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186-080
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /'_~- p_~_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: r~ Diskettes. No. [3 Maps: [3 Grayscale items: [] Other, No/Type D Other items scannable by large scanner [] Poor Quality Originals: , ~. OVERSIZED (Non-Scannable) Othe [] Logs of various kinds TOTAL PAGES: /~5 NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: [] Other Isl Project Proofing By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl SCANNED BY: BEVERLY BRi~HERYL MARIA LOWELL Is~ ReScanned {done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: /' ~/J ~'/O ,~~''' ~ - Quality Checked '(done) RevlNOTScanned,wpd Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2725 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Milne Pt. 04/02/03 Color Well Job # Log Description Date Blueline Prints CD f{'-20..B ~.~-c~ L~ 23081 CH EDIT MGR 12/08/02 ~. 9-35A\Ct.~--~ ~ ~ 23050 RST 01108103 1 1 /.~O"~_~., O.S. 9-28A '~ C( ,~ -~ ~[_'~ 22515 RST 11/10102 ~. 18-05 ~.'~-~(~ 22411 MCNL 08/~9102 4 4 J~~ ~.S~-14A ~ ~%'~ 23100 SCMT 03105103 2 ~-30 =~-~ ~ =3078 SCMT 0=~ 3/03 ~IA~ 23087 OH EDIT ARC & IMPULSE (PDC) ~1/03102 1 j ~'~ ~-34A ~ ~,~ ~ 23087 MDVISION RESISTIVI~ 1~/03102 1 -- ~31A / ~ 23087 ~D VISION RESISTIVI~ ~1/03102 1 ~-31A~ 23087 MD VISION RESISTIVI~(BHP) ~/03/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ,~,..... ,..~..? Receive STATE OF ALASKA ~j~j~ ~I¢~&~ND GAS CONSERVATION COMMISSION W~['~OIVl~i'-[=~ll~ibN OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator-'-"--"~""~yr~.i. 7. Permit Number BP Exploration (Alaska)Inc. 186-080 3O2-338 3. Address ~- -'?~'"~' ' '~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612~~ ..... 50-029-21583-00 4. Location of well at surface 9. Unit or Lease Name 951' SNL, 221' WEL, SEC. 24, T11N, R14E, UM X=691539, Y= 5960912 Prudhoe Bay Unit At top of productive interval 3523' SNL, 5069' WEL, SEC. 24, T11N, R14E, UM X=686758, Y=5958218 10. Well Number At total depth 18-05 5234' SNL, 2391' WEL, SEC. 23, T11N, R14E, UM X=684201,Y= 5956444 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool RKB = 49' ADL 028307 12. Date Spudded 04/21/1986 ! 13' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband' 05/21/1986 11/19/2002 115' water depth' if °ffshore N/A M SL II 10' N°' °f C°mpleti°ns Zero 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 13~.,'H 8850 FTI 12965 8799 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run Sonic / CNL / GR, CBL ~:~, CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 2156# Poleset 13-3/8" 72# L-80 34' 3008' 17-1/2" 3000 sx CS III, 400 sx Class 'G' 9-5/8" 47# L-80 32' 10264' 12-1/4" 500 sx Class 'G' 7" 29# L-80 7919' 12500' 8-1/2" 970 sx Class 'G' 4-1/2" 13.5# N-80 12409' 12965' 8-1/2" Uncemented Slotted Liner 24. Perforations open to Production (MD+'I'VD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2#, N-80 11622'- 12406' None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT 8{ KIND OF MATERIAL USED 12425' P&A w/56.3 Bbls Cement, Held 900 psi 12100' Set CIBP 11622' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL'BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HouR RATE CORE DATA 2~, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. Form 10-407 Rev. 07-01-80 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sag River 10020' 8147' Shublik 10094' 8186' Sadlerochit 10255' 8261' ,.'-l~,l~ ~ ,-~ 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 82. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e "~0~~ ~ Title Technical Assistant Date 18-05 186-080 302-338 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Dave Wesley, 564-5773 INSTRUCTIONS (~ENERAL; 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 cementing and the location of the cementing tool. ITEM 27'- Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: 18-05A Accept: 12/02/02 Field: Prudhoe Bay Unit Spud: 12/10/02 APl: 50-029-21583-01 Release: 12/16/02 Permit: 202-219 Rig: Nabors 2ES Date : ........ : .......... : ....... ~....~..:.: : PRE-RIG WORK 11/16/02 DFF W/2.7 CENT, S. BAILER TO 12329' SLM. STOP DUE TO HAW. 11/19/02 MIRU DOCT #8 W/15752' OF 1.75" TS, 34.6 BBL VOL, 108K RF. MU 1.90" CRC, XO, 2.0" STGR, 2.25" BDN (7/8" BALL). CHANGE PACK-OFFS (PREVIOUS 2 JOBS HOT). LOAD AND KILL WELL W/2% KCL, WHILE RIH. PUMP 100 BBLS CRUDE DOWN BACKSIDE OF COIL FOR POSITIVE WHP, (400 PSI). TAG BO-I-FOM AT 12947' CTM. PUH TO 12502'. PUMP 14.6 BBLS 15.8# CEMENT OUT NOZZLE AND GET 200 PSI WHP BUMP BEFORE PUH LAYING IN CEMENT. PUMPED A TOTAL OF 56.3 BBLS CEMENT AND GOT 22 BBLS BACK IN RETURNS, 34.3 BBLS BEHIND PIPE. TOC AT 10313'. PULL TO SAFETY AT 9500'. SQUEEZE 2 MORE BBLS, BEHIND PIPE MAINTAINING 900 PSI WHP. RIH TO CLEANOUT TO 12425' WITH 1.5# BIO. 11/20/02 PLUG & ABANDON PERFS-CONTINUED. CLEAN OUT CEMENT PLUG TO 12425' CTMD, CONTAMINATING WITH 2 PASSES OF 1.5# BIO AND THEN 2 PASSES JE-B-ING WITH 2% SLK WATER. POOH AND FREEZE PROTECT WELL TO 2500' WITH 60/40. LEFT WELL SHUT IN WITH 700 PSI WHP. NOTIFIED DSO OF WELL STATUS. CREW TO PERFORM WEEKLY BOP TEST. JOB COMPLY. -.--- 11/25/02 DRIFTED & TAGGED W/2.50" CENT, SAMPLE BAILER @ 12,279' WLM. (SAMPLE OF PLASTIC COATING) A'FI'EMPTED TO TEST CMT. PLUG WITH TRI-PLEX. APPR. 46 BBLS OF DIESEL, TO NO AVAIL. NOTIFY DSO & RELEASE TRI-PLEX. L CANNED ! 6 2003 11/26/02 MIT TBG, FAILED W/LLRT OF .6 BPM @ 2000 PSI, MIT IA TO 3500 PSI, PASSED. 11/28/02 RUN 1: SET BAKER CIBP 2.652" AT 12,100 FT. RUN 2: STRING SHOT AT 11625 FT, LOADED WITH 240 GM EXPLOSIVES. RUN 3: CHC 2.375" SEVERING HEAD. CUT 3.5" TUBING AT 11625 FT. 11/29/02 ATTEMPT TO CIRC-OUT. TUBING, LOCKED UP AFTER 5 BBLS OF METHANOL. TUBING PUNCH: PUNCH THE INTERVAL 11505'- 11507' USING 9 MEDIUM CHARGES. TBG PRESSURE: 1200 PSI / 600 PSI IA BEFORE SHOT. NO CHANGE IN PRESSURES AFTER FIRING. DID NOT GO BELOW 11600' TO AVOID GETTING STUCK IN CUT PIPE AT 11625'. ALL SHOTS FIRED. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. 11/30/02 RIH WHILE CIRCULATING HOT DIESEL TO FILL TUBING. PRESSURE UP TUBING TO 3000. NO CHANGE IN lAP. DUMP IA TO LP FLOWLINE PRESSURE. NO CHANGE. TUBING-2453 IAP-442. MONITOR. ASSIST CTU W/ATTEMPT TO ACHIEVE CIRCULATION BETWEEN TBG & IA - PT COIL TO 4000 PSI. PUMPED 50 BBLS DSL TO DISPLACE MEOH IN COIL. PUMPED 172 BBLS DSL @ 120 - 150 DEG F DOWN COIL TO FILL TBG. 18-05A, Rotary Sidetrack Page 2 12/'01/02 CTU ASSIST - ATTEMPT TO CIRCULATE WELL DOWN TBG AND UP I.A. W/25 BBLS DIESEL (UNABLE TO CIRCULATE). FREEZE PROTECT FL W/70 BBLS DSL & 6 BBLS NEAT. UNABLE TO CIRCULATE. TUBING-2398 IAP-445. BLEED WHP TO 250 AND FREEZE PROTECT COIL AS POH. RIG DOWN AND STAND BY WHILE SLICKLINE UNIT PULLS DGLV. ABLE TO CIRC TBG TO IA. PULL RKED FROM STA-2. HBR CIRC FLUID THRU OPEN POCKET. SET DGLV-RK IN STA-2 AND PT TO CONFIRM GOOD SET. BLEED TBG/IA DOWN. T/I/O=20/100/0 (RIG PREP) IA FL @ SURFACE. BLED IA FROM 100 PSI TO 0 PSi IN 1.5 HRS. MONITORED IA PRESSURE FOR 30 MINS. IA PRESSURE STATED THE SAME. FINAL WHP'S 20/0/0. BP EXPLORATION Page I of 8 Operations Summa RePort . Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: REENTER+COMPLETE Start: 12/2/2002 End: 12/16~2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/16/2002 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase DeScription of OPerations 11/30/2002 13:00 - 00:00 11.00 MOB P PRE Bridal up blocks. Move camp and pits to DS 18. Move sub base off well. Remove derrick pins. Lower cattle chute. Lay down derrick. Move sub base to DS 18. Raise and pin derrick. Pin cattle chute. Hook top drive to blocks. Hang bridal lines. 12/1/2002 00:00 - 01:00 1.00 MOB P PRE Hang bddal lines and rig up floor. 01:00 - 22:30 21.50 MOB N WAIT PRE Rig on standby due to wells group prep. work on 18-05. Coil tubing service unit rigged up on 18-05. Circulated tubing to hot diesel. Attempted to circulate down tubing, out IA. Unable to circulate. RD coil tubing. RU slickline. Pull lower dummy GL¥. Able to circulate through lower GLM. Install DV in lower station. RD slickline. Remove flow lines and well house. Grade and level pad. Perform rig service while waiting on well. ~{~[~ ~ ~ '~Y '~ ~ 200~ Install strainer on mud pump. Adjust length oftop drive blower hose, service top drive. Change oil in centrifugal pumps. Inspect crown section. Work on BOP landings. Grease choke manifold. Slip new spool of drilling line onto drum and blocks. 22:30 - 00:00 1.50 MOB P PRE Lay mats. Spread herculite. 12/2/2002 00:00 - 02:00 2.00 MOB P I PRE Lay rig mats. Move and spot sub base over 18-05. Move pit I complex and camp. Hook up lines in interconnect. Take on I seawater. 02:00 - 03:00 1.00 MOB P PRE Lay herculite and spot pit complex. 03:00 - 04:30 1.50 MOB P PRE Spot cuttings tank, mud shack, and geologist shack. Berm rig. Hook up lines. Lay walkways. Spot camp. Move and spot shop. Hook up geronimo line. 04:30 - 06:00 1.50 RIGU P PRE Accept rig at 04:30. Hold pre spud meeting and install secondary annulus valve. ;06:00 - 13:00 7.00 RIGU P PRE Bleed 220 psi off inner annulus. Suck fluid out of tree. 13:00 - 15:00 2.00 BOPSUR P PRE ND adapter flange and tree. Vedfy tubing hanger threads and MU 5 3/4" RH ACME XO, 9 turns. 15:00 - 17:00 2.00 BOPSUR P PRE NU BOP. 17:00 - 17:30 0.50 BOPSUF P PRE RU to test BOP. 17:30 - 21:00 3.50 BOPSUR P PRE Test BOPE to 250 psi / 3,500 psi. Witness of BOP test waived by Chuck Sheve of AOGCC. 21:00 - 21:30 0.50 BOPSUR P PRE RD test equipment. 21:30 - 22:00 0.50 BOPSUR P DECOMP Pull blanking plug. 22:00 - 23:00 1.00 BOPSUR P DECOMP RU lubricator and pull BPV. 23:00 - 00:00 1.00 BOPSUR P DECOMP MU XOs and screw landing joint into tubing hanger. 12/3/2002 00:00 - 01:00 1.00 PULL P DECOMP Attempt to screw into tubing hanger. Bottom thread on XO gald. Dress threads and attempt to screw into hanger. Not able to screw into hanger. 01:00 - 05:00 4.00 PULL P DECOMP MU spear with double grapple and packoff. Spear tubing. Unseat tubing hanger. Attempt to circulate. Pressure up to 1,500 psi. No circulation. Attempt to pull tubing. Work up to max pull of 235 K. Tubing did not pull free. Work tubing and attempt to gain circulation. 05:00 - 05:30 0.50 PULL P DECOMP Release spear and LD spear assembly. 05:30 - 07:30 2.00 PULL P DECOMP RU eline and lubricator and test to 500 psi. 07:30 - 11:00 3.50 PULL P DECOMP RIH with tubing punch and shoot holes at 11,250'. Atempt to circulate. Pressure up to 1,000 psi. No circulation. Bleed pressure off and POH w! gun, all shots fired. MU gun #2 and start RIH. POH. 11:00 - 12:30 1.50 PULL P DECOMP Attempt to circulate down tubing with 3,000 psi. No circulation. Surge pressure on tubing. Swap hoses and attempt to Printed: 12/26/2002 10:13:47AM BP EXPLORATION page 2 of 8 Operations Summary Report . · . : Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: REENTER+COMPLETE Start: 12/2/2002 End: 12/16/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/16/2002 Rig Name: NABORS 2ES Rig Number: 2ES Date From- To Hours Task Code NPT Phase DesCriPti0n~fOPerations: '::ii: · 12/3/2002 11:00 - 12:30 1.50 PULL P DECOMP reverse circulate up to 3,000 psi. No circulation. 12:30 - 15:00 2.50 PULL P DECOMP RIH w/tubing punch (2" gun, 9 shots, 0 phasing) and fire gun at 11,021' to 11,023'. 15:00 - 19:00 4.00 PULL P DECOMP Pressure up on tubing to 2,750 psi. Pressure falling offto 550 psi. Continue to circulate hole clean with clean diesel at 3 bpm, 550 psi. 19:00 - 21:30 2.50 PULL P DECOMP Pump 50 bbl soap pill, displace well bore to clean seawater at 5 bpm, 975 psi. Obtained soap and seawater returns after 323 bbls pumped. Clean seawater after 388 bbls pumped. ~.~'~..~,--~f~f~i~' ~ f~,¥' '.! ~ 20.0~ Circulating uphole through GLM or possible hole in tubing near 4,800'. 21:30 - 22:30 1.00 PULL P DECOMP Screw into tubing hanger with landing joint. Unseat hanger and pull 40 K over. Set in slips. 22:30 - 23:30 1.00 PULL P DECOMP RU eline. 23:30 - 00:00 0.50 PULL P DECOMP RIH w/2 3~8" chemical cutter. 12/4/2002 00:00 - 02:00 2.00 PULL N DFAL DECOMP RIH to 2,300'. Lost GR signal from eline tool. POH and change tools. 02:00 - 06:00 4.00 PULL P DECOMP RIH with 2 3/8" chemical cutter. Fire chemical cutter at 10,470'. No indication on surface or from line tension that cutter fired. POH. Cutter hung up in GLM at 6,586'. Pressure up tubing and work cutter free. POH with 500 psi on tubing. No circulation at 500 psi. 06:00 - 06:30 0.50 PULL P DECOMP Latch onto landing joint and pull hanger to rig floor. Tubing came free at 210K. PU=175K. 06:30 - 07:00 0.50 PULL P DECOMP LD tubing hanger and eline. 07:00 - 10:00 3.00 PULL P DECOMP RU and break circulation. Well flowing. 100 psi shut in annulus pressure. Circulate through choke at 3 bpm, 400 psi. 10:00 - 14:00 4.00 PULL P DECOMP Screw top drive to tubing. Reciprocate and circulate at 6 bpm, 850 psi. 14:00 - 14:30 0.50 PULL P DECOMP RU casing equipment and spooling unit. 14:30 - 17:00 2.50 PULL P DECOMP Pull completion equipment. LD 4 1/2" tubing and dual encapsulated control lines. LD SSSV. Recovered 39 of 40 SS control line bands. 17:00- 17:30 0.50 PULL P DECOMP RD spooling unit. 17:30 - 18:30 1.00 PULL P DECOMP POH and LD 4,000' 4 1/2" tubing. 18:30 - 19:00 0.50 PULL P DECOMP Circulate to clear tubing of diesel at 8 bpm, 610 psi. Pump dry job. 19:00 - 19:30 0.50 PULL P DECOMP LD 474' of 4 1/2" tubing. Recovered 140 joints of 4 1/2" tubing. 19:30 - 20:00 0.50 PULL P DECOMP Change out handling equipment to 3 1/2". 20:00 - 00:00 4.00 PULL P DECOMP LD 3 1/2" tubing. 12/5/2002 00:00 - 01:00 1.00 PULL P DECOMP Continue to LD 3 1/2" tubing. Recovered 140 joints of 4 1/2" tubing, 193 joints of 3 1/2" tubing, 2 GLMs, 1 SSSV w/39 control line bands, 12.81' cut joint. 01:00 - 02:00 1.00 PULL P DECOMP Clear floor, LD casing tongs. 02:00 - 03:30 1.50 PULL P DECOMP Pressure test casing to 3,500 psi. Lost 200 psi in 20 minutes. Bleed off pressure and check surface equipment. Pressure test casing to 3,500 psi for 30 minutes. Lost 250 psi in 30 minutes. 03:30 - 04:00 0.50 BOPSUF P DECOMP Install wear bushing. 04:00 - 05:00 1.00 FISH P DECOMP MU overshot w/cut lip guide and mill control packoff, and 3 1/2" grapple, bumper sub, jars, 9 DCs, and accelerator. 05:00 - 10:00 5.00 FISH P DECOMP RIH picking up 4" DP to 7,928'. 10:00 - 11:30 1.50 FISH P DECOMP Circulate diesel and gas out at 10.5 bpm, 1,750 psi. Printed: 12./'26/2002 10:13:47AM BP EXPLORATION Page 3 of 8 Operations Summary Report : Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: REENTER+COMPLETE Start: 12/2/2002 End: 12/16/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/16/2002 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT- Phase Description of Operations 121512002 11:30 - 14:30 3.001 FISH P DECOMP Continue to RIH and PU DP to 10,456'. Break circulation every 1,000'. 14:30 - 16:00 1.50! FISH P DECOMP Circulate at 10 bpm, 2,015 psi. PU-180K, SO=140K, Rot=-155K, Tq. =7K 16:00 - 16:30 0.50 FISH P DECOMP Tag top of 3 1/2" tubing stub at 10,464'. Engage fish. Jar on tubing with 325K up. Fish came free. PU weight with fish=200K. 16:30 - 17:30 1.00 FISH P DECOMP Unable to circulate through fish. POH to 10,390'. Circulation obtained. CBU at 10.5 bpm, 2,115 psi. 17:30 - 18:30 1.00 FISH P DECOMP Monitor well. Clean oil based mud / KCI fluid from under shale shakers. 18:30-22:30 4.00 FISH P DECOMP Pump dry job. POH from10,390' to 314'. 22:30 - 23:30 1.00 FISH P DECOMP Stand back BHA. 23:30 - 00:00 0.50 FISH P DECOMP LD overshot with cut joint of 3 1/2" tubing. 12/6/2002 00:00 - 01:30 1.50 FISH P DECOMP POH and LD 3 1/2" tubing fish. Top cutjt 16.74'. Recovered 36 joints of tubing and one 12.57' cut joint. 1/4 of the tubing ~i{~/'.~.~ ~ ~ ¥ ~_ ~i 200~ circumference was not cut. Three of the joints that were previously shot with an eline tubing punch, at 11,021', 11,250', and 11,505' had 9 holes each. The holes in the joint at 11,505' were plugged. 01:30 o 02:00 0.50 FISH P DECOMP LD casing tongs. Clear rig floor. 02:00 - 03:00 1.00 FISH P DECOMP Pressure test casing to 3,500 psi for 30 minutes. Lost 150 psi. 03:00 - 05:30 2.50 FISH P DECOMP Clean ddp pan. Remove rotary table and clean out emulsified mud and solids that were circulated out of the hole. 05:30 - 06:30 1.00 FISH P DECOMP Break fish out of overshot and break down overshot assembly 06:30 - 08:00 1.50 CLEAN P DECOMP MU window mills, 1 joint HWDP, float sub, bumper sub, jar, DCs, 15 joints HWDP to 770'. 08:00 - 10:00 2.00 CLEAN P DECOMP RIH picking up 108 joints 4" DP to 4,131' 10:00 - 14:00 4.00 CLEAN P DECOMP RIH to 11,535'. 14:00 - 15:30 1.50 CLEAN P DECOMP Wash from 11,535' to 11,622'. Tag tubing stump at 11,622'. 15:30 - 16:30 1.00 CLEAN P DECOMP Circulate sweep around at 10.5 bpm, 2,700 psi. 16:30 - 17:00 0.50 CLEAN P DECOMP POH from 11,622' to 11,157'. 17:00 - 18:00 1.00 CLEAN P DECOMP Test casing to 3,500 psi for 30 minutes. Lost 100 psi in 30 minutes. 18:00 - 18:30 0.50 CLEAN P DECOMP RIH from 11,157'to 11,622'. 18:30 - 22:00 3.50 CLEAN P DECOMP Circulate sweep sround at 11.7 bpm, 2,770 psi. Still getting some oil based emulsion back. Circulate second sweep. 22:00 - 22:30 0.50 CLEAN P DECOMP Servicetop drive. 22:30 - 00:00 1.50 CLEAN P DECOMP POH from 11,622' to 8,265'. PU=190K, SO=135K. 12/7/2002 :00:00 - 04:30 4.50 CLEAN P DECOMP POH and stand back BHA. 04:30 - 05:30 1.00 STWHIP P WEXlT MU whipstock to window mills. Orient whipstock to MWD. 05:30 - 06:30 1.00 STWHIP P WEXlT RIH with BHA to 830'. Change elevators. Flow test MWD. 06:30 - 11:00 4.50 STWHIP P WEXIT RIH from 830' to 11,561'. 11:00 - 11:30 0.50 STWHIP P WEXlT Install blower hose. Orient whipstock. Tag tubing stump at 11,622'. Set whipstock 82 degress right of high side. Shear whipstock bolt. Top of window will be 11,604'. 11:30 - 14:00 2.50 STWHIP P WEXlT Displace well bore to 8.6 ppg Fie-pro mud. 14:00 - 00:00 10.00 s'rWHIP P WEXlT Mill window from 11,604' to 11,621'. Weight on mill 2K - 10K from 11,604' to 11,613'. Torque 6K- 10K. RPM 95 - 120. Flow rate 300 gpm. Penetration 10 - 25 minutes per foot. From 11,613' to 11,621' penetration rate slowed to 30- 62 minutes per foot. Increased weight on mill to 10K - 35K. 12/8/2002 00:00 - 04:00 4.00 STWHIP P WEXlT Continue to mill to 11,622'. Increased weight on mill to 30K - Printed: 12/26/2002 10:13:47 AM BP EXPLORATION Page 4 of 8 Operations Summa Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: REENTER+COMPLETE Start: 12/2/2002 End: 12/16/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/16/2002 Rig Name: NABORS 2ES Rig Number: 2ES Date From -To Hours Task Code NPT Phase DeScription~ofOperations -.~ : 121812002 00:00 - 04:00 4.00 STWHIP 3 WEXlT 35K. Pump sweep while milling. One foot of progress in the last 140 minutes. Metal cuffings, formation sand, and cement in samples. Mills quit. 04:00 - 04:30 0.50 STWHIP :) WEXIT Monitor well, static. POH to 11,440'. Pump dry job. Blow down surface equipment. 04:30 - 06:00 1.50 STWHIP :) WEXIT Slip and cut ddlling line, service top drive. 06:00 - 10:00 4.00 STWHIP :) WEXIT POH from 11,440' to 812'. 10:00 - 10:30 0.50 STWHIP :) WEXIT Stand back BHA. 10:30 - 11:00 0.50 STWHIP :~ WEXIT LD MWD and window mills. Starter mill worn fiat and upper stdng mill is 1/16" under gauge. 11:00 - 12:00 1.00 STWHIP ~ WEXIT MU new starter mill, bit sub, and new full gauge stdng mill. 12:00 - 15:30 3.50 STWHIP 3 WEXIT RIH to 11,622'. 15:30- 17:30 2.00 STWHIP :) WEXIT Millfrom 11,622'to 11,630'. Weight on mills6K-20K. RPM: 100 - 110. Torque: 8K - 10K fi*lbs, 400 gpm. Penetration rate: 3 - 17 minutes per foot. 17:30 - 18:00 0.50 STWHIP 3 WEXIT Work through window. 18:00 - 19:30 1.50 STWHIP 3 WEXIT Circulate sweep around at 11 bpm, 2,350 psi. 19:30 - 20:00 0.50 DRILL :) WEXIT Perform FIT test to 10.0 ppg EMW. (8.6 ppg mud, 8,630' TVD, 629 psi surface pressure). 20:00 - 00:00 4.00 STWHIP P WEXIT POH from 11,630' to 785'. 12/9/2002 00:00 - 01:00 1.00 S'I'WHIP P WEXIT LD BHA. String mill in gauge. 10% wear on starter mill. 01:00 - 02:00 1.00 BOPSUF. P PROD1 Flush BOP stack of all metal. Flush choke and kill line. 02:00 - 02:30 0.50 BOPSUF,P PROD1 Pull wear bushing. Set test plug. 02:30 - 06:00 3.50 BOPSUF.P PROD1 Test BOPE to 250 psi / 3,500 psi. Hydril will not test. Change out Hydril element. Witness of test waived by John Crisp of AOGCC. ' 06:00 - 15:30 9.50 BOPSUF.P PROD1 Change out Hydril element and test Hydril to 250 psi / 3,500 3si. RD test equipment. Pull test plug and install wear bushing. 15:30- 19:00 3.50 DRILL =P PROD1 MU BHA. Upload MWD. Load RA source. 19:00 - 23:00 4.00 DRILL P PROD1 RIH to 11,526'. 23:00 - 23:30 0.50 DRILL P PROD1 Service top drive and install blower hose. 23:30 - 00:00 0.50 DRILL i P PROD1 Orient to 82 degrees dght of high side. PU=165K, SO=135K. 12/10/2002 00:00 - 00:30 0.50 DRILL ~P PROD1 RIH With 4" Drill Pipe From Mast To 11,580' - Orient Motor And Bit Travel Thru Window To 11,627' 00:30 - 02:00 1.50 DRILL P PROD1 Wash Under Gauge Hole From 11,627' To 11,630' · .... 02:00 - 00:00 22.00 DRILL P PROD1 Obtain Slow Pump Rates - Directional Drill Ahead Froth 11 ,~ To 12,368' - Weight On Bit 7K To 20K - With Pum,,p~ 114 Strokes Or 279 GPM - Off Bottom Pump P~re At 1945 Psi. & On Bottom Pump Pressure ~si._- Top Drive NED 1 200', RPMAt0 To 50 - Off Botto~~. Bottom.... Torque At 10K - St~eight At155K -Drag Up At ! 180K And Dr~,.Q~n At 135K 60' To 11,700' - (Zone 4 N) - ........... Very Fine Sand With J Common Siltstone-Siltstone Light Is Tan And Hard ~~ 11,700' To 11,930' - (Zone 2A) - Medium Grain Sand - ROP Average 50 To 100 FPH - Sand Is Clean 20 To 25 APl GR And Well Sorted Probably Gas Swept - High Resisitivity 11,930' To 12,170' - (Zone 1 B) - Predomiately Fine Grain Sand ' - Clean To Slightly Shaley Increasingly Silty Near Base - Probable Oil With Gas Under Reams - Several Thin Siltstone Interbeds Printed: 12/26/2002 10:13:47 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~-- [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack Name of Operator BP Exploration (Alaska) Inc. 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 951' SNL, 221' WEL, SEC. 24, T11 N, R14E, UM At top of productive interval 3525' SNL, 5068' WEL, SEC. 24, T11N, R14E, UM At effective depth 4937' SNL, 2010' WEL, SEC. 23, T11N, R14E, UM At total depth 5233' SNL, 2383' WEL, SEC. 23, T11N, R14E, UM 6. Datum Elevation (DF or KB) RKB = 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 18-05 9. Permit Number 186-080 10. APl Number 50- 029-21583-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13444 feet Plugs (measured) true vertical 8849 feet Effective depth: measured 12965 feet Junk (measured) true vertical 8802 feet Casing Length Size Cemented Structural Conductor 110' 20" 2156# Poleset Surface 2974' 13-3/8" 3000 sx CS III, 400 sx Class 'G' Intermediate Production 10232' 9-5/8" 500 sx Class 'G' Liner 4581' 7" 970 sx Class 'G' (Liner Tieback) Slotted Liner 556' 4-1/2" Uncemented Slotted Liner MD TVD 110' 110' 3008' 2837' 10264' 8264' 7919'-12500' 6570'-8774' 12409'-12965' 8770'-8799' Perforation depth: measured Slotted Section: 12501'-12953' RECEIVED Open Hole Section: 12965'- 13444' true vertical Slotted Section: 8774'-8798' OCT ,.~ 0 2002 open Hole Section: 8799'- 8849' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 4474'; Anchorage Packers and SSSV (type and measured depth) 7" Baker External Casing Packer at 12483'; 4-1/2" TIW 'SS' packer at 12409'; 4-1/2", Camco 'Bal-O' SSSV at 2236' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation / November 15, 2002 ' !6. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Dave Wesley, 564-5773 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: []Oil []Gas []Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Bill IsaacsonjL~ U,,. ~ ~ Title Senior Drilling Engineer Conditions of Approval: Notify Commissio,~,,/so representative m,~.witness Plug integrity /~ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Approved by order of the Commission Date '~(,)/Z ¢~/0'~. bp To: From: Subject: Reference: Winton Aubert - AOGCC Date: October 24, 2002 Dave Wesley, Jr. - BPXA GPB Rotary Drilling 18-05 Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-21583-00 Approval is requested for the proposed P&A of PBU well 18-05. Well 18-05 is a high angle Zl B well drilled in 1986 and completed with 4 1/2" slotted liner and 4 1/2" x 3 1/2" tubing string. It has been a great well, on full time until 1995, cycled with 50/~. on-time until 2Q02, less than 20% on-time since then. It has a cumulative lifetime production of 5.5 bo, but has now gassed out and is ready for sidetrack. The latest estimate of remaining value is 81 mbo.~ A tubing caliper was run in July of 2002. The 4 1/2" tubing is in good to poor condition with up to 80% wall penetration at five spots in the 4000' to 4500' depth range./The 3 1/2" tubing is in generally poor condition with five penetrations up to 70% from 5500' to 8700'.'The tubing condition is clearly an added risk to this sidetrack. In spite of this, the well passed an inner annulus integrity test on August 6, 2002 and meets integrity screening requirements. The well is currently shut in with no well work opportunity. As a result of the tubing condition, it will be beneficial to sidetrack with a rotary rig and replace the tubing. The 18-05A sidetrack is currently scheduled for Nabors rig 2ES, beginning around December 01,2002, after the completion of the 1-32A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Pre-Ri.q Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. NOTE: Slick line made an attempt to drift tubing on 7/29/02. Greatest depth attained was 12,120' MD, due to high inclination of -81°. Coiled Tubing entered the well on 8/19/02 for a logging run, and made a tag at 12,930' MD. 2. R/U coil tubing unit. Plug and abandon, with cement, the 8 ½" hole, including the fish, at TD of the well. Also, P&A the slotted liner interval from 12,951' up into the solid 4 ½" tubing to -12,425' MD, plus squeeze away -23bbls throughout the slotted liner interval, filling the 8 ~" 'hqle X 4 W' liner annulus. The estimated cement volu/me required to perform this P&A is('5~4b~ls(. Do not leave cement shall/ewer than 12,425' MD."Circulate the tubing clean above the cement"--'~-' 'top. 3. Drift and tag'the top of the cement to confirm the tubing is clear to the TIW Overshot Seal Assembly, at 12,394' MD. 4. Fluid-pack the 4 %" × 3 %" tubing and 9 5/8" X 7" × tubing annulus to surface. Test the integrity of the cement plug and the 9 5/8" X 7" casing to 3500psi for 30 minutes. ~' 5. Rig up E-line. RIH and chemical cut the 3 ½", 9.2# tubing at -11,625' MD, in the middle of a joint. 6. 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 the top 2,200' with diesel. 18-05 Application for Sundry RiR 7. Test the 9 5/8" pack-off and tubing hanger seals. Function ail Lock Down Screws. 8. Bleed casing and annulus pressures to zero. 9. If necessary, level the pad. Please provide total well preparation cost on the handover form. Operations: 1. MI/RU Nabors rig 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. Pull 5 W' X 4W' X 3 ¼" tubing from the pre-rig tubing cut at -11,625' MD. POOH L/D completion. 5. M/U 6" milling BHA and P/U 4" drill pipe. RIH and drift down to the remaining tubing stump. Displace the well to milling fluid. POOH. 6. P/U and RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whip stock, as desired, and set on tubing stump. Mill window in 7", 29.0# casing at _+ 11,600' MD, plus an additional -20' formation. Pull up into 7" casing and conduct an FIT to 10.0ppg EMW. POOH. 7. RIH with 6" DidGPJRes/Den/Neu assembly. Kick off and drill the 6" section to planned TD of 13,656' MD. 8. Run and cement a 4 W', 12.6#, L-80 production liner. POOH. 9. PJU and RIH with Halliburton 2 %" dpc perforating guns. Perforate per Halliburton recommendation. POOH. 10. Set packer and test the tubing and annulus to 3500psi for 30 minutes. 11. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 12. Freeze protect the well to -2200' and secure the well. 13. Rig down and move off. Post-Ri.q Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Estimated Pre-rig Start Date: 11/15/02 Estimated Spud Date: 12/01/02 Dave Wesley, Jr. Operations Drilling Engineer 564-5773 18-05 Application for Sundry WELLHEAD = FMC ACTUATOR = Axelson KB. ELEV -- 49 BF. ELEV = 20.8' KOP = 1,400' Datum TVD = 8800' SS 4 1/2", 12.6~, L-80 tbg. I.D. = 3.958" @ 4,473'. 18-05 Current SAFETY NOTES: Fish left @12967' during w ell completion on 07/05/86 I 25' I-'J 5 1/2" X 4 1/2" Tbg XO; ID = 3.958" I2236' I-I "'~'~"~'~°"A"°sssv"°=~'~'~"l 3,008' I-'J 13 3/8", 72#, L-80, Casing; I.D. = 12.347"I GAS LIFT MANDRELS ST IVE) ']'VD DEV TYPE VLV LATCH PORT DATE 1 3891 3501 43° ~ DV RK 0 7/9/1986 2 6586 5500 37° MMIG-2 RKED RKP 0 7/24/1986 4,474'I-J4 1/2"X 3 1/2" Tbg XO; ID = 2.992" 7,~' I-I~ ~,,x ~,, Baker A Lnr Hngr ?,~32'I-I~o~omo, Baker Tieback extension Minimum I.D. =2.813" @ 9815'. 3 1/2" OTIS 'X' Nipple 9,815' I--J 3 1/2" OTIS'X' Ldg Nip. ID= 2.813" 9,926' H 9 5/8"X7" Baker A Liner Hanger ~,~3~ I-I ~'' Baker Tieback Seal assembly 9 5/8", 47#, L-80 casing,iD: 8.681" I 3 1/2", 9.2#, N-80 tubing I.D.= 2.992" 12,393' 12,394' I--I 12,397' I-'1 12,409' 3 1/2" TEN Overshot Seal Assembly TEN Polished Riser w/2.813" I.D. 'X' Profile 7" X 4-1/2" TEN SS Pkr ID= 2.813" 12483' 147" Baker Ext Csg Pkr; I.D. = 6.200" J I/ 7", 29~, L-80 Liner, I~ I/ ID = 6.184" 12,500' PERFORATION SUIVIVIA RY REF LOG: Array Sonic on 5/22/86 ANGLEATTOP PERF: 88°@ 12500' Note: Refer to Production DB for historical perf data 4-1/2"I SLTDI 12502-12951 07/10/86 I 12,502' 14Top of 4 1/2" Slt'd liner; I.D.: 3.958" I J 13,444' J-~8 1/2"Open hole TD 12,967' H Fish - Bit, bit sub, 12 .its 4 3/4" drill I/ pipe, and bumper jars. DATE REV BY COIV~IENTS DATE REV BY COIVIVIENTS 07/09/86 ORIGINAL COIVE~LETION 01/02/01 SIS-QAAI CONVERTED TO CANVAS 02/01/01 SIS-LG REVISION 10/12/01 CH/tlh CORRECTIONS 09/20/02 DEW ReCreated in C7 PRUDHOE BAY UNIT WELL: 18-05 FERMIT No: 186-0800 AP1 No: 50-029-21583-00 SEC 24, T11N, R14E, 952' FNL, 221' FEL BP Exploration (Alaska) 18-05 Pre R.o Condition during w ell completion on 07/05/O6 i WELLHEAD = FMC ~'~R~ .......... ~-~-o'~' -- ---~~- - i'~7~'~'= ........................... ~'--~ I 25' H 5 1/2"X 4 1/2" Tbg XO; ID = 3.958" "~:.--_'.i~..;..:i'_;;L.; '.'~.!._..,.°io_'__-~- I 2236' I-I "-~/~" ~MOO.^.-o sssv..D = ~'~"1 Datum IVD = I~,~"~ ...... ~'~0-0~ss j i~ I 3,oos' I-I ~/~'',~#,'-~°, ca.i..;..~.= ~'~"~"1 GAS LIFT MANDRELS ~'~' ST rVD TVD DEVi TYPE VLV LATCH I:~RT DATE . 1 3891 3501 43° ' IVNIG DV RK 0 7/9/1986 2 6586 5500 37° MMIG-2 RKED RKP 0 7/24/1986i ~1 4,474' I-I 4 ~/~..x~ ~/~"~xo;,D=2.~" I ~ -- ~1 7,919' Id 9 5/8"X7" Baker A Lnr Hngr I ~1 7.932' I-I ~o~omo, Baker Tieback extension I ~,i~m,.D.=2.813"@ I I- I 9,8~s' H 3~/2"O~S'X'LdgNip.,D=2.S~3" 9815'. 3 1/2" OTIS 'X' Nipple ; ~1 9,926' H ~ ~..x ~,,Baker A LnrHngr I ~ ~1 9,935' I--I ~''Baker Tieback Sealassembly I i 9 5/8", 47#, L-80 casing, -- ID = 8.681" 10,264' : ~---z._--- Pre rig tubing cut at -11,625' MD. / -~1 12,394' Id 31/2"TIWOvershotSealAssembly I ~ ~/~,.,..~. ~o,.~,.. ~2.3.3' I, ~1- ~1 ~.3.~" I-I ~v ~o.~.e. ~se. w/~.~" ,.~.'X' ~o~i,. I I.D.= 2.992" ~' ~'~¥op of P&^ Comont plu~ at ~ 12,425' MD / ~--~1 12483' I-I>,:~--~~¥~: ~:---~.~oo,, I /112,502' ,--14T°P of 4 1,2" SIt'd liner; I.D. =3.958" ] 7", 29~, L-80 Liner, -- 12500' '~JC~<':;~'~/ .... ID= 6.184" ' ~%%<~ F12 967' ~'~ Fish-Bit, bit sub, 12 its43'4" ~""'1 ~i': pipe and bumper jars "~Z.i.~ I '-'-' J/ , · PER FO RATION SUMMARY ~%~~ r ~'~7965';--~ d41,2,,, 12.6#, L-80 Liner ; I.D. = 3.958" RE~ LOG: Array Sonic on 5/22/86 "'%.~-~,~%."~. "~ , \ \'~'~ 12 951' Bottom of 4 1/2 Sltd hner ID 3958 ] [ [ [ P q[ ^~ I ,,~'.=~=~ ~ I 14-~/~,,Isu~l ~s0~-~s~ I o I o~/~0/~ I ~:-~==' .... : :=-':" ..... == = ,, DATE REV BY OObWIENT8 DATE REV BY OOIV~/IENT8 PRUDHOE BAY UNIT 07/09/86 ORIGINAL C;OMPLETtON 09/20/02 DEW Proposed Pre rig work WELL: 18-05 01/02/01 818-QAA OONVERTED TO CANVAS PERMIT No: 186-0800 02/01/01 $1S-LG REVISION AP1No: 50-029-21583-00 10/12/01 GH/tlh OORREGTION8 8EO24, TllN, R14E, 952' FNL, 221' FEL 09/20/02 DEW ReOrented in 07 BP Explorntion (Alnskn) ST rv~ TVD DEV TYPE VLV LATCH PORT DATE 1 3891 3501 43° IVtV~ DV RK 0 7/9/1986 2 6586 5500 37° MMIG-2 RKED RKP 0 7/24/1986, ~CANNE,~ NNV a 5 ?NN? AECO ALASKA, INC. F".O. BOX t e(.).360 ANCHORAGE, ALASKA 995te DATF · 4-i t-ge REF-EREiNCE~: ARCO MAGNETIC TAF'E(S) WITH · -34 3-23-9(~- 5-.4 3-'22-9(,") 5--J~.A .3--J-9~' 8-5 2-'24-?e 8-~ 8 2-25-?(~ CNL (3 PASS) ICL.(6 ) FASS /L ~q 'rD'r-F' (6 PASS), RUN ~ ,.JOB:~4249 JOB~4247 JOB:~'75'TS3 JOB4:737t 7 JOB:~73'? ~ 8 F'LE:'ASE S'IGN AND RE::I'URN I'HE AI'I'ACHED COPY AS' RECEIPT OF DATA. RECEIVED BY ................... ..-~-.--~ HAVE: A NICE DAY! ,S'AL [..Y HOFFECKER ATO- i 529 TRANS~. 9e~ 39 APR 1 8 Alaska Oil.& Gas Cons. Commission D I $ T R I CENTRAL FILES (CH) CFIEVRON D & M I'AHMAS BROWN (OH) EXXON HARAI'HON MOBIL PHILLIPS PB WELL FILES BF'X STATE OF ALASKA TEXACO AI"I_AS ATLAS $CH SCH SCH A N C: i"i 0 F': A (.; F_:, A L A 3.' K A .......... , "x~ "'.t- · CO ........ HOLE F..'. ~:. r I:_ h E.~.~U,:. AR CA ;.~ ~'-u iNALS PLEASE ,S'i.Gi',I. ANi) RETLJRN THE ATTACHED C:OF'Y AS RE:CEIF'T OF' DA'TA. F.:ECE I VED BY ¢'¢~[~k'~! HAVE A NICE'DAY! RECEIVED '!" R A N £' :~ 9 (') ,.~"?'7 MAR - 81990 Alaska Oil & Gas Cons. Comm~ssloJ. ¢ C:ENTRAL FILES · ~ C 1-.t E V R 0 N D & M ~l: ,-.,~:'x'r~::'~,~ ~"I ON. , ~.,..... EXF'LORATVON~. . · ~ EXXON M A F;.: A 'i" I--t 0 N :..- MOBIL '"- PHILLZF-'S F'B ~[::I._1.. F':I:LE$ F..' & D · .-"' BF:'X '"' STA'f'E or: ALA;'.:."KA '"' ]" ~::' Y A C 0 '11' ~ ',;' STATE OF ALASKA ' AL (A OIL AND GAS CONSERVATION CC AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdoWn [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other X:] _t,~vlD 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska_. Inc. RKR be' Feet 3. Address 8. Unit or Property name P.0. Box 100360 Anchorage~ AK 99510-0360 Prudhoe Ba), Unit 4. Location of well at surface 7. Well number 952' FNL, 221' FEL, Sec.24, TllN, R14E, UM 18-5 At top of productive interval 8. Approval number 1701' FSL, 111' FWL, Sec.24, TllN, R14E, UM (using MWD) 282 At effective depth 9. APl number None 50-- n~q-~'~ At total depth 10. Pool 43' FSL~ 2385' FEL~ 5ec.23~ TllN~ R14Et UM (using MWD) Pru{lh0~ B~y Of] pool 11. Present well condition summary Total depth: measured, 13444'M[) feet Plugs (measured) None true vertical 8849'TVD feet Effective depth: measured None feet Junk (measured) None true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 2156# Pol eset 110 'MD 110 ' TVD Surface 2974' 13-3/8" 3000 sx CS i II & 3008'MD 2829'TVD 400 sx Class G Production 10232' 9-5/8" 500 sx Class G 10264'MD 8265'TVD Liner/Tieback sleeve 4581' 7" 970 sx Class G 7919'-12500'MD 6571'-8775'TVD Slotted liner 556' 4-1/2" Open Hole Completion 12409'-12965'MD 8771 '-8800'TVD Perforation depth: measured Open Hole Completion true vertical Tubing (size, grade and measured depth) REC:EIYED Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary N/A Naska 0il & I]as Cons, C0mml&fi0rl Intervals treated (measured) AiIohorage Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Inj. ection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run XqMWD 15. I h'ereby certify that the forego~--~ is true and correct to the best of my knowledge . Signed (~ TitleAssoc~ate Engineer Date ~-~-~ Form 10-404 Rev. 12-1-85J (Dani) SW02/69 Submit in Duplicate ARCO Alaska, loc F'.O. Box Anchorage, Alaska 99510 DATE' February~° .-,,"z t987 REFERENCE' ARCO Cased Hole Final 2-i0 ?-i9-86 Perf. Record Run i, 5" 4-4 7-i7-86 F'erf. Record Run i, 5" 9-t -/ -,-_o~_o,~., ,. , ,.,,., CEI' Rut, t , ~""..," t8-5 5-23-86 [;BT Run t, 5" i8-5 6-25-86 CBL Variable Densit'y Run i, 5' $ch $ch $ch $ch F'Lease sign and return the attached copy as receipt of data. Received By A NICE DAY! HAVE Ro~anne Peek AT0-t529 TRAN$~.~'°~tt8~ Approved -- E" //' ~'~.~,.-,,x - ~ ]~-¢/~ , :~a Oil ~ Gas Cons. Commi~sJ: Anchc:.~ge DISTRIBUTION · ,,-Ce~ntra L Fi Les · ..'"' Chevr oi~ D & M ~ Ex tension ExpLoration ~~ EXXO~ Mara ~hon ~ Mob i L ~ F'hi L L ip.s F'B We l l R & D '"'.,,- $oh i o ~ Sta~e of ~~ Texaco FiLe~ ALaska ARCO Alaska, P.O. Box t Anchorage, A 99510 I)ATE' February 2 O, t987 REFERENCE' ARCO Cas'ed Hol. e Final '>-t8 6-27-87 MuLti--Finger C;aLiper Ru¥'~ t, ~"' 1t-9 6-25-86 CET Run t, 5' t ~_.o¢.,~ ,~, 6--7-86 CH I)IL. Run t , 5" t.8-5 6-25-86 MuLl'i-Finger Caliper Run t ";" ~'c h $c h 5'ch Z,c h · PLease .~ign and return the attached copy as' receipt of data, Received By_ HAVE A NICE DAY! Rosanne Peek AT0-t529 TRANS $87114 Approved '- DISTRIBUTION Gas Cons. c0mmissi0~ Anchorage $ Phi llips F'B WeLL Fi les R & D $ $ohio -'~-~ . "~- ,~_,~ .j.., -. . -.. Texaco (:'~ F;; E: I) (:'~ I. a .'.-;.' k a, :[ 'n c:, I::' ,. O, I-~ (::, x i 0 (.) ?!: 6 0 c: o ,:~- "i (-) I>(~TEi' F:'ebi-ua;-y c;,~ , i°,~,,'°'"' I:;' II ...:' I::' It ..:- (~'iP l:~ i" C)V ~:.~ cJ .......................................................................... (J ,_'-i .4.,..:':i ,. P ,. (] ,. B o x 'i (') (') S 6 (') 1:7 i I. ARCO Alaska, h~ L..,~ Prudhoe Bay~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 22, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 18-5 Permit No. 86-80 Enclosed is the Completion Report detailing work completed on the above-mentioned wel 1. Very truly yours, D. F. Scheve DFS/SPK:sd Enclosures cc: Standard Alaska Production Company File: PI(DS 18-5)W4-3 RECEIVED OCT 2 4 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' '-' ~-":; STATE Of ALASKA ~"', ALASK~IL AND GAS CONSERVATION b~,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ~ 7. Permit Number ARCO Alaska, Inc. 86-80 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21583 ,,, 4. Location of well at surface 9. Unit or Lease Name 951' FNL, 221' FEL, Sec. 24, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1701' FSL, 111' FWL, Sec. 24, TllN, R14E, UM (using MWD)* 18-5 , At Total Depth ~ ~ ¢~,..:. ~.; 11. Field and Pool 43' FSL, 2385' FEL, Sec. ~"4', TllN, R14E, UM (using MWD)* Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool L 49' RKBI ADL 28307 ALK 2317 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 04/21/86 05/21/86 07/09/86 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD} 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13445'MD, 8849'TVD None YES [~ MWD NO [] 2236 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run Sonic/CNL/GR, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~A H-40 Surf. 110' ' 30" 2156# ?olege/ 13-3/8" 72.0# L-80 Surf, 3008' 17%" 3000 sx CS 111 & 400 s:[ Clas~ G 9-5/8" 47,0# L-80 Surf. 10264' 12%" 500 sx Class G 7" 29.04~ L-80 7919' 12500' 8~." 970 sx Class G 4%" 13.5# N-80 12409' 12965' 8~." Uncemented slotted 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Slotted Liner a~"/~,, 1 ~,.06, 1 9~,~q, - . 12500'-12953' (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8726'-8749'(SS) DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7/20/86 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GA'S~MCF WATER-BBL CHOKESIZE IGAS'OILRATIO 7/20/8~ 12 TEST PERIOD I~ 1975 1264 ~ ~nI ~'.~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 887 750 24-HOUR RATE ~ 3950 2528 0 28.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ~ Data will be revised after the Gyro is r~n. OCT 2 4 1986 Alaska Oil & Gas Cons. Commission Anchorage ,,. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in du~cate.~ 29. GEOLOGIC MARKERS NAME To be submitted W MEAS. DEPTH hen gyro is run. TRUE VERT. DEPTH 30. F~RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form . 0-407 , ~ STATE OF ALASKA - , ALASK~ OIL AND GAS CONSERVATION (..~MMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 86-80 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-21583 , 4. Location of well at surface 9. Unit or Lease Name 951' FNL, 221' FEL, Sec. 24, T11N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1701' FSL, 111' FWL, Sec. 24, T11N, R14E, UN (using MWD)W 18-5 At Total Depth 11. Field and Pool 43' FSL, 2385' FEL, Sec. 23, T11N, R14E, UM (using MWD)* Prudhoe Bay Field i ' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 49' RKB ADL 28307 ALK 2317 , 12. Date Spudded4/21/86 13. Date T.D. Reacheds/21/86 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 1161N°' °f C°mpleti°ns7/09/86 N/A feet MS L 1 17. motalDepth(MD+mVD) 18.PlugaackDepth(UD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121.Thickness of Permafrost 13444'MD, 8849'TVD None YES F~X MWD NO [] 2236 feetMD 1900' (Approx) 22. TYpe Electric or Other Logs Run Soni c/CNL/GR, CBL ,, 23. CASING' LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ITOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED z0*' ~1.5# H'40 Surf 110' 30" 2156 # Poleset 13-3/8" 72.0# L-80 Surf 3008' 17-1/2" 3000 sx CS Ill & 400 sx (:lass G 9-5/8" 47.0# L-80 Surf 10264 ' 12-1/4" 500 sx C1 ass G 7" 29.0# L-80 7919i 12500' 8-1/2" 970 sx Class G 4-1/2" 13.5# N-80 12409' 12965' 8-1/2" Open hole completion . , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , 4½"/3½" 12406 ' 12409 ' Open hole completion 26. ACID, FRACTURE, CEMENT sQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ..... 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FloWing, gas lift, etC.) ' · Date of Test Hours Tested PRoDUCTIoN FOR oIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD !~ I Flow Tubing Casing Pressure CALCULATED' OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ '28.''. CORE DATA "Brie~ description of iithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. NonekD(RIVED OCT 2 0 1986 Alaska 0ii & Gas Cons. Commission Anchorage Rev. 7-1-80 ° 29. ' GEOLOGIC MARKERS' FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted whe gyro is run. N/A 31. LIST OF ATTACHMENTS HWD (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge : INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". Form 10-407 Teleco Oilfield Se~ ,s of Alaska Inc. [ TELE£O] 6~ 16 Nielson Way Anchorage, AK 99502 (907) 562-2646 May 23, 1986 JOB #494 TAK ARCO ALASKA WELL: DS 18-5 PRUDHOE BAY NABORS 26-E Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to ARCO. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Eno l osures RECEIVED JUL 2 8 1986 A ~t, ll~T COMPANY TELECO OILFIELD SERVICES JOB 494 SURVEY CALCULATIONS ***************************************** Date 05/22/86 Page 1 Company: ARCO ALASKA Well: DS 18-5 Location: PRUDHOE BAY Rig: NABORS 26-E TELECO Job # 494 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.30 degrees 31.30 degrees 242..16 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS , DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **************************************************************************************************** TIE-IN 450.00 0.0 189.5 S 09 30 W 450.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD 927.00 5.4 212.0 S 32 00 W 926.18 18.07 22.61S 8.50W 24.16 S 20.600W 0.995 1078.00 7.6 216.2 S 36 12 W 1076.20 33.16 36.76S 18.08W 40.97 S 26.187W 1.490 1289.00 8.4 225.0 S 45 00 W 1285.14 60.44 59.04S 37.17W 69.76 S 32.195W 0.692 776.00 4.2 201.1 S 21 06 W 775.71 7.82 11.33S 2.86W 11.68 S 14.175W 1.369 596.00 1.8 189.5 S 09 30 W 595.97 1.39 2.26S 0.38W 2.29 S 9.558W 1.233 TELECO Job # 494 TAK 05/22/86 Page 3 ill I Ill TELECO Job # 494 TAK 05/22/86 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **************************************************************************************************** 1512.00 11.8 235.2 S 55 12 W 1504.66 98.63 84.08S 67.13W 107.59 S 38.601W 1.717 1700.00 14.2 237.7 S 57 42 W 1687.82 140.70 107.45S 102.3'7W 148.41 S 43.611W 1.311 1920.00 18.7 234.9 S 54 54 W 1898.77 202.65 142.01S 154.18W 209.61 S 47.353W 2.076 2110.00 24.0 238.0 S 58 00 W 2075.66 271.45 180.22S 211.80W 278.10 S 49.606W 2.851 2291.00 2'7.2 239.1 S 59 06 W 2238.87 349.49 221.02S 278.51W 355.55 S 51.565W 1.787 2514.00 30.9 233.1 S 53 06 W 2433.79 457.10 281.37S 368.33W 463.50 S 52.623W 2.110 2705.00 34.0 235.2 S 55 12 W 2594.94 558.56 341.38S 451.38W 565.94 S 52.899W 1.727 2941.00 37.7 237.0 S 57 O0 W 2786.20 695.98 418.45S 3573.00 42.8 239.4 S 59 24 W 3268.40 1103.19 633.55S 566.08W 703.95 S 53.527W 1.630 912.99W 1111.28 S 55.242W 0.843 4642.00 42.5 242.2 S 62 12 W 4050.37 1831.86 986.61S S 57.532W 0.212 4202.00 43.3 241.5 S 61 30 W 3728.05 1532.35 845.30S 1286.50W 1539.35 S 56.693W 0.241 1550.58W 1837.85 5271.00 44.7 246.1 S 66 06 W 4505.84 2265.26 1175.69S 1940.85W 2269.17 S 58.794W 0.552 5743.00 41.2 245.8 S 65 48 W 4851.27 2586.10 1306.72S 2234.48W 2588.52 S 59.681W 0.743 6307.00 39.5 245.4 S 65 24 W 5281.08 2950.60 1457.58S , 6575.00 36.7 244.0 S 64 O0 W 5491.96 3115.79 1528.24S 2567.03W 2951.98 2716.51W 3116.88 S 60.412W 0.305 7249.00 37.7 244.3 S 64 18 W 6028.81 3523.04 1705.92S 7818.00 34.6 244.3 S 64 18 W 6488.21 3858.40 1851.28S · S 60.639W 1.093 3083.24W 3523.71 S 61.045W 0.151 3385.73W 3858.81 S 61.331W 0.545 TELECO Job # 494 TAK 05/22/86 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE ~ SEVERITY feet deg deg deg/min · feet feet feet feet feet deg deg/100 ' 10830.00 75.6 242.2 S 62 12 W 8436.69 6031.12 2824.22S 5329.00W 6031.12 S 62.078W 1.967 10960.00 76.7 237.7 S 57 42 W 8467.81 6157.21 2887.40S 5438.23W 6157.23 S 62.034W 3.473 11084.00 75.8 239.1 S 59 06 W 8497.28 6277.39 2950.51S 5540.81W 6277.43 S 61.965W 1.315 11206.00 74.8 237.3 S 57 18 W 8528.24 6395.11 3012.69S 5641.10W 6395.18 S 61.895W 1.646 11328.00 74.6 239.4 S 59 24 W 8560.43 6512.52 3074.43S 5741.27W 6512.63 S 61.831W 1.668 11425.00 74.1 240.5 S 60 30 W 8586.60 6605.85 3121.20S 5822.12W 6605.98 S 61.805W 1.207 11540.00 74.8 240.8 S 60 48 W 8617.43 6716.61 3175.51S , 11661.00 75.9 240.5 S 60 30 W 8648.03 6833.64 3232.89S 11781.00 77.4 239.1 S 59 06 W 8675.74 6950.29 3291.62S 11900.00 78.6 238.7 S 58 42 W 8700.48 7066.50 3351.74S 12042.00 80.2 232.7 S 52 42 W 8726.60 7205.12 3430.36S 12135.00 81.1 232.4 S 52 24 W 8741.71 7295.59 3486.15S 12227.00 82.1 232.4 S 52 24 W 8755.15 7385.30 3541.64S 12391.00 86.2 233.8 S 53 48 W 8771.86 7546.37 3639.57S 12578.00 88.3 232.7 S 52 42 W 8780.83 7730.88 3751.32S 12761.00 87.1 232.4 S 52 24 W 8788.17 7911.16 3862.51S 5918.69W 6716.75 6020.73W 6833.80 6121.64W 6950.48 6221.30W 7066.74 6336.55W 7205.50 6409.40W 7296.14 6481.54W 7386.04 6611.97W 7547.49 6761.62W 7732.53 6906.78W 7913.44 S 61.785W 0.659 S 61.766W 0.940 S 61.733W 1.688 S 61.686W 1.061 S 61. 571W 4.303 S 61.458W 1.019 S 61. 347W 1. 089 S 61.169W 2.640 S 60. 979W 1. 268 S 60.785W 0.676 12945.00 85.6 232.0 S 52 00 W 8799.89 8092.02 3975.05S 7051.87W 8095.05 S 60.591W 0.844 TELECO Job # 494 TAK 05/22/86 Page 5 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG. DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE. SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' · ***, ** ****, *** ** ** ******** ***** ****** ************************** ********************** **************. 13126.00 84.7 231.7 S 51 42 W 8815.19 13251.00 83.8 231.3 S 51 18 W 8827.71 13401.00 83.5 231.3 S 51 18 W 8844.30 8269.46 4086.46S 7193.70W 8273.36 S 60.401W 8391.68 4163.88S 7291.03W 8396.25 S 60.270W 8538.10 4257.03S 7407.43W 8543.55 S 60.114W 0.524 0.787 0.204 TE~ZCO 0 i 1 ~ i el d Serv i VERTIC^L PROJECTION 20OO 4000 6000 I-- LLI ca 8000 I U 0 2000 4000 6000 8000 10000 12000 10000 12000 14000 16000 1 BO00 VERTICAL SECTION Get) TEL£CO 0 i 1 ~ i e 1 d PLAN VIEW Services g6C10 8000' 6400 4800 3200 1600 0 _.%-__ . ~.. i .....i_,I '- ~ .'E~ -4 .... --.[. 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' --t- J ..... ~--~--~-~ .... · ~ t I ~ i , ; : ' J J · I l..... , L , .,-. ...,..._ ~. ,,.. ,_..1_., ....... .~_..,_ ...... ~,.-..L. ~.~.~..L-=--..! ...... ---t---l-,.----., ..... ,'---'~'- t"'f ..... ;",, ~-"~ ......i !i"i-'''/ ' ~' '" i' ~ 4 il ~ ' .-~i-~ ~j ~j~' :L,' ..,J~J~r' : ~' ' ,_.J-. -., ..... -.+4 ....... ~- ................. 4 , -t'-t' , , , ,, i.. ' , . ~ , ' ' ............. ' ' t .--,- ......... , ,....--~-..,.-- ..... ~--'-k --~-,- .... . ......... ,--- -~----+-,--~---.----.-,----*,~,,,,--~'~ .... -..4,-- ~..L_-L-...~ ' .4.- i - i ~.-~.; ---.I..--.~-+--- ,---t---1---4,-~ ---.4.---i----.~-.,+- ..... ~ .... t---~- --- ' ' ' : ~ ..j._..J ~ ' .. ~ ' ~ --.I- .... 't'" .... i.-- +.- l---.t--.+--.T--I ...... - i-"'"-' ...... r-"- i-"T .... "r- - f ~ · ,._~_L._L.L.. r.i_:[-"~_L._,,.._....~ ...... __-:h__~~.~_L-- .... WEST (~t) 1600 3200 4800 v 8000 9800 12800 GREAT LAND DIRECTIONAL DRILLING INC. REF'ORT OF SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. C 0 P P A N Y DRILL SITE 18 WELL NO. 5 W E L !... N A f"~ [:. PRI. JDHOE BAY L. 0 C A 'i" I 0 N AL486D15 ~IWD & SINGLE SHOT 5-21-86 ,.! 0 E; N U ?1 r:?, E R T Y I::' E S U R V E Y D A T E RIKE G~TES DZRECTZON~L SUPERg]SO~~~ N A ~"~ E ]" I T I... E S I G N A T U 450FT 13401 FT D E P "i' I"I I N 'T' E F;.'. V A I... F' I:;:. O fq T 0 4-21-86 5-21-86 D A't" Ii!: S U F;..' V E Y T A K E N F" R O l"q T 0 THIS IS A RECO~D OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FIL. ES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST: ALL SURVEYS ARE CONFIDENCE. OCT 2 0 1986 1 ~aska 0il & Gas Cons. Commission Anchorage 3REAT [_AND OIRECTIONAL DRILLING, INC ' 1 ient .... ' ,.,* t & & · , · , · , · dell. ............... : ]lo.~ure Oirection...' ~agnetic Declination: ]ara file name ...... : ARCO ALASKA, INC. DRILL SITE 18 WELL N0.5 S 62.17 W 31 deg 15 rain E OStS-5.DAT RECORD [Well assumed Comput at ion Survey date Method RK8 Height. OF SURVEY vertical to 450.0) 5'-27-86 RADIIJS OF CURVATURE 5-22-86 MWD TOOL READINGS 49.0 ft dEAS DRIFT DEPTH OG MN 450 0 596 'L 48 / ,e_, 4 1.') 927 5 30 1078 7 :?6 1289 8 24 1512 11 48 1708 14 12 1.920 18 42 2ilo 24 8 .. .., 12 '2509 30 54 2705 34 0 2941 37 42 3573 42 48 4202 43 18 464'2 42 30 5271 44 42 5743 41 12 6307 39 30 6575 37 0 7249 37 42 7818 :?4 36 8100 34 0 8447 34 48 TRUVERT SUBSEA SECTION DEPTH DEPTH DIST 450. O0 401. O0 O, O0 595. ',-)8 546.98 1.39 775.72 726.72 7.82 926. [7 877. 17 1.8. 18 076. 18 1027. 18 33,:78 1285. 1'2 1'236. 12 613,66 1504.64 1455,64 98.84 1687.80 ~638.80 140.92 1898.74 1849.74 202,87 ')0~c' C, 4 20')6 64 '~'" · _ ,.~. ~ . 2'238.85 2189,85 349.72 '~4')9 39 '" _ .- ,_ . ,.380. :]9 454,91 2594.77 '2545.77 559.03 2786.03 2737.03 696.44 .- b8. '23 3') 19. 23 1103.65 3727.88 3678.88 1532.81 4050.19 4001.19 1832.31 4505.67 4456,67 2265.73 4851,18 4802.10 2586.72 5280.91 5231,91 2951.36- 5491.35 5442· 35 3117.10 '6027. 14 5978· 14 3525· 79 6486.54 6437.54 386 i. 20 6719 , 50 6670,51] 4020.05 7005.81 6956.81 4215.61 RE(] T I ON ANGLE t]. 1313 E 9.51] W '21. lO W 32. O0 W :16. 2 O W S 45, i] 0 W S 55,..'"0 W S 57,70 W S 55,00 W S 58.00 W RELATIVE COORDINATES FROM WELL-HEAD O.-O0 N 0.00 E · ~ ' S 3 8 '2. ,b 0.. W I1.33 S '2. '' ~3b W '" S ,' 2 · 74 8 56 W 36.99 S !8. 2I W 59·27 S 37.30 W 84.32 S 67·26 W 107,69 S 102.50 W 142.19 S 154.34 W 180.36 S 212.00 W 59. lO W 221. 15 S 278.71 W 53·10 W 280.16 S 366·51 W 55.20 W 341,74 S 451,74 W 57,00 W 418,81 $ 566,44 W 59,40 W 633,91 $ 913,35 W ',~ 61.50 W S 62·00 W S 66.10 W ',3 65·00 W S 65·40 W 845.66 S 1286.86 W 987.42 S 1558.69 W 1177.18 S 1948.62 W 1310.27 S 2233.33 W 1463.43 S 2564.81 W S 64.00 W 1534.33 S 2714.80 W S 64.00 W 1713.58 'S' 3082.32 W S 64.30 W 1859.92 S 3384.35 W S 63.40 W 1929.95 S 3526.99 W S 68,40 W 2009,98 S 3705,89 W CLOSURE DISTANCE OG MN S 0.00 N 0 0 0 E 2·29 S 9 30 0 W 11.69 S 14 9 50 'W '24.29 S 20 37 36 W 41.23 S 26 12 37 W 70.03 S 32 11 107.86 S 38 34 148.67 S 43 35 209.86 S 47 20 278.34 S 49 36 10 W 47 W 1'2 W 45 W 38 W 355·79 S 51 34 4 W 461,32 S 52 36 22 W 566.44 S 52 53 34 W 704.45 S 53 31 17 W 1111.78 S 55 14 15 W 1539.85 S 56 41 21 W 1838.38 S 57 30 45 W 2269.75 S 58 45 32 W 2589.32 $ 59 36 1W 2952.95 S 60 17 30 W 3118.38 S 60 3526.62 S 60 3861.75 S 61 4020.50 S 61 4215,88 $ 61 31 34 W 55 43 W 12 30 W 18 46 W 31 33 W DOG LEG ,::leg/' 1 ) O. 000 I. '233 1.334 0.863 1.39'2 O, 389 1. 537 1.279 '~ 049 2.802 1,773 1. 846 I ,6~'~ \ 1 5 8.826 O. 176 O. 189 0. 476 0.748 0.303 0.952 fl. 104 O. 545 0.235 0. 523 ~ILL SITE 18 WELL NO.S S-27-86 qEAS DRIFT DEPTH DG MN 8670 :35 24 8890 38 48 9089 4'[ 30 9'2:~1. 43 c, 4 9457 413 4'2 9647 46:36 (~771 9897 54 42 10148 62 6 102:31 64 10407 71 42 10495 74 6 10587 73 54 10678 73 42 10769 74 24 108:30 75 36 10960 76 42 11084 75 48 11206 74 48 11:]'28 74:36 11425 74 6 11540 74 48 11661 75 54 11781 77 24 11900 78 :)6 1'2135 81 6 12391 86 12 12578 88 18 12761 87 6 12945 85 36 TRUVERT SUBSEA SECTION DEPTH DEPTH DIST ,'188.26 71'". . , ~' 3sj 26 434:3 St 7363.70 7314.70 4476. 18 7515 79 ~ '' ~" ... / 4bb., Si 4604.44 '7620. 14 7571, 14 4700,50 7787. 28 7738.28 4852.35 7924.70 787,5.70 4983.43 $006. !._9 7957. 19 5076.84 8082.09 80;33,09 517..-. ,:~J 8 '21:3.5 '2 8164. S '2 5:391. O '2 8'251. 14 8'20'2. 14 5465,00 8317,45 8268,45 5627.89 8343. 32 8294.32 571!.99 8368.68 8319.68 5800.41 8:]94.07 8:]45.87 5887.79 8419. 07 8370.07 5975.29 8434.86 8385,86 6034,21 8465.98 8416,98 6168, 30 8495.45 8446.45 6280.48 8526.41 8477.41 6398.28 8558.60 8509.60 6515.60 8584.77 8535.77 6608.93 8615.68 8566.6fl 6719.68 8646.20 8597.20 6836.70 867::1.91 8624.91 6953.35 8698.65 8649.65 7869.58 8740.06 8691,06 7299.43 8768. 36 8719.36 7550.77 8777.3:3 8728.33 7735.28 8784.68 8735.68 7915.56 8796 . 39 8747. ::19 8096.41 RECORD OF SURVEY DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD S 63.60 W 2062.12 S :3823.00 W S 62.60 W 2122,15 S :]941.32 W 'S 64.60 W 21'~'' 9 ,s, I S 4056.24 W '.;.67.50 W 2'~.18....'"8. 13 4144.2.2_ W S 62.:30 W '2'28'2,77 S 4281.90 id S 63.30 W !3 6'~ "' · ' · ." O W '3 62.20 W S 62.90 W S 62 '~ · ...0 W 62.60 W 61.50 W 61.20 W 61.50 W 6'2. '20 W S 62,20 W S 57.70 W S 59.10 W S 57.30 W S 59.30 W 60.58 W 60,80 W 60.50 W 59.10 W 59.10 W 2:342.69:3 4:]98.49 W 2385,46 S 4481.54 W 2432,35 S 4570.48 W '2530.8:3 ',3 4760.06 W 2564.94 S 4825.72 W 2640.40 S 4970.07 W · 2679.82 S 5044.36 W 2722.22 S 5121.97 W 2764.12 S 5198.66 W 2805.40 S 5275.80 W 2832.88 S 5327.92 W 2896.07 S 5437.15 W 2959.18 S 5539.73 W 3021.36 S 5640.02 W 3083.19 S 5740.14 W 3130.03 S 5820.94 3184.33 S 5917.51 3241.71S 6019.55 3300.44 S 6120.45 3360.22 S 6228.33 52.90 W 3489.50 S 6412,00 W 53,80 W 3641,32 S 6616,06 W 52.70 W 3753.07 S 6765.71 W 52.40 W 3864.25 S 6910.87 W 52,80 W 3976.80 S 7055.96 W CLOSURE '-' DISTANCE OG MN S 4343.69 S 61 39 2'8 W 4476.33 S 61 42 2 W 4604.56 S 61 46 12 W 4700.57 S 61 50 29 W 4852.39 S 61 56 13 W 4983.47 S 61 ,57 35 W 5076.87 S 61 58 27 W 5177.42 S 61 S8 43 W 5391.04 S 62 O S W 5465.02 S 62 0 31 W 5627.91 S 62 I 12 W 5712.01 S 62 1 14 W 5800.44 !3 62 0 37 W 5887.82 S 62 0 2 W 5975.31 S 61 59 54 W 6034, 23 S 62 O 1 W 6160.34 S 61 57 30 W 6280.55 S 61 53 24 W 6398.32 S 61 49 19 W 6515,77 S 61 45 31 W 6609.12 S 61 43 56 W 6719.89 S 61 42 52 W 6836.94 S 61 41 46 W 6953.62 S 61 39 52 W 7069.91 S 61 37 20 W 7300.02 S 61 26 40 W 7551.91 S 61 tO 22 W 7736.95 S 60 58 55 W 7917.86 S 60 47 17 W 8099.47 S 60 35 38 W DOG LEG deg/100 0.771 1.556 1.4 I 95 3,118 3,749 ~., · ! / 8 2.956 2.388 4.380 2.962 0.371 O. 375 l. 049 1.9"7) 3 3,. 1. 286 1.600 1.533 1.255 0.655 0.939 1,672 1.008 2,786 2.023 1. 267 0.676 0.843 ~ILL '.SITE 18 WELL NO.S S-27-8£, dEAS DRIFT )EPTH DG MN L3126 84 42 L3251 83 0 I 340 1 82 313 RECORD TRUVERT SUBSEA SECTION ' DIRECTION DEPTH DEPTH OIST ANGLE 8811.69 8762.69 8273.84 8825.09 8776.09 8395.97 8844,02 8795.02 8542,10 S 51.70 W S S 1. 30 W S 5l. 30 W OF SURVEY RELATIVE COOROINATES FROM WELL-HEAO 4088.20 S 7197,78 W 4165.57 S 7295.04 W 4258.60 iS 7411.17 W CLOSURE DISTANCE DG MN S 8277.77 S 60 24 15 W 8400.57 S 60 16 23 W 8547.58 S 60 7 3 W DOG LEG de9/lO0 0.524 1.39F) 0 3 >,ILL SITE 18 WELL N0.$ DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 5-27-86 ,lEA S. )EPTH TRU VER DEPTH T SUB SEA DEPTH MD-TVO DIFF. VERTICAL CORRECT RELATIVE COORDINATES FROM WELL-HEAD 49 49 0 0 0 0.00 O. O0 149 '149 100 0 0 O. O0 O, O0 '249 '249 '20 II 0 I] 0.00 I]. II 0 :349 349 30 II I] 0 ITt. II II Ij. 00 4'49 449 4013 0 I] 0.00 0. O0 549 649 749 850 950 549 649 749 849 949 1049 1149 1 '249 t 349 1449 1.549 1649 I749 1849 1949 '~; 049 2149 2249 '* 349 2449 2549 2649 2749 '",: 849 2949 1051 1t52 125:3 1:]54 145c 500 600 ,-..f .,' t] I] 80 0 9130 1000 [100 1200 1300 1400 1500 1600 1700 1800 1900 2O0O 2100 2200 2:]00 2400 2500 ~600 2700 2800 2900 1558 1660 1764 1868 1974 9 tl 15 19 25 32 42 54 68 83 102 123 146 175 206 2081 2191 2303 2417 253'2 0 0,46 ',.~ 0.95 W 0 4,24 '3 0.65 W I] 9,77 S 0.98 W 1 16,8'2 S 4.69 W 0 24.66 S 9.75 W :34.56 S 15.46 W 45. 14 S 23.84 W 57.28 S 31.16 W 66.54 $ 44.21 W 80.29 S 55,70 W 3 89.80 S 75.06 W 2 103.43 S 93.78 W 4 116.52 S 116.27 W 4 133.02 S 141.02 W 6' 152.61 S 168.99 W 7 tO 12. 14 15 19 21 23 29 31 -~5t 277'2 2895 3024 3155 176.32 S 200.85 W 198.51S 248.77 W 223.90 S 283.27 W 253.33 ~ 328.96 W 287.38 S 376.09 W 326.07 S 426.01 W 363.52 S 482.78 W 405.93 S 541.65 W 446.62 S 609.01W 492.12 S 677,-58 W ILL SITE 18 WELL NO.5 OATA INTERPOLATED FOR EVEN FEET OF lEAS. TRIJ VERT SUB SEA MO-TVD VERTICAL ~EPTH DEPTH DEPTH DIFF. CORRECT :3286 :3049 :300fl 237 3417 3149 .3 tOO 268 3548 3249 3200 299 3684 3349 3380 :~ 35 3828 3449 3400 371 :39 ,57 3549 3580 408 4894 36 49 :3680 445 4231_ 3749 :3788 482 4:367 3849 3808 518 4504 :]949 3900 555 31 31 36 4640 4778 ¢917 5055 5193 37 37 .! 36 37 4049 · 40110 591 36 4149 4!00 629 38 4249 4200 668 39 4349 4380 7136 38 4449 4400 744 38 5330 4549 4500 781 5467 4649 4600 818 5683 4749 4780 854 5748 4849 4800 891 5871 4949 4900 922 600:3 5049 5000 954 6!34 5149 5100 985 6 265 5 '~ ' · .49 5200 1016 6394 5349 5300 1045 6521 5449 5400 1072 6648 5549 5500 1099 677:] 5649 5600 t t 24 6899 5749 5700 t tSO 7025 5849 5800 1176 715 1 5949 5900 1202 37 37 36 37 31 32 31 31 29 27 27 25 26 26 26 SUB SEA OEPTH RELATIVE COORDINATE:; FROM WELL-HEAD 539.24 S 747.32 W 587.99 S 818.17 W 638.37 S 890.89 W 672,38 $ 977.92 W 720.66 S 1057.66 W 769.69 S 1137.18 W 819.44 S 1216.47 W 855.09 S 1304.22 W 899.78 'S 1386.15 W 944,48 S 1467.57 W 989.19 S 1548.48 1031.53 S 1632.12 t077,86 S 1714.56 1125.89 S 1796.99 1175.63 S 1879.39 1194.04 S 1978.53 W 1232.77 S 2064.72 W 1271,26 S 2149.10 W 1309.47 S 2231.63 W 1345.96 S 2309.70 W 1382.24 S 2387,03 W 1418.36 S 2463.68 W 1454.31 S 2539.64 W 1486.39 S 2614.44 W 1520.08 S 2685.42 W 1553,48 S 2754.06 W 1586,'78 CS 2822.32 W 1620.17 S 2890.79 W 1653,67 CS 2959,47 W 1687.26 CS 302.8.35 W 5-27-86- RILL dEAS. ]EPTH SITE 18 %4ELL N0.5 DATA INTERPOLATED FOR EVEN TRU VERT SUB SEAi MO-TVO DEPTH DEPTH DIFF. 7276 6049 6000 1227 7400 6149 6100 1251 7524 6249 6200 t275 76 48 6349 63130 1299 7772 6449 6400 1323 7894 6549 6500 1345 8015 6649 6600 1366 8136 6749 6700 1387 8257 6849 6 $01] ! 408 8378 6949 6988 1429 8500 8622 8746 8872 9002 7049 ° 7000 1451 7149 7100 1473 7249 7200 1497 7349 7300 1523 7449 7400 155:] 9134 / a 4',,-J 75110 1585 9270 7649 7600 1621 9405 7749 7708 1656 9542 7849 7800 1693 9684 7949 7908 1735 100 FEET OF VERTICAL C 0 R R E C T 24 24 '24 24 21 21 22 22 24 26 30 32 36 35 37 42 9842 8049 8000 1793 58 1.0025 8149 8100 1876 83 1..0 226 8249 8200 1977 10 l 10516 8349 8300 2167 190 10889 8449 8400 2440 273 I 1292 8549 8500 2743 303 11673 8649 8608 3024 281 12216 8749 8700 3467 443 SUBSEA DEPTH RELATIVE COORDINATES FROM %4ELL-HEAD 1.720,83 S 3097.17 W 1753,7'2 S 3164.47 W 1786,18 $ 3230.69 W 1818.20 S 3'295.81 W 1849,76 S 3359.83 W 1878.58 S 3422.91 W 1908.63 S 3484. 17 W 1938.99 S 3544.85 W 1.970.98 S 3605.04 %4 ')005 0'~ · ,... . .. S 3664 65 W 20'21.36 S 3733,84 W 2050,01 S 3798.02 W 2082.14 S 3863.02 14 2116,86 S 3931,09 W 2155.47 S 4004.10 W 2192,35 S 4083,38 W 22'28.77 S 4169.02 14 2267.24 S 4251.65 W 2309.52 S 4332.38 W 2:]54.96 S 4422.73 W 2411..64 S 4531.20 2482.38 S 4664.65 W 2562.96 S 4821.9.7 W 2689.29 S 5061.77 W 2860.49 S 5378.10 W 3066,82 S 5708.96 W 3247.52 S 6029.78 W 3537', 95 $ 6475.73 W 5-27-86 ') 'ILL SITE 1.8 WELL NO.5 DATA INTERPOLATED MEAS. TRU VER DEPTH DEPTH FOR EVEN 1_000 SUB SEA DEPTH 1_000 999 950 2000 !974 1925 :30 O0 28:33 2784 400l.] :3581 3532 $ 0 0 0 4-:3 l 1 4 2 6 '2 6 000 50 46 4997 7 000 583 I] 578 t.. 81300 66 37 6588 900t] 7449 7400 '1. 0000 8 t 39 8090 t t 000 8475 12000 871_8 13000 8801_ FEET OF MEASURED DEPTH RELATIVE COORDINATES FROM WELL-HEAD 29,28 S 1.2,49 W 157,99 S 1_76,38 W 438,63 S 596.82 W 785,16 S t1_6'2,00 %4 '1.06.68 tS 1_764,38 t4 1.381 50 S '2:385.46 W 1647.03 S 2945,86 W 1904,9'8 S 3476.79 W 2!54.97 S 4003.19 W 2472,46 S 46 46. 1_0 W 8426 2916.98 S 5469,95 W 8669 3412,57 S 6303,4t W 875'2 4010,59 S 7099,t4 W S-27-86. 450 450 0 i340i 8844 E542 HORIZONTAL VIE N ARCO ALASKA. INC. DRILL SITE i8 WELL NO.5 CLOSURE: 8548 ft S 80.i ~ DECLINATION: 3t.25 deg E SCALE: i inch - 1400 feet DRAWN: 5-22-B6 700 0 700 t400 2BO0 3500 4200 4900 5600 6300 7000 7700 8400 glO0 T/OD 7000 t,;OD D~;00 4!~(~ 4'200 ~,'.q0O ~.~00 8100 i400 700 0 700 lEO0 2400 3200 4000 4800 5600 6400 7800 BO00 { ~00 i -800 VERTICAL SECTION ARCO ALASKA, INC. DRILL SITE i8 WELL NO.5 SECTION AT S 82.17 W COMPUTED BY RADIUS OF CURVATURE SCALE ' 1 inch = t600 feet i DRAWN' 5-22-88 Marker Zdentification ~J KOI' 49O 4S~ O' B} m l~40t I .... c)(; [2 )i986 .... x~ AlaS~ 0ii & .GasJohs. Con' mission ~ ~ . ~., 4000 4800 ~eoo 6400 7200 ~ooo 8soo ARCO ALa.~ka, Inc. F',.O. Box ~}0S60 Anchor'age, ALaska 99~ ~) DATE' tlr+obey- 6, ~ooz. RI:-.FERli:NC, E' ARCO F'~-e'--:.~u~-e Data iP-~, ... o_o_oz.~, ~, ~, F'[0wing ~"adient,F'BU. ,S+a+ic. . Grad lent, Step R. C a m c o D ]: S T R I B LJ T I [] N J::' i J. e 5' A L a .~; I..'. a ARCO ALaska, Inc· p.O. Box Anchorage, ALaska ~.,~E' Aug us*, i,.~, ~.986 REFERENCE' ARCO Pressure Da,a 5-5 ...- ~i 8-i ~i8-2 ~18-5 -~, _~.~._o z~.~. ....~*; a +. i c Grad i ~nt Camco 7-25-86 £~a+,ic Gradien~ Camco 7-°~-°z~, ~,~, S$a~. i,- Gradien~ Sperry-Sun 7-24-86 S~a~iC Gradien~ Camco ~-~4-8~ a~c Gr:d~ent Camco 7-24-86 Sta$~c Grad~en~ Camco F'[ease .sign and re~u;-n the mttached copy as receip~ of dm~a. Recei red --~ ~ Al~ka Oil ~ ~as ConS. Commissbn Linda Hu[ ~ Anchorage ATO-15~°_, TRANS ~86584 CentraL Fi Le~ L.,: ieVi' g & M . Extension ExpLora±ion Exxon Marathon Mob i [ ¢- F'hil [ip~ F'B WeLL F i Les ,.]-;...iii i Sfafe of *'~ ~.'. Te×aco ARCO ALaska, I~.c P.O. Box 100360 Anchorage, ALaska 995~ 8 DATE' August t, ~986 REFERENCE' ARCO Cased Hole Final 4-4 7-5-86 Product ion F"rofj te F.'.ur~ ~4-S2 7-97t0-8& Spinner log Run 9-9 7-2S-86 Pump in Temp Survey Run t 5" 9-35 7-23-86 Pump in Temp Survey Run I ~ -7 7-7-86 Injec$ ion Prof i [~ Loq Rui~ ~i5-4 7-t~-86 Spinner 2urvey Run 1 ~-' ~i8-5 -~-~4-_o~ R'Gamma Ray Rut, i ~'.., Please sign and return the attached copy as receipt of data. Received By HAYE A NICE DAY! Lioda Hu[ce ATO-I~?°_~, DISTRIBUTION Central Fi les l'-:h evi- E×tension E×p[ora*,ion Ex ×on M.mra ~hon Nob i l PB WeLl Ki[es ~ $~hi~ ~i~$tate:.of Alaska ~ T-xa, o ~i~Ka Oil & Ga~ Cons. Commission Ii~ AIr:CO Ai. mska, ]:nc· I::'~0· Box 10036-(:) Anchor'age, ALaska 995'i 0 DATE: J,ll.y 2 4,'i986 R E r= E R Ii:' N C I? ' ARCC) Dir'ec'tional. Da1.'a .... :? 8 '5 -.-27 - 86 M W .1[) D i -29 6'~7-86 HWD Dir'ect.'iona · --S-O '?--.'1--86 MWD D i rect: i ona .-- 3 '! '~', -- ''~.,.. ''~.. - ,.., ~ ,_,z- M W D D i r e c 't i o n a -.34 '?-.9-86 MWD t -t 7 6-t ~-)-..86 Mi,JO D i rec t .... t8 7-t--86 MWD Di t --24 '7-'7-86 MWD D J r'ec ~' i ona 8-'-5 5-2¥-.86 MWD D i r ec .l.. i onn I. T e t. e c o I_ Te I. eco l Te Leco Te I. eco L Te Leco L 're I.e,:o I. Te I. et:c) I. Te I. eco I. 'l'e I. e c o PLea.~;e .xign and ret urn 'l'he a.~.tached I::.'. e c e i v e d B y ............................................... I..IAVE A NICIE DAY! I... i 'ncla Hu Lee ATO- ~ "~'~:~ ...-' ^:~ ~ 'T'R A N 5' ... q z a'?. -" '~' C. Cf, 't ../ t' copy a.s rece i p'{' o'F (.t;.~ fa, D 3: S T F;.' ]: B LJ T I 0 N C'. e n 't r a L I:-' i !. e Ch ev'r o'n D & M Exten.~io'n Expl. o)-atio E x x o n Ma'," a ihon Hc, b i £ Phi I. Lip ~ · 11:l::' B W e I. I. F i I. e .s' R & D .Il. ~', · ,' ,.~ 0 h J o :,,- ;'~'t. ate o'f AI. as'ka 'l'e x a c o 1986 Alaska 011 & Gas Cone. Commission STATE OF ALASKA ALAS~,. · OIL AND GAS CONSERVATION COME, "SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well r~ Alter casing ~ Time extension © Change approved program ~. Plugging [] Stimulate © Pull tubing C Amend order ~ Perforate r~ Other 2. Name of Operator ARCO Alaska, -- Inco 3. Address Po Oo Box 100~60 Anchorage, AK 99510 4. Location of well at surface 952'FNL, 221'FEL, Sec.24, T11N, R14E, UM At top of productive interval 600'FSL, 2000'FEL, Sec.23, TllN, R14E, UM (approx.) At effective depth None At.total depth ~5'FSL, 2385'FEL, Sec.23, TllN, R14E, UM (approx.) 5. Datum elevation (DF or KB) 49'RKB 6. Unit or ~oper.t,y name Prudhoe ~ay unit 7. Well number 18-5 8. Permit number 86-80 9. APl number 50-- 029-21 583 10. Pool Prbdhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 13444 feet 8848 feet Plugs (measured) None Effective depth: measured N o n e true vertical feet Junk (measured) None feet Casing ~ngth Size Conductor 80' 20" Surface 2974' 13-3/8" Producti on 1 0232 ' Lnr/TiebackSleeve 4581 ' Slotted Liner 556' 9-5/8" 7" 4-1/2" _. Perforation depth: measured Cemented Measured depth 2156# Pol eset ll0'MD 3000 sx CS I!1 & 300.8 'MD 400 sx Class G 500 sx Class G 10264'MD 970 sx Class G 7919'-12500'MD Open Hole Completion 12409'-12965'MD true vertical OPEN HOLE COMPLETION Tubing (size, grade and measured depth) 4-1/2"/3-1/2',, L-80/N-80, tbg w/tail ~ 12,406' Packers and ~S¥ ltyDe and measured deoth) SS pier-~-~z,~O9' & SSSV ~ 2236' True Vertical depth ll0'TVD 2829 'TVD 8265 'TVD 6571 '-8775'TVD 8771 '-8800 jUL 2 S$ 0~l ~ Gas Cons, Gommissi0~ ~chora~e 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation December, 1986 14. If proposal was verbally approved Name of approver Date approved Signed15' I hereby certify~~~that the foregoing is true and,~ correctTitle t°Ass°ci ate Engi neerthe best of my knowledge ~/ commission Use Only ( DAM ) SA/084 Date '~' ~--~"~ Conditions of approval APproved by Form 10-403 Rev 12-1-85 Notify commisSion so representative may witness Approval No. ~,~,- ~ /.~ Plug integrity ~ [] BO? ~.~!_.~ [] location clearance % by order of ,~. :~,: ~. ~ ~ .:~ Commissioner the commission Date Submit in triplicate fee~'~' · ' rVD ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no, AFE AS0359 Nabors 26-E Operator ARCO Alaeka, Inc. County, parish or borough North Slope Borough Lease or Unit . ADL #28307 Title Drill AP1 50-029-21583 Date 4/21/86 Hour 1330 Hrs. State Alaeka IARCO W.I. Prior status if a W,O, Spudded or W.O. begun Spud 21.661 Date and depth as of 8:00 a.m. 4/22/86 4/23/86 4/24/86 4/25/86 4/26/86 thru 4/28/86 Complete record for each day reported 20" @ 1.I0' 870', (660'), DD Wt. 8.7, PV 17, YP 42, PH 10, 14L 10, Sol 3.3 Accept ri8 @ 0900 hfs, 4/21/86. NU diverter sys. 1330 hre, 4/2i/86. Drl to 435', DD to 870'. Spud well @ 20" @ 110' 1952', (1082'), DD Wt. 9.3, PV 18, YP 42, PH 8.5, WL 12.8, Sol 6 DD & surv 17½" hole to 1952'. 450', Assumed vertical 596', 1.8°, S 9.5W, 595 TVD, 1.4 VS, 2.3S, 1078', 7.6°, 836W, 1076 TVD, 33.8 VS, 36.7S, 1289', 8.4°, S45W, 1285 ~q), 61.0 VS, 58.9S, 1700', 14.2°, S58W, 0.4W 18.8W 37.9W 1687 ~D, 141.3 VS, 106.7S, 103.4W 20" @ 110' 3015', (1063'), Prep to rn 13-3/8" csg Wt. 9.4, PV 15, YP 38, PH 9.5, WL 25, Sol 7.5 Drl & surv 17½" bole to 2802', make wiper trip, drl to 3015', C&C, TOH f/csg. 1920', 18.7°, SSSW, 1898.77 ~v-D, 203.28 VS, 141.35S, 155.17W 2291', 27.2°, S59.1W, 2238.89 TVD, 350.14 VS, 220.08S, 279.66W 2705', 34°, S55.2W, 2594.35 TVD, 559.38 VS, 340.82S, 452.49W 13-3/8" @ 3008' 3015', (0'), NU BOPE Rn 74 its, 13-3/8", 72~, J-55 BTC & 2 its J-55 csg w/FC @ 2925', FS @ 3008'. Cat w/3000 ex CS III, followed by 400 ex "G" w/21 CaC1 & .2I FP-6. Displ using rig pmps, bump plug. diverter NU BOPE. 13-3/8" @ 3008' 7071', (4056'), Drlg wt. 9.3, Pv 7, YP 6, ~a 8.5, ~ 9.4, SoZ 6.5 Ts~ BOP~ co 5000 psi. TI~ co 2924~ DO FC & 60' ca~ cs~ cas ~o 2000 psi. Drl caC & FS + 10' ney fomaCion. Conduce leak-off tst to 14.5 EMW. Drl, Navi-Drl & surv 12k" hole to ~ 7071'. L.Ld 3573', 42.8°, S59.4W, 3268.35, 1104.05 VS, 632.51S, 914.36W~ 4202', 43.3°, S61.5W, 3728.02, 1533.20 VS, 844.21S, 1278.36W 4642', 42.5°, S62W, 4050.34, 1832.71VS, 895.98S, 1551.70W 5743', 41.2°, S65~, 4851.33, 2586.95 VS, 1308.41S, 2234.42W 6307', 39.5°, S65.4W, 5281.15, 2951.57 VS, 1461.60S, 2565.79W 6575', 37°, S64W, 5491.60, 3117.29 VS, 1532.448, 2715.89W The above is correct For forth preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ] Title 7/24/86 Drilling Supervisor ARCO Oil and Gas Company '~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ unlil completion. District Field Alaska Prudhoe Bay County or Parish Lease or Unit I State North Slope Borough Alaska Well no. I 18-5 Date and depth as of 8:00 a.m. 4/29/86 4/3o/86 5/01/86 5/02/86 5/03/86 thru 5/05/86 5/06/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 3008, 7978', (907*), Drlg Wt. 9.6, PV 10, YP 5, PH 9.5, ~L 7.6, Sol 8 Drl & surv 12¼" hole to 7978'. 7249', 37.7°, S64W, 6028.10 TVD, 3525.03 VS, 1711.28S, 3082.57~ 13-3/8" @ 3008' 8577', (599'), Drlg Wt. 9.8, PV 9, YP 4, PH 9, WL 5.8, Sol 9 Drl & surv 12¼" hole to 8577'. 7818', 34.6°, S64.3W, 6488.09, 3859.64 rS, 1857.35S, 3383.87W 8447', 34.8°, S68.4W, 7007.42, 4213.93 rS, 2007.23S, 3705.38W 13-3/8" @ 3008' 9095', (518'), Drlg Wt. 9.9, PV 10, YP 7, PH 10, WL 6.0, Sol -- Drl & surv 12¼" hole to 9095'. 8670', 35.4°, S63.6W, 7189.90, 4341.77 rS, 2059.38S, 3822.42W 8890', 38.8°, S62.6W, 7365.34, 4474.43 rS, 2119.45S, 3940.72W 13-3/8" @ 3008' 9403', (308'), PON f/BHAchg Wt. 9.8+, PV 12, YP 10, PH 9.0, WL 7.2, Sol 10 Drl to 9275', Navi-Drl to 9403', PON f/BHA. 9089', 41.5°, S64.6Ws 7517.44, 4602.67 VS, 2176.44S, 4055.66W 9231', 43.9°, S67.SW, 7621.80, 4698.71 rS, 2215.47S, 4143.66W 13-3/8" @ 3008' 10,235', (832'), Drlg Wt. 10.2, PV 16, YP 15, PH 10, WL 6.8, Sol 11 Pmp pill, POH. RIH, rm 9033'-9403', drl & surv 12¼" hole to 10,235'. 9,457', 40.7°, S62.3W, 7788.99, 4850.50 VS, 2279.74S, 4281.38W 9,771', 51.2°, S62.2W, 8007.90, 5074.98 VS, 2382.405, 4481.03W 10,148', 62.1°, S62.9W, 8215.23, 5389.15 VS, 2527.73S, 4759.58W 13-3/8" @ 3008' 10,280', (45'), Rn'g 9-5/8" csg Wt. 10.2, PV 16, YP 15, PH 10, WL 6.8, Sol 11 Drl & surv 12¼" hole to 10,280', 15 std short trip, C&C, POH, LD BMA. Chg rams. RU & begin rn'g 9-5/8" caS. 10,231', 6.4°, S62.2W, 8252.85, 5463.12 VS, 2561.83S, 4825.22W RECEIVED J U L 8 The above is correct Signature . ' For form\~repar~tion and distribution see Procedures Manual ~ection 10, Drilling, Pages 86 and 87 JOate JTitle 7/24/86 Aiaska Oil & Gas Cons Drilling Supervi~-.o-.~^.. · Commission ARCO Oil and Gas Company.,a~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations; If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Field JLease or Unit I #28307 Date and depth Complete record for each day while drilling or workover in progress Prudhoe Bay 5/07/86 5/o8/86 5/09/86 5/lO/86 thru 5/12/86 5/13/86 ' 5/14/86 as of 8:00 a.m. 9-5/8" @ 10,264' 10,280', (0'), RIH W/8~" bit Wt. 10.0, PV 14, YP 8, PH 9.0, ~L 9.8, Sol 10 Fin rn'g 9-5/8" csg, wrk 10 its to btm. Cmt w/500 sx C1 "G" w/.75% D-31 & .20% R-5. Displ using rig pmps, did not bump plug. CIP @ 1300 hfs, 5/6/86. NU &tst BOPE. RIH w/8½" bit. 9-5/8" @ 10,264' 10,284', (4'), Chg to OilFaze Wt. 9.5, PV 45, YP 15, PM --, WL 5.2, Sol 12.5 TIH w/5" DP & 8½" bit, tst csg to 3000 psi. DO flt equip & cmt + 4' new hole. Conduct formation ret to 13.1 ppg EMW. Cln pice & take on 9.5 ppg OilFaze mud. 9-5/8" @ 10,264' i0,471', (187'), Trip f/BHA Wt. 9.3, PV 30, YP 60, PH --, WL 6.9, Sol 13 Displ w/OilFaze. Drl 8½" hole to 10,471', trip f/BHA. 10,407', 71.7°, S62.6W, 8319.15, 5626.01VS, 2637.288, 4969.58W 9-5/8" @ 10,264' 10,920', (449'), TIH w/globe bsk~ Wt. 9.2, PV 20, YP 16, PH --, WL 7.2, Sol ll TIH, rm f/10,375'-10,471', drl 8½" hole to 10,918', TOH, lost 3 cones in hole. TIH w/mill & boot bskt, mill on Junk, TOH. TIH w/globe bskt, wsh over Junk, TOM, chg shoe on globe bskt, TIH. 10,495', 74.1°, S61.5W, 8345.03, 5710.12 VS, 2676.718, 5043.38W 10,830', 75.6°, 862.2W, 8436.57, 6032.34 Va, 2829.778, 5327.44W 9-5/8" @ 10,264' 10,927', (7'), TOH Wt. 9.4, PV 21, YP 14, PH --, WL 6.5, Sol 12 TIH w/globe bskt, wsh over Junk, TOH. PU mill #3, TIH, mill on junk, TOH. TIH w/bit & SB, drl to 10,927', TOH. Alaska IWell no. 18-5 D 9-5/8" @ 10,264' 10,946', (19'), PU retry BP Wt. 9.3, PV 20, YP 15, PH 7, WL 7.2, Sol 11 TOH w/bit. TIH w/mill, stab hanging up @ wear bushing, TOH. TIH w/bit, drl f/10,927'-10,946', TOH. MU tat plug, tat BOPE, pull tat plug, left junk ring in wellhead. TIH w/pkr & att to set @ 900' & 650'; failed to set, TOH & LD same. RECEIVE J U L 2 8 ]986 The above is correct Signature._ IDate ITitle 7/24186 ~,a~aa u. a Gas Cons. Commission DrillingSuperviso For form I~reparation and distribution see, Procedures Manual Section 10, Drilling, Pages 86 end 87 ARCO Oil and Gas Company '~' v Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field I County or Perish iState Alaska ILease or Unit North Slope Borough Prudhoe Bay ADL //28307 Date and depth COmplete record for each day while drilling or workover in progress as of 8:00 a.m. Alaska 5/15/86 5/16/86 5/17/86 thru 5/19/86 5/20/86 5/21/86 5/22/86 The above is correct For form pre~paration and distribution Well no, 18-5 9-5/8" @ 10,264' 10,995', (49'), Drlg Wt. 9.2+, PV 19, YP 14, PH 7, W-L 6.8, Sol 10 Set 9-5/8" retry BP @ 500', ND BOPE, ND top spool, chg out packof£ & spool. NU & tst. ND & tst BOPE. Pull BP. RIH, drl 8¥' hole f/10,946'-10,995'. 9-5/8" @ 10,264' 11,245', (250'), Drlg Wt. 9.3, PV 18, YP 12, PH --, ~CL 8, Sol 10 Drl & surv 8½" hole to 11,245'. 10,960', 76.7°, S57.7W, 8467.70, 6156.43 VS, 2892.96S, 5436.65W 11,084's 75.8°, S59.0W, 8487.18, 6278.62 VS, 2956.07S, 5539.23W 9-5/8" @ 10,264' 12,450', (1205'), POH f/BHA Wt. 9.3+, PV 20, YP 12, PH --, ~TL 40, Sol 10 Drl & surv 8½" hole to 12,450'. 11,206', 74.8°, S57.3W, 8528.14, 6396.34 VS, 3018.258, 5639.32W 11,661', 75.9°, S60.5W, 8647.43, 6835.01VS, 3238.518, 6019.26W 12,135', 81.1', S52.9W, 8741.00, 7297.80 VS, 3486.358, 6411.69W 12,391', 86.2°, S53.8W, 8769.53, 7549.18 VS, 3638.16S, 6615.76W 9-5/8" @ 10,264' 13,150', (700'), Drlg Wt. 9.4, PV 17, YP 15, PH --, ~L 38, Sol 10 Drl & surv 8½" hole to 13,150'. 12,578', 88.3*, S52.7W, 8778 TVD, 7734 VS, 3749.91S, 6765.41W 12,945', 85.6°, 852.0W, 8798 TVD, 8095 VS, 3973.64S, 7055.66W 13,126', 84.7*, S51.7W, 8813 TVD, 8272 ¥S, 4085.05S, 7197.48W 9-5/8" @ 10,264' 13,425', (275'), Drlg Wt. 9.4, PV 18, YP 16, PH --, WL 40, Sol 10 Drl & surv 8½" hole t° 13,425'. 13,251', 83.8°, S51.3W, 8825.39, 8394.65 VS, 4162.47S, 7294.84W 9-5/8" @ 10,264' 13,444', (0'), Logging Wt. 9.5+, PV 18, YP 15, PH --, VfL 45, Sol 10 Drl to 13,444', CBU, TOH. RU loggers, rn Sonic/CNL/GR logging f/10,157'-11,898', TOH w/~rL. TIH w/DP to 11,533'. RU ~L, TIH & latch up. TIB w/$onic/Ch-L/GR to 12,816'. 13,401', 82.5°, S51.3~, 8843.28, 8540.94 VS, 4255.88S, 7411.04W Date ]Title 7/24/86 Drilling Supervisor see Procedures Manual Section 10, Drilling, Pages 8§ and 87 D crl"lll i\L~.I-I V ED J U L 2 8 1986 Alaska OJJ & Gas Cons. Commission Anchoraoe ARCO Oil and Gas Companyv'~' Daily Well History--Interim Instructions: This form is used during drilling or Workover operations. 'If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Field JLease or Unit I #28307 Complete record for each day while drilling or workover in progress Prudhoe Bay 5123186 5124/86 thru 5/27/86 Date and depth as of 8:00 a.m. 5/28/86 5129186 5/30/86 Alaska IWell no. 18-5 9-5/8" @ 10,264' 13,444', (0'), Condition hole Wt. 9.5, PV 18, YP 18, PH --, WL 40, Sol 11 TIH to 13,370', rn Sonic/CNL/GR f/13,365'-11,626', rn CBL in 9-5/8" csg f/10,224'-8998'. RD Schl. TIH, make conditioning run prior to rn'g 7". 7" @ 12,500' 13,444', (0'), Wsh over tl jt Wt. 9.4+, PV 17, YP 18, PH --, WL 20.6, Sol 10 TIH, wsh & rm f/13,307'-13,444', C&C, TOH. Chg rams to 7" & tst. Rn 59 its, + 1 mkr jr, 7", 29#, L-80 BTC lnr w/top @ 9926', mkr Jt @ 12,048', LC top @ 12,492', FS @ 12,500', top of pkr @ 12,484'. Drop ball, ball did not seat. MAP 650 sx C1 "G" w/5% KC1, .5% D-31, 1.2% D-19, .2% R-5 & .2% D-6. Displ mud using rig pmp, external csg pkr set & stage cmt colt opened. CIP @ 1530 hfs, 5/24/86. Pull 10 stds + 1 DP, break cmt head, att to TOM; pipe stuck. Wrk pipe. TIH w/freept, make BO @ 8402', TOH w/string shot. TOH w/5" DP. RIH w/BHA & 12 its wsh pipe, wsh f/8402'-8404', TOH. TIH w/shoe #2, wsh f/8404'-8499', TOH. TIH w/shoe #3, wsh over tl jt @ 8499'. 7" @ 12,500' 13,444', (0'), TOH w/screw-in sub Wt. 9.3, PV 16, YP 13, PM --, WL 18.0, Sol 9 Wsh over fsh f/8499'-8536', TOH. TIH w/shoe #4, mill over tl f/8534'-8439', wrk pipe above tl joint; unable to wrk or mill past it, TOH. PU 10' pup, screw into fsh, pull, pulled loose f/fsh, TOH. 7" @ 12,500' 13,444', (0'), RIH w/cripple shoe mill #2 Wt. 9.4, PV 17, YP 15, PH --, WL 20.3, Sol 11 POH w/screw in sub. RIH w/OS & 6-1/8" grapple, jar, slipped off fsh, POH. RIH w/8-1/4" x 5" ID cripple shoe mill, mill over tl jr, POH. MU new mill & RIH. 7" @ 12,500' 13,444', (0'), POH w/OS Wt. 9.4, PV 16, YP 16, PH --, WL 17.2, Sol 11 RIH w/mill, remill tl Jr, CBU, POH. RIH w/guide mill & OS, wsh over fsh & jar. RU WL, RIH w/colt log, POOH, add wt. RIH to 8526' WL, POH. RIH w/shot, shoot @ 8495' (3rd jt f/TOF). Backed off drl colr, screw drl colt in, tel OS f/fsh, lost fluid, observe well, POH. The above is correct Signet rre .~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ]Title 7/24/86 Alaska Oil & Gas Cons. Commission Anchorage ARCO Oil and Gas Company '~ Daily Well History---Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially, Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion. District iCounty or Parish IStste Alaska North Slope Borough I Loase Or unit ADL #28307 Complete record for each day while drilling or workover in progress Field Prudhoe Bay Date and deptl~ 5/3[/86 thru 6/02/86 6/03/86 6/04/86 as of 8:00 a.m. 6/05/86 6/06/86 6/07/86 thru 6/09/86 Alaska ]WeU no. 18-5 7" @ 12,500' 13,444', (0'), POH f/cutter Wt. 9.5, PV 14, YP 16, PH --, WL 17.8, Sol 10 Wsh over fsh f/8591'-8597', POH, chg BNA. RIH w/mill #11, wsh over f/8597'-8625', POH f/cutter, 7" @ 12,500' 13,444', (0'), Wsh over DP Wt. 9.3, PV 14, YP 17, PH --, W'L 17.6, Sol 10 Chg BNA, RIH w/outside cutter, cut fsh @ 8597', POH, LD fsh. RIH w/web pipe, wsh over f/8625'-8631'. 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.2+, PV 14, YP 16, PH --, krL 15.8, Sol 10 Wsh over fsh to 8639', circ, TOH, LD 39 its S-135 DP. TIH' w/mill shoe ~13, wsh over fsh f/8639'-8640', circ hi-vis sweep, TOH, LD 39 its, S-135 DP. TIH w/carbide shoe ~14, wsh over fish f/8640'-8643'. (TOP @ 8597') 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.2+, PV 13, YP 18, PH --, ~L 15.1, Sol 10 Wsh over fsh f/8643'-8659', TOH w/shoe ~14. TIH w/mill shoe #15, wsh over fsh f/8659'-8686'. 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.3+, PV 17, YP 20, PH --, ~L 14.2, 8ol 10 Wsh over fsh to 8692, TOH. TIH w/DP cutter, att to cut f/8654'-8686', TOH. TIH w/mill, wsh & mill over fsh f/8682'-8717', TOH. TIH w/DP cutter, cut fsh @ 8685', TOH. w/new BHA & shoe ~18, wsh over fsh f/8717~-8720'. The above is correct For form p~eparation and distribution see Procedure~ Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 7/24/86 Drilling Supervisor J U k 2 8 I986 RIH Alaska Oil & Gas Cons. Commission Anchorage 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.4, PV 17, YP 21, PH --, kTL 15.3, Sol 12 Chg OS grapples, RIH, latch fsh, circ & Jar. Rn freept to btm of fsh. RIH w/string shot, BO @ 8~99', POH w/3 its DP rah. RIH w/mill & wsh pipe, wsh over f/8499'-8535', mill 8535'-8543', trip f/new mill. RIH w/wsh pipe to TOF @ 8499', wsh over fsh to 8591'. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used dbring drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting o! oil string until completion. District Field I CoUnty or Parish IState Alaska ILease or Unit North Slope Borough Prudhoe Bay I ADL //28307 Alaska IWell no. 18-5 Date and depth as of 8:00 a.m. 6/10/86 6/11/86 6/12/86 6/13/86 6/14/86 thru 6/16/86 6/17/86 6/18/86 The aboSignat%x ve is correct, % For form p~'e~a~-atio~ and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.3, PV 15, YP 18, PH --, W-L 13.8, Sol 9 Wsh over fsh f/8720'-8762', TOH w/shoe #18. over fsh f/8762'-8764'. TIH w/shoe 19, wsh 7" @ 12,500' 13,444', (0'), TIH w/DP cutter Wt. 9.2+, PV 14, YP 17, PH --, W-L 13.2, Sol 9 Wsh over feb f/8764'-8808', TOH w/shoe #19, ID 1Jt wsh pipe. TIH w/cutter. 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.3, PV 12, YP 18, PH --, WL 13.0, Sol 9 RIR w/cutter, make cut @ 8778', POH; no rec'y. RIH w/OS, Jar on fsh, POH w/l jt fsh. RIH w/mill & wsh pipe, mill f/8808'-8810'. 7" @ 12,500' 13,444', (0'), Wsh Over fsh Wt. 9.3+, PV 14, YP 16, PR --, WL 12.2, Sol 9 Wsh over fsh to 8810', POE. RIg w/mill & wsh over to 8838'. 7" @ 12,500' 13,444', (0'), Wsh over fsh Wt. 9.3+, PV 14, YP 16, PE --, WL 12.2, Sol 9 Cont wsh'g over fsh f/8838'-8924'. 7" @ 12,500' 13,444', (0'), RU f/string shot Wt. 9.4, PV 12, YP 20, PH --, WL 12.0, Sol 9 Wsh over f/8924'-8939', CBU, POE. RIE w/pin tap BRA, screw in & POH; no fsh. MU taper tap BRA, RIH, att to BO. RU WL f/string shot. 7" @ 12,500' 13,444', (0'), RIg w/mill ~26 Wt. 9.4, PV 15, YP 20, PR --, WL 11.2, Sol 9 RU & rn CCL dummy rn, open thru fsh, unable to pull up, pulled out of socket w/W-L, POE. POE w/J-jr assy. RIB w/mill #25, mill f/8939'-8942', POE f/mill. DEr'CI /lZD i\L~.. L I ¥ ~. Date 7/24/86 ITM rill*ns Supe isor j U L '" 1-q86 AJaska 0il & Gas Cons, AnchoraDe ARCO Oil and Gas Company '~' Daily Well History--Interim ~ Instructions: This form is used during dr ling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District I County or Parish ~ State Alaska North Slope Borough Field Lease or Unit ?rudhoe Bay AD~ #28307 Date and depth as of 8:00 a.m. 6/19/86 6/20/86 6/21/86 thru 6/23/86 6124186 6/25/86 6/26/86 Complete record for each day while drilling or workover in progress 7" @ 12,500' 13,444', (0'), TIH w/taper tap Wt. 9.4, PV 14, YP 14, PH --, W-L 12.5, Sol 9 TIH w/mill shoe, mill on fsh @ 8942', CBU, TOR. PU Jarring assy, TlR, space out & latch up J-Jr, Jar on fsh, TOH. taper tap & TlR. new 7" @ 12,500' 13,444', (0'), TOH Wt. 9.4+, PV 14, YP 17, PH --, WL 12.5, $ol 9 TIH w/taper tap, screw into fsh, jar, POH; no fsh. RIE w/outside cutter, art to cut fsh @ 8814', pulled off of fsh, TOE. RIH w/mill & J-hook, jar on fsh, pulled loose, TOH to ck if fsh parted where cutting att was made. 7" @ 12,500' 13,444', (0'), Cln JB Wt. 9.5, PV 14, YP 16, PH --, WL 12, Sol 9 RIH, tag fsh @ 8711', Jar, TOH, ID 3 its DP (4 its left in hole). RIH w/hollow mill & OS, tag fsh @ 8814', dress TOF. RU W-L, RIH w/string shot, shoot f/8940'-8960', TOR. Jar on fsh, BO, TOH, ID 4 its fsh. TIH w/screw in sub, wrk torque. RIH w/string shot, BO @ 8940', TOH; no ret'y, RD Gearhart. TIH w/mill shoe, mill on fsh @ 8639'-8640', TOE, cln JB, cbt shoe. TIH w/mill shoe, wsh over fsh f/8940'-8959', circ hi-vis sweep, TOE, rec'd fsh in wsh pipe. TIH f/flat btm mill, mill cmt stringers & junk f/8959'-9900', CBU, TOH, empty JB. 7" @ 12,500' 13,444', (0'), PU 3%" DP .Wt. 9.6, PV 15, YP 19, PR --, WL 12.2, Sol 10 Cln JB. TIR w/mill to 9900', mill cmt to 9926', TOE. TIE w/bit & cst scrpr, circ, TOH Chg top rams to 3%" &tst. RIH w/6" mill/JB/7" cst scrpr on 3%" DP. 7" @ 12,500' 13,444', (0'), RIH w/MCC Wt. 9.5, PV 14, YP 19, PH --, WL 11.8, Sol 9 TlR w/mill, wsh f/9926' (7" TOL) to 11,959', drl cmt to 12,447', circ, pmp sweep around, TOR. RU $chl, RIB w/MCC. Alaska IWell no, 18-5 7" @ 12,500' 13,444', (0'), POH w/DP Wt. 9.6, PV 13, YP 18, PH --, WL 12.4, Sol 9 Rn MCC caliper log f/12,415'-10,512'. Rn CBL f/12,415'-9959', RD Schl, POH w/DP. The above is correct Sig t e For form ~)reparafion and distribution see Procedures Manual Section 10, Drilling, Pages 8§ and 87 IDate I Ti fie 7/24/86 Drilling Supervisor " -c IVED I~ Lk. L J U L 2 8 1 186 Alaska 0ii & Gas Cons. C0mmiz~i0n Anch0ra~e .4 ARCO Oil and Gas Company" v Daily Well History--Interim InStructions: This form is used during dr II ng or workover Operations if testing, corln or r Number all drill stem tests sequentially Attach descriplion of all cot-~ .... ' -. ' g, pe forating show form.,*; ....... : _ . completion. Report official or representative test on "Final" , ..... =~: .wo.r.K .P. er~'ormed by Producina § cfi., ........... =,,,- m desc. rlblng worx error on Wednesday of the week in which o I str no is set ~,,k .... .u...!. !l ~uomlt "lnlerlm" sheets whe- ~.'%,-~ 2":n. w. ill be reported on "Interim" ........ !~ wee~;ly ~or workovers and following set~'n,~'~?~u.[,??_i_n°t.l,ess frequent y than every :~)-~"~,'~l ~ ~. ~,, =L~m~ until completion - ----, District Prudhoe - . . Date and depth as of 8:00 a.m. County or Parish North Slope Borough ADL #28307 Complete record for each day while drilling or workover in progress 6/27/86 6/28/86 thru 6/30/86 7/01/86 7/02/86 7/03/86 7" @ I2,500' 13,444' (0') POOH w/chain mill , Wt. 9.6, PV 16, YP 19, PH --, WL 11.5, $ol 10 POOH, RD Schl. PU 7" RTTS, TlR, set @ 9947'. Tst 7" lnr Co 2000 psi; OK, POOL w/RTTS. RIH w/9-5/8" RTTS, tst csg above 8000' to 2000 psi; OK. BelOw 8000', pmp @ I BPM w/150 psi, POOH w/RTTS. PU Bkr chain mill, TIH to 9926', wrk mill thru tieback sly, CBU, POOH w/mill. 7" 7919'-12,500' 13,444', (0'), Drlg Wt. 9.5, PV 14, YP 16, PH --, ~L 12.2, Sol 9 LD chain mill. Instl &tst variable rams. RU & rn 46 its, 7" , 29#, L-80 BT¢ csg f/7919'-12,500' w/tieback slv@ 7932', LC @ 9841'. Cmt w/320 sx C1 "G" w/.75% CD-31, .I~ R-5 & .1% FP-8. Displ cmt using rig pmps, bump plug. C~IP @ 0446 hrs~ 6/28/86. Chg rams to 3½" &tst RIH w/9-5/8" csg to TOL @ 7919' · ,tst lnr lap to 2300 psi; OK, POOH. RIH~ tag cmt @ 9763', DO cmt to £/9763'-9840', tst lnr lap to 2300 psi; OK. Drl cmt stringers f/10,218'-10,462'. LD I1 its DPs RIH w/mill to 12 447' tst 7" lnr to 2300 psi; OK. Drl to 12,493'. ' ' 7" 7919'-12,500' 13,444', (0'), Milling @ 12,496' Wt. 9.5, PV 15, YP 19, PH --, WL 11.6, Sol 9 Mill cmt & junk f/12,~92'-12,495'. POH, chg mill & RIH. Att to work thru the tieback sleeve· POH, chg mill & ~IH, mill & .~rotate thru tieback sleeve, mill f/12,495'-12,496'. 7" 7919'-12,500' 13,444', (0'), Wrk'g pipe Wt. 9.3, PV 14, YP 17, PH --, WL 12, Sol 9 Mill to ]2,496.5', POOH. RIH w/new BHA, drl to 12,500', wsh & rm to 12,528', CBU. ~IH to 12,727', tight. Rm to 12s769'. RIH to 13,369' , circ, hole paked off. Wrk pipe. Est circ, unable to rotate. 7" 7919'-12,500' 13,444' (0'), RIH w/CLL Wt. 9.1, PV II, YP 19, PH --, WL 12.4, Sol 9 Wrk & jar stuck pipe. Lower mud wt to 9.1 ppg. Cont to jar w/o success. RU Gearhart w/string shot to BO 7" csg scrpr. RIH, unable to get Sho~ below scrpr. RIH w/s~ort unarmed shot rod to est CCL. Will set dn in XO above scrpr. The above is correct For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and ~7 J U L 2 8 1986 Alaska 0ii & Gas Cons, Anchorage ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all Cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I A1 aska Field Itease or Unit I Prudhoe Bay Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. 7/04'/86 thru 7/07/86 North Slope Borough ADL #28307 Alaska 4-1/2" slotted lnr f/12,409'-12,965' 13,444', (0'), RIH w/OS Wt. 9.2, PV 12, YP 16, PH --, WL 7.6, Sol 10 RIH w/WL tools, unable to get any tools below casing scraper. C&C mud, spot SFT soak around BHA, wrk & Jar stuck pipe. BO pipe below drlg jars, POOH. RIH w/fsh'g string, screw into fsh, jar on stuck pipe. RU WL & att to freept; unable to get tls past 12,360', POOH. RIH w/clean out bit, circ, POOH f/4-1-2" lnr. RU & rn 4-1/2" slotted lnr. RIH w/OS on DP. IWell no. 18-5 Set & tst pkr, POOH. The above is correct ~ S,gnature ~ ~.{~.~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate I Title 7/24/86 Drilling SupervisorR EC E IV L D J U L 2 8 1986 Alaska 0il & 6as Cons. Oo.lm!3oi3~ Anchor-a~e .. AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State District ~County or Parish Alaska I North Slope Borough Alaska Field ~Lease or Unit I Well no. Prudhoe Bay I ADL #28307 I 18-5 Auth. or W.O. no. ~ Title A~E AS0359 I Drill NabOrs 26-E AP1 50-029-21583 Operator I A.R.Co. W.I. ri'ets, number o, w. Us (act,v, or inscUv.) on this, I ~cost center prior to plugging and I ARCO Alaska, Inc. 21.66% Jabandonment of this well Spudded or W.O. begUnspud IDate 4/21/86 /IH°ur 1330 Hrs. IPr'°r 'leta' '' e w'°' 7/08/86 Date and depth as of 8:00 a.m. Complete record for each day reported 7/09/86 7/10/86 4-1/2" slotted lnr f/12,409'-12,965' 13,444', (0'), Rn CA Wt. 9.2, PV 12, YP 13, PH --, W-L 8.8, Sol 10 RIH w/DP & wsh over, circ, POOH, LDDP. RU & rn 3-1/2"/4-1/2" CA. 4-1/2" slotted lnr f/12,409'-12,965' 13,444', (0'), POH w/SSSV dummy Wt. 9.2, PV 12, YP 13, PH --, W-L 8.8, Sol 10 Rn 140 its, 4½", 12.6#, L-80 BTC & 255 its, 3½", 9.2#, N-80 8RD tbg w/SSSV @ 2236', XN nipple @ 9815', Lnr Pkr @ 12,409', TT @ 12,406'. ND BOPE, ND & tst tree. RU to pull SSSV d,,mmy & dummy. 4-1/2" slotted lnr £/12,409'-12,965' 13,444', (0'), RR Att to pull dummy GLM @ 3890' w/o success. Set BPV, att to inject diesel dn 9-5/8" x 13-3/8" ann; would not pmp. RR @ 1530 hfs, 7/9/86. Stacking rig. O~dTO I"ewTD IPBOepth 13,444' Open hole compl Released rigI Date I KInd of rlg 1530 Hrs. [ 7/9/86 I Rotary Classifications (o11, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, gPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ~.~ L. ~ ) 7/24/86 Drilling Suoervisor Alas~,,, ~,, & ~as C~ns. cnmm~ssion For form preparation and distribution, Anchor~ge see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO ALaska, Inc P.O. Box Anchorage, Alaska 995~ DATE: duly ~ ,t986 REFERENCE: ARCO Magnetic Tapes w/£isting ~8-5 5-22-86 OH L~ ~T~553 Run S' c: h F'Lea~e sign and return the a~ached copy as r Received By__ HAYE A NICE DAY! Lindm Hu[ce TRAN$ :~86409 eceip$ of data, DItTRIBUI'ION Central Fi Les Ch evr on D & M Exl'ension Exp[ora(ion Ex xon Marathon Mob i [ Phi L L ip.~ PB WeLL F:'i Les R ~., D ~ $ohio State o'f ALaska Texaco C D...':'., i' a Alaska & Gas Cons. Commission Anchorage ARCO Alaska, Inc.~ Post Office b,,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat- DS 18 (Wells~5' 8, 9, 12, 14, 19) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU1/06 Enclosure If RECEIVED APR 2 1 1986 Alaska 011 & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /~'~ % ,,~,,," F LA Ii E PIT / ! 16 24 ~ · ~0 ~0 .r· ~0 19 0 ~4 -- '1 , , EXISTIN6 WELL NEW WELL VICINITY IdAP s~olo:l"= 2.5 NOTES' I. STATE PLANE COORDINATES ARE ZONE 4. 2. ALL GEODETIC POSITIONS ARE BASED ON NAD 1927. $.0FFSETS TO SECTION LINES ARE COM- PUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. PLANT COORDINATES AS PER WILLIAMS BROTHERS DRAWINGS~PB-OIB-2-I-d REV. 6 LOCATION IN SECTION 9 8 5 19 14 12 486' FNL 605' FNL 951' FNL 1358' FNL 929' FNL 1161' FNL 342' FEL 312' FEL 221' FEL 116 ' FEL 541' FWL 401 FWL STATE PLANE COORDINATES NORTHIN6 5,961, 57Z.92 5,961,257.55 5,960,.911 .44 5,960,507.66 5,960,947. 74 5,960,717.04 FNL= FROM NORTH SECTION LINE FEL= FROM EAST SECTION LINE FWL= FROM WEST SECTION LINE CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY. REGISTERED AND .LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT RE- PRESENTS A LOCAl:ION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIi, IENSIONS AND OTHER DETAILS ARE CORRECT. EASTING GEODETIC POSITION PLANT COORDINATES LATITUOE (N) LONaTUOE (WI NORTH EAST 691,406.24 6 9 I, 439.32 691,5~8.57 691,654.35 692,100 . 14 69Z,166 . 29 70° 17'56.532." 70° 17' 55.39d' 70°17'. 51,96L~' 70o17'. 47,963" ?0° 17'52.178" 70o~ 7'49.893'' 148° 26' 59.ll4'* 148o26'58.255'' 148°26'55.600" 148° 26' 52. 526" 148° 26' 59.208" 148026':57. 452" 2125 2005 1645 1225 1525 1285 425 425 425 425 975 975 RECEIVED APR 2 1 1986 Almskm 011 & Gas Cons. Commission Anchora~ AS-BUILT WELL LOCATION D.S. 18 DATE: $/17/86 !BSSDI], IIIllll d I. lll lllltllll ARCO SCALE: I": 400' SHEET: IOFI FRO-ANCH F6 ~8603 April 16, 1986 Telecopy= (907) 276-7542 Mr. T. P. Oostermeyer. Regional Drilling ~Engimeer ARCO Alaska, Inc. P. O. Bex !00~0 Anchorage, Alaska 99510-0360 os 18-5 Re: Prudhoe Bay ARCO Alaska, Inc ~ Permit N~. 86-80 ~. Loc. 952tFNL, 221'FEL, Sec. 24, TllN, RliE,'UM. B~le Loc. 421'FSL, 2341'FEL, Sec. 23, TllN, R14E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid u.s in scheduling field Work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to w,itness testing of the equipment before the surface casing-shoe is drilled, Where a diverter system is required, plea. se also notify this office 24 hours prior to commencing . equipment install4tion so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Cas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc.- Department of Fish & Game, Habitat Section w/o encl. Department of EnVironmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA '~-"~ ALASKA ~i~ AND GAS CONSERVATION cOM,..,SSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill'~ Redrill ~1 lb. Type of welI. Exploratory F] StratigraphicTest [] Development Oil ~ Re-Entry [] Deepen Service [] Developement Gas [] Single Zone ]~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. 16' GL 49' RKB feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oil Pool P.O. Box 100360, Anchorage, AK 99510 ADL 28307 ALK 2317 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.O25) 952.'FNL, 221 'FEL, 5ec.24, T11N, R14E, UN Prudhoe Bay Unit Statewide At top of productive interval 8. Well nurpber Number 600'FSL, 2000'FEL, Sec.23, TllN, R14E, UM 18-5 #8088-26-27 At total depth 9. Approximate spud date Amount ~,21 'FSL, 2341'FEL, Sec.23, TllN, R14E, UM 04/18/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line DS 18-4 120'@surf. 13,144'MD 421' feet DS 18-6 120'(~surf. feet 2560 (8828'TVD) feet 16. To be completed for deviated wells KOP1/500 ' 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) KO'P2/.8298 '&KOP3/1051 8 ' Maximum hole angle 85 0 Maximum surface 3020 psigAttotatdepth(TVD) 3900 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" .~! .5# H-~.0 We!d _~O' 33' 33' !!3' !!_TM 2000~ 17½" I~-~/R" 77~_n.~ L-~0, BTr_ ~nnl, ~, ~, ~n~, ~, 12-1/4" 9-5/8" ~,7.O# L-80 BT(':. 1134R7~'~,1 ' ~,1 ~ 113~1R R~{lq~ c~lll3 .~x ~_1~_~_~ 8:~" 7" Z9.0# L-80 BTC 2307' 10187' 8155' 12494 8769' 500 sx (,:,lass C 8½" 4½" 3.5# N-80 VFJ 750' 12394' 8759' 13144 8828' ,slotted open hole comp 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate APR ! 4 ]986 Production Liner Alaska 0ii & Gas Cons. Perforation depth: measured Anchorage true vertical 20. Attachments Fili.n,g fee .]~ Property plat [] BOP Sketch ,~ Diverter Sketch [] Drilling program ~ Drilling fluid program ~ Time vs depth plot ii:~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] ... 21. I hereby certify that the.~fore, going is true and correct to the best of my knowledge ~ . I~"~//~ y,,~.~-I/~' / / ...... Regional Drilling Engineer ~/j~/~.~ bignea/ ~' / "~(~/'~C" ~ iizle Date ommission Use Only (JRR) PD/PD2~7 Permit Number ~, o [ APl number .~ I Appro,.v~l gl.at.e,,... [ See cover letter · ~(c- ~ I 50-- o't-.5~ - I-~5";~.~ I Uq/.I.~/~I for other requirements Conditions of approval Samples required [] Yes {~-No Mud log required [] Yes J~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required working p,r, eg'~e for ~JOPE~,4~;_ [] L'.'~;~ 5M; [] 1OM; [] 15M Other: , ~ ~ '- ..~.~ ( ~//~ (~~~//~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 ~ / , Subr :riplicate DS 18-5 DRILLING PROGRAM 1. Drill 30" conductor hole and set 20" casing. Secure with 2000// Poleset. 2. MIRU drilling rig. Nipple up riser. 3. Drill 17-1/2" hole to KOP at 500'. Kick off building 1.5°/100' oriented· S62°10'W. Drill to 13-3/8" casing point at 2852'TVD/3033'MD. Cement to surface with 2900 sx Cold Set III and 400 sx Cold Set II. 4. Nipple up and test BOPE. (Test rams @ 5000 psi, annular @ 3000 psi.) 5. Test casing to 2000 psi. Perform l eakoff test. Drill 12-1/4" hole at 38° to KOP2 at 7000'TVD. Kick off and build 1.5°/100' to 62°. Drill to the Top of the Sadlerochit. Run 9-5/8" casing and cement with 500 sx Class "G" cement. 6. Change mud system from low sol ids non-dispersed to oil base mud. 7. Test casing to 3000 psi. Perform leakoff test. Drill 8-1/2" hole building angle at 1.5°/100' to maximum angle of 85°. Hold 85° angle to TD at IO0'MD past the Base of the Sadlerochit. 8. Run open hole logs. 9. Run 7" liner and cement with +500 sx Class "G" cement. 10. Clean out cement in 9-5/8" casing and 7" liner. Pressure test casing to 3000 ps i. 11. Run cased hole logs. 12. Clean out open hole to TD. Run 4-1/2" flush joint slotted liner to TD and set on packer with SBR 100' above 7" casing shoe. 13. Change over well to 9.2 ppg brine. 14. RIH with SBR overshot and 3-1/2" x 4-1/2" tubing with SSSV. Stab overshot on SBR and land tubing. Pressure test tubing casing annul us. 15. Set BPV. ND BOPE and NU tree. Test tree to 5000 psi. Secure well and release rig. 16. Run gyro. Displace well to diesel cap. 17. Produce well through 4-1/2" slotted liner. Stimulate as required based upon production data. NOTE' a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. Existing wells within 200' of the proposed well are DS 18-4, 120' surface, and DS 18-6, 120' @ surface. c. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. d. Maximum surface pressure is based upon BHP and a full column gas to TD (0.10 psi/ft). e. The AOGCC has waived the requirement for a surface hole diverter system on Drill Site 18. Therefore, a diverter system.~mi~gbt not be used for this well. PD/PD247a 'tw Depth (TVD) Surf to 13-3/8" Csg Poi nt 13-3/8" Csg Shoe 8.8 to to K-lO 9.2 / Density #/gal 8.8 to 9.2 DS 18-5 MUD PROGRAM Plas Yield / Visc. Point Initial IOM (CP) #/100 ft2 Gel Gel Funnel 160- 3OO 40-60 30+ 50+ 25 Minimum Possible 2 2 5 15 to to to to 4 5 10 25 FL CC/30M % Oil % pH and Solids Type of Mud Gel-Benex Spud Mud 3.5 Low Sol ids to Non-dispersed 6.5 K-lO 9.2 12 to to to 9-5/8"Csg. Pt. 9.8 20 6 2 5 4 to to to to 10 4 8 6 2 4 pH 9-10 to Low Sol ids 10 Non-di sper sed 9-5/8" Csg. Shoe 9.4 to to TD 9.8 18 12 10 5 WATER 0 to 5% Oil Base 1. Degasser' 2. Shakers DS 18-5 EQUIPMENT - DRILLING FLUID SYSTEM Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor 5. Trip tank 6. Agitators 7. Mud cleaner PD/PD247b:tw Alaska Oil & Gas Anch~r~[~e DS 18-5 TYPICAL MUD PIT SCHEMATIC PIT 7 AGITATOR WATER TANK DE S ILTER AGITATOR PIT 4 ? ~ATORS PIT 2 PILL PIT SAND TRAP AGI PIT 3 AGITATOR PIT 5 AGITATORS PIT 6 SHAKERS DEGASSER 't CUTTINGS CONVEYOR CENTRIFUGE I I PIT 1 DEGASSER HOLDING ?ANK (DRAWING NOT TO SCALE) 1. System is equipped with a drilling fluid pit level indicator with.both visual and audio warning devices located in the immediate area of the driller's console. 2. System is equipped with a drilling fluid flow sensor with a read-out convient to the driller's console, i~ ~ f ~.IV 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 D818-6 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 100C ~coP TVD · 600 1.5 13.5 19.5 , : 5.5 28.5 3L5 1~-~ 8' CASING ~ 3~.5 37.5 E( C ~D-2,~2 MD- ~0~ DEP"810 t8.0 38.0 38.0 38.0 S 62 OEG 1G MIN W 7983 FT(TO TARGET) ~ 38.0 ~VERAGE A~ GLE ~ DEG 0 MI~ ~.0 3e.o K-lO ~D m ~799 MD m 8043 DEP m 3894 3R.n K~P TVO ,, 7flfl~ MO~m AOgA D~P m 4~A1 ~6~ ~--, T'fD ' 7440 MD -- 800 DEP - 44l'3 , ~ ~u~ EOC ~/~ - an~o ~,n - 992! LCt~ TVD -- 8C ~4 MD -- 1~)012 DEP - 5389 SI~G R ~D' 8204 MD ' 10292 DiP- 6817 ,vo. ,4. o,,-.. 9-5/8'/KOP ~D = 8309 MO -- 10518 OEP -- 5817 G/O CO~ TACT ~'D -- 8663 Mi) - 11~68 [ EP - 6802 _ I'A~GET ~,D - 8794 1 ID - 12767 DEP - 798 ~ BASE SAI~LEROCHIT ~D - 88~ g MD -- 13( ~ OEP - fl289 TC TVD-88!8MD-13144DEP-18368i 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 t O0 VERT I CRL SECT I ON R C E iV 0'6 ~1%1~$10 $U9/'110 O0~N ' N~O: APR 1 ~ ]98~ £ ~ N COOROINflTE$ 0 - 10000 -9000 -8000 -7000 -6000 -5000 -'t000 -3000 -2000 - 1000 0 1000 .... , ,,,, m T ~ '4795 ~ ~ ~371 m~ ~051 , o o ~300 , ,, ,, ,,,, , ,, '' / 8680 T DS1 III I I I0 I , ,, , ~ , - 10~ -9~ -8000 -7000 -6~ -5000 -~000 -~ -20~ - 1000 0 1000 - N CO0~OINST~5 F, - IN COORDINFITE:S o - 10000 -9000 -O000 -,7000 -6000 -5000 -~t000 -3000 -2000 -1000 0 1000 ' ' ' ' ' ' ' ' ' ' ' ' ' ' I I I ' '' ' ' ' ' ' ' i I I ' ' ' ' ' I ' ' ' ii I I I I I I I ' ' ~ ' ' ' ' ' I ' ~ ' [ ~ I I I I I ' 0S18-6 , , , ~505 ~::'~ O S 1 [ :,~.~;: ?h 61~ 6726 :2. 71 -9000 -8000 -7000 -6000 -5000 -'t000 -3000 -2000 F.. - M ..... ~?' ' ..---,~' E - ~ .COORDINATES -~'400 .- ' '-300 -200' - 100 0 1 O0 200 300' C) (:2 z C~ I I os! -400 I ' f I f I I ! '' I i, , k I , ', .. I ~. .. . . .-' o , ~~co ~~u~ ~ ~2053 ~ / 1997 ~bbUi ~ R E ' /2919 '~102 ~FR -300 -200 - l O0 0 1 O0 200 300 E - Fl COOROIN~TES CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee L//~x_._ ~-/9c-~ (14 thru 22) (23 thru 28) Company Lease & Well No. YES. 1. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ................... .~,~.~ 4. Is well located proper distance from other wells ........... 5. Is sufficient undedicated acreage available in this pool .. 6. Is well to be deviated and is wellbore plat included ...... - 7. Is operator the only affected party ........ --------------------..- -- 6~ s' c.. "'""'""'""'"'"." · 10. 11. 12. 13. NO 14. 15. 16. 17. 18. 19. 20. 21. .22. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. Is a diverter system required ....................................... 24, Is the drilling fluid program~schematicandlist,of~,equipment adequate~ · - - _ 25 Are necessary diagrams and descriptions of~_~7~_~ ...... BOPE attached· 26. Does BOPE have sufficient pressure rating - Test to ~O~O psig .. 27. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 28 Is the presence of H2S gas pr bable · 0 elee®leeleee®ee®®~eee®e,®eeeeeeee (6) OTHER ~o ~, (29 thru 31) (6) Add: For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32 Additional requirements · eee®®el®®ee®·eeee®eeeeeeee®eeeeeeee,ee®®eeeee · Geo lqgy: En$i. neering: WVA MTM ~ HSH ~ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. UNIT AREA NO. 6N/OFF SHORE RENt~L~S Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. -. MICi O ILMED LIS ~/E R I ,t::i C a, T t O N1 LISTING _VP OtO.dgZ VERI=!C~TI3~q LiSTiN3 =aG5 I ]RI3IN, : :~EE, N~ME : 1~+9380 SO-'~TiNJATi2N ~ :01 PREVIOUS REEL : 20MMENTS :SCHL~qEERSER ~ELL SERVICES PR]PRIETAR¥ FIELD T&PE .~-,. TAPE HEADER SERVICE NAME :E3IT OAT= :~$/05/26 ORIGIN :FS1A TAPE N~ME : CONTIN:~TI2N ~ :01 PREVIOJS T&PE : COMMENTS :SCHLUMbERgER ~ELL SERViC=S PR3PRiET~RY ~IELD T~PE .,.... ~-~.L~. HE~DER .,-.,- FILE N~qE :EDIT .00i SEqVICE NAME : VE2SiON ~ : DATE : ,~AXIMU~ LENGTH : 1024 FILE TfPE : PRE~IOU5 FILE : .-~- INFORM4TION RE~ORDS M'N, E M C 0 N T E N T S CN : ~RCO ALASKA ~ N : D S 18 - 5 FN : PR'gDMDE i~Y RA,~: 14E T O W ,~: 11 ~ S E ~~ T: 2 ~ COJN: NORTH SLOPE STAT: AL&SKA ~NE~~ C~TENTS PRES: F NIT T Y P E C~TE S t Z E ~ ~ 3 O E ODD DO0 015 065 000 000 OOB 06!5 000 000 012 065 000 300 004 065 ODD DO0 gD¢ 065 000 000 002 065 OOO DO0 012 065 OOO 000 006 065 TYPE SIZE CODE OOg gO0 Ogl 065 305 NUMEER AT ~CC: 71553 ~UN ~1, DATE L:DSGED: 2Z-MAY-86 LDP: 2. Si~ES 'ASiNG : 9.525" SUR=~C~ T:3 TYPE FLJZ9 : DiL=~Z~FLU!] 5IT SIZ~ : ~.5" ]E~SiTY : ~.~0 L5/3 V:IS~.~ = _75.0 S RM ~ 8HT = - @ 160 D. 'iR'UL~TIOq ENDED= DgO0 5/!1 L0$~ER aN BDTTD~ = 103~ 5/~ ZAX, RE'. TEMP. = 150 DE~S= 1026& .VO OlO.d02 VE~i~ICATID'q LI~TIN3 Oa~= 3 ~',~ SSH: dv)g=-13ER L. aGS INS' UD53 ~,~Ir~ rqtS ;q~G~:rl~ r~-' -'- ALL DAT~ OVERLAYS THE ~ISLD 5LU: Li~. CNT 9AT~ INCLU3ED O~ Tq[S F~PE -- .VP OiO.HOZ VS~I~IC~I2'~ LISTIN3 ,~SE ~ ~RNRA,SDT : RAw N,,,,UTR:]N FCNL,S]T : :AR NCNL.SDT = NEAR COJNTS NPHi,SDT = NEUTRON POROSITY GR,SDT = SAN'.t& R2Y · " N]TE THESF~ L2GS '~RE NJT R:PR:S=NT.-_-D ]q 5_UE LINES CAN N2T 5E CERI=IE~ SDT 3i$iT~L SONIC O~T.& INC-Jg~D gN THiS T~P~ -- FRjM PI~LD ~NALDG PRDCESSZN$: FR 3M :~DT,SDT - DELTA T ~LSDT,SDT - ~ ]~g. SDAC:~ u_~'~L~. T (8 - I0 =T). ~:LDTL,SDT - LONG SPACE DELT~ T LJNG (1~ - 12 FT) ~ NDTE TH~SE L3G$ ARE NDT R~qESENT]3 ON &LU~ LINES C~ NOT 5f V~iFiED FI=LO_ STC. PR3C=SS~G:~ DTCD,STS - ~E~TA T C2qPR~SSZDN.~L · .-DTSM.,ST~ - DE~ TA T SH=.AR ~:D'TST,ST' - DE TA T STDNELY .V~ 010.~02 VERIFICATi9'~ LiSTIN3 ~A3:{ 3 X~: '3AT~ FORMAT :.NT RY TYP_: SIZE % I 66 3 ~ ~+ 65 .lin 15 1 65 ~ 1 66 ]ATJM SPECiFICATI3N BLD'KS ~NS~ SERVICE .SERVICE ~'qlT ID D~DER ~ ]EPT FT 3R SDT SAPt qP H I S DT P J ~RAT S3T RNR~k SDT ~CNL SDT SPS FCNL SDT DT S3T US/F DTL S]T JS/F LSDT SDT JS/F LDTL SDT JS/F D:~ C g S ,9 T d $ /F ]TSM SOT JS/F DTST SOT dS ~.Pl AP! APl '~I FILE SIZE SPL LOG FYPf CLASS '430 NO. O0 OOD O0 0 0 ~, 1 42 310 Ol 0 0 4 I 42 89,9 O0 0 0 4 1 42 420 O1 0 0 4 I 42 ~+20 O1 0 0 4 1 42 330 31 0 O. 4 1 42 330 3.3 O 0 4 I 42 520 80 0 0 4 1 42 520 $0 ~ 0 4 i ~. 2 52 D :8 D 0 0 ~ 42 520 80 0 0 ~ 1 42 000 O0 0 0 4 1 42 OOg OD 0 O F+ 1 42 OOO O0 O 0 ~+ ! R=PR C3]E 5~ 5B 58 5~ 5B PROCESS (O'TAL) OOOO00OO000000 O09000OO000OO0 00000000000000 O00000000000OO OOO0000OO00000 O]O00OO000OO00 O000000000OO00 O00000OO000000 O00000OO000000 00000000000000" 00000000000000 6800000000000000 6g O000000000OO00 58 OOOO0000000000 gEPT 13~23,500D GR RNRA 2,6331 NCNL DTL 84.2773 LSDF DTSM 0.0000 DTST 33,5598 NP~I 26.0254 30?5.5300 FCNL. 11:57.6875 O.OOO0 LOTL O.O900 O.O000 NRAT OT 3T'3 2.¢749 97.02'73 0.0000 .V~ OlO.MO2 VERIFIC~T!]~ LiSTIN3 P&S= 5 13~00.0000 SR 2.5331 NC'iL 1138.5375 LSDT 133.5675 DTST 13300.0000 3R 3.1252 NCN_ 1135.5875 LSDT 15~.D525 OTSF 13200.0000 GR 254.6875 LSDT 153,0525 DTST 13100.0000 GR 2.8284 NC~- 114.1523 LSDT 161.0525 DTST 13000.0000 2.517¢ 91.5273 125.5398 SR NCN_ LSD T DTSF 12900.0000 SR 2.5917 NC/. 131.4~7~ LSDT !51.0525 DTST 12800,0000 GR 2.7598 NCNL 122.6523 LSDT 130.O$25 DTST 12700.0000 ~R 2.8Z8¢ ~CNL 11¢.2773 LSDT 173.0625 DTST 12500.0000 SR 2.5292 NCNL 76.5523 LSDT t53.0525 DTST 12500.0000 GR 2.5555 NCNL 181.5575 LSDT 157.0525 DTST 12~00.0000 GA 2.~05 NCqL 107.552~ LSDT ,53. 3075. O. O. 1~2. 27]5. O. O. ~1. 3035. O. ~1. 3615. O. 1~4. 64. 3633. O. 195. 32. 3519. O. 195. 3,615. O. 1 ~2. ZT. 3633. O. 235. ~6. 3855. O. 1~6. 3739. O. 1 ~ 6. ?.b · 3557. O. 58'93 3000 JOg0 0000 0000 0000 2773 5000 0000 0525 5000 0300 0525 7148 5900 0000 0525 5000 0300 0525 5830 5000 0000 3t25 9736 5000 0000 0525 5000 0000 3525 5055 5000 0000 0525 576~ 5000 0000 qPdi LCT~ NPHI FCqL LOT: NPH! ~CNL LOTL FCqL LDTL NPqI LDTL N~HI FCNL LOTL FCNL LOTL NPqI LDTL NPH! FCNL LDTL NPHT LDTL N P q l FCq' ,... D T L 2.5.025~ NR&T I157.5~75 DT O.O000 32.3313 NR~T ~55.3125 DT 0.0000 9T'3 £8.9062 1053.5875 0.0000 28.652i 1277.5575 ST O.OPOO DT Z4.$535 NR~T 1376.6575 ]T O.O00O DT'D 27.6955 NR~T 1307.5575 DT 0.0300 DT'S 27.2949 qR ~ T 1B04.6875 DT 0.0000 DT'] 27.836'7 NR&T i204.6375 D~T 0.0000 DTC3 Z5.8301 NR~T 1¢66.5~75 DT 0.0000 OTSD !,5.53.59 NR~T 1407.6~75 9T 0.0000 DT"3 ??.8~309 NR~T 1334.5975 ST 0.0000 DTC3 2.~749 1227.5875 59.0273 2.~752 1192.6375 78.0273 2.5563 124.3398 73.0273 2.5506 11'5.5898 97.0273 2.3957 93.5523 70.0273 2.5842 113.9549 57.0273 2.558'8 115.6523 g1.0273 2.5823 124.1523 102.0273 2.4512 112.0898 91.0273 2.4435 I¢1.6875 93.0273 2.5979 105.2773 ~3.0273 .VD 010.H02 VEqiFICATi~ LZSTi~i ~SE ? 164.0525 12300.0000 2.3315 I05.I523 2.~?06 105.77T3 156.0525 12100.0003 3.0381 125.5523 174.352~ 12000.0000 2.5995 114.5273 175.0525 11900.0000 3.0519 118.1523 153.95!5 11~00o0000 2. 5292 176.0525 11 700. 0000 2.6~95 99. 0273 145.0 $ 25 1.8731 122,1523 176.0525 11500. 0000 2.0374 135,9375 156.0525 11~00.0000 1.7139 -2.1248 147.0525 11300.0000 !.82'72 DTST 3R LSDT OTST GR N~,q_ LS3T OTST 3R NCNL LSDT DTST NCNL LS3T OTSF ~R NCNL DTS~ OTST GR NCq. LS~F DTST ~R NC~L LS~DT DT S T SR NCN ~ LS 3 F OTST NC N L LSO T DTST 5R 1~5.0525 "6. 4!51.2500 0.9300 1~5.J525 35.0%30 38P~.5000 195.8525 22.3~55 3655.5300 0.0000 196.3525 18.0986 3959.5000 0.0000 1~0.0525 19.2851 3551.5000 0.0000 192.0525 20.2393 40~1.5000 0.0000 195.0525 &7.1992 3819.5000 O.OOO0 190.0525 15.2393 4931.2500 0.0300 195.0525 19.4893 45D3.2500 195.0525 16.2235 5299.2500 !~5.0525 16.1511 5457.2500 FC~L LDrL NPqI FC~i' LSTL N~qI FCNL LDTL LDTL NPqI LDTL NPfli LOT' NPqi FC~L LDTL NPHI FC~L LDFL N ? qi FCqL LDTL No~i FC~L LgTL N P H I i5.1¢,55 N~T 1554.,5375 DT O 0~00 ]T-~ 25.9756 NR&T 14~1.6~75 DT 0.0900 OT'3 3!.3977 XRtT !!~3.8375 DT 0.3000 DT~] 27.5379 NR~T ,145~.5375 DT O.~O00~ DT"]~, 32,2754 NR&T 1153.5575 DT O.OOO0 DT'3 26.6502 NRaT 1536.6375 DT 0'0000 DTS3 5 9?77 NR~T 1414.5375 DT 0.0200 DTS] 15.5273 NR4T 2531,5090 ]T 0.0000 DTCD t7.4~05 NR&T 2209.5300 ~T 0.0300 OTC] 13.2324 NR~T 3091.5000 DT 0.0300 OTS~ 14.5505 NR'AT 2991.5~00 DT 2.~1'B2 I09.J~95 89.0273 2.4729 109.5523 71.0273 2.8284 1¢8.3125 104.0273 2.578~ 115.5273 97.027B 2.8909 121.5273 103.0273 2.5178 1~0.3125 102..0273 2.4690 98.¢023 74.0273 1.7745 125.5898 105.0273 1.9044 229'18'75 99.0273 1.5221 292.5625 95.0273 1.7110 1228,.6~'75 .VP OlO.HO2 VERiFICaTIS~ LISTiN3 PaiSE )TL )TSVl ]EPT ~ N R ,.1. )TL ]TS'q RNR~ )TL )TS'4 ]EPT ~Nq~, DTL 3TSM DEPT RNR~, DTL DTS'q DEPT RNRA D? L ~T SM DF, Pl' RNR~ DTL DEF'T RNR& gTS '~ DEPT RNR4 DT L D T S M DEPT RNRA DTL DTSM DE RNR~ DT L DTSM DEPT 2001.5875 LSDT 166.0525 DTST llZO0.O000 gR 1,9981 NC~i_ 89.4023 LSDT 1~3.0525 DTST 11100.0000 SR 1.7130 NCN_ 91.2773 LS2T 1G9.0525 2TST llOOO.O000 SR 1.5752 NC~L 129.5525 LS]T 141.0525 DTST 10900.0000 SR 1.4971 NC 1098.6575 LS 132.0525 gT S1' lO800.DO00 GR 1.7~75 NCN~ 2~7.5~75 L$DT 158.0525 DTST 10700.0002 SR 1.7%62 NCN~ 106.9~23 LSDT 143.0525 DTST 10500.0000 GR 2.0~52 NCNL 120-9023 LSDT 158.0525 DTST 10500.0000 GR 2.6135 NCNL -20.3076 LS]T 125.0273 DTST lO~O0.O000 SR 2.1272 NCNL 38.5117 LSDF 159.0525 DTST 1030O.OOO0 SR 2.1057 NCqL 145.3125 LS]T t60.0525 JTST lOZO0.O000 GR O.ODO0 211.3125 22.9258 50 :+3. 2500 0.0000 199.0525 17.1924 5337. 2500 O.OOO0 1~9.0525 17.9111 5171.2500 0.0300 199.0525 15.7080 5375.2500 0.0000 202.0525 i8.5.518 5555.2500 O.O000 232.0525 53!7.2500 0,0300 2~2.0525 23.00~9 4755.2500 0.0900 202.0525 57.8398 3419.5000 O.OOO0 195.0525 Z1.617~ ~227.2500 O.O000 195.0625 Z0.61~3 ~327. 0.0000 1]~5.0525 35.6055 L~TL NP~i LDTL L~,T1 ~' ,.,. NPHi :CNL LJTL NPMi FCNL LDTL NPqZ FCqL LDTL NPHI $CNL LDTL FCNL LDTL NP~I F~NL LOTL NP~i FCNL LOTL FCqL LDTU 16.5gg2 NR~T 2523.5300 DT 0.0300 DTS3 13.3789 NR~T 30~7.5000 DT 0.0000 DTSJ 10.3515 NR&T 3913.5200 DT 0.3000 gTC3 10.3027 NR~T 35~9.5000 DT 0.0000 OTC3 13.3301 NR~T 3271.5000 DT 0.0000 3TS3 !3,2~13 NR&T 3049.5000 3T O.O00O DTC3 17,9199 NR~T 2323.5000 OT 0.0000 DTCD 24.95i2 NR&T 1307.5B75 DT O.OgO0 OTC3 19.3359 NR&T 1955.5B75 OT 0. 0000 DT~3~ 13.9~1 NR~T 2053.5000 DT 0.0000 DTS3' 108.0273 1.8536 95.5523 55.0273 1.5329 113.5273 95.0273 1.~317 176.8125 90.0273 1.4258 210.3125 84.0273 1.6280 235.390,5 8'9.0273 I .5251 10,6. 5273 91.0273 1.9356 123.1523 98.02?3 2.4026 21.8799 71.0273 2.0276 132.9375 !10.0273 2.0081 145.4375 106.0273 1.8829 ~N~a 1.9593 N3~' )TL 54.&~92 LSDT ]TSq 106.0273 DTST )SmT 10120.0000 3R ~NR& 2.3147 NCN. )IL 45.2517 LSDT )ISM 118.0273 3TST 2797. 5000 1 35. 0525 13.5351~ 2399.5000 0.3300 195.0525 9.0300 ~T"] -22.3!~5 q~&? i336.5875 3T 0.0}33 OTC3 55.1357 55.01!7 2.2253 5:3 · &~92 57.0117 ~:',~ :ILE TRAILER ;:::',~ =ILE NAiF :EDIT .001 SERVICE NAME : CESSION ~ : DATE : ~AXIMUM L,:NST.,i : 102~ :iLE TYPE : NEXT FiLE NAME : · ',-'~: TAP5 TRAILER :',:~:: SERVZCE NAME :.-=3I T DATE :~5/05/25 9RiGIN :FSlA TAPE N~'qE : CONTINJ4TiON ~ :01 NEXT TAPE NAME : COMMENTS :SCHLUMBERGER NELL SERVICES P R'3PR ! ETAR Y ~IELO T~PE ~¢ RE~L TRAILER SERVICE NAM5 :EDIT DATE :85105126 ORIGIN : REEL N~ME :149380 CONTINUATION # :01 NEXT RE~L NAME : ~O~MENTS :SCHLO~B~RS:R. N'ELU SERVICES PRSPRIE'TARY FIELD TAPE , AbASKA COMPUTING CENTER * , * ****************************** , .... .-- $CHbUMBERGER ****************************** COMPANY NAME WELL NA~E FIELD NAME BOROUGH STATE REFERENCE NO ARCO AbASKA, INC, D"$,18"5 PRUPHOE BAY NORTH SbOPE ALASKA 50-029-21583 73717 RECEIVED APR ! 8 1990 Alaska, Oil & Gas,Cons. Commisslort AncNorage IS Ta-e~ Verification Listinq thin,herDer Al, asEa Comput~no Center 29-~AR-1990 07:43 **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 90/03/27 ORIGIN ! FbIC REEL NAME : 73717 CONTINUATION # : P~EVIOUS REEL : C~FNT : ARCO ALASKA, INC,,PRUDH{)E BAY,D.S. 18-5,API #50-029-21583 **** TAPE HEADER **** SERVICE MANE : EDIT D~TE : 9o/03/~7 OPI~IM : FbIC T~PF MA~E : 737~7 CONTINUATION # PREVIOUS TAPE COMMENT : ARCO ALASKA, INC.,PRUDHOE BAY,D.S, 18-5,API ~50-029-21583 **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC YE~SION : O01A04 D~TE ~ 90/03127 ~AX REC SIZE : !024 FILE TYPE : LO LAST FILE ~ ******************************************************************************* ******************************************************************************* ** ** ** ** ** SCHLUMBERGER WELL SERVICES ** ** ** ******************************************************************************** ******************************************************************************* Co~PANY NAME: ARCO ALASKA, !NC, WFLL: D.S. 18-5 FIELD: PRUDHOE BAY BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-21583 LOCATION: 752' FNL & 22~' F~L SECTION: 24 TOWNSHIP: lin PER~MEMT DATUM: ~Sh ELEVATION: 0 RANGE: 14E ,IS Tape Verliication I,lStlng ;chlumberqer Alaska Computinq Center 29-~AR-~.990 07:43 MEASURED FRO~ RKB 49 ABOVE PERNANF~T DATUY F. LEYAT!ONS ,B: 49 DF: 48 GL: 16 DATE LOGGED: ~4-FEB-1990 RUN NUMBER: ONE TD DRILLER: 13445 TD LOGGER: 0 CASING: SI,OT LINER: 9 5/8" 47 LB ~ DRILLER DEPTh OF 0 TO 10265 7" 29 LB ~. DRILLER DEPTH OF 7919 TO 12500 4 1/2" ~3.5 LB m DRILLER DEPTH OF 12409 TO 12965 TYPE FLUID IN NOLE: PRODUCED FLUIDS TIME LOGGER ON BOTTOm: 15:00 24-FEB LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDHF3E BAY !MCBRIDE/BARNARD RIC.H/HURST/BRADLEY T~OL NUMBERS: SHHEB 1108 TND-P-90 AT~-AA 160 TNC-P-90 TMG-P-90 IED-IN TO ARRAY SONIC OF ~2-~AY-86 ~URRENT GOC FOUND AT 118~4 LOGGING SPEED OF 30 F/M REOUESTED BY CLIENT COMPUTING CENTER REMARKS: TRAT ON THIS TAPE MATCHES CHANNEL CALLED bCOI ON BL3E~LINE;S AS PE~ CLIENT REQUEST bCO1 - TSCN / T$CF TRAT,HLA : HODGb$-GEHMAN AVERAGED TRAT OF 3 PASSES TPHI.HLA : HODGES-LEHMAN AVERAGED TPHI OF 3 PASSES SIGM,HLA : HODGES-LEHMAN A~E~AGED SIGMA OF 3 PASSES DATE JOB STARTED: 26-MAR-90 JOB REFERENCE NO: 73717 LDP/ANA~ KOHRING PAGE: FILE ' ARCO ALASKA, INC. PRI. JDHOE BAY PASS ~1 bOG DAT~ AND HODGES-I~EYMAN AVERAGED SIG~qA, TRAT, AND TPHI IS Tape Verification Ltstlno chlumberger Alaska Computing Center 29-~AR-1990 07:43 DATA SAMPLED EVERY -.5000 FEET DATA INCLUDFD - TOOL EXTENSION TYPE USED TDT-P .PSl TDT-P ,~LA TOOL THERMAL DECAY TOOL AVG SIG~A,TRAT,TPHI 12500° TO 11496' 12500' TO 11496' PAGE: 3 TABLF TYPE : CONS TUNI VALU OEFI CN ARCO ALASKA' INC Co~p 5;N . aD ame FN PRUDHOE BAY Field Name APIM 5 FL 752' FNL & 221' FEL SECT 24 TOWN RaNG COUN NORTH SLOPE STAT ALASKA NATI USA WIT~ ~ICH/HURST/BRADLEY SON 379258 PDAT MSL EPP FT 0 .L~F APD FT 49, ~B 'FT 49. EDF FT 48, EGL FT ~6 TDD FT 13~45 TL I PT 1 1 295 TLAB !5.0 24'FEB Well Name AP1Serlal Number Field Location Sectlon Township Range Counts; State or Province Nation witness' Name Service Order Number Permanent datum Log Measured ~ro~ SottomoS~ Interval To~ Lo, '"terval Time Logger At Bottom TABLE TYPE : CUPV DEFI DEPT Depth Channel Name SI~ Sigma (Neutron Capture Cross section) TRAT TDT Ratio TPH! TDT Porosit~ $IG~ Sigma (Neutron Capture Cross Sectiom) IS Tape Verification blstinq chlumberger Alaska Computind Center 2g-SAR-lgg0 {)7:43 .... --;[; .... ; ...................... . ................. ST Sta of · DT ISHU SFFD SFNP SBHF SBH~' FTDT NTDT AFFD ~BFD AFND $IGC ~MOr TRAT SDS~ 8~CK FBAC TCAN TCAF TCND TCFD ?SC~ T$CF INND INFD TTEC H¥ RN3 RN5 RN6 RN8 RN9 R~0 RN]! RNa2 RNa4 RN15 RNa. 6 RF4 TDT Porosity TDT Shunt Current Sigma formation - far detector (TI)TP) Sigma formation - near detector (TDTP) Sigma borehole - far detector (TDTP) Sigma borehole - near detector (TDTP) Far TDT~ Count Rate Near TDT~ Count Rate - far detector (TDTP) Amplitude formation ~ F r detector (TDTP) AmPlltt~de borehole - a AmPlitude formation - near detector Amplitude Borehole -- near detector (TDTP) SIGM Correction Borehole sigma (corrected) -- TDTP ~inltron mode monitor ratio (TDTP) TDT Ratio Standard deviation of Sigma-formation (TDTP) Back,round, l~ear Gates Far ackground Total counts analyzed - Dear detector (TDTP) Total counts analyzed - far detector (TDTP) Total counts - near detector (TDTP) Total counts -far detector (~DTP) Selected gates count rate - near Qetector (TDTP) Selected gates count rate - far detector (TDTP) Inelastic counting rate - near detector (TDTP) Inelastic counting rate- ~ar detector (TDTP) TDT-P Telemetry Error Count Head Volta~ Status of C Raw Near ~st Gate Raw Near 2nd Gate Raw Near 3rd Gate Raw Near 4th Gate Raw Near 5th Gate Raw Near 6th Gate Raw Near 7th Gate Raw Near 8th Gate Raw Near 9th Gate Raw Near ~Oth Gate Raw Near l.~th Gate Raw Near ~2th Gate Raw Near ],3th Gate Raw Near ~4tb Gate Raw Near 15th Gate Raw Near 16th Gate Raw Far ~st, Gate Raw Far 2nd Gate Raw Far 3rd Gate Raw Far 4th Gate Raw Far 5th Gate Raw Far 6th Gate PAGE: IS ?ape Verification Listtnq chlumbero, er ~!ask~ Comvutinq Center 29-~AR-1990 07:43 PAGE~ DEFT RE7 Raw ~ar 7th Gate RE8 Raw Far Rth (;ate RFg Raw Far 9th Gate RFIO Ra~ Far loth Gate RFI~ Raw Far llth Gate RE12 Raw Far !2th Gate RF13 Raw Far 13th Gate RF14 Raw Far 14th Gate RF15 Raw Far 15th Gate RF16 Raw Fa~ 16t~ Gate GR Gamma TENS Tension CCL CCL AmPlitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE REPR CODE VALUE ~ 66 0 ~ 66 0 3 73 284 4 66 1 5 66 6 7] 7 65 $ 6~ 0 5 11 66 3 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE- CHAN ** NAM~ SERV UNIT ~SERVICE API API API APi FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~P ELE~ CODE (HEX) DEPT FT 379258 O0 000 O0 0 i I ! 4 68 0000000000 $IG~ HLA CU 379258 O0 000 O0 0 .1 I i 4 68 0000000000 TRAT HLA 379258 O0 000 O0 0 1 I 1 4 68 0000000000 TPH! MbA PU 379258 O0 000 O0 0 I t I 4 68 0000000000 SIG~ PS1 CU 37925~ 51 400 O! 0 1 1 ! 4 68 0000000000 STDT PSI 37925~ 51 390 O0 0 I 1 ! 4 68 0000000000 IS Tare Yerlflcation blstlng chlumber~erAlaska ComDutlnq CeDter 29-~AR-1990 07:43 PAGE% NA~E U IT SEPV _. N Z REP P C ID ORDE~ # LOG TYPE Cb~SS NOD NUMB !Au? ELE~ CODE (HEX) ''''''''''';TPNI PSI U ..... 3.92~'';~'''51 Bg0' ............ O1 ISMU PSI V 379258 51 000 00 0 i 1 1 4 68 0000000000 SFFD PSl CU 379258 5X SBHF PS! CU 379258 51 $SHN P$1 CU 379258 FTDT PS1 CPS 379258 5! NTDT PS1 CPS 379258 51 AFF~ PS1 CPS 379258 5X ABF~ PS], CPS 379258 AFND PSi CPS 379258 5t ABND PS1 CPS 379~58 51 $IGC PSi CU 379258 5~ $~BH PS/ CU 379258 51 HHOF PSi 379258 5~ TPAT PS! 379258 5! 5D$I PSi C[! 379258 5~ BACK PS~ CPS 379258 5! FBAC PS1 CPS 37925~ 5~ TCA~ P$I 379258 51 TCAF PS! 379258 51 TCND PS1 CPS 379~58 5~ TCFD PS1 CPS 379258 51 TSCN PSi CPS 379258 51 TSCF PSi CPS 379258 5I INND PSi CPS 379258 51 INFD PSi CPS 379258 51 TTEC PSi 379258 51 HV PSi V 379258 51 SATC PSi 379258 51 RNi PS1 CPS 379258 51 RN~ PS1 CPS 379258 51 RN3 PS! CPS 379~58 51 ~N4 PSi CPS 379~58 51 RN5 PS1 CPS 379258 51 RN6 PS! CPS 379258 5! ~N7 PSI CPS 379258 51 8N8 PS1 CPS 379258 51 RN9 PS~ CPS ~79~58 51 RN!0 'PS~ CPS 379258 5! ~Nll PSt CPS 379258 51 RNI~ PS! CPS 379258 51 RN!3 PS1 CPS 379~58 5~ RN14 PS1 CPS 379258 51 RN!5 PS1 CPS 379258 ~NI6 PS! CPS ]79258 51 ~F! PS! CPS 379258 RF2 PS! CPS 379258 51 ~F3 PSl CPS 379258 5~ RF4 PSI CPS 379258 5~ ~5 PS~ CPS 379258 51 400 02 0 ! 1 ! 4 68 400 02 0 1 1 1 4 68 400 O~ 0 ! 1 1 4 68 400 O! 0 1 ! 1 4 68 000 O0 0 I 1 1 4 68 000 O0 0 I I I 4 68 391 O0 0 1 1 1 4 68 391 O0 0 1 1 1 4 68 390 O0 0 1 1 1 4 68 390 O0 0 1 ! 1 4 68 400 Ol 0 I t I 4 68 400 O1 0 1 i 1 4 68 000 O0 0 i 1 1 4 68 000 O0 0 I ! 1 4 6~ 000 O0 0 1 I 1 4 68 390 17 0 1 1 1 4 68 391 17 0 1 I 1 4 68 000 O0 0 1 I I 4 68 000 O0 0 I 1 I 4 68 000 O0 0 1 1 I 4 68 000 O0 0 1 1 1 4 68 000 O0 0 I 1 1 4 68 000 O0 0 1 1 1 4 68 000 O0 0 I 1 1 4 68 000 O0 0 i ! 1 4 68 390 O0 0 1 I 1 4 68 000 O0 0 1 1 1 4 68 000 O0 0 1 1 I 4 68 390 O1 0 I 1 1 4 68 390 02 0 i I 1 4 68 390 O~ 0 I t 1 4 68 390 04 0 I ! ! 4 68 390 05 0 i 1 I 4 68 390 06 0 1 1 1 4 68 390 07 0 i I 1 4 68 390 08 0 1 1 1 4 68 390 09 0 ! I I 4 68 390 I0 0 1 t ! 4 68 390 11 0 I 1 1 4 68 390 i2 0 1 I I 4 68 390 i3 0 1 i 1 4 68 390 14 0 1 1 ! 4 68 390 15 0 I i I 4 390 16 0 i ! I 4 391 Ol O . I 1 I 4 39l 02 0 i I 1 4 391 '03 0 I I 1 4 39t 04 0 ! I 1 4 391 05 0 1 I 1 4 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0O0OOO000O 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 IS Tape Verification 5istlnq chltlmberger AlasKa ComputinO Center 29-!~AR-!990 07:43 NAME Sr~."RV I E VI ElaN... T S R C API API AP1 API ILF E NIJ~B [-JU.,B~ M SIZE REPR PROCESS. ID ORDER # LOG TYPE CLASS MOD NUmB SA~P ELES~. CODE (HEX) ......... ............................ ........... RF6 PS1 ] 5 1 391 06 1 1 1 4 68 0000000000 51 391 07 0 I ! .1 4 68 0000000000 RF7 PS! CPS 379258 RF8 PS! CPS 379258 51 RFg PS! CPS 379258 51. ~FIO PSi CPS 379258 51 RF!~ PS1 CPS 379258 51 RF12 PSi CPS 379258 51 RF13 PSi CPS 379258 51 RF14 PSi CPS 370258 51 RF15 PS/ CPS 379258 5~ RF16 PSI CPS 379258 51 GR PS1 GAPI 379258 51 391 O8 0 1 1 1 4 391 09 0 1 1 1 4 68 391 10 0 1 1 ! 4 68 391 ~1 0 1 1 1 4 68 391 12 0 1 I 1 4 68 391 13 0 ~ I ! 4 68 ]91 14 0 I 1 ! 4 68 ]~1 15 0 1 I 1 4 68 391 16 0 I 1 1 4 68 310 01 0 I f ! 4 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TF..N~ PS1 LB 379258 Sl 635 2X 0 ! 1 X 4 68 0000000000 CCL. PSl V 379258 51 1.50 .01 O. ~ I I .4 .6.8 .0.00.0.0.00.0.0...0 ** DATA ** DEPT $IGP PS1 SFFD FTDT PS1 AFND PSi MPOF PSI FMAC PSI TCFD PSI INFD RNg'P$! R~I3,P$1 RFS,PS1 ~Fg,PSl PF13,PS1 DEPT SFFD PSi FTDT PSi AFND PS1 MMOF FBAC TCFD INFD PSi R~ RN5 PSI RNg PS! RNI3 12507.500 '999 25O '999:250 '999.250 =999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~0 -999,250 -999,250 -999,250 -999,250 000 12500,018 35,874 24.854 4]8,206 1 lq7 24 623 9112 953 452 086 928 030 !680 871 2078 598 3243 371 SIGM,HLA STDT,PS1 SFND,PS! NTDT'PSI ABN[).P81 TRAT,PSI TSCN,PS! TTEC,PSl RN2PS! RN6 PS1 RNIO PSi RN14 PS1 RF2 RF6 RFIO PSi RFI4 PSl TENS $IGM.HLA STDT,P$! SFND.PS1 'NTDT'PS1 ABND,PS! TRAT,P$! CAN'P$1 TTscN,PS! TTEC,PSI RM2'PS1 RN6,P$1 RNIO,PSI RNI4,PSI 12 438 TRAT,HLA -999 250 TPHI,PSi -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 SBHF,P$! 250 AFFD,PS1 250 SIGC,PS1 250 SDSI,PS! 250 TCAF PS! 250 TSCF PS1 250 HV PSI 250 RN3 PS1 250 ~N7,PSt 250 R~ll~P$1 250 RN!5,P$1 250 RF3'PS! 250 RF7,PS1 250 RFII.~P$1 250 RFI5,PS1 250 CCL'PSI 2~ 847 TRAT.HLA 66:O0 TPHI'P$I 88o 387 SDSI PS1 9~015 ~3 TCAF PSl 514 6 ~U:,..CF PSl 0 000 HV PS1 51 600 ~N3,PSI !747 !59 RN7,PSI 24 .7,9 7 2 367 TPHI.HbA -999 250 ISHU,PS1 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 SBHN.PS! 250 ABFD.PS1 250 SIBH.PS! 250 BACK.PS1 250 TCND 250 INND 250 SATC 250 RN4 250 RN8 .250 RN12 .250 RNI6 250 RF4 250 RF8 250 RF12 250 RFI6 ~50 PSI PS1 PS1 PS1 PS1 PS1 ,PS1 72 66 0 6 35063 3!48 239 !!26 10 438 TPHI,HLA 61 638 ISHU~P$! 244 SBHN,P$1 516 ABFD,PS~ 000 SlBH.PS! 298 BACK,PS1 094 TCND,PSl 828 INND,PS1 750 SATC.PS! 894 RN4,PS1 1197,917 RNS,PS! 3125,000 RNi2'PS! 1302.083 RNI6.PSI .27 539 -999 250 -999 250 '-999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 999,250 28,613 32,531 139,206 0,852 261,,983 59,030 28829,660 2808,089 i. O00 1600,379 980,114 3371,212 535,038 I$ Tare Verification Listinq chlumberger ~laska Computing Center I~F! .P$1 326.705 RF'2.P$! RF5 PS! 459.280 RF6'PSl PFgiPSi 729,167 RF, O~PSl RFI~ PS1 1216.856 ~F14 PS1 DFPT 12400,000 SIG~,HLA SFFD,PSI 36.276 SFN FTDT.PS1 6.175 NTDT'PS1 AFND PS1 323.550 ABND.PS1 MMOF:PS1 1 294 TRAT.PS1 FRAC PSi 13:327 TCAN TCFD:PS1 4918.205 TSCN:PS1 INFD.PS! 336,232 TTEC,PS1 RN1 PS1 914,352 RN2,P$1 ~N5iPS1 1325.231 RN6,PSI RN9 PSi 1657.986 RN10,PS1 13,PSl 3767.940 RN14,PSl R;FI.PSi 235.746 RF2.PS1 RFS,PSI 271'382 RF6 PS1 RFg. Ps1 ]78.2~9 RFIO:P$1 RF13,PSI 652,412 RF14.PS1 G~,PSI 8,445 TENS.PSi DEPT SFFD FTDT AFND M~OF FBAC TCFD INFD RN5 ~N9 RN13 ~F5 RF13 G~ PS1 PS1 PS1 PS1 PSI PS1 PSI PSi PSi PS1 PSI PSi PSI PSi PS1 12300,000 1~,599 13.565 9.910 490.554 1'~77 17 622 7868 672 341 891 881 944 !454 861 I847 222 3059 027 267 857 338 542 513,393 1101,190 I6,094 $!GM, STDT' NTDT ABND TRAT TCAN T$CN TTEC RN6 R~I0 RN14 RF R~IO RF14 TENS H LA PS1 PS1 PS1 PS1 PS1 PSi PSI PSi .PSi PSi .S!G~ FTDT AFND M~OF FBAC TCFP iNFD PS1 PS! PS1 psi PS1 PSi PSi PSI 1220().000 15,597 16,463 8,8!4 483,572 1,220 17,973 6672,369 345,061 849,609 t4~5,]!2 SIG~. STDT, SFNO, NTDT, ABND, ~RAT TCAN TSC~ TTEC R~2, RM6, HLA PSi PS1 PSl PSi PS1 PSl PSi PS1. PSI 29-~AR-1990 07:43 20 640 RF3,PS1 549:242 RF7,PS1 681.818 ~FI!.PSI 1054.280 RF15,PS1 210,000 CCL.PS1 15,180 66,000 1~,266 16,676 460,~98 2,406 29300 414 4149:287 0 000 59 340 1134 259 1542 245 1519 O97 9.288 279 605 3~9 254 583 882 190 000 12.508 6.000 5,0~3 27,2 5 435,0!7 2 478 44902 ~5 8228 8 0 000 89 010 1506 944 I788 ~94 2812 500 24 768 394 345 558 036 1,!12;351 !95,000 15,055 66 000 18:~73 24,992 442,862 2,555 34 477 0.ooo 92,880 1455.078 TRAT.HLA TPHI.PS1 SBHF.PS1 AFFD,PS1 S!fiC PSI SD$I:PSI TCAF,P$1 TSCF.PS1 HV,PS1 RN3,PSI PN7,PS1 RNll,PS1 RN15.PS1 RF3.PS1 RF7,PS1 RFII,PS! RF15.PS1 CCL.PS! TRAT.HLA TPHI,P$! SBHF,PS! AF~D.PS~ SIGC,P$1 SDSI.PS1 TCAF,PSI TSCF'PS1 RN3'PSI RNT,PS1 RNII:'PSI PF3'PSi RF7,PS! RFII,PS1 ~15,PS1 CCL,PSI TRAT,HLA TPHI,PS! AFFD;PS1 SIGC~PSi SDSI~PS! ~CAF'PS1 SCF.PSI ~V,PSI RN3.PS1 RN7,PSI 274 383!523 1089 015 700 757 0.000 2 383 32:684 66 062 63 584 0 762 0 288 12177 223 1724 440 240 375 1241 319 665 509 2013 889 980 903 235 746 200 110 526316 452 303 0 000 2 492 31 761 40 696 99 672 0 847 0 248 18119 512 32O 109 100~ 278472 2701389 !885 417 234 375 3!9 940 796 131 855 655 0 000 2.525 35,658 48,475 92.317 0.917 0.345 13443,943 2433.390 242'875 116,536 1957;031 RF4.FS~ PS1 RF12:PS1 RF16.PS1 TP~I.HLA ISMU.PS1 SBHN PSI ABFD:PSI SIBM.PS1 BACK.PS1 TCND.PS1 INND,PS1 SATC.PS1 RN4.PS1 RNS.PS1 RN12.PSI RN16.PS{ RF4.PS1 RF8 P$! RF12:PSI RF16.PSI TPHI.HLA iSHU PS1 SBHN:PS1 ABFD.PS1 'SIBH.PSI BACK.PS! TCND.PS1 INND,PS1 RN4,PSI RNS,PS1 RN16.PS1 RF4.PS1 RFB,P$1 RFI~,PSI RF16.PSI TP}~,HLA ISM,PSI SBMN P ABFD'PSt SIBH.PS1 BACK.PSI ~C~gD PS1 INND:PS1 SATC,PS1 RN4~PS1 RNS.PS1 PAGE: 421 401 388}258 1131 629 246 212 1 396 73 825 80,006 111 275 72 887 189~8 527 3124 697 1-000 1571 180 963 542 1822 917 407 986 307 0!8 274 123 561 952 150 768 31 836 33 344 55 393 100 728 70 907 90 018 26252 617 273~ 339 000 I371 528 968750 2826389 833 333 293 899 275 298 985~63 401 86 33 936 32 094 57 000 93 597 75 252 101 t8 23508 ~33 2670 690 i o00 1432 292 934 245 ,IS Tame Verification blstlng ;chlumberger AlaSka Computlnq Center ~N9 PS1 1858.724 RNIO.PSi R~13iPS1 2520.297 ~14.PSt F! PS! 256.696 RF2,PS1 PF5,PS1 334.82! RF'6.PS1 RF~.PSI 53!,994 RF!O,PS! RF13 PSi 941,220 RFI4.PS1 GR:PS! 16,719 TENS.PSI DEPT, 12100.000 SIGM.HLA SIG~.PS1 11.881 STDT.PSI SFFD,PS1 12,855 SFS!O,PS1 FTDT.PS1 9.754 NTDT.PS1 AFND,PS1 50!.406 ABND,PS1 M~OF.PS! 1,149 TRAT.PS! F~AC,PS! 19.45~ TCAN,PS1 TCFD,PS1 7746.567 TSCN,PS1 INFD,PS! 308,9~! TTEC,PS! RHI.P$1 844.494 RN2,PS! ~NS.PS1 1350,44.6 RN6,PS1 RN~,PS1 174!.071 RN10,PS1 RN!3 PS1 3!84,523 RN14,PSI RFI:PSI 256.944 RF2,Ps! RFS.PS1 305,556 RF6.PS{ ~F~.PS! 510,417 RFIO,PS1 RF13,PS1 1104,167 RF14.PS1 G~,PS! 13,0~3 TENS,PSi D~PT SFFD FTDT TCF~ RN13 GR 12000, PS1 ~!' PS! II, PSI 9 PS! 496 PSi 1 PSI 21 PS1 7954 PSi 324 PS1 863 PSI 1391 PS1 1744 PS1 3273 PSi 236 PSI 3~9 PSi 51=3 PS! 1107 PSI 10, 000 SIGM,HLA 379 STDT,PS1 968 SFND,PSi 462 hTDT.PS1 25 ABND,PS! 15 T~AT ,PSi 987 TCAN,P$1 769 TsCn,PSl 003 TTEC'PSi 095 RN2'PS1 369 RN6,PSI 792 809 RN14,PS1 411 RF2*PSI 61 RF6'PS! 889 RFI, 0~PSl 639 RFI4,PS! 453 DEPT,p 11900.000 SIG~,HL~ SIGM,,.Sl ' 11,812 STDT'PS AFNDSPS{ 506'279 ABND'PS1 M~OF,PSI t.225 TRAT,PS! FBAC,PS1 22,903 TCAN.PSi TCFD.PS1 7466,736 TSC~'DS! iNFD,PS1 3~8,600 TTEC,PS1 29-~AR-19qO 07;43 1767 578 RNI 1,PS1 2044!2~1 RN15,PS1 15 4 0 ~F3.PS1 412'946 RF7.PSI 546 875 RFll,PS1 859:375 RF15°PSl 185,000 CCL,PS1 11 836 66 000 14 028 28 246 406 835 2 654 50449~375 9151.510 0,000 92.880 1532 738 1729 911 3102 678 15 480 402 778 458 333 1152 778 215 000 11 148 66 000 13 613 27 50571 4 .9279 318 0 000 14 1 31!7 559 23 220 368 056 524 306 1177 083 200 o0o il,96! 66,000 14.364 28,311 407,369 2,709 48899 391 8958 195 0 000 TRAT.HLA TPMI,PSt SBHF,PS1 AFFO,PS1 SIGC.PSI SDSI.PS1 TCAF.PS! TSCF.PSI HV,PS1 RN3,PS1 RN7,PS1 RSlI,PS1 ~N15,PS1 RF3,PS1 RF7.PS1 RFll.PS1 RF15,P81 CCL,PSi TRAT HLA TPH! SBHF PS1 AFFO PSl 'SIGC PSl SDSI PSI TCAF, PS I ~ ~ T~C~, H V, P $1 2486 1402: 256. 256. 773. 550. O. 2 40 99 0 o: 19010 3448: 243, 1000. 1168 2648 226.~ 22~ 340 760 S40 0 2 34 41 96 0 0 19583 3593 1034 ~160 ~2622 2406 ~25 340 815 :993 0 2 38 41 96 0 0 18050 3306 242 979 995 696 696 809 595 000 654 106 173 394 766 236 426 488 375 744 155 809 904 694 278 4~7 278 000 588 394 933 579 768 216 855 425 000 226 714 768 994 694 278 972 055 000 68O 0 O8 889 24O 898 235 741 75O RNI2.PS1 RN16,PS1 RF4,PS1 RF8.PSI RF12.PS1 RF16.P8! TPHI.HLA iSHU.PS1 SBHN.PS1 ABFD,PSt SIBH,PS1 BACK.PSi TCND.PS1 INND PS1 SA.r,,PS1 RN4.PSI RN8,PS1 RN12'PS1 ~N16,PS1 ~F4,FS1 RFB.PS1 RF12,PS1 RF16,PS1 TPHI.HbA ISHU,PS1 BHN..PS! ABFD'PS1 SIBH,P81 BACK,PS1 TCND,PS! INND~PS1 SATC,PSl RN4,PSI RNB.'PS~ RN12,P81 RN16,P$! RF4,PS1 RFB,PSI RFI2'PS1 RFI6.PSI TPHI.HLA ISHU,PSI SB~NiPSI ABFD,PS1 SigH,PS1 BACK,PSi TCND,.PSl INND,PS1 SATC'PS1 PAGE~ 2483.724 651,042 316,220 293,899 799.851 241.815 36,084 30,375 51,094 92,048 62 099 Ii1'i792 26785 766 2650 380 1 000 12762042 941,220 2912,946 i097 470 284~722 4o622so 34 424 29 078 54 438 91. 301 69 576 125 765 26787 20 2583 ~57 !39~ 000 1369 915 178 I138 3 298 611 281 250 954 61 510 ~1,7 36,719 :27,766 '53,14~ 88, 7. 66,740 135'397 2~354.~32 564,.55 1,000 Tape Verification l,,iStinq ;chlumberger AlasKa Cor0P,JtlDq Cepter RN!,P$1 878 472 RM2.P$1 RNS.P$i 1326:389 R~6,PS1 ~Ng,PS1 1677,083 RNIO,P$1 RN13,PS1 3173.611 ~N14.PS1 REI.PS1 23q.375 ~F2,P$1 ~FS,PS1 2q?,619 ~FG,PS1 RF~.PS1 465,030 ~FIO,PS1 ~F13,PS1 1090,030 ~F14.PSI G~.PSI 11,531 TE~S,P$1 DEPT, SIG~.PS1 SFFD PS1 AFNP PSi MMOF FBAC PS1 TCFD PS1 I~FD PS1 RN~ PS1 ~NS:P$! ~N9 PSi ~13~PS1 RRFI,PSI RE5 RFg' ,PSi RF13.P$! G~.PS! 11800, 9. {0, g, 401, 1. 24 ~896 334 9O4 1205 1577 2611 238 334' 520, 1205, 12, 000 SIG~.HLA 632 STDT.PS1 252 SFNO.PS1 755 NTDT.PS1 859 ABND.PS1 220 TRAT,PS1 100 ~CAN!PS1 186 SCN PSI 529 TTEC PSt 018 RN2'PS1 357 RN6 381 RNIO~P$i 607 RN14,PS1 095 RF2'P$1 821 ~F6,PS1 833 R~IO'PSi 357 RF~4,PS1 578 TENS.PS1 DEBT FFD FTDT AFND FBAC TCFD INFD RN5 RN9 RNI3 RF5 RFi3 G~ .PSI. PSI PSi P$1 PSI PS! PSi PS! PSI ,PSI 'P8! ,PS1 ~PSl .,PSi, ;PSi 11700 17,, 19, 7, 464. 1. 28, 5~49; 877, !316. 2287' 245' ~0~; 494; 792. 000 8IGM.HLA 591 STDT.PS! 200 SFND,PS1 402 NTDT,PSl 032 ABND.PSI 1.88 TRAT'P$! 537 TCAM'PS1 968 TSCN,PSI 812 TTEC'P$1 76 RN2~PS1 ~64 RN6,P$1 547 946 RNI. 4'PSi 36 RF~,PSi. 80 RFG,PS! 792 RFIO,PS! 411 RF14,PS1 953 TENS,PS! DEPT SFFD FTDT AFND ~OF FBAC PSl PSi PS1 ll600,000 9,882 10.342 1l'988 501,735 1,241 27,4!.0 SIGM.HLA STDT~PS! SFND~PS1 NTDT;PSi A~NO~DSt TRAT,PS1 TCAN,PS1 29-~AR-~990 07:43 127 710 RN3.PSI 14271083 RN7,P$! 1802 083 RN!i.DS! 3163 194 R~:15.PS1 23 220 RF3,PS1 424~107 ~F7,PS1 505,952 RFll.PS1 1104,911 RF15.PS! 185.000 CCL,PS1 9,578 66,000 11.799 22.204 400.116 1.978 46~02,523 8553,074 0.000 131 580 1.305i80] 1536 458 2689 732 30 ~60 401 ~6 502 232 1339 286 215 000 17,422 66'000 20.461 22'649 413.388 2.871 27220,129 5031.032 0 000 I31 580 1343 006 1674 07 1860 ~I9 30 960 342 26~ 487 351 639 ~0 1~5 0 9 695 66 000 11 709 27 613 424 810 2 049 58341.461 TRAT,HLA TPHI.DS1 SBHF,PS1 AFFD,PS1 SIGC.PS1 SDSI.DS1 TCAF.PS1 TSCF.PSi HV.P$1 RN3,DS1 RN7,D$1 RNll.PSI. RNlS'PS1 RF3,PS1 RF7,PS1 RFll',P$1 RF15,PSI CCL,PS1 TRAT .HLA TPHI,PSI $BHF,PSI AFFD PSI SIGC PS1 SDSI TCAF TSCF PS1 . Hv'PSI RN3,PSI RN7 PSi RNll PSi RU15 PSI RE3 RF7'PS! RFI1,PSi RFI5,PSI CCL,PSi TRAT,HbA TPHI,PS1 AFFD SIgC SDSI PSI TCAP PSl 986 1111 2572 2229 219 334 751 874 0 1 19 51 93 0 0 23664 4324 242. 1052 937 2124 2291 252 345 758 1194 0 2 44 50 87 0 0 9480 1752 243 1045 904 2317 1!64 223 249 669 427 0 2 20 42 !13 0 0 28470 111 111 917 167 494 821 488 256 000 989 413 102 981 652 251 453 636 875 827 5OO 256 667 976 982 928 196 000 822 763 060 O82 987 477 154 195 000 387 018 708 434 214 256 643 827 ,000 049 487 764 734 6O4 .195 ,566 RN4.PS1 RN8,PS! RN12.P$1 RN16,PSI RF4.PS1 RES.PS1 RF12 RF16~PS1 TPHI.HLA ISHU,P$1 SBHN.PS1 ABFD,PS1 SIBH,PS1 BACK.PS1 TCND.PSI INND,PS1 SATC PS1 RN4 PS1 RN8 PS1 RN!2 PS1 RN16 PS1 RF4*PS1 RFS.PS1 RF12,PS1 RF16,PSI TPH'!,HLA ISHU,PS1 8BHN,P$1 ABED,PS1 SIBHPS1 BACK· PS1 TCND INND P$1 SATC PS1 RN4 PS1 RN8 PSI RN12 PS1, RNI6 PS1 RF4,PS1 RF8,PSI RFI, 2,P$1 RFI6,PSI TPHI,HLA ISHU,PS! ssH 'psl ABFD.PS1 SIBH.PSl BACK'PSI TCND,PSi PAGE: 10 1322,917 885,417 2822,917 1104,t67 286,458 293,899 840.774 416.667 19,727 28,641 62,072 99,187 80,207 143,078 24177'535 2759'604 1 000 1331 845 944 940 2340 029 1261 161 345 982 275 298 952 ~81 658 82 43 164 3O 000 59 5O3 85 847 81 175 139~ 000 0 ~ 915 :! ~ 312 500 282 738 729,167 186,012 : 1: I 8 5 547 10~ 458 63 525 165 019 28675 621 .IS TaDe VerifJ. cation bt chlumberger AlasKa Comp TCFD,PSl 10512 891 INFD,PSl 353~503 Nl,PS1 875 000 NS,PS1 1444~444 RNg.PS1 1788,!94 RN13,P$! 3513,889 RF!,P$1 230,655 RFS,PS1 405 506 RFg,P$1 535:714 RF13,P$1 1424,851 GR.PS! 11,148 DFPT SFFD FTDT AFND MMOF TCFD INFD RN9 RN13 RF13 GR ,PSi ,PSi PSI PSi PSI PSI PSi ,PSI ,PSI ,['Si PSi PSl PS1 P$1 11500, 10, I0, 14, 455, I, 31 12249~ 394 869 1434 1850 3349 447 645 1649 9 000 167 619 289 043 219 707 834 003 391 295 961 359 667 917 833 305 227 DEPT $IgM SFFD FTDT AF~D FBAC TCFD INFD RN9 RNI3 RF~ RFg RFI3 G~ 11495, PS1 9' PS! 10, PSI 14, PS! 452, PSi PS1 28, PSi 12262, P$1 392, PSI 86~ PS! !~6 PS! 173]: PS1 317 P$1 264 PS1 472 P$1 658 PSI 1670 PS1 7 O0 94 27 O5 66 98 .5 09 05 36 47 48 ? 2 ** END OF DATA ** sttno uttnd Center TSCN PS1 TTEC:PSI RN2,PSI RN6.PSi R~IO.PS1 R~14.PS1 R~'2.PS1 RF6,PS1 RFI0.P$1 RF~4.P$1 TENS,PS1 SIGM,HLA STDT,PS1 SFND,PS1 NTDT,PS1 ABND'PS1 TRAT.PS1 TCA~.PS1 TSCN.PS1 TTEC.PS1 RN2.PS! RN6,PSI RNIO PS1 R~I14 PSl RF2 PS1 RF6 PS1 RFIO PS1 RF14.PSi TENS'PS1 SIGM.HbA STDT,PS1 SFND PS 1 D]., PS 1 ~N D * PS 1 TRAT ,PS 1 TCAN * PS I TSCN,PS1 TTEC,PS1 RN2.P$1 RN6,PS! RNIO.PS1 RN14,PSI ~F PS 1 tO,PSt RF14,PS1 TENS,PSI 29-MAR-1990 07:43 1.0796.500 TSCF,P$1 O.000 Hr,PS1 142.416 RN3,PS1 1548.611 RN7.PS! 1829.861 RNI!,PS1 3489.583 RN15,PS1 27.090 RF3,PSI 487 351 RF7.DS1 606i]99 RFll.PSI 1677 827 RF15,PS1 t85.000 CCL.DSl lO.lb4 66,000 25, 3 437.056 1 643 54487i391 ~0050'654 0 000 !62 540 15~6 506 1790 865 3473 558 30'960 565,972 663,{94 198b.111 1~5,000 9,992 66.000 11,248 25,265 447,353 =1.642 556u0'484 102.8 510 ' 0 000 185 760 1480 655 !763 393 3299 851 27 090 531 994 669 643 1994,047 215,000 TRAT.HLA TPHI,PS! SBHF,PS1 AFFD.PS1 $IGC,PSI SDSI,PS! TCAF.PS! TSCF,PSl HV.PS1 RN3,PS1 RN7.PS1 RM!I,D$1 RN15,PS1 RF3,PSI RF7,P$1 RFII,PS! RFI5,PS1 CCh,PS1 TRAT,HLA TPHI,P$1 SBHF',PSi AFFD,PS1 SIGC,PS1 :8DSI.PSl TCAF.PSI TS ~ , PS 1 HV,PS1 RN3,PS1 RN7 ,PS1 R N 11, P $1 R~IS,PSI RF3,PSi R F 7 .. P S 1 RF1 ]. ,PS1 RFI5,PS1 CCL,PS1 5268 680 243~125 1055.555 1256.944 2680 555 2913~194 275.298 438.988 911.458 1499,256 0.000 1 674 12 648 42 471 125 221 0 391 0 195 33156 078 6115 916 242 625 1141 827 1157 853 2608'173 3020 833 302 083 524 306 1038 194 !815 972 0 o00 ! 643 !~ 676 4 082 124 395 0 405 0 184 33882 938 62!5 478 243 000 1119 792 1194 196 25O3 720 2805059 342 262 513 393 1023 065 181! 756 0.000 INND,PS1 SATC.P$1 RN4.PS1 RNS,PS1 RN12.PS1 RN16.PS1 RF4 PS1 RFSiPS1 RFi~.PS1 RF16.PS1 TPHI.HLA ISHU.PS! SBHN.PS1 ABFD.PS1 SIBH.PS1 BACK.PS1 TC~D,PS1 I~ND.PS1 SATC PS1 RN4~PSI. RNS.PS1 RN12.PS1 RN16 PS1 RF4 PSi RF8 PSl RF12 PSI RF16 PS1 TPHI,H. bA ISHU PS1 8BHN'PSI ABFD,PS1 SIBH,PS1 BACK,PSi TCND,P$1 IN'ND,PSI SATC,PS1 RN4,PSI RNS,PS1 RNi2,PS! RN16,P$1 RF4'pS1 RF81PS1 RF!2,PS1 RF!6,PS1 PAGEI 11 2614,833 1,000 1368,055 916,667 2989 583 1635 417 364 583 308 780 1123 512 799 851 13.184 29,078 60,628 129,898 73,285 183.330 27860 535 2707 126 1 000 1458 333 957 532 3012 820 1690 705 413 194 309 028 1298 611 979 167 12 646 29 938 57 841 129 414 68854 17~ 226 2787 926 2830 149 1. 000 1495 ~36 926 39 2849 702 1584 82:1 453 '869 319940 1220 238 989 583 IS TaPe verification Listing chlumberqer !laska Computing Center **** FILM TRAILER FILE N~ME : EDIT .001 SERVICE : FLIC VERSION : O01A04 DATF ~ 90/03/27 ~AX RFC SIZE : ~02~ FILE TYPE : LO L~ST FILE 29-MAR-1990 07:43 PAGE: 12 **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01A04 DATE : 90/0]/27 ~AX RFC SIZE : 1024 FILE TYPE : LO LAST FILE ****************************************************************************** , * FILE ' EDIT,002 * ARCO ALASKA, INC, * PRUDHOE BAY O !8-S , * , * * * * , * * ~2500' TO !1499' , ****************************************************************************** PASS #2 bOG DATA DATA SAMPLED EVERY DATA INCLUDED - TOOL EXTENSION TOOL TYPE USEO NA~E TDT-P ,PS2 THERMAL DECAY TOOL TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, IiNC, Compamv Name FN PRUDHo~ BAY Field ~ame IS Tape Verification Llsting chlumber~er Alaska Computin~ Center 29-~AR-1990 07:45 PAGE: TUNI VALU DEFI '''W~' ....................................... DO"$ i~i~.i5 We 11 ,.~ame ' ..... ''''''''''''''' APIN 5 !583 AP! Serial Number FL 752' F!~L & 221' FEL Fleld 5ocation SECT 24 Section TOWN 11N Township RA'N~ 14E Ranqe COUN NO~TH SLOPE Cou6ty STAT ALASKA State or Province N~T~ USA Nation WITN RICH/HURST/BRA~)LEY Witness' Name SON 379258 Service Order Number PDAT MSL Permanent datum ~PD FT O, L~F RKB Log Measured From APD FT 49. EKB FT 49. EDF VT 48, E~b FT 16 T~D FT 13~45, TYPE DEPT STDT TPH! ISHU SFFD FTDT NTDT AFFD ABFD AFND ABND SIGC SIB~ ~OF T~AT SDS! BACK FBAC TCA~ TCAF TCND TCFD TSC~~ Depth Channel Name sigma (Neutron Capture Cross section) status of TnT TnT Porosity TnT Shunt Current Sigma far,etlon far detector (TDTP) Sigma formation '- near detector~ (TnT'P) Sl.~ma borehole - far ~etector (IDTP) Sigma bare,ale - near detector (TDTP) Far TDT~ Count Rate Near TDT~ Count Rate Amplitude formation -- far detector (TDTP) Amplitude bare,ale-- Far detector (T~TP) Amplitude for~,atlon - near detector (TDTP) Amplitude Borehole -- near detector (TDTP) SIGM Correction Borehole sigma (corrected) -- TDTP ~.lnitron mode monitor ratio (TDTP) TnT Ratio Standard deviation of Sic~ma-for~,at~on (TDTP) Back,rOUnd Near (;ares Far ' acKqr~und Total COUntS na yzed near detector Total counts n..a .VZed ~ far detector (f...TP)' D Total counts - near detector Total counts - far detect, or (TDTP) Selected gates count rate - near detector (TDTP) IS Tape verification hist{hq chlu~berqer AlasKa Computing Center 29-~AR-1990 07:43 PAGE: 14 TSCF Selected gates count rate - far detector (TDTP) INNI> Inelastic~counting rate - near detector (TDTP) INFD Inelastic counting rate - far detector (TDTP) TTEC TDT-P Telemetry Error Count HV Head Voltaae SATC Status of RN! Raw Near ~st Gate RN2 Raw ~ear 2nd Gate RN3 Raw Near 3rd Gate RN4 Raw Near 4t~ Gate RN5 Raw Near 5tn Gate RN6 Raw Near 6th Gate RN7 Raw Near 7th Gate RN~ Raw Near 8th Gate RN9 Raw Near 9th Gate RN~O Raw Near lOth Gate R~)ll Raw Near l~th Gate RNI~ Raw Near 12th Gate RN13 Raw Near 13th Gate RMV4 Raw Near 14th Gate RN15 Raw wear 15t~ Gate RN16 Raw Near 16th Gat~ RF1 Raw Far Ist Gate RF2 Raw Far 2nd Gate RF3 Raw Far 3rd Gate RF4 Raw Far 4th Gate RF5 Raw Far 5th Gate RF6 Raw Far 6t~ Gate RF7 Raw Far 7t~ Gate RF8 Raw Far 8th Gate RF9 Raw Far 9th Gate RF~O Raw Far ~Oth Gate RFI~, Raw Far l~tn Gate RFi~ Raw Far 12th Gate RF~3 Raw Far ]3th Gate RF~4 Raw Far 1,4th Gate RFI5 Raw Far 15th Gate RF16 Raw Far ~,6tD Gate GR Gamma Ray T~NS Tensio~ CCL CCL AmPl.~tude IS ~a~e Verification Listlnq cblumheraer AlasKa Computing (]enter '29-MAR-1990 ** DATA FORMAT SPECIFICATIUN RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE 66 2 66 0 3 73 272 4 66 5 66 6 73 7 65 ~ 68 0 5 9 65 ~ 66 3 12 68 1~ 66 0 14 65 15 66 6~ 16 66 0 66 1 m~#mmmm#mmmmmmm~mm~mmmmmmm~mm ** SET TYPE - CHAN ** ~m m~mM~mmmmm~mmmmmmm m ' ~ m m mmmmmmm '""'"'"'... ...,,-.---.-,.--,.---.--..--..-.---........-.-.............,.........,,,,,,.,,,.. s, o, o , oooooooooo $?DT P$2 379258 51 ?PHI P$2 PU 379258 51 ISHU PS2 V 379258 51 SFFD PS2 CU 379258 51 f ~ $..ND P$2 CU 379258 51 SBHF PS2 CU 379258 8BHN 'PS2 CU 379258 FTDT PS2 CPS 379258 5! NTDT PS2 CPS 379258 AFFD PS~ CPS 379258 51 ABFD PS~ CPS 379258 5 AFND PS2 CPS 379258 MIGC PS2 CU 379258 51 SIBH PS2 CU 379258 51 MM'OF PS2 379258 51 TRAT P82 , 379258 SDSI PS2 CU 379258 51 BACK PS2 CPS 379258 51 FBAC PS2 CPS 379258 51 TCAN PS2 37925S TCAF PS2 37925~ TCND PS2 CPS 379258 51 TCFD PS2 CPS 37925~ 390 O0 0 2 1 I 4 890 Ol 0 2 1 ! 4 000 O0 0 2 ! ! 4 400 02 0 2 1 1 4 4OO O2 0 2 1 1 4 400 OI 0 2 1 1 4 400 O1 0 2 ! I 4 000 O0 0 ~ I I 4 000 O0 O' 2 t 1 4 39i O0 0 2 I I 4 391 O0 0 2 1 1 4 390 O0 0 2 I ! 4 390 O0 0 2 1 1 4 400 O1 0 2 ! 1 4 400 O1 0 2 ! 1 4 000 O0 0 2 1, I 4 000 00 0 2 ! 1 4 000 O0 0 2 t 1 4 390 17 0 2 1 1 4 391 17 0 2 ! 1 4 000 O0 0 2 I 1 4 000 O0 0 2 I 1 4 000 O0 0 2 1 ! 4 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 6B 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 :0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 PAGE: 15 IS Tape Peri!!cation Listing chlumberqer AlasKa Computl~o Center 29-~AR-!990 07:43 PAGE: 16 TSC~t P$2 TSCF PS2 CPS 379258 51 000 00 INND PS2 CPS 37925~ 51 000 00 INFD P$~ CPS 379258 51 000 O0 TTEC PS2 379258 51 390 00 HV PS2 V 379258 51 000 00 SATC PS2 379258 5i 000 00 RNI PS2 CPS 379258 51 390 RH2 P$2 CPS 379258 51 390 02 RN3 PS2 CPS 379258 51 390 03 RN4 P$2 CPS 379258 51 390 04 RN5 PS2 CPS 379258 51 390 05 RN6 P$2 CPS 37'9258 5! 390 06 RN7 PS2 CPS 379258 51 390 07 PN8 PS2 CPS 379258 51 390 08 RN9 PS2 CPS 379258 51 390 09 RN10 PS2 CPS 379258 51 390 RNll P82 CPS 379258 51 390 1,1 RN12 P$2 CPS 379258 51 390 12 RN13 PS2 CPS 379258 51 390 13 RNI4 PS2 CPS 379258 51 390 14 RN15 PS2 CPS 379258 51 390 15 RN16 P$2 CPS 379258 51 390 16 RFI P82 CPS 379258 51 391 01 RF2 P$2 CPS 379258 5I 391 02 RF3 P$2 CPS 379258 51, 391 03 RF4 P82 CPS 379258 51 391 04 RF5 PS2 CPS 379258 5! 39! 05 RF6 P$2 CPS 379258 51 39~ 06 RF7 P$2 CPS 379258 51 39! 07 RF8 PS2 CPS 379258 51 39t 08 RF9 PS2 CPS ~379258 51 391 09 RF!O P$2 CPS 379258 51 391, 10 RFI! P82 CPS 379258 51 39! RF12 P$2 CPS 379258 51 391 12 RF!3 PS~ CPS 379258 51 39! 13 RFI4 P$2 CPS 379258 51 391 14 RF15 P$2' CPS 379258 51 391 !5 RF16 P$2 CPS 379258 5! 391, 1.6 GR P$2 GAP! 379258 51 3!0 01 TENS PS2 LB 379258 51 635 21 CCL PS2 Y 379258 5! 150 01 NIT SERVICE AP1 APl a. PI AFI FILE ORDER ~ LOG TYPE CLASS ~O[: NUMB SAN:P EL~ CODE (HEX) CPS 37 9258 51 000 O0 0 2 1 1 4 68 000 0000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 i 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 i 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 i ! 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 1 ! 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 ! I ,4 68 0000000000 0 2 I I 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 I I 4 68 0000000000 0 2 ! 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 I 1 4 68 0000000000 ** DATA ** DEPT 12507 000 $!GM,PS2 iSH{.I ' * ,PS2 37' 313 SFFD,PS2 F..H~I:, PS 2 57 84i FTDT, P$2 $ ABFD,p$2 129 414 AFND,PS2 9,94.2 ST[i, .... )~ PS2 66,000 'TPHI,P$2 12,6'76 10,279 SFN[),PS2 !1,248 SBHF,PS2 46,082 14'056 t~TDT,FS2 25,265 AFFD,P$2 124,395 452,663 A~ND'P$~ 447,353 SIGC,P$2 0,405 Tape verification Listinq chlumberger AlasKa Computing CeDter SIFH,PS2 BAC~.PS2 TCND,PS2 INND,PS2 $~TC.PS2 RN4 PS2 ~N~ PS2 RN12 PS2 RF4 PS2 RF8 P$2 ~F19 P$2 RF16 PS2 DFPT ISHU~PS2 SBH~ PS2 ABFD PS2 $IBH P$2 BACK PS2 TCND PS2 /NND SATC PS2 RN4 RNI~,P$2 RNI6 P$2 RF4 RF8 P$2 RF12 P$2 '~16 PS2 DEPT ABFD BA S~TC N4 R~12 ~P16 PS2 PS2 PS2 PS2 PS2 PS2 P$~ PS2 PS2 PS2 PS2 PS2 PS2 PS2 DEPT ISHU:PS2 ABFD,P~2 $~BN,P$2 68 854 175i226 27873 926 2830,149 1,000 1505.682 937.500 3181.818 823 864, 392:992 345 644 1126:894 355,114 12500,000 37,125 46,791 125,496 50 846 152:430 27474,]98 2604,670 I 000 1490 885 914 714 3164 062 872 396 405045 347 366 11!7 568 330 865 12400,000 34,719 197 ll 884 18577 254 3154324 1000 1547619 970 982 !789434 703 319 840 ~gO !79 602 678 238,095 12300,000 35,563 54,284 99,385 68 ' 277 MMOF,PS2 FBAC,PS2 TCFD,PS2 INFD,PS2 RNI,PS2 RNS,P$2 ~N9,PS2 RNIS,PS2 RFI.PS2 RFS,P$2 RFg,PS2 RF13,PS2 GR,PS2 SIGN,PS2 SFFD,P$2 FTDT.PS2 AFND.PS2 ~OF,PS2 FBAC,PS2 TCFD,PS2 INFD,PS2 RN1.PS~ RN5 PS2 RN9 PS2 R~13 PS2 RFI P$2 RF5 PS2 RF9'PS2 RF13.P$2 GR,PS2 S!G~ PS2 S.BD,PS2 FTDT,PS2 AFND,P$2 ~iMOP.P$2 FBAC PS2 TCFO PS2 INFD PS2 RN1 P$2 RN5 PS2 RN9 P$2 RN13 PS2 RF1 PS2 RF5 PS2 RF9 P$2 RFI3,P$2 GR,P$2 SIG~ P$2 SFFD,PS2 FTDT,PS2 A. FND,PS2 ~OF,PS2 29'~AR-1990 07:43 1282 TRA'r,PS2 28i983 TCA~',~, P$2 12262 156 TSCN.PS2 392 952 TTEC.PS2 fig0 151 RN2,PS2 1628:788 RN6,P$2 2012,3!0 RNIO,PS2 3143.939 RNX4.PS2 331.439 ~F2,PS2 478,220 RF6,PS2 729.167 RF10,PS2 1145.833 RF14,PS2 25,250 TENS,PS2 16 768 1716931 ~ 3 871 7 43~ 7 3 458 914 71~ 1608 O73 2008 463 3043,620 300,591 453,1il 684'975 1199,638 25'250 14 800 1,5 637 32~ 067 oll ! 253 24 687 4993 091 338 647 907 738 1335 565 1670 387 1830 357 215 774 290 179 386 905 613 839 26'047 1:2,459 i3,596 9'936 489,584 1,199 STDT.PS2 SFND.PS2 NTDT.PS2 ARNO,PS2 TRAT,PS2 TCAN'PS2 TMCN,PS2 TTEC,PS2 RN2,PS2 RN6,P$2 RN10,PS2 RN14,PS2 RF2,PS2 RF6,PS2 RFI0,PS2 RFX4,P$2 TENS,PS2 STDT,PS~ SFND,P$2 NTDT,PS2 ABND TCAN,P$2 T$CN'PS2 TTEC~PS2 RN2.PS~ RN6,PS2 RN10,PS2 R~14,PS2 RF2,PS2 RF6'P$2 R~10':PS2 RF!4'PS2 TENS,PS2 STDT,P$2 SFND,~S2 NTDT, S2 ABND,PS2 TRAT,PS2 1 642 5565O 484 10208 510 0 000 139 320 1856 060 2012 310 25O9 469 25 800 553 977 677 08] 1017 992 200.000 SOSI,PS2 TCAF,P$2 TSCF.P$2 HV.~$2 RN3 PS2 RN7:PS2 RNII.P$2 ~N15.PS2 RF3,P$2 RF7,P$2 RFI~,PS2 RF15,P$2 CCb. PS2 66,000 TPHI.PS2 19,863 SBHF P$2 30 922 AFFD!PS2 479 534 SIGC PS2 2 343 SDSI.PS2 41977 7075 0 1,57 1718 200B 2460 34 523 685 1058 210 727 TCAF.PS2 524 TSCF,PS2 000 HV,PS2 896 RN3.PS2 750 RN7.PS2 463 RNI1.PS2 938 RNI5 P$2 543 RF3 272 RF7 PS2 979 RFll 741 RF15 PS2 000 CCL PS2 66,000 16 79 446 ~10 2~ 18 23792!64 4088ii0 0056 TPHI PS2 SBHF AFFD PS2 $IGC PS2 SDSIPS2 TCAF TSCF ~VPS2 147,~60 RN3 P$2 !186, 56 RN7 PS2 151~,137 RNll PS2 15 .'137 RN15 P$2 30.960 RF3 PS2 293'899 RF7 P$2 383.i85 RFI. I'P$2 617,559 RF15;P$2 ~85.000 CCh,PS2 66,000 TPHi,PS2 14,977 SBHF,PS2 27'348 APFD*PS2 432,375 SIGC,PS2 2.499 SDSI~PS2 PAGE: 17 0 184 33882 938 15 478 6271 938 1079 545 1240 530 3001 894 1624 053 241477 407 197 1084 280 686 553 0,000 3 088 162 12i,123 0447 17918 984 3020 32! 241 875 11035!6 1227 213 3001. ]02 1601. 562 283 7 1026 027 709 797 o 0o0 29,439 57;530 61'472 0,930 0;402 10261'986 176];510 242,250 1194196 729 t67 1990 327 1216518 223 214 204 554 315 435 268 0000 31 663 43 579 99 43 ! 0 888 0 247 Tame Verification bistlno .chlumberqer AlasKa Computin~ Center B~CK INND, SATC. R~12 RF~ RF17i RF16 PS2 151.482 FgAC P$2 PS2 26228.922 TCFD:PS2 PS2 2661.922 !~FD PS2 P$2 1.000 RN~:PS2 PS2 1415.441 R~,!5.PS2 PS2 909,926 9N9.~S2 PS2 2861,520 ~N1],PS2 PS2 I081,495 RFI.~S2 PS2 ]]8.542 RF5 PS9 257.161 RFg:PS2 PS2 957,0]{ ~F13.PS2 PS2 449,219 GR,PS2 DEPT ISHU PS2 A~FD SIBH PS2 BACK,PS2 TCND,PS2 S~T PS2 "~4.~82 ~8,P82 ~1 PS2 RF4.PS2 RFS,Pf2 ~F ,PS2 12200 54 96 7O 159, 23725. 257], 1, 1430, 949. 2504, 809' 2 000 672 902 421 538 O45 605 502 000 288 519 006 295 627 67~ 142 50O SIGN PS2 SFFD!P$2 FTDT PS2 AFND PS2 ~OF~PS2 FBAC'PS2 TCFD,FS2 IiqFD,PS2 RNI,P$2 RNS,P$2 RN9,PS2 RN13 PS2 RF1 P$2 RF5 PS2 RF9 PS2 RFI3 PS2 GR,PS2 DEPT ISHU SBHN ABFD IBH AC~ TCND INND S~TC RN4 R~16 RFI~ RFI6 P$2 PS2 PS2 PS2 P$2 P$2 PS2 PS2 P$2 PS2 PS2 P$2 12100 51 '62 26925 2470 1 1313, 892, 3054, 1257, 276. 299, 914, 468, ooo 25o 364 059 710 ]79 477 679 000 244 857 315 440 693 ~79 714 750 $IG~.PS2 SFFD,PS2 FTDT,P$2 AFND.P$2 MMOF'P82 FBAC,P$2 TCFD,PS2 INFD,PS2 RN1,P$2 RNS'PS2 RN9~PS2 RNi~3;PS2 R~I;PS2 RF5'PS2 RFg,PS2 RF13,PS2 GR,PS2 DEPT ISHU SBH~ ABFD BACK PS2 PS2 PS2 PS2 PS2 12000. 32 52 91 65 174 o00 594 904 254 492 108 SIGM.PS2 ~FFD' PS 2 FTDT~PS2 AF~D,PS2 ~OF,PS2 FBAC,P$2 29-MAR-1990 07:43 28 255 ~944!722 332 353 888 480 !,495:098 1862 745 3174 020 227 865 358 O73 524 089 1113,2~1 22,~13 14 808 15,869 8.663 471,!95 I 1~5 29 007 6714 309 335 049 865 385 1498 397 1746 795 2676 263 480 367 647 517 770 955 882 31. 109 1! 949 12 763 49~ 62! !08. 1 248 28.607 338'58o 874,25~ 380'208 ~741,071 3206.845 21s,o 2 5 ,5 8 ,328 11.052 !l,SeO 9.439 500,5~5 1,~50 29,..~71 TCAN.PS2 TSCN.PS2 TTEC.P$2 RN2,PS2 RN6.PS2 RM!O.PS2 RNI4,P$2 RF2,PS2 RF6,PS2 RFIO.P$2 R~14,PS2 TENS.PS2 STDT,PS2 SFND.PS2 NTDT,PS2 ABND,PS2 TRAT'PS2 TCAN,PS2 TSCN.PS2 TTEC,PS2 RN2.PS2 RN6,PS2 R~IO.P$2 RN14,PS2 RF2,PS2 RF6,PS2 RFIO,PS2 RF14,PS2 TENS,PS2 ~STDT,PS2 SFND PS2 NTDT PS2 ABND PS2 TRAT PS2 TCAN PS2 TSCM PS2 TTEC PS2 R~2,PS2 RM6,PS2 RNIO.PS2 RNI4'P$2 RF2'PS2 RF6,PS2 RFIO'PS2 RF14,PS2 TE~S,PS2 STDT .PS2 SFND'PS2 NTDT.PS2 ABND,P$2 TRAT,PS2 TCAN,PS2 46124 o 152: 1531 !9111 2873 23 458. 498. 1142. 185. 66. 17, 24, 443, 2, 33717. 6303, 0 . 165, 1534, 1806. 2319 009 210 66 t3 2~ 407 2 52408 9177 0 142 1536 1778 3210 19 393 478 66, 13. 28, 415, 50701. 320 139 0 O0 220 863 765 774 220 984 047 578 0o0 000 828 724 523 540 297 038 000 120 455 891 711 768 000 000 g20 109 679 422 762 000 416 458 274 565 35O 5!6 813 000 000 657 08~ 548 584 547 TCAF.PS2 T$CF.PS2 HV.PS2 RN3.PS2 RNT.PS2 RNII.PS2 RN15 PS2 RFS~PS2 RF7,PS2 RFII,PS~ RF15.P$2 CCL.PS2 TPHI.PS2 SBHF,PS2 AFFD.P$2 $ICC,PS2 SDSI.PS2 TCAF.PS2 TSCF.PS2 HV,PS2 RN3 PS2 R~7 PS2 RNll PS2 R~15 PS2 RF3 PS2 RF7 PS2 RFI.~ PS2 RF! PS2 CCb P$2 TPHI PS2 SBHF P$2 AFFD PS2 SIGC PS2 ?c~ TSCF P$2 HV P$2 RN3 P$2 RN7.PS2 RNIi,P$2 RN15.P$2 RFS,PS2 RF7,PS2 RFI!;P$2 RF15,PS2 CCL,PS2 T'PHI,PS2 SBHF,PS2 AFPD,PS2 SIGC;,P$2 ,SDSI'PS2 PAGE: 18 18459 367 3321 390 242 500 1026 348 1124 387 2610 294 2212 010 244 332 031 826 823 875 651 0 000 34 028 471 ~ o67 0 399 13272,783 248i,186 242 625 1097 756 1033 654 2500 000 1518429 251 225 303 309 793 505 643 382 36,361 35 646 98 ~!0 0 94 0 248 19565 695 3426 345 24i 375 1000 744 1179 315 2752 976 2440 476 2~8099 315,755 758"464 947;266 0,000 33,816 41.'375 95;38~ 0'910 0'228 !9623,715 Tape Verification Listlnq chlumberger AlasKa Computing Center TCND INND SATC RN4 RNI~ RN16 RF4 RF12 RF16, PS2 26889,004 TCFD PS2 PS2 2541.986 INFD:PS2 PS2 1 000 ~N1.PS2 P$2 1354:167 RN5.Ps2 PS2 937,500 RN9,P$2 PS2 2965.029 RN1],P$2 PS2 1387,649 RFI.PS2 P$2 300,481 RFS.PS2 PS2 276.442 RFg,PS2 PS2 913.461 RF13,PS2 PS2 524.840 GP.P$2 DEPT SBHN ABFD S~BH TCND S~TC RN16 RF4 RF12 ~16 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 P$2 PS2 PS2 11900,000 30,859 53.~45 90.051 67 204 186 229 26040 691 2578 360 1 000 1340 278 881 944 2770 833 1243 055 264 137 275 298 877 976 420 387 SIG~, SFFO. FTDT, AFND. ~OF FBAC TCFO INFD RN5 R~i9 RN1] RF5 RF9 RF13 GR PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 PS2 DEPT ABFD BAC~ TCND INND SATC RN4 R~12 RN16 RF4 RFI~ RF16 PS2 PS2 PS2 P$2 PS2 P$2 PS2 PS2 P$2 PS2 PS2 PS2 PS2 PS2 11800,000 33'844 61,661 91,~18 79'921 185,506 25108'789 ~642'080 1,000 1430,555 899,305 2579'861 1468'750 297'619 279,018 840,774 617,559 SFFD FTDT AFND MMOF TCFD INFO RN! RN5 RN9 RN13 RF1 RF5 RF9 RF13 PS2 PS2 PS2 PS2 PS2 P$2 PS2 PS2 P$2 P$2 PS2 PS2 PS2 PS2 , P$2 , PS2 ,PS2 DEPT, ISHU,P$2 SBHN,PS2 ABFD,PS2 SIBH,PS2 T D,PS2 11700 30 60 89 193 20428 000 813 947 049 451 929 973 SIG~ SFFD FTOT AFND gMOF TCFD P$2 PS2 PS2 PS2 PS2 P$2 ,P$2 2g-MAR-1990 07:413 7921 30! 332 572 855 655 ~4~7 411 1770 833 3363,095 228 365 332 532 452 724 114~ 827 2 o31 I1 917 12~857 9,245 500,903 1,251 32,763 7481,961 305,~9 833.333 1354,tb7 1750,000 3229,167 197,173 342,2~2 498.5~2 1049,1 7 27,625 8 958 414 860 i93 8226 335 882 3 1697 9!7 2934 027 45 536 33! I01 468 750 1086 309 21 750 }7,6i3 9,136 7'075 470,268 1,234 53~5'370 5,004 TSCN.PS2 T~EC,PS2 RN2,PS2 RN6,PS2 RNIO,PS2 RN14,PS2 RF2,PS2 RF6,P$2 RFI0,PS2 RF14.PS2 TENS,PS2 STDT,PS2 SFND,PS2 NTDT,PS2 ABND,P$2 TRAT*PS2 TCA~,PS2 TSCN,PS2 TTEC'PS2 RN2,PS2 RN6,PS2 RN10,P$2 RNI4,PS2 RF2,PS2 RF6,P$2 RFI0,PS2 RF14,PS2 TENS'PS2 STDT,PS2 8FND,PS2 NTDT,PS2 ABND,PS2 TRAT,PS2 TCAN,PS2 TSCN,PS2 TTEC,PS2 RN2,PS2 RN6,P82 RN10,PS2 RNI4,P$2 RF2,PM2 RF6'P$2 RFiO'P$2 RF14,PS2 T~NS,PS2 STDT,P$2 SFNO,PS2 NTDT,PS2 ABN!),PS2 TRAT,PS2 TCAN,PS2 T$CS,PS2 9346 0 170 1569 1789 3195. 27 · 424, 512, 1237, 215, 66 14. 27. 402. 2, 47440, 8731, O. 178 1572 1746 3038 34 412 494 1156 215 66 12 22 427 2 45899 8624 143 1500 1621 3013 34 386 1186 66, 2~, 22, 406, 2, 26896, 4785, 236 000 280 940 434 684 O9O 679 82O 981 000 000 565 979 715 672 555 141 000 020 917 528 194 8 ~0 946 792 994 000 000 086 933 942 81 0 O0 190 000 528 889 830 905 , 56 000 00 124 242 223 848 777 563 TSCF HV RN3 RN7 RNll RN15 RF3 RF7 RFll RF15 CCL TPHI SBHF AFFD SIGC SDS! TCAF T$CF 8V RN3 RN7 RNll RN15 RF3 RF7 RF11 RF15 CCI,, TPHI SBHF AFFD $IGC SDSI TCAF T$CF HV RN3 RN7 RNI! RN15 RF,3 RF7 RFll RF15 cc~ TPHI $BHF AFFD $IGC SDSI TCAF TSCF .PS2 .PS2 ,PS2 ,PS2 ,PS2 ,PS2 PS2 ·' .PS2 .PS2 ,PS2 ,PS2 ,PS2 ,PS2 ,PS2 .PS2 .PS2 .PS2 ,PS2 PS2 PS2 PS2 PS2 PS2 P$2 PS2 PS2 PS2 PS2 ,PS2 ,PS2 'PS2 ,PS2 ,P$2 'PS2 PS2 P$2 PS2 PS2 P82 PS2 ,PS2 ,PS2 .PS2 ,PS2 ePS2 PAGE: 3617 243 1004 1171 2574 2481 216 376 733 1053 0 36 17756i 3268 243 '982, 1159· 2642 2284 219 38 922 0 23 54 87 0 0 21397 402O 242 1069 1059 2434 2444 249 327 7~4 1164 44¸, 45, 83, 1, O, 9443, 1680, 19 402 125 464 875 404 398 346 603 173 686 000 359 562 867 931 253 992 065 125 639 722 494 542 488 619 000 069 640 146 815 2 8 441 !25 4.44 02~ O2? 4.44 38! 34 000 060 200 ~80 6~ 230 IS Tape Verification Listing chlumberoer Alaska Compt~tinq Center 29-~AR-J. 990 07:43 INND.PS2 2570,761 !NFD,PS2 3o4 SATC,PS~ 1.000 RNI,PS2 864 RN4.PS2 1357,639 RN5.PS2 1322 ~NS.PS2 892,361 RNg,Ps2 16~0 RN12.P$2 2274.305 RN]3.PS2 2229 RNlf.PS2 920.139 RFI,P$2 220 RF4 PS2 ]28 526 RFS.PS2 312 ~FS:PS2 268:429 RFg,Ps2 440 RFI2,PS2 677.083 RP13,PS2 729 ~F16.PS2 216,346 GP'PS2 36: 116OO 'PS2 55 ,PS~ 10~ .PS2 66 .PS2 190, ,P$2 28887. ,PS2 2573 .P$2 PS2 1400, PS2 922. PS2 2974 PS2 1706 P$2 336 PS2 284 P$2 114 000 SIGM,PS2 672 SFFO,PS2 035 FTDT PS2 ~ 8 AFND.iP$2 ~6 ~mOF PS2 876 FBAC,PS2 258 TCFD,PS2 953 INFO,PS2 000 RN1.PS2 ~23 RN5,PS2 181 RN9.PS2 877 ~N13 PS2 495 RFI:'P$2 538 RF5,PS2 455 {~Fg,PS2 827 RFi3.PS2 365 GR,PS2 DEPT ISHU SBHN ABFD SIB. BACF TCN~ INND SATC ~N4 RF4 RF~6 DEPT, ii500,000 $IGM,P$2 ISHU'PS2 34,094 SFFD'PS2 $BHN,P$2 57.994 FTDT,PS2 ABFD'PS2 124,217 AFND,PS2 SIBH.PS2 69 286 ~OF.PS2 .... ' FBAC"P$2 BACK,PS2 204,821 TCND,PS~ 27876,348 TCFD'PS2 INND~P$2 ~665,973 TNFD,P8~ S~TC,PS2 1.000 R~I'P$2 RN4~PS2 1430'555 RN§,PS2 RNS~PS2 892,361 RN9'P$2 RN!~PS2 2930.555 RN13"PS2 RN1 .PS2 1729 I67 RFI,PS2 RF4,PS2 420~387 RF5,PS2 RFB.PS2 3!9,940 RFg,PS2 2,P$2 1324,405 RF!3,PS2 ~16,PS2. 963,542. GR,P$2 11498,500 P$2 33,406 P$2 57,I72 PS2 127,201 PS2 67,592 PS2 202,496 PS2 27657,898 PS2 2676,t]3 SIG~ .Ps2 SFFD' ~rEf,P$2 AFND,PS2 ~MOF.PS2 FBAC PS2 TCFD PS2 INFD PS2 DEPT ISHU ABFD B~.¢~ TCND I~ND 505, 1, 10471, 346. 888. 1443, 1783. 3563, 240 400 14 21 10 10 13 455 11920 3'73 850 1447 1795 3440 273 479 703 9 10 13 449 1 '35 12035 376 902 TTEC.PS2 58] CN2.PS2 9i7 RN6.PS2 555 R~IO,PS2 167 RN14,PS2 353 ~F2,PS2 500 RF6,PS2 705 RFIO PS2 167 RF14 PS2 375 T~NS PS2 666 STDT,PS2 315 SFND,PS2 923 MTDT.PS2 400 ABND,PS2 218 TRAT,PS2 609 TCAN,PS2 766 TSCN,PS2 954 TTEC,PS2 480 R~2,PS2 015 RN6,PS~ 088 r~lo;Ps 112 RN14'PS2 385 RF2,PS2 641 ~F6,P$2 923 RFI0,PS2 219 TES,PS2 727 468 138 250 346 4 917 2 577 9il 125 946 998 81,7 224 629 113 STDT,P$2 SFND,PS2 NTDT,PS2 ABND,P$2 TRAT'P$2 TCAN,P$~ TSCN'.PS2 TTEC,P$2 RN2,PS2 RN6,P$2 RNIO,PS2 RN14.P$2 RF2 PS2 RF6 P$~ RF~O PS2 RF14 PS2 TENS,PS2 STDT,PS2 SFn )'PS NTD~,PS2 B D, PS2 TRAT,P$2 CA~:i ~82 TTEC, P:$2 0,000 212 850 1420 139 1618 055 1767 361 38 7O0 348 558 440 7O5 633 013 185 000 66.000 11 771 27 993 422 006 2 058 60096 195 10809 061 472 1562 500 1783 088 3694 853 27 090 456 731 629 006 1626 603 190 000 66 000 11 455 25 371 44028'5 1 684 54100 695 10066 365 0 000 185 760 153 194 174~055 3350694 46 440 587 797 673363 1848 958 205 000 66.000 11.504 435 48 i,655 54078~031 9980:~340 O0 HV PS2 R~3:PS2 RNT.P$2 RNII.PS2 RN15.PS2 RF3,PS2 RF7,PS2 RFll,PS2 ~F15.PS2 CCL,P$2 TPHI,PS2 SBHF,PS2 AFFD,P$2 SIGC PS2 s s :Ps2 TCAF PS2 TSCF!PS2 HV PS2 RN3,PS2 RN7.PS2 RNll.PS2 RNIS,PS2 RF3.PS2 RF7,PS2 RFI!,PS2 RF15,PS2 CCL,PS2 TPHI,PS2 SBHF,PS2 Af'FD.PS2 SIGC,PS2 SDSI,PS2 TCAF,P$2 TSCF,P$2 HV'PS2 R~3,P$2 RN7,PS2 RNII,PS2 RNIS,P$2 RF3,PS2 RFT,PS2 RFIl,PS2 ~FIS,PS2 CCL,P$2 TPHI.PS2 SBHF'PS2 AFFD,PS2 SIGC'PS2 SD$I*PS2 TCAF PS~ TSCF PS2 HV P$2 PAGE: 2o 242 000 1059i028 982 639 2277 777 1361,111 256,410 248.397 637.019 420.67] 0.000 20 704 44~1~ 113,026 0,684 O.191 29207.914 5253 412 243 500 1041 667 1317 402 2656 250 2867 647 276 442 464 744 889 423 1 0 13 261 46 950 121, 416 ,0 446 0 195 130 664 3~978 462 24t 625 .1104 167 1190 972 2583 333 2920 33! I01 483 1'000 744 17137 351 0 o00 2,582 45'553 122;576 0' 472 0~216 32685~047 6032;528 242'500 IS Tape Verification Listlnq chlumber~er Alaska Computing Center 29-MAR-J990 07:4] PAGES 21 SATC PS2 1 000 R~I.PS2 ~4iPS2 ~46~05 ~5.PS2 ¢~ PS2 927.083 ~M9.PS2 RNI~,PS2 2875,000 R:~q13 P$2 RNI6,P$2 1614,583 RFliP$2 CF4.PS2 420,673 ~F5 P$2 ~F8 PS2 ]12,500 RFg,PS2 RF16,PS2 965,545 GR,PS2 840.278 RN2.PS2 1447,917 RN6,PS2 1791.667 RMIO,PS2 3267,361 240,385 RF2.PS2 444,711 RF6,PS2 64g 038 RFIO,PS2 1658i664 ~FI4,P$2 21 484 TENS.PS2 182 664 RN3 P$2 '545i611 R~7iPS~ 1756 944 R~ll PS2 3388 889 RN15'PS2 30.960 RFS,P$2 524,840 RF7,PS2 689,103 RFll,PS2 1846,955 RF~5,PS~ 195,000 CCL.PS2 1114,583 1298 61! 2555 555 2840 277 320 513 468 750 10~9 647 ~690 705 0,000 ** END OF DATA ** **** FILE TRAILER **** FILF MA~E : EDIT .002 SERVICE : FLIC VERSION : O01A04 DATF ~ 90/03/~7 ~AX REC SIZE : 1024 FTLF TYPE ~ LO LhST FILE : **** FILE HEADER **** FILE NAME : EDIT ,003 SERVICE : FLIC V~RSiOM : 001A04 DATE : 90/03/27 ~AX R~C SIZE : !024 FILE TYPE : bO LAST FILE : ******************************************************************************* FILE - EBIT,O03 ARCO ALASKA, !MC, PRUDNOE 8AY 5 29 !583 PASS ~3 LOG DATA DATA SAMPLED EVERY -,5000 FEET DATA INCL!JDED - ,IS Tame Veri~ication 5istimq ,chlumberoer AlasKa Computlnq Center 2g-NAR-!990 07:43 * TOgb EXTENSIO~ TOOL * TYPE USED NAME * TDT-P ,PS3 THERMAL OECa¥ TOOt, 12500' TO 11294' PAGE: 22 TABI,E TYPE : CONS TONI VALU DEFI FN PRUDHOE BAY FleidName aPl~ 5~-629-21583 APl Serial Number FI, 752' FN[, & 221' FED Field Location SECT 24 Section TOWN lin Township R~NG 14E Range COON NORTH *LQPE County STAT ALASKA State or Province N~TI USA Natlo~ WITN RIC~/H[}RST/BPADLEY Witness' Name SON 379258 Service Order Number PDAT ~SL Permanent datum EPD FT 0 L~F R~ 5ON Measured From APD FT 49, EKB FT 49, EDF FT EGL FT 16 TDD FT 13~,45, T~BLE TYPE : CUR¥ DEPT TPHI NTDT AFMD ABFD AFND Depth Channel Name Sigma (Neutron Capture Cross Section) Status of TDT TDT Porosity TDT Shunt Current Sigma formation ~ far detector (TbTP) Sigma formation nea~ oetector (IDTP) Sigma borebole - far- detector (TDTP) Sigma borehole - near detector (TDTP) Far TDTM Count Rate Near TDTM Count Rate Amplitude formation --far detector (TDTP) Amplitude boreho!e -- Far detector (TDTP) Amplitude formation - Dear detector (TDTP) IS Tame Verification Listing ChlumberQer AlasKa Computing Center 29-MAR-1990 07:43 PAGE: 23 DEFI A~ND~mPlJtUde Borehole '' Dear detector T)~ ( DTP SIGC S!G~ Correctiom $IBH TRAT BACK FBAC TCAN TCAF TCND TCFD TSC~ T$CF INND INFD TTEC HV SATC RN2 RN4 RN7 RNa ~N9 RNI0 RNll RN12 R~I~ R~I5 RNI6 RF1 RF2 ~F6 ~F7 RFIO ~F12 RF 3 RF}4 RF!5 RFi6 G~ TENS Borehole sigma (corrected) -- TDTF Mlnltron mode monitor ratio (TDTP) TDT ~atio Standard deviation of Sigma-formation (TDTP) Back,round, Near Gates Far BacKground Total counts analyzed - near detector (TDTP) Total COUntS analyzed - far detector {TDTP) Total counts - near detector (TDTP) Total counts - ~ar detector (TDTP) Selected gates count rate - near detector (TDTP) Selectedgates count rate - ~ar detector (TDTP) Inelastic count~nq rate - near detector (TDTP) Inelastic counting rate - far detector (TDTP) TDT-P Telemetry Error Count Head Voltage Status o~ ATC Raw Near !st Gate Raw Near 2nd Gate Raw Near 3rd Gate Raw Near 4th Gate Raw Near 5th Gate Raw Near 6th Gate Raw Near7tn Gate Raw Near 8th Gate Raw Near gth Gate Raw Near lOth Gate Raw Near llth Gate Raw Near 12th Gate Raw Near 13th Gate Raw Near 14th Gate Raw Near 15th Gate Raw Near i6th Gate Raw Far 1st Gate ~aw Far 2nd Gate Raw Far 3rd Gate Raw Far 4th Gate Raw Far 5th Gate Raw Far 6t~ Gate Raw,Far 7tn Gate Raw Far 8th Gate Raw Far 9t'h Gate Raw Far ~Otb Gate Raw Far llth Gate Raw Far 12th Gate Raw Far 13th Gate Raw Far 14th Gate Raw Far 15th Gate ~aw Far 16th Gate Gamma Ray Tense. on Tape Verification 61stinq :chlumberger AlasKa Computing Center 2g-MAR-1990 07:43 PAGE: ¸24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 272 4 66 5 66 6 73 7 65 8 68 0~5 9 65 F.' 11 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** X; ............ '"'""'"" ORDER ~ BOG TYPE CLA88 MOD NUMB 8AMP EbE~ C~DE (HEX) DEPT FT SIGN PS3 CU 8TDT ?PHI PS3 PU SFFD PS3 CU SFND P83 CU SBHF PS] CU 8BHN P83 CU 379258 O0 379258 51 379258 51 379258 5i 379258 51 379258 51 379258 51 379258 379258 5! FTDT PS3 CPS 379258 5I NTDT PS3 CPS 379258 51 AFFD PS~ CPS 379258 51 ABFD PS3 CPS 379258 51 AFND PS3 CPS 379258 51 ABND PS3 CPS 379258 5i SIGC PS3 CH 379258 51 $IB~ PS3 CU 379258 51 NMOF PS3 379258 51 000 O0 0 3 1 I 4 68 400 O1 0 3 I 1 4 68 390 O0 0 3 ! 1 4 68 890 01 0 3 I I 4 68 000 O0 0 3 1 1 4 68 4OO O2 0 3 1 1 4 68 400 02 0 3 ~ ! 4 68 400 O1 0 3 ! I 4 68 400 O1 0 3 1 1 4 68 000 O0 0 3 I 1 4 68 000 O0 0 3 I I 4 68 391 O0 0 3 1 I 4 68 391 O0 0 3 ~ I 4 68 390 O0 0 3 t I 4 68 ~90 O0 0 3 ! 1 4 68 400 O1 0 3 1 1 4 68 400 Ol 0 3 1 1 4 68 OOO O0 0 3 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS ?ape Verification Llstlnq 'chlumberoer AlasKa Computtnq Center 29-~,AR-1990 07:43 PAGE: 25 LO ; TYP CLASs cov taxx) '"" ........... .... .... .... ...... ' ........... """ ...... ' .... ' .... TRAT P~3 79 58 1 0 0 3 1 1 4 68 0000000000 SDS! P$3 CU 379258 5I 000 00 0 3 1 1 4 68 0000000000 BAC~ PS3 CPS 379258 F8AC PS3 CPS 379258 51 TCA~ PS3 379258 51 TCAF PS3 379258 51 TCND PS3 CPS 379258 TCFD PS3 CPS 379258 T$CN PS3 CPS 379258 T$CF PS3 CPS 379255 ]NND PS3 CPS 379258 INFD PS3 CPS 379258 51 TTEC PS3 379258 5! ~V PS3 V 37925~ 5~ SATC P83 37925~ 51 RN~ PS3 CPS 379258 5! R~2 PS3 CPS 379258 51 R~3 P83 CP& 379258 51 PN4 PS3 CPS 379258 51 RN5 P83 CPS 379258 51 R'N7 PS3 CPS 379258 51 RN8 PS3 CPS 379258 51 RN9 PS3 CPS 379258 51 RN10 PS3 CPS 379258 51 RNII PS3 CPS 379258 51 P$3 CPS 51 390 17 391 17 000 O0 000 00 O00 OO 000 O0 000 00 000 00 OO0 00 000 00 390 O0 000 O0 000 O0 390 390 O2 390 03 390 04 39O 05 390 06 390 O7 390 08 390 09 390 390 390 12 R~2 379258 ~N 3 P$3 CPS 379258 51 390 13 RN14 PS3 CPS 379258 51 390 !4 R~15 P$3 CPS 379258 51 390 15 RN16 P$3 CPS 379258 51 RF! P$3 CPS 379258 51 RF2 P83 CPS 379258 51 RE3 PS3 CPS 379258 5! RF4 P$3 CPS 379258 51. RF5 PS3 CPS 379258 51 RF6 PS3 CPS 379258 51 RF7 PS3 CPS 379258 51 RF8 PS3 CPS 379258 51 RF9 P$3 CPS 379258 51 RF10 P83 CPS 379258 51 RF!! P$3 CPS 379258 51 RF12 PS3 CPS 379258 51 RF!3 PS3 CPS 379258 51 RFi4 P$3 CPS 379258 51 RF15 PS3 CPS 379258 51 RFi6 PS3 CPS '379258 51 GR PS3 GAPI 379258 5! TENS PS3 LB 379258 51 CCL PS3 V 379258 5i 390 16 39! 39I 02 391 03 391 04 391 05 391 06 391 07 391 08 391 09 391 10 391 39t !2 391 13 391 t4 39I 15 391, !6 310 O1 635 21 150 O1 0 3 o 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 o 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 I 1 4 68 0000000000 i 1 4 68 O00000OO00 ! I 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 1 I 4 6~ 0000000000 1 1 4 68 0000000000 1 1' 4 68 0000000000 1 1 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 ! 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 ! 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 ! 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 i 1 4 68 0000000000 ! ! 4 68 0000000000 I, I 4 68 0000000000 I ! 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 I 1 4 68 0000000000 I I 4 68 0000000000 I 1 4 68 0000000000 1 I, 4 68 0000000000 I ! 4 68 0000000000 1 1 4 68 000000000'0 1 I 4 68 0000000000 ! ! 4 68 0000000000 ! 1 4 68 0000000000 IS Tape Verification bi$tlnq cb!umberqer AlasKa Computing Center 29-MAR-!990 07:43 PAGE: 26 mmmmmmmm~mmm~mmmmmmmm~mmmmmmmmmmmmmmm#mmmmmmmmm~m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DATA ** DFPT. ISH[' PS3 SBHN PS3 ASFD PS3 SIgH PS3 BACK P$3 TCND.PS3 INND.P$3 SATC.PS3 ~N4.PS3 RNa'PS3 RN12,PS3 ~ ~PS3 RFg. PS3 RF]? PS3 DEPT. ISHU PS3 SBNN:PS3 ABFD PS3 B~CK,PS3 ~NN~ PS3 RN12 PS3 RN!~ Ps3 RF4 PS3 ~F~ PS3 RFi~ PS3 RF!6 PS3 DEPT, 'ISHI!,PS3 $~HN.PS3 ABFD PS3 SiBH PS3 BAC~ PS3 TCND PS3 INND PS3 SATC PS3 RN4 PS3 RN~ PS3 RNI~ PS3 RN16 PS3 ~F4 PS3 12506.000 SIGM.PS3 14 044 STDT,PS3 39,46g SFFD,PS3 15:328 SFND,PS3 53.363 FTDT,PS3 9.997 NTgT,PS3 98,558 AFND,PS3 527.948 ABeD,PS3 66 352 M~OF,PS3 1.227 TRAT.PS3 ]52:500 FBAC.PS3 2q,81~ TCAN,PS3 25542 855: TCFD,PS3 75~4.489 TSCN,P$3 17! i 000 RNI,PS3 9vv~O91 RN2,PS3 1590~909 RN5,PS3 1709.200 RN6,PS3 965,909 RN9,PS3 2102.272 RNIO PS3 3214.962 RNI3.PS3 3233.90~ RNI4:PS3 937'500 RFI.PS3 298.295 RF~,PS3 388.258 RF5,PS3 454,015 RF6,PS3 345 644 RFg'PS3 667,614 RFIO,PS3 1164:773 RF1.3.PS3 1245.265 RF14.PS3 3~3'5~3 GR.PS3 63.156 TENS,PS3 I2500,000 38.625 54,985 99,604 59,822 i71.733 27464.738 2528'162 1,000 1590,909 965,909 3214,962 93 '500 345'644 1164~773 383,523 1,2400,000 36,875 73,908 79,326 1!0 882 151 457 18459 727 3049 979 1 o0o 3 18~1 510 745 443 289 062 SIGg,PS3 SFFD.PS3 FTDT ' PS 3 AFND PS3 M~OF PS3 FBAC PS3 TCFD PS3 INFO RN1 PS3 RN5 P$3 RN9 RN13 PS3 RF1 PS3 RF5 PS3 RF9 RFI 3 PS3 GR PS3 SIGM.PS3 SFFD PS3 FTDT P$3 AFND P$3 MMOF P$3 TCFD P$3 INFD PS3 RN! PS3 PS3 RN5'pS3 RNg, RNI3,P$3 RFI'PS3 RFS,PS3 14.665 15 625 0!717 532 684 !,047 6 458 610 742 26 83! 909 O91 1709 280 2i02 272 3233 29~ 464 667 1245 63 STDT,PS3 SFND.P$3 NTDT.PS3 ABND TRAT PS3 TCAN PS3 TSCN PS3 TTEC PS3 RN2 P$3 RNS,PS3 RNiO,PS3 90~ RN14 PS3 295 RF2 P$3 015 RF6 PS3 6!4 RFIO PS3 265 RF14 PS3 156 TENS,PS3 15,3~3 ]6'246 6'O2O 323'603 1.287 30 O3 331 913 917'969 134~,656 ~63 ,1!5 ]806,640 23],77] 299,479 STDT SFND PS3 NTDT PS3 ABND TRAT TCAN,PS3 TSCN,PS3 TTEC'PS3 PN2,PS3 RN6,PS3 RNIO.PS3 RN14,PS3 RF2,PS3 ~F6,PS3 66.000 TPHI.P$3 17 245 SB~F P$3 436.563 $IGC,P$3 2.492 SD$I.PS3 58572 734 TC~F,PS3 7386]228 TSCF,P$3 0 000 ~V.PS3 185 760 RN3'PS3 1837 121 RN7 PS3 ~059 659 RNll:PS3 2618 371 RN15.PS3 46 440 RF3.P$3 501 894 RF7 PS3 662 879 RFll:PS3 1~12,689 RF15,PS3 85.000 CCL.PS3 ' 66.000 17.328 27'556 440.101 34~640 356.156 19~227,807 oo0 18 760 2 2618 46 501 662 1112 195 TPHI.PS3 SBHF.PS3 AFFD.PS3 SIGC,PS3 SDSI,PS3 TCAF.PS3 TSCF,PS3 HV PS3 RN7,PS3 659 RNll,PS3 7! RN1].'P$3 140 RF 'PS3 894 RF7.PS3 879 RF!l,PS3 689 RF15*PS3 000 CCL,PS3 66 000 TPHI,PS3 18 561 1¸6 448 2 24642 4054 0 123 !1,68 1529 15!0 28 286 $BHF'PS3 558 AFFD,PS3 596 $IGC PS3 408 SDSI 695 TCAF 496 TSCF 000 ~V 840 RN3 620 RN7 948 RNll 417 RN15 380 RF3 458 RF7 PS3 PS3 P$3 PS3 PS3 PS3 PS3 P$3 PS3 PS3 31 834 41i855 101 866 1,149 0 251 23507 008 2964 316 238 125 1112 689 1425 189 3039 772 1657 197 298 295 468 750 1036 932 838 068 0 000 0,000 4'1,966 208'501 0'955 O, 11 5524, 15 ~208,658 24~,000 11.1 ,689 1425,~89 30.39, ,72 57,197 i~98,295 468,750 i036,93~ 838'06 0,000 31 808 61:' 49 6! 0 831 0 405 10235 594 1684 ~76 1~43 ~5 20 03 758'464 1956,380 32;813 1126.562 200,521 .IS Tape Verification Listing ;chlumber!~er Alaska Computing Center PFS,PS3 270,833 RFg.P$3 RFi~,P$3 583,333 RF13.PS3 RF16,PS3 231,771 GR.PS3 DEPT 12300,000 SIGg. PS3 ISHU:PS3 37,750 SFFD,PS3 S~PN.PS3 56 213 FTDT,PS3 ABFD.PS] 94:376 AFND.PS3 SIBH,PS3 73,006 ~MOF,PS3 BACK.PS3 162.623 FBAC,PS3 TCND.PS3 24928.988 TCFD.PS3 INND.PS3 2357,055 INFD.PS3 SATC,PS] 1.000 RN1.PS3 RN4.PS3 13~8,889 RNS,PS3 RNS,PS] 889.757 RN9,PS3 RNI~.PS] 2690.972 RN13,PS3 RN16.PS3 112.4,132 RF~ P83 ~F4.PS3 323.661 ~F5:PS3 ~FS'PS3 293,899 RF9'PS3 RF12,PS3 837.053 RF13,PS3 RF16,PS3 394.345 GR,P$3 DFPT, ISHU. SIBH TCND !MND SATC R~12 ~I6 RF!2 RF!6, P$3 PS3 PS3 P$3 PS3 PS3 PS 3 P$3 PS3 12200.000 41,219 54.678 93 841 69~717 !72,751 23114,238 2626,594 000 1461 805 930 555 2586 805 92.3 61.1 328 947 271382 833 333 29O 570 SIGM. SFFD, FTDT, AFND ~MOF FBAC TCFD INFD RN! RN5 RN9 RN13 R~t3 PS3 05.3 PS3 P$3 P$3 PS3 PS3 PS3 PS3 PS3 P$3 P$3 PS3 DEPT. iSHU, ABFD~ BACK~ TCND, P$3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 12100 000 39 906 53 642 9t 586 67 879 173'815 27218,289 2552,049 1,~000 1356.647 949,90i 2961,309 1299,603 ~95,139 263,310 P$3 PS3 P$3 PS3 PS3 PS3 PS3 P$3 PS3 PS3 PS3 PS3 PS3 PS3 29-NAR-1990 07:43 398,437 RFIO,PS3 632.812 RF14,PS3 71.375 TENS.PS] 12.490 STDT.PS3 13.488 SFND,PS3 9.265 NTDT,PS3 474,450 ABND,PS~ 1 282 T:RAI" .PS3 32~365 TCAN.PS3 7453.259 TSCN.PS3 338,214, TTEC,PS3 802 951 RN2.P$3 1380~208 RN6.PS3 1762 153 RN10,PS3 3025!~]3 ~N14.PS3 226 5 RF2,PS3 360,863 RF6,PS3 505,952 RF10,PS3 1011,905 RF14.PS3 39,031 TENS,PS3 14,917 15,915 8.7~1 462 6 6 08 6761 444 324 2~9 892 I 179 139 249 ~8 331 9 531 798 921 053 37 875 II,141 12, 78 9 560 5! : o9 1 192 30 157 7847 ~()7 8 254 i391 369 !76~,873 337 .016 318 87 474,537 STDT,PS3 SFND,PS3 NTDT,PS3 ABND,PS3 TRAT,P$3 TCAN,PS3 TSCN,PS3 TTEC,P$3 RN'2,PS3 RN6,PS3 RN!O,P$3 RN14'P$3 RF2,PS3 RF6,P$3 RF~0;PS3 RF14,P$3 TENS,PS3 'T $.'DT,P$3 SFND'PS3 MTDT.PS3 ABND'PS3 TRAT,PS3 TCAN,PS3 T$CN,~S3 TTEC, S3 RN2',PS3 RN6.PS3 ~NIO~PS3 RN14'PS3 RF2,PS3 PF6,P$3 RFIO,PS3 408,854 638.021 2O0.000 66.000 15.274 26.196 411.078 2 497 44343:750 7794 984 01000 143 190 15~2 118 1788.194 2756'076 19,350 412.946 520.833 1000,744 215.000 66 17 24 434 2 39717 6151 0 166 461 7!5 2229 25 39! 5!8 923 i80 66 14 28 2 65781 9250 0 157. 1540, 1822. 3~.07. 20. 410, 532. 000 88O 2OO 407 470 531 655 000 410 805 278 167 800 996 O92 794 000 000 233 968 596 635 813 O45 000 380 i78 ~40 880 407 RFll PS3 RF15:PS3 CCL,PS3 TPHI.PS3 SBHF,PS3 AFFD PS3 SIGC:PS3 SDSI PS3 TCAF:PS3 T$CF,PS3 HV.PS3 RN3.PS3 RN7,PS3 RNI1,PS3 ~NI~.PS3 RF .PS3 RFT.P$3 RF~I,PS3 RF15,PS3 CCL,PS3 TPHI.PS3 SBHF,PS3 AFFD PS3 $IGC PS3 SDS! PS3 TCAF PS3 TSCF PS3 HV PS3 RN3 PS3 RN7 PS3 RNll PS3 RNI5 PS3 PS3 RFi~ PS3 RF1 P$3 COb,PS3 TPHI,P$3 SBHF,P83 AFFD,P$3 SIGC,PS3 SDSI,P$3 TCAF,PS3 TSCF,PS3 MV,P$3 RN3.P$3 ~N7 PS3 RNII PS3 RN15 PS3 RF3,PS3 RF7..PS3 RFI!,Ps3 PAGE: 27 546 875 0.000 32 192 42 020 93 199 0 951 0 268 17760 219 3121 988 240 750 1046 007 1102 430 2534 722 2122 396 252 976 264:137 751.488 855'655 0,000 32,028 46,428 90 145 I 044 0 426 16079 709 2490 ~08 241 50 1086 805 101,7 361 2451389 1614583 224 :781 276 864 753 838 652 412 0 000 35,79~ 42,17. 97,370 0,892 0'216 24962,934 3510'214 237,500 997'024 1!65~675 2673~611 2445,436 263,310 344,3.29 787,037 .IS Tape Verification Listino .cblumberger AlasKa Computin~ Center RF12,PS3 911,458 RF13,PS3 RF16,PS3 509,259 GR,P83 DEPT. ISHU.P$3 SB~,PS3 AB D,P$3 SlB~,PS3 B~C".PS3 TCND,PS3 INND.P$3 SATC,PS3 PN4 P$3 RNSiP$3 RN12 P$3 RNI6,PS3 RF4,P$3 PFS.PS3 RF12.PS3 RF1.6.PS3 12000,000 41,656 55.709 94,536 7~.567 1~8.114 27630.641 2659 983 1 000 1314 103 953 526 3088 942 1458 333 319 940 271 577 896,577 509,673 SIG~,P$3 SFFO,PS3 FTDT.PS3 aFND,PS3 ~OF,PS3 FBAC,P$3 TCFD'PS3 INFD PS3 RNI:PS3 RNS,PS3 RN9,P$3 RN13,PS3 RFi.PS3 RFS,PS3 RFg. P$3 RF13,PS3 GR.P$3 DEPT. ISHU ABFD SIB~ BACK TCND INND '$~TC RN4 RN!~, RNI , RF8 RF16, P$3 PS3 PS3 PS3 PS3 PS3 P$3 PS3 PS3 P$3 PS3 PS3 PS3 PS3 PS3 11,90 4 5 8 6 18 2632 263 1342 933 2908 !394 28 465 0,u00 3,313 0,195 6 322 0 O59 9 9O5 0 309 8 310 1 000 147 494 654 231 250 000 36I 27~ S!GM SFFD FTDT ~FND FBAC TCFD INFD RN9 R~13 ~F5 RF9 .P$3 P$3 PS3 PS3 PS3 P$,3 P$3 ,P83 .PS3 ,PS ;p 3 3 'P$3 DEPT, !SHU. ABFD $iBH BACK TCND !NND $~TC' RN4' F4, RY!2. PS3 PS3 P$3 PS3 PS3 P$3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 11800 000 42 094 65 61! 99 789 84 662 196 613 23435 676 2857 043 1,000 1333;333 96!,805 2291;667 1468,750 0'449 937'500 $IG~ SFFD FTDT AFND FBAC TCFD INFD R~!3 ~F! RF9 RFt3 ,P$3 ,PS3 'PS3 ;Ps3 ,~$3 '~;S3 ,PS3 ;Ps3 ,PS3 PS3 PS3 P$3 P$3 29-~AR-1990 07:43 1!51 620 ~F14,P$3 31:359 TENS,PS3 11.095 12 198 9!939 510 083 1.185 32,482 5096,471 326.913 821.31~ 1398.23 1830 929 3457;532 241 815 353 423 476 190 1190 476 34 688 12 221 13:194 9,615 498,699 1.124 36't92 7515,222 304,479 877,404 1398;237 1822,9~7 3345,3 3 239,5 3 340,2 8 465,278 1100i694 34;969 9,623 t0.405 9.984 386 337 1 199 32 .8~25 3 32.~ 090 9~ 083 54 611 2642 361 216 346 5 ~5 1 853 955 STDT.PS3 SFND PS3 ~TD't:PS3 ABND,PS3 TRAT.PS3 TCAN,P$3 TSCN,PS~ TTEC,PS3 RN2,P$3 RN6,PS3 RN10,PS3 RN14.PS3 RF2 PS3 RFIO.P$3 PF14.PS3 TENS.PS3 STDT,PS3 SFND,PS3 NTDT.P$3 ANN[) PS3 TR.f,PS3 TCAN,PS3 TSCN,PS3 TTEC PS3 RN2 PS3 RN6 .P$3 RNi0 PS3 RN14 P83 RF2,P$3 RF6.,P$3 ~FIO;P$3 RFi4,P$3 TENS,PS3 STDT,P$3 SFND'P$3 NTDT,PS3 ABND,P$3 :TRAT'PS3 TCAN'PS3 TSCN,P83 TTEC PS3 RN2 P$3 RN6 PS3 RMIO PS3 RN!4'PS3 RF2,PS3 RF6,PS~ RF10,PS3 RFI4'PS3 1192 210 66 13 28 414 2 52315 9654 0 I78 1654 1846 3505 27 416 528 1216 190 66 14 27 408 2 47338 8846 0 170 1514 18.30 3120 ~0 524 112:1 190 66 12 21 403 43267 8102 0 204 ~215 1555 2791 25 400 496 !354 .130 .O00 00o ,507 .693 .519 .607 094 :803 000 O20 647 955 60g OgO 667 .274 518 '000 m 000 366 963 825 671 359 30~ ,000 .280 423 9.29 993 96O 361 !306 528 000 .O00 '004 400 490 858 016 299 000 :336 278 555 667 800 '641 ,795 ,I, 67 RF15 PS3 CCL:PS3 TPMI.PS3 SBHF.PS3 AFFD,PS3 SIGC.PS3 SDSI.PS3 TCAF.PS3 TSCF,PS3 HV,PS3 ~N3.PS3 RNT.PS3 RNII.PS3 RNI5.PS3 RF3.PS3 RF7 P$3 RFIliPS3 RF15 PS3 CCL'PS3 TPHI.PS3 SB~F PS3 AFFD:PS3 $IGC PS3 SD$I PS3 TCAF P$3 TSCF P$3 ~V PS3 RN3 P$3 RN7 PS3 RN!I PS3 RN15 P$3 RF3 P$3 RF7 PS3 RFi~ PS3 RF1 PS3 CCL,P$3 TPHI.PS3 $BMF,P$3 AFFD'P$3 $IUC P$3 SDSI PS3 TCAF P63 TSCF P$3 ~iV,P$3 RN3.PS3 RN7'P$3 RNlI,P~3 RN15;PS3 RF3,PS3 RF7;Ps3 RFII,PS3 RF!5'PS3 PAGE: 978 35, 40, 10i, O, 0. 20066 3703 243 1065 1225 2676 2700 245 349 814 1056 0 36 45 98 0 0 17724 3312 243 977 122~ 268 2455 2!8 333 784 951 0 7 45 92 23287 4360 243 :!031: 979 2093 2319 252 376 769 1233 28 009 000 249 940 810 216 277 252 375 7O5 961 282 32O 536 702 732 547 000 303 435 O16 766 269 750 293 125 564 955 30! 929 .750 14O 001 030 5 50 167 ,'/5O 4O4 6O3 231 974 ~IS Ta~e Yerification Listlnn ;chlumberger AlasKa Computing Cent:er 713.141 GR.PS3 DFPT, 11700.000 $IGM.PS3 IShU.PS] 42,094 SFFD.PS3 SBBN,PS3 59 148 FTDT.PS3 ABF~,PS3 901219 AFNO,P$3 SIgH,PSI 80,365 M!~OF,PS3 BAC~.PS3 201.840 FBAC PS] TC~D.PS] 20936'0~7 TCFD!PS3 INF9 PS3 IN~.~D PS3 2604,251 SATC:PS] 1,000 RNI,P$3 RN4,PS3 1423.611 RN5.P$3 ~NS.PS] 930'555 R~{9,PS3 RNI~.PS3 2413,194 RN13.PS3 RN16,P$3 902,778 RF{.P$3 PF4.PS3 332.532 RFS,PS3 RF~,PS3 248,397 RFg. PS3 RWI~,PS3 733.173 RFi3.PS3 RF16,PS3 244,391 GR,PS3 ISHU $BHN ABFD TCND INND RNS, RNI~, RN1,6. RF4, RFI~ RFI6 11600 PS3 40 PS3 52 PS3 111 PSI PS3 206 PS3 28726 PS3 2657 PS3 PS3 133~ PS3 913 P$3 3012 PS3 1.770 P$3 375 PS3 291 P$3 1149 P$3 899 000 344 692 327 707 032 676 601 000 141 461 820 833 000 667 305 305 SIG~ PS3 SFFD:P$3 FTDT,PS3 ~FND,PS3 ~MOF.P$3 FBAC.PS3 TCFD PS3 INFD PS3 RN! P$3 ~N5 P83 RN9 PS3 RN13 PS3 ~F1,PS3 ~F5.P$3 RF9,PS3 RF13;PS3 DEPT !SHU BACK, TCND. INND SATC RNI~ RN16 ~F4 RF!~ RFI6 11500 PS3 38 PS3 58 PS3 135 PS3 69 PS3 216 PS3 2~657 PS3 2620 P$3 I PS3 1482 PS3 945 PS3 3016 PS3 ~798 PS3 442 PS3 297 P$3 1283 PS3 963 ,000 .625 322 067 822 906 496 479 000 372 51] 7O8 619 542 $IG~ SFFD FTDT AFND ~gOF TCFD INFD R~9 RN13 RF9, RF13, PS3 PS3 PS3 PS3 PS3 P$3 PS3 P$3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 PS3 29-~AR-~990 07;43 31,766 I'E ;$''N .PS3 16. 1.8. 7. 471, 1 35 5603 302 1416 1760 2336 208i 340 480. 701, 9~ 514 1 34 10571 1474 1750 3517 263 378 559 14~7 36 i0 I0 i4 483 i2399 1438 1786 34~5 286 483 16 910 STDT,PS3 264 SFND.PS3 ~3 NTDT.PS3 8 ABN[).P$3 211 TRAT.PS3 019 TCAN.PS3 580 TSCN,PS3 25! TTEC,PS3 944 ~N2,PS3 667 RN6.P$3 417 RNIO*PS3 805 RN14,PS3 333 ~FR,P$3 545 RF6.PS] 7~9 ~FIO,PS3 122 RFI4,PS3 844 TENS,PS3 592 STDT,PS3 277 SFND.PS3 ~5 NTDT,PS3 I ABND,PS3 257 TRAT.PS3 666 TCAN,P$3 633 T"'~''', ou~ PS3 833 TTEC'PS3 397 RN2'PS3 359 RN6,P$3 801, RNIO,PS3 628 RN14"P$3 889 RF2~PS3 472 RF6"P$3 028 RF10,PS3 9!7 RF14,PS3 188 TENS~PS3 STDT,P$3 407 NTDT,PS3 945 ABND,P$3 PS3 163 TRAT,Ps3 4~4 TCAN,... 340 TSC~,PS3 381 TTEC.P$3 397 RN2'PS3 301 RN6,PS3 859 RNI(),PS3 57'7 RN1,4'PS3 458 RF2,PS3 631 RF6,PS3 524 RFIO,PS3 226 RF!4,PS3 438 T~NS*PS3 180,000 66 000 ilo84 22 220 414 665 ~ 729 25248 910 4789 977 0 O00 176 472 1489'583 1743,055 1895.833 27,090 340.545 436,699 629,006 195.000 66 000 11 963 28 534 423 109 2 047 57581 242 10840 340 0 000 189 630 1618 590 1786 859 3741 987 34 i~ 0 5!3 ~9 597 2 185 000 66,000 11.708 26 973 447 221 1 686 56111008 10470 764 0 000 193 500 1554 48.7 i810 897 3597 756 38 700 576 637 680 803 1897 321 205 O00 CCL.PS3 TPMI.P$3 SBHF.PS3 AFFD,PS3 SIGC,PS3 SDSI.PS3 TCAF.PS3 TSCF.PS3 HV.PS3 RN3.PS3 RN7,PS3 RNll.PS~ RN15 PS3 RF3:PS3 RF7.PS] RF!I PS3 FlS:PS3 CCL.PS3 TPHI,PS3 SB~F.PS3 AFFD,PS3 SIGC.PS3 SDSI.PS3 TCAF,PS3 TSCF,PS3 HV'PS3 RN3,PS3 RNT,PS3 RNI! P$3 RF.3,PS3 RF7,P$3 RF!~,PS3 RF1. ,P$3 CCL,PS3 TPMF~ P$3 $BH AFFD,PS3 $IGC.PS3 SD$I,PS3 TCAF,P$3 TSCF P$3 MV PS3 RN3 PS3 RN7 PS3 RNIl,PS3 RNiS,PS3 RF3,PS3 RF7.PS3 ~Fll,PS3 ~FIS.PS3 CCh. PS3 PAGE: 29 0.000 39 708 9: 6o 79,038 1,487 0 564 9251 295 1755 065 243 125 1100 694 1034 722 2347 222 128t 250 252 404 276 442 673 077 452 724 0 000 20,109 44 900 113 486 0 792 0 229 28131'105 5296,008 243'000 1001,603 1326,i22 2572,115 2988,782 · 288 !94 461. 806 888 889 1451, 389 0 000 1¸3 0 !95 33276 031 6209 575 242 875 1157 853 21 294 3064 904 31 500 49~ 512 1.030 506 !711~09 O .00 Tape Verification Listlng ~chlumberger AlasKa Computing Center DEPT. ISHU. PS3 SBH~. PS3 ABFD.PS3 $IB~.PS] BACK.PS3 TCND.PS3 IN~D,PS3 S~TC.PS3 RN4,PS3 RNa,PS3 RNi2.PS3 RN16.PS3 RF4 PS3 RFS:PS3 RF12 PS3 RFI6~PS3 DEpT ISHU.PS3 SBH~!,PS3 ASFD,PS] SIBH.PS3 BACK PS3 TCND PS3 SATC PS3 ~4 PS3 RN!~ PS3 R~16 PS3 ~F4 PS3 RF8 PS3 RF PS3 D~PT ISHU P$3 ABFD PS3 BAC~ PS3 TCND P$3 S~TC PS3 R~!2 PS3 R~16 PS3 Pr4 PS3 ~F8 PS3 RFI2 PS3 RFI6,PS3 11400,000 37.750 60 527 137:361 72,559 218,434 29812.332 2701 142 1 000 1550 481 925 481 2920 673 2143 429 468 750 308 780 1324,405 1331,845 11300.000 38 625 62:972 140.223 76'295 228,563 28265 504 2798 380 1 000 1521 577 930 059 2719 494 1923 363 476 763 344 551 1254 006 1145 833 11294 000 39 063 59 872 144 352 71101 224 371 28360 992 2914 128 I 000 ~566 220 944 940 2879 464 1860 !!!9 520 833 360 577 1390 224 1101 763 SIG:4.PS3 S~ FD PS3 FTDT ' .PS3 AFND.P$3 ~OF P$3 FBAC' ,PS3 TCFD,P$3 !NFD,PS3 RNI.P$3 RN5,PS3 RNg,PS3 RN~3.P$3 RF1,P$3 RFS,PS3 Rf'9,P$3 RF13,PS3 GR,P$3 $Ig~ P$3 SFFD P$3 FTDT PS3 AFND PS3 ~GF PS3 FBAC,PS3 TCFD.PS3 INFD,PS3 "~ PS3 RN1,. RNS,PS3 RNg,PS3 RN!3 PS3 RF1 PS3 RF5 PS3 RF9 PS3 RF!3 PS3 GR'PS3 29-g~R-lg90 07;43 8.822 9,124 14.666 471,339 1,302 38,307 13766.666 422 479 861i378 1458 333 1955,128 358~.730 282 738 52O 833 647 321 17~9 434 7,762 9,359 9 891 14 300 437 288 4~ 269 629 12922 631 42~ 793 85 655 1488 095 1834 3307 ~7 280 449 ~6.827 697,~15 1742, 88 10,117 10,049 t4, 3 457,~2 1. 9 1315 , 53 420.495 885,4!7 149~,~56 185 . 78 3247,768 300.48! 4~0,769 705, ! 28 i790,865 10,625 STDT,P$3 SFND.P$3 NTDT,PS] AB~O,PS3 TRAT.PS3 TCAN,PS3 TSCN,PS3 TTFC,PS3 RN2,PS3 RN6'PS3 RN10,PS3 RN~4,PS3 RF2,PS3 RF6,PS3 RFIO,P$3 RF14,PS3 TENS,PS3 STDT,PS3 SFND.PS3 MTDT,P$3 ABND,PS3 TRAT.PS3 TCAN,PS3 TSCN,PS3 TTEC,PS3 RN2,PS3 RN6.PS3 RNIO,P$3 RNI~.PS3 RF2'PS3 RF6,PS3 RFIO,PS3 Rf'l. 4,P83 TENS,PS3 STDT.P$3 SFND.P$3 NTDT,PS3 ABND,P$3 TRAT,PS3 TCAN,PS3 TSC~,PS3 TTEC,P$3 RN2,PS3 RN6,PS3 RNIO,PS3 R~14'~S3 RF2,PS3 RF6,~S~ RFIO,.S3 RFI4,PS3 TENS,PS3 66 000 TPHI,P$3 25 531 453~170 SIGC.PS3 1,57a SDSI.PS3 61224.602 TCAF.PS3 11536,809 T$CF,PS3 0,000 HV PS3 193.500 RN3:P$3 1622.596 RN7,PS3 1850.961 RNII.PS3 3886.218 RN!5 PS3 27 090 RF3~PS3 6021678 RF7 PS3 710 565 RFll:PS3 2247 023 RF15,PS3 210 000 CCL.PS3 66.000 TPHI,PS3 10,909 SBHF,PS3 24 151 AFFD,PS3 471 559 SIGC,PS3 SDSI-,PS3 1 53149 10062 0 208 1577 1774 3511 46 604 701 2087 205 531 703 TCAF PS3 223 TSCF:PS3 000 ~¥,P$3 980 RN3,P$3 381 RN7,PS3 .553 RNll.P'S3 904 RN15,PS3 440 RF3.PS3 968 RFT'~P$3 !22 RF!!,P$3 339 RF15,PS3 000 CCL'PS3 !1, 25 473 1 52693 9946 0 228 66 000 TPHI.PS3 647 8BHF P83 488 AFFD PS3 191 $IGC PS3 517 SDSI PS3 492 TCAF*P$3 430 TSCF;.PS3 000 HV,PS3 330 RN3,Ps3 I558.780 RN7*PS3 1826,637 RN~!'PS] 3325~893 RNI5,PS3 38~700 RF3.PS3 604,968 RP7,PS3 701.122 RF!!.,PS3 1967,t47 RF!5~Ps3 {80.000 CCL,PS3 PAGEI 30 11,278 46,804 135,452 0 364 01173 38770 344 7305 659 243 000 1181 891 1270 032 2696 314 3433 693 383 185 595 238 1004 464 2180 059 0,000 10 572 48 720 12~546 425 0 190 34706969 6570 671 243 375 1201. 637 1153 274 2526 042 3046 875 368 590 584 936 !045 673 1967 147 o ooo 10 39:2 47 629 0 197 34732 664 6556:142 243 000 1145 833 1212 797 2630208 :2916 667 404 647 536 859 !133 814 1971. 154 0 000 Tape VeriflcatloD Listlnq chlumberger Alaska Co~putinq Center 29-~AR-1990 07:43 PAGES ** KND OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT $~RVIC~ : FLIC VERSION ~ 0OlA04 DATE ~ 90/0]/27 MAX REC SIZ~ : FILE TYPE ~ LO LAST FILE **** TAPE TRAILER **** SERVICE NAPE : EDIT [)ATP : 90/03/27 ORIGIN : FLIC TAPE NAME : 73717 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT ~ ARCO ALASKA, I~C.,PRUDHOE BAY,D.S. 18-5,API #50-029-21553 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 90/03/27 O~IG!N : ~LIC, REE[~' NA~E : 73717 CONTINUATION # : PREVIOUS REEL CO~ENT : ARCO ALASKA, INC,,PRUDHOE BAY,D.8. 18-5,API ~50-029-21583
