/fm stty-c[st/fm ca[c-stst/fm ca[c-stty-c[st/fm s[ty-c[st/fm ss/vfn-fn/sft COMPANY Arco Alaska Inc. PETROLEUM'TESTING SERVICE,'~NC. UELL Ue~t Sak 3C-4 PAGE 3 FiLE No. 6509 'DATE November 27~ 1985 .. ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY PermeabJtJty O/g ....................... FEET PERCENT mci. RATIO OIL WATER TOTAL ..o..... ........ o........... ..... . .... ... ..... CORE NO. 6 (CONTINUED) (3270 - 3298.5) : REC. (3270 - 3298.45) ...............o........ ..... ......... .... ............. ..... . ....... CORE ANALYSIS APPARENT SAND GRAIN 'DENSITY gm/cc 3286.25 42.9 1830. 0.10 7.4 76.2 83.6 2.71 3286.8 40.0 1370. 0.00 0.0 84.5 84.5 2.71 3287.35 43.1 2230. 0.00 0.0 78.2 78.2 2.75 3287.8 41.1 939. 0.00 0.0 78.4 78.4 2.73 3288.3 42.0 3540. 0.00 0.0 81.8 81.8 2.71 3288.75 51.5 2550. 0.00 0.0 84.6 84.6 2.70 3289.2 5.1 0.5 0.00 0.0 93.5 93.5 2.71 3289.75 4.4 0.8 0.00 0.0 82.1 82.i 2.72 3290.2 3.5 0.3 0.00 0.0 92.2 92.2 2.72 3290.75 3.9 0.3 0.00 0.0 84.5 84.5 2.71 3291.3 40.9 1600. 0.00 0.0 82.3 82.3 2.70 3291.8 35.1 4.7 0.00 0.0 92.6 92.6 2.77 3292.3 ~0.5 9.5 0.00 0.0 90.5 90.5 3.11 3292.75 5.5 0.4 0.00 0.0 84.8 84.8 2.75 3293.2 7.6 0.3 0.00 0.0 91.2 91.2 2.74 3293.7 38.4 2910. 0.00 0.0 81.2 81.2 2.68 3294.25 40.9 3080. 0.00 0.0 79.9 79.9 2.68 3294.85 49.2 5650. 0.00 0.0 56.0 56.0 2.68 3295.25 45.1 3990. 0.00 0.0 67.0 67.0 2.68 SIMULATED RESERVOIR STRESS psi at SIMULATED 'RESERVOIR STRESS ....................... Air POROSITY Permeabilty PERCENT md. 11000 39.7 1140.0 '1000 37,7 1320.0 1000 38.4 1440.0 1000 37.8 670.0 1000 37,1 1390.0 1000 44.4 1160.0 1000 4.9 · 0.1 1000 4.2 < 0.05 1000 3.2 < 0.05 1000 3.7 < 0.05 1000 36.8 1400.0 1000 27.9 3.6 SAMPLE FAILED '1000 5.R < 0.05 1000 7.3 < 0.05 1000 35~6 2630J0 1000 38.2 2480.0 1000 44.6 2890.0 1000 40.4 3340.0 DESCRIPTION Ss/vfn-fn/sft 'ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft catc-stst/hd catc-stst/hd catc-stst/hd catc-s~st/hd ss/vfn-fn/sft sdy-ctst/fm carb-ferr-stst/fm catc-stst/hd ca[c-s[st/hd ~s/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE~ INC. CORE ANALYSIS WELL West Sak 3C-4 PAGE .4 FILE No. 6509 DATE November 27, 1985 ARCtlIHEOES Air SATURATION % PORE SPACE DEPTH POROSITY PermeabJtjty O/N FEET PERCENT md. RATIO OIL WATER TOTAL ......................... .... ....... .......... .. ......... .....~..... CORE NO. 6 (CONTINUED) (]2?0 - 3298,5) : REC, (]270 - ]298.65) 3295.8 43.2 4000. 0.00 0.0 , 79.9 79.9 3296.35 62.3 3760. 0.00 0.0 76.9 76.9 3296.85 41.S 3010. 0.00 0.0 82.1 B2.1 3297.25 42.1 3330. 0.00 0.0 74,6 76.6 3297.5 RUBBLED MATERIAL - NO SAHPLE 3298.~ 61.9 998. 0.01 0,4 85.6 86.0 CORE NO. 7 (3301 - 3327) : REC. (3301 - 3327.55) 3301.35 43.8 3920. 0.00 3301.B5 40.9 2800. 0.00 3302.2 39.4 2430. 0.00 3302.7 41.3 3360. 0.00 3303.25 40.6 1940. 0.00 3303.? 41.7 1950. 0.00 3304.0 SECTION PRESERVED' 3305.0 SECTION PRESERVED 3305.25 40.5 1040. 0.00 3305.7 41.2 1120. 0.00 0.0 83.0 83.0 2.68 0.0 86.3 86.3 2.68 0.0 86.3 86.3 2.69 0.0 83,6 83.6 2.69 o.o 84.3 84.3 2.70 0.0 8~.3 85.3 2.70 APPARENT SAND GRAIN DENSITY gm/cc , at SIHULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY PermeabJ(ty psi PERCENT md. 2.68 . 1000 40.1 3120.0 2.68 ~000 38.6 2120.0 2.68 1000 38.9 2430.0 2.68 1000 39.3 2360.0 2.69 1000 37.7 667.0 1000 40.2 2450.0 · 1000 38.2 2540.0 1000 36.9 1820.0 1000 ]9.0 2140.0 1000 37.5 1270.0 1000 38.5 1230.0 0.0 85,1 85.1 2.72 1000 38.1 674.0 0.0 82,9 82.9 2.71 1000 38,1 769,0 3306.25 40.8 338. 0.00 0.0 84.9 84.9 2.72 3306.7 40.8 329. 0.00 0.0 85.5 85.5 2.76 1000 37,5 281.0 1000 36,4 278,0 DESCRIPTIOH ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft ss/vfn-fn/sft slty-ss/vfn-fn/sft stty-ss/~fn-fn/sft COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE, !NC. CORE ANALYSIS ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeabitity 0/~ ....................... FEET PERCENT md. RATIO OIL gATER TOTAL .....o.. ....o... .......o..o. ....o ... . .... CORE NO. 7 (CONTINUED) (3301 - 3327) : REC. (3301 - 3327.55) 3307.2 41.4 989. 0.00 0.0 86.8 86.8 33Q7.75 39.9 1080. 0.00 0.0 82.5 82.5 3308.15 80.9 798. 0.00 0.0 85.4 85.4 3308.7 41.7 2290. 0.00 0.0 86.7 86.7 3309.15 43.1 1760. 0.00 0.0 88.2 88.2 3309.7 42.5 2330. 0.00 0.0 87.0 87.0 3310.15 42,6 2320. 0.00 0.0 84.7 84.7 3310.75 42.1 3080. 0.00 0.0 72.6 72.6 3311.2 38.9 579. 0.00 0.0 86.7 86.7 3311.7 38.1 444. 0.00 0.0 88.7 88.7 3312.25 41.4 678. 0.00 0.0 86.2 86.2 3312.75 37,0 39. 0.00 0.0 93.8 93.8 3313.2 36.8 22. 0.00 0.0 92.3 92.3 3313.75 35.3 34. 0.00 0.0 91.8 91.8 3314.25 41.2 300. ** 0.00 0.0 89.2 89.2 3314.8 39.2 328. 0.00 0.0 87.2 87.2 3315.3 39.8 662. 0.00 0.0 79.9 79.9 3315.8 35.7 34. 0.00 0.0 91.7 91.7 APPARENT SAND GRAIN DENSITY · , gm/cc 2.71 2.71 2.71 2.70 2.7O 2.70 2.70 2.70 2.71 2.72 gELL ges~ Sak 3C-4 at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY Permeabjtty psi PERCENT md. ~000 37.7 557.0 1000 37.6 644.0 1000 37.5 463.0 1000 39.2 1200.0 1000 38.6 1140.0 1000 39.5 1680.0 1000 38.9 1350.0 1000 39.8 1830.0 1000 35.9 369.0 1000 34.8 265.0 2.70 1000 38.0 267.0 2.76 1000 33.6 12.0 2.74 1000 32.8 12.0 2.74 1000 32.1 13.0 2.73 1000 37.1 200.0** 2.74 1000 36.5 202.0 2.72 1000 36.6 435.0 2.73 1000 32.1 20.0 PAGE 5 FiLE No. 6509 , DATE November 27, 1985 DESCRIPTION s[ty-ss/vfn-fn/sft ss/vfn/sft ss/vfn/sft ss/vfn-fn/sft ss/vfn/sft ss/vfn/sft ss/vfn/sft ss/vfn/sft sdy-stst/sft sdy-stst/sft stty-ss/vfn/sft cty-stst/fm cty-stst/fm cty-stst/fm sist/fm stst/fm sdy-stst/fm stst/fm ** FRACTUREDf ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska inc. PETROEEUM TESTING SERVICE~ INC. CORE. ANALYS ! S ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeabitity 0/~ ....................... FEET PERCENT md. RATIO OIL WATER TOTAL ........ ........ ......o..... ..o.. ... .o... ..... CORE NO. 7 (CONTINUED) (3301 - 3327) : REC. (3301 ' 3327.55) 3316.25 40.4 217. 0.00 0.0 75.5 75.5 3316.8 40.7 352. 0.00 0.0 99.0 99.0 3317.15 45.4 100. ** 0.00 0.0 85.3 85.3 3317.8 33.9 92. 0.00 0.0 99.0' 99.0 3318.25 39.1 354. 0.00 0.0 89:1 89.1 3318.65 39.5 289. 0.00 0.0 85.7 85.7 3319.25 35.7 95. 0.00 0.0 92.4 92.4 3319.8 34.0 80. 0.00 0.0 93.8 93.8 3320.25 37.4 443. 0.00 0.0 83,2 83.2 3320.85 37.1 250. 0.00 0.0 89.8 89.8 3321.25 38.8 240. 0.00 0.0 87.7 87.7 3321.75 37.7 257. 0.00 0.0 87.0 87.0 3322.15 38.4 265. 0.00 0.0 85,1 85.1 3322.7 37.0 128. 0.00 0.0 87!4 87.4 3323.15 37.7 309. 0.00 0.0 84.1 84.1 · , 3323.7 39.3 300. ** 0.00 0.0 87.0 87.0 3324.15 41.3 350. ** 0.10 6.6 67.4 74.0 3324.55 41.1 350. ** 0.17 10.4 61.3 71.7 APPARENT SAND GRAIN DENSITY gm/cc SIHULATED RESERVOIR STRESS psi WELL ** FRACTURED~ ESTIMATED AIR PERMEABILITY at SIMULATED RESERVOIR STRESS Air POROSITY Permeabi[ty PERCENT md. 2.72 . 1000 35.0 134.0 2.72 1000 37.8 281.0 2.73 1000 40.9 75.0** 2.67 1000 31.2 41.0 2.73 1000 35.9 274.0 2.72 1000 36.5 219.0 .., 2.70 1000 34.0 57.0 " 2.69 1000 32.4 54.0 2.68 1000 34.8 301.0 2.72 1000 34.9 179.0 West Sak 3C-4 PAGE ,6 FILE No. 6509 DATE November 2Z, 1985 2.72 1000 35.5 179.0 2.7'5 1000 34.1 178.0 2.74 1000 34.7 214.0 2.73 1000 34.0 88.0 2.72 1000 34.6 255.0 2.72 1000 35.8 200.0** 2.71 1000 37.2 250.0** 2.70 1000 3Z.4 250.0** DESCRIPTION sist/fm sd~-stst/fm cl'~-stst/fm ct'~-stst/fm sd~-s[st/fm sd'~-sIst/fm ct'r-s[st/fm ct'~-stst/fm ~dt-slst/f~ sd~-stst/fm sdy-stst/fm sdy-stst/fm sdy-stst/fm sdy-stst/fm sdy-s[st/fm sdy-s[st/fm sdy-s[st/fm sdy-s[st/fm PETROLEUM TESTING SERVICE, INC. PAGE ? FILE No. 6509 DATE November 27, 1985 COMPANY Arco Ataska inc.. gELL Nest Sak 3C-4 CORE ANALYSIS ARCHIMEDES Air POROSITY Permeabitity DEPTH O/N FEET PERCENT md. RATIO. OIL. gATER TOTAL , ........ .......o ............ .o... ... CORE NO. 7 (CONTINUED) (3301 - 3327) : REC. (3301 - 3327.55) APPARENT SATURATION X PORE SPACE SAND GRAIN ........................ DENSITY gm/cc 3325.1 38.6 534. 0.00 0.0 83.1 3325.9 36.5 125. 0.00 0.0 90.0 3326.15 38.5 160. 0.00 0.0 88.0 3326.5 RUBBLED HATERIAL - NO SAMPLE 3327.0 RUBBLED HATERIAL - NO SAMPLE CORE NO. 8 (3327 - 3358) : REC. (3327.55 - 3356.95) 83.1 2.71 90.0 2.71 88.0 2.72 3327.7 30.5 2.8 0.00 0.0 97.6 97.6 2.75 3328.3 28.5 1.2 0.00 0.0 96.1 96.1 . 2.74 3328.7 29.4 1.8 0.00 0.0 95.5 95.5 2.74 3329.2 29.9 2.4 0.00 0.0 94.9 94.9 2.74 3329.75 29.5 2.4 0.00 0.0 94.5 94.5 2.73 3330.25 30.1 2.3 0.00 0.0 95.4 95.4 2.73 3330.? 29.7 2.9 0.00 0.0 94.6 94.6 2.73 3331.15 30.0 2.4 0.03 2.8 91.5 94.3 2.73 3331.7 30.5 9.5 0.00 0.0 93.8 93.8 2.75 3332.25 30.4 3.0 ** 0.01 1.3 92.5 93.8 2.75 3332.7 28.5 5.0 0.03 2.7 89.3 92.0 2.71 3333.25 32.0 1.0 0.00 0.0 95.5 95.5 2.76 3333.75 41.3 835. 0.98 40.0 40.7 80.7 2.71 at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR. Air STRESS POROSITY PermeabJtty psi. PERCENT. md. ........ ....... ....... 1000 36.1 463.0 1000 33.6 84.0 1000 34.3 103.0 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 29.2 27.1 26.7 26.1 27.6 27.4 26.6 28.5 28.6 28.3 26.5 29.8 37.0 1.3 0.4 0.5 0.7 0.7 0.7 0.7 0.7 3.9 2.0** 2.1 0.3 641.0 DESCRIPTION sd¥-stst/fm sd¥-stst/fm sd¥-stst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm clst/fm ctst/fm sdy-stst/fm ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska Inc. PETROLEUM TESTING SERVICE, iINC. CORE ANALYSIS UELL West Sak3C*4 PAGE 8 ~FILE No. 6509 'DATE November 27,.1985 ARCHIMEDES Air SATURATION X PORE SPACE DEPTH POROSITY Permeabit|t¥ O/W ....................... . FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 8 (CONTINUED) (3327 - 3358) : REC. (3327.55 - 3356.95) 3336.25 42.5 1660. 1.04 40.9 39.5 80.4 3334.75 41.1 1420. 1.09 42.0 38.5 80.5 3335.25 34.5 6.3 0.08 7.0 84.3 91.3 3335.75 37.0 59. 0.14 11.0 76.2 87.2 3336.15 31.6 6.3 0.01 0.7 92~2 92.9 3336.65 32.3 2.4 0.02 2.1 91.8 93.9 3337.2 31.9 4.4 0.11 9.0 83.3 92.3 3337.? 31.9 3.2 0.10 8.3 85.4 93.7 3338.15 33.6 18. 0.02 1.7 88.0 89.7 3338.65 31.2 1.6 - 0.05 4.1 90.4 94.5 3339.25 33.3 4.6 0.02 1.5 87.2 88.7 3339.85 34.6 20. 0.01 1.3 87.5 88.8 3340.35 33.6 4.9 0.00 0.0 88.8 88.8 3340.85 32.4 4.7 0.02 2.2 8819 91.1 3341.35 34.3 14. 0.00 0.0 88.7 88.7 3341.75 32.7 5.5 0.00 0.0 90.5 90.5 3342.2 31.1 2.4 0.00 0.0 93.5 93.5 3342.? 31.2 3.3 0.00 0.0 92.1 92.1 APPARENT SAND GRAIN DENSITY gm/cc at SIHULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY PermeabJ[ty psi PERCENT md. 2.71 , 1000 38.0 1020.0 2.70 1000 38.7 1050.0 2.73 lO00 31.9 3.3 2.73 1000 34.6 32.0 2.72 1000 29.9 3.4 2.75 1000 30.6 0.9 ., 2.73 10o0 28.5 1.7' 2.74 1000 27;2 1.2 2.74 1000 30.6 6.3 2.74 1000 28.0 0.6 2.73 1000 30.3 2.2 2.73 1000 31.4 11.0 2.73 1000 29.9 2.8 2.73 1000 30.3 2.2 2.73 1000 31.7 10.0 2.75 1000 30.7 3.1 2.74 1000 29.5 0.9 2.74 1000 28.2 1.3 DESCR I PT ION stty-ss/vfn/fm stty-ss/vfn/fm stty-ctst/fm stty-ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm Stty-ctst/fm ctst/fm clst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm ctst/fm ctst/fm COMPANY Arco Ataska inc,. PETROLEUH TESTING SERVICE, ~INC. WELL West Sak 3C-4 PAGE 9 FILE No, 6509 'DATE November 27~ 1985 CORE ANALYSIS ARCHIHEDES Air POROSITY Permeabit~ty DEPTH O/N FEET PERCENT ind, RATIO OIL WATER TOTAL ...ooo.. ........ ............ .o... ..o ..... ..... ............................ ..... ....... .... ......................-. CORE NO, 8 (CONTINUED) (3327 - 3358) : REC, (3327,55 - 3356.95) .....................................------.------------------------ APPARENT SATURATiOH ~ PORE SPACE SAND GRAIN ........................ DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIHULATED ....................... RESERVOIR Air STRESS 'POROSITY PermeabJtty psi PERCENT md, ........ ........ ........... 3343,15 31,0 4,9 0,00 0,0 90,9 90,9 2,74 1000 27,9 1,5 3363,75 30,5 2,4 0,00 0,0 91.8 91,8 2,74 9000 28.4 0,9 3346,35 30.5 2.2 0.00 .0.0 92,6 92,6 2,73 1000 27,0 0,8 3344,75 30,6 4,3 0,00 0,0 91.4 91,4 2,73 1000 27,3 1,6 3345.15 29,1 4,7 0.00 0,0 96.9 96,9 2,68 1000 26.8 1,9 3345,65 25,7 2.6 0,00 0.0 99,1 99,1 2,73 1000 24,3 1,0 3346,15 28,8 2,4 0,00 0,0 98.4 98.4 2,76 1000 26.1 0,9 3346.65 29,2 2.6 0.00 0,0 99.0 99,0 2,73 1000 26,7 1,0 3367.15 29,3 2,9 0,00 0,0 98,6 98,6 2,74 1000 27,1 1,1 3367,65 29,0 2,1 0,00 0,0 99,6 99,6 2,73 1000 26,9 0,9 DESCRIPTION ..........o ctst/fm clst/fm ctst/fm c~st/fm c~st/fm c~st/fm cLst/fm c~st/fm c~st/fm c~st/fm 33~8,15 30,8 2,4 0,00 0,0 98,6 98,6 2,73 3368,65 29.6 8,8 0.00 0.0 99,3 99,3 2,72 3349,15 29.0 4.0 0,00 0,0 98,5 98,5 2.73 3349,65 30,0 4,7 0,00 0,0 99,5 99,5 2,71 3350,15 31,0 4,5 0,00 0,0 99,3 99,3 2,73 3350.65 29.7 3.6 0.00 0.0 99.1 ~.1 2.72 3350.85 SECTION PRESERVED 3351.85 SECTION PRESERVED 3351.9 32.4 7.7 0.00 0.0 92.0 92.0 2.72 1000 28.0 0,7 1000 28,1 2.2 1000 27,4 1,4 1000 28,5 1,7 1000 29,5 3.2 1000 27;6 1.3 1000 30.9 5,2 ctst/fm ctst/fm ctst/fm cLst/fm ctst/fm ctst/fm ctst/fm COHPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE, JNCo CORE ANALYSIS WELE West. Sak 3C-4 PAGE 10 FiLE No. 6509 DATE November 27, 1985 ARCHIMEDES Air, DEPTH POROSITY Permeabi[|ty 0/~ FEET PERCENT md. RATIO SATURATIO~ X PORE SPACE OIL WATER TOTAL CORE NO. 8 (CONTINUED) (3327 - 3358) : REC. (3327.55 - 3356.95) .................................................................... 3352.15 33.2 29. 0.02 2.0 85.9 87.9 3352.65 33.4 43. 0.04 3.6 87.1 90.7 3353.25 30.5 30. ** 0,04 3.5 86.3 89.8 3353.6 33.5 16. 0.03 3.0 86.5r' 89.5 3356.25 29.6 11. 0,00 ' 0,0 91,5 91,5 3354.85 31.9 18. 0,00 0.0 91.4 91.4 3355.15 34,0 38. 0,02 1,9 88.4 90.3 3355.8 32.1 18. 0,02 2,1 89.2 91.3 3356.15 31.8 40. 0.01 1.2 87.7 88.9 3356.8 27.9 4.4 0,00 0.0 95.2 95.2 CORE NO. 9 (3358 - 3388) : REC. (3358 - 3388.3) .......................................................',... 3358.3 28.1 2.7 0.00 0.0 99'j4 3358.75 27.5 0.7 0.00 0.0 99.2 · , 3359.2 27.0 0.5 0.00 0.0 98.2 3359.? 27.1 0.7 0.00 0.0 97.8 3360.1 26.8 0.7 0.00 0.0 97.6 3360.6 27.7 0.5 0.00 0.0 98.2 3361.~ 26.4 0.7 0.00 0.0 99.0 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabi[ty gm/cc psi PERCENT md. ........~ ........ o.o...o. ........... 2.71 1000 31.2 13.0 2.71 1000 31.0 22.0 2.67 SAHPLE FAILED 2.71 1000 32.0 8.0 2.66 1000 27.5 4.2 2.71 1000 30.5 6.9 2.71 1000 31.3 17.0 2.70 1000 30.5 7.6 2.70 1000 30.3 14.0 2.72 1000 25.3 1.7 99.4 2.77 1000 27.7 0.7 99.2 2.74 1000 25.2 0.4 98.2 2.T5 1000 25.6 0.3 97.8 2.72 1000 26.1 0.5 97.6 2.72 1000 25.5 0.4 98.2 2.74 1000 25.9 0.4 99.0 2.~ 1000 25.7 0.2 DESCRIPTION cty-s[st/fm cty-stst/fm cLy-stst/fm stty-ctst/fm stty-ctst/fm ctst/fm ctst/fm cLst/fm ctst/fm c[y-sLst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm c[st/fm ** FRACTURED, ESTIMATED AIR PERHEABILITY CO.pAN+ ArCo Ataska inc.. PETROLEUH TESTING SERVI'CE, ~ELL west Sak 3C-4 PAGE 11 FILE No. 6509 DATE November 27~ 1985 ARCHIHEDES Air DEPTH POROSITY Permeabitity O/W FEET PERCENT md. RATIO ....o ...... .....o.... ......... ........................... .... ....... CORE NO. 9 (CONTINUED) (3358 - 3388) : REC. (3358 - 33~.3) ..'............................. .... . ..... .... . ................ .... CORE ANALYSIS APPARENT SATURATION X PORE'SPACE SAND GRAIN ......................... DENSITY OIL WATER TOTAL gm/cc at SIHULATED RESERVOIR STRESS SIHULATED ....................... RESERVOIR Air STRESS POROSITY PermeabjJty Psi PERCE~T mci. .eeJeee. .Jemetae ....eJ.Jee. 3361.8 27.2 1.4 0.00 0.0 99.4 99.4 2.73 i000 25.~ 0.8 3362.2 26.7 0.7 0.00 0.0 98.7 98.7 2.73 1000 24.4 0.4 3362.6 27.3 1.3 0.00 .0.0 95.5 95.5 2.72 jO00 25.3 0.8 3363.1 26.8 0.7 0.00 0.0 99.0 99.0 2.73 JO00 24.6 0.4 3363.6 28.4 0.4 0.00 0.0 74.3 74.3 2.75 i000 27.8 0.1 3364.1 28.1 0.7 0.00 0.0 96.5 96.5 2.74 1000 26.9 3364.7 28.3 1.8 0.00 0.0 93.5 93.5 2.74 1000 26.& 0.8 3365.05 29.3 4.0 0.00 0.0 61.7 61.7 2.70 1000 27.2 1,9 3365.7 28.3 1.1 0.00 0.0 64.1 64.1 2.70 1000 26.2 0,7 3366.1 28.2 0.7 0.00 0.0 96.5 96.5 2.73 1000 25.0 0,4 DESCRIPTION ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm c[st/fm ctst/fm ctst/fm c[st/fm c[st/fm 3366.7 28.3 3.9 0.00 0.0 96.5 96.5 2.78 1000 26.5 1.3 3367.2 26.7 3.2 0.00 0.0 98.2 98.2 2.71 1000 24.7 0.8 3367.7 29.6 9.7 0.01 0.8 86.6 87.4 2.73 1000 26.6 2.6 3368.55 38.6 811, 10.74 62.3 5.8 68.1 2,69 1000 37.7 7"32.0 3368.75 39.1 832. 2.88 58.2 20.2 78.4 2,74 1000 36.6 779.0 3369.25 41,6 544. 2.65 50.7 20.7 71.4 2.73 1000 38J9 413.0 3369.8 38.2 606. 2.63 46.6 19.1 65.5 2.69 1000 36,1 331.0 3370.3 39.5 610. 1.14 60.6 35.3 73.7 2.73 1000 37,'8 369.0 , . ctst/fm ctst/fm stty-c~st/fm stty-ss/vfn-fn/sft ~tt¥-;ss/vfn-fn/sft S~ty-ss/vfn-fn/sft ~st/sft ~tty-ss/vfn-fn/sft COMPANY Arco ALaska Inc. PETROLEUM TESTING SERViCEd,INC. CORE ANALYSIS UELL west Sak3C-4 PAGE 12 FILE'No. 6509' DATE. November 27, 1985 ARCHIMEDES A)r SATURATION % PORE SPACE OEPTH POROSITY PermeabJEity O/U ....................... FEET PERCENT md. RATIO OIL WATER TOTAL .....o.. ...0.o.. ........-... ..... ... ..... CORE NO. 9 (CONTINUED) (3358 - 3388) : REC. (3358 - 3388.3) ..............o. ................. ..o ........... . 3370.5 3371.5 3371.65 3372.65 3372.85 3373.15 3373.5 3374.0 3374.5 3375.0 RUBBLED MATERIAL - NO SAMPLE 31.1 15. 0.00 0.0 SECTION PRESERVED SECTION PRESERVED 60.4 536. 3.41 .67.2 41.3 811. 2.31 58.8 RUBBLED MATERIAL ' NO SAMPLE RUBBLED MATERIAL ' NO SAMPLE RUBBLED MATERIAL - NO SAMPLE RUBBLED MATERIAL..- NO SAMPLE at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ............... ' ........ SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY PermeabJLty gm/cc psi PERCENT mci. 93.3 93.3 2.77 3375.85 3376.2 3376.75 3377.3 3377.5 3378.3 3378.85 3379.25 3379.65 3380.15 32.0 12. 0.01 1.4 31.4 1.6 0.00 0.0 38.6 124. 0.62 25.9 38.0 146. 1.03 30.6 RUBBLED MA[ERIAL '.NO SAMPLE 40.1 203. 0.75" 26.1 31.7 9.3 * 0.04 2.9 32.4 4.2 0.03 2.3 34.9 20. ** 0.33 15.2 40.4 925. ** 1.35 38.Z 19~7 86.9 2.73 25.4 84.2 2.73 99.4 84.8 67.9 60.4 60.7 79.7 82.7 61.4 67.4 3380.8 3381.25 3381.8 3382.2 42.2 953. 3.51 50.5 41.1 471. 2.42 49.4 40.4 513. 1.74 40.5 33.0 31 . 0.05 3.5 98.0 84.8 42.0 29;t8 34.6 76.8 80.4 46.2 28.7 64.9 69.8 63.8 72.5 14.4 20.4 23.3 69.0 1000 29.9 4.0 1000 37.2 512.0 1000 37.4 693.0 2.75 1000 29.3 3.2 2.78 1000 28.4 0.5 2.73 1000 35.4 89.0 2.71 1000 35.0 62.0 2.69 1000 36.3 110.0 2.75 1000 29.4 2.0 * 2.74 1000 30.4 1.2 2.74 1000 30.6 15.0'* 2.72 SAJqPLE FAILED 2.7'3 2.?3 2.72 2.72 SAMPLE FAILED SAMPLE FAILED SAMPLE FAILED 1000 30.2 23.0 DESCRIPTION stty-ctst/fm stty-ss/vfn-fn/sft sLty-ss/vfn-fn/sft ctst/fm ctst/fm stst/fm sLst/fm stty-cLst/fm ctst/fm ctst/fm sLty-cLst/fm sLst/sft stst/sft stst/sft sLst/sft cty-stst/fm COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE, iNC. WELL gest Sak 3C-4 PAnE ~3 FILE No. 6509 DATE November 27, 1985 CORE ANALYSIS ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeabi(it¥ O/g ....................... FEET PERCENT md. RATIO OIL gATER TOTAL CORE NO. 9 (CONTINUED) (3358 - 3388) : REC. (3358 - 3388.3) 3382.7 38.8 244. 1.34 38.5 28.8 67.3 3383.15 36.4 60. 0.38 19.0 49.4 68.4 3383.65 39.1 253., 0.86 26.9 31.2 58.1 3384.2 41.3 395. 1.64 43.5 26.6 70.1 3384.75 39.7 227. 1.72 43.1 25.1 68.2 3385.2 39.1 357. 2.71 54.7 20.2 74.9 3385.7 37~6 1160. 3.49 59.7 17.1 76.8 3386.2 40.8 862. 3.01 55.9 18.6 74.5' 3386.45 40.3 750. 3.05 51.8 17.0 68.8 3387.0 RUBBLED MATERIAL - NO SAMPLE at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabi{ty gm/cc psi PERCENT md. ......... ........ ....o... 2.71 1000 36.1 221.0 2.72 1000 32.5 30.0 2.72 1000 35.4 231.0 2.72 1000 36.8 336.0 2.73 1000 36.3 183.0 2.70 1000 36.6 302.0 2.69 1000 35.1 992.0 2.71 1000 36.0 658.0 2.69 1000 37.8 588.0 DESCRIPTION sist/fm cty-stst/fm stst/fm sJst/fm slst/fm stst/fm stty-ss/vfn-fn/sft stty-ss/vfn-fn/sft stst/sft 3387.7 36.7 793. 0.96 36.0 37.6 CORE NO. 10 (3388 - 3414) : REC. (3388.3 - 3414.2) 3388.45 37.8 176. 1.31 42.1 32.1 3388.85 39.2 293. 0.86 32.7 38.2 3389.25 38.2 223. 0.75 30.9 41.3 3389.7 37.5 356. 0.62 29.0 47.0 3390.25 33.8 66. 0.18 11.2 62.8 3390.65 31.3 2.3 0.03 1.7 49.9 73.6 2.76 1000 34.9 409.0 74.2 2.73 1000 33.8 135.0 70.9 2.73 1000 35.2 204.0 72.2 2.73 1000 34.0 171.0 76.0 2.71 1000 35.1 328.0 74.0 2.73 1000 30.8 34.0 51.6 2.75 1000 29.3 1.8 SlSt/Sft stst/fm stst/fm s[st/fm stst/fm cty-stst/fm ctst/fm COMPANY Arco Ataska inc. PETROLEUM TESTING SER¥~CE, iNC, CORE ANALYSIS ~ELL ,West Sak 3C-4 .PAGE . ~14 FILE No, 6509 DATE November 27, ~985 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY 'Permeabitity 0/~ ....................... FEET PERCENT md. RATIO OIL WATER TOTAC ......., ..,.o... ....,.... .... o..o .-., ..-.o ..... e...o,......~o.. ............. . ........ CORE NO. 10 (CONTINUED) (]588 - ]416) : REC. (]]88.3 - 3614.2) -.....-............ ..... ............;. ....... ............... .... .... 3391.15 31,9 8.0 ** 0.16 9.2 56.9 66,1 3391.8 30.8 10. ** 0.00 0.0 79.6 79.6 3392.3 36.2 99. 0.59 26.0 44.3 70.3 3392.85 39.0 300. ** 1.12 38.0 34.0 72.0 3393.35 35.3 315. 0.66 29.8 45.2 75.0 3393.8 ]2.7 39. 0.07 5.1 71.6 76.7 3394.2 ]6.6 129. 0.62 26.8 43.3 70.1 3394.7 33.0 37, 0.08 6.0 73.0 79.0 3395.1 32.5 7.7 0.05 3.8 71.1 74.9 3395.?5 36.4 96. * 0.29 17.1 58.0 75.1 3396.25 31.2 4.5 0.01 0.6 83.5 84.1 3396.65 33.6 10. ** 0.23 14.0 62.0 76.0 3397.35 42.9 629. 0.87 34.9 39.9 74.8 3397.85 43.5 888. 1,47 45.0 30.7 75.7 3398.35 35.1 65. 0.11 7.6 70.4 78.0 3398.8 36.8 110. 0.37" 20.3 55.5 75.8 33~9.2 38.2 165. 0.89 33.1 37.2 70.3 33~9.7 32.8 9.0 0.12 8.7 70.5 79.2 * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY APPARENT SAND GRAIN 'DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATEO ....................... RESERVOIR Air STRESS ,POROSITY PermeabJity psi PERCENT md. ........ ....o... ....e...... 2.74 1000 29.6 6.0** 2.76 1000 27.4 7.5** 2.73 1000 33.6 38.0 2.72 1000 35.6 200.0'* 2.72 1000 32.0 88.0 2.75 1000 29.4 18.0 2.72 1000 33.8 78.0 .."' 2.74 1000 30.4 8.2 2.?0 1000 28.4 2.2 2.75 1000 32.5 46.0 * 2.72 1000 29.3 2.6 2.72 1000 29.7 7.0'* 2.71 1000 38.5 423.0 2.70 1000 40.4 663.0 2,72 1000 31.3 21.0 2.74 1000 33.5 65.0 2.72 1000 34.0 103.0 2.73 1000 30.0 4.1 ,DESCRIPTION ctst/fm ctst/fm cty-s[st/fm cty-stst/fm stst/fm s[ty-c[st/fm stst/fm slty-c[st/fm ~[ty-c[st/fm s[ty-c[st/fm stty-c[st/fm sity-c[st/fm s[st/sft s[st/sft s[ty-ctst/fm stty-c[st/fm s[ty-c[st/fm s[ty-c[st/fm COHPANY' Arco Alaska Inc.. PETROLEUM TESTING SERVICE'f INCo CORE ANALYSIS ARCNIHEDES Air POROSITY Permeability DEPTH O/g FEET PERCENT incl. RATIO OIL WATER TOTAL CORE NO. 10 (CONTINUED) (3388 - 3414) : REC. (3388.3 - 3414.2) APPARENT SATURATION ~ PORE SPACE SAND GRAIN ........................ DENSITY 9m/cc WELL at SIHULATED RESERVOIR STRESS SIHULATED ....................... RESERVOIR Air STRESS POROSITY Permeabt[ty psi PERCENT mci. 3400.15 33.8 16. 0.09 5.9 67.4 ~.3 2.71 1000' 30.8 9.3 3400.75 31.3 7.8 0.05 &.3 79.1 83.4 2.70 1000 29.6 3.2 3401.25 34.0 28. 0.19 1.2.1 62.2 74.3 2.71 1000 30.2 8.6 3401,85 35.0 29, 0.36 19.4 53.9 D.3 2.72 1000 31.6 13.0 3402.35 31,6 7.7 0.04 3.0 76.7 79.7 2.70 1000 28.2 2.5 3402.8 32.9 10. 0.02 1.3 59.9 61.2 2.72 1000 29,4 4.4 3403.2 32.1 16. 0.04 3.5 80.1 83.6 2.71 1000 28.8 4.8 3403.75 33.8 32. 0.04 3.0 73.4' 76.4 2.71 1000 30.9 14.0 3404.2 32.5 4.7 0.04 3.2 D.3 76.5 2.71 1000' 29;3 2,6 3404.65 30.6 4.8 0.01 0.4 80.9 81.3 2.72 1000' 28.0 2.6 3405.25 31,8 4.5 0.03 2.0 78.5 80.5 2.70 1000 28.0 2.1 3405.8 33.3 28. 0.01 1.2 80.2 81.4 2.71 1000 29.5 10.0 3406.25 33.9 34. 0.03 2.0 74.7 76.7 2.70 1000 30.7 19.0 3406.75 30.3 2.6 0.00 0.0 77.9 77.9 2.70 1000 27.7' 1.7 3407.2 30.8 2.5 0.00 0.0 79.9 79.9 2.70 1000' 27.1 1.6 3407.8 31.7 2.2 0.08 4.8 63.2 68.0 2.71 1000 28,3 1.4 3408.25 30.9 2.3 0.03 2.4 77.0 79.4 2.70 1000 27,7 1.3 3408.~ 31.1 3.8 0.01 1.1 79.9 81.0 2.71 1000 27.7 2.0 West Sak'3C-4 DESCRIPTION slty-ctSt/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm s[ty-ctst/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fa stty-ctst/fm stty-ctst/fa c[st/fm ctst/fm cist/fm c[st/fa PAGE ~5 ~ILE'No. 6509 DATE November 27, 1985 COHPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE, INCo CORE ANALYSIS gELL gest Sak 3C-4 o PAGE , 16 FILE No. 6509 DATE November 27, 1985 ARCHIHEDES Air SATURATION ~ PORE SPACE DEPTH POROSITY Permeability O/U ....................... FEET PERCENT md. RATIO OIL ~ATER TOTAL ~.e..o.~ .o-.-..- ...o.------o ----- ---, ----- ..........................................-...........--.-..-.------ CORE NO. 10 (CONTINUED) (3388 - 3414) : REC. (3388.3 - 3414.2) .......................................---.---.---------,----------- 3409.25 29.7 2.7 0.00 0.0 75,5 75,5 3409.75 32.7 10, ** 0.05 3.5 71,2 74.7 3410.2 28.6 2.7 0.03 2.0 66.6 68.6 3410.? 29.3 11. 0.03 1.8 63.1 64.9 3411.15 6.3 <0.05 0.00 0.0 7rL8 77.8 3411.65 29.5 4.6 0.02 1.4 67.9 69.3 3412.25 33.3 18. o.oz 4.7 66.7 71.4 3412.65 30.3 4.9 O.05 3.7 7o.7 74.4 3413.1 27.9 0.8 0.00 0.0 74,3 74.3 3413.75 29.5 0.9 , 0.00 0.0 62.8 62.8 3414.15 28.1 1.1 0.00 0.0 66.0 ......................................-...---------------- CORE NO. 11 (3417 - 3443) : REC. (3417 - 3442.75) ........................................ ..... o .... 3417.35 35.0 25. **. 0.24 12.2 51.4 3417.8 32.0 25. ** 0.11 7.7 67.3 3418.35 32.3 8.5 0.11 6.9 61.9 3418.8 31.3 6.0 0.05 3.9 78.7 3419.3 31.1 6.7 0.01 1.1 83.6 3419.75 33.2 15. 0.09 6.2 71.4 at SIHULATED RESERVOIR STRESS APPARENT SIHULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabitty gm/cc psi PERCENT md. ..o...... .=.o.... ........ 2.70 , 1000 26.0 1,3 2.71 1000 30.7 7.5** 2.70 1000 26.2 1.7 2.71 1000 26.8 6.0 2.66 1000 6.1 < 0.05 2.70 1000' 27.4 2.2 2.71 1000 30.0 8.2 " 2.72 1000 27;3 3.9 2.70 1000 25.6 0.4 2.71 1000, 27.1 0.4 66.0 2.70 1000 26.5 0.4 63.6 2.71 1000 31.3 17,0'* 75.0 2.71 1000 29.7 17.0'* 68.8 2.71 1000 29.7 6.1 82.6 2.71 1000 28.6 3.5 84.7 2.72 1000 28.1 3.1 77.6 2.71 1000 30.2 13.0 DESCRIPTION c[st/fm ctst/fm ctst/fm stty-ctst/fm catc-stst/hd s[ty-ctst/fm slty-c[st/fm $[ty-ctst/fm c[st/fm c[st/fm ctst/fm stty-ctst/fm stty-c[st/fm stty-ctst/fm slty-ctst/fm stty-c[st/fm stty-ctst/fm FRACTURED, ESTIHATED AIR PERMEABILITY · COMPANY Arco Alaska Inc. .PETROLEUM TESTING SERViCEo .iNC. CORE ANALYSIS ARCHIMEDES Air SATURATION ~ PORE SPACE DEPTH POROSITY PermeabJtity 0/~ ....................... FEET PERCENT md. RATIO Oil VATER TOTAL o....... ...o...o ....o......o .... . ... o ......... oo.. ........'..... ...........................'........................ CORE NO. 11 (CONTINUED) (3417 - 3443) : REC. (3417 - 3442.75) ......o..o......o... ......... ........... ...... .o .... 3420.3 32.6 4.7 0.03 2.1 79.8 81.9 3420.8 32.1 23. 0.02 1.4 64.6 66.0 3421.2 30.9 12. 0.04 2.4 67.6 70.0 3421.8 30.3 11. 0.01 0.8 71.2 72.0 3422.3 31.0 8.3 0.01 0.9 82.0 82.9 3422.75 31.7 10. 0.03 1.7 62.6 '~.3 3423.25 3i.5 8.7 0.01 0.4 63.4 63.8 3423.7 31.2 4.0 0.05 3.5 75.0 78.5 3424.25 30.6 7.1 0.05 3.4 ~.4 76.8 3424.75 31.0 4.1 0.04 3.0 78.2 81.2 3425.3 31.6 5.4 0.01 1.1 82.6 83.7 3425.7 30.7 4.5 0.01 0.9 81.0 81.9 3426.3 30.1 9.5 0.03 2.5 77.2 79.7 3426.85 37.0 384. 0.66 30.0 45.8 75.8 3427.25 45.0 298. * 0.66 32.1 48.4 80.5 3427.65 41.0 62. * 1.70 49.1 28.8 77.9 3428.2 33.0 11. 0.48 23.9 49.7 7'3.6 3428.7 36.7 48. 0.58 26.8 46.2 APPARENT SAND GRAIN DENSITY gm/cc SIMULATED RESERVOIR STRESS Psi * FRACTURED VELL at SIMULATED RESERVOIR STRESS Air POROSITY Permeabi[ty PERCENT md. 2.72 1000 29.3 3.0 2.70 1000 29.3 13.0 2.70 lOOp 29.6 6.1 2.70 1000 27.5 5.6 2.72 1000 28.9 3.6 , 2.72 ,1000 29.2 5.4 2.71 1000 29.4 ' 4.1 2.72 1000 28.7 2.1 2.70 1000 28.2 3.5 2.71 ,1000 28.1 2.2 Vest Sak PAGE ,17 FILE No. 6509. DATE November 27, .~985 2.72 1000 28.4 2.7 2.71 1000 28.1 1.2 2.70 1000 26.7 4.3 2.71 1000 34.1 221.0 2.72 1000 39.8 271.0 2.71 1000 38;5 48.0 2.72 1000 29.9 8.0 2.73 1000 34.4 38.0 DESCRIPTION sity-cist/fm stty-cist/fm s[ty-c(st/fm s[ty-ctst/fm stty-ctst/fm s[ty-ctst/fm s[ty-ctst/fm stty-ctst/fm stty-c~st/fm slty-c~st/fm stty-cLst/fm stty-ctst/fm sLty-c~st/fm stst/sft stty-ctst/fm s[ty-c~st/fm s[ty-c~st/fm stst/sft COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICEd,INC. CORE ANALYSIS VELL 'Vest Sak 3C-4 PAGE. 18 ',FILE No. 6509 DATE November 27,'1985 ARCHIHEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/V ....................... FEET PERCENT md. RATIO OIL VATER TOTA~ ... ............. .......---.- ..... ... ... ..... · ............'......................---------------------------------. CORE NO. 11 (CONTINUED) (3417 - 3443) : REC. (3417 - 3442.75) ...~.........o...... ..... ..... 3429.25 45.5 392. 0.71 32.6 46.0 78.6 3429.7 36.3 91. 0.35 18.7 54.0 72.7 3430.25 32.6 5.3 0.03 2.5 72.6 75.1 3430.7 37.7 56. 0.19 12.8 66.0 78.8 3431.25 38.8 40. * 0.00 0.0 89.1 89.1 3431.65 38.3 292. 1.37 44.8 32.7 77.5 3432.4 36.6 1980. * 0.06 4.2 75.9 80.1 3432.85 32.2 6.2 0.00 0.0 78.7 78.7 3433.35 32.1 7.5 0.00 0.0 79.2 79.2 3433.8 31.8 8.7 0.00 0.0 79.2 79.2 3434.3 32.3 13. 0.00 0.0 80.9 80.9 3434.75 32.6 7.7 0.00 0.0 76.8 76.8 3435.35 32.5 5.8 0.00 0.0 .6~.8 64.8 3435.85 32.1 6.1 0.00 0.0 7~.3 79.3 3436.3 31.5 5.2 0.00 0.0 73.5 73.5 3436.8 31.4 9.0 0.00" 0.0 81.6 81.6 3437.2 31.9 5.8 0.01 0.9 72.3 73.2 3437.65 32.2 7.8 0.06 4.2 68.9 73.1 FRACTURED APPARENT SAND GRAIN DENSITY gm/cc SIMULATED RESERVOIR STRESS psi , at SIMULATED RESERVOIR STRESS .....................-. POROSITY Permeabitty PERCENT md, 2.72. 1000 41.2 295.0 2.71 :1000 32.7 67.0 2.7'5 1000 30.1 3.6 2.72 1000 33.5 42.0 2.80 1000 36.2 16.0 2.71 1000 35.4 98.0 2.71 1000 33.8 979.0'* 2.70 1000 29.9 3.9 2.70 1000 29.8 4.4 2.69 1000 29.7 5.0 2.71 1000 30.1 8.6 2.71 1000 30.7 4.5 2.71 1000 30.4 4.6 2.71 1000 30.7 3.5 2.71 1000 29.4 3.0 2.71 1000 29.6 5.0 2.70 1000 30.1 3.8 2.70 1000 30.3 4.1 DESCRIPTION stst/sft stst/sft stty-ctst/fm cty-stst/sft ctst/fm s[ty-c[st/sft stty-ctst/fm s[ty-ctst/fm s[ty-c[st/fm s[ty-c[st/fm stty-ctst/fm stty-ctst/fm slty-ctst/fm stty-ctst/fm s[ty-c[st/fm stty-c[st/fm stty-ctst/fm stty-c[st/fm COMPANY Arco ALaska inc., PETROLEUM TESTING SERVICE',, iNC. ~E'L~ West Sak 3C-4 PAGE 1~ FILE No. 6509 'DATE November 27, ~985 ., ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY PermeabiLity 0/~ ........................ FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 11 (CONTINUED) (3417 - 3443) : REC. (3417 - 3442.75) 3438.4 43.2 465. 1.15 37.6 32.8 70.4 3438.8 60.6 276. 1.09 42.3 38.8. 81.1 3439.25 34.3 333. 0.93 45.5 48.8 94.3 3439.7 45.1 200. ** 0.77 32.7 42.3 75.0 3440.2 36.3 100. ** 0.06 4.1 64.7 68.8 3440.65 33.3 9.5 0.15 10.7 72.5 83.2 3441.2 29.1 3.9 0.00 0.0 88.8 88.8 3441.7 30.6 4.4 0.05 3.6 78.5 82.1 3442.1 35.1 38. 0.49 26.4 54.2 80.6 3442.7 29.9 2.8 0.02 1.9 85.7 87.6 CORE NO. 12 (3443 - 3474) : REC. (3443 - 3475.7) 3443.2 31.7 8.7 0.02 1.8 83.3 3443.7 34.6 5.6 0.15 11.0 72.9 3444.25 33.6 20. 0.15 10.0 67.3 3444.8 33.9 10. 0.23 12.7 55.7 3445.15 33.1 5.1 0.15 10.2 66.2 3445.7 32.1 4.6 0.10 7.2 72.3 3446.15 32.0 4.8 0.09 5.9 67.0 CORE ANALYSIS ** FRACTURED, ESTIMATED AIR PERMEABILITY at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY PermeabiJty gm/cc psi PERCENT md. 2.71 tooo 38.~ 359.0 2.70 iO00 36.3 194.0 2.70 1000 32.5 237.0 2.75 1000 39.4 150.0'* 2.70 1000 33.9 75.0'* 2.7Z 1000 31.4 4.0 2.70 1000 26.7 2.0 2.69 1000 29.0 2.8 2.70 ~000 32.0 21.0 2.69 iOOb 27.6 1.5 ; , 85.1 2.69 ~000 28.7 3.8 83.9 2.69 1000 31.4 3.3 77.3 2.69 1000 30.9 10.0 68.4 2.68 i000 31.6 6.7 76.4 2.70 i000 29.8 2.7 79.5 2.69 1000 30.~ 2.4 72.9 2.69 1000 30.3 2.1 DESCRIPTION sJst/sfZ stst/fm s[st/fm cty-stst/fm c[y-s[st/fm foss-stty-ctst/fm stty-cLst/fm s[ty-ctst/fm stty-cLst/fm c[st/fm skty-ctst/fm sLty-c[st/fm stty-cLst/fm stty-6[st/fm s[ty-ctst/fm s[ty-ctst/fm sLty-ctst/fm COMPANY Arco Alaska Inc. PETROLEUM TESTING SERVICE~ INC. CORE ANALYSIS WELL Wes,t Sak 3C-4 PAGE , 20 FILE No. 6509 DATE November 27, 1985 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeabittty 0/~ ....................... FEET PERCENT md. RATIO OIL WATER TOTAL ..e..... ....... ...................... ..oo .............'....................................................... CORE NO. 12 (CONTINUED) (3443 - 3474) : REC. (3¢43 - 3473.7) IllllelllllmeJlJJlellllelmllllmjllelll/Jljellllllmllmlmmm,lmmmmlmmelm 3446.8 32.9 5.1 0.15 9.4 63.3 72.7 3447.3 31.2 3.1 0.05 3.5 75.0 78.5 3447.7 31.4 3.6 0.04 3.7 84.3 88.0 3448.3 32.2 5.4 0.22 14.2 63.5 7r.r 3448.9 33.5 12. 0.15 8.8 58~9 67.7 3449.3 31.3 4.6 0.04 3.2 7'3.7 Z6.9 3449.75 29.4 2.9 0.04 2.8 71.2 74.0 3450.2 29.4 2.9 0.17 11.1 64.4 75.5 3450.7 29.1 7.1 0.02 1.2 7~.0 74.2 3451.2 29.6 5.6 0.06 4.4 71.8 76.2 3451.7 31.0 7.0 0.12 7.5 63.1 70.6 3452.2 28.9 5.5 0.02 1.2 77.6 78.8 3452.8 29.0 2.5 0.09 5.7 63.0 68.7 3~53.3 32.0 7.8 0.20 12.5 61~L6 74.1 3~53.75 30.2 1.1 0.05 3.6 75.0 78.6 3454.25 30.~ 4.8 0.04 " 2.7 71.2 73.9 3454.75 31.1 3.6 0.04 2.7 73.5 76.2 3455.2 31.9 13. 0.04 2.6 68.7 71.3 APPARENT SAND GRAIN DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY PermeabJtty psi PERCENT md. .... .... ....0..~ 2.70 1000 30.0 2.9 2.69 1000 29.0 1.8 2.68 1000 29.5 1.0 2.69 1000 30.0 2.5 2.70 1000 31.5 7.1 2.72 1000 29.2 2.1 2.69 1000 28.1 1.7 ."' 2.70 1000 27,8 1.3 2.68 1000 28.2 2.8 2.67 1000 27.9 2.7 2.67 1000 29.0 3.7 2.67 1000 27.3 2.2 2.67 1000 27.8 1.2 2.68 1000 30.0 4.9 2.66 1000 28.5 1.0 2.66 1000 28.5 1.3 2.67 1000 29.1 2.1 2.68 1000 29.2 12.0 DESCRIPTION stty-c[st/fm stty-c[st/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm stty-ctst/fm s[ty-cLst/fm S[ty-ctst/fm Stty-cLst/fm stty-cLst/fm stty-ct'st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm ctst/fm ctst/fm c[st/fm stty-c[st/fm ,,~ ::='7 COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE,, INC. CORE ANALYSIS ARCHIHEDES Air SATURATION % PORE SPACE DEPTH POROSITY PermeabitJty 0/~ .... , ................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 12 (CONTINUED) (3443 - 3474) : REC. (3443 - 3473.7) 3455.75 30.9 3.7 0.05 3.2 69.9 73.1 3456.3 32.0 4.1 0.01 1.1 78.9 80.0 3656.85 33.2 29. * 0.00 0.0 82.9 82.9 3457.3 32.7 0.8 0.00 0.0 85.2 85.2 3457.5 SECTION PRESERVED 3458.5 SECTION PRESERVED 3458.85 28'6 1.5 0.03 2.0 71.8 73.8 3459.3 30.2 7.9 0.02 1.3 74.2 75.5' 3459.75 28.7 2.0 0.03 2.5 73.7 76.2 3460.25 29.3 12. 0.05 3.3 71.2 74.5 3460.8 30.5 10. 0.03 2.2 70.3 72.5 3461.25 29.0 3.8 0.02 1.4 76.2 77.6 3461.65 30.3 30. ** 0.03 2.0 66.2 68.2 3462.2 30.5 20. ** 0.02 1.3 71.7 ~.0 3462.7 29.0 5.6 0.04 3.1 75.4 78.5 3463.15 27.6 2.7 0.02 1.7 73.5 75.2 3463.7 29.5 2.2 0.02 1.6 78.3 79.9 3464.25 29.9 3.6 0.03 2.2 76.9 79.1 3464.65 35.7 20. ** 0.35 18.4 51.9 70.3 APPARENT SAND GRAIN DENSITY gm/cc SIMULATED RESERVOIR STRESS psi at SIMULATED RESERVOIR STRESS ....................... ASr POROSITY Permeabilty PERCENT md. ........ * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY 2.66 1000 29.0' 2.0 2.67 lO00 29.8 1.8 2.69 1000 30.6 2.7 * 2.68 1000 30.9 0.7 2.68 1000 26.2 0.8 2.69 1000 26.9 4.2 2.69 1000 25.9 1.1 2.67 1000 27.7 4.9 West, Sak 3C-4 PAGE 2~ FiLE No. 6509 DATE November 27,1985 2.69 1000 27.1 4.6 2.69 1000 26.3 1.7 2.69 1000 27.5 20.0** 2.70 1000 28.3 15.0'* 2.69 1000 27.2 2.0 2.68 1000 24.6 0.8 2.68 1000 26.2 0.7 2.67 1000 27.6 1.1 2.70 1000 33.1 15.0'* DESCRIPTION ctst/fm sJty-ctst/fm c[st/fm cist/fm c[st/fm sJty-c[st/fm c[st/fm s[ty-c[st/fm s[ty-c[st/fm s[ty-c[st/fm s[ty-c[st/fm ctst/fm stty-ctst/fm ctst/fm c[st/fm ctst/fm stty-ctst/fm COMPANY Arco Alaska Inc. PETROLEUM TESTING SERVI'CE~ ~NCo CORE ANALYSIS ~EL~ PAGE .22 FILE No. 6509 DATE November 27, 1985 gest' Sak 3C-4 o ARCHIMEDES . Air SATURATION % PORE SPACE DEPTH POROSITY Permeabitity O/g ....................... FEET PERCENT md. RATIO OIL gATER TOTAL ........ ...,~.... .o.o. .... . ........... o ....... ............................................ .... .....o... .... CORE NO. 12 (CONTINUED) (3443 - 3474) : REC. (3443 - 3473.7) .... ..............o....... .... ......o.... ........ 3465.2 29.0 6.0 0.04 2.8 69.8 72.6 3465.7 40.6 120. 0.38 20.2 53.3 73.5 3466.15 41.0 289. 2.54 41.4 16.3 57.7 3466.7 34.3 20. ** 0.32 16.8 5278 69.6 3467.35 33.9 13. 0.21 11.7 55.7 67.4 3467.75 36.3 74. 0.93 33.? 36.2 69.9 3468.35 36.2 10. 0.16 10.1 63.4 73.5 3468.8 32.5 10. 0.25 16.2 6~.2 80.4 3469.15 30.7 2.9 0.03 2.6 85.7 88.3 3469.7 29.9 3.6 0.05 4.1 81.3 85.4 3470.25 32.0 17. 0.51 26.9 53.1 80.0 3470.9 33.8 29. 0.58 29.1 50.3 79.4 3471.25 30.9 22. 0.14 10.1 7~..1 83.2 3471.85 32.3 28. 0.29 17.9 62~4 80.3 3472.25 32.5 28. 0.05 4.1 75.0 79.1 ·, 3472.65 29.5 3.4 0.10 7.5 78.0 85.5 347'3.25 28.7 2.4 0.07 5.8 77.6 83.4 3473.65 29.8 12. 0.06 5.1 78.8 83.9 FRACTURED, ESTIMATED AIR PERMEABILITY APPARENT SAND GRAIN DENSITY gm/cc SIMULATED. RESERVOIR STRESS psi at SIMULATED RESERVOIR STRESS ....................... POROSITY Pe~meabilty PERCENT md. ........ 2.69 ' 1000 26.9 2.0 2.70 1000 38.1 103.0 2.70 1000 37.6 222.0 2.67 1000 31.1 15.0'* 2.68 1000 30.6 6.7 2.69 1000 33.3 47.0 2.70 1000 32.8 5.0 ~ 2.66 1000 30.0 6.8 2.65 1000 28.5 1.1 2.65 1000 27.5 1.7 2.66 1000 29.4 5.7 2.69 1000 30.5 15.0 2.66 1000 28.0 6.6 2.66 1000 29.5 9.3 2.65 1000 30.0 13.0 2.67 1000 27.7 1.7 2.66 1000 26.2 1.2 2.66 1000 26.5 5.5 DESCRIPTION ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm stty-ctst/fm Stty-ctst/fm slty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm s[ty-ctst/fm s~ty-c[st/fm stty-c[st/fm s[ty-c[st/fm COMPANY Arco Alaska Inc. ARCHIMEDES Air DEPTH POROSITY Permeabitity O/W FEET PERCENT md. RATIO OIL WATER .......................................................... CORE NO. 13 (3474 - 3503) : REC. (3473.7 - 3501) SATURATION X PORE SPACE TOTAL 3674.1 28.0 2.2 0.00 0.0 96.0 96.0 3474.6 34.9 25. ** 0.43 23.0 53.5 76.5 3475.2 28.9 5.0 0.01 1.0 83.2 84.2 3475.65 27.6 2.2 0.03 '2.7 85.7 88.4 3476.15 27.7 3.7 0.04 3.6 81.4 85.0 3476.65 29.0 1.6 0.00 0.0 94.2 94.2 3477.35 27.2 3.8 0.06 5.1 84.8 89.9 3477.7 27.0 1.7 0.08 7.0 82.7 89.7 3478.2 30.7 15. 0.11 8.4 73.6 82.0 3478.75 30,5 3,8 0,05 4.3 81.7 86.0 3479.2 29.8 5.0 0.06 4.8 80.6 85.4 3479.75 30.3 5.1 0.02 2.0 84.0 86.0 3480.25 28.2 4.2 0.04 3.3 81.2 84.5 3480.7 32.7 15. ** 0.04 2.9 75.9 78.8 3481.15 29.5 2.6 0.11 8.2 77.8 86.0 3481.65 34.4 8.0 ** 0.49 23.9 49.2 73.1 3482.25 29.0 2.2 0.02 1.6 86.6 88.2 3482.8 30.9 2.1 0.00 0.0 92.5 92.5 3483.2 32.6 24. 0.10 7.6 74.5 82.1 3483.6 32.0 3.9 0.04 3.5 80.4 83.9 PETROLEUM TESTING SERVICED.INC. CORE ANALYSIS APPARENT SAND GRAIN ., DENSITY gm/cc SIMULATED RESERVOIR STRESS , psi WELL West Sak 3C-4 PAGE 23 FILE No. 6509 DATE November 27. 1985 at SIMULATED RESERVOIR STRESS ....................... Air POROSITY Permeabltty PERCENT mci. ........ ........... DESCRIPTION ........... 2.67 2.65 2.66 2.66 2.66 2.67 2.76 2.66 2.67 2.67 ,1000 26.1 0.7 1000 30.7 17.0'* 1000 27,4 2.7 1000 25.3 1.2 1000 25.8 2.1 1OD0 26.5 O.7 1000 25.8 - 1.9 1000 24.5 0.8 1000 28.0 6.5 1000 28.4 2.0 2.67 1000 27.5 2.5 2.67 1000 28.0 2.8 2.68 1000 25.9 2.1 2.70 1000 29.1 10.0'* 2.69 1000 27.0 1.3 2.71 SAMPLE FAILED 2.68 1000 27.0 1.1 2.69 1000 28.9 0.9 2.70 1000 29.8 14.0 2.69 1000 28.8 2.2 stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm ,stty-c~st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm .ctst/fm ,ctst/fm stty;ctst/fm stty-ctst/fm ctst/fm stt¥-ctst/fm ,stty-ctst/fm ** FRACTURED, ESTIMATED AIR PERMEABILITY COHPANY Arco Alaska Inc. PETROLEUH TESTING CORE ANALYSIS WELL West Sak 3C-4 ,PAGE 24 ~F~I. LE No. 6509 ,DATE November 27, 1985 ARCHIMEDES Air DEPTH POROSITY Permeabitity O/g FEET PERCENT md. RATIO ........ ....o... ....o....... ..... SATURATION % PORE SPACE ....................... OIL WATER TOTAL' CORE NO. 13 (CONTINUED) (3474 - 3503) : REC. (347"5.7 - 3501) 3684.1 29.4 1.3 0.02 1.6 88.8 90.4 3484.7 30.7 2.7 0.02 2.0 87.2 89.2 3485,2 30,1 6,7 0,01 0,6 88,2 88,8 3485.8 29,6 2,0 0,00 0,0 91,8 91,8 3486,2 29,1 1,5 0,01 0,8 90;2. 91,0 3486.7 29.8 1.5 0.00 0.0 91.9 91.9 3487,1 28.8 1,5 0,00 0,0 92.6 92,6 3487.65 29.6 3.9 0.00 0.0 92.5 92.5 3488.2 30.8 2.5 0.01 1.2 89.7 90.9 3488.75 28.8 1.2 0.01 0.6 93.2 93.8 3489.15 28.7 5.0 ** 0.00 0.0 94.9 94.9 3489.8 29.1 2.2 0.00 0.0 89.7 89.7 3490.25 29.2 1,1 0,00 0,0 92,0 92,0 3490,8 28,6 5.0 ** 0,00 0,0 92r4 92.4 3491,3 28,9 2,1 0,00 0,0 91,4 91,4 3491,8 29.6 5,6 0,00 .' 0,0 93,3 93.3 3492.2 28.1 14, * 0.00 0.0 87,8 87,8 3492.65 29,9 2,5 0,00 0.0 89,4 89,4 * FRACTURED ** FRACTURED, ESTIHATED AIR PERMEABILITY APPARENT SAND GRAIN DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY Permeabl[ty psi PERCE,N~ md. -------- ~....o.. 2.67 1000 26.8 0.7 2.69 1000 28.1 1.5 2.69 1000 27.4 2.6 2.69 1000 26.2 1.1 2.68 1000 27.3 0.8 2.69 1000 27.7 0,8 2.69 1000 26.7 1.0 ,," 2.67 1000 27.0 2.1 2.69 1000 27.9 1.7 2.68 1000 27.0 0.7 2.69 1000 27.0 3.0'* 2.68 1000 27.2 1.1 2.68 1000 26.8 0.7 2.68 1000 26.2 3.0** 2.68 1000 26.5 1.3 2.67 1000 27.0 2.5 2.68 1000 26.1 5.2 * 2.70 1000 27.6 1.2 DESCRIPTION' ctst/fm s[ty-ctst/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm c[st/fm c[st/fm s[ty-ctst/fm S[ty-c[st/fm clst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm c[st/fm c[st/fm PETROLEUH ,TESTING SERVICE. ~lNC. PAGE 25 FILE No. 6509 'DATE :Novenber 27, 1985 COMPANY Arco Alaska Inc. WELL West Sak 3C-4 .CORE ANALYSIS ARCHIMEDES Air SATURATION ~ PORE SPACE DEPTH POROSITY Permeabitity O/W .... : .................. FEET PERCENT md. RATIO' OIL WATER TOTAL ............. ~ ..... ........................ ...... CORE NO. 13 (CONTINUED) (3474 - 3503) : REC. (3473.7 - 3501) 3493.25 29.6 4.2 * 0.00 0.0 90.4 90.4 3493.75 30.8 2.6 0.01 1.0 89.2 90.2 3494.25 33.7 14. 0.22 14.2 65.6 79.8 3494.75 32.1 11. 0.00 0.0 89.3 89.3 3495.2 32.8 16. 0.00 0.0 88.1 88.1 3495.6 32.3 12. 0.00 0.0 90.5 90.5 3496.15 32.4 13. 0.00 0.0 92.9 92.9 3496.75 33.2 7.3 0.10 7.7 79.7 87.4 3497.2 33.8 11. 0.40 24.1 59.8 83.9 3497.65 34.8 32. 0,34 20.3 59.5 79.8 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air . DENSITY STRESS POROSITY PermeabJ[ty gm/cc psi PERCENT md. 2.69 ~000 27.9 1.7 2.70 1000 28.7 1.2 2.69 1000 30.3 9.1 2.70 1000 29.2 3.6 2.70 1000 29.7 5.4 2.71 1000 29.3 4.4 2.70 1000 29.3 4.7 2.71 1000 30.4 3.4 2.71 1000 30.2. 5.4 .2.70 1000 32.8 11.0 ,DESCRIPTION c[st/fm s[ty-c[st/fm s[ty-c[st/fm s[ty-c[st/fm stty-ctst/fm s[ty-c[st/fm s[ty-c[st/fm s[ty-ctst/fm s[ty-c[st/fm s[ty-ctst/fm 3497.8 SECTION PRESERVED 3498.8 SECTION PRESERVED 3499.2 38.8 131, 1.09 41.2 37.7 3499.75 38.8 556. 0.54 27.6 51.1 3500.5 36.9 184. 1.53 47.6 31.2 3500.8 36.3 320. 1.46 45.4 31.0 CORE NO. 14 (3503 - 3534) : REC. (3501 - 3532.35) 3501.2 35.8 31. 1.09 42.6 39.0 3501.75 41.4 30. ** 0.55 29.4 53.2 78.9 2.68 1000 35.1 114.0 78.7 2.69 1000 34.7 458.0 78.8 2.68 1000 33.9 169.0 76.4 2.68 1000 33.4' 309.0 81.6 2.69 1000 32.8 21.0 82.6 2.69 1000 37.0 20.0** stst/fm stst/fm s[st/fm stst/fm stty-c[st/fm sity-ctst/fm FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska Inc, PETROLEUM TESTING SERV~CEo~.NCo CORE AJiALYSI S WELL Vest Sak'3C-4 'PAGE .26 FiLE No. 6509 DATE November 27o'1985 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeabitity O/g ....................... FEET PERCENT mci. RATIO OIL UATER TOTAL ........ ...... .... .........o o..o. ... ..~.. ........... .... ..................................................... CORE NO, 14 (CONTINUED) (3503 - 3534) : REC, (3501 - 3532,35) 3502.25 32.2 4.1 0.16 12.0 74.4 86.4 3502.85 34.5 10. ** 0.14 10.2 75.2 85.4 3503.25 34.3 9.8 0.05 4.1 75.1 79.2 3503.75 37.1 20. ** 0.23 15.8 69.5' 85.3 3504,2 33,3 8,5 0,11 7,8 73.'6 81,4 3504.75 33.6 7.7 0.54 29.6 54.5 84.1 3505.3 30.9 5.9 0.02 1.5 84.8 86.3 3505.8 31.8 7.5 0.02 1.4 85.6 87.0 3506.25 33.6 20, 0.20 12.7 64.3 77.0 3506.75 34.3 25, 0.44 23,8 53,6 77,4 3507.1 36.0 30. ** 0.35 21.7 62.7 84.4 3507.7 34.7 54. 0.40 23.1 57.9 81.0 3508.2 33.5 16. 0.61 30.1 49.7 79.8 , $508.75 32,5 15. 0.12 8.5 71~5 80.0 3509.15 34.2 50. ** 0.19 12.3 63.8 76.1 · , 3509.65 34.3 50. ** 0.05 3.9 71.5 75.4 3510.25 33.3 17. 0.17 11.4 66.2 77.6 3510.75 35.1 20. ** 0.19 11.9 64.3 76.2 FRACTURED, ESTIMATED AIR PERMEABILITY APPARENT SAND GRAIN DENSITY gm/cc SIMULATED RESERVOIR STRESS psi at SIMULATED RESERVOIR STRESS Air POROSITY PermeabJtty PERCENT mci. 2.69 . 1000 29.1 2.1 2.68 1000 32.0 7.0** 2.69 1000 30.9 5.5 2.69 1000 35.3 15.0'* 2.69 1000 31.7 5.4 2.67 1000 30.0 5,1 2.66 1000 28.1 2.0 "' 2.65 1000 28.9 4.7 2.67 1000 31.0 12.0 2.67 1000 31.0 11.0 2,67 1000 33.1 20,0** 2,66 1000 31.6 21.0 2.67 1000 31.3 11.0 2,67 1000 29,9 9.8 2.68 1000 31,1 35,0'* 2.68 1000 31.4 35.0** 2.69 1000 31.2 11.0 2,68 1000 31.8 15,0'* DESCRIPTION sity-c[st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm s[ty-ctst/fm s[ty-c[st/fm s[ty-c[st/fm stty-c[st/fm s[ty-ctst/fm s[ty-c[st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm stty-c[st/fm stty-ctst/fm s[ty-c[st/fm slty-ctst/fm PETRoLI~UI~ TESTING SERV~ iN'C. PAGE 27 FILE No. 6509 DATE November 27, 1985 COMPANY Arco Alaska nc ? WELL West Sak 3C-4 CORE ANALYSIS ARCHIHEDES Air SATURATION X PORE sPAcE DEPTtl POROSITY Permeabi(ity 0/~ FEET PERCENT' md. RATIO OIL WATER TOTAL ... .......... ........................... ....... ..................... CORE NO. 14 (CONTINUED) (3503 - 3534) : REC. (3501 - 3532.35) 3511.25 30.5 4.0 0.06 4.3 75.1 79.4 3511.75 30.9 2.2 0.01 0.7 84.4 85.1 3512.15 33.8 23. 0.08 6.0 73.2 79.2 3512.7 31.2 2.7 0.24 15.6 64.9 80.5 3513.15 32.9 30. ** 0.22 13.8 61.9 75.7 3513.75 32.4 5.6 0.02 1.6 76.0 ?7.6 3514.2 31.3 27. 0.21 14.1 66.8 80.9 3514.7 30.3 3.7 0.04 3.6 80.2 83.8 3515.2 29.3 4.7 0.07 5.6 80.7 86.3 3515.7 34.7 20. ** 0.10 6.4 64.2' 70.6 AppARENT SAND GRAIN · DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY Permeabitty ps~ PERCENT md. 2.66 1000 28. i 3.1 2.67 i000 28.2 1.6 2.68 1000 30.1 7.9 2.68 1000 29.7 1.9 2.67 1000 29.2 20.0'* 2.68 1000 30.7 3.9 2.68 SAMPLE FAILEO' 2.68 1000 27.3 2.5 2.68 1000 27.0 3.3 · 2.65 1000 30.5 15.0'* DESCRIPTION stty-cLst/fm sLty-ci~t/fm stty-ctst/fm stty-ctst/fm stty-c~st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm sLty-c~st/fm stty-ciSt/fm 3516.25 30.2 3.6 0.13 9.6 73.0 82.6 3516.8 32.7 4.1 0.17 11.4 66.5 77.9 3517.35 31.6 4.4 0.05 4.1 77.4 81.5 3517.8 31.6 7.2 0.09 6.6 72.2 78.8 3518.25 28.3 2.1 0.06 5.2 82.6 87.8 3518.65 28.5 1.5 0.03 2.4 88.3 90.7 3519.25 29.5 2.6 0.03 2.3 84.1 86.4 3519.7 28.6 3.7 0.03 2.2 85.1 87.3 3520.25 30.8 2.9 0.03 2.6 83.1 85.7 2.69 1000 27.2 2.6 2.70 .1000 30.6 3.0 2.70 1000 29.1 3.2 2.70 1000 28.8 4.8 2.70 1000 25.9 1.4 2.70 1000 25.5 0.9 2.69 1000 26.2' 2.2 2.69 1000 25.0 2.8 2.70 1000 28.? 2.1 stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco A[aska Inc. PETROLEUM TESTING SERVICE~I~C, CORE ANALYSIS ~ELL, West Sak3C-4 PAGEI 28, FILE No. 6509 DATE November 27, 1985 RRCHIMEOES Air' SATURATION X PORE SPACE DEPTH POROSITY Permeabittty O/g ....................... FEET PERCENT ~d. RATIO OIL WATER TOTAL ........ ......o. ......... ....... . .... ..... oo....~.o. ...... ..................... ........ ....................... CORE NO. 14 (COHTIHUEO) (3503 - 3534) : REC. 43501 - 3532.35) 3520.8 30.9 4.0 0.02 1.4 80.8 87.2 3521.25 30.2 2.1 0.01 0.8 88.1 88.9 3521.7 29.6 3.3 0.01 0.2 90.6 90.8 3522.3 31.8 20. ** 0.04 3.2 83.6' 86.8 , 3522.8 29.5 14. 0.01 0.6 83.0 83.6 3523.3 30.2 25. ** 0.03 2.4 86.6 89.0 3523.8 29.6 25. ** 0.00 0.0 88.9 88.9 3524.2 27.4 3.8 0.00 0.0 93.3 93.3 3524.65 29,2 25. ** 0.01 1,0 87.4 88.4 3525.15 30,9 4.3 0.00 0.0 94.0 94.0 3525.7 29,0 25. ** 0.03 2.4 89.3 91.7 3526.2 28.8 3.8 0.02 1.6 93.? 95.3 3526.75 33.5 17. 1.11 47.3 42.6 89.9 3527.25 32.5 3.0 0.03 3.0 90~6 93.6 3527.8 32.0 2.7 0.21 14.9 71.1 86.0 · , 3528.3 34.3 1020, * 0.01 0.5 87.2 87.7 3528.7 33.2 20. ** 0.05 4.4 82.9 87.3 3529.15 29.2 2.6 0.00 0.0 94.7 94.7 3529.8 28.1 5.8 0.00 0.0 89.4 89.4 APPARENT SANO GRAIN DENSITY gm/cc SIMULATED RESERVOIR STRESS psi at SIMULATED RESERVOIR STRESS A(r POROSITY Permeabitt¥ PERCENT, mci. 2.70 1000 28.7, 2.7 2.70 1000, 28.1 1.4 2.70 1000 26.4 1.8 2.70 1000 28.1 15.0'* 2.68 1000 27.0 8.7 2.69 SAMPLE FAILED 2.67 1000 27.9 I?.0'*""' 2.66 1000 26.0 2.0 2.66 1000 26.9 17.0'* 2.67 1000 27.2 2.5 2.64 1000 26.0 17.0'* 2.65 1000 25.6 2.1 2.65 1000 30.6 14.0 2.Zl 1000 29.3 1.7 2.70 1000 28.3 1.8 2.76 1000 31.1 152.0 * 2.70 1000 30.7 15.0'* 2.71 1000 27.5 1.4 2.62 1000 26.7 3.2 DESCRIPTION slty-cist/fm sity-ctst/fm stty-ctst/fm s{ty-c,tst/fm s[ty.c{st/fm s[ty-c{st/fm s{t¥-c{st/fm stty. ctst/fm stty-clst/fm slty-ctst/fm stty-cist/fa stty-ctst/fm stty-ctst/fm stty-ctst/fm s[ty-c[st/fm stty-ctst/fm s[ty-ctst/fm s[ty-c[st/fm s[ty-ctst/fm * FRACTURED ** [RACTURED, ESTIMATED AIR PERMEABILITY · COMPANY Arco Alaska Inc. PETROLEUH ,,~ TESTING SERVICE, INC, WELL t/est Sak 3C-4 PAGE 29 FILE No. 6509 DATE November 27, 1985 ARCIIIMEDES Air SATURATION ~ PORE SPACE DEPTH POROSITY Permeability O/t/ ....................... FEET PERCENT md. RATIO OIL t/ATER TOTAL ......o. .... .,....................................................., CORE NO. 14 (CONTINUED) (3503 - 3534)': REC. (3501 - 3532.35) ..................... ...... ......................................... 3530.35 32.4 99. O.OZ 1.4 84.6 86.0 3530.8 38.7 755. 1.95 58.1 29.8 87.9 3531.1 38.8 190. 3.01 67.1 22.3 89.4 3531.5 RUBBLED MATERIAL - NO SAMPLE 3532.0 RUBBLED MATERIAL - NO SAMPLE CORE NO. 15 (3534 - 3549) : REC. (3532.35 - 3545.55) 3532.35 SECTION PRESERVED 3533.35 SECTION PRESERVED 3533.4 32.9 636. 1.60 44.6 2?.9 72.5 3533.9 31.8 480. 1.40 43.6 31.2 74.8 3534.5 3.6 <0.05 0.04 3.1 '/3.5 76.6 353C.9 7.0 0.4 0.00 0.0 80.2 80.2 3535.25 3.4 <0.05 0.00 0.0 96.9 96.9 3535.85 4.8 <0.05 ** 0.00 0.0 93.4 93.4 3536.15 2.6 0.1 0.00 0.0 81.6 81.6 3536.55 10.5 <0.05 ** 0.00 0.0 87.8 87.8 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc , at SIMULATED RESERVOIR STRESS , SIMULATED ....................... RESERVOIR Air STRESS POROSITY PermeabJ[ty ps§ PERCENT md. --.~--.- ..e..... 2.66 2.67 2.66 1000 1000 1'000. 30.9 41.0 35.7 306.0 35.1 103.0 2.68 2.67 2.65 2.68 2.62 2.62 Z.62 2.61 1000 1000 1000 1000 1000 1000 1000 31.7' 399.0 30.1 239.0 3.5 < 0.05 6.9 0.3 3.3 < 0.05 4.7' < 0.05** 2.5 < 0.05 SAMPLE FAILED DESCR 1 PT i ON cty-s[st/fm st,st/sft stst/fm s[st/sft stst/sft s[st/sft catc-s[st/hd ca[c-stst/hd catc-s[st/hd catc-s[st/hd catc-stst/hd ca[c-s[st/hd 3537.2 3.8 <0.05 0.00 0.0 88.? 88.7 3537.75 11.2 5.0 ** 0.00 0.0 96.2 96.2 3538.15 6.1 0.3 0.00 0.0 90.4 90.4 3538.75 25.8 3.3 0.08 6.6 83.3 89.9 2.61 1000 3.7 < 0.05 2.63 1000 10.9 2.9** 2.62 1000 5.9 ' < 0.05 2.64 1000 24.1 1.8 ca[c-stst/hd catc-s[st/hd catc-stst/hd stst/hd COMPANY Arco Alaska Inc. PETROLEUH TESTING SERVICE,lINC. CORE ANALYSIS ~ELL Uest S~k 3C-4 o PAGE . 30 FILE NOD 6509 DAtE November 27, 1985 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY PermeabitJty O/W ....................... . FEET PERCENT md. RATIO OIL WATER TOTAL ..o..o.. .... .oo. ..o.....,.... ..o.. ..,, ..... ..... CORE NO. 15 (CONTINUED) (3534 - 3549) : REC. (3532.35 - 3545.55) ....,....................................................'........... 3539.15 23.9 1.2 0.00 0.0 84.9 84.9 3539.75 24.6 1.8 0.00 0.0 92.4 92.4 3540.3 25.4 2.3 0.00 0.0 93.2 93.2 3540.8 26.8 1.7 0.00 0.0 95.i' 95.1 .' 3541.15 26.3 2.7 0.00 0.0 92.2 92.2 3541.7 25.8 2.4 0.00 0.0 92.0 92.0 3542.25 30.3 3.3 0.00 0.0 80.6 80,6 3542.85 26.6 1.7 0.00 0.0 92.0 92.0 3543.45 27.6 3.7 0.00 0.0 89.5 89.5 3543.85 26.6 2.2 0.04 3.4 89.7 93.1 3544.25 30.3 5.9 0.41 23.9 58.1 82.0 3544.55 37.5 8.8 1.04 41.8 40.2 82.0 3545.0 RUBBLEO MATERIAL - NO SAMPLE " CORE NO. 16 (3549 - 3564) : REC. (3545.55 - 3561.05) .......... ..... ...................... ................ ..... 3545.65 33.9 65, 2.62 60.3 23.0 83.3 3546.1 32.2 71. 0.20 15.4 75.2 90.6 3546.65 29.6 5.1 1.01 42.7 42.3 85.0 3547.2 33.1 39. 1.40 45.9 32.7 78.6 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air 'DENSITY STRESS POROSITY permeabt[ty gm/cc psi PERCENT mci. ...Jllee'. ..eJeJJa ..eeee. J eJJeJeeJ.ee 2.65 . 1000 22.0 0.4 2.67 1000 22.8 0.4 2.66 1000 23.6 0.5 2.69 1000 24.4 0.4 2.66 1000 25.1 0.7 2.66 1000 24.3 0.8 ,. 2.64 1000 27.4 2.1 " 2.66 1000 24,6 0.8 2.65 1000 25.3 1.2 2.66 1000 24.4 0.8 2.65 1000 28.2 3.5 2.81 1000 34.4 4.4 2.64 1000 31.5 49.0 2.58 1000 29.8 22.0 2.59 1000 17.7 3.7 2.62 1000 30.9 19.0 DESCRIPTIOH ..........~ stty-ctst/fm cist/fm ctst/fm ctst/fm ctst/fm ctst/fm cist/fm clst/fm ~tst/fm ctst/fm stst/fm stst/fm stst/fm stst/fm sity-ctst/fm sity-ctst/fm COMPANY Arco Alaska Inc.. PETRObEUH'TESTiNGSERVI~E~, INC. CORE ANALYSIS West Sak 3C-4 PAGE 31 FILE NO. 6509 DATE November 27, 1985 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability 0/~ ....................... FEET PERCENT md. RATIO OIL. WATER TOTAL .oo....~............ ......... . .... 00. .................... ~.... ....... CORE NO. 16 (CONTINUED) (3549 - 3564) : REC. (3545.55 - 3561.05) 3547.85 32.9 32. 1.87 49.6 26.5 3548.2 32.8 31. 2.48 55.5 22.4 3548.75 31.3 19. 0.69 32.2 46.7 3549.3 31.1 7.0 0.42 24.1 57.3 3549.85 31.0 25. 0.69 30.1 43.7 3550.3 30.6 19. 0.36 22.0 60.3 3550.85 29.1 3.2 0.08 5.9 76.7 3551.2 27.9 2.8 0.03 2.1 82.5 3551.85 29.6 11. 0.12 9.1 75.5 3552.3 27.4 3.8 0.03 2.5 86.0 76.1 .77.9 78.9 81.4 7-5.8 82.3 82.6 84.6 84.6 88.5 3552.85 28.4 2.9 0.04 3.3 90.9 3553.55 30.5 13. 1.29 46.9 36.3 3553.85 28.5 8.5 0.91 40.4 44.3 3554.2 30.8 19. 1.17 41.1 35.1 3554.6 32.8 43. 1.27 45.4 35.7 3555.15 28.6 13. 0.15 12.2 81.0 3555.75 29.6 13. 0.66 33.7 51.3 3556.3 27.5 4.2 0.00 0.0 93.7 94.2 83.2 84.7 76.2 81.1 93.2 85.0 93.7 APPARENT SAND GRAIN DENSITY gm/cc 2.63 2.62 2.63 2,63 2.62 2.61 2.62 2.62 2.59 · 2.61 2.63 2.59 2.58 2.59 2.60 2.59 · 2.59 2.63 at' SIMULATED RESERVOIR STRESS SIMULATED ........................ RESERVOIR' Air STRESS POROSITY. Permeabi[ty ps~. PERCENT md. .o.....o ...o.~.. .0......... 1000 1000, 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 1000 31.0 .: 30.3 29.5 28.5 29.6 28.9 26.1 24.3 26.9 24.6 19.0 13.0 5.7 4.0 7.8 4.1 2.3 1.9 3.5 1.1 25.0 28.6 27.0 28.7 30.2 26.6 27.9 24.3 0.9 6.3 3.9 9.4 '17.0 4.0 5.3 1.1 DESCRIPTION ........... stt'f-ctst/fm stt'f-ctst/fm stt'f-c~st/fm s[t'f-c[st/fm s[t'f-ctst/fm stt*f-ctst/fm s[t~f-c[st/fm stt'/-c[st/fm stt'f-c[st/fm ctst/fm stty-c[st/fm s[ty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-c[st/fm stty-ctst/fm stty-clst/fm COi~PANY Arco Alaska Inc. PETROLEUH TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 3C-4 PAGE 32 FiLE No. 6509 DATE November 27m 1985 ARCHIMEDES Air. SATURATION ~ PORE SPACE DEPTH POROSITY Permeabitity 0/~ ....................... FEET PERCENT' md. RATIO OIL WATER TOTAL ................................... .............. CORE NO. 16 (CONTINUED) (3549 - 3564) : REC. (3545.55 - 3561.05) ......................... ........................... .......... ..... 3556.8 27.2 3.8 0.00 0.0 90.3 90.3 3557.25 28.6 1.6 0.00 0.0 85.9 85.9 3557.8 28.2 3.3 0.00 0.0 97.1 97.1 3558.35 27.2 2.3 0.00 0.0 91.1' 91.1 3558.7 26.4 2.7 0.00 0.0 89.'2 89.2 3559.45 27.0 2.5 0.00 0.0 87.? 87.7 3559.85 25.5 4.2 0.00 0.0 90.6 90.6 3560.3 26.8 2.6 0.00 0.0 95.8 95.8 3560.75 23.0 0.8 0.00 0.0 87.0 87.0 CORE NO. 17 (3564 - 3567) : REC. (3561.05 - 3565.05) .e...-.o...~... ..... ooo-----o---------o- ...... ------------ 3561.35 26.1 3.7 0.00 0.0 85.6 3561.? 25.9 2.2 0.00 0.0 85.7 3562.25 26.3 9.5 0.00 0.0 84'J4 3562.75 25.5 4.7 0.00 0.0 91.5 3563.1 28.9 4.7 0.00" 0.0 89.7 3563.?5 26.6 1.4 0.00 0.0 89.8 3564.15 25.5 2.3 0.00 0.0 91.6 3564.75 27.0 2.0 ** 0.00 0.0 83.6 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ........................ ,, SAND GRAIN RESERVOIR ' . Air DENSITY STRESS POROSITY Permeabitt¥ gm/cc psi 'PERCENT md. --------e .o.o.... ........ ** FRACTURED, ESTIMATED AIR PERHEABILITY 2.65 1000 25.1 ";' 0.9 2.67 1000 27.2 0.9 2.68 1000 26.3 0.7 2.6? 1000 25.7 1.3 2.66 1000 25.0 0.7 2.64 1000 25.5 1.5 2.60 1000 . 24.2 .2.6 .."" 2.60 1000 25.6 1.5 2.66 1000 21.5 0.1 85.6 2.66 1000 23.6 0.7 85.7 2.65 1000 23.2 1.6 84.4 2.65 1000 24.5 8.6 91.5 2.65 1000 23.9 3.3 89.7 2.69 1000 25.5 2.2 89.8 2.66 1000 24.5 0.4 91.6 2.65 1000 23.0 0.4 83.6 2.6~ 1000 25.8 1.5'* DESCRIPTION ........... ctst/fm ctst/fm ctst/fm ctst/fm ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-cist/fm stty-c[st/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm stty-ctst/fm COMPANY Arco Alaska Inc.- ARCHIHEDES Air DEPTH POROSITY PermeabitJty 0/~ FEET PERCENT md. RATIO r PETROLEUH TESTING SERV[CE~ INC. WELL ges~ Sak 3C-4 PAGE $3 FiLE No, 6509 OATE November 2Z~ 1985 CORE ANALYSIS SATURATION X PORE SPACE OIL WATER TOTAL at $1HULATED RESERVOIR STRESS APPARENT SIHULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabitty gm/cc psi PERCENT md. DESCRIPTION TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERHEAHETER = ~00 psi .., OIL GRAVitY SUPPLIED BY CUSTOHER ~ 18 Frequentty~ APPARENT SANO GRAIN DENSITY data are [ess than the expected vatue for the rock type encountered. This maybe caused by one or more of the fottoulng reasons: 1. The presence of Totuene insotubte organic materla[. 2. Water sotubte compotaxls left behind In the extraction process. 3. isotated pores that appear to be part of the sand grain votive as determined during the measurement of effective porosity. 4. The presence of to~ density ctays or minerals. To obtain accurate sand grain density vatues sultabte for tog Interpretation, it is necessary to-'~ent)tetety dlsaggregate the sample to expose Isolated pores and to extract or treat the sampte ulth additiona[ sotvents or methods to remove entrained organic mat,flat and ~ater soluble compourxJs prior to making the measurement of ABSOLUTE SAND GRAIN DENSITY. i -.(~Oi!.:andGasCompany =O Well History - Initial Report - Daily · _!-.l~;:P~pare and[submit - ~' ~ -:-: -~ Daily work-prior Dist~!ct _' . · the "lniUll~P~' on the first Wednesday after a well is spudded or workover operations are started. to sPUdding ~olJId:be'~ummarized on the form giving inclusive dates only. :Alaska ICounty. parish or borough North Slope Borough Lea~ or Unit ADL 25629 Title Drill Field- -~' : _. _::.: Kuparuk l~ver Auth[ or W,O, no, ~ AI[O08:I- . -. Nabors 26E Operator" API 50-029-21416 State Alaska IWell no. 3C-4 - ARCO Alaska, Inc. Spudded or W.O. begun ~,- - . Date Date and depth aa of 8:00 a.m..' -:-:::' 8116185- _ · - . 8117/85 8/19/85 8120185 8/21/85 8122/85 8/23/85 Complete record for each day reported I ARCO W.I. JHour [Prior status If a W,O, 8/16/85 0700 hrs. 56.24% 16" @ 100' 100' (0')', Pre to Spud Accept R~ @ 0100 hfs, 8-16-85. Fsh out broken kelly, PU BHA, prep to spud. Spud @ 0700 hfs, 8-16-85. 10-3/4" @ 2445' 2878' (2778'), RIH to Cut Core #4 Drl f/100'-2460', circ. Short trip SLM, cite hole f/csg. LD BHA. Rm 60 its, 10-3/4", 45.5#, K-55, BTC csg. FS @ 2445', FC @ 2363'. Lnd cSg, RU Howco, circ csg volume. Cmt w/1050 sx permafrost "E", 12.2#/gal, followed by 380 sx permafrost "C", 15.4#/gal. Displ cmt w/223 bbl mud, bmp plug w/1500 psi; floats OK. Performed top job w/200 sx Permafrost C. CIP @ 1430 hfs, 8-17-85. RIH tst, csg, drl out, FC, FC & cmt. Drl to core point. Cut & recvr core 1,2,& 3 f/2790'-2878'. 501', .3° S87W, 501TVD, -0 VS, S.1, W1.3 1009', .3°~ S83W, 1009 TVD, 0 VS, S.3, W4 1511', .2°, S15E, 1511TVD, -2 VS, S1.9, W5 1952', 1.5°, S55E, 1951TVD, -7 VS, S7.1, 1.3W 10-3/4" @ 2445' 3325' (447'), Cut West Sak Cores Cut Ugnu Cores f/2878'-2928'. Drl to 3270' , cut'g WS cores. 10-3/4" @ 2445' 3480' (155'), Cut West Sak Core Cut & recover West Sak cores f/3325'-3480'. 10-3/4" @ 2445' 3571' (91'), Cutt'g West Sak Core Wt. 8.9, PV 19, YP 6, PH 10.5, WL 5.8, Sol 5 Cut & recover West Sak cores f/3480'-3571'. 10-3/4" @ 2445' 3784' (213'), Electric Log'g Wt. 8.9, PV 13, YP 6, PH 9.5, WL 5.8, Sol 4 Cut core f/3571'-3591', no recovery, POOH. RIH, rm cored section, drl f/3591'-3784'. Short trip. C&C mud, POOH. RU logger, rn w/DIL/GR/SP/LSS f/3728'-2445', rn LDT/CNL/NGT/EPT. In progress The a. bove is correct~ For fo~epa~atio~and distribution, see Procedu~s Manual, Section 10, DHIling, Pages 86 and 87. Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim InatmnUen~: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or reprosentalive test on "Final" form. 1) Submit "Interim" sheets when filled oLIt but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setling of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25629 Complete record for each day while drilling or werkover in progroas 8/24/85 thru 8126185 8/27/85 rstate Alaska IWell no. 3C-4 10-3/4" @ 2445' 7037' (3293'), Drl'g 8½" Hole Wt. 10.2, PV 21, YP 15, PH 9.5, WL 5.4, Sol 11 · Finish log w/LDT/CNL/NGT/EPT f/3762'-2445'. Rn log #3 SHDT f/3762' f/3762' f/3689' 3739', 4340', 4715', 5284', 5908', 6624', -2445'. Rn 3 OH RFT's. Rn log #7, tern of LDT/GR, -2445'. Set wear bsh'g, PU BHA, RIH. PU HWDP, ream -3784', drl f/3784'-7037 0.6°, S39.SE, 3738.5 TVD, -18.7 VS, 20.3S, 33.6E 17.4°, N4.2E, 4330.7 TVD, -57.4 VS, 55.0N, 51.8E 24.2°, N14.2E, 4681.5 TVD, 188.4 VS, 145.N, 73.5E 43.9°, N4.8W,' 5148.7 TVD, 54.6 VS, 500.3N, 104.8E 44.8°, N4.2E, 5595.1TVD, 940.0 VS, 935.2N, 123.5E 44.0°, N6.2E, 6106.0 TVD, 1441.1VS, 1434.8N, 169.4E 10-3/4" @ 2445' 7631' (594'), POOH Wt. 10.3, PV 14, YP 10, PH 9.5, WL 5.4, Sol 12 Drl f/7037'-7631', make 42 std short trip. C&C mud f/logging, POOH. 7009', 43.8°, N4.2E, 6383.4 TVD, 1707.8 VS, 1700.6N, 193.6E The above is correct ~,% ~ For fo~ preparation and distribution s~ Procedures Manual ~ction 10, Drilling, Pages 86 and 87 ITitle Drilling Superintendent .', ~ ~ .?~ ;fl .:. ~, r'~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~3~' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ~County or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit I Well no. Kuparuk River ADL 256~9 3C-4 Auth. or W.O. no. ~Title AFE AK0081 I Completion Nabors 26E API 50-029-21416 Operator IA.R.Co. W.I. Irotal number of wells (active or inactive) on this, ARCO Alaska, Inc, ] 56 24~ /COSt center prior to plugging and I ° iabandonment of this well Spudded or W.O. begun · ~ Date Hour ~ Prior status if aW.O, Spudded I 8/16/85 0700 hrs. I 8/28/85 Date and depth as of 8:00 a.m. 8/29/85 Complete record for each day reported 10-3/4" @ 2445' 7670' (39'), RU CSG CREW Wt. 10.2+, PV 12, YP 9, PH 9.0, WL 5.6, Sol 12 Fin POOH, RU loggers & rn DIL/SFL/GR/CAL/SP f/7627'-2440', & FDC/CNL f/7627'-6000', & f/4400'-2440'. Tst BOPE to 3000 psi; OK. RIH, drl f/7631'-7670', C&C mud, POOH. Pull wear bush'g, chg top BOP rams to 7", tst to 3000 psi; OK. 7600', 43.0°, N6.2E, 6812.8 TVD, 2113.5 VS, 2105.0N, 230.4E 7" @ 7650' 7568' (0'), RR 10.3 Brine Rn 188 its of 7", 26#, J-55, BTC csg, FC @ 7568', FS @ 7650'. M&P 380 sx Perm "E", @ 12.3 ppg, followed w/250 sx CL "G", + 5% KC1, .3% Halad 24 @ 15.8 ppg. Bmp plug to 3000 psi, OK. CIP @ 1645 hrs, 8-28-85. RR @ 2300 hfs, 8-28-85. (Arctic packed with 250 sx Permafrost C & 89 bbls, 7.7 ppg Arctic Pack). Old TD New TD PB Depth Released rig Date ~K nd of rig 2300 hrs. 8/28/85 I Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I S ingle Producing method I Official reservoir name(s) Flowing J Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production · Oil on test ~Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~er~l liPn~ c ~da.~%s 81~ifannnudaal~TS. e ~t i~n 1 ~, ' ~'~ ~ Drilling Superintendent * I II I ~UB. SURFACE DIRECTIONAL ~URVEY [~UIDANCE [~]ONTINUOUS ['~OOL Company :mco ALASKA, T~COR~PORATF. D, Well Name 3C-4 (420' FNL, 1402' FEL, S14, T12N, RgE, UM) Field/Location ~,~A~, N,O, RT~ SLOP,E, A,I.~.SKA .Job Reference No.; 70856 Loaaed By: KOZUSKA Oatl 07-OCTOBER-1985 Computed KRUWELL GCT DIP~CTTONA[, SUPV£¥ FOR ARCO Ai,~ASKA, INC, 3C -4 KUPA~UF NURTI4 SbOPF,AbASKA SURVEY OATF: 30-SEP-85 FN~IN£FP~ KOZU~KA T~)Ob bOCATIL)N: TANGFhrIAb- averaqed deviat&on and azimuth TNTERPD[,ATTO~: [olN~iAF VFRTICAb SECTION: ttOATZ O1S'[' PROJECTED ONTO A TARGET AZIMUTH OF NORTH 2 PEG 42 M~N gA~ ARCh ALASKA, Ih(", 3(?.-4 KUPARIIK NORTH SLOPE,A[,ASKA C~'tPU TATInN I.)ATE: 7-0CT-85 PAGE I-~ DATE OF SURVEY{ ]0-$EP-85 KELSY RUSHING EhEVATiON{ 85,00 PT ENGTNEERI KOZUSKA ZNTERPOI,ATED VA[,L!E$ F~]~ EVEN 100 FEET OF MEASURED DEPTH TRUE SUR-SEA COURSE MEA$I)RFD VERTICAl. VE~'rICAb DEVEATION A?I~UTH DEPTH OFPTH DEPTH ,DEG MT~ DEG -85,00 0 o N 0 0 E i5,00 0 13, $ 82 59 W 115.00' 0 10 N 6 54 tv ~14,99 0 21. N ~8 ~ ~ 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 RO0.O0 o00,oO ]14,09 0 29 4t4'99 0 19 514'q9 0 16 614,09 0 15 714,q9 0 21 a14,g8 0 26 VERTICAL D(]GGEG RECTANGUEAR COORDINATES HI SECTION SEVERITY NORTH/SOUTH EAST/WEST D F~ET DEG/100 FEET FEET O O0 lO0~00 200.00 209 90 309 9a 499 99 599 99 599 90 799 99 B99:9~ 0 27 o 21 o 0 2n 0 24 o 21 o2t o 30 0 4? 1 21 0.00 8.00 -0.44 .49 '0.29 0.35 0.12 0.0~ 0.66 0.06 1.18 0,04 1,66 0,13 2.08 0,35 ~.]4 0,10 ~.62 0,16 1000.00 909,98 g14,g8 110o O0 1099.9a lnld,98 1200!00 1199,9~ 1,114,g8 1300 O0 1.209,9n 1400,00 1399,97 1500,00 1499.97 1414.07 1600.00 1599 97 1514.g7 1700 O0 1699' 1800:OV 1799'97 1614.07 lqO0.O0 ~809'96 1714.06 ,94 1RI4,O~ 1 38 I 30 I 41 1 31 N 36 20 ~ N 11 0 F N 53 36 W N 58 44 W N 69 30 W 2000,00 1999.91 lql4,Ol 2100.00 2009.H7 2014,n7 2700.09 ?I. 09,H? 2114.P2 2]00.00 2299.Tg 2714,79 2400,00 2399,75 2'~14,75 2500 OL) ~409 71 2414,71 2600:00 ~SO9:6n 2qi4.68 ~700.0.) ~99 66 '261~.&6 2500,0,) ~709[u4 2714.~4 2900.00 2~gg,b~ 2R14,62 1 '4 0 54 0 55 0 5~ 0 45 3000,00 ?999.bO 2q14.60 3100.00 3009,Sq 3014.59 3200,00 3199.57 3114.57 ]300.00 32~9.55 3714.q5 3400,00 3309.54 3~14,54 3KO0.O0 ~499,57 3600,n0 ~5oq.51 3514,51 3700,00 3699,50 3614,50 3800,O0 3799,4~ 3714.49 3gO0,00 ]8~g,4~ 3014,48 62 58 W 2.68 1.20 25 58 w 2.08 0.36 ~4 17 E 1,63 0.74 1.6 47 ~' 1,9! 0,61 73 13 W ~.46 0 99 11 10 w ~.19 0',36 b 11 W 1,58 0,13 70 2~ F 0,82 0,28 40 40 ? -0,04 0,90 %,t 20 ~: -1,20 0,65 S '17 1 E '2.14 0.66 N ~2 5 t -g.06 0,12 N 79 48 E -~.46 0.0~ ~ 79 20 E -0.78 0.10 N H1 57 ~ -0.~4 0.17 S q3 q E -0.24 0,13 S t4 40 E -0.52 2.51 S ~5 4] ~ -1.87 0,2~ $ '%2 ~0 ~ -~.19 0,35 $ 43 5~ E -4,55 ,00 ,4] 0,27 0,14 0,65 1 16 1 63 N 2 05 N 2 34 N 2 65 . 0 O0 E 0 29 W 0 48 W 0 28 W O, E Oo ~ E 0,5 E 0,10 E 0,5] W 2 75 N 2 ~6 ~ 1 98 N 2 55 ~ 2 30 N 1 70 N 0 93 N 0 05 N I 18 S W 1 1 72 W I 44 W 1 69 W 2 26 W ,48 W 2,37 W 1,92 W 0,55 W 2,2] 2,28 1,81 1.27 0,86 0,98 ,37 ,80 4,18 5,60 1,81 4,67 7,51 10,37 13,20 15 69 17 99 19 56 20 87 22 2? -5.95 -7.]9 -~.74 -10.01 -11,~1 -17,44 -13.74 -15.07 -16,31 -17.17 0,40 0,37 0,25 0 18 0 39 0 31 44 0 20 4 4~ 7,07 8,57 9,98 11 30 S 12 56 13 84,1 15 18 16 54 t7 81 18 69 23 62 E 24 80 E 25 94 E 27 16 E 28 22 E 29 28 E ]0 19 E 30 93 E Ii 38 E 31 84 E DEPARTURE AZIMUTH ~,'.,i PEG MiN 0 'S W : 64 W o [ 1~ N 15 2 ?0 Ntt W 76 38 42 45 44 06 9 W 2 54 N 68 ]0 1 92 N 88 27 W 1 ~0 S 2,87 519 7 72 8 76 26 E tO 45 13 23 S 86 l~ E 15 7~ 24 66 27 29 3O ~5 36 36 79 42 S 67 24 E 07 92 8 59 35 E ARCO Ai;.~ASKA, TNC., 3C-4 NORTH $[JOPE, A[.,ASKA MEA$11RFD VERTICAL 4000,00 3999 4100.00 4098 4200.00 4196 4300,00 4292 4400 O0 4388 4500i00 4482 4600 O0 4576 4700 O0 4669 4800.00 4759 4900,00 4.847 01 80 6O 5000.00 4932 5100,00 5013 5200,00 5Uql 5300,00 5165 5400,00 52]7 5500,00 5309 5600.00 5380 5700.00 5452 5800.00 5524 5900,00 5595 .46 ,77 .48 49 2~ 79 24 6000.00 5666,75 6100.00 5717,8] 6200.00 5809.01 6300.00 5~80.39 6400.00 5951.94 6500.00 6023.56 6600.00 6095.06 6700.00 6166.9P 6800.00 6239.00 6900.00 6311.02 7000 O0 ~383,24 7100~00 6455,33 7200,00 65~7,01 7]00,00 6598,5~ 7400.00 6670,14 7500.00 6741.51 7600,00 6813,04 7670,00 6~63,17 cn~PUTATION [)ATE: INTERPOLATED VAT, UFS FOR EVEN 7-0CT-85 PAGE DATE OF SURVEY1 30-SEP-85 KEbbY BUSHING EbEVATIONI ENGXNEERI KOZUSKA 100 FEET OF MEASURED DEPTH SUB-SEA COURSE VERTICAl, VERTICAE DEVIATION AZi"UTH SECTION ~EP'T'H DEG MTN D~G MYN FEET 3914,]4 5 5 N?b 1, ~ -12.90 013~'49 9 35 N ~0 16 ~ -0,97 ltl,)6 13 46 N 8 57 g 18.99 4~07~'85 16 17 N 2 55 E 45.18 4]0~'29 18 16 ~ 2 ]4 ~ 75.00 4]97.78 19 53 8 4 5 ~ 107.73 4491.4i 21 15 ~ 8 11 E 14~.77 45~4.01 2] 10 ~ !0 56 E 180.22 4674.g0 ~6 3~ ~ 12 47 ~ 221.54 476~.60 ]0 25 ~ 12 5 ~ 268.62 4847.46 33 35 N 10 JO E 320.89 4028.77 ]7 27 ~{ 6 57 ~ ]78.71 5006.43 40 2¢) N 4 58 ~ 441.62 5080,48 43 32 ~ 6 2 ~ 508.72 5157,49 44 5 N 6 8 ~ 577,98 5~24,21 44 1~ N 5 55 ~ 647,55 5~95.79 44 ll " 5 49 ~ 717,~7 5367.59 44 % ~..) 5 3q E 786,77 5439.24 44 21 N 5 29 F 856,45 5510,62 44 36 ~ 5 27 F g26,40 85,00 FT 5K81,75 44 40 ~ 5 45 E 096,60 565~,83 44 40 N 5 50 F 1066,84 5724,01 44 32 N 5 47 P 1136,06 5795,39 44 25 ~J 5 46 K 1~06,90 5866,94 44 17 N 5 45 E 1276.66 5938,56 44 lB N 5 25 E 1346,]5 601o,06 44 o ~1 5 15 ~ 1416.20 6081,98 43 55 N 5 q E 1485,61 6154,00 43 58 ~ 5 ~ F 1554 93 b226,02 43 51 ~I 5 14 E 1624:23 629P.24 43 4) ~ 5 11 £ 1693.34 6t7o.33 44 9 N 4 56 E 176~.58 6449.01 44 17 N 4 19 F 1832,27 ~513.5~ 44 18 N 3 31 ~ 190~.10 658~,14 44 26 N 3 6 E 1971.94 6656,5] 44 ~8 N 2 45 F 2041 99 6728,04 44 1~ N 2 4~' E 2111:86 b~'7¢,12 44 1o N 2 45 ~ 2160,78 OOGbEG SEVERITY DEG/IO0 4,51 4,97 4,20 2 15 1~6~ I 76 2 67 4~29 RECTANGUbAR COORDINATESD NORTH/SOUTH EAST/WEST FEET FEET FI 14 52 S 2 82 8 16 93 N 43 04 N 72 83 N 105 52 N 140 42 N 177 61 n 218,57 N 265,20 N 34 07 E 39 35 g 44 26 E 46 45 E 47 77 E 49 51 E 53 19 E 59 67 E 6 31E 7~ 88 E DEPARTURE AZYMUTH "'It N 163~E 4.14 3{7.04 89 28 96 27 14 367,t8 46 437,20 g 449.46 6~ 504.06" !!22 642,35 N llO 64 22 573,05 N 118 13 585,10 125 44 654,49 N 0.15 711,82 132 57 0.28 761.07 ~ 139 56 0,40 850,50 146 31 862,~9 45 0,46 990017 159 77 1002098 0.06 1060.15 ~ ~1073,22 ~ ~ 59 174166 0795 4~ 14, 181 Ii 0.20 1269.20 188 15 1283,07 } 105 06 45 1406.27 N 201 42 1422,6! 1491,99 17 154~,57 21] 91 1561,{0 0,14 1615.66 ~ 220 1~ 1630,59 0,37 1664054 226,43 1699'69 O. o, 2032.44 ~ 247.07 O0 2102,23 250062 ~ 1977097 Oe. O0 2~51.09 N 2166.3t CO~IPU'i'AT 101,t DATE: PA~E ~1' ARCO AL,~,$KA, TNC. 3C-4 KUPARtlK NONTI-t 8[,OPE,ALASKA PATE Or SURVE¥I 30-$EP-65 KELbY BUSHING EbEVATIONI ENGXNEERI KOZUSKA 85'00 f,NTERPOLATED VA1,UES F~R EVE. 1000 FEET Of' MEASURED DEPT TRUE ,.qUB-$EA ' ', HEASUREI~ V F..RT,[ CAT,, DEPTH DEPTH PEPTH 'DEG MTN DFtG MTN VERTZCAb DOGhEG SECTION SEVERITY FEET r)EG/t00 0.00 U,O0 -65,00' 0 0 1000,00 9gg 98 914,98 ,:0 27 2000 OO 1999:91 1q14.91 "1 ~noo~oo 2999.60 2~14,60 t 4000.00 3999.34 3~14.'34 '5 5 5000,00 4932 4A 4847,46 33 35 6000,00 566~:75 558~,75 44 40 ?00O,00 63a3 2~ 629~,24 43 4~ 7670,00 6863:1~ o~?~,12 44 lq N 0 0 r 0,00 $ 62 5~ ~/ 2,68 S 77 1 r -2.14 $ ~8 5! E -5.q5 N 7b 1 F -~2.90 N 10 30 E 320.89 N 5 45 E 996,60 N 5 1. l ~' 1.693,34 N 2 45 E 2160.78 0,00 1,20 0,66 0,40 4,51 4'14 0,46 0,37 0,00 RECTANGUbAR COORDXNATEg HORZZ, DEPARTURE: FEET FEET .:,:,,;' DEG MZN 0 ! 0 O0 N 2 75 N 2238 7 07 14 52 317 04 990 17 1684 54 2151,09 N 256 COt,,tPU~'AT InN [)ATE: 7-0CT-85 PAGE ARCO ALASI~A, rNC, 3C-4 KUPARUK NORTH St,C)PE, A[,ASKA DATE OF SURVEY: 30-$EP-85 KELhY BUSHING EhEVATIONI ENGTNEERI KOZUSKA 85,00 rT INTERPUI,ATED VAI,UFS I~OR t!:¥EN 100 FE~T OF SUIR-SE/~ DEPTH TRUF. SUB-SEA CnUR$[< MEASIIREI) Vr. RTIr'AI., VERT.ICAb DEV!A'rlr.~N ATI.~UTtt DEPTH D~p'~I't DEPTH' DEG ~TN DEG ~TN O.OU O.OO -85,00 0 0 ~.; 0 0 F 85.00 RS,00 0,00 0 16 $ f. 8 1.7 w ~85.00 l~5.0O 100,00 0 o N 71 lO W 285.n0 205,0o 200,00 0 20 ~ 3'1 4~ ~ 385.nl 385.00 300.00 0 22 ~, 36 5R F 48~.01 4~5.t)0 400,00 0 19 P ?8 26 F 585.01 b85.00 500.00 0 17 ~ ~3 10 F~ 685.01 6g5,UO 600,00 0 14 N 36 57 w 785.01 7~5.U0 700.00 0 21 N 59 46 v/ 885.02 885.00 ROO,O0 0 25 ~,~ ~7 50 W q85.02 9Rb. O0 000.00 1085 02 1085.00 I. OO0.O0 1185~02 1185,00 ]100.00 1~85.02 12~5.00 1385.o3 13~b. O0 1]On.Ou 1485.~3 1485.o0 1585.o3 15~5.0o 150o.0o ~78~.04 1785 0() i70o.oo 1885,n5 18~b~0 l~On. OO 1985.o8 1985.00 208~.13 ~0~5.0o 2000,00 2185.1'1 ?ln5.oO 210o.o0 2~85.21 ~2~5 O0 22o0.00 2385.~b 23~5:0n ~300.00 2485.78 7485.0o 240o.00 2585.]1 ~5~5.00 250n.00 2685.33 2b~5.00 2600.00 2785.]5 7785.00 2700.00 2~85.37 28RS,t)O 2085.39 79~5,00 3085.41 ]0~5.00 3285,45 ]2~5.0o 370o,Ou 3385,4b 339b.00 3300.00 3485.47 34~5.00 3400,0u 3585.48 35R5.0o 3685.KO 378~.5t ]7q5:00 3700.n0 3885.52 ]8~5.00 380n,O0 VERTICAL DOGLEG SECTION SEVER1TY FEET PEG/lO0 0.00 0.00 -0.42 0.55 '0.33 0,26 0.05 0.1~ 0.57 0.05 1.10 0.02 1.59 0,06 2.04 O, 2.30 0,10 2.5B 0.09 2.72 1.01 2.17 0,13 1.67 0,37 1.~3 0.4~ 3.42 0.95 2.27 0.55 1.69 0.35 0.94 0.19 n.o9 0.70 -1..01 0.6~ -2.05 0,75 -?.13 0.30 -1.55 O.OR -0.88 0,09 -0.27 0,56 -o.22 0,15 -0.46 1,06 '1.6B 0.60 -2.99 0,16 -4,35 0.2Y '5,75 0,56 "7.18 0,30 -R.55 ~,25 -g. R2 0,46 -11.04 ,49 -13.55 21 -16.13 '' ; 3 '17,15 ATES "J.. ~'I DEPAR'~URE RECTANGUbAR COORDT NORTH/SOUTH EAST/W~$T '" ' !!.: AZIMUTH ' DEG .NlM ~EET FEET . . 0,00 N 0,41 S O, 31 $ 0.06 lu 0 57 N 1 08 N I 56 N 2 O1 N 2 29 N 2 61 N 2,78 N 2,25 ~ 1,75 N 1,90 N 2,50 N 2,38 N 1,80 N 1,06 N 0.18 N 0,97 $ 2,12 S 2,34 8 1,89 1,35 0,88 $ 0948 1308 2595 3978 5398 6,86 S 8,35 S 9,77 S 11,11 .S I 65 8 14,~8 S 1 63 S 1 67 S 0 O0 E 0 22 W 0 47 W 0 34 W 0071/: 0,39 E 0,62 E 0.62 1/: I, O W , 7 W 1,75 W 1,47 W 1,60 W 2,21 W 2,47 W 2,41 W 2,02 W 0,92 W 1411/: 4241/: 7081/: 9 94 E 1281 E 15 34 1/: 17 69 E 19 35 1/: 20 68 1/: 22 07 E 23 45 1/: 24 63 E 25 76 1/: 27 Ol 1/: 28 08 E 29 13 E 30 06 g 30 85 E 31 32 E 31 76 1/: 7 10 12 15 17 19 97 N 32 35 W 24 N 4~ 50 W 06 N 5~ 49 W 63 N 66 18 W 03 N 84 48 W 27 S 40 15 W 24 43 26 27 29 30 32 33 34 35 36 6~ 6663tie 17 S 64 $ E 56 S 63 E 93 ~ 6~ 3 E 94 ~ 60 37 ~ 84 8 59 33 E ARCO AI,.,ASKA. T'NCo 3C'4 KI!PARI~K CO~,PUD'ATION DATF,: 7-0CT-85 DATE Or 8URVE¥~ 30-&EP-85 K~LbY 8USHXNG EbEVRTXONI 8SeO0 ENGINEER: KOZUSKA INTERPOT,ATED VA!,UE$ F[)~ EVEF] ]00 FEET Or SUB-SEA DEPTH T~lJ~ SUg-SEA CDI3RSF' ~EASt~RF[') YERTICAL VF. aTTCAL, DEVIATiflN DEPTU DFPTH DEPTH DEG 3985.61 3985.oo 3900,00 4 25 4086.]3 4095,00 400~,00 8 59 4188o~2 41~5.0o 4100,00 ~3 2~. 4291,~3 42~5.00 4200,00 16 7 4396.53 43~5.0n 4~00,00 18 13 450~ 36 4485,00 4400.00 19 5K 460~3 45~5,00 't~OO,O0 ?1 24 4717 ab 46~5.00 4600,00 73 47 482R'~O 4785 O0 4700,00 27 42 4043:70 4885:00 4800,00 31 45 5064,07 49~5 O0 4000,00 ~6 5191,59 50~5~()0 5000.00 40 13 5~27,04 ~185,00 51.00,00 43 51 5466.21 52fl5.00 5~00,00 44 5605.R8 5385.00 5300,00 44 5745 15 54~5 O0 5400.00 5885109 55~5100 5500.00 44 34 6025.6~ 56~5.00 5600.00 44 43 6166.78 5795.00 5700.00 44 6306.45 5885.00 5800.00 VERTICAL DOC..bEG RECTANGUbAR COOROXNATE$ HO'RlZ;'~, ~EPIRTURE [I 26 16 [< -1~.98 ~{ ?1 59 E -3,08 ~ 10 n F": 16.~9 ~' 3 'I ~' 4~,01 ~:'; 2 33 F" 73.91 ~ ¢ In F 1.08.54 . 8 31 F 146.13 ~II 1~ E ~87.12 ~! 12 58 V 234'71 u !1 25 g 29n~94 t.~ 8 24 F 357.28 N 4 57 F 436,21 ~ b 11 ~ 527.40 ~i 5 50 E 624,01 ,,T 5 4q E 721,36 ~, 5 32 ~' ~1.~,17 ~ 5 26 F 915,05 ~ 5 51 ~ 1014,64 ~ 5 4~ E 1113.33 ~,~ 5 46 ~' 191~.41 6446.19 59~5.00 500n.n0 44 15 6585.09 60R5.00 6n00.00 44 14 6725.01 61~5.00 ~10~.00 43 54 6863.01 62~5.00 0700.00 4t 53 700~.~3 63n5.00 b]OO.O0 43 47 714J.]3 64fl5.00 b400.00 44 11 7~81.02 65~5 O0 b~OO,eO 44 1~ 7420.82 6685:00 6600.00 a4 2R 7KbO.80 6795.00 o700,eO 44 1~ 7670,0U 6863,1~ ~77~,12 44 lO ~ 5 42 r 130~,88 ~ 5 13 V 1406.46 ~ 5 10 F 1502.04 ~ 5 11 F 1599,26 ~' 5 11 E 1695.02 ~ 4 49 F 1791,33 ~' 3 37 F 1888.83 P,' 2 57 v 1986.53 ~! 2 4~ E 2084.47 N 2 45 E 2160,78 4,60 5,06 4.36 2,1.3 1,64 2, 2,7~ 4,40 2,99 .15 58 S 4 90 S 14 25 ~ 40 78 N 71 75 ~ 106 32 N 143 76 ~ 287 ~i3 N 33 56 E 38 56 E 43 79 E 46 34 E 47 72 E 49 58 E 53 72 E 76~ 01 E 37,00' ~ 65 5 E &",7 39 E 117,1i N 3 194,27 N 18 18 E 241,83 N 17 7 E 299,2] N 16 4 31 3 14 0 44 0 25 0 15 0 41 0,09 0,09 0,10 0,24 39 79 ~ 365 444 65 ~ 534 00 63. 99 61 [ 824 90 [ 922 6! 57 E 1217 0,45 0,92 0,16 0,37 0,36 0,55 0,49 0,57 0,00 0,00 1301 31 ~ 191 38 E t315 30 N 8 21 E 1398 57 N 200 52 E 14i2 87 N 8 9 E 1494 74 N 209 26 E 1509 1590 76 M 217 86 E 1605 1686 22 N 226 58 E 1701 1782 24 N 235 04 g 1797 1879 51 N 242 21 E 1895 1977 05 N 247,83 E 1992 2074 87 N 252,67 E 2090 2151,09 ~ 256.35 E 2166 32 N 7 58 E 37 N ? Ig 67 N 7 3r 05 N 7 2~, d 52 N 7 8 E, N 6 47 g ARcrl AL~KA~ TNC. NORTH ~LOPE,ALA~KA MARKER Trip EIJPARUK C BA,,SF, KUPARUK C TOP KIIPAEUK A ~AsF WUPAr~UK A PI~TP COMPLITATIDN DATE: PAGE DATE OP SURVEY: ]O-SEP-85 KELbY BUSH~NG EbEVAT[ONI ENGTNEERI KOZUSKA 85,00 INTERPOLATED VAI, d~S FnR CHOSEN HORIZONS 7168.00 7200.00 7389.00 Vb12.00 7568,00 ORiGZN: 420' FNL, 1402' TVO' FROM KB SUB-SEA 6504.10 6527,0! 6667 29 6750~09 6790.15 6863.12 6419,10 6442 O] 6577 29 6665 09 6705 15 6778 12 RECTANGU~AE NOR ~H/SOUTH": ~AST/WEST ' ~[, 1800.78 N N . 92'.~ N . 040,92 ]o?,.,o . 2151~09 N 25~ DATE: 7-OCT-R5 PAG~ ARCfl ALASKA, TN('. 3C-4 KIIpARIIt~ NORTH SLOPE,Af,AfiKA DA~E O~ SURV~¥) 30-6EP-B5 KELLY BUSHING ELEVATZON ENGiNEE~I KOZU~KA 85.00 TOE> BASE TOP BASF PMTh TD KI~PARtlK C KUPA~UK C KI.)PAR!IK A KUPAnUK A ************ STRATIGRAPHIC 7168,00 7200 O0 7512,00 7568.00 7U70,00 SUMMARY FROM ORIGIN= 6504,10 6527.01 6662.29 6750,09 6790.15 6~63,]2 420' FNL, SUB'SEA 6419.10 6442 01 6577 29 6665 09 6705 15 6778 12 s u. r. c? z o. : ..,,i, ,,:.; .:,~:'i,,}?~,~ ' R gE, UM NOR TH/80'U:~H'¥',' ::~AST / WEST 1954, ? , · ":" :'~':;~: '4 , 64 r FINAL WEI.,b br]CATTON AT T.D: IRU~ SUB-SEA MEASURED VFRTICAI, V~i~'fTCAL DEPTH D~PTH DEPTH Hr~RIZONTAL OEPAR?URE DISTANCE AZIMUTH VE~T OEG 7670,00 68b{.12 677~..17 2166.31 N 6 47 E SCHLUMBERGER O l RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3C-4 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO :90-SEP-8S REFERENCE 0000~08S6 WELL NAME: 3C-4 SURFACE LOCATION: NORTH 3000 ~SO0 ~000 ISO0 1000 500 -SO0 SOUTH -lO00 -2000 ~EST ~20' FNL, 1402' FEL, S14, T12N, . -':, UM HORIZONTAL PROJECTION REF DO0070~S SCALE = l/SO0 IN/FT -+..~'.:*-½~-t~+~--i-.}-i-;~-~-+++.-;--t-~. ~.:.:~-,d~+-+-~--~--.~--!---t--.~--..G--~:---.i---~,.+~--.-G.-i.--; ...... ;-'-i--', .......... + ...... 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' ........... - ............... , ....................................... ~'":"'? ...... " .......: .... :"~ · ........ T"-"'~ ...................................................... ................................... ., , ,: ......... "7 ......... [7- ....... 7'" i '"'"T"'"'?"'? .......................... t ........ i '; .... ; ....... [ ' ' ': ..... ~ ' ' ' :" [": ....... :7 ..... T'T"7'~ ...... ~ .... i ....... : ...... : PROJECTION ON VERTICAL PLANE 2. - 102. .,'.,SCALEO IN VERTICAl. 0EPT~ 2. HO.~IZ SCALE = I/SO0 IN/FT Suggested form to be inserted~i~~ each "Active" well folder to check for timely compliance with our regulations. 'oPfRATOR, WEL~ NAb~E AND NUMBER Reports and Materials to be received by: ~ ~--~ 7-' Date Required Date Received Remarks Completion Report ·. ~., ~ ~ ~',LT~. T.~- ~'- .; .... ~ Well History - Samples Registered Survey Plat y,~_ Inclination Survey Production Test Reports Log Run Digitized Data NEW PROJECTS ENGINEERING TRANSMITTAL # /) ~ ~ TO: DATE: FROM: L. K. SMITH/P. S. BAXTER WELL NAME: ,_~ - ~ TRANSMITTED HEREWITH ARE THE FOLLOWING: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: DATE: PLEASE RETURN RECEIPT TO: ARCO ALASIC~, INC. ~ ~~.~~ ATTN: PATSY S. BAXTER AT0/5 P. O. BOX 100360 ANCHORAGE, AK 99510~ '" i elephone 907 276 1215 DATE: 09-10-85 TRANSMITTAL NO: 5343 D: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 . ".ED HEREWITH ~ THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ~ND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ~ LIS TAPE AND VERIFICATION LISTING: ~/27/85 #70793 2430-7658.~-~ c~.~ ~' -- iNOWLEDGED: DRILLING L. JOHNSTON MOBIL NSK CL~K DISTRIBUTION:. W. PASHER EXXON PHILLIPS OIL J. RATHMELL UNION K.TULIN/VAULT ARCO Alaska, Inc. is a Subs~.diary of AllanlicRichfieldComoanv ARCO Alaska, Inc. Post Office B, 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the August monthly reports for the following wells: 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) L1-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRUll/L62 Enclosures Alasl(a 0il & Gas Cons. Commission knchora!~o ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany STATE OF ALASKA '~'" ALASKA O,~ AND GAS CONSERVATION CON, vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling weleX[] Workover operation [] Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well at surface 99510 420' FNL, 1~+02' FEL, Sec.14, T12N, R9E, UM (approx) Elevation in feet (indicate KB, DF, etc.) 86' RKB 6. Lease Designation and Serial No, ADL~29 ~ 2562 7. Permit No. 85-190 8. APl Number 50- 029-21416 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 36-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of_ August ,19 ~85 _ 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0700 hfs, 8/16/85, Drld 13-1/2" hole to 2460'. Ran, cmtd, & tstd 10-3/4" csg. Drld 9-7/8" hole to 2790'. Cut cores f/2790' - 2928'. Continued drlg to 3270', Cut cores f/3270' - 3591'. Reamed cored hole. Drld 9-7/8" hole to 3784', Ran logs. Drld 8-1/2" hole to 7631'; ran logs, Continued drlg 8-1/2" hole to 7670'TD (8/27/85). Ran, cmtd, & tstd 7" csg. PBTD = 7568'. Secured well & RR (~ 2300 hfs, 8/28/85. 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 60.5#/ft H-40 weld conductor set @ 100'. Cmtd w/183 sx CS II. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe ~ 2445'. Cmtd w/1050 sx PF "E" & 380 sx PF "C". Performed top job w/lO0 sx Permafrost C. 7" 26.0#/ft J-55, BTC csg w/shoe ~ 7650'. Cmtd w/380 sx PF "E", 250 sx Class "G", and 250 sx Permafrost C. 14. Coring resume and brief description Core #1 f/2790'-2820'; rebovered 30' Core #2 f/2820'-2850'; recovered 24.5' Core #3 f/2850'-2878'; recovered 31' Core #4 f/2878'-2905'; recovered 27' Core #5 f/2905'-2928'; recovered 23' Core #6 f/3270'-3301'; recovered 28' Core #7 f/3301'-3332'; recovered 26' Core #8 f/3332'-3357'; recovered 31' Core #9 f/3357'-3587'; recovered 30' Core #10 f/3387'-3417'; recovered 29' (cont'd on following sheet) 15. Logs run and depth where run DIL/GR/SP/LSS f/3728' = 2445' LDT/CNL/NGT/EPT f/3762' - 2445' SHDT f/3762' - 2445' RFT f/3762' - 2445' DIL/SFL/GR/Cal/SP f/7627' - 2440' FDC/CNL f/7627' - 6000' & 4400' - 2440' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission ~J~~ TITLE Associate Engineer DATE__ t-~s f-~-rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ~ ~ n~n~ DRH/MR15 Submit in duolicate Monthly Report of Drilling and Workover Operations 3C-4 (cont'd) Item 14: Core #11 f/3417' - 3445'; recovered 26' Core #12 f/3445' - 3470'; recovered 31' Core #13 f/3470' - 3501'; recovered 29' Core #14 f/3501' - 3530'; recovered 31' Core #15 f/3530' - 3543'; recovered 15' Core #16 f/3543' - 3558'; recovered 15' Core #17 f/3558' - 3561'; recovered 3' Core #18 f/3561' - 3591'; no recovery RECEIVED Alaska Oil & bas Corls. Commission Anchorage NEW PROJECTS ENGINEERING TRANSMITTAL TO: FROM: L. K. SMITH/P. S. BAXTER TRANSMITTED HEREWITH ARE THE FOLLOWING: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY ~c~ AC~OW~Oo~: , ' l~ r, PLEASE RETURN RECEIPT TO: ALASKA, INC. ATTN: PATSY S. BAXTER ATO~/~q 0i! C' P. O. BOX 100360 'qnOhor~p'~s' C°rnn~iSsion ANCHORAGE, AK 99510 ; M EMORAN OUM State of Alaska TO: THRU: ALASKA_OIL A[~D GAS CONSERVATION CO~-~4ISSION Co V./ t~_tt~rton DATE: August 26 1985 Chai~ ~ ' ~;/~i::./:~ FI LE NO: D. H~. 5 9 ~nnie C. Smi~., Co~ssioner : ~o~ ~o~ FROM: Harold R. Hawkins /. / SUBJECT: Petroleum Inspector .? BOPE Test ARCO, K.R.U. 3C-4 Permit 85-190 Kuparuk River Field Saturday, August. 17.,. 1985:. I left Milne Point, subject of another report, to ARCO's 3C Pad K.R.U. To witness a BOPE test. Sunday, AugUst 18, 1985: I witnessed the BOPE test on ARCO's K.R.U.' 3C':4.- .... There Wer~ no failures. I filled out an A.O.G.C.C. report which is attached. In summary, I witnessed the successful BOPE test on KRU 3C-4 that Nabor's 26E crew performed for ARCO. 02-00IA(Rev. 10/79) Z)&G #4 /84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMbIISSION B,O,P.E. Inspection Report inspector Well Ri __Well Sign_~___ ACCUMULATOR SYSTEbl Cenc-~al dou~ekeeping Rig. Re :: e ,:ye Pit ~ ~ ~' ~:,s VJ. sual Audio Cas Petect:ors it'..;~'E Stock Test Pressure Choke Line VaJves ii ..... ~_. Ii.C,R, Valve Check Valve ............. 'J'e,~ t Results: Failures ..... Full Charge Pressure ........ i~~/~.~ Pressure After Closure.._/_.f~) Pump incr, clos. pres. 200 psig_~ Full Charge Pressure Attained Controls: Master ~/~ Remot ~ Blinds swJ tch Kel!Z and Floor Sa~etf Va.lve8 Upper Kelly Test Pressure_ Lower Kelly ........ Test Pressure~.~.~.~ Ball Type ............... Test Pres~u~'e Inside BOP Test Choke Manifold Test Adjustable Chokes_~ ~ Test Time__~ .... hra ........ ~ h~s~ibut. Jon orig. - AO&GCC cc - Operator cc - Supervisor .-,cc for~_ . ~~_.. August 8, 1985 Mr. J. B..Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupartuk River Unit 3C-4 ARCO Alaska, Inc.~ Permit No. 85-190 Sur. Loc. 420'FNL, 1402'FEL, Sec. 14, T12N, R9E, UM. Btmhole Loc. 1637'FSL, 1305'FEL, Sec. 11, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewzn Kuparuk River Unit 3C-4 -2- August 8, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I.~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chat~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~,~.. Post Office, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3C-4 Dear Mr. Chatterton' Enclosed are' Enclosures o An application for Permit to Drill Kuparuk 3C-4, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on August 10, 1985. If you have any questions, please call me at 263-4970. ] .~.~~S i r e 1 y, Area Drilling Engineer PD/L139 "qnC/7ot~°~r~' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA t.,iL AND GAS CONSERVATION CO~,,MISSION PERMIT TO DRILL 20 AAC 25.O05 DRILL I~ I lb. Type of well EXPLORATORY [] REDRILL [] I DEVELOPMENT OIL i~X DEEPEN [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. ~ 3. Address P. O. Box 100360, Anchorage, Alaska 99510 SERVICE [] STRATIGRAPHIC SINGLE ZONE J~ MULTIPLE ZO N~] 9. Unit or lease name Kuparuk River 4. Location of well at surface 420' FNL, 1402' FEL, Sec.14, T12N, RgE, UN At top of proposed producing interval 1209' FSL, 1325' FEL, Sec.11, T12N, RgE, UN At total depth 1637' FSL, 1305' FEL, Sec.ll, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 86', PAD 49' 6. Lease designation and serial no. ADL 25629 ALK 2562 10. Well number 3C-4 11. Field and pool ~/$'- uA· Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount ,$500,000 15. Distance to nearest drilling or completed 3C-5 well 333' @ 1196'TVD feet 18. Approximate spud date 08/10/85 19. If deviated (see 20 AAC 25.050) 2917 ' psig@___80°F Surface 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 420 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7592' MD, 6850' TVD feet 2560 20. Anticipated pressures KICK OFF POINT 3900 feet. MAXIMUM HOLE ANGLE 43 o (see 20 AAC 25.035 (c) (2) 3335 psig@ 6512 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program I SIZE SETTING DEPTH Hole I C_a_.si n g !13-1/2"I 10-3/4" 8-1/2" 7" Weight 62.5# 45.5# 26.0# 22. Describe proposed program: CASING AND LINER Grade ] Coupling H-40 / Weld J-55/HF-E1W BTC -55/HF-E1W B~ Length MD TOP TVD QUANTITY OF CEMENT (include stage data) · ,oo c, 600 SX CS ,,1 & ~'~,,1~ 3.{}o_ sx cs I~ sx Tail Class 6 80' 2413' 7556' 37' I 37' 117'1 I 37' 2450'I 2450' 37' I I 36' I I 36' MD BOTTOM TVD 117' 7592'1 6850' I I ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7592' MD (6850' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2917 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. A 9-7/8" hole will be drilled to the top of the Ugnu Sands where an 8" core barrel will be used to core 150' of Ugnu and 350' of West Sak Sands. Below the cored intervals, an 8-1/2" hole will be drilled to TD where 7" production casing will be set. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-4 will be 333' away from 3C-5 at 1196'TVD. (continued on attached sheet) 23. I hereby~at the foregoing//~,,~, .is true and correct to the best of my knowledge The space ~ f0r~nr~ssion use CONDITIONS OF APPROVAL DATE ~./~/~.~ Samples required ~IYES ~ Permit number APPROVED BY Form 10-401 (JFB) PD/PDI~-9 Mud log required I--lYES [~NO Approval date 8/,,08185 Directional Survey required ~,M ES I-)NO APl number 5o- o'~?- '~I~/1~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 8, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3C-4 (cont'd) There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 10-3/4" annulus of this well. The 7" x 10-3/4" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. Upon completion of the disposal process, the 10-3/4" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. C°rrlriTiSsion ....... PAD 3C. 'WELL. NO= 41: PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA-- i ~i_--t ...... EASTMAN I4HIPSTOCK,---INC2 ......................._ _ · ............ ..... .~ . . . [ ........ : . . ,.. ..... ! - .- .................. . .~ .... ...... :: ...... _ . . _. .... ................ _ . . , . , . __ ~ .... ~ - .~ ................... _ . . . :. _ . . ..... ......................... BASE PERMAFROST..-TTVD=1586 ................. . ' . . . . _ .q :- ........ TOP UGNU" SNDS :-'-TVD=2596 .............................................................. ~ .... ...... - - ~ m-- 3000 K--13 T'VD=3060 ....... ~ = .......... : ......... ~ .... ~ .............................................. _ , ~ ............ .-m TOP W SAK SNDS TVD=5266 '- ....... ' ..... _ _ ~ ~ c - _ - .. . ~ - _ . ~ . -. ..... ~ ....... . ........................................ o _ K-12'- TvD=3596 KO~ TVD=3900 1~D=3900 DE~=O ...... - .... m ....... 4000. -3 .............. ~ ..... - ............~ m ~ . . :_ - ' ' ~-.- - ~ 39 [OC. ~TVD=-5207-TMD=5339 DEP=517 ~ ~75 u'O~, U~. ;. - -- ' ' : AVERAGE ANGLE' ....... ~ - ; ~ ....... ~ _' . :__ - . ' ~'.' :;~ ~;L _ X : :;TOP uPPR'SNDS' TVD=6393 THD=6966 DEP=1630 ' -'-- _ J ..... · .. _ _ .... ~-' i__>_~~_2._TAROET CNTR-' TVD=6512 T~D=71.29-DEP=1742 -F .... ~-'~ ..... i ................. - ~, ....TOP LO~R SNDS TVD=6596 T~D=7244 DEP=1821 ._- - ~ : _ . . _: ..... ~ ~ ....... ~ .......BASE KUP SNDS .TVD=6704 T~D=7392 DEP=1922 .;~L .... 2ZOO0_. - .......... ~:-- - ~ ..... TD (LOCGIN¢.?_/) ...... TVD=685O.._[~D=~592m~DE~,205_~.~ I I I : . -'-: '~ - - O. ~':' ~:1000' ' 2000 - 3000 '. ....... c k: s[crio ~ ' ~. % iL_:_iVER/t :. ................ 2/ ............... ~ .................... ; .............. ~ ........................ . .-~ .............. ~ ..... ; ...... .._ ..... .~ - . .- . ~ -~ .... ~ - . . . _ ~ ; .... : _ . ; . _ ; . [ ~_ _ ; .... ~ · ~ . _ . _; · . ~ ~-- ~ ..... .......... ..... . .... , ..... ........ = .......................................................... _ : - . ....... SCULL , ---T - ~ - - -: ............... ~ ...... :_.:_ _~_i .... ::': ......... . ~" ,:-'--~-!- . , . ................ ! . ' .... . ~ . - . ~ ................... ...... ; .... ......... ~ ........ PAD ;3C.'WELL NOt 4- PROPOSED i'- ' . / '1[ "N ........... :iiii~i-ii~'i----il;~-i~_iiiiill _iKUPARUK-.-F.I. ELD..NORTH SLOPE. ALASKA - ~~_~~ .... :"--- ~__~i .::--! i:i~'ASTHAN-!_ I~H ! pSTocK~- ~-:::~ ::::: .... ; ===================== !: r:L:::: ! .-':_: t.-:_:! ~ ::- :.i. __'_ ',a/. ~ ~: }_'":': .... :_ .... :_ , .............................. : ~ ---- .... ~ ............. i ................................. 'l ............. :-: '- --:-----:' ......... .-- - : ........ i ...... I .' - ' ~ ............ ...... :_ ......... :~_: ............... ~_:_ _ ! ................... ! ..... ;_: ......... : : ............ ~ ...... : ........ ; ; .... ~ ......... ..... ...... 7- --%1.1000:::_-_: ii-:O '- :'-'~i':i:: :1 000 - 2000 .......... 14000:1 .......................... I ..... I ........... :-- , ..-- _~. . -_ . ~ ...... ? .......... i . . iii. _il_ .l l_ ._ ' - ': ...... ' ........... ................ ....................... :___ ...... :__ _ ~ ....... ;.. _ ................. : ........ '. ........ ~ ...... , ....................... --' .... :---: ...... ~:---h .... ~: ......... : ............... ~ ....... t ......... 'hri,~O00:,-.; ........ : .... : :'-' ...... r ...... ; ....... ' ...... : ..... : - '-: ................................... _ :..'~ .......... ~ ...... .......... ~ ............. ............................................... : ............... .... ; ................. : . .......... TI"ID-7129 :, ..... _~. -! .................. .............. ' ..... i - DEP"I742 .... TARG'E LI~AT'iD#~ ........ ' ...... .............................. $ 320'-'FSL.. 1320°--FEL i_i_:r,~- : i!_.l ii:iii._il l 'i ~-i-' :' l--:'-::-#ORTH-: - i'-i- ' i '. EAST__. 821740- SEC:. II. Tt2N. RgE: ........... : ...... ..................... 4 ......................... · ..... ..... .............................. .................... · . _ . ~.. ............. -/ ...... ' i .......... .................................. ........ f ............ ....................................______ ~. L' '. . .; ......... :_~. _ ' . . ~ ' .......................... ! ...................... : , ................................ ~ .............. : ................ ......... ~ ..... ; ..... :-- : .......................... __! · ; : ................... ! ......... i' ..... ~ ........r-' - : -i ....... ; ....... ~ ............................. .,' .................. -,-,,_.,,,,_-- -, .r~r~r~-- -- : ¢ .......... ;- ...... : ........ , ......................... ~ ................. ,... ........ L_ .............. ~-_-__2 ..... ' ....... ~ ........ ; ............. : ............. ...... ~ ............... -~- ~ SUI~FACE LOOA1'~O# ~ ....... . ..... ~ ............ ' .............. ~ : -~- ~ SEc,-~4~" t~2~.-'R~ .... : ...... - -,,__-~-~,-~----n"~'--/".'~'--' ..... } - , ;. : .......... ---- ......· , .--~: -l_ - ...... : .......... .................... '7 ........ ........ i N'.--h2-.-D E6.-4 2--- ri I :N--E ~:~-:::--::~-~--~ 'o;/:.~. ~';~:_ : ~,,o~).~:_,_: ...... :__._.. - ~ - . ~Oo~ , _~0oo i~'19oo,, NORTH ' ' ' 800' 1 500 17'00 600 WOO ,I ;~00 :1 200 ,' '." ..~.'.:'i ",,..'.. ~ ..'.,.",.' ,~'t~ :. i.." i · I ' . I , I . ' , : . / - : ' f : ' ' , -- ' :~ : "<"~ '~'*''i '' '' ~' ' '"' ' '"': ~"t~'~ '1 ' . .'~ ~I . ..., ...................... ~..,. .. . ..: ......... ' , I . ' _ i . '.'...' L..'. ...... : ..... ', ' DO¸ )O t , AR ALASKA. iNc. ' ", A, IIUK FIELD.: ~NORTH SLOPE'.i ALASKA WEEL. PATHS..EXTEND BEYOND'. ....... :._ I{~:'Vl~'k, lJH WINDOW , i' 't . i , :: ' ! I ' : ' ............ ~ ...... ~ '""" 37~z> ................................................... ' ~ ' ~ ' ' ' · i i , ,.. i . . . I [.. ,.-'; ...... t~ ' ~ . ,. '.t' ,~ I I ' ' I.'" : "32~ ' '"-; -: ............... ' ........ : ........ .... ' ............... -. ~ ~ ,.'~. . : . '1,'1~,', '"l { ' ''I ' '~: ' ' · {:.:~ .... , ~ 3tO ' ' .,. ," ; I · ' '. . ' i . = { ~ , . , --:--, .... ~ ...... : .... , ........ ,_.' i_~ _: ' ........ =~_~_: .... ,._. { .... .,. .......... :_~=.....: ..... ' '=,'~ ,~ ;Il, ,-, I l, . .., ,' ' ~ I ~,,I . {,,, ,..{ ..... . ,. i~'' { ~ ; I , ' ~ ' ': ' ' ' ' ' ' -; ;- I : ~ :.l., : I ' I ' , { ] , . ' I ~ : · ' I , : . ', ~ : ~ ; ~ , " = I ~ ' ,I .~_~ .'...~._L[~_...~. _~ .:_L..=:.. ~ ...... ..... ~ -', ... { ,:{~ I , ,',l: KUPARUK RIVER UNIT 20" DIVESTER SCHEMATIC D'ESCR I PT I ON I. IG · C~CTOR. 2. TAi',,i,(O STARTER HEAD. 5. TAh,IKO SAVER SUB. 4. TANI<O LO~R QUICK-CO~/~CT ASSY. 5. TANKO UPPER QOICK-CC)K/~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/I0' OUTLETS. '7. I0' HCR BALL VALVES Il/I O' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE A~AR PREVENTER. 8. 20' 2000 PSI Ah~',~LAR PREVENTER. MAI: NTENANCE & OPERAT. I ON · 4 i. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES '- HAVE OPENED PROPERLY. 2. CLOSE AhaNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Ah~JLAR PREVENTER IN THE EVENT'THAT AN INFLUX OF WELLB(3~ FLUIDS OR GAS IS DETECTED. IF ~ECESSARY, blAh~JALLY OVERRID~ AND CLOSE APPROPR I ATE VALVE TO ACHIEVE DO~f~IND DIVERSION, DO NOT SHUT IN V~LL UNDER ANY CIRCUMSTANCES. 7 DIAGRAM #1 13-5/B" 5000 PSI RSRRA BOP STAQ< I. 16" - 2000 PSI TAN<~ STARTING HF_AD 2. I1' - 3000 PSI CA~IN~ FF. AD 3. I1' - ~ PSI X 1,3--S/8' - ..5000 PSI SPACE:R SPODL 4. 13-5/8' - 54:X~ PS]: PIPE ~ 5. 13-5/8' - SCOD PSI DRILLING ~ VU'O.O<E: Al~ KILL LIhF..S 6. 13--5/8" - ,5000 PSI ~ ~ W/PIPE RN~ C:N TCP,, 7. I,.~'8' - 5(X)0 PSI AAN.LAR AC~ATOR CAPAC)TY T, EST J , mi I l [ - 4 2 I. O-ECX AhD FILL AC~TCR RF~OIR TO F~ LEVEL WITH HYDRAULIC FLUID.' 2. A~ THAT ACCl~T~ PI~ IS 5000 PSI WITH 3. CI~ TINE:, T~iEN CLOSE ALL UNITS SINU_TA~OUSLY ALL UNITS A~ CLOSED WITN (~%~3ING ~ ~FF. RECEIVED: AUG 0 1985 4. RE:CC~ CN NADC EEPC~T, TiE ACCEPTABLE LOA~R LIMIT IS 4S SE~ CLOSIha3 TIlVE AhD 1200 PSI RE~INING 13-5/8" BOP STAC~ 1. FILL BCP STACK AAD ~ MANIFCLD WITH ARCTIC DIESE/.. 2. Q-ECK THAT ALL LOCK D(~ SC~ IN ~ ARE FULLY RETRACTED. SE. AT TEST PLUG IN ~ WITH RLt~ING J'r AAD RLFI IN LOCK~ SC~. LIhE VALVES AD,/A(~ TO BCP STACK. ALL OT~ 4. PRES~ UP TO 2.50 PSI A~ NO_D FCR I0 MIN. IN- CREAS~ PEE~ TO 3000 PSI ~ HCLD FCR I0 MIN. BLEED PR~S~ TO 0 PSI. 5. (~C~N ~ PEE'VENTER AI~ MANJAL KILL AAD O-~ LIhE VALVES. CLOSE TCP PIPE RAiv~ Ah~ HCR VALVES CN KILL AhD Q-~ LIhES. 6. TEST TO 250 PSI Aha) 3000 PSI AS IN STEP 4. 7. CcAFrlAIJE TESTING ALL VALVES, LIAES, AAD (~S WITH A 250 PSI LEAN AhD 3000 PSI HI(3t-L TEST AS IN STEP 4. DO NOT PR~~ TEST ANY ~ON_THATY~S NOT A FULL CLOSING P~SITIVE SEAL CHCKE. FUNCT~ TEST CHCXES THAT DO NOT FULLY CLOSE. TEST BOTTC~ PIPE RAN~ TO 250 PSI AND 3000 PSI. CLOSE BLIAD RA~ AhD TEST TO 2..50 PSI AAD 3000 PSI. CPEN BLIND RAMS AND R~I~ TEST PLUG. MAKE SURE 'MANIFOLD AhD LIhES ARE FULL OF NCN-FREEZING FLUID. SET ALL VALVES IN DRILLING PCSITICt~ 12. TEST STAh~IPE VALVES, KELLY, KFIly COQ<S, DRILL PIPE SAFETY VALVE, AAD INSIDE BCP TO 250 PSI AAD 3OOO PSI. 3. RECCRD TEST Ih,':'Ot~TICIN ~ BLC~ ~ TEST FORM, SIGN, AAD SEAD TO DRILLING SUPERVISCR. 4, PERFCRM CCNIM_ETE BCPE TEST AFTER NIPPLING UP A~D Y~cEKLY THEREAFTER FI~ICNALLY CI:~TE B(~ DAILY. , Oil & Gas Cons. Commission 4. nchorage ARCO Alaska, Inc? '~. Post Office ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat Wells 1-16 Dear Elaine' Enclosed is an as-built location plat for you have any questions, please call me at Si ncerely, Gruber Associate Engineer J G/tw GRU6/L113 Enclosure - 3C Pad the subject wells. 263 -4944. If ,. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Y = 5,995,855.15 Lot. = 70°25'58.955'' SEC. ll WELL I x= 528,205.68 Long.-' 149°46'13.622" ~ SEC. 14 596"FNL 1366'FEL N 0 R T H - Y = 5,995,893.73 Lat. = 70023'59.532" WELL 2 x= 528,193.14 Long.= 149°46'15.983' 5.37' FNL, 1378'F£L Y = 5~995~952.43 Let. = 70°2¥~.110" WELL 3 x= 528,180.60 Lon~= 149°46'14.~43' 478'FNL~ 1390'FEL Y = 5~996~ 011.07 Let. = 70°24'00.687' ~ ~ WELL 4 x= 5~s, lss.~z Lo,~.:~4~°~s'14.~o~" 420' FNL~ 1402'FEL ~ ~'~ ~ ~ ' ~ WELL 5 X= 528,520.16 Long.= 149°46'04.3~' 346' FNL ~ 1050'FEL Y = 5~996,027.76 L~I. = 70°24'00.837' WELL 6' x= 5ze,s~z.s~ Lo,~.= 404' FNL ~ 10~' FEL Y= 5~995,969.11 Let. = 70o2¥00.260" WELL 7 x= 528,~5.24 Long.= 149o46'03.658" 463~FNL ~ 1025' FEL ~ Y= 5~995,910.44 L~I. = 70o23'59.685" ~-~ WELL 8 x= 528,557.71 Long,= 149°46'03.299" 5~'FNL ~ 1013'FEL ' Y= 5~995~372.49 Lot. = 7~25'54.~7" WELL 9 x, 528,672.61 Long.= 149°45'59.993'' ~O'FNL ~ 901' FEL WELL 10 x= s~e,sss, o~ Lo,~=~so~'~.~s" 1119'FNL ~ 889' FEL Y = 5~995~255.22 Lat. = ~°23'53.233" WELL '11 x= ~,s~7.~ u,o.= ~o~'5~.z7~" 1177'FNL~ 876'FEL Y = 5~995~196.51 L~t. = 70°23'52,6~" WELL 12 x= 5~8,710.19 Lona.= 14~45'58.912" DRILL SITE 3'C .c~:,'=.oo' ~'~.~, AS-BUILT CONDUCTOR LOCATIONS v= 5,~5,121.33 Let. = 70°~3'51.929" WELL 13 x= 528,358.10 ~ng.= 149°~'09.235' WITHIN SECTION 14~ TI2N~ 'RgE~ U.M.~ ALASKA 1310'FNL~ 1217'FEL NOTE: Y= 5~995~180.01 Let. = 70°23'52.5~" WELL 14 x= 528,3~.63 Long.=149°46'09.594" COORDINATES ARE ALASKA STATE PLANE ZONE 4. 1251'~L ~ 1229' F~ SECTION LINE DISTANCES ARE TRUE. Y= ~995~238.66 Lat. = 7~23'5~.084" HORIZONTAL POSITION PER LHD 5 ASS~. MONUM~S 19-1 6 19-2. WELL 15 X= 528,333.07 Long.= 149°46'09.956" VERTICAL POSITION PER LHD 6 ASSOC. TBM 0PI6~ 6 DOC. 125. 1193'FNL~ I241'FEL 'WELL NO. 6 INFORMATION PER DWG. NO. NSK 9.05.303dl. Y= 5~5~297.32 Lot. = 70°23'53.661" WELL 16 x: 528,320.55 Long. =149° 46'10. 316" 1134' FNL~ 1253' FEL CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND THIS PLAT REPRESENTS A LOCATION SURVEY ~. THAT ALL DIMENSIONS AND OTHER DETAILS -. ~ "~ . ~UF~U~ ' ~ ,~. ~ S~RVEYEO FOR. A~O AlasKa. Inc. ~ .......... ~~~~~ lull ~ ~ I .,.~UULU/ ~..~~..~ ....... I~II" v. D~TE MAY I~, 1~85 ..... '"": ' ' ¥. . ' CHECKED J HERMAN 3340 Arctic Bou/evar~ Suite 20, ~nchorage A/ask, 99503 I~- -- ' ..... I CHECK ~LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE' .oc (gA_ thru 8) (8) (3) Admin /~-'-' ~-'C'~f 9. 7~ru 12) . 10. (10 and 12. (13 thru (22 thrd .~6) 1. Is the permit fee attached ......... ~ ............................... 2. Is well to be located in a defined pool ..................... 3. Is well located proper distance from property line .......... 4. Is well located proper distance from other wells ............. ii!iI 5. Is sufficient undedicated acreage available in this pool .... 6. Is well to be-deviated and is wellbore plat included ........ 7. IS operator the only affected Party ........... ' ............... 8 Can permit b approv d b for day wait · · e e e e ten- ,..., ...... . .... ., ....... 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO h d f ' Does operator ave abon in orce .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ' Is conductor string provided .............. Is enough cement used to circula;~';~ ;;~;;~';n~ Will cement tie in surface and intermediate or production strings ... ,~ Will cement cover all known productive horizons ................... '._~g_ Will surface casing protect fresh water zones., ........ Will all'casing give adequate safety in collapse~ ~nsl;~ ;~d ~;~.. · Is this well to be kicked off from an existing wellbore ............. Is old wellb0re abandonment procedure included on 10-403 ............ wellbore separation propo ed Is adequate s ............................ Is a' diverter system required ' ' Are fiecessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to .~ffB'b psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. the pr f H2S gas. p babl Is esence o ro e ,.,.,,,,,,,,,,.,,,,,,,.,..,,,..,, ... Additional requirements ,, .......................................... · . , Additional Remarks: REMARKS HJH #~"# ' , . ' ";:, INITIAL , .GEO. ,UNIT ' ON/OFF 'pOOL CLASS STATUS" ' AREA NO. ' 'SHORE ' '~. · %' ,~,: ":: ?:~..,i , ~, , , · ,, ...... ~,,,..~.. ~.; , ,, . , ,., , ~ 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. .o OR~G~N : R E~I,,~ NAME : 131.4~,4 CONT!N~IA~I~N PREVIOUS R~EL CO~N'FN~S :LI~R~RY TA~ DATE :~5t09i~5 ORIGIN TAPE N~MF :0789 CONTINUATION # :01 PRE¥IOU$ T~PE : COmMeNTS :LIbRaRY TAPE EOF ~LE NAm~ :EDIT ,OOl 8EPVTC~ NA~E : DATE : 4AXImU~ LEmGTH : 1024 MILE TYPM : PREVIOUS FILE ; ** INFOR~TI~3N RECORDS ** ~N~N COMTFNT$ UNIT TYPE CATE SIZE CODE C~ : ~RCO At,ASKA INC 000 000 01~ 065 WN : 3C-4 000 000 004 065 ?N : KUPA~UK-iWEST SAK INTERVAL) 000 000 027 065 ~ANG: ~E 000 000 002 065 TOWN: 12N 000 000 004 065 SECT: ~4 000 000 002 @6~ ~T~T: Ab%S~A OOO 000 006 0~5 OT~¥: US~ 000 000 003 065 UNIT TYPE CATE SIZE CODE PR~$: E 000 000 001 065 ** CO~UEWT$ ** ******************************************************************************** T.~¥P 010,~t07... vF, PI?ICA?ION h!$T~NG PA~E 2 ~,L,ASKA COh~P'UTIgG C~NTE~ COMPANY '= A~LANTIC ~ICHWIE~D CU~PANY WELL ; ~IELD : PRUDHOE WIELD = KUPARUK (WEST SAK INTERVAL - SHALLOW SANDS) COtlNTY NORTH S[,,0, ~, BQRDUGH JDR NU~BFR AT ACC: 707S9 [,,DP: C. T.,K T E CASING = ~0.75" ~ 45.50' ' RiT SIZE :, 9.875" TO 3600' TYPE FT.~,U ID = ND DENSITY - ~.9 LB/G R~i : 4,3J0 ~ 6~..0 viSCOSItY : 42,0 S RMF ~. 4.620 g 6~ DF ~H : ~.0 Rh, C 1.930 ~ ~ DF FLUID I,OSS = ~.0 C3 ~M AT BH~ -, .3~9 ' MATRIX S~NDSTONE ***** THIS [)AT~ HAS NOT BEFN DFPTH SHIFTED - [tVERLAYS FIELD PRINTS SCHhl;M~E~GE~ .[,O.¢~$ YNCbt.'D~O t,~ITH THIE, ~AGNETIC TAPE: ..DUAl., IMDUCTIDN SPHERIC~IJLY FOCUSED LOG (OIL) [~OMG SPACED SONIC LOC~ (bSS) LITHD DENSITY COMPENSATED [,OG (bDT) COMPENSATED NEUTRO~ I,,O~ MATORAL ~A~,~ TOOL (NGT) , ** DATa FORMAT RECORD ** TYPE S1ZE DEDR CODE ENTRY 2 1 66 0 4 ! 66 8 4 73 60 9 4 65 ,lin ~,6 1 66 0 1 66 0 DAI'U~ SPFC?FIC~T7ON RLOCK$ ~NEM S~RVICE SMRVlCE UN.~T APl APl ADI ~PI ~IbE SIZE SPb REPR ~ROCESS ID ORDE~ # bOG TYPE CbgSS ~OD NO, CODE (OCTAb') DEPT ' FT O0 000 O0 0 0 4 1 68 00000000000000 SF;,U DII, OHM~ O0 220 01 0 0 4 I 68 0000000000000~ ION DII, OH~ O0 120 44 0 0 4 1 68 0000000000000 ~.o o~'~, o..~ OD ~.2o ~ o o 4 ~ e~ oooo~ooooooo s~ .~,, ~v oD o~o o~ o o 4 ~ ,~ oooo~.~ooooooo LVP Oln. HO~ VE~I, FICAWlON LISTING GR DiY. GAPI O0 SGR LDT GAPI O0 CALl ~DT IN O0 DRRO l~[)~ G/C3 O0 ~R~T !,D~ O0 ~N~A ~DT O0 WPHI LDT PU O0 PEF LD~ O0 MCNb LOT CPS O0 ~CWh LDT CPS O0 OhS LDT O0 OSS bD~ SG~ ~GT GAPI O0 CG~ NGT GA~I O0 ~OTA ~GT ~U THOR NGT PPM O0 UR~N NGT PP~ 00 ~T [.,S~ US/F O0 DT[, ~$~ US/F O0 SP [,,55 ~V O0 MATT ~PT DB/M O0 CALf ~PT IN O0 SG~ EPT GAPl O0 NVU ~PT v O0 FVU ~PT V O0 WVD ~PT V O0 ~VR ~P? V O0 FVR MPT V 310 28O 35O 356 42O 000 ~90 35~ 33O ]3O 000 000 719 719 79O 79~ 520 5 0 o~o 1,30 000 000 000 000 000 00o ** DATA ** SP RHOB MPHI OL$ POTA TPL ~V~ 377~.5000 SFLU -3o 9951 GR -q90:~500 DRHO -999.~500 PEr -~90.~500 OSS -q99.~500 POTA 95.5273 DT -q90.~500 EATT -o99.~500 wVU -099.~500 wV~ J 95 -999 -99q -~99 -999 -~99 DEPT SP Mpw I p[)T A 2.2151 DR~O ~,B47'/ PEF !,,5b~5 POTA 79. O. O. O. O1 O1 Ol O2 Ol Ol O0 O0 O! O0 O0 Ol Ol 5O ~0 5O 5O O1 ~0 RO Ol O1 O1 Oi O1 O0 O0 O0 O0 O0 O0 !4{.4 5273 2500 2500 2500 2500 5273 2500 2500 2776 2148 0215 5303 0156 SGR NRAT THOR CASI NVD B'R ~_T NCNL THoR I 68 00000000000000 ~ 68 00000000000000 00000000000000 I ~ oooooooooooooo , ~. oooooooooooooo , ~, oooooooooooooo I' ~ oooooo~ooooo ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~0 oooooooooooooo I ~ oooooooooooooo ~ ooooooooooo,ooo ~ ~ o, ooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo I ,I oooooooooooooo 000000000~0000 ~ ~ oooooooooooooo ~ ~ ooooooooooo.o oooooooooo,oooo ~ oooooooooooooo i ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooo,oooooo ~ ~, oooooooooooooo ~ ,~ oooooooo, oooooo ~ ~ oooooooooooooo ~ ,~ oooooooooooooo ~ ~ oooooooooooooo ~ ,~ oooooooooooooo ~ ~ oooooooooooooo 5.5906 -.~.~oo c~, .2500 ~CNb 9~,2500 URIN i10,0273 SP -999.2500 -990.2500 FVD 3.402b 86.7148 CALf 3.6350 ~NRA 174~..6875 rCNb 86.7148 CGR 7.5867 {IRAN 8.7051 -999.2500 '999.2500 "99~,2500 -999,2500 -999,2500 '30, -999,~500 3,3459 7107 9, 3,8 86 455,8' 06 7874 T, VP 010,~,~07 vEnIP!CAwlnN bTST1NG PAGE 5 SP RHO6 NPHi POmA TPL N'VU DEPT SP RHOB NPHI POTA TPI., NV'U SP POTA TP[, NVU NYn 3600 -33 2 .0 7~ 0000 SFLU 6. 01,95 ~R 78, ~.428 DRHO n .972 PEF ..0~3 DT ,2676 ~ATT .~266 wVI! O. 3500 -33 1 45 -0 70 20 1 0000 620 DR}{[] 0 5137 POTA 0 2773 6611 EA. TT 296 7491 FVU ~4~9 WV~ O' 3400 -3~ 41. -0 1 6n 16 0000 4883 ~R 60! osnl 6R~O 0 0532 0S$ 0 6602 P0TA o 4180 OT 12~ 4111 EATT 268 3682 .~468 ~V~ ~0~ 2.0569 o~0 0 ~PHI 40.67~8 PEF OLS -0,0342 05S OR 47,0B05 nT 130 ?PL 15,~301 ~ATT 174" NV{] 1.~85b rVU n' ~V~ 4,~4~8 ~¥~ O, SP ~PHI 3~00 -25 -0 0000 SFT..,U 0951 1975 DRNO 6270 PEF 2'173 6406 3101 75O5 5125 4023 0063 94 0142 5273 55oo 4382 2773 1304 4397 0 51 6406 5459 7500 0945 4180 0405 574.5 03~1 n166 2773 6406 2407 7505 298~ 98,35 00~9 0549 0269 0146 3125 3125 8169 75OO 9851 3398 0020 4307 0176 C A b I N V'D NRAT THOR DTL NV O NRAT THOR OTb CAbI mVD THOR CALl ! SG~. HRAT DTI. CALl NCNL ~.10.7773 SP 9.7207 SGR 1,9366 FVD 3.5~ RNRA 9' URAN ' 9 SGR . 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