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HomeMy WebLinkAbout196-163XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ,i,~ Number of Well History File RESCAN Complete Color items - Pages: Gray.scale, halftones, pictures, graphs, charts - Pages: ~ Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type 'OVERSIZED Logs of various kinds Other COMMENTS: Scanned b~ ~~, M~-~ Nathan Lowell TO RE-SCAN Notes: i~-.~,c...~nnP, d by: Beverly Mildred Daretha Nathan Lowell Date: /s/ e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission e RECEIVED JUL 2 4 2006 1 a. Well Status: D Oil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: v 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/23/2006 196-163 306-147 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1 0106/1996 50- 029-20697-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/18/1996 PBU 15-02A 1441' FNL, 285' FWL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3224' FNL, 4300' FEL, SEC. 21, T11N, R14E, UM 63' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2703' FNL, 4303' FEL, SEC. 21, T11N, R14E, UM 11844 + 8994 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676223 y- 5960047 Zone- ASP4 12390 + 8976 Ft ADL 028306 TPI: x- 671685 y- 5958158 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 671669 y- 5958679 Zone- ASP4 N/A MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR 22. CASING, LINER AND CEMENTING RECORD A;" !.h' ·.';;;i',; 'iii.2 i,Jt.l.;;ii)~;)!;i;; ¡iif;);i;;i;i!i; ~fii~~;i~~} ;iV;; ;;i;};f;;":)~17é,i<i,i '" :i;i 0<;"01" i,.'; , IUP;;. BhTfOM ¡ii ,;',,;., .iO<i 20" 91.5# H-40 Surface 79' Surface 79' 30" 1902 sx Poleset 13-3/8" 72# L-80 Surface 2675' Surface 2675' 17-1/2" 300 sx Fondu 400 sx Permafrost 9-518" 47# L-80/S0095 Surfac.e 10034' Surface 8316' 12-1/4" 500 sx Class 'G' 7" 29# L-80 9726' 10034' 8079' 8316' 8-1/2" 350 sx Class 'G' 2-7/8" 6.5# L-80 9692' 11905' 8053' 8994' 3-3/4" 145 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and i?;d; Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2",17#, L-80 8965' - 9721' 9710' MD TVD MD TVD 4-1/2", 12.6#, N-80 9721' - 9792' '-;;;;);;;;;;;; ,i'"" ¡¿q,-)!; ;; ,,-'0-, ,. p 'Î '" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED SCAN~ t¡;tJ d U L I.) ~J 9700' Set CIBP 9387' P&A w/1 0 Bbls Class 'G' 8815' Set EZSV wI Whipstock on Top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL -BSL GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL-BsL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFL JUL 252006 Form 10-407 Revised 12/2003 0 RIG I N A tTINUED ON REVERSE SIDE (, 28. GEOLOGIC MARK 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 2A 10776' 8878' None Zone 1 B 10846' 8918' Zone 1 A 11866' 8994' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I ~erebY certify that the fO~ing ~s true and correct to the best of my knowledge. Signed Terrie Hubble /10) Title Technical Assistant Date 07/~1o~ PBU15-02A Well Number 196-163 306-147 Permit No. I A roval No. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Jeff Cutler, 564-4134 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Well: 15-02B Accept: 06/03/06 Field: Prudhoe Bay Unit Spud: 06/11/06 API: 50-029-20697-02 Release: 06/30/06 PRE-RIG WORK 05/19/06 DRIFTED TO 9,600' SLM WITH A 10'-2 1/4" BAILER. DRIFTED WITH 2.25" CENT. AND SAMPLE BAILER TO 9,754' SL. UNABLE TO MAKE ANYMORE HOLE. RAN 1.89 SWAGE TO 9,766', UNABLE TO WORK ANY FURTHER. SET 1" DGLV (BK) IN STA # 2 (DWP-POGLM). PULL I RUN REPORT TURNED IN. WELL LEFT SHUT IN. OS/20/06 PERFORMED CONTINUOUS GYRO DATA SURVEY FROM 9000' TO SURFACE. WELL LEFT SHUT IN. OS/23/06 RIH WITH 2.25" 00 JSN DOWN TO TARGET DEPTH ON 9725' CTMD. PAINT YELLOW FLAG AT 9715' CTMD. POOH. RIH WI WEATHERFORD 2-7/8" CIBP, SET AT 9700' CTM (TAG I CONFIRM GOOD SET). RIH WI 1.75" BDN, TAG CIBP AT 9700' CTM. CIRCULATE BOTTOMS UP. LAY IN 10 BBLS CLASS G CEMENT FROM 9700' TO 9200' CTMD; OBTAINED 1:1 RETURNS. DROP BALL AND CLEAN OUT CEMENT DOWN TO 9400' CTMD WITH 1.5 PPG BIO FOLLOWD BY 1% KCL. POOH CHASING RETURNS AT 80%. JET 4 PASSES ACROSS ALL JEWELRY (2 POGLM'S AND SSSV NIPPLE). POOH, CHASING RETURNS AT 80%. TRAP 1000 PSI ON WELL. RDMO. JOB COMPLETE. OS/25/06 TAGGED TOC WI 1.90" CENT AND SAMPLE BAILER AT 9387' SLM. PRESSURE UP TBG TO 2500 PSI, RETAG TOC AT 9387' SLM. MIT-T TO 2500 PSI (PASSED). SAMPLE OF CEMENT IN BAILER. DRIFTED WI 4.55" G-RING TO TOP OF POGLUM AT 3177' SLM. JARRED ON POGLUM FOR APPROX 1HR. WIRE PARTED AT SURFACE ON SECOND RUN. FISHED ALL OF WIRE AND TOOLSTRING. CHANGE TO BRAIDED LINE, RIH WI GS. OS/26/06 JARRED ON POGLUM WI BRAIDED LINE FOR APPROX 8HRS AT 4000#. MOVED UP HOLE FROM 3164' BLM TO 3083' BLM, RESET 5 1/2" PRT IN POGLUM AT 3083' BLM. (PRT IS 62" OAL HAS 41/2" F.N. BAITSUB IS 8" DEEP. PINNED WI (8) STEEL 5/16" SHEAR SCREWS). WELL LEFT SI FOR COIL. NOTE: PRT WILL STICK OUT OF POGLUM APPROX 32", POGLUM IS 242.7" OAL. OS/28/06 RIH WITH WFD 4.5" HYDRAULIC GS SPEAR WITH UPIDOWN JAR. LATCH POGLM AT 3127' CTMD. HIT 1 JAR LICK AT 5K OVER AND PULLED POGLM UP HOLE 10' AND WOULD PULL NO MORE. PROCEEDED TO HIT 50 JAR LICKS; NO MOVEMENT. POOH AND CUT 100' OF PIPE. MU WFD 4.5" HYDRAULIC SPEAR WITH ACCELERATOR, 2 WEIGHT BARS AND UPIDOWN JARS. RIH - ENGAGE FISH AT 3122' -19 JAR LICKS AT 10K TO 20K TO FREE FISH. 2 JAR LICKS THRU SSSV, LD FISH. ALL FISH RECOVERED EXCEPT 2 EA 3" X 1.5" SLIPS AND SMALL CHUNKS OF RUBBER. RDMO. FISHING JOB COMPLETE. DRIFTED WI 4.50 CENT AND 51/2" BLB TO TOP OF POGLM AT 8972' SLM, NO PROBLEMS WI DRIFT. RDMO. WELL LEFT SI. 05/30/06 WELL SI UPON ARRIVAL. TIIIO 200/500/50. 5.5" TUBING CUT AT 8955 FT WITH 4.15" POWERCUTTER. FINAL TIIIO 300/500/80. RDMO. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 1 5-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 6/1/2006 Rig Release: 6/30/2006 Rig Number: 27E Spud Date: 2/12/1982 End: 6/1/2006 00:00 - 06:00 6.00 MOB P PRE Disconnect Complex's Interconnects. Remove All Berm Dunage, Check Tire Pressures, Function Tested Hydraulic Wheel Jacking Systems 06:00 - 09:00 3.00 MOB P PRE Move Suppport Complexes from Around Rig and Stage for Transport to DS15. 09:00 - 12:00 3.00 MOB P PRE Move Pump Room Complex, Pit Complex and Motor Complex to DS15 12:00 - 15:00 3.00 MOB P PRE Move Pipesheds to DS15 15:00 - 18:00 3.00 MOB P PRE Move Substructure Off of AGI-07A 18:00 - 20:00 2.00 MOB P PRE Move Rear Substructure Wheel Cylinder to Inner Position, Clean Up Around Wellhead 20:00 - 00:00 4.00 MOB P PRE Move Substructure with Derrick Up to DS15 6/2/2006 00:00 - 01 :00 1.00 MOB P PRE Move Substructure from East Side of Pad to West Side of Pad 01 :00 - 04:00 3.00 MOB P PRE Move Rear Substructure Well Cylinder Goose Necks to Outer Position. Lay Mats Aroung Well 02B and Cover with Herculite 04:00 - 07:00 3.00 MOB P PRE Spot Substructure Over Well 07:00 - 12:00 5.00 MOB P PRE Set Pipeshed Mats, Spot Pipsheds 12:00 - 18:00 6.00 MOB P PRE Set Cuttings Tank, Pit Complex, Motor Complex and Pump Room Complex. 18:00 - 00:00 6.00 MOB P PRE Hook Up Interconnect Lines 6/312006 00:00 - 02:00 2.00 MOB P PRE Spot Camp on Location, Set Camp Support Generator, Set Shop, Electrical Shop and Parts House 02:00 - 10:00 8.00 MOB P PRE Berm Substructure, Pits Complex, Motor Complex and Camp Support Generator. Replaced Equalizer Valves Between Pits 3 & 4 and 5 & 6. 10:00 - 12:00 2.00 WHSUR P DECOMP PJSM; RIU Circulating Hoses to Circulating Manifold to Displace Well with 140 deg. Water. DSM Unable to Pull BPV Because of Single Master Valve on Wellhead. ACCEPTED RIG FOR OPERATIONS AT 1000HRS, 6/3/06 12:00 - 16:00 4.00 WHSUR P DECOMP Ordered and Installed Swab Valve on Wellhead 16:00 - 17:00 1.00 WHSUR P DECOMP Tested Tree, Circulating Manifold and Lines to 3,500 psi. 17:00 - 18:00 1.00 WHSUR P DECOMP RlU DSM Lubricator, Pulled BPV, RID Lubricator 18:00 - 19:00 1.00 WHSUR P DECOMP Reversed Circulated 100 bbls 120 deg. Water at 5 bpm, 600psi Down 5-1/2" x 9-5/8" Annulus Taking Returns Up 5-1/2" Tubing to Slop Tank. 19:00 - 20:00 1.00 WHSUR P DECOMP Shut Down Pumps and Switched Valves to Pump Down Tubing Taking Retums Off the Annulus to Slop Tank. Pumped 30 bbl Safe Surf 0 Pill at 5 bpm, 260 psi. Followed by 140 deg Water at 12 bpm, 700 psi. At 23 bbls Water Away Noticed Diesel Mist Coming Out Gas Buster Vent Line. Immediately Shut Down Pumps and Secured the Well. Discovered Diesel Mist Covered +/-60' x 60' Area. Notified 5700 and Reported Discharge to Bill Rodsky. 20:00 - 22:00 2.00 WHSUR N HMAN DECOMP Started Spill Clean Up. Bagged Oily Absorbant in Double Oily Waste Bags. ACS Arrived on Location at 2030 hrs. Utilized Vac Truck on Location Suck Up Standing Snow Melt Water with Oily Sheen 22:00 - 22:30 0.50 WHSUR P DECOMP Held PJSM with Rig Crew, Mudman, Toolpusher and WSL. Developed Procedure for Circulating Through the Choke Manifold/Gas Buster. 22:30 - 00:00 1.50 WHSUR P DECOMP Displaced Diesel from 5-1/2" x 9-5/8" Annulus by Pumping Down the 5-1/2" Tubing. Pump Rates Below Rate Pressure BBLs Pumped Printed: 7/512006 10:10:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 15-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 6/1/2006 Rig Release: 6/30/2006 Rig Number: 27E Spud Date: 2/12/1982 End: 6/312006 22:30 - 00:00 1.50 WHSUR P DECOMP 1 bpm o psi 10 bbls 2bpm 20 psi 20 bbls 3bpm 50 psi 50 bbls 4bpm 100 psi 100 bbls Diesel Out of Well 6/4/2006 00:00 - 02:30 2.50 WHSUR P DECOMP Continued to Pump Down 5-1/2" Tubing Taking Returns Off 5-1/2" x 9-5/8" Annulus at the Following Rates Rate Pressure BBLs Pumped 4bpm 100 psi 200 bbls 5bpm 150 psi 400 bbls 6bpm 230 psi 600 bbls 7bpm 300 psi 1,000 bbls Clean Fluid at surface at 700 bbls Circulated 1 Bottoms Up After Clean Fluid to Surface 02:30 - 04:30 2.00 WHSUR P DECOMP M/U BPV and Running Tool on T-Bar. Set BPV, Would not Set, Removed BPV and Reset Locking Dogs, BPV Prematurely Set While on Rig Floor, Remove from Running Tool and Reset Again, Run BPV and Set. Tested from Below to 1,000 psi. 04:30 - 06:00 1.50 WHSUR P DECOMP Blow Down Circulating Lines and RID Same 06:00 - 07:00 1.00 WHSUR P DECOMP PJSM; N/D Swab Valve, Master Valve and Adapter Valve 07:00 - 08:30 1.50 BOPSU P DECOMP Installed Blanking Plug in Tubing Hanger 08:30 - 17:00 8.50 BOPSU P DECOMP PJSM; N/U BOPE's. Move Stack from Cellar Pedistal to Wellhead. Installed BOPE Bolts and Torqued Same, Installed Double Annulus Valves, M/U Choke and Kill Lines, Set Drilling Riser. 17:00 - 18:00 1.00 BOPSU DECOMP Installed 3-1/2" x 6" Variable Rams. 18:00 - 22:00 4.00 BOPSU DECOMP M/U Flowline, Connected BOPE Securing Lines. Hook Up Auxiliary Lines and Drain Lines to Flowline. 22:00 - 23:00 1.00 BOPSU DECOMP PIU 5-1/2" Test Joint. M/U XO, Pump in Sub, Floor Safety Valve. Installed Test Joint and Closed Lower Pipe Rams. M/U Test Manifold to Pump in Sub 23:00 - 23:30 0.50 BOPSU P DECOMP Test BOPE's. All Components Tested to 250 psi low 1 3,500 psi high. All Tests Charted and Held 5 min Each. Wittness of Test Waived by AGOCC Rep. Chuck Scheeve. Tests Witnessed by WSL Rodney Klepzig and Nabors Tool Pusher Rick Brumley. Test Sequence 1. Lower Pipe Rams Blanking Plug Leaking by. Bled Down All Pressure 23:30 - 00:00 0.50 BOPSU SFAL DECOMP RID Test Manifold, Removed Test Joint and UD Same 6/5/2006 00:00 - 01 :30 1.50 BOPSU SFAL DECOMP P/U 1 Jt. DP and M/U Blanking Plug Running Tool. Retrieved Bad Blanking Plug. Removed Bad Plug and Installed Good Plug on Running Tool. RIH and Set Plug. B/O and Remove DP Joint 1 Running Tool 01 :30 - 02:00 0.50 BOPSU SFAL DECOMP Closed Blind Rams and Tested Blanking Plug to 3,500 psi. Kill Line Connection Leaked. Bled Down All Pressure. 02:00 - 03:00 1.00 BOPSU SFAL DECOMP Replaced Seal Ring in Kill Line Unibolt Connection 03:00 - 03:30 0.50 BOPSU SFAL DECOMP Retest Blanking Plug, Blind Rams and Kill Line to 3,500 psi 03:30 - 04:30 1.00 BOPSU DECOMP Test BOPE's. All Components Tested to 250 psi low 13,500 psi high. All Tests Charted and Held 5 min Each. Wittness of Test Waived by AGOCC Rep. Chuck Scheeve. Tests Witnessed by WSL Rodney Klepzig and Nabors Tool Pusher Rick Brumley. Test Sequence 1. Blind Rams Printed: 7/512006 10:10:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 15-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 6/1/2006 Rig Release: 6/30/2006 Rig Number: 27E Spud Date: 2/12/1982 End: 2. Lower Pipe Rams, Floor Safety Valve SFAL Change Out Flow Line Air Boot in Substructure Corridor Continued to Test BOPE's Test Sequence 3. Upper Pipe Rams, Manual Kill and Choke Valves 4. Kill HCR, Choke Manifold Valves 1 & 2 5. Choke manifold Valves 3,4,5 & 6 6. Choke Manifold Valves 7, 8 & 9 7. Choke Manifold Valves 10, 11 & 12 8. Choke Manifold Valves 13, 14 & 15 9. Choke Manifold Valve 16 10. Annular, Lower Top Drive Well Control Valve 11. Upper Well Control Valve-Failed 10:00 - 11 :00 1.00 BOPSU DECOMP UD Test Joint, M/U Pump in Sub to Top Drive and Retest Upper Well Control Valve-Failed 11 :00 - 15:00 4.00 BOPSU SFAL DECOMP Removed Lower and Upper Well Control Valves 15:00 - 16:30 1.50 BOPSU DECOMP M/U New Upper Well Control Valve and IBOP to Test Sub, Test Valves to 250 psi low 1 3,500 psi high. Test Witnessed by WSL Chris Clemens. 16:30 - 17:00 0.50 BOPSU DECOMP B/O Valves and RID Testing Equipment 17:00 - 19:00 2.00 BOPSU DECOMP P/U Joint DP and M/U Blanking Plug Retrieving Tool, Retrieve Blanking Plug, B/O Plug and Running Tool, UD DP 19:00 - 20:00 1.00 BOPSU DECOMP PJSM, RlU DSM Lubricator Extension and Lubricator. Pull BPV. RID Lubricator 20:00 - 22:00 2.00 BOPSU SFAL DECOMP Installed New Upper Well Control Valve with Pneumatic Actuator, M/U Lower Well Control Valve 22:00 - 23:00 1.00 PULL P DECOMP P/U and M/U Double Spear Assy. with 4.805 Grapples to 1Joint DP. RIH and Spear Tubing Hanger 23:00 - 23:30 0.50 PULL P DECOMP BOLDS, Pull Tubing Hanger to Rig Floor with 180K Up Weight 23:30 - 00:00 0.50 PULL P DECOMP Circulated Surface to Surface at 9 bpm , 700 psi 6/6/2006 00:00 - 00:30 0.50 PULL P DECOMP Circulated at 9 bpm, 700psi 00:30 - 01 :00 0.50 PULL P DECOMP B/O and UD Spear Assy. UD Joint DP 01 :00 - 01 :30 0.50 PULL P DECOMP BIO and UD Tubing Hnager 01 :30 - 03:30 2.00 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing 03:30 - 08:30 5.00 PULL N RREP DECOMP Replaced Pipe Skate Hydraulic Pipe Ejector Cylinder 08:30 - 10:30 2.00 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing 10:30 - 11 :00 0.50 PULL N RREP DECOMP Replace bad hose on link tilt 11 :00 - 11 :30 0.50 PULL P DECOMP POH laying down 5-1/2" 17# L-BO LTC-ABM Tubing 11 :30 - 12:00 0.50 PULL P DECOMP Rig down control line spooler. Recovered 26 clamps and 26 pins and 4 stainless bands. 12:00 - 20:30 8.50 PULL P DECOMP POH laying down 5-1/2" 17# L-80 L TC-ABM Tubing. A total of 229 jts, an 11.67' stub, and a SSSV assy were pulled and layed down. 20:30 - 21 :30 1.00 PULL DECOMP Rig down casing equipment 21 :30 - 22:30 1.00 BOPSU DECOMP Make up test jt to test bope 22:30 - 00:00 1.50 BOPSU DECOMP Test topllower variable pipe rams and hydril around 4" dp. Tested 250 psi low - 3500 psi high for five minutes each and recorded on chart. AOGCC Chuck Scheeve waived to witness test. Witnessed by WSL Charlie Noakes and TP Rick Brumley. Install wear ring, RILDS 6/7/2006 00:00 - 00:30 0.50 BOPSU DECOMP Lay down wear ring puller and test jt. 00:30 - 10:00 9.50 CLEAN DECOMP Make up milling assembly, RIH picking up 4" dp 1 x1. 10:00 - 15:00 5.00 CLEAN RREP DECOMP Replace pipe skate injector. Printed: 7/512006 10:10:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 15-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 6/1/2006 Rig Release: 6/30/2006 Rig Number: 27E Spud Date: 2/12/1982 End: 6/7/2006 15:00 - 16:00 1.00 EVAL P DECOMP Safety stand down on enviromental and safety. 16:00 - 17:00 1.00 CLEAN P DECOMP RIH with milling assembly picking up 4" dp 1x1. 17:00 - 20:00 3.00 CLEAN N RREP DECOMP Clean up glycol spill from brake cooling system overflow. Approximately 40 gallons spilled in containment. 20:00 - 21 :30 1.50 CLEAN P DECOMP RIH with milling assembly picking up 4" dp 1x1. Tagged 5-1/2" stump at 8765', which is ten feet deeper than wireline measurement. 21 :30 - 23:00 1.50 CLEAN P DECOMP Circulate bottoms up at 600 gpm at 2250 psi. At 4000 stks gas was breaking out at surface. The pump was shut down and we observed the well. Gas was breaking out but no flow. Shut the well in and circulated 1100 stks at 5 bpm at 375 psi through the choke. No gas observed or smelled coming out of the gas buster. Once we had bottoms up we turned the pump off and shut the well in. SIDPP =0, SICP=O. Opened up the choke line and opened up the hydril. No flow. Circulated another 500 stks, gas quit bubbling, shut the pump off and observed the well for 5 minutes, no flow. Possible gas migrated from between tubing cut off at 8965' and TOC at 9700'. 23:00 - 00:00 1.00 CLEAN P DECOMP Pump dry job and POH. Water wt=8.4 ppg in/out. 6/8/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP POH with milling assy. 01 :00 - 01 :30 0.50 CLEAN N RREP DECOMP Work on Draw Works 01 :30 - 03:30 2.00 CLEAN P DECOMP POH with milling assy to bha. 03:30 - 05:00 1.50 CLEAN P DECOMP Stand back 20 hwt, jar and 9 dc's. 05:00 - 05:30 0.50 CLEAN P DECOMP Lay down XO, float sub, 1 jt hwt, watermellon mill, bit sub, and starting mill. 05:30 - 08:30 3.00 CLEAN P DECOMP Rig up Schlumberger, run 8-1/2" gauge ring, junk basket and GR/CCL, tagged up on tubing stump at 8965', no significant debris. 08:30 - 11 :30 3.00 DHB P DECOMP Run #2, Set EZSV at 8815', 5' above a casing collar, POH, rig down Schlumberger. 11 :30 - 12:30 1.00 CASE P DECOMP Test 9-5/8" casing against EZSV at 3500 psi for 30 minutes. OK, Monitor well. 12:30 - 13:00 0.50 WHSUR P DECOMP Drain stack, pull wear bushing. 13:00 - 16:30 3.50 BOPSU P DECOMP Nipple down flow line, riser, BOP, pull off tubing spool and 9-5/8" pack off. 16:30 - 17:30 DECOMP Set new 9-5/8" pack off, nipple up Gen II retro tubing spool. 17:30 - 19:00 DECOMP FMC prep spool, test 9-5/8" packoff and bottom flange of tubing spool to 5000 psi for 10 minutes. 19:00 - 22:00 3.00 BOPSU DECOMP Nipple up BOP, riser, and flow line. 22:00 - 23:30 1.50 BOPSU DECOMP Test top flange of Gen II retro spool, HCR choke/kill line valves, and Hydril annular preventer to 250 psi low / 3500 psi high for 5 minutes each. Test witnessed by WSL Chartie Noakes and TP Rick Brumley. Lay down test jt. 23:30 - 00:00 0.50 STWHIP P WEXIT Pick up whipstock and milling assy. 6/9/2006 00:00 - 04:00 4.00 STWHIP P WEXIT Pick up whipstock, starter mill, bit sub watermellon mill, 1 HWT, float sub, XO, MWD, UBHO sub, orient MWD and UBHO sub to whipstock, program MWD. 04:00 - 05:00 1.00 STWHIP P WEXIT RIH with 9 dc's, shallow pulse test MWD, pick up XO, bumper sub, 21 hwt, XO. 05:00 - 06:00 1.00 STWHIP P WEXIT RIH as per RP and Baker fishing hands recommendation with whipstock and milling assy. 90 to 120 seconds per stand. 06:00 - 07:00 1.00 STWHIP P WEXIT Serice top drive, install blower hose, fill pipe. 07:00 - 13:30 6.50 STWHIP P WEXIT RIH as per RP and Baker fishing hands recommendation with Printed: 7/512006 10:10:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 15-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 6/1/2006 Rig Release: 6/30/2006 Rig Number: 27E Spud Date: 2/12/1982 End: 6/9/2006 07:00 - 13:30 6.50 STWHIP P WEXIT whipstock and milling assy. 90 to 120 seconds per stand. Fill pipe every 30 stands. Make Madd Pass from 8554' to 8750' at 100'/hr. 13:30 - 14:00 0.50 STWHIP P WEXIT Orient whipstock 76L of HS at 8694', set at 8815' at 76L of HS. UW=195k, DW=165k, 500 gpm at 2080 psi. TOW=8794', BOW=881 0'. 14:00 - 16:00 2.00 STWHIP P WEXIT Pump 50 bbl duo vise spacer (3 Ibs/bbl), displace well with 10.1 ppg LSND mud at 500 gpm, 2000 psi.. 16:00 - 00:00 8.00 STWHIP P WEXIT Mill window F/8794' - T/8804'. 500 gpm, 2550 psi, UW=200k, DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-8k, 90 rpms rot, 10.1 ppg in/out, yp=40. 6/10/2006 00:00 - 02:00 2.00 STWHIP P WEXIT Mill window F/8804' - T/881 0'. 500 gpm, 2550 psi, UW=200k, DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-8k, 90 rpms rot, 10.1 ppg in/out, yp=40. 02:00 - 04:30 2.50 STWHIP P WEXIT Drill F/8810' - T/8820'. Mill not making any progress. 30k wt on bit, 500 gpm, 2600 psi, UW=2ook, DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-8k, 90 rpms rot, 10.1 ppg in/out, yp=40. 04:30 - 06:00 1.50 STWHIP P WEXIT Pump 23 bbl Super Sweep, 600 gpm at 3400 ppsi, 110 rpm's, 165k rot, 40 yp, 10.1 ppg in/out. 20% increase in cuttings returns. 06:00 - 06:30 0.50 STWHIP P WEXIT Mix and pump dry job. 06:30 - 12:00 5.50 STWHIP P WEXIT POH. stand hwdp back in derrick. 12:00 - 13:30 1.50 STWHIP P WEXIT Lay down steel dc's. 13:30 - 14:00 0.50 STWHIP P WEXIT Download MWD tools. 14:00 - 14:30 0.50 STWHIP P WEXIT Lay down MWD, bumper sub, and milling assy. 14:30 - 15:00 0.50 STWHIP P WEXIT Lay down bha off rig floor. 15:00 - 16:30 1.50 STWHIP P WEXIT Pick up stack washing assy, flush stack, pull wear ring, flush stack, function rams to clear debris, repeat stack flush, service and reinstall wear ring. 16:30 - 18:30 2.00 STWHIP P WEXIT Pick up bit, mud motor, fit sub, stab, mwd, 3 nmfdc's, 6 hwdp, drlg jar, 15 hwt, and xo. 18:30 - 19:00 0.50 STWHIP P WEXIT RIH picking up 4" dp 1 x 1. (9 jts.) 19:00 - 19:30 0.50 STWHIP P WEXIT Shallow pulse test MWD. 19:30 - 22:00 2.50 STWHIP P WEXIT RIH picking up 4" dp 1 x 1. (64 jts.) 22:00 - 22:30 0.50 STWHIP P WEXIT Change out dies on Iron Roughneck, inspect pipe skate. 22:30 - 23:30 1.00 STWHIP P WEXIT RIH picking up 20 jts 4" dp 1 x 1 for a total of 93 jts. 23:30 - 00:00 0.50 STWHIP P WEXIT Cut and slip drilling line. 6/11/2006 00:00 - 02:30 2.50 STWHIP P WEXIT Cut and slip drilling line, service top drive and blocks. 02:30 - 05:30 3.00 STWHIP P WEXIT TIH to 8,735', set depth, fill pipe, orient motor to 80 left of highside, shut off mud pumps, exit window, no problem going through window. UW=185k, DW=155k. 05:30 - 05:45 0.25 DRILL P INT1 Slide from 8,820' to 8,822', pick up 5' to 8,817' to circulate bottoms up for FIT. 500 gpm at 2,550 psi. 05:45 - 06:30 0.75 DRILL P INT1 Circulate bottoms up at 500 gpm, 2,550 psi. 06:30 - 07:00 0.50 DRILL P INT1 Pull up into 9-5/8" casing to 8,766', mw=10.1 ppg in/out, perform FIT to 11.5 ppg. (535 psi.) 07:00 - 00:00 17.00 DRILL P INT1 Directional drill 8-1/2" hole F/8,822' - T/9,700' as per Sun dd's. Drill Kingak as per RP. r rop, 500 gpm at 3,040 psi, -155k, RW=170k, 80 rpm's, tq , tq off 4,500, MW 10.2 ppg in/out. Pumped high vise sw '. Yp 85, 25% increase in cuttings returns. 6/12/2006 00:00 - 05:30 P INT1 Directional drill 8-1 ' - T/10,0000' as per Sperry Printed: 7/512006 to:10:38 AM Re: 15-02 P&A e ! 'f6-<,,-.. I""'; e Subject: Re: 15-02 P&A From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Mon, 22 May 2006 13:45:37 -0800 To: "Cutler, Jeff Nil <Jeff.Cutler@bp.com> Jeff, AOGCC hereby approves changes to your PBU 15-02A (PTD 196-163) abandonment procedure, as described below. All other sundry approval stipulations apply. Winton Aubert AOGCC 793-1231 Cutler, Jeff N wrote: Winton, During the pre-rig work on 15-02 it was determined the perfs were packed off with calcium carbonate and drilling mud. In the Application for Sundry we specified laying cement from the PBTD of 11,844 to 9700', with the top perf being at 10,925. We would like to alter this slightly instead of trying to clean up the well through the perfs and laying in cement across them we would like to wash down above the perfs, set a CIBP, then lay in cement above the BP plug a minimum of 200' or to 9,700' which ever is greater. This change would assure we have clean, uncontaminated, P&A cement. Jeff Cutler BPXA - Alaska Drilling and Wells Operations Drilling Engineer Office: (907) 564-4134 Cell: (907) 529-8092 Fax: (907) 564-4040 SCAN.r.JED· ,,¡UN 1 ;j 1 of 1 5/22/2006 1 :46 PM e e FRANK H. MURKOWSKI, GOVERNOR A1tASKA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 \ó \~ -:9 \~ Re: Prudho~ Bay Field, Prudhoe Bay Oil Pool, PBU 15-02A Sundry Number: 306-147 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~day of April, 2006 Enc!. <J { ~/ö ()lJ /y/ ~1 {) Þ ~r ~ '1/"]..7 J ()" .. STATE OF ALASKA I . ALASKA ~ AND GAS CONSERVATION CO MISSION APPLICATION FOR SUNDRY APPROVAL / 20 MC 25.280 .QVê? 1. Type of Request: 181 Abandon o Alter Casing o Change Approved Program ~úA- +/2,1/ 'U)Ð<ø IVED R 2 5 ZOû6 " o Suspend 0 Operation Shutdown 0 Perforate 0 Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension ADL 028306 ,',' , ,,', Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): 12390 8976 I 11844 Casing Length Size MD Structural Conductor Surface Intermediate Production Liner 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name J~ve Wesley " Title Senior Drilling Engineer /'i /. Prepared By Name/Number: Signature Ætt1t' ¿~:") Ø--, Phone 564-5153 Date ¡/!zI/U.¿l4> Terrie Hubble. 564-4628 / /' Commission Use Only 2. Operator Name: BP Exploration (Alaska) Inc. J. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 63' 8. Property Designation: 79' 2675' 10034' 20" 13-3/8" 9-5/8" Liner 951' 2276' 2-7/8" 7" Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 10925' - 11841' / 8953' - 8994' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker '3-H' packer 12. Attachments: 181 Description Summary of Proposal 0 BOP ):?ketch o Detailed Operations Program / ' 14. Estimated Date for Commencing Operations: May( 1 , ?Ó06 Date: 4. Current Well Cla~ 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 196-163 r' 6. API Number: 50-029-20697-01-00 / 9. Well Name and Number: PBU 15-02A /' 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool , '," . " : Effective Depth TVD (ft) Plugs (measured): Junk (measured): / 8994 None None / TVD Burst Collapse 79' 2675' 10034' 79' 1490 470 2675' 4930 2670 8316' 6870 4760 8079' - 8316' 8160 7020 8053' - 8994' 10570 11160 9726' - 10034' 9692' - 11905' Tubing Size: .,/ 4-1/2", 12.6# x 5-1/2", Tubing Grade: I Tubing MD (ft): N-80 / L-80 9792' / Packers and SSSV MD (ft): 9710' / 13. Well Class after proposed work: o Exploratory 181 Development 0 Service 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged /181 Abandoned o WINJ 0 WDSPL Contact Jeff Cutler, 564-4134 I Sundry Number: 3Ct£J - 147 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance T-est ßO f> e to 3Soo t/) r.. e' . Other: " A-tJ y? ~ 0 úe.d. {&r kA- L C? - 4-0 l ye¡ Subsequent Form Required: to - rr ;~ Approved By: U Form 10-403 Revised 07/2005 V ' ORIGINJW RBDMS 8Fl APR 2 8 2006 ~ to-r~' Je ~~ ¡µ.£{/ IS-07...ß. COMMISSIONER APPROVED BY THE COMMISSION Date 4-zi,ð6 "- Submit In Duplicate e e . Obp To: Winton Aubert - AOGCC Date: April 13, 2006 From: Jeff Cutler - BPXA GPB Rotary Drilling Subject Reference: 15-02A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20697-01 Approval is requested for the proposed P&A of PBU well 15-02A. Well 15-02 was sidetracked by coil in November 1996 as a Zone 1 A horizontal. An attempt was made to toe the well up into Zone 1 B at the end but was unsuccessful due to the 13N shale. Over 500' of shales were drilled in the toe with no sand. Overall sand quality was poor over the 1300' horizontal interval with less than 300' of quality pay in Zone 1 A. There was no HOT although references to heavy oil and thick crude suggest it may be close. Attempts were made to improve productivity with a gas lift program, a frac and adding perfs. The well has been shut in since 12/03 due to annular communication problems. A sidetrack to re-complete the well as an Ivishak Zone 1 A producer is seen as the best way to maximize the value of the wellbore. The sidetrack is currently scheduled for Nabors rig 27E, beginning around June 7s1 2006. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: ./ L TSI since 12/03 due to Ann Comm ./ POGLM's @ 8987' MO and 3203' MO ./ 11/23/03: Pulled OGL V #2 - pocket left open ./ 5-1/2" OTIS SSSV nipple @ 2116'MO ./ Minimum 10 = 2.34" in POGLM #1 @ 3203" MD. ./ 13-5/8': 5K FMC Gen /I wellhead. Scope * Notify the field AOGCC representative with intent to plug and abandon * Pre-Riq Operations: 1. Replace all live Gas Lift valves with Dummy valves and fluid pack as necessary for CT P&A. 2. R/U SL and drift tbg, tag up on upper POGLM @ 3203' MD 3. RIH braided line and retrieve upper POGLM. 4. RU e-line and run gyro surveys dOelO/Ner POGLM@8987'. 5. R~ CT, RIH to 11,844" MD. Lay i '12.5 þbls of cement, leaving TOC at -9700' MD. POH and RD CT ..- Unit. .~ 6. RU SL and drift the 5W' tubing, tag up on lower POGLM @ 8987' MD. This will confirm the tubing is clear to the required cut depth of 8,950' MD. 7. RIH with the appropriate jet cutter and cut the 5W' tubing at -8,950' MD. 8. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 9. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Level the pad as necessary. 15-02A Application for Sundry e e Riq Operations: 1. MI I RU Nabors rig 27E. Pull BPV 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC / 4. R/U. Pull 5%" tubing from the cut at -8,950' MD and above. 5. R/U E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH and tag tubing stump. POOH. L:. RIH with HES EZSV on E-line. Set bridge plug at -8,874', as required to avoid cutting a casing collar while milling the window. POOH. RID E-line. 7. Pressure-test the 9-5/8" casing to 3,500psi for 30 minutes. Record test. T~s £0 _ ~.ß. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as 3 desired, and set on bridge plug. Shear off of whip stock. ~'}r KJ'(/ ~ C 9. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9-5/8" casing at ± 8,850' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POH. 12. M/U 8W' Dir/GR assembly. RIH, kick off and drill the 8%" intermediate section. 13. Continue drilling ahead in the 8%" hole section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POH. 14. Run and cement a 7",26.0#, L-80 intermediate drilling liner. Test to 3,500 psi. 15. M/U 6-Ya" Dir/GR/Res assembly. RIH to the 7" liner landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct a FIT to 10.0ppg EMW. Drill ahead through Zone 3, completing build section. POH 19. M/U 6- Ya" PDC drilling assembly with Dir/GR/Res/Denl Neu. RIH. 20. MAD pass down from PGOC sending Den/Neu logs to surface real time. 21. Drill ahead to TD in the production interval recording Den/Neu data. 22. Circulate well bore clean, short trip to shoe, circulate. POOH. 23. Run and cement 4%",12.6#, L-80, IBT-M solid production liner. POH. 24. RU SLB. RIH with DPC perf guns. Depth correlate and perforate -1,000' with 2-1/2" PowerJets at 6 spf. 25. R/U and run a 4%", 12.6#, L-80, TC-II tubing completion, stinging into the 4112" liner tie back sleeve. 26. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 27. Set a BPV. 28. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 29. Freeze protect the well to -2,200' TVD. Secure the well. 30. Rig down and move off. Post-Ria Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Well Coordinates: Surface Location: Target Location: Intermediate Target Bottom Hole Location: x = 676,223.0 I Y = 5,960,046.7 X = 672,222.0 I Y = 5,958,094.0 X=672,713.4 IY=5,957,466.1 X = 671,551.6 I Y = 5,959,212.2 Z = 8,920.0' TVDss Z = 8,270.0' TVDss Z = 8,880.0' TVDss Timinq: Estimated Pre-rig operations start date: Estimated Rig operations I spud date: Jeff Cutler 05/01/06 06/07/06 15-02A Application for Sundry e Operations Drilling Engineer 564-4134 e 15-02A Application for Sundry TREE = WELLHEAD ~ ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = FMC GEN 2 FMC AXELSON 63' ? 3100' 94 @ 12351' 10753' 8800' SS e 15-02A SAÆTY NOTES: POGLM'S @ 3203' & 8987', ID = 2.34" - 70° @ 10970' AND 90° @ 11120' 2116' -f 5-1/2" OTIS RQM SSSV NIP. ID = 4.562" I . Minimum ID = 2.34" @ 3203' 5-1/2"AVA POGLM GAS LIFT MANDRELS 1VD DEV TYÆ VLV LATCH PORT DATE 3200 12 DWP BK '2 8987 7492 37 DWP BK , POGLMS; ID - 2.34" TOP OF 2-7/8" LNR- CT I 3-1/2" X 2-7/8" XO 1 5-112" BOT PBRASSY (BÐiIND CT LNR) 13-3/8" CSG. 72#. L-80. ID = 12.347" I 2675' 15-1/2" TBG-PC. 17#. L-80. .0232 bpf. ID = 4.892" 1 1 TOP OF 4-1/2" LNR 1 1 TOP OF 7" LNR I 9629' 4-1/2" SCOOP GUIDEG SEAL ASSY 9632' 9632' 9690' 9710' 9721' -i 9-5/8" X 5-1/2" BOT 3-H A<R (BÐiIND CT LNR) -i 5-1/2" X 4-1/2" XO (BÐiIND CT LNR) I 14-1/2" TBG-PC. 12.6#, N-80. .0152 bpf. ID = 3.958" I 9792' - 4-1/2" OTIS XN NIP (BÐiIND CT LNR). ID = 3.725" - 4-1/2" BOT SHEA ROUT SUB (BÐiIND CT LNR) I -i 4-1/2" TUBING TAIL (BÐiIND CT LNR) I I ELMO TT LOGGED 04/11/90 (BÐiIND CT LNR) DATE 03/06/82 11/08/96 02106/02 09/11/03 9-5/8" CSG, 47#. L-80. ID = 8.681" PERFORA TION SUMMARY REF LOG: SWS RST ON 06/10/98 ANGLE AT TOP PERF: 67 @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 6 10925 - 10940 0 04/28/01 2" 6 10955 - 10995 0 03/13/00 2" 6 11010 - 11070 0 03/13/00 2-1/8" 4 11251 - 11525 0 11/07/96 2-1/8" 4 11550 -11841 0 11/07/96 7" SIDETRACK WINDOW 10677' - 10683' 7" LNR. 29#. L-80. .0371 bpf. ID = 6.184" 1 10677' I PBTO I 2-7/8" LNR - CT. 6.5#, L-80. .00579 bpf. 10 = 2.441" I I TO 1 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK RNlTP CORRECTIONS CMO/TLP PERF ANGLE CORRECTION DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-02A PERMIT No: 1961630 API No: 50-029-20697-01 SEe 22. T11 N, R14E. 4301.98' FEL & 2698.93' FNL BP Exploration (Alaska) TREE¡: WELLHEAD ~ ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = DATE 03/06/82 11/08/96 02106/02 09/11/03 10/24/05 FMC GEN 2 FMC AXELSON . 63' ? 3100' 94 @ 12351' 10753' 8800' SS e 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2675' Minimum ID = 3.725" @ 9,810' 4-1/2" "XN" Nipple 9-5/8" Halliburton EZSV set @ H 8874' I 5-1/2" tbg chem cut @ 1-1 8950' I 5-1/2" POGLM (2.34" ID) H 8987' PERFORA TION SUMMARY REF LOG: SWS RST ON 06/10/98 ANGLEATTOPPERF: 67 @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 10677' 15-028 SAÆTY NOTES: POGLM'S @ 3203' & 8987', ID=2.34" -70o@ 10970' AND90o@ 11120' Proposed Completion GAS LIFT MANDRELS ST MD TVD DEV TY VLV LATCH PORT DATE 4 3 2 1 8700' 1-1 7" X 9-5/8" Baker S-3 Packer 9750' 9770' 9790' 9810' 1-17" x 41/2" Baker S3 Packer H4 1/2" X Nipple (3.813" ID) H4 1/2" X Nipple (3.813" ID) 1-141/2" XN Nipple (3.725" ID) H41/2" WLEG -141/2" Hanger /Iiner top packer 1-1 7",26#, L-80, IBT-M Liner 9700' 1-1 Top of P&A Cement I ./ 10034' H 9-5/8" CSG, 47#, L-80, ID = 8.681" ,/ I PBTO H 2-7/8" LNR- CT, 6.5#, L-80, .00579 bpf, 10 = 2.441" H 11905' TO H 12390' REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK RNITP CORRECTIONS CMOfTLP PERF ANGLE CORRECTION JNC Proposed Completion DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-02B PERMT No: 1961630 API No: 50-029-20697-02 SEC 22, T11 N, R14E, 4301.98' FEL & 2698.93' FNL BP Exploration (Alaska) ., PRUDHOE BAY PRUDHOE OIL PBU_DS15 R HOE BAY 100 1S-02A _ Oil Rate (CD) (M bbl/d ) - Water Rate (CD) (M bbl/d Gas Rate D)(MMcf/d) Cum Oil rod (MMbbl) _ Gas / Oil Ratio (M cr/bbl ) Water Cut % 50 10 o 5 o 1 0.05 0,01 1996 97 gO 2000 01 02 Date 03 05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1437' FNL, 4993' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 3913' FNL, 3569' FEL, Sec.21, T11N, R14E, UM At effective depth At total depth 2699' FNL, 4302' FEL, Sec. 21, T11N, R14E, UM 5. Type of Well: Development __X Exploratow__ Stratigraph lc__ Service__ (asp's 676222, 5960049) (asp's 672433, 5957488) (asp's 671668, 5958681) 6. Datum elevation (DF or KB feet) RKB 63 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-02A 9. Permit number / approval number 196-163 10. APl number 50-029-20697-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Surface 2612' Production 9971' Liner 951' Liner 2273' 12390 feet 8976 feet 11844 feet 8994 feet Size Cemented 20" 19o2 sx Poleset 13-3/8" 3000 Sx Fondu & 400 Sx PF 9-5/8" 500 Sx Class G 7" 350 Sx Class G 2-7/8" 30 bbls of Class G Plugs (measured) Junk (measured) Measured Depth 79' 2675' 10034' 10677' 11905' True VerticalDepth 79' 2675' 8316' 8808' 8994' Perforation depth: measured 10925'-10940'; 10955'-10995'; 11010'-11070'; 11251'-11525'; 11550'-11841'. true vertical 8953' - 8959'; 8965' - 8978'; 8983' - 8992'; 8996' - 8995'; 8995' - 8994'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2", 17#, L-8O PCT @ 9721' MD; 4-1/2", 12.6#, N-80 PCT @ 9792' MD. 9-5/8" X 5-1/2" BOT 3-H PACKER (BEHIND CT LINER) @ 9710' MD. 5-1/2" OTIS RQM SSSV @ 2116' MD. RECEIVED MAY 0 9 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl 643 1614 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 15100 0 18680 0 Casing Pressure Tubing Pressure - 418 418 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. Signed ~ Title: DS 15 Surveillance Engineer Preston Evans Date May 7, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 15-02A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/26/2001- 4/28/2001' RIH w/2" dummy gun & drifted to 10916' SLM (HAW). Was able to get to 11000' SLM without roller stem. MIRU wireline unit & PT'd equip to 3000 psi. RIH w/CCL/GR/SAFE/2" PJ guns. Toolstring ran w/rollers above & below guns. Did tie-in. Shot 15' of Add Perforations from: 10925' - 10940' MD (Zone 2A) Reference Log: BHCS 4/4/1982. Used 2" carriers & all shots @ 6 SPF, random orientation, & 60° phasing. POOH w/guns. ASF. RD wireline unit. Placed 15-02A on production & obtained a valid welltest. Page 1 otq op' B FOP, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1437' FNL, 4993' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 3913' FNL, 3569' FEL, Sec.21, T11N, R14E, UM At effective depth At total depth 2699' FNL, 4302' FEL, Sec. 21, T11N, R14E, UM 5. Type of Well: Development __X Exploratow~ Stratigraph Service__ (asp's 676222, 5960049) (asp's 672433, 5957488) (asp's 671668, 5958681) 6. Datum elevation (DF or KB feet) RKB 63 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-02A 9. Permit number / approval number 196-163 10. APl number 50-029-20697-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Surface 2612' Production 9971' Liner 951' Liner 2273' 12390 feet 8976 feet 11844 feet 8994 feet Size Cemented 20" 19o2 Sx Poleset 13-3/8" 3000 Sx Fondu & 400 Sx PF 9-5/8" 500 Sx Class G 7" 350 Sx Class G 2-7/8" 30 bbls of Class G Plugs (measured) Junk (measured) Measured Depth 79' 2675' 10034' 10677' 11905' True vertical Depth 79' 2675' 8316' 8808' 8994' Perforation depth: measured 10955'-10995'; 11010'-11070'; 11251'-11525'; 11550'-11841'. true vertical 8965' - 8978'; 8983' - 8992'; 8996' - 8995'; 8995' - 8994'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 9721' MD; 4-1/2", 12.6#, N-80 PCT @ 9792' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BOT 3-H PACKER (BEHIND CT LINER) @ 9710' MD. 5-1/2" OTIS RQM SSSV @ 2116' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 1029 Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl 16271 0 488 11588 0 Casing Pressure Tubing Pressure 419 925 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. Signed "' ~/(.4,~ ~ ~ Title ARCO Engineering S upervisor Erin Oba ' Prepared by Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 15-02A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 3/12/2000 - 3/13/2000: MIRU CTU. PT'd equip. Opened up well & RIH w/Memory GR/CCL logging tools. Logged f/10750' - 11100' MD. POOH w/logging tools. RIH w/CT conveyed perforating guns & shot 100' of Add Perforations located @: 10955' - 10995' MD (Zone 1) Reference Log: BHCS 4/4/1982. 11010' - 11070' MD (Zone 1) Well was flowing throughout perf job. Used 2" carriers & all shots @ 6 SPF, random orientation, 60" phasing, & underbalanced pressure. POOH w/guns. ASF. RD. Placed 15-02A on production & obtained a valid welltest. Page 1 PERMIT DATA ............ 96-163 MWD SRVY 96-163 MWD SRVY 96-163 MWD SRVY 96-163 MWD SRVY 96-163 NGP-MD 96-163 NGP-TVD 96-163 NGP-TVD 96-163 NGP-MD 96-163 7933 96-163 7934 96-163 MWD SRVY AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 11/05/98 T DATA PLUS RUN RECVD zR-~10600-123 ~-1o6oo-111 ~PERRY 1 ~%'JSPERRY 1 ~0677-123 ~f8744-8913 ~% 1067~011166 · ~3,6,9-11 SPERRY GR ,/ 0600-~1167 PB1~ 90 F IN~LL FINAL FINAL FINAL ,~S PERRY GR PB1 >R/.i0600_11167 v~ !/ ':' 3,6,7 02/12/97 02/12/97 03/05/97 03/05/97 03/12/97 03/12/97 03/12/97 03/12/97 03/26/97 03/26/97 02/26/97 10-407 ~R~'COMPLETION DATE /// DAILY WELL OPS R Are dry ditch samples required? yes ~~d received? Was the well cored? yes ~Analysis & description received? Are well tests required? ~yes ~lReceived? Well is in compliance In~l~i~l COMMENTS .... STATE OF ALASKA -- A .... KA OIL AND GAS CONSERVATION COMMISSIL REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Bevelopment_X 63' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1441' FNL, 285' FWL, Sec 22, T11 N, R14E, UM. 15-02A At top of productive interval: 9. Permit number/approval number: 1370' FSL, 1712' FWL, Sec 21, T11N, R14E, UM. 96-163 At effective depth: 1~. APl number: 50-029-20697-01 At total depth: 11. Field/Pool: 2701' FNL, 4301' FEL, Sec 21, T11N, R14E, UM. Prudhoe Bay Oil Pool t 2. Present well condition summary Total Depth: measured 12390 feet Plugs (measured) PBTD Tagged @ 8977' MD (6/23/96). true vertical 8976 feet Effective Depth: measured 11844 feet Junk (measured) true vertical 8994 feet Casing Length Size Cemented Measured depth True verllcal depth Conductor 79' 20" 1902 Sx Poleset 79' 79' Surface 2612' 13-3/8" 3000 Sx Fondu & 2675' 2675' 400 Sx Permafrost Production 9971' 9-5/8" 500 Sx Class G 10034' 8316' Liner 951' 7" 350 Sx Class G 10677' 8808' Liner 2276' 2-7/8" 30 Bbls Class G 11905' 8994' Perforation Depth measured 11251-11525';11550-11841'::f~ ~* ~¢, ~! ~ ~J¢?~-i~ ~ ~'~ ~ true vertical 8996 - 8995'; 8995 - 8994' APR $ 1997 Tubing (size, grade, and measured depth) 5-1/2", 17¢, L-80, Tbg @ 9721' MD; 4-1/2", 12.6#, N-80, Tbg @ 9792' MD. ~'a-8~_~.0il .& , 'Ar]ch0rage Packers and SSSV (type and measured depth) 9-5/8 x 5-1/2" DOT 3-H Packer @ 9710' MD; 5-1/2" Otis RQM SSSV @ 2116' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured)ORIGINAL 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 Subsequent to operation 159 3394 5 311 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil_X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ "~/3 · ~ Title: Engineering Supervisor Date z/Z. _ ~ _ ~ '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 15-02A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE I 3/17/97: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the perforations located at: 11251 - 11525' MD (Z1) 11550- 11841' MD (Zl) Pumped: a) 301 bbls 20# Pre Pad Gel @ 25 bpm, followed by b) Shutdown. ISIP @ 1320. Resumed pumping Data Frac: c) 52 bbls 30# Crosslinked Gel @ 5 - 25 bpm, followed by d) 230 bbls 20# Non-Crosslinked Gels @ 5 - 25 bpm, followed by e) Shutdown. ISIP @ 1487. Resumed pumping the Fracture Treatment: f) 26 bbls 30# Crosslinked Gelled Pad @ 25 bpm, followed by g) 118 bbls Slurry w/proppant concentrat ions @ 1 - 8 ppg, followed by h) 230 bbls 20# Non-Crosslinked Flush @ 5 - 25 bpm, followed by i) Shutdown. Placed a total of 17,997 lbs of proppant into the formation. Rigged down. 3/20/97: RIH w/CT & jetted a proppant fill cleanout down to 11652' MD. Returned well to production & obtained a valid welltest. ;/-",. ? -;-;) ::; '~ '; !997 SE~4T BY :ARCO ALASKA INC ;~-q-26-97 · 9' 08A~ 'PRB RESOURCE DEVELOP--, 907 276 7-542 _ ., "') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2 N~eoi ~ ...... ARCO ~. Ino 3A~ ..... 8 APIN~'r ..... P.O. ~,,~, An~,AK 9~51~ ,., 1~1' ~ 2~ ~. ~ ~ TI 1N. R14E UM 137~ ~ 171~' ~ ~I. T11N, RI4E UM ~1' ~.~ ~t" ~ S~ 21. TIIN. R14E UM ..... PRU~E ~Y FI~ 5 ~ ~ ~ K~M KB. DF. g~l I 6 Le~ D~tmn ~d ~ ~. PRUD~E BAY OIL P~L 1~. ,,1 ~1~6~_,, 11/~ ...... 17 TO~ (M~) 18 ~D~ (M~) _ .......... ,..... , , ~ Ty~ EI~ ~ Omer L~ R~ 23 CASlN~ L~ER ~O ~~G RE.RD .. C~G S~ ... ~, P~ ~. G~DE TOP . .................. ~ 91.6 ~ H~ 1~ ~ ~ ~ S~ 267~ 17-1~" ~ Sx Fo~ &,~ Sx Per~t · ~" 47.0 ~ L~S ~_~ 1~' ~ '" =~ ~ ~.~ '~ ~ J ,,.~ ~s. ~. a .......... '" ~ ' . 2-7/8' 6.S ~ ..... L-~ ~'. . 119~ , ~4~... 24 P~~ o~ ~ ~ ~ ~ T~ ln~ ~ ~o n~ ~ ~ S~ ~) ....... PACK~ S~ ~D) 112Sl- ~ ~5' MD: ~- ~ ~ at 4~t. ~1~'.~ D~ ~ (MO~ ,,~U~ & KINO OF UAT~ U8~ ~A ._. ... .., ,., , , , ,. ~. · ... I -' L. i~DF WA~L OIL ~TY~Pl (c~) ~ ..... 2B ~ ~ATA __ . , . .H- ~ *, .... """'- '" 29. 30. GEOLOGIC MARt<ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9029' 8440' N/A 31. LIST OF A'I-I'ACHMENTS Summary of 15-02A Coil Tubing Sidetrack Drilling operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~¢'~ % ' ~ Engineering Supervisor Date ~ '" ~' 42- ~_? INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ,~,~-'~'..~'~,.~..:.~,¥~.~. ~, ~ ~' .... :' ~..~/. ~.~ ~,:~.~ ...... ~' "~i Form 10-407 ORIGINAL 15-02A DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS I 0/5/96. Milled a pilot hole through the cement plug from 10648' to 10677' MD. POOH w/w BHA. 1 0/6 MU & drilled /96 · RIH w/window milling BHA. Milled window through the 7" liner from 10677 to 10683', then formation to 10686' MD. Backreamed window. 1 0/7/96' POOH w/BHA. Circulated well over to FIo-Pro. section to 10740' MD. RIH w/drilling BHA & drilled 3.75" sidetrack build 10/8/96- Continued drilling build section to 11146' MD. to 11167' MD. POOH w/BHA. POOH w/BHA. RIH w/drilling BHA & resumed drilling I 0/9/96- RIH w/drilling BHA to 11100' MD, then attempted to work by sticky shales to bottom. POOH w/BHA. RIH w/nozzle & tagged bottom at 11162' MD. CBU then pumped 5 bbls of 17 ppg Class G cement to plugback to 10910 ' MD. Circulated biozan over plug & POOH circulating FIo-Pro. I 0/1 0/96' WOC. RDMO CTU. Rig on standby for repairs. 1 0/11/96 - 1 0/1 4/96' Rig on standby for repairs. Circulated Hot Seawater through tubing holes to maintain warm wellbore. I 0/1 5/96- MIRU CTU & PT equipment. RIH w/drilling BHA & tagged TOC at 10927' MD. I 0/1 6~96' Drilled off cement plug to complete build section to 11250', then drilled horizontal hole to 11510' MD. I 0/1 7/96' Drilled horizontally through shales to 12185' MD. Backreamed hole. I 0/1 8/96' POOH w/BHA. Circulated well to new FIo-Pro. RIH w/drilling BHA & resumed drilling horizontal hole to TD at 12390' MD. Backreamed by sticky shale section at 12140' MD & POOH w/BHA. I 0/1 9/96' MU & RIH w/2-7/8" liner assembly. POOH for fishing tools. Landed & stuck liner at 10748' MD. Attempted to free liner. I 0/20/96' RIH w/fishing BHA & tagged TOL at 8150' MD. Attempted to latch liner. Circulated lube pill by liner. POOH w/BHA. RIH w/chemical cutter & cut liner at 10626' MD. POOH w/cutter. I O/2 I/96 · RIH w/spear & latched liner at 8153' MD. POOH w/liner from above 10626' MD. latched TOF. Jarred on fish. POOH w/no fish. RIH w/overshot & I 0/22/96- RIH w/overshot & tagged TOF at 10609' MD. POOH. RIH w/chemical cutter & cut liner at 10710' MD. RIH w/overshot & latched TOF. POOH w/liner fish from above 10710' MD. 15-02A DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS I 0/23/96: RIH w/washpipe & tagged TOF at 10710' MD. Attempted to wash over fish. minus 60' of pipe left in hole. RIH w/spear & attempted to fish washpipe. I 0/24/96: RIH w/spear & tagged TOF at 10706' MD. POOH w/no fish. mill fish at 10710' MD. POOH for bit swap. I 0/25/96: RDMO CTU for power pack repairs. RU pipe shed & prep for fishing operations. I 0/26/96: RU & stocked pipe shed w/liner joints. I 0/27/96: RU tongs to power pack. RIH w/DP/spear & latched TOF at 10708' MD. Jarred on fish. POOH w/fish. I 0/28/96: LD 11' piece of liner fish. RIH w/spear for WP fish. Latched fish & POOH w/top 30' of parted WP fish. I 0/29/96: RIH w/overshot. Latched TOF at 10715' MD. POOH w/1 joint of liner fish from above float collar. RIH w/spear & latched TOF at 10735' MD. Jarred on fish. I 0/30/96: POOH w/last of washpipe fish. RIH w/overshot & latched TOF at 10748' MD. POOH w/float collar fish. 10/31/96: RIH wRVP & washed over liner fish. POOH w/fish minus shoe joint. RIH w/overshot & latched TOF. I 1/1/96: POOH w/last of 2-7/8" liner & float shoe fish. Unload DP from shed then RD pipe shed. 11/2/96 - 11/3/96: RDMO pipe shed. Standby for CTU. MIRU CTU & PT equipment. I I/4/96: RIH w/hole opener BHA. Reamed open hole to 11928' MD. Swept hole clean twice. POOH w/BHA. I 1/5/96: MU & RIH w/2-7/8" liner. Worked liner to 11905' MD; could not work deeper. Pumped 30 bbls of CIG cement to set the liner at 9629 - 11905' MD. Bumped plug, unstung TOL, & POOH. Drifted liner to tag PBTD at 11671' MD. POOH. I I/6/96: RIH w/milling BHA & milled liner cement to 11770' MD then RIH to tag landing collar at 11844' MD. POOH to TOL & PT liner to 2000 psi. POOH w/BHA. I I/7/96: RIH w/perforating guns & shot initial perforation intervals at: 11251 11525' MD (Z1) 11550 - 11841' MD (Z1) Used 2-1/8" carriers & shot all perforations at 4 spf. POOH w/perf guns. POOH w/parted washpipe POOH; no fish. MU & RIH w/milling BHA. Attempted to 15-02A DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS I I/8/96 · RDMO CTU. I 1/1 O/96' RIH w/5-1/2" AVA DWP POGLM across tubing circulation holes at 3200 - 3214' MD (seal to seal). POOH & RD. Attempted to establish sustainable production w/gaslift. I 2128196' RIH & retrieved the AVA DWP POGLM (listed above). I/1 4/97' RIH w/tubing puncher & punched 5 circulation holes in the tubing between 8998 - 9000' MD. 1/17/97' Ran & set two 5-1/2" AVA DWP POGLM's across the circulation holes at 3207 - 3217' MD (seal to seal), and at 8991 - 9006' MD (seal to seal). Attempted to establish sustainable production from the well w/gaslift. A Hydraulic Fracture Treatment is pending in the near future. The well does not sustain flow. SPE~.o_f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC PBU / 15-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 MWD SURVEY JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10600.00 8748.30 8685.30 38 42 S 59.60 W .00 2595.40S 4071.40W 10681.22 8811.46 8748.46 39 12 S 59.50 W .62 2621.28S 4115.42W 10719.07 8839.91 8776.91 43 30 S 71.00 W 23.03 2631.61S 4138.08W 10760.07 8868.02 8805.02 50 5 S 83.70 W 27.68 2637.95S 4167.15W 10775.02 8877.48 8814.48 51 25 S 85.81 W 14.05 2639.00S 4178.68W -1839.63 -1857.37 -1863.56 -1864.70 -1863.71 10790.72 8887.10 8824.10 53 1 S 88.58 W 17.27 2639.61S 4191.07W 10806.34 8896.30 8833.30 54 50 N 84.70 W 36.66 2639.17S 4203.68W 10819.27 8903.60 8840.60 56 30 N 80.83 W 27.89 2637.82S 4214.27W 10837.14 8913.18 8850.18 58 37 N 76.26 W 24.60 2634.82S 4229.04W 10852.97 8921.22 8858.22 60 22 N 70.99 W 30.76 2630.98S 4242.12W -1862.12 -1859.48 -1856.29 -1850.74 -1844.66 10863.14 8926.19 8863.19 61 4 N 70.11 W 10.22 2628.02S 4250.48W 10882.07 8935.07 8872.07 63 1 N 64.31 W 28.94 2621.54S 4265.88W 10895.92 8941.21 8878.21 64 20 N 61.67 W 19.56 2615.90S 4276.94W 10909.69 8947.05 8884.05 65 28 N 58.16 W 24.52 2609.65S 4287.73W 10923.04 8952.46 8889.46 66 48 N 55.34 W 21.70 2602.96S 4297.94W -1840.28 -1831.20 -1823.70 -1815.65 -1807.27 10942.89 8960.01 8897.01 68 28 N 51.30 W 20.62 2591.99S 4312.65W 10955.27 8964.42 8901.42 69 46 N 47.96 W 27.34 2584.50S 4321.46W 10968.52 8968.83 8905.83 71 22 N 44.97 W 24.43 2575.89S 4330.52W 10986.64 8974.32 8911.32 73 23 N 39.88 W 29.00 2563.15S 4342.16W 11000.24 8978.06 8915.06 74 42 N 37.24 W 21.04 2552.92S 4350.31W -1793.89 -1784.96 -1774.90 -1760.31 -1748.81 11013.09 8981.30 8918.30 76 1 N 34.25 W 24.71 2542.83S 4357.57W 11031.39 8985.52 8922.52 77 20 N 30.38 W 21.81 2527.79S 4367.09W 11046.84 8988.71 8925.71 78 50 N 26.69 W 25.30 2514.51S 4374.31W 11061.62 8991.42 8928.42 80 4 N 23.18 W 24.79 2501.33S 4380.43W 11076.34 8993.83 8930.83 81 2 N 19.66 W 24.49 2487.82S 4385.73W -1737.60 -1721.12 -1706.77 -1692.73 -1678.49 11087.79 8995.54 8932.54 81 49 N 17.20 W 22.34 2477.08S 4389.31W 11114.59 8998.80 8935.80 84 11 N 11.57 W 22.65 2451.32S 4395.91W 11127.07 8999.83 8936.83 86 18 N 9.46 W 23.87 2439.10S 4398.18W 11147.07 9000.38 8937.38 90 31 N 4.54 W 32.40 2419.26S 4400.61W 11167.00 9000.20 8937.20 90 31 N 4.54 W .00 2399.40S 4402.19W -1667.29 -1640.78 -1628.34 -1608.39 -1588.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5013.62 FEET AT SOUTH 61 DEG. 24 MIN. WEST AT MD = 11167 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 349.88 DEG. TIE-IN SURVEY AT 10,600.00' MD WINDOW POINT AT 10,681.20' MD PROJECTED SURVEY AT 11,167.00' MD RECEIVED MAR 0 5 1991 ,~iaska 0~i & Gas (.;OHS. SPE. .f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC PBU / 15-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10600.00 8748.30 8685.30 2595.40 S 4071.40 W 1851.70 11167.00 9000.20 8937.20 2399.40 S 4402.19 W 2166.80 315.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPA _f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU / 15-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10600.00 8748.30 8685.30 2595.40 S 4071.40 W 1851.70 10618.84 8763.00 8700.00 2601.36 S 4081.56 W 1855.84 4.14 10752.50 8863.00 8800.00 2637.05 S 4161.57 W 1889.50 33.67 10951.44 8963.00 8900.00 2586.70 S 4318.66 W 1988.44 98.93 11167.00 9000.20 8937.20 2399.40 S 4402.19 W 2166.80 178.36 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SP,-..¢RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~RCO ALASKA INC P~u / 15-02A 5OO2920697O1 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7~97 DATE OF SURVEY: 101996 MWD SURVEY JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANG~ COORDINATES DEGREES DG/100 NORlq-~I/SOUTH EAST/WEST VERT. SECT. 10600.00 8748.30 8685.30 10681.22 8811.46 8748.46 10719.07 8839.91 8776.91 10760.07 8868.02 8805.02 10775.02 8877.48 8814.48 38 42 39 12 43 30 5O 5 51 25 S 59.60 W .00 S 59.50 W .62 S 71.00 W 23.03 S 83.70 W 27.68 S 85.81 W 14.05 2595.40S 4071.40W 2621.28S 4115.42W 2631.61S 4138.08W 2637.95S 4167.15W 2639.00S 4178.68W -1839 -1857 -1863 -1864 -1863 .63 .37 .56 .70 .71 10790.72 8887.10 8824.10 10806.34 8896.30 8833.30 10819.27 8903.60 8840.60 10837.14 8913.18 8850.18 10852.97 8921.22 8858.22 53 1 54 50 56 30 58 37 60 22 S 88.58 W 17.27 N 84.70 W 36.66 N 80.83 W 27.89 N 76.26 W 24.60 N 70.99 W 30.76 2639.61S 4191.07W 2639.17S 4203.68W 2637.82S 4214.27W 2634.82S 4229.04W 2630.98S 4242.12W -1862 -1859 -1856 -1850 -1844 .12 .48 .29 .74 .66 10863.14 8926.19 8863.19 10882.07 8935.07 8872.07 10895.92 8941.21 8878.21 10909.69 8947.05 8884.05 10916.54 8949.86 8886.86 61 4 63 1 64 20 65 28 66 5 N 70.11 W 10.22 N 64.31 W 28.94 N 61.67 W 19.56 N 58.16 W 24.52 N 56.75 W 20.78 2628.02S 4250.48W 2621.54S 4265.88W 2615.90S 4276.94W 2609.65S 4287.73W 2606.29S 4293.00W -1840 -1831 -1823 -1815 -1811 .28 .20 .70 .65 .42 10941.39 8959.55 8896.55 10957.91 8965.74 8902.74 10969.54 8970.04 8907.04 10987.49 8976.13 8913.13 11000.99 8980.11 8917.11 68 1 67 56 68 38 71 43 74 0 N 53.94 W 13.01 N 55.70 W 9.89 N 55.70 W 6.02 N 55.70 W 17.16 N 55.87 W 16.93 2593.28S 4311.81W 2584.45S 4324.33W 2578.36S 4333.26W 2568.85S 4347.21W 2561.60S 4357.87W -1795 -1784 -1776 -1765 -1756 .3O .41 .85 .03 .02 11015.34 8983.72 8920.72 11031.04 8986.91 8923.91 11043.99 8988.98 8925.98 11059.81 8990.88 8927.88 11091.96 8993.13 8930.13 76 49 N 55.34 W 19.97 79 43 N 55.70 W 18.61 81 54 N 53.59 W 23.34 84 17 N 53.59 W 15.04 87 42 N 49.72 W 16.04 2553.75S 4369.33W 2545.05S 4382.00W 2537.65S 4392.42W 2528.33S 4405.06W 2508.44S 4430.20W -1746 -1735 -1726 -1714 -1690 .28 .49 .38 .98 .98 11119.96 8993.75 8930.75 11154.41 8994.06 8931.06 11179.84 8994.61 8931.61 11211.29 8995.60 8932.60 11229.57 8995.95 8932.95 89 44 N 44.97 W 18.44 89 12 N 37.24 W 22.49 88 19 N 35.83 W 6.53 88 4 N 28.80 W 22.36 89 44 N 27.40 W 11.92 2489.48S 4450.78W 2463.54S 4473.42W 2443.12S 4488.55W 2416.57S 4505.34W 2400.45S 4513.95W -1668 -1639 -1616 -1587 -1569 .70 .19 .42 .33 .95 11257.92 8995.88 8932.88 11278.24 8995.74 8932.74 11313.24 8995.74 8932.74 11360.94 8995.52 8932.52 11399.69 8994.96 8931.96 90 31 N 24.93 W 9.15 90 15 N 23.18 W 8.71 89 44 N 21.07 W 6.21 90 47 N 18.43 W 5.96 90 52 N 17.20 W 3.18 2375.01S 4526.45W 2356.45S 4534.73W 2324.04S 4547.91W 2279.15S 4564.03W 2242.26S 4575.88W -1542 -1522 -1488 -1441 -1403 ORIGINAL .71 .99 .76 .74 .35 S~. ~{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU / 15-02A 500292069701 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 101996 MWD SURVEY JOB NUMBER: AK- MW- 60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 11438.69 8994.57 8931.57 11465.57 8994.57 8931.57 11472.07 8994.58 8931.58 11519.34 8994.66 8931.66 11544.67 8994.99 8931.99 11575.67 8995.89 8932.89 11616.27 8997.17 8934.17 11642.94 8997.72 8934.72 11675.12 8997.82 8934.82 11712.09 8997.14 8934.14 11746.49 8996.19 8933.19 11777.89 8995.42 8932.42 11802.42 8994.90 8931.90 11833.54 8994.47 8931.47 11867.42 8994.41 8931.41 11907.47 8994.23 8931.23 11938.97 8993.48 8930.48 11976.72 8992.58 8929.58 12001.59 8992.37 8929.37 12026.12 8992.15 8929.15 12041.54 8991.90 8928.90 12070.72 8991.34 8928.34 12103.67 8990.55 8927.55 12136.69 8989.26 8926.26 12164.42 8988.16 8925.16 12199.28 8987.04 8924.04 12233.61 8985.59 8922.59 12262.33 8984.23 8921.23 !2290.71 8982.64 8919.64 12320.21 8980.88 8917.88 COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 90 15 N 14.39 W 7.38 2204.74S 89 44 N 12.45 W 7.47 2178.60S 90 0 N 12.10 W 6.71 2172.25S 89 49 N 6.30 W 12.28 2125.61S 88 40 N 6.30 W 4.50 2100.43S 87 58 N 4.54 W 6.11 2069.59S 88 25 N 2.26 W 5.72 2029.09S 89 12 N .85 W 6.06 2002.44S 90 26 N 3.37 E 13.66 1970.27S 91 40 N 6.71 E 9.63 1933.46S 91 29 N 8.11 E 4.10 1899.36S 91 19 N 9.17 E 3.42 1868.33S 91 8 N 11.!0 E 7.90 1844.19S 90 26 N 11.45 E 2.52 1813.67S 89 44 N 10.22 E 4.18 1780.40S 90 47 N 8.82 E 4.37 1740.91S 91 55 N 8.99 E 3.66 1709.80S 90 47 N 4.07 E 13.37 1672.31S 90 10 N 3.19 E 4.30 1647.50S 90 52 N 1.96 E 5.77 1622.99S 90 58 N 2.14 E 1.31 1607.58S 91 13 N .56 E 5.49 1578.42S 91 29 N .85 W 4.35 1545.48S 92 59 N 1.73 W 5.27 1512.50S 91 34 N 2.26 W 5.43 1484.81S 92 6 N 3.84 W 4.78 1450.02S 92 43 N 2.26 W 4.93 1415.78S 92 43 N 4.54 W 7.93 1387.14S 93 41 N 5.07 W 3.89 1358.91S 93 9 N 8.06 W 10.28 1329.66S 12350.73 8978.94 8915.94 94 7 N 8.94 W 4.29 1299.54S 12369.88 8977.56 8914.56 94 7 N 9.99 W 5.47 1280.70S 12390.00 8976.12 8913.12 94 5 N 11.20 W 6.00 1260.97S VERT. SECT. 4586.49W -1364.54 4592.73W -1337.71 4594.11W -1331.22 4601.67W -1283.97 4604.45W -1258.70 4607.37W -1227.82 4609.78W -1187.53 4610.50W -1161.17 4609.80W -1129.63 4606.55W -1093.96 4602.12W -1061.17 4597.40W -1031.45 4593.08W -1008.44 4587.00W -979.47 4580.63W -947.83 4574.01W -910.12 4569.14W -880.35 4564.85W -844.20 4563.27W -820.05 4562.17W -796.12 4561.62W -781.05 4560.93W -752.46 4561.01W -720.02 4561.76W -687.42 4562.72W -659.99 4564.57W -625.42 4566.40W -591.38 4568.10W -562.90 4570.47W -534.69 4573.84W -505.30 4578.34W -474.85 4581.48W -455.76 4585.17W -435.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4755.40 FEET AT SOUTH 74 DEG. 37 MIN. WEST AT MD = 12390 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 349.88 DEG. TIE-IN SURVEY AT 10,600.00' MD WINDOW POINT AT 10,681.20' MD S. ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC PBU / 15-02A 500292069701 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 101996 JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SL~-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAI~G~ COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10600.00 8748.30 11600.00 8996.72 12390.00 8976.12 8685.30 2595.40 S 4071.40 W 1851.70 8933.72 2045.34 S 4609.14 W 2603.28 751.58 8913.12 1260.97 S 4585.17 W 3413.88 810.61 THE CALCTTLATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPL-..RY-SUN DRILLING SERVICES A~NCHORAGE ALASKA PAGE ARCO ALASKA !NC PBU / 15-02A 500292069701 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 101996 JOB NUMBER: AK-MW-60142 .KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRL~ SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEP~q DEPTH TOTAL RECTANGULAR COORDINATES NOR~qq/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10600.00 8748.30 8685.30 2595.40 S 4071.40 W 1851.70 10618.84 8763.00 8700.00 2601.36 S 4081.56 W 1855.84 4.14 10752.50 8863.00 8800.00 2637.05 S 4161.57 W 1889.50 33.67 10950.59 8963.00 8900.00 2588.38 S 4318.80 W 1987.59 98.08 10980.00 8973.70 8910.70 2572.84 S 4341.35 W 2006.30 18.71 THE CALCL~_JkTION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPE,,RY-SUN DRILLING SERVICES ANCHORAGE ~ ~_LAS KA PAGE 1 ARCO AI--ASKA INC PBU / !5-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 MWD SURVEY JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD \~RTICAL \~RTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10600.00 8748.30 8685.30 38 42 S 59.60 W .00 2595.40S 4071.40W -1839.63 10681.22 8811.46 8748.46 39 12 S 59.50 W .62 2621.28S 4115.42W -1857.37 10719.07 8839.91 8776.91 43 30 S 71.00 W 23.03 2631.61S 4138.08W -1863.56 10760.07 8868.02 8805.02 50 5 S 83.70 W 27.68 2637.95S 4167.15W -1864.70 10775.02 8877.48 8814.48 51 25 S 85.81 W 14.05 2639.00S 4178.68W -1863.71 10790.72 8887.10 8824.10 53 1 S 88.58 W 17.27 2639.61S 10806.34 8896.30 8833.30 54 50 N 84.70 W 36.66 2639.17S 10819.27 8903.60 8840.60 56 30 N 80.83 W 27.89 2637.82S 10837.14 8913.18 8850.18 58 37 N 76.26 W 24.60 2634.82S 10852.97 8921.22 8858.22 60 22 N 70.99 W 30.76 2630.98S 4191.07W -1862.12 4203.68W -1859.48 4214.27W -1856.29 4229.04W -1850.74 4242.12W -1844.66 10863.14 8926.19 8863.19 61 4 N 70.11 W 10.22 2628.02S 10882.07 8935.07 8872.07 63 1 N 64.31 W 28.94 2621.54S 10895.92 8941.21 8878.21 64 20 N 61.67 W 19.56 2615.90S 10909.69 8947.05 8884.05 65 28 N 58.i6 W 24.52 2609.65S 10923.04 8952.46 8889.46 66 48 N 55.34 W 21.70 2602.96S 4250.48W -1840.28 4265.88W -1831.20 4276.94W -1823.70 4287.73W -1815.65 4297.94W -1807.27 10942.89 8960.01 8897.01 68 28 N 51.30 W 20.62 2591.99S 10955.27 8964.42 8901.42 69 46 N 47.96 W 27.34 2584.50S 10968.52 8968.83 8905.83 71 22 N 44.97 W 24.43 2575.89S 10986.64 8974.32 8911.32 73 23 N 39.88 W 29.00 2563.15S 11000.24 8978.06 8915.06 74 42 N 37.24 W 21.04 2552.92S 4312.65W -1793.89 4321.46W -1784.96 4330.52W -1774.90 4342.16W -1760.31 4350.31W -1748.81 11013.09 8981.30 8918.30 76 1 N 34.25 W 24.71 2542.83S 11031.39 8985.52 8922.52 77 20 N 30.38 W 21.81 2527.79S 11046.84 8988.71 8925.71 78 50 N 26.69 W 25.30 2514.51S 11061.62 8991.42 8928.42 80 4 N 23.18 W 24.79 2501.33S 11076.34 8993.83 8930.83 81 2 N 19.66 W 24.49 2487.82S 4357.57W -1737.60 4367.09W -1721.12 4374.31W -1706.77 4380.43W -1692.73 4385.73W -1678.49 11087.79 8995.54 8932.54 81 49 N 17.20 W 22.34 2477.08S 11114.59 8998.80 8935.80 84 11 N 11.57 W 22.65 2451.32S 11127.07 8999.83 8936.83 86 18 N 9.46 W 23.87 2439.10S 11147.07 9000.38 8937.38 90 31 N 4.54 W 32.40 2419.26S 11167.00 9000.20 8937.20 90 31 N 4.54 W .00 2399.40S 4389.31W -1667.29 4395.91W -1640.78 4398.18W -1628.34 4400.61W -1608.39 4402.19W -1588.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF TIIREE-DIMENSION MINIMUM CLIRVATURE METHOD. HORIZONTAL DISPLACEMENT = 5013.62 FEET AT SOUTH 61 DEG. 24 MIN. WEST AT MD = 11167 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 349.88 DEG. TIE-IN SURVEY AT 10,600.00' MD WINDOW POINT AT 10,681.20' MD PROJECTED SURVEY AT 11,167.00' MD SP,...RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC PBU / 15-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10600.00 8748.30 8685.30 11167.00 9000.20 8937.20 2595.40 S 4071.40 W 1851.70 2399.40 S 4402.19 W 2166.80 315.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~RRY-SUN DRiLLiNG SERVICES ~_,NCHORAGE AXJkS KA PAGE ARCO ALASKA INC PBU / 15-02APB1 500292069770 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 101696 JOB NUMBER: AK-MW-60142 KELLY BUSHING ELEV. = 63.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10600.00 8748.30 8685.30 2595.40 S 4071.40 W 1851.70 10618.84 8763.00 8700.00 2601.36 S 4081.56 W 1855.84 4.14 10752.50 8863.00 8800.00 2637.05 S 4161.57 W 1889.50 33.67 10951.44 8963.00 8900.00 2586.70 S 4318.66 W 1988.44 98.93 11167.00 9000.20 8937.20 2399.40 S 4402.19 W 2166.80 178.36 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS I~ FI I I--I--I IM G S ~= i:l~J I r' =: S WELL LOG TRANSMITTAL To: State of Alaska March 26, 1997 Alaska Oil and Gas Conservation Cormn. Attn.' Loft Taylor ,~-';~6(7~/2~ 3001 Porcupine Dr. ~.~ ~ ~ Anchorage, Alaska 99501 '~ ~ MWD Formation Evaluation Logs - D.S. 15-02A & 15-02A PB 1, AK-MW-60142 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Yan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Disc with verification listing. API#: 50-029-20697-01 & 50-029-20697-70. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company C] F::i I I_1_ I IM (:S WELL LOG TRANSMITTAL To: State of Alaska March 12, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS 15-02A & 15-02A PB 1, AK-MW-60142 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 15-02A: 2"x 5" MD Gamma Ray Logs: 50-029-20697-01 2" x 5" TVD Gamma Ray Logs: 50-029-20697-01 / DS lS-0ZA PBI: ~ W 2" x 5" MD Gamma Ray Logs: 50-029-20697-70 2" x 5" TVD Gamma Ray Logs: 50-029-20697-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company February 27, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 15-02A PB 1 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 15-02A PB1 MWD survey Tie-In point at 10,600.00', Window Point at 10,681.20' and a Projected survey at 11,167.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. ECEIVED MAR 0 5 199]' 011 & Gas Co~s. Corf~ssl~ 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (9.07)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company February 27, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 15-02A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 15-02A MWD survey Tie-In point at 10,600.00', Window Point at 10,681.20' and a Projected survey at 12,390.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. RECEIVED MAR 05 1997 Oil & Gas Cons. Commtsa)n Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I I--I-I I~ 13 February 11, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 15-02A PB 1 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 15-02A PB1 MWD survey Tie-In point at 10,600.00', Window Point at 10,681.20' and a Projected survey at 11,167.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI Ft I I--I-- I N 13 SEIki/ICE S February 11, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 15-02A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 15-02A MWD survey Tie-In point at 10,600.00', Window Point at 10,681.20' and a Projected survey at 12,390.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, ...:, :"' .: '<' ~- ....... : ---(__ William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9,07)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc, Company MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 15, 1996 Blair Wondzell, ~ P. I. Supervis~r~~'~/-%/,.~ FROM: Bobby Fo~tei¥//'\ SUBJECT: Petroleum InsCector FILE NO: AG91JODD.doc BOPE Test - Rig3S ARCO - PBU Prudhoe Bay Field Tuesday, October 15, 1996: I traveled this date ARCO's PBU DS 15-02A being drilled by the CTU rig Dowel / Nabors 3S and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 failure. The H2S sensor at the shale shaker was not working properly. This is to be repaired or replaced ASAP and the AOGCC inspector notified. I also requested that the manifold pressure on the accumulator unit be set at the proper setting. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment was stored properly. Summary: I witnessed the BOPE test on ARCO's DS15-02A being drilled by Dowell/Nabors rig 3S - test time 3.5 hours - 1 failure. Attachment: AG91JODD.XLS I was notified 10/16/96 by Jeff Hupp, ARCO rep., that the repairs had been made to the accumulator system and the H2S sensor had been replaced. X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION COILED TUBING DRILMNG BOPE TEST OPERATION: Drlg: X Workover: Drlg Contractor: Doweli / Nabors Rig No. Operator: Arco AJaska/nc, Well Name: DS15-O2A Casing Size: 9.625 X 7" Set @ PBD 9750' Test: Initial X Weekly Other DATE: 10/15/96 3S PTD # 96-0163 Rig Ph.# 659-1595 Rep.: ARVELL BASS Rig Rep.: JMMY Location: Sec. 22 T. l~N R. ~4E Meridian Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Quan. Pressure P/F BaliType "' ] 350/3500 I'P BOP STACK: Quan. Annular Preventer 1 Pipe Rams '1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line VaNes 2 Test Press. Test 250,2,500 Pressure 350/3,500 250/3000 350/3,500 250/3000 350/3,500 350/3,500 pti= P CHOKE MANIFOLD: P No. Valves 12 P No. Flanges 37 P Manual Chokes 1 P Hydraulic Chokes ' /' P 350/3,500 P Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure 3000 P · Pressure After Closure 1,550 P MUD SYSTEM: V'~uai Alarm 200 psi Attained After Closure minutes 10 sec. Pit Level Indicators OK OK System Pressure Attained minutes 52 sec. Meth. Gas Detector -_-.__OK ~OK Blind Switch Covers: Master: _ yes Remote: yes H2S Gas Detector OK OK , , _ Nitgn. Btl's: 4 2100, 1700, 2400, 2000 Psig. Number of Failures: 1 ,Test Time: 3.5 Hours. Number of valves tested ~6 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: H2S sensor at shale shaker is to be replaced and the AOGCC inspector is to be notified. The accumulator is to be adjust, ed to the proper seffing of t500 psig ASAP Distribution: orig-Well File c - Oper./PJg c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AG91JODD.XLS TONY KNOWLE$, GOVERNOR ALASi~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 26, 1996 Erin M. Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510 Re: Prudhoe Bay Unit 15-02A ARCO Alaska, Inc. Permit No: 96-163 Sur. Loc. 1441'FNL, 285 I'FWL, Sec. 22, T1 IN, R14E, UM Btmhole Loc. 2138'FNL, 4126'FEL, Sec. 2I, T11N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill m Redrill X lb. Type of Well Exploratory~ Stratigraphic Test . Development Oil Re-Entrym Deepen _ Service _ Development Gas M Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Poo~ ARCO Alaska. Inc. RKB 63' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510 ADL 28306 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 1441' FNL, 285" FWL, Sec 22, T11N, R14E, UM prudhoe B~y unit Statewide At top of productive interval 8. Well number Number 1370' FSL, 1712' FWL Sec 21, T11N, R14E, UM 15-02A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2138' FNL, 4126' FEL, Sec 21, T11N, R14E, UM September 25, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) property line 1274 feet No Close Approach 12955' MD / 8998' TVD 16. To be completed for deviated wells 17. Anticipaled pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10695' MD Maximum hole anc~le 90° Maximum surface 3O00 psig At total depth {TVDI 3500 psi~l 18. Casing program Setting Depth size specification To1:) Bottom Quantity of cement , Hole Casin~l Wei~)ht Grade Couplin~l Length MD TVD MD TVD (include sta~le dataI 3-3/4" 2-7/8" 6,4 L-80 FL4S 3205' 9750' 8098' 12955' 8998' 25 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 907011009 feetfeet Plugs(measured) 0 R Effective depth: measured 10939 feet Junk (measured true vertical 9015 leer Casing Length Size Cemented Measured depth True Vertical d__eepth.. ,_ _. E'IVED Conductor 79' 20" 1902# Polese, 79' 79'K~I'~ Surface 2612' 13-3/8" 3000 Sx Fondu & 400 Sx PF 2675' 2675' Production 9971' 9-5/8" 500 Sx CIG 10034' 8315:? ~ ? Liner 1283' 7' 350SxClG 11009' 907~> ~ 01996 Pedoration depth: measured 10850 - 10860'; 10864 - 10874'; 10888 - 10932' Alaska Oil & Gas Cons. Commission r,f-- -,~ _,3 true vertical 8944 - 8952'; 8955 o 8963'; 8974 - 9009' 20. Attachments Filing fee ~x Property plat _ BOP Sketch ~ Diverter Sketch _ Drilling program x~ Drilling fluid program __ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (:~,~ 5.1Fie ~-~ .-5 ~.'~ % ~' ~.V ~ ~ c~ r-~:[ ~, ~. ~ ~'" --/. 50 .~"., Signed '~'~~ "~. ~ Titlle En~lineerin~ Supervisor Date ~(~¢.~0/ '"- Commission Use Only / Per~:u.~./.Nqmber ~ I APl number I Approval date I See cover letter for /~'" ~Y~r/'~- ~I 50- O,~.-? -- ,~-~(~ ~ ~' 7 '~3/i I other recjuirements Conditions of approval Samples re~u~ed __Y e s,~ N o Mud log require~ / __ Y e s ~ N o Hydrogen sulfide measures ~ Y e s __ N o Directional survey required /~Yes N o Required working pressure for BOPE __2M; __ 3 M; __ 5 M; __ I OM; __ 1 5-'~' '-~3500 psi for CTU Other: Original Signed By David W. Johnston by order of ~ -c:~- Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplica DS 15-2A CT Sidetrack and Completion Intended Procedure Objective' Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure' Cement squeeze the current perforations and plugback the existing completion to - 10645' md. Mill window in 7" casing at ~10765' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). Directionally drill 3-3/4" x 1700' horizontal well to access Zone lB reserves. Build angle to ~90°. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Return well to production. Alaska 0!1S Gas Cor~s. 6,.s,'rmm::~s;,v~'; · _.~ -~ September 19, 1996 DS 15-2A 5-1/2" Tubing 5-1/2" Otis RQM sSSV Nipple (4.562" ID) Circulating Holes in tubing pOGLM installed from +__ 3197 - 3217' 9-5/8" BOT 3-H Pkr. 4-1/2" Otis 'XN', 3.725" No-Go ID 4-1/2" Tubing tail 9710' 9780' 9792' 4-1/2" GS FN on top of liner @ +__9750' Window Cut in 7" casing with CT,-- 10675 - 10680' .,~___~-~~ 3-3/4" open hole Original perforations cement sqz'd. TD @ +12995' 2-7/8" FL4S liner 7" Casing Shoe @ 1 RECEIVED ,.,. i,,,, (-.',ii (!' r,,,-,,, '"'3r;:: Sent by: FROM DRTLEX ALASKA 90~7.562 4452 09/19/96 11;:5~ JOD LtUb ~uLje ~/u 1 ;5-02~f0 9/t9/~ 11:49 AM ~'~O 15-92 B ~IDETRAGK PI.AN PREPARED fOR STE~E WARD (~ - ARCQ) SEPT. 19 1996 ~ - ' / ....................... ~ ..... ~ __..L .............. ~. ~ ...... ~ ............................. ~ ................. + ~RT~A~ SECT~N U~GD ~' 349 e8~ R~T~ TO ~UE N~H E ................. ,,' . ~ ................... ~ .......~ ................ ~ ............. ~ · . , .......................... J~ J '1 ......... ~~ REL. T~O'~~"~'~RD: ARE REL ~0 GRID N~ J ; ) J ..................... ...................... ! i ', ........................................................ ;.. ' I' i .......... +' J ~ ~ '"~ .......................... : ............ J ...... ,~ .... 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' .............. ~ ............... : -- ' I - ' ' : .... ~ ...... ~-; ............ : ............. :"{ ............... :'"'( ......... ' ................. i .... ~ ............... i17~.0~ ~.~ ~2.4j 8~.t~ ~7,a~ -1~.2~ ~t6.0~ 0.0~ 3.1 3.~ 59~118.0:671651.1 , ~'i~.~." '~:~ .... ~':5~ ........ ~57C ........... ~f~:~~-'-~, .......... '~:~'T ...... ~'~'-~'~7:~""67~6~.~ ...... ~ ......... ~ ................................ .............. [ ............. ................ ............ .............. ............. .................... ............... ; ................. . ........... .................... '~8~,1. ...... ~:bT"-~;~--'~~-~~-~f~T'~5:bi~. ...... 0.C ......... ~.'1' ' 3.~' 5~1~7'.~: '~7~64~.6~ "~'f~:~ .... ~:~ ........ ~T~ .... ~ ...... ~'~"":i'~3~':~5'8~' ' 06: 31] 31~ 5~070~ ~716~1~ ....... ~ II~OQ ~0' ~7D 89351~ I~72 -16719~ ~299 O0: 31 31 5~2~ 671~36~ ' ........ :.{ · , , ~ ; ~ , Sent by: FROU DRILEX ALASKA 9~562 4452 09/19/96 11'39 Job 385 Page 5,,'5 ~z3~.o 9o0 '~3~o .... ~o.o 123~0_0 90.0; 12390.0; 90,0i 124-20 O, ........ "i24.5001 '3~-4T~3.-dI' ~o.o: 1251O.Ol '~'--'-~ .......... 128~.0 ~.0 I~D.O ~.0~ ~=~.o:' - ~-;~ ~=z2oo~ mar- " : 127~ 0 ' ~=~.o eo.o' i~o.o. __. . ~,o'{ '~,o; ~2~3ooj ~.o~ ~5~[ ~ 7 ~ 893~ 1 27.6! 8935.1 28.4. 8935.t 1712.91 '17~.4 1814.4. 1887.8 1 $11.7 lg31.5 3.1 3.! 5~M62.0 871684.8, : '.~'.'C--'--i~'"Si)5~e~,o ~7~:~i;,"- .................... " 3, I: '" 3.-~-"'-~0:0,' e717_~:4j ........... !' -~,0; ,,15.38.7; 0.0 --'-~1t'! 3,1: ~.3~ ~8~9T ~6~ 3.1~ 3.1] ~T 671727.41 : J s:fi' '~,.~ ~-~:~{ ....... ~ ............. ~ , ....'~3~~=~,:. o.o':, '-~'s:~; -~' . , ............ ~ .... ~ . · ~7e.3/ ~7.3! ....... '~;~T-'~.~ 3 ~! ~2.0J '~~ ........ -~.~t'~~""o.o'~ =.~/ ~~~!"'~.~: ............ ~ ........ ;".; ............. . '~~~;] o.o~ '~:~t ~.~._.~,~,.o 6~7~..~_: ......... ~ ..... ?~.~L-"~:~"~:~'j/".: ..... ~-~; ~-~; ~~ ~. ' "'~"'-~:';;;'~ ....... -74Z7 ~.5~ '"O:b'j ..... ~' ' 3.1J 5~.0~'~1~,3, "' ~ "~ .... ', -~.7' ~,o.oj' o.o~ ~.~ 3.~J 59~2~.p~ sn~.s[~. To: .............. pIULE _ I I I iiiJll ARCO ALASKA 154Y2 DJRECTiOt~e,L ALASKA i i i i iiii i ii .... _1 Il , , NoFtP ReL to 5?Id N. True (~0', · · . ARCO ALASKA INC. 15-2STOT - PLAN IN TRUE. REL. 15-2ORTR · ORIG. ~N TRUE. REL. ORIGINAL WELL BORE DmLE C_ Vertical Section Scale 1 inch: 200 ft PLANE OF VERT SECTn 349.88° REL TO TRUE NORTH FILE NAME ' C: ;ARCOALK[15412;15-2At .PLO DRAWN BY : BIMO HADIPUTRO DATE · SEPT. 1§. 1996 _~ .... ,, iim I mi · i ...... I I i Shop Fuel Boilers Water I60~40 I Trplx I Mud Pump Room Pipe rack Ext. Dowell Drilling Equipment Trailer Ext. Preferred Major Equipment Layout for CT Drilling in DS 15-2A Ext. C T Drilling Wellhead Detail 1~ CT Head Injector ~~.._~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I-- Methanol Injection ~ I! Otis 7' WLA Quick I Co.nest ~ I I Alignment Guide Flange-- 7-1/16", 5M Ram Type Dual ~ ~ Gate BOPE ~ HCR Flanged Fire Resistant Manual Valve Kelly Hose To Dual \ ChokeManifold X I I' I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure ~-- 0.29' (3.5") 2" Cutters or Combination Cutter/Blinds 2" Slip/Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate DOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams o.458' (6.5") Manual Master Valve 2" Pump-In j/Tubing Hanger 9-5/8" Annulus 13-3/8" Annulus Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree ,,~_, .o~,A O1.~--AND GAS CONSERVATION COM"-"-qSION APPLlCAT _.,N FOR SUNDRY APP..OVALS 1. Type of Request: Abandon X Suspend Operation shutdown Re-enter suspended well ,, Alter casing Repair well Plugging X Time extension Stimulate Change approved program Pull tubing ' Vadance Perforate ' I ' 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1441' FNL,2851' FWL, Sec 22, T11 N, R14E, UM. At top of productive interval 1370' FSL, 1712' FWL, Sec 21, T11N, R14E, UM. At effective depth At total-depth 1119' FSL, 1274' FWL, Sec 21, T11N, R14E, UM. 5. Type of Well Development Exploratory Stratigraphic Service CXher 6. Datum of elevation(DF or KB) Pa3' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 15-2 9. Permit number 82-07 10. APl number 50 - 029-20697 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11009 feet true vertical 9070 feet Effective depth: measured 10939 feet true vertical 9015 feet Casing Length Size Conductor 79' 20" Su dace 2612' 13-3/8" Production 9971' 9-5/8''~ Liner 1283' 7" Plugs(measured) PBTD Tagged at 10939' MD (12/7/95~. Cemented Measured depth True vertical depth 1902# Poleset 79' 79' 3000 Sx Fondu & 400 Sx PF 2675' 2675' 500 Sx Ci G 10034' 8315' 350 SX Ci G R E C(~~'V'E D 9070' Perforation depth: S~_P 19 1996 measured 10850 - 10860'; 10864 - 10874'; 10888 - 10932' Alaska 0il & G.~s Cons. Commission true vertical 8944 - 8952'; 8955 - 8963'; 8974 - 9009' Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9721' MD; 4-1/2", 12.6#, N-80, PCT @ 9792' MD; 2-3/8" Coil Tubing String @ 3098 - 9779' MD. Packers and SSSV (type and measured depth) BeT 3H Packer @ 9710' MD; TIW Packer @ 3098' MD; Otis RQM SSSV @ 2116' MD. 13. Attachments Description summary of proposal . x. Detailed operations program BOP sketch .,X 14. Estimated date for commencing operation 15. Status of well classification as: September, 1996 16. If proposal was verbally approved Oil X Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the bes of my knowledge. ~ c ~:s-~io~5 ? $ i' ~v~. ~J~ c'~ -' Pal,=, ~-~ Jo_~ Title Engineering Supervisor Date ~'- ~'-~ FOR COMMISSION H.C;E ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. 9/,~ - Plug integrity . BOP Test . Location clearance. Mechanical Integrity Test Subsequent form required 10- .. Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 RI W c~: ,IWP_ SUBMIT IN TRIPLICATE , · WELL PERMIT CHECKLIST COMPANY WELLN^ME/~,/~/ /,.~'"'-,::~~ PROGRAM:expl-I de~r~d~se~ well~re~ O~n. dis~~r~ ~ · ~ ' FIE~&P~L ~DA~ IN~C~SS~~ /~Y GEOLAR~ ~~ UN~ ' /~~ O~OFFSHORE ~ ADI~INISTRA¥1oN ' ENGINEERING 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number ................ 4. Well locat~:l in a defined pool ................. 5. Well located proper distance from ddg unit boundary ..... 6. Well located proper distance from other wells ........ 7. Sufficient acreage available in drilling unit. ......... __ 8. If deviated, is wellbore plat included ............. 9. Operator only aJfected party .................. 10. Operator has sppmpdate bond in force ............ 11. Permit can be issued without conservation order ...... 12. Permit can be issued without administrative approval .... .IY~N 13. Can permit be approved before 15-day wail ........ ,, , REMARKS GEOLOGY APPR DA/i'E/~... 15. Surface casing protects all known USDWs .......... Y 16. CMT vol adequate to circulate on conductor & surf csg .... Y N'~ 17. CMT vol adequate to tie-in long string to surf c. sg ....... Y~ 18. CMT will cover ail known productive horizons ........ ..,.~ 19. Casing designs adequate for C, T, B & permafrost ..... ~ N 20. Adequate tankage or reserve pit. ............... 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ,.~N 22. Adequate wellbere separation proposed ............ _(_~N . , A 23. If diverter required, is it adequate ............... 24. Ddlling fluid program schematic & equip list adequate .... ~N 25. BOPEs adequate ........................ r,~N 26. BOPE press ra~ng adequate; test to ~ psig.~ N 27, Choke manifold complies w/AP! RP-53 (May 84) ....... Q~N 28. Work will occur without operation shutdown .......... (~..N 29. Is presence of H2S gas probable .................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potenlJal overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. //Y N/v/ , · 33. Seabed condilJon survey (if off-shore) ........... /'. Y N 34. Contact name/phone for weekly progre~, repoT ...../f... Y N iaXTomr~mry ong'J GEOL,?Y: ENGINEERING: COMMISSION: BEW l~.~,_...~j~"z,~, DWJ ~'"~. JDH ~ JDN TAB~ CommenL~nstructJons: Well HistorY File · APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~perry-Sun Drilling Services LIS Scan Utility Mon Mar 24 09:50:52 1997 Reel Header ~~~~9 Service name ............. LISTP Date ..................... 97/03/24 Origin ................... STS Reel Name ................ UNKNOW~B%O-~~ Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MW- 60142 B. JAHN BAS S/MOONEY 15-02A 500292069701 ARCO ALASKA, INC. R CE V D BAR 26 1997 Ais, ska Oi~ ~ vas Cons. Crjmmissio~ Anchorage SPERRY-SUN DRILLING SERVICES 24-MAR-97 MWD RUN 6 AK-MW-60142 B. JAHN BASS/MOONEY MWD RUN 9 AK-MW-60142 B. JA/~N BASS/MOONEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 10 AK-MW-60142 B. JAHN HUPP/REYNOLD MWD RUN 11 AK-MW-60142 A. WORTHINGT HUPP/REYNOLD 22 liN 14E 1441 2851 63.00 .00 GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2765.0 9.625 10034.0 3.800 7.000 11009.0 3.750 12390.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 3 DATA FROM 10677'MD, 8745'SSTVD TO 10688'MD, 8754'SSTVD, IS REAL TIME. 3. MWD RUNS 1,2,4,5,7, AND 8 CONTAIN NO DATA AND ARE NOT PRESENTED. 4. MWD RUNS 3,6,9,10, AND 11 ARE DIRECTIONAL WITH SCINTILLATION TYP~ GAMMA RAY (NGP). 5. THE WINDOW WAS CUT IN 7" CASING. THE TOP WAS AT 10677'MD, 8745'SSTVD. THE BOTTOM WAS AT 10683'MD, 8750'SSTVD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DICK OWENS OF ARCO ALASKA, INC. ON MARCH 11, 1997. 7. THIS WELL REACHED A TOTAL DEPTH (TD) AT 12390'MD, 8913'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMY~A RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10654.0 12363.0 ROP 10677.0 12389.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD MWD MWD $ REMARKS: 3 10677.0 10688.0 6 10691.0 10942.0 9 10942.0 11251.0 10 11251.0 12188.0 11 12188.0 12389.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units .................... '... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10654 12389 11521.5 3471 10654 ROP 0.56 1067.38 72.9431 3425 10677 GR 18.02 333.79 78.2734 3419 10654 Last Reading 12389 12389 12363 First Reading For Entire File .......... 10654 Last Reading For Entire File ........... 12389 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: ~ RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10654.0 ROP 10677.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10664.5 10687.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 07-OCT-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10688.0 10677.0 10688.0 39.2 39.2 TOOL NUMBER NGP 246 3.800 3.8 Biozan/Seawater .00 .0 .0 0 .0 .000 .000 .000 .000 82.0 .3 MILLING WINDOW IN 7" CASING. FINISHED WINDOW, POOH FOR BUILD ASSY. Data Format Sp~cificatmon Record Data R~cord Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10654 10687.5 10670.8 68 10654 ROP 0.56 36.15 16.1909 22 10677 GR 31.98 40.03 35.4405 22 10654 Last Reading 10687.5 10687.5 10664.5 First Reading For Entire File .......... 10654 Last Reading For Entire File ........... 10687.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10664.5 ROP 10679.0 STOP DEPTH 10941.5 10941.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: DRILL BUILD SECTION TO COMPLETION. 08-OCT-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10942.0 10691.'0 10942.0 43.5 86.3 TOOL NUMBER NGP 315 3.75O 3.8 Flo-Pro 8.80 54.0 8.4 5.9 .000 .000 .000 ,000 70.0 .3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam.Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 6~ 4 2 GR MWD 6 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10664.5 10941.5 10803 555 10664.5 ROP 40.99 3074.29 157.838 526 10679 GR 18.02 333.79 45.3529 555 10664.5 Last Reading 10941.5 10941.5 10941.5 First Reading For Entire File .......... 10664.5 Last Reading For Entire File ........... 10941.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation..- ..... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10900.5 11224.0 ROP 10940.5 11250.5 $ LOG HEADER DATA DATE LOGGED: 16-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11251.0 10942.0 BOTTOM LOG INTERVAm (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11251.0 68.5 89.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 320 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHNfM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 9.20 55.0 8.5 5.7 .000 .000 .000 .000 70.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: BUILD TO HORIZONTAL. DRILL AHEAD TURNING AZIMUTH $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datu~n Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam . DEPT 10900.5 11250.5 11075.5 701 GR 33.74 246.8 85.1048 648 ROP 14.19 186.38 58.9122 621 Reading 10900.5 10900.5 10940.5 Reading 11250.5 11224 11250.5 First Reading For Entire File .......... 10900.5 Last Reading For Entire File ........... 11250.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11224.0 12161.5 ROP 11251.0 12188.0 $ LOG HEADER DATA DATE LOGGED: 18-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12188.0 TOP LOG INTERVAL (FT): 11251.0 BOTTOM LOG INTERVAL (FT): 12188.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.0 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 315 BOREH~LE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OH/V~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 9.20 .0 9.2 5.3 .000 .000 .000 .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .3 REMARKS: DRILL HORIZONTAL. POOH FOR BIT AND MOTOR. 70.3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 AAPI 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11224 12188 11706 1929 11224 GR 38.62 138.99 76.9579 1876 11224 ROP 18.67 1067.38 74.9459 1873 11251 Last Reading 12188 12161.5 12188 First Reading For Entire File .......... 11224 Last Reading For Entire File ........... 12188 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12161.0 12363.0 ROP 12188.0 12389.0 $ LOG HEADER DATA DATE LOGGED: 19-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12390.0 TOP LOG INTERVAL (FT): 12188.0 BOTTOM LOG INTERVAL (FT): 12390.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM AnNGLE: 92.1 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: TOOL NUMBER NGP 320 3.750 3.8 Flo-Pro 9.20 .0 9.2 MUD CHLORIDES (~M) : FLU-ID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 5.3 .000 .000 .000 .000 72.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .3 REMARKS: DRILL HORIZONTAL. POOH FOR STICKY SHALES. TD WELL. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing..~ .................. 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12161 12389 12275 457 12161 GR 78.24 152.09 114.81 405 12161 ROP 28.66 990 95.2985 403 12188 Last Reading 12389 12363 12389 First Reading For Entire File .......... 12161 Last Reading For Entire File ........... 12389 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EO~F Tape Trailer Service name ............. LISTPE Date ..................... 97/03/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File ' ' Sat Mar 22 22:05:~~t%~~. "U ~%~ Reel Header .~_~__~ Service name ............. LISTPE . ~~ Date ..................... 97/03/22 Origin ................... STS ~%~ Reel Name ................ UNKNOWN ContinUation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MW-60142 B. JAHN BASS/MOONEY 1ST STRING RaOE!VED i997 Alaska Oil & G~ Cons. C, or, mis-sio, 15-02A PB1 500292069770 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22 -MAR- 97 MWD RUN 6 AK-MW-60142 B. JAHN BASS/MOONEY MWD RUN 7 AK-MW-60142 B. JAHN BASS/MOONEY 22 S2 14E 1441 2851 63.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2675.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9.625 10034.0 3.800 7.000 11009.0 3.750 11167.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 3 DATA FROM 10677'MD, 8745'SSTVD TO 10688'MD, 8754'SSTVD, IS REAL TIME. 3. MWD RUNS 1,2,4, AND 5 CONTAIN NO DATA AND ARE NOT PRESENTED. 4. MWD RUNS 3,6, AND 7 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 5. THE WINDOW WAS CUT IN 7" CASING. THE TOP WAS AT 10677'MD, 8745'SSTVD. THE BOTTOM WAS AT 10683'MD, 8750'SSTVD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DICK OWENS OF ARCO ALASKA, INC. ON MARCH 11, 1997. 7. THIS WELL REACHED A TOTAL DEPTH {TD) AT ll166'MD, 8937'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUPRiARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10654.0 11141.5 ROP 10677.0 11166.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 10677.0 10687.5 6 10679.0 11145.0 7 11145.5 11166.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10654 11166 10910 1025 10654 ROP 0.56 380.33 71.1845 979 10677 GR 18.02 333.79 56.1676 976 10654 Last Reading 11166 11166 11141.5 First Reading For Entire File .......... 10654 Last Reading For Entire File ........... 11166 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMA2~Y VENDOR TOOL CODE START DEPTH STOP DEPTH GR ROP $ · LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: z~654.0 10664.5 10677.0 10687.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE. NGP NATURAL G~ PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 07-OCT-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10688.0 10677.0 10688.0 39.2 39.2 ToOL NUMBER NGP 246 3.800 3.8 Biozan/Seawater .00 .0 .0 0 .0 .000 .000 .000 .000 82.0 .3 MILLING WINDOW IN 7" CASING. FINISHED WINDOW, POOH FOR BUILD ASSY. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum'Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10654 10687.5 10670.8 68 10654 GR 31.98 40.03 35.4405 22 10654 ROP 0.56 36.15 16.1909 22 10677 Last Reading 10687.5 10664.5 10687.5 First Reading For Entire File .......... 10654 Last Reading For Entire File ............ 10687.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEAHDER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10664.5 11119.0 ROP 10679.0 11145.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 08-OCT-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM~ LOG I~NTERVAL ( FT ): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: DRILL BUILD SECTION TO COMPLETION. 11146.0 10691.0 11146.0 43.5 86.3 TOOL NUMBER NGP 315 3.750 3.8 Flo-Pro 8.80 54.0 8.4 5.9 .000 .000 .000 .000 70.0 .3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Last Name Mfn Max Mean Nsam Reading Reading DEPT 10664.5 11145 10904.8 962 10664.5 11145 GR 18.02 333.79 55.7482 910 10664.5 11119 ROP 40.99 3074.29 122.609 933 10679 11145 First Reading For Entire File .......... 10664.5 Last Reading For Entire File ........... 11145 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB. 004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11110.5 11141.5 ROP 11145.5 11166.0 $ LOG HEADER DATA DATE LOGGED: 09-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 90.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11166.0 11146.0 11166.0 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : NGP 320 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 8.8O 54.0 8.4 5.9 .000 .000 .000 .000 65.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .3 REMARKS: HORIZONTAL SECTION. BIT BALLED UP. POOH FOR BIT, MOTOR. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11110.5 11166 11138.2 112 11110.5 GR 40.94 132.59 73.8267 63 11110.5 ROP 37.12 103.97 59.1052 42 11145.5 Last Reading 11166 11141.5 11166 First Reading For Entire File .......... 11110.5 Last Reading For Entire File ........... 11166 File Traiie~ " Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER . . ............................ * ....... SCHLUMBERGER ....... . ............................ COMPANY NAME : ARCO AL~SKA INC. WELL NAI4E : DS 15-02A FIELD NAME : PRUDHOE BAY BOROUGH ' NORTH SLOPE STATE . ALASKA API NUMBER : 500292069701 REFERENCE NO : 99052 RECEIVED !999 Alas~ ~ & Gas'Cons. CommOn AnYone LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: **** REEL H~ER **** SERVICE NAME : EDIT DATE · 99/02/22 ORIGIN · FLIC REEL NAME : 99052 CONTINUATION # : PREVIOUS REEL : COMMENT · ARCO ALASKA INC, DS 15-02A, PRUDHOE BAY, # 50-029-20697-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE . 99/02/22 ORIGIN · FLIC TAPE NAME : 99052 CONTINUATION # : 1 PREVIOUS TAPE : CONk4~2~r . ARCO ALASKA INC, DS 15~02A, PRUDHOE BAY, # 50-029-20697-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINELOGS WELL NAME: DS 15-02A API iV-U-MBER: 500292069701 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-FEB-99 JOB ~ER: 99052 LOGGING ENGINEER: P.NASH OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 22 TOWNSHIP: lin ~GE: 14E FNL: 1441 FSL: FEL: FWL: 285 ELEVATION (FT FROM MSL O) KELLY BUSHING: 63. O0 DERRICK FLOOR: 62.00 GROUND LEVEL: 28.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 2. 875 11905.0 2ND STRING 3RD STRING PRODUCTION STRING # CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CNT LDWG CURVE CODE: GR RUN NOW~ER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 10666.0 10665.5 10660.5 10634.0 10633.0 10631.5 10625.5 10624.5 10614.5 10613.0 10596.5 10594.5 10592 5 10570 5 10543 5 10523 5 10522 5 10520 5 10516.0 10498.5 10492.0 10429.0 10414.5 10400.0 10398.5 10392.5 10390.5 10371.5 10370.0 10363.5 10362.0 10356.0 10355.0 10340.0 10333 5 10321 5 10319 0 10317 0 10303 5 10302 0 10267 5 10266.0 10255.5 10248.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88886.0 10664.0 10633.5 10630.5 10623.5 10613.5 10595.5 10593.0 10541.5 10523.5 10520.5 10498.0 10490.0 10428.5 10400.5 10392.5 10372.5 10364.0 10356.5 10341.0 10334.0 10323.5 10319.5 10304.0 10268.5 10256.5 10249.5 88886.5 10664.0 10660.0 10633.5 10630.5 10623.5 10613.5 10593.0 10571.0 10541.5 10523.5 10517.0 10498.0 10490.0 10417.0 10400.5 10392.5 10372.5 10364. 0 10356.5 10341.0 10335.0 10323.5 10319.5 10304. 0 10268.5 10256.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 10247.0 10237.5 10231.0 10215.0 100.0 $ 10232.0 10215.5 100.5 10249.5 10240.0 10232.0 10215.5 100.5 CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 15-02A ON lO-JUN-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE BASE PASS #1 GRCH TO THE BASELINE GANR4A RAY PROVIDED BY THE CLIENT (GR.CNT); AND RST SIGMA-MODE BASE PASS #1SIGM TO GR.CNT. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. *NOTE: NO DEPTH SHIFTS WERE APPLIED BELOW THE KICK-OFF POINT OF 10677'. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE I~JMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SOY4NARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11795.0 10212.0 RST 11822.0 10212.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: # BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH GRCH RST REMA_~KS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: FOR RST SIGM-MODE BASE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT tl 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1189310 O0 000 O0 0 1 1 i 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 1 ! 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 5 NA~E SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DSIG RST 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 GR CNT GAPI 1189310 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11820.500 NBAC.RST 2700.535 FBAC.RST 3658 670 SBNA.FIL 52.309 SFNA.FIL 13.342 SBFA.FIL 35.990 SFFA.FIL 13 017 TRAT.FIL 0.953 IRAT. FIL 0.439 CIRN. FIL 1.599 CIRF. FIL 3 816 BSAL.RST 55.299 SIBF. RST 41.701 TPHI.RST 26.566 SFFC.RST 13 565 SFNC.RST 14.112 SIGM. RST 13.568 DSIG.RST 0.557 FBEF.RST 63 810 CRRA.RST 2.264 GRCH.RST -999.250 TENS.RST 36.000 CCL.RST 0 000 GR.CNT -999.250 DEPT. 2422.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL -999 250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999 250 IRAT.FIL -999.250 CIRN. FIL -999.250 CIRF.FIL -999.250 BSAL.RST -999 250 SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST -999 250 SIGM.RST -999.250 DSIG.RST -999.250 FBEF.RST -999.250 CRRA.RST -999 250 GRCH.RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.CNT 31 201 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/22 ~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~k%~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11795.0 10212.0 RST 11822.0 10212.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88891.0 88888.0 11754.5 11757.5 11727.5 11728.5 11702.5 11703.5 11697.5 11698.0 11694.0 11694.0 11683.0 11680.5 11666.0 11666.0 11654.5 11655.0 11641.0 11640.0 11609.0 11608.0 11608.0 11608.0 11592.0 11592.0 11567.5 11566.0 11549.0 11548.5 11544.5 11543.5 11527.5 11526.0 11518.5 11516.5 11500.5 11499.5 11495.0 11494.0 11435.0 11434.5 11414.5 11413.5 11406.5 11406.0 11389.0 11387.5 11371.0 11370.0 11360.5 11359.0 11352.0 11350.5 11328.5 11326.0 11297.0 11292.5 11279.0 11277.0 11276.5 11276.0 11253.0 11251.5 11242.0 11239.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 11223.5 11217.5 11215.0 11211.0 11186.0 11181 0 11178 0 11171 5 11168 5 11162 0 11150 5 11148 5 11129.0 11113.5 11107.5 11105.5 11084.5 11082.5 11062.5 11060.0 11049.5 11038.0 11020.5 !1001.5 10997.5 10992.5 10988.5 10985.0 10980.5 10969.0 10968.5 10941.0 10932.5 10930.0 10886.5 10883.5 10882.0 10860 5 10852 0 10850 5 10834 5 10813 5 10806 5 10801 0 10797.0 10795.0 10790.5 10788.5 10782.0 10775.0 10766.0 10763.5 10752.5 10725.0 10723.5 11222.0 11216.0 11213.5 11176.5 11170.5 11160.5 11147.5 11111.0 11102.5 11083.5 11061.0 11048.5 11037.0 11000.5 10984.0 10979.0 10967.5 10931.5 10886.0 10883.5 10859.5 10850.5 10833.5 10804.5 10800.0 10795.5 10788.5 10787.0 10774.0 10764.5 10751.5 10723.0 11210.5 11185.5 11179.5 11165.5 11149.5 11127.5 11107.5 11082.0 11058.5 11019.5 10996.0 10992.0 10987.5 10967.5 10940.0 10929.5 10881.5 10849.5 10812.5 10794.5 10780.5 10762.5 l 0722.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 10705.5 10696.0 10687.0 10656.5 10647.5 10645.0 10638.5 10631.5 10630.0 10624.0 10623 5 10611 5 10595 5 10592 5 10570 5 10553 0 10549 5 10515.5 10486.5 10473.0 10464.0 10444.0 10431.0 10416.0 10414.0 10398.5 10392.0 10390.0 10374.5 10355.5 10354.5 10337.5 10317.0 10301.5 10292.0 10277.5 10267.0 10256.5 10246.5 10239.5 10237.5 10220.0 100.0 $ 10694.5 10648.5 10645.0 10631.0 10623.5 10595.0 10548.5 10416.5 10392.5 10356.5 10268.5 101.5 10704.5 10686.0 10656.5 10648.5 10638.5 10632.0 10623.5 10613.0 10593.5 10571.5 10553.0 10517.0 10485.0 10472.5 10464.5 10445.5 10433.0 10417.0 10400.5 10392.5 10377.5 10356.5 10339.5 10320.0 10304.0 10295.0 10280.0 10258 0 10249 5 10242 5 10240 0 10221 0 101 0 R~4ARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASE PASS #2 GRCH TO BASE PASS #1 GRCH; AND BASE PASS #2 SIGM TO BASE PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 CIRN FIL 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1189310 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 10 ** DATA ** DEPT. 11822.000 NBAC.RST 2915.033 FBAC.RST 3967.990 SBNA.FIL SFNA.FIL 13.328 SBFA.FIL 32.956 SFFA.FIL 13.185 TRAT. FIL IRAT. FIL 0.437 CIRN. FIL 1.597 CIRF. FIL 3.702 BSAL.RST SIBF. RST 49.824 TPHI.RST 27.528 SFFC.RST 13.727 SFNC.RST SIGM. RST 13.733 DSIG.RST 0.461 FBEF.RST 66.767 CRRA.RST GRCH. RST -999.250 TENS.RST 36.000 CCL.RST 0.001 DEPT. 10213.000 NBAC.RST 2396.613 FBAC.RST SFNA.FIL 17.979 SBFA.FIL 50.995 SFFA.FIL IRAT.FIL 0.407 CIRN. FIL 0.880 CIRF. FIL SIBF.RST 87.640 TPHI.RST 7.898 SFFC.RST SIGM. RST 12.310 DSIG.RST 0.004 FBEF.RST GRCHmRST -999.250 TENS.RST 33.000 CCL.RST 2992 456 15 223 2 657 12 303 71 835 -0 021 SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST 46.995 0.970 77.248 14.109 2.248 63.704 0.796 172.416 11.734 2.467 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA24~ : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~4~ARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: GRCH 11795.0 10180.0 RST 11822.0 10180.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11762.5 11732.5 11716.5 11702.0 11694.5 11686.0 11673.5 !1645.0 11601.5 11579.0 11567.5 11562.5 11555.0 11550.5 11546.5 11534.5 11528.5 11512.0 11506.5 11500.5 11494.0 11484.5 11471.0 11440.5 11437.0 11419 5 11414 5 11411 5 11408 0 11392 5 11357 5 11342 5 11333.0 11325.5 11311.5 11287.5 11275.5 11273.0 11270.0 11251.5 11223.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88884.5 11759.0 11728.5 11712.5 11698.0 11683.5 11670.0 11640.0 11601.0 11577.0 11561 . 0 11551 . 5 11545.0 11526.0 11510.5 11492.0 11434.5 11418.0 11413.5 11406.0 11391.0 11341.5 11273.5 11269.5 88888.0 11694.5 11566.5 11551.0 11534.5 11505.5 11499.0 11485.0 11470.0 11440.5 11412.0 11357.0 11333.0 11325.5 11310.5 11287.5 11269.5 11251.5 11224.5 ~ 22-FEB-1999 11:59 PAGE: 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11214,0 11210.0 11197,5 11181,0 11165.5 11161.0 11148.0 11147.5 11135.0 11129.0 11121.0 11111.5 11098.5 11092.0 11087.5 11082 0 11077 5 11075 0 11063 0 11061 5 11050 5 11038.5 11022.5 11009.5 11002.0 10997.0 10994.0 10977.5 10970.5 10961 5 10952 0 10932 0 10930 0 10908 5 10886 5 10884 0 10881.5 10877.0 10850.5 10810.5 10799.5 10788.0 10763.5 10724.0 10723.5 10710.0 10687.5 10664.5 10663.5 10659.5 10650.0 10649.5 10628.5 10613.5 10611.5 11213.5 11196.0 11181.5 11160.5 11147.5 11108.5 11098.0 11086.5 11076,5 11061.5 11059, 0 11037.0 11021.5 11009.5 11000.5 10993,5 10976,5 10970.0 10951,0 10931,5 10908.5 10886.5 10883.5 10876.0 10809.5 10787,0 10723.0 10709.0 10664.0 10649.5 10613.0 11210.5 11165.5 11146.5 11134.0 11127.5 11120.5 11091.5 11082.0 11074.5 11050.0 10996.5 10961.0 10929.5 10881.0 10850.0 10799.0 10763.0 10723.0 10686.5 10664.0 10660.0 10650.5 10628.5 10613.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 13 10593 5 ! 0592 0 10570 0 10556 5 ! 0553 0 10537 0 10530 0 10515 5 10492 5 10464 0 10430 5 10415 5 10414.0 10391.5 10389.5 10361.5 10355.0 10354.5 10337.5 10316.5 10312.0 10308.0 10302.5 10292.0 10281.0 ! 0265.5 10257.0 10255.0 10246.5 10237.0 10228.5 10217.0 !00.0 $ 10593.5 10555.5 10416.0 10392.5 10356.5 10314.5 10304.0 10282.0 10256.5 10229.0 100.5 10593.5 10571.0 10552.5 10536.0 10530.5 10517.0 10491.0 10464.0 10433.0 10417.0 10392.5 10364.0 10356.5 10339.5 10319.5 10311.0 10294.5 10268.5 10258.5 10249.5 10240.0 10218.0 101.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASE PASS #3 GRCH TO BASE PASS #1 GRCH; AND BASE PASS #3 SIGM TO BASE PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 14 TYPE REPR CODE VALUE 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RST 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1189310 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 15 DEPT. 11822.000 NBAC.RST SFNA.FIL 13.638 SBFA.FIL IRAT. FIL 0.438 CIRN. FIL SIBF.RST 40.367 TPHI.RST SIGM. RST 13.764 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 10180.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST 35.561 TENS.RST 2751.492 FBAC.RST 34.677 SFFA.FIL 1.585 CIRF. FIL 27.620 SFFC.RST 0.506 FBEF.RST 33.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST 3544.458 SBNA.FIL 13.200 TRAT.FIL 3.731 BSAL.RST 13.768 SFNC.RST 67.725 CRRA.RST 0.001 -999.250 SBNA.FIL -999.250 TRAT.FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 52.828 0.970 51.641 14.453 2.249 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUIVI~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 4 DEPTH INCR~4ENT: 0.5000 FILE S~IAR, Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11795.0 10014.0 RST 11822.0 10014.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 16 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11764.0 11729.0 11726.5 11690.0 11685.5 11681.5 11658.5 11645.0 11639.0 11608.5 11584.0 11576.5 11576.0 11569 0 11567 0 11554 0 11528 5 11527 5 11507 5 11502 0 11487.5 11460.5 11441.5 11437.5 11433.0 11415.0 11407.5 11390.0 11384.0 11360.5 11351.0 11338.5 11335 0 11318 0 11295 5 11289 0 11271 0 11251 0 11215 0 11212.0 11197.0 11185.0 11164.0 11147.5 11133.5 11110.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.5 88887.0 11728.5 11685.5 11656.5 11641.5 11604.5 11580.5 11573.0 11565.5 11551.5 11526.0 11459.5 11434.5 11413.5 11387.5 11316.0 11269.0 11213.5 11196.0 11184.5 11162.5 11109.0 11763.0 11725.0 11688.5 11680.0 11637.5 11575.5 11565.0 11527.0 11505.5 11499.0 11485.0 11440.0 11432.5 11406.0 11383.0 11358.5 11350.0 11338.0 11333.5 11294.0 11287.5 11251.0 11211.0 11146.5 11132.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 17 11096 0 11094 5 11088 5 11079 5 11064 0 11038 5 11022.0 11021.5 11010.0 11002.0 10997.5 10996.0 10981.5 10972.5 10969.0 10968.5 10962.5 10953.0 10942.0 10933.0 10930.5 10917.0 10885.0 10882.0 10852.5 10851.0 10835.0 1 0825.5 10816.5 10789.0 10782.0 10780.5 10778.0 10766.5 10753.5 10751.5 10724.0 10706.0 10697.5 1 0685.0 10665.5 10657.0 10654.5 10639.5 10630.0 10615.0 10612.5 10595.5 10593.0 10592.5 10570.5 10546.0 10523.0 10516.0 10513.0 11092.5 11087.0 11037.0 11020.0 11007.0 11000.5 10993.5 10979.0 10970.5 10967.5 10950.5 10940.5 10930.5 10914.5 10883.0 10850.5 1 0833.5 10823.5 10814.5 10787.0 10778.5 10777.0 10764.5 10751.5 10695.0 i 0653.5 10613.5 i 0595.5 10591.5 11094.5 11079.0 11062.5 11019.5 10996.0 10967. S 10960.5 10929.5 10881.0 10849.5 10780.5 10750.0 10723.0 10704.5 10683.0 10664.0 10656.5 10639.0 ! 0628.5 10613.0 10593.5 10571.0 10544.0 10523.5 10517.0 10514.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FBB-1999 11:59 PAGE: 18 10493.5 10491.5 10484.5 10482.5 10465.0 10464.0 10444.5 10445.0 10431.0 10433.0 10416.5 10416.5 10415.0 10417.5 10399°0 10400.5 10392.5 10392.5 10390.5 10392.5 10378.5 10381.0 10370.5 10372.5 10355~5 10356.5 10357.0 10338.0 10339.0 10335.5 10336.5 10317.0 10319.5 10314.5 10315.5 10303.5 10304.0 10302.0 10304.0 10267.5 10268.5 10266.5 10268.5 10256.0 10256.5 10254.5 10256.0 10237.5 10240.0 10218.0 10218.0 100.0 100.5 100.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR THE RST SIGMA-MODE FLOWING PASS. THE DEPTH SHIFTS SHOWN ABOVEREFLECT THE FLOWING PASS GRCH TO BASE PASS #1 GRCH; AND THE FLOWING PASS SIGM TO BASE PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alas~<a Computing Center 22-FEB-1999 11:59 PAGE: 19 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL~ST PPK 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1189310 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11821.000 NBAC.RST SFNA.FIL 13.967 SBFA.FIL IP~T. FIL 0.456 CIRN. FIL SIBF. RST 32.643 TPHI.RST SIGM. RST 13.920 DSIG.RST GRCH.RST -999.250 TENS.RST 2264 706 37 990 1 465 21 466 0 447 34 000 FBAC.RST 3372.549 SBNA.FIL SFFA.FIL 13.450 TRAT. FIL CIRF. FIL 3.722 BSAL.RST SFFC.RST 13.919 SFNC.RST FBEF. RST 59.717 CRRA.RST CCL.RST -0.001 56.556 0.863 30.139 14.505 2.161 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 20 DEPT. 10014.000 NBAC.RST SFNA.FIL 43.318 SBFA.FIL IRAT.FIL 0.353 CIRN. FIL SIBF.RST 132.248 TPHI.RST SIGM. RST 45.167 DSIG.RST GRCH.RST -999.250 TENS.RST 2377.896 FBAC.RST 68.027 SFFA.FIL 0.329 CIRF. FIL 49.355 SFFC.RST 5.253 FBEF.RST 29.000 CCL.RST 2892. 193 40.215 O. 637 45. 186 73. 434 -0. 014 SBNA. FIL TRA T. FIL BSAL. RST SFNC. RST CRRA. RST 66.720 1.476 269.609 51.520 2.756 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION ' O01CO1 DATE . 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCRE~IENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NO?4BERS 1, 2, 3, RST $ RE~IARKS: THE ARITI~4ETIC AVERAGE OF THE 3 BASE PASSES WAS CAI~CULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1189310 NBAC RST CPS 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1189310 O0 000 O0 0 $ 1 1 4 68 0000000000 SFNA RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 CIRN RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 BSALRSAV PPK 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RSAV PU-S 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RSAV CU 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RSAV CU 1189310 O0 000 O0 0 $ 1 1 4 68 0000000000 DSIG RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RSAV UA 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA RSAV 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1189310 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 22 ** DATA ** DEPT. 11820. 500 NBAC.RST 2700. 535 FBAC.RST SFNA.RSAV 13 . 386 SBFA.RSAV 35. 537 SFFA.RSAV IRAT. RSAV O. 434 CIRN. RSAV 1. 589 CIRF.RSAV SIBF. RSAV 40. 906 TPHI.RSAV 26. 834 SFFC.RSAV SIGM~RSAV 13. 636 DSIG.RSAV O. 533 FBEF.RSAV GRCHo RST - 999.250 3658. 670 SBNA.RSAV 13. 080 TRAT.RSAV 3.838 BSAL. RSAV 13. 634 SFNC.RSAV 66. 094 CRRA. RSAV 53.402 0.957 53.087 14.169 2.253 DEPT. 10212.500 NBAC.RST 2229.313 FBAC.RST 3046.580 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999. 250 CIRN. RSAV -999. 250 CIRF. RSAV -999. 250 BSAL. RSAV -999. 250 SIBFoRSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST 20. 481 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION . O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE ' 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NTJM~ER : 1 DEPTH INCRE~fENT : 0.5000 FILE S~4~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 11839.0 10143.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 23 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): lO-JUN-98 8Cl-205 1330 lO-JUN-98 11842.0 11842.0 9700.0 11842.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAN~IA RAY RST RES. SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8. 500 11905.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAI~) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: RST-A RUN IN SIGMA MODE DEPTH CORRELATED TO BHC SONIC LOG 4-MARCH-1982 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 24 TOOLS RUN WITH COILED TUBING PRESSURE AND TEMPERATURE RUN WITH CPLT FLOWING PASS DOWN RECORDED WITH PRESSURE AND TEMPERATURE, ALSO FLOWING SIGMA PASS RECORDED (WELL CHOKED BACK TO 6.9 ~CFD) . WELL THEN SHUT IN AND 360 BBLS OF CRUDE PUMPED. 3 BASELINE PASSES RECORDED. TDT-P EQUIVALENT CURVES DISPLAYED FOR 1 BASELINE PASS FOR COMPARISON. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE- CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS! F/HR 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PSi LB 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS! V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 25 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) AQTMPS1 S 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PSi 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PSI 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PSI V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS1 UA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PSI MA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS1 UA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PSi UA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PSI V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 XM2V PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 P~XLC PS! 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PSi 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 ~PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PSi PPK 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PSi 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS1 CPS 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PSi CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS! CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PSI CU 1189310 O0 000 O0 0 6 ! 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFNA SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS1 CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS1 CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM R2P CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 KHZ 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS1 AMP 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS1 PU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI R2P PU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS1 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH R2P CU 1189310 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11839. NPDE. PS1 1536. AQTM. PS1 0 CM2V. PS1 -12 RCAK. PS1 ! FSCE. PS1 2 HVPV. PSi ! 57 NBEF. PS1 32 BSTR . PS1 2 0 XP5V. PSi 5 RXLC. PSI O. 000 CS.PS1 218 NSCE.PS1 661 CHV. PS1 211 RCFR.PS1 000 RTDF. PS1 324 FSCR.PS1 227 BMCU. PS1 114 FBEF. PS1 983 BSPR.PS1 050 XP2V. PS1 000 RXRC.PS1 62.3 61 2. 441 200. 854 O. 000 O. 000 -0 343 54 492 71 168 1 021 12 041 0 000 TENS.PS1 CRRA.PS1 CPSV. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PS1 MARC. PSI Xt42V. PS1 RXAK. PS1 36 000 NPHV. PS1 2 216 NSCR. PS1 5 089 CP2V. PS1 0 000 RCRC. PS1 1486 817 FPDE. PS1 0 661 SF6P.PS1 60.012 EXCU. PS1 0.923 FPGF. PS1 0.000 XHV. PS1 -12.191 RXFR.PS1 0.000 SHCU. PS1 1538 087 3 084 22 173 0 000 1476 213 114 253 0.395 0.995 200.854 0.000 48.454 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 27 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG TRAT. FIL CRFI. PSi CACU. PS1 TPHI. PS1 RSCS. PSi DEPT. NPDE. PS1 AQTM. PS1 CM2V. PSi RCAK. PS1 FSCE. PSi HVPV. PS! NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PSI SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG TRAT. FIL CRFI. PS1 CACU. PS1 TPHI. PSI RSCS. PS1 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 336 413 2 681 -999.250 8463.000 10142.000 1564 256 1 322 -12 172 0 000 2 186 156 803 29.794 53.917 5.050 0.000 158.266 0.744 0.389 19.472 0.468 18.567 17.221 0.334 O. 828 165. 427 2. 621 9.859 8463.000 BSAL.SIG CIRF.FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC.PS1 SIGM. R2P GR.PS1 CTM. PS1 BUST. PSi TPHI.SIG SIBH.R2P CS.PS1 NSCE.PS1 CHV. PS1 RCFR.PS1 RTDF.PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR. PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT.FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC.PS1 SIGM. R2P GR.PS1 CTM. PS1 BUST. PSi TPHI.SIG SIBH.R2P -999.250 CIRN. PS1 -999.250 DSIG. PS1 -999.250 NBAC. PS1 -999.250 SBFA. PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 TRAT. PS1 53.835 RDIX. PS1 65.918 XTM. PS1 3.000 BUSP. PS1 -999.250 TPHI.R2P -999.250 2096.700 2.730 201.218 0.000 0.000 0.095 36.343 79.311 1.121 12.053 0.000 4. 595 2. 327 O. 391 58. 759 5.154 66.107 15 959 17 243 42 908 67 627 3 000 0 741 62 402 TENS.PSi CRRA.PS1 CPSV. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PS1 MARC. PSi XI42V. PS1 RXAK. PS1 CIRN. PS1 DSIG. PS1 NBAC. PS1 SBFA. PS1 SBFA.SIG SBFA.FIL SIGM. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUSP. PS1 TPHI.R2P -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 71386.000 65.430 3.000 -999.250 37.000 2.662 5.065 0.000 1497.804 1.322 59.960 1.006 0.000 -12.243 0.000 0.719 -0.615 2231.096 47.270 5.137 48.414 15.641 0.811 97962.000 66.406 3.000 21.157 CIRF. FBAC. S FNA . SFNA. SFNA. SIBF. SIBF. TRA T . CRNI. FICU. RSXS . CCLC . NPHV. NSCR . CP2 V. RCRC. FPDE. SF6P. EXCU. FPGF. XHV. RXFR . SHCU. CIRF. FBAC. SFNA. SFNA. SFNA. SIBF. SIBF. TRA T . FICU. RSXS . CCLC. PS1 PS1 PS1 SIG FIL PS1 SIG SIG PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PS1 PSl SIG FIL PS1 SIG SIG PS1 PS1 PS1 PS1 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 745 534 2 998 8878 000 0 000 1569 825 0 145 12 217 0 000 1491 242 116 946 2 741 1 001 200 663 0 000 36.028 2.254 3084.904 22.306 0.763 22.609 81.717 1.904 O. 018 440. 365 2. 637 8878.OOO -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 28 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION ' O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUNk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11839.5 10170.5 RST $ LOG HEADER DATA DATE LOGGED: 10 -JUN- 98 SOFTWARE VERSION: 8Cl -205 TIME LOGGER ON BOTTOM: 1330 lO-JUN-98 TD DRILLER (FT): 11842.0 TD LOGGER (FT) : 11842.0 TOP LOG INTERVAL (FT) : 9700.0 BOTTOM LOG INTERVAL (FT) : 11842.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA!~VA RAY RST RES. SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER CGRS-A RST-A 8.500 11905.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 29 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: RST-A RUN IN SIGMA MODE DEPTH CORRELATED TO BHC SONIC LOG 4-MARCH-1982 TOOLS RUN WITH COILED TUBING PRESSURE AND TEMPERATURE RUN WITH CPLT FLOWING PASS DOWN RECORDED WITH PRESSURE AND TEMPERATURE, ALSO FLOWING SIGMA PASS RECORDED (WELL CHOKED BACK TO 6.9 ~4~ICFD) . WELL THEN SHUT IN AND 360 BBLS OF CRUDE PUMPED. 3 BASELINE PASSES RECORDED. TDT-P EQUIVALENT CURVES DISPLAYED FOR 1 BASELINE PASS FOR COMPARISON. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 3O TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 2 12 . 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS2 F/HR 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NPHV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS2 S 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FPHV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS2 S 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS2 PSIG 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS2 UA 1189310 O0 000 O0 0 7 1 t 4 68 0000000000 GDCU PS2 MA 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS2 UA 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS2 UA 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS2 UA 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 MA~C PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 XH~? PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 31 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) XPSV PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS2 MA 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS2 CPS 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1189310 00' 000 O0 0 7 1 1 4 68 0000000000 SIGM R2P CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 KHZ 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 KHZ 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS2 DEGC 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS2 DEGC 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 AMP 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 32 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RSXS PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI R2P PU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS2 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH R2P CU 1189310 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DBPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG TRAT. FIL CRFI.PS2 CACU. PS2 TPHI.PS2 RSCS.PS2 DEPT. NPDE. PS2 AQ~4. PS2 CM2V. PS2 RCAK.PS2 FSCE.PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XP5V. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 11839. 500 1555. 482 O. 661 -12.211 0.000 2.235 156.983 31.717 26.154 5 050 0 000 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 252.444 2.642 -999.250 8463.000 10170.000 1563.836 1.322 -12.231 0 000 2 217 156 790 29 971 44 776 5 050 0.000 172.416 0.880 0.409 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RzYRC. PS2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 SIGM. R2P GR.PS2 CTM. PS2 BUST. PS2 TPHI.SIG SIBH.R2P CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF. FIL IRAT. FIL 1905.770 2.769 201.339 0.000 0.000 0.216 44.238 70.514 1.091 12.056 0.000 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 208 609 66 895 3 000 -999 250 -999.250 1593.224 2.701 201.096 0.000 0.000 0.050 36.559 80.265 1.289 12.059 0.000 4.638 2.657 0.407 TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XM2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUSP. PS2 TPHI.R2P TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 ~2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 35.000 2.223 5.050 0.000 1486.817 0 661 59 356 0 925 0 000 -12 250 0 000 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 114118.000 67.871 3.000 -999.250 35.000 2.678 5.055 0.000 1491.700 1.322 60.081 0.996 0.000 -12.247 0.000 0.857 O.O04 2396.613 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. SIG CRNI. PS2 FICU. PS2 RSXS.PS2 CCLC. PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR. PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 1550.294 -0.473 12.187 0.000 1480.104 116. 812 1.184 O. 981 200.854 0.000 34.796 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 561.236 2.607 8878.000 0.067 1562. 501 - O. 253 12.209 O. 000 1489. 831 ll 7. 431 2 762 1 001 200 714 0 000 39 126 2 726 2992 456 17. 885 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 33 SFFA.PS2 14.609 SBNA.PS2 SFFAoSIG 0.308 SBNA.SIG SFFA.FIL 15.223 SBNA.FIL SFNC.PS2 11.734 SFFC. PS2 SIGM. SIG 0.263 SIGM. R2P TR~T. FIL 0.796 GR.PS2 CRFI.PS2 167.319 CTM. PS2 CACU~PS2 2.620 BUST. PS2 TPHI.PS2 7.898 TPHI.SIG RSCS.PS2 8463.000 SIBH. R2P 61.134 SBFA.PS2 5.239 SBFA.SIG 63.704 SBFA.FIL 12.303 SIGM. PS2 -999.250 TRAT. PS2 36.127 RDIX. PS2 66.406 XTM. PS2 3.000 BUSP.PS2 0.658 TPHI.R2P -999.250 48.645 SFNA.SIG 5.410 SFNA.FIL 50.995 SIBF. PS2 12.310 SIBF. SIG 0.807 TRAT. SIG 140420.000 CRNI.PS2 66.843 FICU. PS2 3.000 RSXS.PS2 -999.250 CCLC.PS2 0.587 17. 979 87. 640 1. 961 O. 017 448. 093 2. 665 8878. 000 -999. 250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION · O01CO1 DATE : 99/02/22 MAi~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SO?4NARY VENDOR TOOL CODE START DEPTH RST 11839.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI£~ELOGGER ON BOTTOM: STOP DEPTH .......... 10136.5 lO-JUN-98 8Cl-205 1330 lO-JUN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 34 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 11842.0 11842.0 9700.0 11842.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY RST RES. SATURATION $ TOOL NUMBER. CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11905.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: RST-A RUN IN SIGMA MODE DEPTH CORRELATED TO BHC SONIC LOG 4-MARCH-1982 TOOLS RUN WITH COILED TUBING PRESSURE AND TEMPERATURE RUN WITH CPLT FLOWING PASS DOWN RECORDED WITH PRESSURE AND TEMPERATURE, ALSO FLOWING SIGMA PASS RECORDED (WELL CHOKED BACK TO 6.9 ~4~ICFD). LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 35 WELL THEN SHUT IN AND 360 BBLS OF CRUDE PUMPED. 3 BASELINE PASSES RECORDED. TDT-P EQUIVALENT CURVES DISPLAYED FOR 1 BASELINE PASS FOR COMPARISON. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - C~ ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3 F/HR 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 36 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCFR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RCAK PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS3 MA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 Xlq2V PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CItY PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 37 NA~fE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFFA FIL CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SRNC PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIGMR2P CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 K~Z 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 KHZ 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS3 AMP 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI R2P PU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS3 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH R2P CU 1189310 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11839.000 CS.PS3 3765.690 TENS.PS3 31,000 NPHV. PS3 NPDE. PS3 1563.646 NSCE.PS3 2,793 CRRA.PS3 2,197 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 201.339 CPSV. PS3 5.060 CP2V. PS3 CM2V. PS3 -12.250 RCFR.PS3 0.000 RCLC. PS3 0,000 RCRC. PS3 RCAK. PS3 0.000 RTDF. PS3 0,000 FPHV. PS3 1496.583 FPDE. PS3 FSCE. PS3 2,294 FSCR.PS3 0,164 AQTF. PS3 0.661 SF6P. PS3 HVPV. PS3 156.738 BMCU. PS3 39.257 GDCU. PS3 59,356 EXCU. PS3 NBEF. PS3 30,894 FBEF. PS3 67.879 NPGF. PS3 1.001 FPGF. PS3 BSTR.PS3 28.909 BSPR.PS3 1,015 MARC. PS3 0.000 XHV. PS3 XPSV. PS3 5.050 XP2V. PS3 12,056 3q~2V. PS3 -12.211 RXFR.PS3 RXLC. PS3 0,000 RXRC. PS3 0.000 RXAK. PS3 0.000 SHCU. PS3 BSAL. PS3 -999,250 BSAL.SIG -999,250 CIRN. PS3 -999,250 CIRF. PS3 CIRNoFIL -999.250 CIRF.FIL -999,250 DSIG.PS3 -999.250 FBAC. PS3 IRAT. PS3 -999.250 IP~a~T. FIL -999.250 NBAC.PS3 -999.250 SFNA.PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 -999,250 SFNA.SIG SFFA.SIG -999,250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL 1564.943 -0,306 12.261 0.000 1489.106 117.579 1. 973 1. 001 200. 612 0.000 31.219 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 38 SFFA.FIL -999.250 SBNA.FIL SFNC. PS3 -999.250 SFFC. PS3 SIGM. SIG -999.250 SIGM. R2P TRAT. FIL -999.250 GR.PS3 CRFI.PS3 222.397 CIT4. PS3 CACU. PS3 2.646 BUST. PS3 TPHI.PS3 -999.250 TPHI.SIG RSCS.PS3 8459.000 SIBH.R2P DEPT. NPDE. PS3 AQTM. PS3 CM2V. PS3 RCAK. PS3 FSCE. PS3 HVPV. PS3 NBEF. PS3 BSTR.PS3 XPSV. PS3 RY~C. PS3 BSAL.PS3 CIRN. FIL IRAT. PS3 SFFA. PS3 SFFA.SIG SFFA.FIL SFNC. PS3 SIGM. SIG TRAT. FIL CRFI.PS3 CACU. PS3 TPHI.PS3 RSCS. PS3 10136. 000 1563. 646 0 661 -12 231 0 000 2 187 156 891 30 009 42 346 5 050 O. 000 187. 431 O. 726 O. 385 16. 321 O. 365 16. 841 13. 746 0.298 0. 773 168. 460 2. 622 6.198 8459. 000 CS.PS3 NSCE. PS3 CHV. PS3 RCFR.PS3 RTDF. PS3 FSCR.PS3 BMCU. PS3 FBEF. PS3 BSPR.PS3 XP2V. PS3 RXRC. PS3 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS3 SBNA.SIG SBNA.FIL SFFC. PS3 SIGM. R2P GR.PS3 CTM. PS3 BUST. PS3 TPHI.SIG SIBH.R2P -999.250 SBFA.FIL -999.250 -999.250 SIGM. PS3 -999.250 -999.250 TRAT. PS3 -999.250 271.212 RDIX. PS3 157275.000 68.359 XTM. PS3 68.848 3.000 BUSP.PS3 3.000 -999.250 TPHI.R2P -999.250 -999.250 3319.440 TENS.PS3 2.700 CRRA.PS3 201.339 CPSV. PS3 0.000 RCLC. PS3 0.000 FPHV. PS3 0.102 AQTF. PS3 36.218 GDCU. PS3 78.738 NPGF.PS3 1.172 MARC.PS3 12.056 X~42V. PS3 0.000 RXAK.PS3 4.385 CIRN. PS3 2.407 DSIG.PS3 0.385 NBAC. PS3 62.922 SBFA.PS3 5.106 SBFA.SIG 64.859 SBFA.FIL 13.964 SIGM. PS3 -999.250 TRAT. PS3 46.656 RDIX. PS3 64.941 XTM. PS3 3.000 BUSP.PS3 0.694 TPHI.R2P -999.250 35 000 2 624 5 060 0 000 1489 259 0 661 60 012 1 001 0 000 -12 248 0.000 0.731 0.604 2355.615 52.316 4.956 51.515 13.898 0.783 182853.000 65.796 3.000 -999.250 SIBF. PS3 SIBF. SIG TRAT. SIG CRNI.PS3 FICU. PS3 RSXS.PS3 CCLC. PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. SIG CRNI.PS3 FICU. PS3 RSXS.PS3 CCLC.PS3 -999.250 -999.250 -999.250 488.638 2.739 8878.000 0.057 1562.501 0.715 12.202 0.000 1489.106 117 387 3 058 1 001 200 763 0 000 38 576 2 601 2892 157 20.084 0.708 19.796 94.061 1.896 0.018 442.009 2.667 8878.0OO -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .008 SERVICE ' FLIC VERSION · 0 O1 CO! DATE . 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 39 **** FILE HEADER **** FILE NAlVZE : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NURIBER: 4 DEPTH INCREMENT: 0.5000 FILE SUN~N~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 11840.5 9943.0 RST $ LOG HEADER DATA DATE LOGGED: 10 - JUN- 98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 1330 lO-JUN-98 TD DRILLER (FT) : 11842.0 TD LOGGER (FT) : 11842.0 TOP LOG INTERVAL (FT) : 9700.0 BOTTOM LOG INTERVAL (FT) : 11842.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RES. SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER CGRS-A RST-A 8.500 11905.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 4O FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) .. GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS) .. NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: RST-A RUN IN SIGMA MODE DEPTH CORRELATED TO BHC SONIC LOG 4-MARCH-1982 TOOLS RUN WITH COILED TUBING PRESSURE AND TEMPERATURE RUN WITH CPLT FLOWING PASS DOWN RECORDED WITH PRESSURE AND TEMPERATURE, ALSO FLOWING SIGMA PASS RECORDED (WELL CHOKED BACK TO 6.9 N~4CFD). WELL THEN SHUT IN AND 360 BBLS OF CRUDE PUMPED. 3 BASELINE PASSES RECORDED. TDT-P EQUIVALENT CURVES DISPLAYED FOR 1 BASELINE PASS FOR COMPARISON. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR FLOWING PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PA GE: 41 TYPE REPR CODE VALUE 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CS FLO F/HR 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TENS FLO LB 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVFLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMFLO S 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CHV FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CP5V FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKFLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVFLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR FLO' 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF FLO S 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P FLO PSIG 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU FLO UA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU FLO MA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU FLO UA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF FLO UA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF FLO UA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 MARC FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 XHV FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 42 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) XPSV FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 XM2V FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKFLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU FLO MA 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL FLO PPK 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC FLO CPS 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC FLO CPS 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM FLO CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM R2P CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 GR FLO GAPI 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI FLO KHZ 1189310 O0 000 O0 0 9 i 1 4 68 0000000000 CRFI FLO KHZ 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CTM FLO DEGC 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 XTM FLO DEGC 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 FICU FLO AMP 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CACU FLO AMP 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BUST FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 43 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) RSXS FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI FLO PU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI R2P PU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC FLO V 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS FLO 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH R2P CU 1189310 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11840.500 CS.FLO 1875.000 TENS.FLO NPDE. FLO 1553.956 NSCE.FLO 2.209 CRRA.FLO AQTM. FLO 0.661 CHV. FLO 201.096 CPSV. FLO CM2V. FLO -12.191 RCFR.FLO 0.000 RCLC.FLO RCAK.FLO 2.000 RTDF. FLO 0.000 FPHV. FLO FSCE.FLO 2.240 FSCR.FLO -0.618 AQTF. FLO HVPV. FLO 157.227 BMCU. FLO 52.441 GDCU. FLO NBEF.FLO 30.294 FBEF.FLO 65.546 NPGF. FLO BSTR.FLO 24.578 BSPR.FLO 1.106 MARC.FLO XPSV. FLO 5.050 XP2V. FLO 12.041 X~2V. FLO RXLC.FLO 0.000 RXRC.FLO 0.000 RXAK. FLO BSAL.FLO -999.250 BSAL.SIG -999.250 CIRN. FLO CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.FLO IRAT.FLO -999.250 IRAT. FIL -999.250 NBAC. FLO SFFA.FLO -999.250 SBNA.FLO -999.250 SBFA.FLO SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC.FLO -999.250 SFFC.FLO -999.250 SIGM. FLO SIGM. SIG -999.250 SIGM. R2P -999.250 TRAT. FLO TRAT.FIL -999.250 GR.FLO 73.470 RDIX. FLO CRFI.FLO 311.469 CTM. FLO 87.402 XTM. FLO CACU. FLO 2.646 BUST.FLO 3.000 BUSP. FLO TPHI.FLO -999.250 TPHI.SIG -999.250 TPHI.R2P RSCS.FLO 8463.000 SIBH.R2P -999.250 DEPT. 9942.000 CS.FLO 3600.719 TENS.FLO NPDE.FLO 1566.697 NSCE.FLO 2.542 CRRA.FLO AQTM. FLO 0.661 CHV. FLO 201.339 CPSV. FLO CM2V. FLO -12. 231 RCFR. FLO O. 000 RCLC. FLO RCAK. FLO 2. 000 RTDF. FLO O. 000 FPHV. FLO FSCE. FLO 2.104 FSCR. FLO - O. 347 AQTF. FLO HVPV. FLO 157.227 BMCU. FLO 32.854 GDCU. FLO NBEF. FLO 26.463 FBEF. FLO 65.925 NPGF. FLO BSTR.FLO 66.952 BSPR.FLO 1.157 t4ARC.FLO XPSV. FLO 5.044 XP2V. FLO 12.047 X~2V. FLO RXLC.FLO 0.000 RXRC. FLO 0.000 RXAK.FLO BSAL.FLO 270.156 BSAL.SIG 5.560 CIR1V. FLO CIRN. FIL 0.286 CIRF.FIL 0.514 DSIG.FLO IRAT.FLO 0.365 IRAT. FIL 0.367 NBAC.FLO 34 000 2 164 5 079 0 000 1506 349 0 661 60 668 0.900 0.000 -12.231 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 229475.000 83.496 3.000 -999.250 29.000 2.491 5.069 0.000 1508.790 0.661 60.387 0.999 0 000 -12 231 0 000 0 282 6 215 2329 769 NPHV. FLO NSCR. FLO CP2 V. FLO RCRC. FLO FPDE. FLO SF6P. FLO EXCU. FLO FPGF. FLO XHV. FLO RXFR.FLO SHCU. FLO CIRF. FLO FBAC. FLO SFNA.FLO SFNA.SIG SFNA.FIL SIBF. FLO SIBF. SIG TRAT. SIG CRNI. FLO FICU. FLO RSXS. FLO CCLC. FLO NPHV. FLO NSCR. FLO CP2V. FLO RCRC. FLO FPDE. FLO SF6P. FLO EXCU. FLO FPGF. FLO XHV. FLO RXFR.FLO SHCU. FLO CIRF. FLO FBAC. FLO SFNA.FLO 1569.825 2.993 12.246 0.000 1493.531 123 464 0 000 0 967 200 127 0 000 26 991 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 673.916 2.803 8878.000 -0.038 1564.943 0.057 12.202 0.000 1497.155 124.487 3.213 0.999 200.577 0.000 30.011 0.514 2878.824 45.598 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 11:59 PAGE: 44 SFFA.FLO 44.117 SBNA.FLO 70.700 SBFA.FLO 53.081 SFNA.SIG SFFA.SIG 3.006 SBNA.SIG 4.387 SBFA.SIG 6.871 SFNA.FIL SFFA.FIL 43.932 SBNA.FIL 68.296 SBFA.FIL 65.753 SIBF. FLO S?NC.FLO 54.195 SFFC.FLO 48.916 SIGM. FLO 48.927 SIBF. SIG SIGM. SIG 1.964 SIGM. R2P -999.250 TRAT. FLO 1.509 TRAT. SIG TRAT. FIL 1.532 GR.FLO 37.079 RDIX. FLO 257933.000 CRNI.FLO CRFI.FLO 181.484 CTM. FLO 81.055 XTM. FLO 80.497 FICU. FLO CACU. FLO 2.597 BUST. FLO 3.000 BUSP. FLO 3.000 RSXS.FLO TPHI.FLO 50.504 TPHI.SIG 3.291 TPHI.R2P -999.250 CCLC. FLO RSCS.FLO 8463.000 SIBH.R2P -999.250 1 868 45 919 132 523 2 796 0 078 452 117 2 531 8878 000 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 99/02/22 ORIGIN : FLIC TAPE NAME : 99052 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, DS 15-02A, PRUDHOE BAY, # 50-029-20697-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ' 99/02/22 ORIGIN : FLIC REEL NAME : 99052 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, DS 15-02A, PRUDHOE BAY, # 50-029-20697-01