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184-074
P LUGG iJiG LOCATION C~,~.'zR~.gCE REPORT_ Sta~a cf A!askz ~= oz.-. ~ ~ c~szx~=zc~ cc~sszo~ k_-- .- Wei! ."Tame Lcca~icm Review t_k~e well file, ~u~' c=mmae, u: on plu%~j~-~g, wail haa~ sUnUps, ~ !ocauicn c!e~ce'- ,~r~e _!o~. c!e~. c~e. . ~ ~ ~ ~.,_ to~ ~i, ~ [/53~ ~ Well hear =am o~f: -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Staius of Well ' Classification of Se'rvice Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name' of 0~erator ........................ 7. P~rmit Number - BP Exploration (Alaska) Inc. 184-074 301-279 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21115-00 4. Location of well at surface 9. Unit or Lease Name 854' SNL, 165' EWL, SEC. 22, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval ~:~ ...... 3521' NSL, 3696' EWL, SEC. 15, T11N, R14E, UM At total depth I '~".~F~ ~i 10. Well Number 4208' NSL, 4209' EWL, SEC. 15, T11N, R14E, UM i S~,4~~' 15-16 Field 11. and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation andI$el~_l..~,~'~, Prudhoe Bay Field / Prudhoe Bay Pool RKB = 71' ADL 028306 12. Date Spudded06/06/1984 113' Date I'D' Reached 114' Date COmp'' Susp'' Or Aband'06/25/1984 10/5/2001 115' Water depth' if OffshOreN/A MSL 116' NO' Of COmpletionsZerO 17' T°tal Depth (MD+TVD)118'11891 8850 FT Plug Back Depth (MD+TVD)11826 8824 FT1119' Directional SurveY 120'[]Yes [] No Depth where SSSV set. 21. Thickness of PermafrostN/A MDI 1oeo' (Approx.) 22. Type Electric or Other Logs Run DIL / BHCS / GR / SP, LDT / CNL / GR / CAL, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD CASiNC~ ..... SE.i_r'iNG DEPTH " 'HOLE ' SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' ;~0" 1910# Poleset 13-3/8" 7~# ..... L-~0 ' Surface ' ' 2495' '1'7-':1/2" 'J960 sx Permafrost 'E', 400 sx PF 'C' , 9-5/8" 47# L-80 Surface 10850' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' , , , 7" 29# L-80 10496' 11848' 8-1/2" 380 sx Class 'G' ,,, 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.3#, L-80 11712' 10243' & 11699' MD TVD MD TVD 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11685' Set XXN Plug to isolate Perfs 11560' Set Cement Retainer 11560' pea with 31 bbls Class 'G', Sqzd to 1000 psi 11536' Set Whipstock 27. PRODUCTION TEST Date ~:irst Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Ho~rs Tested PRODUCe'ION FoR OIL-BI~L~' GAS-MCF ' ' WATER'BBL CHOKE SIZE ~ GAS'OIL RATIO TEST PERIOD ! FI(~w Tul~ir~g'Casing' Pressure CAL~ULATED OIL-BgL G'A~-M~F ' WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE ~. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips· RECEIVED JAN ]. ] 2002 ?~:~.r'" i ~m :~' i~ ~:~, AlaskaOil &Gas, , Cons, Commission Form 10-407 Rev. 07-01-80 Anul~ur .~ubmlt · ' In Duplicate 29. Geologic Markers 30. Formation Tests ' Measured True Vertical Include interval tested, pressure dat~, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Sadlerochit 10898' 8355' Top Zone 3 11124' 8489' Top Zone 2 11255' 8561' GOC 11532' 8701' Top Zone 1 B 11695' 8772' RECEIVED 1 1 Alaska 0il & Gas Cons. Commissio, Apr. hnr~..~. 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~'~~.__~ ~~.~ Title Technical Assistant Date 15-16 184-074 301-279 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENEral.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM '~6 A~D 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 proclucing 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 O¢iGi qAL Well: 15-16A Rig Accept: 11/09/01 Field: Prudhoe Bay Unit Rig Spud: 11/11/01 APl: 50-029-21115-01 Rig Release: 11/20/01 Permit: 201-192 Drilling Rig: Nordic #1 PRE-RIG WORK 08/14/01 Drift tubing. 08/15/01 Locked out TRSSSV. 08/18/01 MITIA passed to 3000 psi. 08/22/01 Drift with 16' x 2.8" dummy patch to 10436'. Pulled patch from 10433'. Missing lower elements and bottom section of patch. 08/23/01 Ran LIB to 10448', took picture of bottom portion of eclipse patch, recovered ¥~ of smaller element. Ran 2.69" blind box to 10448' in an attempt to jar patch parts down hole. Pulled bottom 28" of patch. Missing one element. Tagged PBTD at 11759'. Tagged XN nipple at 11698'. 09/27/01 Pressure tested master valve and wing and swab, passed. MITOA passed. PPPOT-IC passed. 09/28/01 Set 2.813 XXN plug at 11685'. Pull GLV's. 09/29101 Injectivity test:: Loaded well with 150 bbls seawater; 1 bpm at 2600 psi; 1.4 bpm at 3000 psi. Freeze protected well with 25 bbls methanol. 10/02/01 Tubing punched at 6 foot intervals (11658' - 11664') with 1.56" tubing puncher. 10/05/01 Tag plug, pick up to 11560' and set cement retainer. Shear off and put 6 bbls Biozan on top of retainer. Put 30.5 bbls 17.0 ppg cement in straddle squeeze at 500 up to 1000 psi. Very little cement behind pipe. Put 1 bbl cement on top of retainer and pull up to safety, holding 1000 whp. Run in hole and cleanout to 11545' with Biozan. Get 50 bbls cement returns back to tanks, run back in hole, unable to jet down to cement retainer. Got to 11540', pull up hole to 9000'. Injection test: Pump .7 bbls, pressure to 1500 psi, solid. Pull out of hole jetting mandrels and jewelry. At surface, o-rings missing from seal area of stinger. 15-16A, Pre-Coil Tubing Drillir,~ Page 2 10/19101 Drifted tubing with 25' long 2.7" max OD dummy whipstock to 11412' sim. Unable to work deeper. Run in hole with 1-1/2" toolstring, sat down at 11425' and 11453', able to work through. Tagged hard at 11494' sim. Cement in bailer. 10/24/01 Make up chomp mill. Run in hole, dry tag at 11531' Mill to 11546', pull up hole to 11400' back reaming. Pump 15 bbls Bio, run in hole milling to 11565'. Pull up hole chasing returns to 11400'. Run in hole milling to 11568'. Pump another 15 bbls Bio, tagged cement retainer. Drop 5/8" circulating ball, chase with KCL, pump 20 bbls Bio, pull out of hole chasing returns. Freeze protect tubing. 10/25/01 Drifted tubing with dummy whipstock to top of cement at 11534'. 10/26/01 Logged SCMT-A (and field test SCMT-BB) from TD of 11557' to 10239'. Good cement in annulus from 11546' to 10560'. Got hung up at GLM at 9830', pull out of rope socket. Will need to fish SCMT-BB. 10/28/01 Latch and pull out of hole SWS SCMT tool string at 11488'. 10/29/01 Set TIW LSX whipstock with top at 11536', face at 172 degrees right. RA tag at 11541' ~::~!: :i .:~ , .~ ~ ' BP EXpLORATION Page I ~ i - iiOperationssummary Report ' Legal Well Name: 15-16 Common Well Name: 15-16A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 10/19/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ~-.Date:-::~:From~To !H°ursi:Acfi~i~ic°d~NPT: ~phaSei'~"iillI ;:: ~ Description'ofOperations 11/9/2001 00:00 - 01:00 1.00 MOB ~ PRE Continue move from 15-32A. 01:00 - 02:30 1.50 RIGU P PRE Accept rig at 0100 hrs 11/9/01. ND tree cap. Nipple up BOP stack. 02:30 - 06:30 4.00 RIGU P PRE Pressure test BOP stack. Witness waived by AOGCC. 06:30 - 07:00 0.50 RIGU P PRE Standby while DSM crew moves green tank out, builds dike, moves green tank back in place. 07:00 - 09:45 2.75 RIGU P PRE Resume pressure testing. DSM dike spot and dike flowback tank. RU hardline and PT 09:45 - 10:15 0.50 STWHIP P WEXlT PU BHA components, MWD collars, motor, etc. 10:15 - 10:35 0.33 S'I'WHIP P WEXIT Safety meeting prior to making up milling BHA. 10:35 - 11:45 1.17 STWHIP P WEXlT Shut lateral valve, open wing, bleed off trapped FL pressure of 450 psi. SI wing. MU BHA #1, Special HC longer gauge window mill SN 0324862, with WF fixed 2.5 deg motor. 11:45- 12:00 0.25 STWHIP P WEXIT MU injecter. 12:00 - 12:25 0.42 S'I-WHIP P WEXIT RIH for shallow hole test. 12:25 - 12:35 0.17 STWHIP P WEXIT Tag up at SSSV several times dry. Check, that it is locked out. Kick on pumps to 0.9 bpm, catch fluid, ran through ok. 12:35 - 13:00 0.42 STWHIP P WEXIT Shallow hole test of MWD and orienter. Got 2 clicks on second orienting attempt. 13:00 - 14:45 1.75 STWHIP P WEXIT Continue RIH. Note - S riser remaining at 0 psi. Lateral valve is holding, tagged x nipple, bounced thru it w/o using pumps. 14:45 - 14:50 0.08 S TWHIP P WEXIT Up weight prior to tagging=28 klbs. Tag at 11555', correct to 11536', top of whipstock. Kick on pumps. Found TF = 0 deg. 14:50 - 15:05 0.25 STWHIP P WEXIT Orient around to 140R. RIH, Tag again at 11535' pumps on, add 1 more foot. Top of whipstock=11536', getting 30 deg reactive. PU orient to 165L. Free spin=2100 psi @ 1.7 bpm. 15:05 - 15:45 0.67 STWHIP:P WEXIT RIH, start milling at top of whipstock 11536'. Paint flag. TF173L. Mill, keeping WeB less than 2500 psi. Mill to 11538'. Pump 5 bbl bio sweep. 15:45 - 20:00 4.25 STVVHIP P WEXIT Pull up 1' to 11537', start time milling as per procedure. 20:00 - 00:00 4.00 STWHIP P WEXIT Continue time milling at 1'/hr. 11538.5' 5k wt/little diff1160L, 11540.0' 8k/50 psi/170L, 11541.0' 8.71d100 psi/170L, 11541.7'/8.6k/300 psi/177L, 11542.1'/7.8k/550/173L, 11542.2'/4.8k/0/143L. Assume exit at 11542.1' 11/10/2001 00:00 - 01:10 1.17 STWHIP P WEXIT Mill/drill formation from 11542.1' w/50 psi diff at 8-11K wt 146L to about 11546' actual, 11 547.8' stacked. Pump sweep, backream, clean 01:10-03:00 1.83 S'I'WHIP P WEXIT POOH for tapered mill. Seeflag at 11536.0' 03:00 - 03:30 0.50 STWHIP P WEXIT Change motor/mills. This was a good mill! Hard to tell that it was even used! MU 1.75 deg motor and 2.80" WF tapered mill 03:30 - 04:50 1.33 STWHIP P WEXlT RIH w/BHA #2 04:50 - 05:00 0.17 STWHIP P WEXIT Fire drill-simulated fire in mud mixing room, discuss 05:00 - 05:30 0.50 STWHIP P WEXIT Resume RIH 05:30 - 06:20 0.83 STWHIP P WEXIT Tag at 11553' CTD. PUH 27k, start pump, toggle MWD several times, get TF 1L. Orient to 173R 06:20 - 06:30 0.17 STWHIP P WEXlT Tag again w/pump on before flag (at 11536.5' this BHA). SD pump and measure. Corr to 11532.5' 06:30 - 06:40 0.17i STWHIP P WEXIT Orient around to 170R. 08:40 - 08:30 1.83 STWHIP P WEXIT Begin milling at top of window. Attempt to mill for 2 hours. Many multiple stalls with no progress at all. Trip for a cutrite only version of the crayola mill. Printed: 11/27/2001 4:14:04PM i ".. i i;ierati°nssummary RePort Legal Well Name: 15-16 Common Well Name: 15-16A Spud Date: 11/19/2001 'Event Name: REENTER+COMPLETE Start: 10/19/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ~ Date~i.~~ ~From~_To~-HOurs' Activity~e~ NPT i~Phase:~ ~ .- Description of Operations 11/10/2001 08:30- 10:15 1.75 STWHIP P WEXlT POOH with milling BHA #2 (Crayola mill). 10:15 - 10:45 0.50 STWHIP P WEXlT Tag up at surface, mechanical depth counter on depth to electrical. Stand back injector, break out Crayola mill #1, make up crayola mill #2, 2.80" cutrite crayola mill, with no MM buttons. 10:45 - 12:45 2.00 S'I-WHIP P WEXIT RIH with BHA #3. Phz 1 12:45 - 12:55 0.17 STWHIP P WEXIT Dry tag, pick up kick pumps on. Flag appears significantly off depth. Assume new coil stretch. Call tag top of whipstock. Orient to 178R, RIH tag again, make a -8' correction. Set !depth to tag at top of whipstock at 11536'. 12:55 - 17:15 4.33 STWHIP P WEXIT Begin milling at top of window at 11536'. 1.5/1.3/2020 psi. Getting 400# motor work at 11536' plus lots of stalls. Watch 3its for 1/2 hour, no loss in level. Out micro motion is off by about 0.2 bpm. Good work at top of window at 11536' down to 11538.7, Drilling break at 11538.7', easy ROP to bottom of window at 11542'. Numerous stalls at 11543'. 17:15 - 18:10 0.92 STWHIP P WEXIT Hard milling at bottom of window. Seeing a lip at 11543'. Trying to mill at bottom of window. (Possibly TD?) 18:10 - 18:40 0.50 STWHIP P WEXIT Make tie in pass down to confirm depth. Log down from 11390' at 60 fph. 18:40- 19:40 1.00 STWHIP = WEXIT No coif. RIH. Ream 11532-44' 1.7/2400/180R, clean. See flag at 11541.4'. Backream same, pump sweep Reream at 165L, clean. Backream at 140L, clean 19:40 - 20:10 0.50 STVVHIP = WEXIT Orient around 20:10 - 20:35 0.42 STWHIP P WEXlT Ream at 137R, clean. Ream at 140R, clean. Dry tag, clean. Flag still at 11541.4'. Flag at 11400' EOP 20:35 - 22:10 1.58 S'I'WHIP P WEXIT POOH for drlg assy 22:10 - 22:35 0.42 STWHIPi P WEXlT LD milling BHA. Mill was 2.78". Phz 2 22:35 - 23:20 0.75 DRILL P :PROD1 MU drilling BHA 23:20 - 00:00 0.67' DRILL P PROD1 RIH w/BHA ~4 (1.83 deg motor) 11/11/2001 00:00 - 01:40 1.67 DRILL P PROD1 Continue RIH. Phz 1. Mud swap trucks held up to convoy 01:40 - 01:55 0.25 DRILL P PROD1 Corr at flag -16.8' at 11476'. Chk TF 40R. Orient to Iow side 01:55 - 02:30 0.58 DRILL P PROD1 RIH at 144R, clean to tag at 11543.8'. Drill/ream (not much room to work) 1.7/2300/136R to 11548' 02:30 - 02:50 0.33 DRILL P PROD1 Orient to drilling TF. Back to normal driving conditions 02:50 - 03:50 1.00 DRILL P PROD1 Drilling in a shale 1.7/2300/70R. See RA tag and corr +2' 03:50 - 04:35 0.75 DRILL P PROD1 Swap to used/new FIo Pro mud. Drill to 11572' 1.6/3430/70R 04:35 - 05:05 0.50 DRILL = PROD1 Orient to high side Lost 5 deg w/Iow side exit that wasn't factored into revised plan. Need to drill high side to catch up build which will delay turn and make it wider. No problem w/geo. Alt plan would be to tdp for larger motor which would incr DLS 05:05 - 06:30 1.42 DRILL 3 PROD1 Drilling painfully slow from 11572' 1.6/3350/10R, 1.8/3800 06:30 - 08:15 1.75 DRILL = PROD1 11583', drilling build section. 1.6 in/out. 193 bbls in pits. Free ,IPROD1 spin 3100 psi at 1.5 bpm. Drilling at 3600 psi. 20 fph. 08:15 - 09:00 0.75 DRILL P i 11600', continue to drill build section slowly. ROP slow, less than 20 fph. S riser pressured up to 375 psi between wing and lateral valve. Bleed off to slop oil trailor. 09:00 - 10:45 1.75 DRILL P PROD1 11605', hard drilling, not making any ROP, difficult holding tool face, but still getting good stalls on motor. POOH to examine bit and motor. 10:45 - 11:15 0.50 DRILL P PROD1 Tag up at surface. Stand back injecter. No damage at all to Hughes bi centered bit. Suspect weak motor. Change out Printed: 11/27/2001 4:14:04 PM · }'_ ;OPeratiOns SummarY Report Legal Well Name: 'i5-16 Common Well Name: 15-16^ Spud Date: ~ ~/~/200~ Event Name: REENTER+COMPLETE Sta~: 10/19/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ?2~Dat~.--~ ~From~To~ ~um--Activin: ~G~e: :~NP~ ~Phase : ~ Description of Operations 1 11/11/2001 10:45 - 11:15 0.50 DRILL P PROD1 motor. Pick up used DPI bi ~ntemd bit. 11:15- 11:30 0.25 DRILL P PROD1 RIH with BHA~5 11:30 - 12:00 0.50 DRILL P PROD1 Fire and rig evacuation drill. 12:00 - 13:40 1.67 DRILL P PROD1 Continue to RIH with BHA ~5. 13:40 - 14:30 0.83 DRILL P PROD1 Kick pumps on 1.7 bpm, 3550 free spin, 100% returns, TF found at 130L, Tag boEom, make -15' ~rm~ion. Orient around. 14:30 - 17:30 3.00 DRILL P PROD1 11605', resume drilling. Still on a hard streak. Geeing lots of stalls, Iow ROP. 17:30 - 18:15 0.75 DRILL P PROD1 11615', Di~cult drilling. 1.6/1.6, 3500 psi. Ve~ ve~ Iow ROP. Seeing some pyrite in cu~ings, liEle che~. Geo says fo~ation should be drilling easily, and pyrite should not be an issue??? Continue to pound away. Got to be something wrong. 18:15- 19:25 1.17 DRILL P PROD1 1.3/2950, 1.4/3050, 1.513300, 1.6/3500~0R Drill to 11621' 19:25 - 20:05 0.67 DRILL P PROD1 Orient around 20:05 - 20:55 0.83 DRILL P PROD1 Drill miserably slow to 11627.7' and had numerous stalls and not geeing good su~eys 20:55 - 22:35 1.67 DRILL P PROD1 Wiper to window. POOH for bit 22:35 - 00:00 1.42 DRILL ~P PROD1 Bit okay, PT BHA okay. Change bit, open MWD restrictor, orientor 1111~2001 00:00 - 02:15 2.25 DRILL P PROD1 RIH w/BHA ~ Hughes Bi ~nter bit. 02:15 - 02:25 0.17 DRILL P PROD1 Co~ -15' at 11515'. Stad pump, chk TF ~ 71L 02:25 - 03:00 0.58 DRILL 3 PROD1 RIH thru window at 71L, clean. Pre~utiona~ mare to TD. Tag TD at 11627.7' Drill a foot at 40'/hr w/3K e~ra string 1.6/3350/143R. PUH to orient and plugged something in BHA. T~ to unplug-nope 03:00 - ~:40 1.67 DRILL N DFAL PROD1 POOH to chk B~. See flag at 11550' this BHA ~:40 - 05:30 0.83 DRILL N DFAL PROD1 Motor was hard to turn by hand. Send in for inspe~ion. Adjust prior motor to 2.12 deg bend ~05:30 - 07:55 2.42 DRILL N DFAL PROD1 RIH w/B~ ~7. SliT 1.6/2600. Make -15' corrosion at 11500', based on depth ~rm~ion made on last run. Continue RIH, made it thru window with not a bobble. Tag bosom, make an additional ~' depth ~rmction. 07:55 - 08:20 0.42 DRILL N DFAL PROD1 Orientto 90R 08:20 - 08:30 0.17 DRILL P PROD1 11628', Resume drilling, Free spin 3200 psi, 1.5 in/out. (Out MM still reading 0.2 bpm light, pits say no losses), Drilling with new 25 kls~ mud. Making 60 fph. TF 90L by mistake (MWD not sync'd right), drilled great for 8'. 08:30 - 08:40 0.17 DRILL P PROD1 11635', Need to orient to 90R, PU, orient around. 08:40 - 09:20 0.67 DRILL ,P PROD1 Resume drilling, 80 ~h, TF 95R. 1.6/1.6 3500 psi drilling, 300 3si motor 09:20 - 09:35 0.25 DRILL P PROD1 11690', odent around to 30R. 09:35 - 10:00 0.42 DRILL P PROD1 Resume drilling. 10:00 - 12:00 2.00 DRILL P PROD1 11706', As soon as ROP took off, dog legs dropped to 10 deg/100'. ~n not land well with currant motor. POOH. Discuss with DD and Geo best plan fo~ard. Motor was drilling fine as of sta~ of trip. Tripping for bigger bend motor and PDC bit. 12:00 - 12:45 0.75 DRILL 3 PROD1 Adjust motor to 2.6 deg, pickup DPI PDC bit. (Non bi~ntered). 12:45 - 15:00 2.25 DRILL 3 PROD1 RIH with BHA 15:00 - 15:25 0.42 DRILL P PROD1 Tag TD for tie in. Make -22' depth ~rre~ion. Set depth to 11706', orient to 0 deg. 15:25 - 15:30 0.08 DRILL P PROD1 11706', resume drilling. 3200 psi free spin, 1.5 in/out, TF 60R, Printed: 11/27/2001 4:14:04PM '~1 STATE OF ALASKA '''----' ALASK'--' '')IL AND GAS CONSERVATION COM'v''SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 854' SNL, 165' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 3521' NSL, 3696' EWL, SEC. 15, T11N, R14E, UM At effective depth 4160' NSL, 4173' EWL, SEC. 15, T11N, R14E, UM At total depth 4208' NSL, 4209' EWL, SEC. 15, T11N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 71' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15-16 9. Permit Number 184-074 10. APl Number 50-029-21115-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Casing Present well condition summary Total depth: measured 11891 feet true vertical 8850 feet Effective depth: measured 11826 feet true vertical 8824 feet Length Size Structural Conductor 80' 20" Surface 2495' 13-3/8" Intermediate Production 10850' 9-5/8" Liner 1352' 7" Plugs (measured) Junk (measured) Fish: See Diagram (10/95 & 01/98) Cemented 1910# Poleset 1900 sx PF 'E', 400 sx PF 'C' 500 sx Class 'G', 300 sx PF 'C' 380 sx Class 'G' MD 80' 2495' 10850' 10496' - 11848' TVD 80' 2495' 8325' 8094' - 8833' Perforation depth: measured 11691' - 11695', 11740' - 11784' Sqzd: 11675'- 11695', 11714'- 11740' true vertical 8770' - 8772', 8790' - 8808' Sqzd: 8764'- 8772', 8779'- 8790' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 11712' Alaska Oil & Gas Cons, Anchoraqe Packers and SSSV (type and measured depth) Baker 'FB-I' Permanent packer at 11699'; Baker model 'D' permanent packer at 10243'; 3-1/2" Camco 'TRDP-1A' SSSV Nipple at 2235' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation September 29, 2001 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Mary Endacott, 564-4388 [] 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 :'-~"~ .i' /,~.~,/~)/~-,./,r~,~/L T tle CT Dr ngEngineer Date M.S. Endacou/// '/_~ ~ ~ ~ ~' ~.'~"~'~ v ~ Conditions of Approval: Noti~ Commission so represen.tive ma~ fitne~ ~%O~ ~. ~.$ ~ ~ Approval No. Plug integd~ BOP Test~ Lo~tion cleaBnce I Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev. 06/15/88 Subsequent form required 10- Original S~ned By C.mmv OudjulL nDl lklAi Commissioner Date //~.~// Submit Ir'(TrilClicate September 24, 2001 To: Attention: Subject: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Tom Maunder Petroleum Engineer Well 15-16 CTD Sidetrack Prep bp BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well 15-16 is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prep 15-16 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. ]. Tree wing & master valves will be tested. 2. Using slickline, the tubing will be drifted and calipered. 3. Inner Annulus will be liquid packed and pressure tested. 4. Install permanent plug in XN to abandon frac'd perfs 11,714'-11,784'. 5. Pull DGLV in straddle. Perform injectivity test into straddle. 6. Service coil will punch holes in the 3Y2" straddle assembly at 11,400' and abandon perforations behind it (11,691'-95' MD) below a cement retainer with 30bbls 17 ppg cement. Planned top of cement approx. 10,400' behind the 3~". ?. Pressure test cement and tag/drift TOO. 8. Install whipstock at 11,520'. Slickline, wireline & service coil prep work is expected to commence September 29, 2001. Coil tubing drilling operations, as detailed below will commence October 7, 2001. ]. A 3" sidetrack, -2400' long will be drilled out of the 3Y2" tubing and 7" liner, high side into the Zone 1 reservoir. 2. The sidetrack will be completed with a 2-3/8", solid, cemented & perforated liner. _., :/i..¢ / ~_ ........ M.S. Endacott CT Drilling Engineer Tel' 564-4388 Fax' 564-5510 endacoms@bp.com Well File Petrotechnical Data Center Terrie Hubble WELLHEAD = FMC ACTUATOR = AXELSON OLD KB. ELEV = 71 BF. REV = KOP= 3000' Max Angte = 66@ 11891 Datum IVD = 11919' Datum TV D = 8800' SS 4-1/2" 12.6~ x 3-1/2" 9.3# TBG XO, ID = 2.99Z' H I 13-3/8 " CSG, 72~, L-80, ID = 12_347" H 69' 2495' 15-16 SAFETY NOTES: AVA 3.5" ECLIPSE PATCH ACROSS GLM ~ 3 @ 10443' (11/17/95), ID = 1.75" 3-1/2" CAMCO TRDP-1A SSSV NIP (SHGLE CONTROL UNE}, ID = 2.812" ~SLI~N~S M~-7 M~-7 M~-7 M~-7 M~-7 IMinimum ID = 1.75" @ 10442' I AVA ECLPSE PATCH I I BKRSEALBOREEXT, ID=4.750" H 10247' I 4-1/2"BKRGBH-22SEALASSY, ID=3.875" H 10259' I TOPOF 7" LI~, H 10492' I 9-5/8" CSG, 47#, L-80, ID = 8.681" 10850' PERFORATION SUMMARY REF LOG: BHCS ON 06/24/84 ANGLE AT TOP PERF: 66 @ 11675' No{e: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-1/8" 0 11675-11695 S 11108/90 4-1/2" 2 11691-11695 O 11/14/90 4" 0 11714-11777 S 11/08/90 3-3/8" 4 11740-11784 O 11/14/90 3-11Z' 'rBG, 9.3~, L-80, .0087 bpf, ID= 2.992" 11709' I mTDH 7" LNR, 29#, L-80, 0.0371 bpf, ID= 6.184" H I-I 11826' 11848' 11891' 10168' H Cf'EMMAND'MMG'LTS'RK'DEV=49 I 10243' H9-5/8"X4-1/2'' BAKERMODELD | PERM P~<~, ID: 4.750" I 10280' 10442' H3-1/2" OTIS X NIP, ID = 2.813" HAVA3.5" ECLPS PATCH, 09/30/98, ID= 1.75" I 11698' H 3-1/Z' BKP, GBH-22 SEAL ASSY, ID = 3.00" I 11699' ~-~ 7"X3-1/Z'BAKERFB-1PERMPKRID=4.000" 11710' ~--~ 3-1/2"OTISXNI~IP, D=2-750"I 11712' H 3-1/2" BAKER WLEG, ID= 2.867" 11750' 11760' (2) RUBBER REIVENTS 2" X 2.74"; 2 SLIP KEYS 1"X5/8'3(3/8" F/AVA ECUPSE- 01/07/98 (4) SLIP B_EIVENTS & 1 RUBBER ELEMI~IT - 10/17/95 DATE REV BY COIVlVIENTS DATE REV BY COIVIVIENTS PRUDHOEBAY UNIT 06/30/84 OI~GINAL COMPLETION 08/25/01 PE/CH CORRECTIONS WELl_: 15-16 11/18/90 LAST WORKOVER PERIVIT No: 84-074 12/11100 SIS-Isl . CONVERTED TO CANVAS ARNo: 50-929-21115-00 01/19/01 SIS-IVD FINAL Sec. 22T11N R14E, 1069.52 FELl068.55 FN_ 06/27/01 I~I/'rP CORRECTIONS BP Exploration (Alaska) TREE = FMC GlEN 3 WELLHEAD = FMC ACTUATOR = AXELSON OLD KB. ELEV = 71' KOP = 3000' '~'T~'i~i~'"; ...................... ~"~'"~"~8'~'~''~' Datum MD = 11919' Datum 'IYD = 8800' SS 4-1/2" 12.6# X 3-1/2" 9.34¢ TBG XO, ID = 2.992" H 69' I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2495' 15-16A PROPOSED CTD SIDETRACK 10247' 10259' 2235' 10168' 10243' 10280' 3-1/2" CAIVICO TRDP-1A SSSV NIP (SINGLE CONTROL LINE), ID = 2.812" GAS LIFT MANDRELS TYP~MANI VLV I~TCHI MUC-,-2-7 11-1/2"1 ~ I M~2-7 11-1/2"1 ~ I MMC,-2-7 11-1/2"1 ~ I M~2-7 11-1/2"1 ~ I MUC,-~-~ I~-~Z'I ~< I M~2-7 11-1/2"1 ~< I MUG-2-7 11-1/2"1 ~ I MUC,-2-7 11-1/2"1 ~< I MUC,-~-~ I~-~"1 ~< I MUG-LTS 11-1/2"I ~< I MMV-2-7 11-1/2"1 RK I MMV-2-7 11-1/2"1 RK I PKR, ID = 4.750" Id 3-112" OTIS X NIP, ID= 2.813" of Proposed 2-3/8" L-80 Liner Top Note: Retrieved 3-1/2" Eclipse Patch from 10442' MD in August of 2001 I TOP OF 7" LNR H 10492' 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 10850' Punch Hole in Straddle PERFORATION SUMMARY REF LOG: BHCS ON 06/24/84 ANGLE AT TOP PERF: 66 @ 11675' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 0 11675-11695 S 11/08/90 4-1/2" 2 11691-11695 O 11/14/90 4" 0 11714-11777 S 11/08/90 3-3/8" 4 11740-11784 O 11/14/90 I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID: 2.992" Id 11709' 7" LNR, 29#, L-80, 0.0371 bpf, ID: 6.184" id 11826' 11848' 11---~; Mill Window off Mechanical Whipstock I 3" Hole ] I .... ~:..-. :,~, ~:~;~.~:,~ ~ ~:~:...; ¢:'h ~:~'~ :':~':~.;-.,:;-~'~-~.~; .~ ~[~..' '. ':..:; ~ · - ' ~ ~ : ' I ~-~'~" ~-~0 Liner, Cemented & Perforated I-I 11698' H3-1/2- BKR GBH-22 SEAL ASSY, ID: 3.00" 11699' Id 7" X 3-1/2" BAKER FB-1 PERMPKR, ID:4.000" I ~7~0' I-I ~7~2' H 3-1/2" OTIS XN NIP, ID = 2.750" 3-1/2" BAKER WLEG, ID = 2.867" 11750' I~ (2) RUBBER ELEMENTS 2" X 2.74"; 2 SLIP / KEYS 1"X5/8"X3/8" F/AVA ECLIPSE- 01/07/98 11760' I~ (4) SLIP ELEMENTS & 1 RUBBER / ELEMENT - 10/17/95 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06130/84 ORIGINAL COMPLETION 08/25/01 F'E/CH CORRECTIONS WELL: 15-16A Proposed ST 11/18/90 LAST WORKOVER 08/30/01 pcr 15-16A ST proposal PERMIT No: 184-074 12/11100 SlS-Isl CONVERTED TO CANVAS ARNo: 50-029-21115-01 01/19/01 SIS-MD FINAL Sec. 22 T11N R14F__,1069.52 FEL 1068.55 FNL 06/27/01 RN/TP CORRECTIONS BP Exploration (Alaska) Subject: 15-16 squeeze revision Date: Tue, 2 Oct 2001 12:35:47 -0500 From: "Endacott, Mary $" <EndacoMS@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Tom Thanks for the question. We've made a change in the plan since we submitted the sundry. Now plan to punch the tubing 11658-64' then set a retainer at 11560' and conduct a suicide squeeze lifting cement to a target depth of 10,500 behind the 3 1/2" tubing. We'll be taking returns through the production mandrels # 12 and #13. Here's an updated drawing .... <<15-16revised.ZIP>> Mary S. Endacott Coil Tubing Drig Engr 907-564-4388 737c endacoms@bp.com i Name: 15--16revised.ZIP 1 ~;~15-16revised. ZIP Type: Zip Compressed (application/x-zip-compressed) Data Encoding: ba ~se64 1 of 1 10/2/01 11:18AM WI~L~D= FMC ACTUATOR-- kX]tS(~ OLD KB_ ELEV -- 71' BF. ELEV = KOP = 3000' Max A~ = 65 @ 11891' 15-16A PROPOSED CTD SIDETRACK I l ~nirrmm ID= 2.75' Ofis~ Nipple ! Bt<R~BOREEkq'.I:)=4.750' H ! ~-1~' ~ sa-i-= SF_AL Ass','. o = 3.~75" H 1025~ 3-112' CAMOO TR[~-IA SSSV MP(~= 2.8I$'J I 4384 4235 42 IvMD 13~ RI( 0 5/21/95 59~ 5230 50 bl~ ~ RK 0 7164 5989 51 MdG ~ Ri( 0 806~ 6534 53 M~ 13~ F;S<. 0 ~ ~ 52 ~ ~ ~ 0 ~ 7~ ~ ~ ~ ~ 0 ~ ~ ~ ~ ~ ~ 0 PERM PKR. D = 4.750' i~_QT_ ~ HYD !-~ WI TB 104~i' 9-.5~B' CSG. 47#. L-8~I. ID = 8_6;81 ~ LOG: BHCS ON (~24t84 ANGLE[AT TO~P PIS~F- ~ ~ 11675' I',lete; Refe~ to RrodudJoo ~ tot histmical pe~ da~a SIZE SPF [NTERVAL Op~ESqz 3-1/6"" 0 11675-11695 S 1 4-1/2= 2 11691-11695 O 11114/90 4- o t ~7~441777 s l~,me~rgo 3-3/¢ 4i 11740-11784 O 11f14/90 ,, -/' X 3-1/2' BAKER FI~I FERMFKR. E~=4.(X)0' H 11~"~'~"~"" 3-112~ TIDG. g_3#. L-80. 0.0087 bpi=. ~ = 2_99?' Bake~ WI._EE~ H1171~ I H 11828' H '"'"' I. H 10353 AND 10443 I'-i oP~ MANE~ELS, NO I:::~JMMY 10500' H PROPOSEDTOPP~CIVfF Top of Proposed 2-3~8" L-80 Liner /.,,,.~ 11520' ~11 Window off r~chanical Whipstock f 2-3/8" L-80 Liner, Cemented & Perforated H 1400{)' I I 11560' HWeatherford Cement Retainer !1 s'H"~l 11658-64 H~.ch Hole in Staddle J 117S0' 11760" DAlE REVV BY OOMa~ffS DATE REV BY ~S 06~38,-'84 ' ORIC-i~L~EIION 08,/251'01 ~ ~ 11118/90 LAST W01:~OV~R i0~r28/01 M~E 15-16A STl~oposal 12~11/00 SIS-bi O0~TOCANVA$ !01/I~1 SIS-MD FINAL t:~ar37i01 ~ CX~~ FRUCHOE BAY ~ VV~J_: 15-16A R'oposed ST PERI~T No: ARNo: 5.0-029-21115-01 Se(. :22 T11N R14E. 1069.52 F'EL 1068.55 FI,,L B!) r::~plorsUon IAI--kill STATE OF ALASKA A-L~$KA OIL AND GAS CONSERVATION COMMISSIb,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 71' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 854' FNL, 165' FVVL, Sec 22, T11N, R14E, UM. 15-16 At top of productive interval: 9. Permit number/approval number: 1706' FNL, 1658' FEL, Sec 15, T11N.. R14E, UM. 84-74 At effective depth: 10. APl number: 50-029-21115 At total deplh: 11. Field/Pool: 1020' FNL, 1147' FEL, Sec 15, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11891 feet Plugs (measured) true vertical 8845 feet Effective Depth: measured 11826 feet Junk (measured) true vertical 8819 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1910 Sx Poleset 80' 80' Surface 2424' 13-3/8" 1900 Sx Perm E & 2495' 2495' 400 Sx PFC Production 10779' 9-5/8" 500 Sx Class G & 10850' 8320' 300 Sx Class G Liner 1352' 7" 380 Sx Class G 11848' 8828' Perforation Depth measured 11692 - 11696'; 11740 - 11784' true vertical 8766- 8768'; 8785- 8802' " Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, PCT @ 11707' MD. ~. ,",:{ ?' . ~.. Alaska, ... Packers and SSSV (type and measured depth) Baker FB-1 Perm Packer @ 10699' MD; Baker Model 'D' Perm Packer @ 10243 ~'~ -("~'? 3-1/2" Camco TRDP-1A SSSV @ 2235' MD. Chora.qe 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached0F IGINAL Intervals treated (measured) 14. ReDresentitive Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 897 19508 0 848 Subsequent to operation 875 14282 0 1043 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"'~ "~, ~ Title: Engineering Supervisor Date ,..~'"/Z - -- Form 10-404 Rev 06/15/88 SUBMIT iN DUPLICATE 15-16 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED 11/7/97: Made tag run that indicated AVA Eclipse Tubing Patch that was set at 10440 - 10460' MD (on 11/17/95), had fallen down hole to 10531' MD. 1/7/98: RIH & latched fallen Tubing Patch. POOH w/Patch minus rubber elements & slips. 9/30/98: RIH & set an AVA Eclipse Tubing Patch from 10442' to 10462' MD (seal to seal), in the 3-1/2" tubing, over GLM #13 located at 10443' MD. POOH. RD. Returned the well to production & obtained a valid welltest. !ii'i. Anchorage, AK 99518-1199 "i A'FI'N: Sherrie GeoQuest 500 W. International Airport Road Well Job # NO. 10223 Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 99501 6/4/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Log Description Date BL RF Sepia . Survey Program Performance Calculation Letter .OWDW-SE ~;~' TEMPERATI '0~Dw-NW .PUMP-IN ~= 0WDw-sv~ v2--' PUMP-IN T-'~ .--~,--' , D.S. 7-03A .... ... PFIODUCTI£ D..S. 7-03A C/" -- DUAL BUR--~ D.S. 11-26 '...,-7' PERFORATi !D.s' 14.03 17 P~RFOR~.T-~ D;S: 14-1~; ..;.~,~ i.i~LATA~], 'D.s. 15-14 {,' THBING PA' D,S, 15-15 ..... "' PERFORAll .............. D.s,, 15-16 , .~' TUBING PA' :~, .... ~ ...... D.S, 15-39 ~.'~ , TDT-P BOR D~: i6-5 b/ / PERFoRA-~ D.S. 16.10' ~ "' PERFORA~ ~ ,, D,s, 18-34 / TDT-P BOR ...... ......... ..... ~E OVERLAY 9 6 04 2 9 I 1 IPERATURE SURVEY 9 6 04 3 0 I 1 IPERATURE SURVEY 9 6 04 3 0 I 1 ,~ PROFILE LOG 9 6 0 5 0 3 I 1 ~ TDT-P 960504 I I · i(; RECORD 960425 1 1 ~--DEPTH CONTROL'- 9 51 1 0 8 I 1 BRIDGE PLUG 9 51 1 0 8 I 1 ~1'! RECORD 9 51 1 2 0 I 1 I(i~ RECORD 9 51 1 2 3 I 1 CFI RECORD 9 51 1 1 7 I 1 .X LOG 960429 I 1 ........... )N RECORD 951111 '1 1 )N RECORD 95111 2 , I 1 ,X LOG 960428 I I :iliSIGNED: PleaSe sign and return one copy of this transmittal to Sher'rie at the above address. Thank you. D ATF: STATE OF ALASKA .-_ ~'///~/,.., ALASKA ¢"-'"~AND GAS CONSERVATION CO -IlSSION ' ~ //-:'/~ REPORT Or: SUNDRY WELL OPE ATIONS '// / 1. Operations performed: operation shutdown Stimulate Plugging Perforate ' / Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 71' RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 854' FNL, 165' FWL, Sec 22, T11N, R14E, UM. 15-16 At top of productive interval 9. Permit number/approval number 1706' FNL, 1658' FEL, Sec 15, T11N, R14E, UM. 84-74 At effective depth 10. APl number 50 - 029-21115 At total depth 11. Field/Pool 1020' FNL, 1147' FEL, Sec 15, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11891 feet Plugs(measured) true vertical 8845 feet Effective depth: measured 11826 feet true vertical 8819 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1910 Sx Poleset 80' 80' Surface 2424' 13-3/8" 1900 Sx Perm E & 400 Sx PFC 2495' 2495' Production 10779' 9-5/8" 500 Sx CIG & 300 Sx CI C 10850' 8320' Liner 1352' 7" 380 Sx CIG 11848' 8828' Perforation depth: measured 11692 - 11696'; 11740 - 11784' JAN true vertical 8766 - 8768'; 8785 - 8802' Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, PCT @ 11707' MD. Anchorage Packers and SSSV (type and measured depth) Baker FB-1 Perm Packer @ 11699' MD; Baker Model 'D' Perm Packer @ 10243' MD; Camco 3-1/2" TRDP-1A SSSV @ 2235' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure :1'4. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1121 15984 0 -- 788 Subsequent to operation 1066 13827 71 -- 950 15. Attachments 16, Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil~ Gas __ Suspended __ Service 17.1. ~hereby c, ertify that the foregoi_ng is ~~ correct to the best of my knowledge. //?-, /~ Signe~d../'" ~'-~ ~-'')' Title Engineering Supervisor Date//' ,~( ,, Form~ ~; 4 Rev 06/15/88 SUBMIT IN DUPLICATE~ ~ 15-16 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED I I/1 7/95 · RIH & set an AVA Eclipse Tubing Patch (1.81" ID) from 10440' to 10460' MD (seal to seal), in the 3-1/2" tubing, over GLM #13 located in straddle at 10443' MD. POOH. Rigged down. Returned the well to production & obtained a valid welltest. STATE OF ALASKA -- ALASKA ~-".AND GAS CONSERVATION CC~ /IISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging ~ Perforate Pull tubing Alter casing ~ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 854' FNL, 165' FWL, Sec. 22, T11N, R14E, UM At top of productive interval 1706' FNL, 1658' FEL, Sec. 15, T11N, R14E, UM At effective depth At total depth 1020' FNL, 1147' FEL, Sec. 15, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 15-16 9. Permit number/approval number 84-74 10. APl number 50 - 029-21115 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11891 feet true vertical 8845 feet Effective depth: measured 11826 feet true vertical 8819 feet Casing Length Size Conductor 80' 20" Sudace 2424' 13-3/8" Production 10779' 9-5/8" Liner 1352' 7" Plugs(measured) Junk(measured) Cemented Measured depth True vertical depth 1910 sx Poleset 80' 80' 1900 sx Perm 'E'& 2495' 2495' 400 sx PF 'C' 500 sx Cl 'G' & 300 sx Cl 'C' 10850' 8320' 380 sx Cl 'G' 11848' 8828' Perforation depth: measured 11692-11696'; 11740-11784' RECEIVED true vertical 8766-8768'; 8785-8802' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, POT @ 11707' MD Pa~ers and SSSV (~pe and measur~ depth) B~er M~el F~I pe~. ~cker ~ 116~' MD; ~ker M~el D ~. packer ~ 10243'; C~ 3-1/2' TRDP-1A ~SV ~ 22~' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or Injection Data _ OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 -- 1239 ~ 7970 v~- 7 -- Tubing Pressure 0 789 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: OilX Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE DS 15-16 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE lB I 2/3/9O' MIRU & PT equipment to 7000 psi. perforations at: 11692 - 11696' MD (ZIB) 11740 - 11784' MD (Z1B) Pumped Breakdown: Surged Pumped a Propped Fracture Treatment through Ref. Log: BHCS 6/24/84. a) 350 bbls 20# Gel, w/400 ball sealers, @ 11 bpm, followed by b) 110 bbls 20# Gelled Flush, @ 13 bpm, followed by c) Shutdown. well to unseat balls, then resumed pumping: d) 110 bbls Seawater, @ 12 bpm, followed by e) Shutdown. ISIP @ 2265. Resumed pumping: f) 100 bbls 40# Gel, @ 18 bpm, followed by g) Shutdown. ISIP @ 2405. Surged well & resumed pumping: h) 425 bbls 40# Crosslinked Pad, @ 20 - 25 bpm, followed by i) 358 bbls Slurry w/proppant concentrations of 1 to 2 ppg, followed by j) Shutdown (due to screenout @ 2 ppg). Placed a total of 10,200 lbs of proppant into the formation. Rigged down. 12/5/90' Performed a proppant fill cleanout to 11754' MD. Flowed well. Returned well to production & obtained a valid production test. ARCO Alaska, Inc. Date: Feb 25, 1994 P.O. Box 100360, i orage, AK Transmittal #: 94024 99510,~ ~1~, Subject: ARCO Static Pressure Surveys From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Number, (M-D-Y) Scale , 2-3 I 6-5-93 Static Press Surv. l 1, 5" Sch 2-5 ! 7-21-93 Static Press Sun/.~ " Sch 3-8 i 11-22-93 Static Press Sun/. I " Sch 3-19 f 1-3-94 Static Press Sun/. i " Sch 3-34A i 11'22'93 I Static Press Surv' i " Sch 3-35 i 12-7-93 Static Press Sun/. I " Sch 3-36 ~ 7-24-93 Static Press Sun/. i " Sch 17.cco 4-12 i 11-17-93 StaticPressSurv.~ " Sch i 4-31 ! 1-3-94 I Static Press Sun/.- i " Sch c[ ~C'~-°t OC0'Lt 4-32 i 9-8-93 I Static Press Sun/. i " Sch 4-41 i 11-21-93 t Static Press Sun/. i " Sch ctt~C-.O-cl. +¢r-,~* l 5-12 ! 7-21-93 i static Press sun/.I"Sch 6-19 , ~ i, 11-28-93 Static Press Sun/. " 7-7A i 7-21-93 Static Press Sun/. I " Sch t 7-8 9-2-93 Static Press Sun/. t " Sch 9-49 f 9-14-93 Static Press Sun/. ! " Sch 11- ii 9-5-93 Static PressSun/. l " Sch 11-17 i 11-26-93 Static Press Sun/. t Sch 12-16A i 11-8-93 Static Press Sun/.¢ Sch 13-14 I 7-2-93 Static Press Sun/. t " Sch 14-01 ~ 11-25-93 StaticPre~Suw. ~ " Sch 14-6 ~ 11-25-93 Static Press Suw. " Sch 14-18 t 11-26-93 Static Pre~ Suw. " Sch 14-38 12-4-93 Static Pre~Suw. " Sch 14-39 12-4-93 Static Pre~ Suw. " Sch 15-6 5-28-92 Static Pre~ Suw. " Sch ~ ~ ~~O 15-15 I 7-5-93 Static Press Suw. " Sch t ~%0 -[~0 15-16 I 8-26-93 Static Press Suw. I " Sch 15-18 ~ 10-26-93 StaticPre~Suw. i " Sch 15-23 ! 9-23-93 Static Pre~ Suw. i " Sch ~-~~ 16-12 f 7-21-93 Static Pre~Su~. i " Sch 16-17 ~ 12-29-93 Static Pre~ Su~. f " Sch i 16-1e ~ 7-18-93 StaticPre~Suw.~ " Sch 16-22 ~ 7-18-93 Static Press Suw. ~ " Sch 17-1 ! 11-23-93 Static Press Su~. i " Sch ~ 17-13 ~ 8-27-93 lStaticPressSu~.~ " Sch 18-29A ~ 5-19-93 Static Pre~Suw. i " Sch ARCO Alaska. Inc. Is a Subsidiary of AtlanllcR]chfleldComp~ny STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Alter casing Repair well Stimulate Plugging __ Perforate Pull tubing X Other X Workover 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 4. Location of well at surface 854' FNL, 165' FWL, Sec. 22, T11N, R14E, UM At top of productive interval 1706' FNL, 1658' FEL, Sec. 15, T11N, R14E, UM At effective depth 1068' FNL, 1182' FEL, Sec. 15, T11N, R14E, UM At total depth 1020' FNL, 1147' FEL, Sec. 15, T11N, R14E, UM 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-16 feet 9. Permit number/approval number ~4-74/ N/A ((~onsv. Order #258) 10. APl number 50-029-2111 5 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 1 1891' feet Plugs (measured) None 8845' feet Effective depth: measured 1 1 826' feet Junk (measured) None true vertical 881 9' feet 13. Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 2 0" 1910# Poleset 1 1 0' 1 1 0' Surface 2467' 1 3-3/8" 1900 sx PF 'E' & 2495' 2495' 400 sx PF 'C' Intermediate 1 0824' 9-5/8" 500 sx Class G & 1 0850' 8320' 300 sx PF 'C' Liner 1 352' 7" 380 sx Class G 1 0496'-11 848' 8089'-8828' Perforation depth: measured 11692'-11696', 11740'-11 784' true vertical 8766'-8767', 8785'-8803' RE( EIVED Tubing (size, grade, and measured depth) DEC 1 ;5 1990 3-1/2", L-80, tbg w/ tail @ 11712' Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. C0mm'tss[C Camco 'TRDP-1A' sssv @ 2235', Baker 'D' pkr @ 10243' & 'FB-I' pkr @ 11699' ~nnhnr~ge Stimulation or cement squeeze summary Intervals treated (measured) All Perforationa f/ 11675'-1-1784' Treatment description including volumes used and final pressure 150 sx Class G 14. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *Workover Well History Copies of Logs and Surveys run __ Daily Report of Well Operations X* 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4(~¢t Rev 05/17/89 Title Drillin~ Analyst Date SUBMIT IN DUPLICATE .Well'Hi~tory Initial Rep, od - D~ily Auth. or W.O. ho.AS 1 "~5 r'"' .o~o~R ~i: 50_029_21115 O~or ~.CO IARCO w'l' 21. 7800 I $~d~d: Or W.O.~. . . Da. [0/22/90 .our 0100 H Da. ~ ~-' ~mple~ record aa of ~ ;~m. 1.0/22~9~::~( 1) FINISH TBG/ANNULUS T~ST. ?"@11848' Y~: 0.0 Seawater TO: 0 RIG MOVE F/ DS 15-6 TO DS 15-16. RIG ACCEPTED e 01:00 HaS, PS:lie2'6 10/22/90. R/U LINES TO F:[,OW~IN~ & ~S. :SS:. R/U LUB. . S~v:~ P~L BPV. R/D L~. ~.P~SS- 800 PSI, TBG-1800 PSI. - : :~ BLEED ~S THOUGH CHO~. P~ D~ ~LUS & TBG. DAILY:S63,125 ~:$63,125 E~:$0 EFC:$1,142~37 10/23/90 ( 2) TESTING BOPE. 7"~11848' ~: 0 BLEED ~LUS. MIX 50 BBLS HEC. BULLH~ 50 BBLS HEC DN PB:11826 TBG. MIX 150 BBLS ~LUS. BULLH~ 150 BBLS HEC DN SUPV:~ ~LUS. F~EZE PROTECT F~WLI~ W/ 100 BBLS DIESEL. R/U AT~S WI~LINE. RIH W/ CH~ ~TTER & CCLS. 10314' CUT A~IN ~ 10314'. P~ED 150 BBLS HEC PILL C~SED W/ 450 BBLS S~WATER. BLED OFF P~SSU~. BULLHE~ 50 BBLS DN TBG TO P~CE BELOW CUT & PE~S. MONITOR WELLi N/D T~E. N/U BOPE. ATT~T TO TEST. KILL LINE HOSE BAD. C/O. TEST BOPE. DAILY:S31,056 ~:$94,181 ETD:SO EFC:$1,173,093 10/24/90 ( 3) P~P~ TO PULL DP. 7"~11848' ~: 8.6 Seawater TD: 0 CONT TEST BOP'S. BO~S. PULL HGR F~E. L/D HGR. CIRC ON PB:11826 ~. .TBG W/ 8.6 PPG S~WATER. CIRC OUT ~S & ~K FLUID. TOOK 9 . SHUT ~LL IN. CONT CIRC THROUGH CHOKE. WELL - ' 10/25/ ~~;W~.FISH. 7"611848' ~: 8.6 Seawater PB:llS~-6~?~~~3~.. DP. P/U ~L~Y & TAG FISH ~ 10332'. ROTATE OVER S~V:~O FISH. P/U ON FISH. ~TATE O~ K-~CHOR. CBU. P~H W/ B~ 91 & 3~1/2" DP. DAILY:S43,412 C~:$167,593 E~:$0 EFC:$1,246,505 10/26/90 ( 5) P~H. 7"~11848' ~: 8.6 Seawater TD: 0 P~H. L/D B~ 91 & ~T OFF SECTION 4-1/2" TBG. M/U B~ ~2. PB:11826~ RIH W/ 3-1/2" DP. TAG P~ ~ 10441' MILL ON PKR F/ SUPV:RWO 10441'-10444'. CBU. P~ 50 BBLS HEC PILL. P~H W/ B~ ~2 & FISH SLowLY. DAILY:S28,634 ~:$196,227 E~:$0 EFC:$1,275,139 10/27/90 ( 6) RIH W/ B~ 94. 7"~11848' ~: 8.6 Seawater TD: 0 POOH. LfD B~ %2 & FISH. M/U B~ 93. RIH W/ 3-1/2" DP. ~ PB:11826 TAG FILL ~'11383'. WASH F/ 11383'-11720'. P~ 50 BBLS NEC S~V:~ S~EP. WASH F/ 1172~'-11731'. CIRC. ROTATE - NO FOOTAGE. CIRC 100 BBLS HEC S~EP. P~H W/ B~ 93. C/O VARIABLE ~S ~ TO 3-1/2" ~S. TEST. OK. M/U B~ 94. RIH W/ 3-1/2" DP. DAILY:S34,894 ~:$231,121 ETD:SO EFC:$1,310,033 · i FOr form:preg&r~la~_-~l~ dl~on, r~ Odlllng; P~--. and~ ,,. ''ECE Det . AR3B-459-1-D DE0 ] 1990 A_ laska.Oii_a 6as Cons. Corr mission ;a, nchorage I Number ail daily well hi.or/forme consecutively U toy am prepared for each well. no. 'ARCO 011 .... Gas Company Daily Well History--Interim Iflstllictlena: This form s used during drillln~ or workovar ol~rations. If testing, coring, or perforating, show formation name in dsscribin,~ work performed. Number all drill stem taste seql~lltially. Attach description of all cores. Work performed by Producing Sect on will be reported on "lnlerlm' sheets until final completion. Report official or rel~'e.~entett~ tset on °'Final" fo~. 1) Submit "lnlerim" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil stHI'~ ia set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. SLOPE ICounty or Parish NORTH ITM AK no. DS 15-16 PRUDHOE BAY Oats and depth as of 8:00 a.m. 10/28/90 ( TD: 0 PB:11826 SUPV:RWO 10/29/90 ( TD: 0 PB:11826 SUPV:RWO 10/30/90 ( TD: 0 PB:11826 SUPV:RWO 10/31/90 ( TD: 0 PB:11826 SUPV:RWO 11/01/90 ( TD: 0 PB:11826 SUPV:JER 11/02/90 ( TD: 0 PB:11826 SUPV:JER 11/03/90 ( TD: 0 PB:11826 SUPV:JER Complete record for each day while drilling or workover in progress AUDI 4 7) 8) 10) [1) 12) 13) POOH. 7"@11848' MW: 8.6 Seawater RIH W/ BHA #4 & 3-1/2" DP. TAG. WASH & ROTATE OVER FISH F/ 11731'-11733'. POOH W/ BHA #4. M/U BHA #5. RIH W/ 3-1/2" DP. TAG @ 11732'. WASH & ROTATE F/ 11732'-11742'. CIRC 50 BBLS HEC SWEEP. DAILY:S31,668 CUM:$262,789 ETD:SO EFC:$1,341,701 CHANGE BHA. 7"@11848' MW: 8.6 Seawater CIRC 50 BBLS HEC SWEEP. POOH. L/D FISH & SHOE. M/U NEW SHOE BF~A #6. RIH W/ 3-1/2" DP. WASH & ROTATE OVER FISH 11742'-11745'. CIRC 50 BBLS HEC SWEEP. POOH. CHANGE BHA. DAILY:S29,498 CUM:$292,287 ETD:S0 EFC:$1,371,199 POOH. 7"@11848' MW: 8.6 Seawater M/U BEA #7. RIH W/ 3-1/2" DP. WASH & ROTATE OVER FISH F/ 11744'-11746'. POOH W/ BHA #7. BREAK OFF SHOE & CLEAN OUT JUNK BASKET. TEST BOP TO 5000 PSI. OK. M/U BHA #8. RIH W/ 3-1/2" DP. TAG FISH @ 11746'. PUMP 50 BBLS HEC SWEEP. POOH W/ BHA #8. DAILY:S35,326 CUM:$327,613 ETD:SO EFC:$1,406,525 POOH. 7"@11848' MW: 8.6 Seawater POOH W/ 3-1/2" DP. L/D BHA #8. M/U BHA #9. RIH W/ 3-1/2" DP. TAG FISH @ 11741'-11745'. ATTEMPT TO LATCH ONTO FISH. POOH. M/U BHA #10. RIH. TAG TOP OF FISH @ 11745'. WORK OVER FISH TO 11747'. POOH. DAILY:S28,877 CUM:$356,490 ETD:SO EFC:$1,435,402 POOH W/ 6" BURNING SHOE. 7"@11848' MW: 8.6 Seawater POOH W/ BHA #10. M/U BKA #11. RIH. TAG FISH @ 11745'. ATTFJV[PT TO ENGAGE FISH. POOH W/ BKA #11. M/U BHA #12. RIH. TAG FISH @ 11745'. BURN OVER FISH F/ 11745'-11746' PUMP 50 BBLS HEC SWEEP. POOH W/ BHA #12. DAILY:S27,408 CUM:$383,898 ETD:S0 EFC:$1,462,810 RIH W/ BHA #14. 7"@11848' MW: 8.6 Seawater POOH W/ BHA #12. M/U BHA #13. RIH TO 11735'. BEGIN SLACKOFF. TAG UP @ 11746'. MILL @ 11746'. PUMP HEC SWEEP. POOH. L/D WASHPIPE, BURNING SHOE. M/U BHA #14. RIH. DAILY:S30,815 CUM:$414,713 ETD:S0 EFC:$1,493,625 RIH W/ BHA #16. 7"@11848' MW: 8.6 Seawater RIH W/ BHA #14. TAG UP @ 11746'. POOH W/ BHA #14. M/U BHA #15. RIH W/ BHA #15. TAG UP @ 11746'. POOH W/ BHA #15. M/U BHA #16. RIH. DAILY:S28,399 CUM:$443,112 ETD:SO EFC:$1,522,024 The al;ova is corl~sd[~. FOr form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 \ ~%~q0 Drilling Supt. RECEIVED DEC l 1Bc,90 AR3B-459-2~B 0il & Gas Cons. Commiss%0n Anchorage JNumber all daily well history forms consecutively JPage no as they are prepared lot each well. I 'ARCO Oil a,... Gas Company Daily Well History--Interim Instructions: This form is used during drilling Or workover operations. If testing, Coring, or perforating, show formation nsme in describin,~ work performed. Number ell ddll stem tests sequ,~ttlMly. Atta~.h description of all cores. Work performed by Producing Section will be reported on "lnMrlm' sheets unlil tinal completion. R~port official or reprel~ttllJvl ~ on "FI~II" form. 1) Submit "lnlerim" sheets when filled out bul not lass frequenlly than every 30 days, or (2) on Wednesday of the week in which oil II]'ilt~ le let. Submit weekly for workovers and following setting of oil strin§ unlil complelion. District Field ARCO ALASKA INC. JCounty or Parish NORTH SLOPE Islsle AK DS 15-16 no. ILease °r Unit Iwe" PRUDHOE BAY Date and depth as of 8:00 a.m. 11/04/90 ( TD: 0 PB:11826 SUPV:JER 11/05/90 ( TD: 0 PB:11826 SUPV:JER 11/06/90 ( TD: 0 PB:11826 SUPV:JER 11/07/90 ( TD: 0 PB:11826 SUPV:JER 11/08/90 ( TD: 0 PB:11826 SUPV:RWO 11/09/90 ( TD: 0 PB:11826 SUPV:RWO 11/10/90 ,( TD: 0 PB:11826 SUPV:RWO Comple, ..... d for ea~l~wh~le drilling ..... k ....in prog .... L5) i7) LB) O) RIH. 7"@11848' MW: 8.6 Seawater RIH W/ BHA #16. P/U KELLY. BEGIN MILL. SET BACK KELLY. POOH. M/U BHA #17. RIH. P/U KELLY. MILL OVER JUNK. TAG UP @ 11748' CIRC. SET BACK KELLY. POOH. M/U BHA #18. RIH. DAILY:S30,462 CUM:$473,574 ETD:S0 EFC:$1,552,486 POOH W/ BHA #19. 7"@11848' MW: 8.6 Seawater RIH W/ BHA #18. TAG UP @ 11754'. POOH W/ BHA #18. M/U BHA #19. RIH. TAG UP @ 11754' MILL 5.5'. PUMP HEC SWEEP. POOH. DAILY:S27,408 CUM:$500,982 ETD:S0 EFC:$1,579,894 POOH W/ BHA #21. 7"@11848' MW: 8.6 Seawater POOH W/ BHA #19. M/U BHA #20. RIH. TAG UP @ 11760'. WASH TO BTM. MILL 4'. POOH. M/U BHA #21. RIH. TAG UP @ 11764'. MILL 6.5'. POOH. DAILY:S27,364 CUM:$528,346 ETD:S0 EFC:$1,607,258 PUMP HEC SWEEP 7"@11848' MW: 8.6 Seawater POOH W/JET BASKET. REC'D 3-1/2" CENT AND OTHER JUNK. TEST BOPE. RIH W/JUNK MILL. MILLED CMT 11,771 -780'. MILLED KINLET CUTTER 11,780 - 786'. MILLED CMT 11,786 - 805'. PMPD 100 BBL HEC SWEEP. DAILY:S41,206 CUM:$569,552 ETD:SO EFC:$1,648,464 RIH W/ 3-1/2" DP 7"@11848' MW: 8.6 Seawater PUMP SWEEP. POOH. RIH W/ RTTS. TEST CSG & LINER LAP. OK. EST INJ RATE INTO PERFS. POOH W/ RTTS. BOP DRILL. RU & RIH W/ STINGER ON DP. DAILY:S34,986 CUM:$604,538 ETD:SO EFC:$1,683,450 POOH W/ CSG SCPR 7"@11848' MW: 8.6 Seawater RIH W/ DP & TBG STINGER TO PBTD. RU BJ & BATCH CMT. SPOT 150 SX CLASS G CMT ON BTM. POOH 15 STDS. SQZ 10 BBLS CMT AWAY. POOH. MU & RIH W/ BIT & SCPR. C/O TO TOL. DAILY:S154,690 CUM:$759,228 ETD:S0 EFC:$1,838,140 RU ATLAS E-LINE 7"@11848' MW: 8.6 Seawater RIH W/ GR/JB ON E-LINE. MU BHA & RIH. RU ELINE RUN JB/GR. NO CO. POOH. RIH W/ CSG SCRAPER TO TOL. NO OBSTRUCTION. CBU. POOH. RU E-LINE. RIH W. GR/JB. DAILY:S28,654 CUM:$787,882 ETD:S787,882 EFC:$1,078,912 The above is correct For ~o~ ~ml'~eration and distribution Drilling Supt. see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B _Oil & Gas Cons." ' ' ' L;0mmlssior, Number all daily well hislory forms conseculively JPage no as they are prepared for each well. 'ARCO Oil a,.. Gas Company Daily Well History--Interim Inltruc~ofle: This form is used during drilling or workover ol~rations. If testing, coring, or perforating, show formation neme in describing work performed, Number all drill stem tests s~:luentt",Jly. At~ d~:ription of all corns. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or r~p~ta/t~ ~ on "l~f~/" form. 1) Submit "lntlrlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil M~II~ I1 ~. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ]State ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit PRUDHOE BAY I DS 15-16 Complete record for each day while drilling or workover in progress AUDI 4 Date and depth as of 8:00 a.m. 11/11/90 ( TD: 0 PB:11826 SUPV:RWO 11/12/90 ( TD: 0 PB:11826 SUPV:RWO 11/13/90 ( TD: 0 PB:11826 SUPV:RWO 11/14/90 ( TD: 0 PB:11826 SUPV:RWO 11/15/90 ( TD: 0 PB:11826 SUPV:JER 11/16/90 ( TD: 0 PB:11826 SUPV:JER 21) 22) 24) ~5) .~6) DRILL CMT 7"@11848' RIH W/ GR/JB. POOH. RIH W/ VERTILOG. TO SURF. RD E-LINE. MU 6" BIT ON BHA. CMT. DAILY:S68,880 CUM:$856,762 ETD:SO AK IWell no. b~: 8.6 Seawater LOG 9-5/8 CSG F/ TOL DRILL SFT CMT, HRD EFC:$1,935,674 CBU 7"@11848' lv~: 8.6 Seawater DRILL CMT. TEST CSG & LINER TO 3000 PSI. OK. DRILL CMT. TEST UPPER PERFS. OK. DRILL CMT. TEST LOWER PERFS. OK. PUMP SWEEP. POOH. PU MILL & BHA. RIH. CO FILL & MILL JUNK. PUMP HEC SWEEP & CIRC. DAILY:S29,586 CUM:$886,348 ETD:S0 EFC:$1,965,260 RIH W/ GR/JB 7"@11848' MW: 8.6 Seawater PUMP HEC SWEEP. REVERSE DP VOL. TEST CSG, LINER & PERFS TO 1800 PSI. OK. POOH. RU ATLAS. RUN 72 ARM CALIPER TO TOL. RIH W/ CIBP WHILE EVALUATING LOGS. POOH W/ CIBP. RD ATLAS. RU HLS E-LINE. RIH W/ GR/JB. DAILY:S55,646 CUM:$941,994 ETD:S0 EFC:$2,020,870 RIH W/ PERF GUN. 7"@11848' MW: 8.6 Seawater RIH W/ 5.98 GR/JB. TAG @ 11650' POOH. R/D HLS. M/U BHA #29. RIH. WORK SCRAPER THROUGH TAG AREA F/ 11560'-11817' REVERSE CIRC. POOH. N/D FLOWLINE. N/U PERF FLANGE. R/U HLS. RIH W. 5.95 GR/JB TO 11746'. POOH. RECOVERED 1/2 GAL CMT & METAL CTGS FROM JB. RIH W/ 4-1/2" ORIENTED PERF GUN ASSY,. 4 SPF, 180 DEG PHASING, 36 GRAM CHARGES. PERF F/ 11764'-11784' POOH. R/D PERF GUN #1. R/U PERF GUN #2. 1 MISS FIRE ON GUN #1. RIH W/ PERF GUN #2. DAILY:S35,205 CUM:$977,199 ETD:SO EFC:$2,056,075 SET PKR ON DP 7"@1184~' MW: 8.6 Seawater ORIENT PERF 11,740-11764 & W/ 2 SPF, 90 DEGREE PHASING F/11692-11696. WLOH. RIH W/ GR/JB. WLOH. RIH W/ 7" FB-1 PKR & TAIL ON E-LINE & SET SAME. WLOH RD E-LINE. MU STRADDLE ASSY AND RIH ON DP. SET PKR @ 11695'. DAILY:S27,408 CUM:$1,004,607 ETD:S1,004,607571 EFC:$1,078,912 · 7"@11848' MW: 8.6 Seawater RELEASE F/ PKR & POOH. LD DP. RU & RUN CUM:$1,092,592 ETD:$1,092,59Z EFC:$1,078,912 RUN COMP PRESS TEST PKR. 3-1/2" COMP ASSY. DAILY:S87,985 The above ia correct For for'tn ~-repa}ation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 ECE AR3B-459-2-B AJ~as,~a.Oil & Gas Cons. Oommissior~ ~chorage Title Drilling Supt. Number all daily well hislory forms consecutively as they are prepared lot each well. Page no. ARCO Oi, ~d Gas Company Daily Well History--Interim lnetl%l¢flahl: This form il ulld dtlHIl~ ~rllllag or workover Ol3~retlone. If testing, coring, or perforating, show formltlon name in describing work performed. Number all drill stem testl s~lumatll~. Att~:h dllcription of ell cores. Work performed by Producing Section will be rsporfed on "lnllHm" sheets until final Filllg I'orm. 1) Submit "lltlaHnl" sheets when filled out bul not Ieee frequently than every 30 days, or (2) completion. Report official or rel=rel~ltlli~l ~ oft" ' on Wednesday of the week Itl t~klch oil It~ I~ I/L Submit weekly for workovers and following setting o! oil string unlil completion. District ARCO A~SKA INC. IC°unty°rPeriehsoRx" SLOPE IState AK I I Field PRUDHOE BAY ILe'se °r Unit DS 15-1(~ Iwell n°' Complete record for e~.~f w~ile drilling or workover in progress Data and depth as of 8:00 a.m. 11/17/90 ( TD: 0 PB:11826 SUPV:JER !7) ND BOPS 7"@11848' MW: 8.6 Seawater RIH W/ 3-1/2" COMP ASSY. MU & TEST SSSV LINE. STING IN & TEST SEAL ASSY. DISP WELL TO INHIB SFJ%WATER W/ DIESEL CAP. LAND TBG. RILDS. TEST TBG & CSG. LD LNGD JT. SET BPV. ND BOPS. CAMCO 'TRDP-1A' SSSV @ 2235', BAKER 'D' PKR @ 10243', 'FB-i' PKR @ 11699', TT @ 11712'. DAILY:S27,936 CUM:$1,120,528 ETD:S1,120,528 EFC:$1,078,912 The above is c ,o~ct see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDe~ "\ J T,t,e \ %~0A~,.~ Drilling Su~t. AR3B-459-2-B RECEIVED DEC 1 Al~sk.a Oil & Gas Cons. Co1111Ill~'i~11 ,~r~chora~e INumber all daily well hislo~' ;orms consecutively as Ihey are prepared for each well. IPage no. "Fiaal requited upon. operation if space P RUDHOE BAY Auth. or W.O. nD.AS1835 Dally Well History-Final Report after allowable ha~ I~en sleighed or well II Plugged, Abandoned, or 8old. for an indefinite or appreciable length of time. On wed<overs when an official teat la not data in blocks provided. The "FI~II Reflert" form may be used for reporting the entire County or Parish NORTH SLOPE Lease or Unit ADL: 28306 IAccountlng coat center code State AK IWell no. DS 15-16 woRKovER API: 50-029-21115 Operator A.R. CO Spudded or w.o.~pEpT A.R.Co. W.I. Date ITotal number of wells (active or inactive) on this~ and Icost center prior to plugging 2 1.7 8 0 0 / labandonment of this well 10/22/90 Date and depth aa of 8.'~O a.m. 11/18/90 ( TD: 0 PB:11826 SUPV:JER Complete record f~l~.l~: da~ reported 8) RIG RELEASED 7"@11848' · .. ~:.. :-%. · -. MW: 8.6 Seawat~er.~- ." CONT ND BOPS. NU TREE. ~TEST TREE. PRS TBG TO SHEA]~'PLU~!:~ DAILY:$201,579 CUM:$1,322,907 ETD:$1,322,071 EFC:$.[~' 12 / RECEIVED DEC Alaska Oil & ~as Cons. Cumr~JssJor~ AnChorage Old TO I New TO PB Depth Released rig I Data Kind of rig Classifications (o11, gas, etc.) I Type completion (single, dual, etc.) Producing method IOfflcial relervoir name(s) Potential test data Well no. Date Reservoir Producing Interval OII or gasTest time Production Oil on test Gas per day Fump size, SPM X length Choke size T.P. C.P. Water % (3OR Gravity Allowable Effective date corrected Signa~e~ ~,~~ Date' . Title Sa ' For fo~ pmpa~h~ and dmtnbutlon ~ P~ures Manual, ~cflon 10, DHIling, Pag~ ~ and 87. AR3B-459-3-C I Number all dally well history fermi consecutively they ere prepared for each well. iPage no. DIvlMon ol Aff. mt~RlchilMdCempany STATE OF ALASKA ALASKA''~-''' AND GAS CONSERVATION CC '¥11SSION REPORT SUNDRY WELL OPI= ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing ~ Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 854' FNL, 165' FWL, Sec. 22, T11 N, R14E, UM At top of productive interval 1706' FNL, 1658' FEL, Sec. 15, TllN, R14E, UM At effective depth At total depth 1020' FNL, 1147' FEL, Sec. 15, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 15-16 9. Permit number/approval number 84-74/90-215 10. APl number 50 - 029-21115 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11891 feet Plugs(measured) 8845 feet Effective depth: measured 11826 feet true vertical 8819 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 1910 sx Poleset 80' Surface 2424' 13-3/8" 1900 sx Perm 'E' & 2495' 400 sx PF 'C' Production 10779' 9-5/8" 500 sx CI 'G' & 300 sx CI 'C' 10850' Liner 1352' 7" 380 sx CI 'G' 11848' Perforation depth: measured 11740-11784' True vedicaldepth 80' 2495' 8320' 8828' RECEIVED true vertical 8785-8802' ~ .~...J~J.~,.GaS COILS. ~.11]a~$8~ Tubing (size, grade, and measured depth) 4-1/2", 12.64t, L-80, PCT @ 10560' MD '"~"';~"~'JCJl0rag~i. " Packers and SSSV (type and measured depth) BOT 3-H packer @ 10451' MD; 4-1/2", Otis RQM SSSV @ 2247' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Sh~t in -. well would not flow. Tubing Pressure Subsequent to operation 1898 5732 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~-- ~" ~~'~ Service Title Sr. Area Operations Engineer 991 Date Form 10-404 Rev 06/15/88 ztRA.IW~ ~.' .I ~r~h~r AT('3-1ATR SUBMIT IN DUPLICATE DS 15-16 DESCRIPTION OF WORK COMPLETED SELECTIVE MUD ACID STIMULATION 4/21/90 : A Mud Acid Stimulation was performed as follows: MIRU CT & PT equipment to 4500 psi. RIH w/CT Inflatabe Packer and set at 11710' MD. PT Packer OK. Treated perforations at: 11740 - 11784' MD Ref. Log: BHCS 6/24/84. Pumped: 12 bbls Xylene, followed by 78 bbls 12% HCI, followed by 160 bbls 6-1.5% HCI-HF, followed by 210 bbls 2% NH4Cl Water, followed by 35 bbls Meth-Water. Shutdown. Deflated and POOH w/packer. N2 lifted to flow well.. Rigged down. Flowed well and obtained a valid production welltest. ARCO Alaska, Ir Prudhoe L_. Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 9, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 15-16, Permit No. 84-74 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/JWS/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 15-16)W1-3 APR 1 1 1990 .0il .& Gas Con~ Cotillon ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS .K"-'OIL AND GAS CONSERVATION t,..'MMISSION APPLIC. rlON FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 854' FNL, 165' FWL, Sec. 22, T11N, R14E, UM At top of productive interval 1706' FNL, 1658' FEL, Sec. 15, T11N, R14E, UM At effective depth At total depth 1020' FNL, 1147' FEL, Sec. 15, T11N, R14E, UM Operalion shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate X Perforate Other 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 15-16 9. Permit number 84-74 10. APl number 50 - 029-21115 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 11891 feet Plugs(measured) 8845 feet Effective depth: measured 11826 feet true vertical 8819 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 1910 sx Poleset Sudace 2424' 13-3/8" 1900 sx Perm 'E' & 400 sx PF 'C' Production 10779' 9-5/8" 500 sx Cl 'G' & 300 sx CI 'C' Liner 1352' 7" 380 sx CI 'G' Perforation depth: measured 11740-11784' Measured depth True vertical depth 80' 80' 2495' 2495' 10850' 8320' 1 1 19.90 true vertical 8785-8802' ..,' ~!:;sk~ 0it & 6as Cons, Commission Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, PC tubing @ 10560' MD ~l~lchora~ Packers and SSSV (type and measured depth) BeT 3-H packer @ 10451' MD; 4-1/2", Otis RQM SSSV @ 2247' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation March 1990 16. If proposal was verbally approved Oil x Gas Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~d~. ~)~~ Title Operations Engineering Manager FOR COMMISSION LI.~E ONLY Conditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Suspended Date IApproval NoTo_ ,,2/.f '--- Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~¢'~' Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 q/iQ I %^1 Qfwl,~r SUBMIT IN TRIPLICATE Drill Site 15-16 ARCO Alaska, Inc. intends to perform a mud acid treatment on DS 15-16. The treatment will be performed as follows: 1. Obtain a wellhead fluid sample from well 15-8 or 15-17 (Well 15-16 will not flow) and perform emulsion and sludge tests with all stimulation fluids. 2. MIRU pump trucks, transports, and coil tubing unit (CTU) with inflatable packer. 3. RIH with tubing tail Iocator, 7" inflatable packer and hydraulic disconnect. Set the packer at 11705' MD. 4. Load 3300 gals of 12% HCI acid and 6600 gals of 6%-1.5% HCI-HF acid with additives. Titrate acid and test for iron content. 5. Roll all acid compartments before pumping starts. 6. Pump the following fluids through the CT: Notes: Friction reducer is to be added to all fluids pumped except Xylene. A. 500 gals of Xylene B. 3300 gals of 12% HCL w/additives C. 6600 gals of 6% HCl - 1.5% HF w/additives D. 8800 gals of 2% NH4CI water F_ Displace the CT as needed with methanol/water. 7. Release the inflatable packer. Pull the packer above the PBR assembly before bringing well back on production. POH with CT. 8. After all the stimulation fluids have been recovered, obtain a test on the well. REEE!VED' /i?~ka.Oii .& Gas Cons, Commissior~ ~chorage 6 5 4 2 2 Gas Cons~ COILED TUBING UNIT BOP EOU ! PMENT H]REL]NE BOP EOUIPHENT 1. SOCK) PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAUS 3. 5000 PSI 4 1/6" HYD~LK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~d:)O0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELIN£ RAK15 (VARIABLE SIZE) :~. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" IrLOW TUBE PACK-OFF ARCO Alaska, Inc. Prudhoe Bay ~.._=~ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 11, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 15-16 Approval No. 9-282 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SLW/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 15-16) W1-3 RECEIVED OCT 1 i 1989 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA:--''1. AND GAS CONSERVATION CC '--'~"/IISSION REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 854' FNL, 165' FWL, Sec. 22, T11N, R14E, UM At top of productive interval 1706' FNL, 1658' FEL, Sec. 15, T11N, R14E, UM At effective depth At total depth 1020' FNL, 1147' FEL, Sec. 15, T11N, R14E, UM 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 15-16 9. Permit number/approval number 84 - 74/9 - 282 10. APl number 50 - 029 - 21115 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11891 feet Plugs(measured) 8845 feet Effective depth: measured true vertical Casing Length Conductor 80' Sudace 2424' Production 10779' Liner 1352' 11826 feet 8819 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1910 SX Poleset 80' 80' 13-3/8" 1900 sx Perm 'E' & 400 sx PF 'C' 2495' 2495' 9-5/8" 500 sx Cl 'G' & 300 sx Cl 'C' 10850' 8320' 7" 380 sx Cl 'G' cmt 11848' 8828' Perforation depth: measured 11740 - 11784' RECEIVED true vertical 8785- 8802' OCT ~. ;L ]989 Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, PC Tubing @ 10560' MD AJaska Off & Gas C0ns~ C0mrn[ss[, Anch0raae Packers and SSSV (type and measured depth) BOT 3-H Packer @ 10451' MD; 4-1/2",Otis RQM SSSV @ 2247' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Pr~ducti0rl or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1898 179O8 0 0 0 0 Tubing Pressure 1973 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 103 S.L. WARD. 265-13135 SUBMIT IN DUPLICATE DS 15-16 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 5/19/89 : MIRU CTU & Stimulation Equipment. PT to 4000 psig. Performed wash of perforations at: 11675 - 11695' MD Ref. Log: BHCS 6/24/84. 11714 - 11784' MD Pumped the following treatment: 48 bbls 12% HC1 w/10% Xylene, followed by, 51 bbls 12-3% HC1-HF, followed by 26 bbls 12% HCI. Displaced w/Crude. POH. Flowed well. Rigged down. 5/21/89 : A CTU Squeeze was performed as follows : MIRU CT & Cementing Equipment. PT equipment to 4200 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 26 bbls of acid resistive cement, squeezing perforations : 11675 - 11695' MD Ref. Log: 6/24/84. 11714 - 11784' MD Contaminated cement with 90 bbls contaminant. Cleaned out contaminated cement from WB. 6/4/89 : Rep erforated: 11741 - 11784' MD Ref. Log: 6/24/84. Added Perforations: 11784 - 11785' MD Ref. Log: 6/24/84. Well would not flow. 6/4/89 : Jet pumped well to flow. 7/16/89 : A CTU Resqueeze was performed as follows : MIRU CT & Cementing Equipment. PT equipment to 4500 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 29 bbls of cement, squeezing perforations : 11741 - 11785' MD Ref. Log: 6/24/84. Pressured up on squeeze to 3000 psi, and held 1 hour. Contaminated cement with 65 bbls contaminant. Cleaned out contaminated cement from WB. DS 15-16 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 7/19/89 : Began underreaming from 11650' CTM, to clean out uncontaminated cement from wellbore. Finished underreaming 7/21/89, after progressing to 11792' 7/23/89: Fill cleanout to remove cement fines from wellbore. 7/31/89: Reperforated' 11740 - 11784' MD Ref. Log: 6/24/84. Attempted to flow well. Well would not flow. 8/7/89' Jet pumped well to flow. Well would not flow. ARCO Alaska, Inc. [ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 10, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 15-16 Permit No. 84-74 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SLW/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 15-16)W1-3 WELL S 3 / 115 ARCO A~aska, ~.c. ~s a Subsidiary of AflanflcR~chfie~dCompamy AR3B--6132~C STATE OF ALASKA -'"', AL .KA OIL AND GAS CONSERVATION COMM, .,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown I Re.enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time extension __ Stimulate I / Change approved program ~ Pull tubing ~ Variance i Perforate ~ Other ..W... 2. Name of Operator 3. Address P.O. Box ]O0~O, Anchorage~ AK 99510 , 4. Location of well at surface .4' ENL. 1.65inte~W~a, Sec. 22, TllN, R14E, UM 8A~ top oT proOluct~ve 1706' FNL, 1658' FEL, Sec. 15, TllN, R14E, UM At effective depth At total depth 1020' FNL, 1147' FEL, Sec. 15, TllN, R14E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number DS 15-16 9. Permit number 84-74 , 10. APl number 50-- 029-21115 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11891 feet Plugs(measured) 8845 feet Effective depth: measured 11826 feet Junk (measured) true vertical 8819 feet Casing ~ngth Size Cemented Measureddepth Surface 80' 20" 1910# Poleset Intermediate 9424' 13-3/8" 1900 sx Perm 'E' & 400 sx PF 'C' Production 10779' 9-5/8" 500 sx Cl 'G' & 300 sx C1 'C' Liner 1352' 7" 380 sx C1 'G' 80' 2495' 10850' 11848' True vertical depth 80' 2495' 8320' 8828' Perforation depth: measured 11675-11695'; 11714-11717'; 11717-11777'; 11777-11784' true vertical 8759-8767'; 8775-8777'; 8777-8800'; 8800-8803' Tubing (size, grade, and measured depth) 4~", 12.6#, L-80, PCT @ 10560' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10451' MD; 4~", Otis RQM SSSV @ 2247' MD 13. Attachments Description summary of proposal ..¢_ Detailed operations program ':? .... <;ti & Q=m Cons. AnGh0rage BOP sketch ~ 14. Estimated date for commencing operation February 1989 16. If proposal was verbally approved Name of approver .... Date approved 15. Status of well classification as: Oil _~ Gas __ Suspended Service - - 17. ! hereby ¢,ertify that the Joregojng is t.,rue and correct to the best of my knowledge. TitleOperations Engineering Manager FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test I Subsequent form required 10-'-!c: '"~r--PrOvedAp OOP¥ ORIGINAL SIGNED BY Approved byorder of the Commissioner LONNIE.C. SMITH ~Commissioner IApproval No. ¢.. ~t~'(~¢~,, WELLS3/ll5 S. L. Ward, 265-1305 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 15-16 CTU CEMENT SQUEEZE PROCEDURE SUMMARY Workover Ob!ective: To cement squeeze the upper perforations which are in the gas/oil contact. . . . . . . . . . Make a slickline run to PBTD. Last PBTD was 11826' CTM on 12/6/88. Surge well and retag PBTD. Perform fill cleanout. Acid wash perforations with HCI and HCI-HF. Ensure the mechanical integrity of the tubing string. RIH with CT and fluid pack the wellbore with filtered seawater. Pump 25 bbls of cement followed by 2 bbls water and 50 bbls contaminant. Hold 3000 psi surface pressure for 60 minutes. Squeeze off the following intervals: Zone Perforations SPF (Ref.: BHCS 6/24/84) 1B 11675 - 11695'MD 4 lB 11714- 11784'MD 8 Jet or reverse out the contaminated cement. Wait a minimum of 2 weeks. Perforate the following interval: ;Zone Perforations 1B 11740 - 11784'MD Shot Density( Ref.' BHCS 6/24/84) FSD If the well will not flow, shoot contingency perforations as follows: Zone Perforations Shot Density( Ref.' BHCS 6/24/84) 1B 11714 - 11740'MD FSD Current status: Producing at 7200 GOR; cycled producer Expected static BHP: 3750psi @ 8775'TVD Expected fluid in wellbore at perforation: Seawater 6 ,5 4 2 CO~ILED TUB/,Nt3 UNIT BOP EOU ! PllENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLAN0£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULK:: SLIPS 4. 5000 P$~ 4 1/6..SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PS! 4 1/16" STUFFING BOX 2 H]RELINE BOP EOUIPHENT 1. 5000 PSI 7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELIN[ RAUS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC P. O, BOX i .... ,^~ ANUHURM~E A~.~,A 99"-i ¢, DATE' t~-t6-88~ REFERENCr' ARCO CASED '~n, c ~ ~ ......FINAL~ ~_ k~U~,~. I TDT-~' RUN 's ~ ~ '~-9-88 DUAL '-' '""~'- ~ .... 2-8-88 PDK-i ~:~(~,,.., RUN .,~ , ..,.~ ~ i 2-8-88 -, ~'~-4-88 COLL. AR/PERF. I:;:(J,'i i , 5:" PLEASE SIGN AND RETURN THE ATTACHED COF'Y A;~' RECEIPT OF i);:~'FA. ;:J C H ATL. A.? ATLA:S' A'F L.A::i: r:-t 'f LA£ 5'CH NEu,:~VED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAN$ ~°87~,, APPROVED DEC 2 o Oil & 63s Cons. Commission N~chorage D I ~'.,'FR t BUT ! ON CENTRAl.. FILES CHEVRON D-~M EXTENSION EXPLORATION EXXON MARATHON MOBIL ~ PHILLIPS PB WELL R & D- · "' SAPC .,,."" STATE OF · .-'"' TEXACO FILE~ ALAS'K A ARCO Alaska', Inc. Post Office B ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 -Date'--' January 29, 1985 Reference: ARCO TVD Logs ~ 15-16 :F/)C/CI~/~'. 6-24-84 ~ ~ 15-16 ?-:::BI-10$/TVD ' . 6-24-84 '"~" "~ 15-16 ~'~?~' ~ ...... 6-24-84 2"&5" #2 Sch 'i 2"&5" #2 Sch '~ 2"&5" #2 Sch 2"&5" #2 Sch Pam Lambert ATo 1429C Trans 012 Chevr~ D&M Bxploration SerVices Extension Exploration Texaco Marathon - Please sign and return the attached sheet as receipt_, ~f~d~a.ta,., ~ Received by 0~L .~'\/~~ . ,,, ..... .., , '.:,ds Cons. Commiss~c~ Mobile Mobile E & P Phillips ?rudhoe Bay Well Files ._ __ , .,~ _~.-~/L Sohio ~S~ 0JJ' & Gas Cons. Commission Anchorag~ ARCO Alaska, Inc. Prudhoe Bay Tb,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 10, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 15-16 Permit No. 84-74 Enclosed is the Completion Report for work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 15-16)W4-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany RECEIVED J u N t ~ ~1tl5 ~',:~.~ ,~1 & Gas Cons. Commission Anchorage STATE OF ALASKA .... ALASKA/'. ~ AND GAS CONSERVATION CO,..~IISSION 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. 84-74 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21115 4. Location of well at surface 9. Unit or Lease Name 854' FNL, 165' FWL, Sec. 22, Ti]N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1706' FNL, 1658' FEL, Sec. 15, Ti]N, R14E, UM 15-16 At Total Depth 11. Field and Pool 1020' FNL, 1147' FEL, Sec. 15, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBI ADL 28306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 116. No. of Completions 06/06/84 06 / 25/84 06/27/84I N/A feet MS LI N/A 1~. Total Depth (MD+TVD) !18. Plug Back DePth (ME~-TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11891' MD, 8845' TVD 11826' MD, 8819' T~DYES~ NO [][ 2247 feet MD 1900' (ADDrOX.) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyro 2~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91,5# H-40 Surf. 80' ~0" 3 c~1 f)!~ Po!eset 13-3/8" 72.0# L-80 Surf. 2~95' 37~,, ]900 .~w p~m "V." + /,f)O ,w PW "C" 9-5/8" 47.0# L-80 Surf. 10850' 1~" 5~0 .~w Cl.~e "C" + qnn cY pw ,,~,, 7" 29.0# L-80 10496' 11848' 8~" 380 sx C1~.~ "C" · 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) *11675 ' -11695, MD ~.~ 10560' !9/:51' 11714-'11784' MD w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ~/^ *added on 5-11-85 w/2 SPF TVD of perf's: 8758-8803' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 1981I Flowin ~. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 5/12/85 12.2 TESTPERIOD I~ 1233 S~!B 907 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL G~-AvITy-API (corr) ' Press. 421 NA 24-FLOUR RATE I~ 2425 1784 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U '"'"'";:,'-'~ t;~.,' & G~s Cons. ~ , ~n0rrlrrl:ss'0. ~ r~chora,qe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -- . . · NAME . _ . Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH : GOR;'and.time of each phase. .- . : . ., Top Sadlerochit ', ~0900' 8351' NO~ Top Zone 3 '--: 1~2~' 8~83' Top Zone 2 ; [ ---.'~25~'. 8555'. "' '~.' ,' .... ~ :. ~' 8696' Top Zone ~' ' ;c:'-~622' 87~ . . Base Sadlerochit N~ ~I c ... . ..._ : : : :. ~ : .., , :.~ , ... . - . ........ 31. LIST OF ATTACHMENTS , , ~ .... ~ . ; .- . . ._ 32. I hereby Certify that the fore~oin~ is true and correct to the Be~t of mg Si~ned Title Regional O~er. En~r. ~ate .... 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 (multipl. e completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 10, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 15-16 Permit No. 84-74 Enclosed is the "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 15-16)Wl-3 ARCO Alaska, Inc. la a Subsidiary of AtlantlcRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LI_~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 854' FNL, 165' FWL, Sec. 22, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 7. Permit No. 84-74 8. APl Number 50- 029-21115 9. Unit or Lease Name 12. I 6. Lease Designation and Serial No. ADL 28306 Prudhoe Bay Unit 10. Well Number DS 15-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate L_~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) · Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 5-11-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 11675'-11695' MD (2 SPF). Shut-in well, POOH, all shots fired. Secured well. RD. Ref: BHCS RECEIVED Alaska Oil & Gas Cons_ Corr,~miss~o Anchorage 14. i herebv~'artify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~~// TitleRegi°nal Operati°ns Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 15, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS I5-16 Permit No. 84-74 Dear Mr. Chatterton: Attached is a Subsequent Sundry Notice for work completed on above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File PI(DS i5-16)W1-3 the ARCO Alaska, Inc, la a Subsidiary o! AllantlcRIchfleldCornpany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL][]( OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 854' FNL, 165' FWL, Sec. 22, TllN, Ri4E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28306 7. Permit No. 84-74 8. APl Number 50- 029--21115 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 15-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 4/15/85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot select-fire interval 11,714' - 11,724' MD (4 SPF), pulled up and shot select-fire interval 11,724' - 11,734' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 11,734' - 11,754' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 11,754' - 11,774' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #4, shot interval 11,774' - 11,784' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHC$: 6/2/84 RECEIVED MAY 2 0 1985 0d & Gas Cons. C0mmissi0r~ Anchorages, 14. I hereby,~l~rtify that the,~regoj,qg is true and correct to the best of my knowledge. Signed .... Title Regional Operations Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay ~.,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 15, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 15-16 Permit No. 84-74 DS 5-7 Permit No. 77-13 Dear Mr. Chatterton: Attached are Well Completion reports for the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/ka At tachment s CC: Sohio Alaska Petroleum Company File PI(DS i5-16)W4-3 File Pi(DS 5-7)W4-3 RECEIVED MAY t 7 1985 Alaska Oil & Gas Cons. Commissior~ A.chorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA .-- ALASKA ~.AND GAS CONSERVATION CC 'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL:~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. O. Box 1003607 Anchorage~ AK 99510 50- 029-21115 4. Location of well at surface 9. Unit or Lease Name 854' FNL, 165' FWL, Sec.22, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1706' FNL, 1658' FEL, Sec.15, TllN, R14E, UM 15-16 At Total Depth 11. Field and Pool 1020' FNL~ 1147' FEL, Sec.15, TllN~ R14E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBI APL 28306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 06/06/84 06/25/84 06/27184 N/A feet MSL] N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD~TVD) 19. DirectionalSurvey 120. Depth where SSSV set 12,. Thickness of Permafrost ll,891'MD,8845'TVD 11826'MD, 8819'TVD YES:x~ NO [] 2247 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCR/CR/SP. LDT/CNI,/GR/Cal. CBL: Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,,, !3-3/8" 72.0# ?=-80 m_,rf 0495' !7-!/2" lqnn ~Y Pe_,~__ ,m,, + An0 s PF "C" 9-5/R" A'7 f'l~ T-Rh R~t'-I= 1CIR~ '19-1//," c;fif'~ ev ~l~ee '~C~' 4- ':tCl~ ~ P'I;' "~." 7" 9q. Cl~ T,-RCl l~/,qR~ 11R/,RT R-1 /9" '~Rf~ .~x Cl~.qS "~" 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) 11,717' - 11,777' MD w/4 spf 4-!/2" lfl~01 10,1:5!' .I '11,714' - 11,717' MD *'11,717' - 11,777' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,11,7777 _ -l-l,784T MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *added on 4/15/85, w/ 4 spf ~/A ** re-perf'd on 4/15/85 w/ 4 spf TVD of perf's: 8775 - 8802' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 19~;1 FI ow1 n~ Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL iOILGRAVITY-API (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Arlch0~Sd~l~mit in duplicate ~::.'T'''~ ~"J~ I?:~ ~ ~ ~'~' '~ ~ .... ~ . ''~,'~, 1--0 .~j~: f NAME Include interval t~ted, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH ~ TRUE VERT. DERTH~ ::.GOR~'and.tim~f~b phase.~ ';':r , :..?: ,; "': -,~. . , ~;~ · op Sadle~ocA~t 10~90,07 ... ~ 8351~ --~op'-Zo~e -3 .......... : ~;~2~-~¥; :. :-- 8~83~ ................................................ Top Zone 2 : ~.,~' _:.. ~ 8555' --~C ............ ~.J2~.: ~11;53~.- ' : 8696" .... ' : -~ ;r, ;- , .. _ . .. ,',',." -... · op Zone ~ : .. ~,622' 8736 'Base Sadleroch~t i;:'7 ;:'..:.- N0~-~ ~ . ~ ~ , ~. , ...... . , . ~., ~ .. . : . . .. ~ . ~ ?? .~ ...... ., .: -:,~ ~ ~;'. .... :,..,. ..~'" .. , ..: . ~ - ;~--~ ~,.' ~ ~,~ :- :' -.-. ;.; · . ~. :- :_ ~ . · .... , - . - . . - ' ; - .- ~: , . . - : :. -- '~ '': '- ''-- ' ' - t' ~ ;'"' ' ' , - . ~ : ~ ': .......... . ........... , - -, . . : . - ~ ., , . . . : ~., , , - - : -, . .. .. ...,-. . ~"~ :. . ~ ~_ -~- '.: : ...- _ . .............. .. , ...... . . . 31.-LIST OF A~ACHMENTS : ' -- ' ...... . . - .. . 32. I hereby certify th~ th~.fOregOing is trUe and c°rr~t to the'best of my knowledge ' ~'~ ' " Ro~e Signed _.' _ TitleR~ginn~l ~,~. ~g, Date. INSTRUCTIONS General: This form .is designed for submitting'a complete and correct well completion report and log on . . all types of lands and leases in Alaska. Item 1' Classification of SerVice Wells' Gas injection, water injection, steam injection, air injection, 'sait 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 fr, om 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 t-'o be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, HYdraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. : Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. ~ Prudhoe Bay ,.,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 8, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 15-16 Permit No. 84-74 Dear Mr. Chatterton: Attached is an Intention Sundry Notice on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachment cc: Sohio Alaska Petroleum Company File PI(DS 16-4)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfieldCompany STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 854' FNL, 165' FWL, Sec. 22, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 12. I 6. Lease Designation and Serial No. ADT. 2R306 7. Permit No. 84-74 8. APl Number 50- 029-21115 9. Unit or Lease Name p~ahn~ Bay Unit 10. Well Number D.q 15-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 15-16 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11675'-11695' MD (20') Ref: BHCS 6-24-84 RECEIVrO APR ! 0 1985 AlasKa 0il & Gas C0n~. ,,u,,~missi0n Anchorage 14. I hereby c.e,rtify that the fore, going is true and correct to the best of my knowledge. Signed ..... - . _ TitleRegional Operations Enqineer The space below for Commission use Date Conditions of Approval, if any: ~'~ ...~]~'l'E IL $111ll ~v Order of Approved by COMMISSIONER the Commission Approved Cop'/ ..Returned Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 2, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 15-16 Dear Mr. Chatterton' Enclosed is a revised Well Completion Report for the subject wel 1. If you have any questions, please call me at 263-4944. Sincerely, · J. Gruber Associate Engineer JG/tw GRU5/L75 Enclosure RECEIVED APR 1985 Alaska. Oil & Gas Con;.;. Corr't['n. ission Anchor;~,.33 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .... STATE OF ALASKA ALASKA, _ AND GAS CONSERVATION CC .vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I S ! ON OIL E~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21115 4. Location of well at surface 9. Unit or Lease Name 854' FNL, 165' FWL, Sec.22, TllN, R14E, UM Prudh0e Bay Unit At Top Producing Interval 10. Well Number 1706' FNL, 1658' FEL, Sec.15, TllN, R14E, UM 15-16 At Total Depth 11. Field and Pool 1020' FNL, 1147' FEL, Sec.15, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKB ADL 28306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshOre J 16. No. of Completions 06/06/84 06/25/84 06/27/84 N/A feet MS L] N/A 17. Total Depth (MD+TV D) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV Set I 21. Thickness of Permafrost 11891 'MD,8845'TVD 11826'MD,8819'TVD YES I~X NO [] 2247feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyro 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# H-40 Surf 80' 30" 1910# Pol ese~. 13-3/8" 72.0# L-80 Surf 2495' 17-1/2" 1900 sx P~rrrl "E" + 400 ~x PF "C" 9-5/8', 47.0# L-80 Surf 10850' 12-1/4" 500 sx C1~,5 "Q" + 300 ~x PF "C" 7" 29.0# L-80 10496' 11848' 8-1/2" 380 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11,717' - 11,777' w/4 spf, 90° phasing 4-1/2" 10560' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/^ 27. N/A PRODUCTION TEST Date First Production J Method of Operation {Flowing, gas lift, etc.) I Date of Test Hours Tested ;PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-oILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED =~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ',cCEiVED Form 10-407 JMM/WC44 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. , 3O. GEOLOGIC MARKERS" FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10,900' 8351 ' N/A Top Zone 3 11,124' 8483' Top Zone 2 11,254' 8555' G0C 11,534' 8696' Top Zone lB 11,622' 8736' Base Sadlerochit NOT REACHED 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~/7~.,~/~.~? .LAF. j~, Title Associate Engineer Date ~,-~.;¢.¢.~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interVal reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, In¢ Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: February 18, 1985 Reference: ARCO CH Final ~z9-16 Injection Profile Sur~ey 1-12-85 Run 1 5" GO ~13-21 Injection Profile Survey 1-14-85 Run 1 5" GO /15-7 Gamma Ray Log 1-27-85 Run 1 5" Camco j15-8 Gamma Ray Log j15-9 Gamma Ray Log .,~15-16 Collar Log 15-20 Gamma Ray Log >~14-29 Spinner f14-30 Spinner 1-28-85 Run 1 5" Camco 2-4-85 Run 1 5" Camco 1-10-85 Run 1 5" GO 1-25-85 Run 2 5" Camco 2-2-85 Run 1 5" Camco 1-30-85 Run 2 5" Camco ., P~~lease sign and return the attached copy as receipt of data, Received by Pam Lambert ATO 1429C Trans #~)~ Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc,:'"" Post Office box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date.: February 11, 1985 Reference: ARCO Pressure Reports 2-10 ~tatic Gradient 1-26-85 Camco 5-2g-~Static Gradient 1-24-85 Camco 6-3~Z/Static Gradient 1-23-85 Camco . 14-14 Pressure Fall Off 12-2-84 GO 15-8 ~'S~atic Gradient 1-25-85 Camco t5-9 C-'Static Gradient 1-25-85 Camco · ~:~_~E~!~S~atic Gradient 1-25-85 Camco 15-20'~Static Gradient 1-25-85 Camco 17-9 .-Static Gradient 1-27-85. Camco ~Please sign and return the attached copy as recipt of data. Received by Pam Lambert ATO 1429C Trans 022. Chevron Exploration Services Extens ion Exploration ~e3aco Marathon Mobile E & P L~itI 1 i p s R~'udhoe,. Bay Well Files Rf_~&: D ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports and Workover Well Histories for the following wells' 1E-3 15-17 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L124 Enclosures RECEIVED FEB 0 6 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary o! AtlanticRichlieldCompany .... STATE OF ALASKA .~-_ ALASKa;- _ANDGAS CONSERVATION CC vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG. I 1. Status of Well Classification of Service Well RECOHPLET I ON OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21115 4. Location of well at surface 9. Unit or Lease Name 854' FNL, 165' FWL, Sec.22, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1706' FNL, 1658' FEL, Sec.15, TllN, R14E, UM 15-16 At Total Depth 11. Field and Pool 1020' FNL, 1147' FEL, Sec.15, T11N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 71' RKBI ADL 28306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/06/8# 06/25/84 ,~/~ ~/~ N/A feet MSL N/A I 06/27/84 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11891'MD,8845'TVD 11826'MD,8819'TVD YES [] NO I~X 2247 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Ca], CBL, Gyro 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# H-40 Surf 80' 30" 1910# Pol eset 13-3/8" 72.0# L-80 Surf 2495' 17-1/2" 1900 sx Perm "E" + 400 ;x PF "C" 9-5/8" 47.0# L-80 Surf 10850' 12-1/4" 500 sx Class "G" + 300 .x PF "C" 7" 29.0# L-80 10496' 11848' 8-1/2" 380 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2" 10560' 10~451 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. , DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .. N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIo I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA .. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0il & Gas Cons. c0mmissi0r, Anch0r~ge Form 10-407 JMM/WC31 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~t 30. ~ - GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad]er'ochit 10,900' 8:351 ' N/A Top Zone :3 11,124' 8483,' Top Zone 2 11,254' 8555' GOC 11,534' 8696' Top Zone lB 11,622' 8736' Base Sadlerochit NOT REA(HED 31. LIST OF ATTACHMENTS Wnr~nv~r W~.I 1 H~ ~i~.nrv 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Associate Engineer` Signed ~ ~ Title Date 2-/-~:~'" INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing 'the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "iltlt~l~Rel~e~t'' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sledding Should.be summarized on the form giving inclusive dates only. District Field Alaska JCounty, parish or borough North Slope Borough lease or Uni! 'hue ADL t/28306 Completion IState Alaska Well no. 15-16 Prudhoe Bay Auth. or W.O. no. AFE 203165 Nab@rs 22E Operator ARCO Alaska, Inc. Spudded or W.O. begun Date ~Hour Complete 11/27/84 J 1200 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. IAFICO W.I. Prior status if a W.O. 21.66% 11/18/84 thru 11/27/84 11/28/84 11/29/84 11/30/84 12/01/84 thru 12/03/84 12/04/84 12/05/84 12/06/84 Rig repair & moving rig. 7" @ 11,848' 9.0 Brine Accept rig @ 1200 hrs, 11/27/84. RU lub, pull BPV, bled press off well. Instl BPV. ND tree, NU BOPE. 7" @ 11,848' 9.0 NaC1 Brine NU BOPE, pull BPV & prep to tst BOPE. 7" @ 11,848' 11,826' PBTD, Tst'g Hydrl 9.0 NaC1 Brine Tst BOPE to 250/5000 psi. 7" @ 11,848' 11,826' PBTD, PU 5" DP 9.0 NaC1 Brine Tst Hydrl to 250 psi/3000 psi, NU choke line. Pull tbg hgr to flr. Displ crude f/ann w/782 bbls, 9.0 ppg brine. Pull 4½", 12.6# L-80 IPC tbg. Chg top & middle rams to 5", tst to 3000 psi. RIB, PU 5" DP. 7" @ 11,848' 11,826' PBTD, POOH w/PBR barrel 9.0 NaC1 Brine RIH, PU 5" DP, tag fsh @ 10,422' & latch. Set grapple & rotate off BOT latch. Circ & cln brine, POOH w/PBR barrel & latch. 7" @ 11,848' 11,826' PBTD, POOH w/pkr assy 9.0 NaC1 Brine POOH w/PBR bbl & BOT latch. MU TSA mill'g tls, RIH, mill pkr, CBU, POOH w/pkr assy & tailpipe. 7" @ 11,848' 11,826' PBTD, Filter brine 9.0 NaC1 Brine POOH w/pkr assy & tailpipe & LD. Chg middle rams to 3½" &tst; OK. PU wshover shoe, RIH, tag fill @ 11,540'. PU Kelly. Filter brine. The above is correct Signature For form preparation and distri~l~,~'~'''' ° ~e Procedures M~u~, ~ctl~ 10, Drilling, Pages ~ ~d 87. Drilling Superintendent O0~,~miSSil~-irnber .Il daily wall history fo~ms consecutively Alaska Oil & Gas Cons. lc, they ~re prepared ,or each well. /,,r:chorage IPfge no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final' Report" on the first Wednesday after allowable has been assigned or well is Plugged, ADandoned. 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 Alaska IWell no. 15-16 District County or Parish Alaska Lease North Slope Borough Field or Unit Prudhoe Bay ADL #28306 Auth. or W.O. no. T t e AFL 203165 Completion Nabors 22E Operator ARCO Alaska, Inc. Spudded or W.O. begun A.R.Co. W.I. 21.66% Date 11/27/84 Complete Date and depth as of 8:00 a.m. 12/07/84 12/10/84 Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our { Prior status if a W.O. I 1200 Hrs. 7" @ 11,848' 11,826' PBTD, Wsh ~ rm to btm Fin filtering brine, wsh & rm f/11,540'-11,778', rev circ & tag btm, POOH, stand back 5 stds; stuck. PU Kelly, pmp out of hole, LD singles until clear'g TOL, POOH, rec'd jnk. MU globe bskt/boot bskt, RIH, break circ & begin wsh'g & rm'g. 7" @ 11,848' TOL @ 10,496', 11,821' PBTD, RR Wsh & rm f/11,778' - 11,821', circ hole cln, POOH, LD DP. Chg rams to 4½" & tst. RU & rn 252 jts, 4½", 12.6# BTC tbg w/tbg tail @ 10,560.21'. ND BOPE, NU & tst tree to 5000 psi; OK. Displ tbg to crude, leaving diesel caps on tbg & ann. RIH, pull dummy SSSV. RIH w/std'g vlv, press up on ann to 1500 psi f/15 min to tst pkr; OK. RU lubr & set BPV. RR @ 1500 hrs, 12/9/84. New TD Date 1500 Hrs. Old TD PB Depth i1,821' Released rig Kind of rig 12/09/84 Classifications (oil, gas. etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gasTest lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date Title ~.MJJ~ ~w..z~-0_-.~-~,- I 1/21/85 Drilling Superintendent F°r '°rm preparati°n ~t~ dist;ibut'°"--~' RECEIVED see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Alaska Oil & Gas Cons. Cornrnission..umbsr a,, Anchora~e ., they are prepared ' ..... h well. ARCO Alaska, Inc Post Office I~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - December, 1984 Dear Mr. Chatterton- Enclosed are the December monthly reports wells' for the DS 6-11 (Workover) 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw' GRU3/L68 Enclosures following 2X-9 2X-10 263-4944. RECEIVED JAN Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ?-"-... STATE OF ALASKA "-" ALASKA t_ _ AND GAS CONSERVATION CO~,,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation)l~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21115 854' 4. Location of Well atsurface FNL, 165' FWL, $ec.22, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71 ' RKB I6. Lease Designation and Serial No. ADL 28306 For the Month of. December ,19 84 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 15-16 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 1200 hfs, 11/27/84. ND tree. NU BOPE. Test same. Displaced well to NaC1. Pulled 4~1/2" tbg. Pulled PBR barrel. Milled pkr. POOH w/same. Washed & reamed to 11,821'. Run 4-1/2" tbg w/tail @ 10,560', pkr @ 10,451', & SSSV @ 2247'. ND BOPE. NU tree. Displace tbg to crude. Secured well & RR @ 1500 hrs, 12/09/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld csg set @ 80'. Installed w/1910# Poleset. 13-3/8"", 72.0#/ft, L-80, BTC csg w/FS @ 2495'. Cmtd w/1900 "E" & 400 sxs PF "C". 9-5/8", 47.0#/ft, L-80, BTC csg w/FS @ 10,850'. Cmtd w/500 sx Class "G" cmt & 300 sx PF "C" cmt. 7", 29.0#/ft, L-80, BTC csg f/10,496' - 11,848'. Cmtd w/380 sxs Class "G" cmt. 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN ! 5 ]985 Alaska 0il & (]as Cons. C0mmis~i0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report ;¢n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ~:nrm ~n~n4 DRN/MR95 Submit in duplicate ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date- July 8, 1985 Reference· ARCO Pressure Surveys 5-8 Static Gradient 5-11 Static Gradient . / 16-11 PFO 5- 31-85 'Ot i s 5- 31-.85 Ot i s 5_ 31-85 Camco 6-16-85 Otis 6-8-85 Camco Camco 17-5 PBU .- 5-29/30-85 as receipt of data Received by Pam Lambert ATO 1429C Trans 193 AlaSka OJi & L~as u~,,,~. Oommission Anchorage Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Sohio State of Alaska Texaco A'n c: h o i" a :::j e, A I. a s- k a ':?"¢ 5: i 6:, Oil & b:_-,o t]:,),qS. Conlmission i) J: ~i-." 'T' F.: i i.)U T ]; (:)i"--i ARCO Alaska, In""--'" Post Office ,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 8, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 15-16 Completion Report Dear Mr. Chatterton: Enclosed is the Completion Report, Daily Drilling History, and two copies of the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4610. Sincerely, T. L. Fithian Area Dril ling Engineer TLF/JMM/tw JMM/L11 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK. L AND GAS CONSERVATION ~ MISSION WELL COMPLETION OR RECOMPLETION FIIEPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21115 4. Location of well at surface TIOJ'~ 9. Unit or Lease Name 854' FNL, 165' FWL, Sec.22, T11N, R14E, UN ~ VE,'~,~Ft~D ~ Prudhoe Bay Unit At Top Producing Interval lSurf.~~,i' '~ 10. Well Number 1706' FNL, 1658' FEL, Sec.15, T11N, R14E, UN ~/ 15-16 At Total Depth 11. Field and Pool 1020' FNL, 1147' FEL, Sec.15, T11N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKB ADL 28306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/06/84 06/25/84 06/27/84 N/A feet MSL 1 · 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11891'ND,8845'TVD 11826'MD, 8819'TVD YES [] NO []I 2227 feetMDI 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL, Gyro 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# H-40 Surf 80' 30" 1910# Pol eset 13-3/8" 72.0# L-80 Surf 2495' 17-1/2" 1900 sx Perm "E" + 400 ;x PF "C" 9-5/8" 47.0# L-80 Surf 10850' 12-1/4" 500 sx Class "G" + 300 ;x PF "C" , 7" 29.0# L-80 10496' 11848' 8-1/2" 380 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 4-1/2" 10544 ' 10437 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · · , . ,-'.- - /-. -r -.~.r-.:.,r~ -.,,~- 1.-~ , .~ Form 10-407 Submit in duplicate Rev. 7-1-80 JMH/WC25 CQNTINUED ON REVERSE SIDE 29. ~. 30. GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10,900' 8351 ' N/A Top Zone 3 11,124' 8483' Top Zone 2 11,254' 8555' GOC 11,534' 8696' Top Zone lB 11,622' 8736' Base Sadlerochit NOT REA(NED 31. LIST OF ATTACHMENTS Drillino History. Gvroseooie Survev (2 copies) 32. I hereby certify ~hat the foregoing is true and correct to the best of my knowledge ~"Z~,~' Area Drilling Engr. Signed_ Title Date · · · INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form fOr each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 '~ ~~andG--~mp~y A V Well History- Initial Report- Dally laal~ie~l=::i~mpare and ~ubmlt the "l~tlai Repe~l' on the flint Wednesday after a well Is spudded or wod<over operations are started. Dally: 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 203165 lCou.nty, perish or borough North Slope Borough Lease or Unit ADL #28306 Title Drill· Complete & Perforate IState Alaska IWell no. 15-16 Operator ARCO Alaska, Inc. Spudded or W.O. begun IOate IHOur Spudded 6/06/84 1530 Hrs. Date and depth as of 8:00 a.m. EEViSED PEk Ji~ 6/07/84 Complete record for each day reposed ~O~isON 20" @ 110' I^RCO w.,. 21.66% Prior status if a W,O. 6/08/84 6/09/84 to 6/11/84 6/12184 6/13/8Z~ 1843', (1733'), Drlg Wt. 9.6, PV 15, YP 47, PH 8, WL NC, Sol 9.5 NU diverter sys. Accept rig @ 0730 hrs, 6/6/84. 1530 hrs, 6/6/84. Drl 17½" hole to 1843'. Spud well @ 13-3/8" @ 2495' 2520', (677'), NU BOPE Wt. 9.6, PV 15, YP 66, PH 8, WL NC, Sol 9.5 Drl 17½" hole to 2520', CBU, TOH f/csg. RU & rn 62 its, 13-3/8", 72#, L-80 BTC csg w/FC @ 2414', FS @ 2495'. Cmt w/1900 sx PF "E" @ 12.3 ppg. Tail in w/400 sx PF "C" @ 15.6 ppg. Displ using rig pmp. CIP @ 2230 hrs, 6/7/84. ND 20" diverter, NU BOPE. 13-3/8" @ 2495' 6146', (3626'), Drlg Wt. 9.1, PV 5, YP 5, PH 8, WL NC, Sol 5.7 Fin NU &tst BOPE. TIH w/jet BHA, tst csg to 1500 psi. DO cmt, FC, FS + 10' new hole. Conduct formation leak-off tst to 11.8 ppg EMW. Drl, jet & surv 12¼" hole to 6146'. 2495', Assumed vertical 2675', 4.6°, N32E, 2674.85 TVD, 7.18 VS, 6.12N, 3.83E 3047', 10.4°, N17E, 3043 TVD, 53.32 VS, 51.81N, 19.81E 3536', 16-3/4°, N25E, 3518 TVD, 165.83 VS, 155.50N, 69.37E 4581', 48-1/2°, N34E, 4393 TVD, 712 VS, 616N, 369E 5129', 51°, N34E, 4747 TVD, 1129 VS, 962N, 603E 13-3/8" @ 2495' 7139', (993'), Drlg Wt. 10.1, PV 9, YP 2, PH 9.5, WL 12.4, Sol 2+ Drl & surv 12¼" hole to 7139'. 5651', 51°, N38E, 5076 TVD, 1534 VS, 1291N, 842E 6141', 51-1/2°, N39E, 5383 TVD, 1917 VS, 1590N, 1079E 669'9',' 52-1/2°', N42E, 5726 TVD, 2356 VS, 1924N, 1365E -_ 13-3/8" @'2495' 7919', (780'), Drlg Wt. 10.2, PV 11, YP 5, PH 9.5, WL 7.0, Sol 13 Drl & surv 12¼" hole to 7919'. 7044' 52-1/2° N40E, 5936 TVD, 2629 VS, 2131N, 1545E , · 7354' 52-3/4° N41E, 6124 TVD, 2876 VS, 2318N, 1705E 7727' 53-1/4° N40E, 6349 TVD, 3173 VS, 2544N, 1898E The above is corr~t Signature ~ ,..~.V . Date sc-J l. 6/28/84 ]Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Number all drill stem tests sequentially. Attach description of all cores. W6rk performed by Producing Section will be reported on "Interim" sheets until final '] /.nalr-,lctiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. %ompletion. 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 whichoil string is set. Submit weekly for workovers and following setting of oil string until completion. Prudhoe Bay Date and depth as of 8:00 a.m. District ICounty or Parish [ State Alaska North Slope Borough Field ILease or Unit #28306 I Complete record for each day while drilling or workover in progress 6/14/84 6/15/84 6/16/84 thru 6/18/84 6/19/84 6/20/84 13-3/8" @ 2495' 8935', (1016'), Drlg Wt. 10.4, PV 11, YP 5, PH 9.6, WL 7.4, Sol 13.5 Drl & surv 12¼" hole to 8935'. 8101', 53°, N40E, 6573 TVD, 3472 VS, 2773N, 2090E 8536', 52-1/2°, N39E, 6837 TVD, 3818 VS, 3040N, 2310E 13-3/8" @ 2495' 9709', (774'), Mx SFT pill Wt. 10.4+, PV 18, YP 10, PH 10, WL 6.0, Sol 14 Drl & surv 12¼" hole to 9709', TOH, chg BHA. TIH to 7362' stuck, jar up & dn. 8972', 51-1/2°, N40E, 7105 TVD, 4162 VS, 3306N, 2529E 9436', 50-1/2°, N38E, 7397 TVD, 4522 VS, 3586N, 2756E Alaska IWell no, 15-16 , pipe 13-3/8" @ 2495' 10,722', (1013'), Drlg Wt. 10.6+, PV 16, YP 9, PH 11.5, WL 4.4, Sol 15 Jar pipe loose, rm 7331'-7438', bridge @ 7642'. Rm 7610'-9709' drl 12¼ hole to 10,238', TOH, stuck pipe @ 2782'. Spot Lub 106 pill, jar dn, pipe free. Spot SFT pill. TIH, drl to 10,498', started taking gas cut mud ret's. C&C mud to 10.6 ppg, drl to 10,722'. 10,161', 45-1/2°, N40E, 7882 TVD, 5061VS, 4005N, 3095E 10,499', 47-1/2°, N41E, 8114 TVD, 5306 VS, 4191N, 3254E 13-3/8" @ 2495' 10,865', (143'), C&C hole Wt. 10.7, PV 11, YP 4, PH 11.5, WL 5.2, Sol 15 Drl 12¼" hole to 10,853', C&C f/logs. RU & rn DIL/SP/GR f/10,846' WLM to 2495'. Drl to 10,865', C&C f/9-5/8" csg. 10,793', 50°, N39E, 8309 TVD, 5527 VS, 4360N, 3396E 9-5/8" @ 10,850' 10,865', (0'), MU 8½" BHA Wt. 10.7, PV 12, YP 5, PH 11.0, WL 5.2, Sol 15+ C&C hole f/csg. RU & rn 272 its + 2 flt jts, 9-5/8", 47#, L-80 BTC w/FC @ 10,775', FS @ 10,850'. Cmt w/500 sx C1 "G" @ 15.8 ppg. Displ cmt w/779 bbls drlg mud using rig pmp, bump plug. CIP @ 0415 hrs, 6/20/84. LD 12¼" BHA. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 6/28/84 Drilling Superintendent %RCO Oil and Gas Company Daily Well History--Interim ~4ructionI: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. um[~er all drill stem tests sequentially. Attach description of all cores. Work p~rformed by Producing Section will be reported on "Interim" sheets until final 3rnpTetion. 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) n Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. 'istrict ICounty or Parish iState . Alaska North Slope Borough ie~d ILease or Unit t/28306 I Complete record for each day while drilling or workover in progress Prudhoe Bay 6/21/84 6/22/84 6/23/84 thru 6/25/84 ate and deptl~ s of 8:00 a.m. 6/26/84 6/27/84 Alaska Well no. 15-16 9-5/8" @ 10,850' 11,116', (251'), Wt up mud Wt. 10.6, PV 12, YP 4, PH 11.0, WL 4.8, Sol 13 RIH w/8½" BHA, tag cmt @ 10,758', DO cmt, FC @ 10,775', cmt to 10,892', tst 9-5/8" csg to 3000 psi; OK. DO FS @ 10,848' + 10' new hole. Conduct leak-off tst to 12.5 ppg EMW. Drl 8½" hole to 11,116', circ gas cut mud, raise mud wt f/10.4 ppg - 10.6 PPg. 9-5/8" @ 10,850' 11,549', (433'), Drlg Wt. 10.6, PV 12, YP 6, PH 11.0, WL 4.8, Sol 14 Drl 8½" hole to 11,277', lost 1000 psi surf press, TOH, wshout in extended nozzle. TIH, rm 11,179'-11,277', drl to 11,549'. 9-5/8" @ 10,850' 11,891', (342'), CBU Wt. 10.6, PV 18, YP 5, PH 11.0, WL 5.4, Sol 14 Drl 8½" hole to 11,750', 10 std short trip, C&C f/logs. Rn DIL/BHCS/SP/GR f/11,670'-10,850, Sadlerochit base not logged. Rm 11,645'-11,750', drl to 11,879', CBU. RU & rn DIL/BHCS/SP/GR f/11,852'-10,851'. Log LDT/CNL/GR/CAL f/11,872'-10,826', RD Schl. TIH, rm 11,834'-11,879', drl rathole 11,879'-11,891', short trip to 9-5/8" shoe, CBU. 7" @ 11,848' 11,843' 7" Shoe, PU 4-3/4" DC/3½" DP Wt. 10.6, PV 10, YP 5, PH 11.0, WL 5.6, Sol 14 Chg & tst rams to 3000 psi. RU & rn 31 its + 1 double short jt, 7", 29#, L-80 BTC csg w/FS @ 11,846', FC @ 11,803', LC @ 11,719'. Stuck lnr @ 11,848' while TIH w/shoe. Pmp Lub 106 pill. Gas cut mud while circ'g, SI well & circ out gas cut mud, welt stable w/10.6 ppg mud. M&P 380 sx Cl "G" cmt w/5% KC1, 1% CFR-2 & .3% Halad 24. Displ cmt w/rig pmp, bump plug. CIP @ 0025 hrs, 6/26/84. Chg rams & tst to 3000 psi. 7" @ 11,848' 11,826' PBTD, Circ @ PBTD Wt. 10.4, PV 13, YP 6, PH 11.5, WL 13.4, Sol 9 RIH w/9-5/8" csg scrpr to 10,011', wsh to TOC @ 10,345'. Drl cmt stringers to 10,400', soft cmt to TOC @ 10,492', CBU, TOH. TIH w/bit & 7" csg scrpr, drl cmt stringers 10,507'-10,539', wsh to 10,571', drl cmt to FC @ 11,799', tst csg to 3000 psi; OK. DO FC & cmt to 11,826', circ. he above is correct ;ignature ~r form preparation and distribution ~e Procedures Manual Section 10, rilling, Pages 86 and 87 Date ITitle 6/28/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report . InalmcUmta: Prepare and submit the "Final RePOrt,, on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fbtal Rel~" should be submitted also when operations-are slle4~ended.for an indefinite or appreciable length of time. On workovers when an official test is not required'upon completion, report completion and representative teat date~ In blocks provided. The "Final RaporC' form may be used for reporting the entire operation if space is available. IAccounting cost center code State Alaska Well no. 15-16 District ~County or Parish Alaska I North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL #28306 Auth. or W.O. no. ~Title AFE 203165 I Drill, Complete & Perforate Operator I A.R.Co. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun J Date , Spudded I 6/06/84 Date and depth as of 8:00 a.m. 6/28/84 6/29/84 6/30/84 7/18/84 Complete record for each day reported I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our I Prlor status If a W.O. 1530 Hrs. 7" @ 11,848' 11,826' PBTD, POOH w/CBL 9.8 NaC1 Tst csg to 3000 psi. Spot 40 bbls 10.2 BridgeSal pill across Sadterochit, displ pill w/9.8 ppg brine. RU & rn GCT gyro to 11,775' WLM. Rn CBL f/11,785'-10,400' WLM, POOH. 7" @ 11,848' 11,826' PBTD, Rn'g 4½" tbg 9.8 NaC1 Chg rams to 4½" & tst. RU & perf 11,777'-11,767' & 11,757'-11747'~ 11,757'-11,767', 11~737'-11~747',v 11,727'-11,737', 11,717'-11,727' @ SPF/90 phasing. 7" @ 11,848' 11,826' PBTD, RR .~.!~Sk~l 0ii ~ (~ ~'~.'-'- Crude ;~]]V~3'~e Rn 252 jts, 4~", 12.6¢, L-80 PC=0 BTC csg w/Tbg Tail 8 10,544', BOT PBR ~ 10,418', 3-~ Pkr ~ 10,437'. ~ BOPE, NU & tst tree to 5000 psi.. Displ well w/564 bbls crude. ~ ~ 0700 hrs, 6/30/84. Arctic Pak w/300 sx PF "C" 15.6 cmt and 125 bbls lightweight Arctic Pak. Did TD I New TD I PBDepth 11,891' (6/25/84) 11,826' Released rig ~ Date ~ Kind of rig 0700 Hrs. I 6/30/84 J Rotary Classifications (oil, gas, etc.) -' Of~l . Producing.rn~thod Official reservoir name(s) Flowing Sadlerochit Potential test data Type completion (single, dual, etc.) -Single Well no. Date :Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is~co~ :t Signature~/_ t ~r -- I Date -..-- ,~,~ 05C. For form preparation and distribution, s..?.e...Proce_d u res _M_ an u .al,__Section 10, 7/18/84 ITM Drilling Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY r~ UIDANCE ~]ONTINUOUS I-fi OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY DRILLSITE 15-16 PRU~)HOE BAY. NORTH SLOPE ALASKA Job Reference No. 69338 Logqed By: Date 27-JUN-84 Computed By: R. Sines GCT DIRECTIONAL SURVE~ CUSTOMER LISTING A'£LANI'IC ~ICHFI~bD COMPANY 15-10 SURVEY DATE: 24-JUL-B4 ENGINEFR: RATttEt{T METitOOS O~' Cf{I~PuTATION ToOL LOC~'fION: I"Ab, GF_,~TIAt,- avera.qeQ oevlat, io~ and ay. imutl] RTH 38 C ri i','~ P o 9' A T I r) N kTLANTIC RICHFIELD )RfLI, SITE' 15-16 )RUDH(tE ~]A~ {ORT[i SLOPE, ADASKA CuPPASY IN'IEI{PULATED VaL, UEb ~'OF, TRUE ~.ASURED VERTICAl,, DEPTH DEPTH VERTTCAL DEVIATLOi'~ AZ£~fUTH DEI')TH DEG M'IN DF,(~ M.lh 0 100 200 300 400 500 600 700 800 900 OO 0.00 O0 100.00 O0 200,00 O0 299.99 O0 400.00 O0 499.99 O0 599'99 O0 699'99 00 799,99 O0 699,98 -71.00 0 0 N U 0 E 29.00 0 0 S 1.2 27 W 129'00 0 0 S 0 5 E 22H,.99 0 34 S 2 b7 E 329,00 0 34 S 4 29 W 42~ ,99 0 34 S 1 49 E 520.99 0 34 $ 10 22 E 62H.q9 0 34 $ 5 21 F 72~.99 0 0 S 3 32 W 828,9~ 0 0 $ 61 1 E [000 Ob [tO0 O0 [~00 O0 [300 O0 [400 Ob [500 O0 600,00 700,00 tOO0,O0 [go0.o0 999.9a lO99'9e 1199,9a 1299.~7 1399.9~ 1499.9~ ~599~7 1699.97 1.799,97 1899,97 928.9~ 0 24 W ~e 22 E 1028,98 O 34 N 80 48 E 1128.98 O 34 S [t9 2R F 122R.97 0 0 $ 88 lq E 1328,9b O lq $ 86 17 E 1428,9~ 0 34 5 ~'I 45 E 1528,97 0 34 $ 65 33 E 1628,97 0 34 S 61 44 E 172~.97 0 10 $ 38 30 E 1828'97 0 0 S 29 52 E 2000,00 2100,00 2200.00 2300 00 2400 OO 2500 OU 2600 00 2700 O0 2800.00 2900,00 1999.97 2099.97 2199.96 ~299.95 2399,94 ~499.93 2599,93 7099.81 2799.32 ~Bq~,bl 1925~.9'1 0 0 S 83 16 E 2028,q7 O 34 ~ 79 25 E 2128,9o O 34 ~ 75 26 E 2?28°95 0 34 S 5'7 32 ~ 2328,94 I 8 S 2~ 52 E 242~.93 0 34 S 1~ 3~ E 2528.93 0 ]4 S 63 22 E 2728,32 o 27 N lb 15 E 2827.5I 8 1 ~ o 52 ~ ~000,00 ]100.00 3200 O0 3300100 3400 00 3500 O0 3600,00 3700,00 3BO0.OO 3900.00 2997.J~ 3095,b9 ~193.3~ 3290.78 339t.85 34~4.23 3579.'78 3673.7(, 3 'l 65.9 ~1 3u5b,.ll 2926.31 9 ~4 ~ 10 15 E 3024.69 10 51 ~ 22 45 E 312~.~ 13 O ~) 33 48 E 3219.78 13 10 ~ 2b 14 E 3316.~5 14 46 N 23 21 E J413,~3 16 20 ~ 2b 14 E 3508,7~ 1~ 37 N 9~ 21. E 360~,70 21 10 ~ 30 20 E 3694,9b 73 53 h 31 30 E 37~5,11 ~'l 27 N 30 56 E DATE: 10-$~:P-84 k;V~N 100 V~RTICAb DUGb SECTION SEVg FEET DEG/ 0,00 '0.17 :o,57 0.93 -1'41 '2,00 '2,72 -3.28 :3,73 3.80 -3.67 -3.25 '2,43 -2.18 '1,80 '1,,49 '1.34 '1,32 -1,4b CF M'~A~U EG RF. CT RJTY NORT 1 O0 f' DATE OF SURVEY: 24-JU6-84 KE66¥ BUSHING EbEVATION; ENGINEER: RATHERT RED DEPTH 71.00F~ ANGIJbA~ COORDINATF..6 HORI~:. DISPARTURE ti/8OUTH gAST/~EBT DI~T, AZIMUTH gET FEET FEET:~, HXN O.OO O.O0 N 0,00 E 0 U,IO 0.15 S 0,09 W 0 0,09 O,b2 S 0,14 W 0 0,41 1,10 $ 0,11 W 1 0,19 1,10 $ 0,12 W O,le 2.51 $ 0,14 W 2 0.08 3,43 $ 0,03 W 3 0,32 4,26 $ 0,12 E 4 0,16 ~,~1 5 0'08 E 4 0,19 b,Ol S 0,14 E 5 7 $'""32 44 ~ ~0 01 5 1 36 ii 0.23 0.19 0'69 U.ll 0.25 O,11 0.25 0,18 0,27 0,19 5,07 S 5 32 ii 5,09 S 12 9 E ~,36 $ E 5,58 $ ' E 6,39 $ 38 25 E 6,97 8 40 47 E 7,51 $ 41 47 E 7,95 ~ 4~ ~8 Z 5,04 S 0,49 4,98 $ 1,07 4.86 $ 1.66 4,86 $ 2.25 4,U9 $ 2.70 4,91 S 3,34 b,O0 S 3,97 5.28 S 4.55 b,60 S 5,01 b,97 $ 5,25 5,40 g 8,23 $ 40 57 i 0,15 E B,62 S 45 30 E 7,16 E 9,18 $ 51 12 g 8,09 E 9,93 $ 54 35 E 8,87 E 11,22 S 52 14 E 9 47 E 12,62 $ 48 39 ~ 11.78 E ~2,96 ~ 65 !9 ~ 14,82 E 15,31 N 75 28 17,22 E 23,72 N 46 3{ E 36,99 N 31 8 E 54,36 a 26 0 E 75,63 N 27 20 E 98,22 N27 52 g 122,21 N 27 I E 14B,84 N 26 28 E 178,30 N 26 29 £ 212,57 N 26 59 E 251,00 N 27 ]6 £ 294,19 N 28 6 £ '1.,5b 1,04 b,22 'O.9b 0,32 b,04 '0,11 0,25 5 75 0.47 0,78 5:76 0,07 0,16 '0,72 0,38 8.34 '1,19 3,83 9,25 3.01 2,6q 5.41 12 17 1,81 3,84 23~4b 1,97 lb,31 36.72 2.75 31,07 53,1b 5,85 4B,B5 74,30 O,b3 67,17 96,6~ 1,45 8b,83 119,94 1.97 108.87 145,79 1,81 133,23 174.65 4,00 159.57m 208,59 2,56 189,41 246.81 2.52 222.41 289,73 3-,87 259.4U 19,13 23,B4 34,'15 45,91 55,54 66,J7 79,b4 9b.49 11b.34 13U,63 ATbANTiC RICiiFIELD Cu~PA~Y DRILh :SITE 15-16 PRUDt~OE iiAi NORTH ~[,,UPE, AbA~KA l)A're; UF $URVE'I: 24-dUb-84 K~hI~Y BUSHING EbEVA?IONI iN%'EhPULATE[) VAI, UEG b'OH ~VEN 100 FEET UF MEASURED DEPTh TRUE 'SUB o ~,,, A EA~URED VERTICAl,, VER'.I.']CAb D[<V]ATIF~t~ AZIMUTH DEPTH DEPTH DEPTH 4100,00 402~,00 3957.00 33 13 4200'00 4110.05 q039'05 36 21 4300 00 4188 57 .t117.57 40 5 4400:00 4262:95 4191.,95 43 40 4500 O0 4334,26 426~,20 45 49 4600 O0 a402.08 433~,08' 49 2 4700 00 4465,08 43~4,0h 52 R 4800 O0 4526.3! 4455.31 52 g 4900 OO 458'1,Ol 4516.61 52 0 PAGE 2 5000,00 4049,56 457~,50 51 33 100,00 4712,13 4641.13 50 59 ~200,0U 4775,05 4704,05 50 b9 5300.00 4837,95 4706,95 50 59 5400 O0 4900,54 482q,54 5~ 59 5500:00 4963.b~ 4~92 61 50 59 5600 O0 5026,78 4955~7~ 5u 59 5700~0U 5089.~5 5018,85 50 59 5800,00 5153.0q 50~2,09 50 29 5900,00 5215,99 5145.99 50 16 V£RTICAL DOGbEG RECTANGUbA~ COORDINATES HORIZ, DEPARTURE SECTION SEV~RiT~ NO~TH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/100 FEEl FEET F~EX : i. OEG MIN 6000 O0 528U.45 52U9.45 5U 59 6100 6200 6300 6400 6500 6600 5700 680O 69O0 00 5~42,~5 5271.95 51 33 O0 5404.82 5333.~2 52 8 O0 5465.85 5394.~b 52 ~2 OO 5526'20 5455.20 52 42 OO 558o,38 55i5,38 52 52 O0 5045,41 5575.41 53 g Oo 5700,9~ 56~5.92 52 ,,2 00 5767.59 5696.69 52 42 Oo 582~.20 5757,~0 52 42 H 30 56 E 358,25 {~ 31 20 E 391,02 N 32 30 E 447,85 ~: 32 39 F 509,45 N 32 30 E 575,99 ~! 32 30 F 645,79 N 33 41 E 718,99 ki 33 48 f3 796,41 5! 33 48 E 875.27 N 3,J 48 E 954,00 7000,00 5888.73 5017.73 52 42 7100,00 5949'29 5878,29 52 42 7200,00 600~.~7 bg38.8'1 52 47 7300,00 6070.20 599q,20 52 42 7400,00 613o.67 o059.6'1 5] 17 7500,00 61q0.60 5119.80 52 42 7600.00 6250.91 v179.ql ~ 17 7700 O0 6311.06 0240.0~. 53 i7 7800:00 6571,U0 b300.Ou 53 17 7900.00 6430-86 0359.g0 53 17 33 48 E 16)32,34 34 22 E 1110.10 34 22 F 1187,71 35 31 E 1205,35 35 31. E 1343,25 35 39 E 1420.7~ 3'7 18 F 1,498,27 38 23 E 1575,86 3~ 57 E ~663,34 3~ 57 E 1730,24 h' 39 32 Fi 1807,51 ~) 3~ 50 E 18U5,55 N 40 40 E 1954,04 N 41 15 F 204~.17 N 41 27 E 2122.77 5' 41 q9 E 220~,45 N 41 49 E 2282,27 ~; 41 49 E 2361.72 N 41 49 E 2440,97 h~ 4i 15 E 2520.44 N 41 15 g 2599,91 N 40 45 E 2679,38 ~ 40 qO F 275~,83 N 40 40 E 28~8,49 r,i 40 ~0 F~ 2918.06 N 40 40 E 2997,8~ ~ 40 6 F 3077.73 N 40 6 E 3157.5~ ~' 40 6 r 3237.50 ~ 40 6 Fi 3317.63 2.72 2,84 3,52 2.54 2.90 4,58 1,20 0.41 1.10 346,98 N 191,19 E 396 17 N28 51 E 395, ~0 N 221.40 E 453 04'7,59 N 254,82 E 515 503,72 N 291,07 E 581 562,07 N 329,00 E 651 024.14 N 369.24 E 725 080,06 N 412,41 E 802 754,25 N 456.58 E 881 8~9,65 N 500,~1 E 960 04 N . E ° 0 18 E ~8 N ~30 36 ~ 1 I N 3o 54 E ~ 58 a 31 11E ~o N 31 24 E 0,99 0.29 0,?0 0.86 1,04 1,93 0,44 1,06 0.56 0.73 884.97 N 54~,42 E 1039 02 N 31 35 E 949.52 N 588,08 E 1116 97 N 31 46 E 1140o~6 N 721,96 E 1350 11' N 32 19 E 120~.18 N 765.81E 1427 60 N 32 29 E ~2~.21 N ~13,3~ E 1504,92 N 32 42 E 1327,56 N 860,82 E 1552,22 N ~ 57 E 13"7.95 N 909,36 E 1659,32 N 3] ~) E 1447,71 N 957,78 E 1735,86 N 33 29 E O 74 1[08 0.04 0,46 0,56 0.98 0,62 0,34 1507.57 N 1006,67 E 1812,77 N 33 43 E 1567,78 N t,)56,~5 E 1890,45 N 33 58 E 1027.75 N 1107.08 E 196 55 NS' 34 13 E 1~81.54 N 1159.07 E 204~!25 N 34 28 E 1747.33 N 1211 82 E 212 42 N $4 44 E 1264:9~ E 220 70 N 34 59 E 1~00,91 ~ 1865.40 N 1318 46 £ 2285.12 N 35 14 6 1925.16 N 1371:51 E 2364,24 N 35 27 ~ 1985 01 N 1424.39 E 2443,18 N 35 39 E 2044:59 N 1477.19 E 2522~39 N 35 50 E O.J7 0.22 ! 39 0~16 1.09 0,42 0,60 0,37 0,31 0,54 2104.28 N 1529.87 E 2001 63 N 36 I E 2164 22 N 1582.21 E 2680 90 N 36 10 g 2224~27 N 1534.39 E 2760 2284,06 N 1586.48 E 2839 2345.03 N ~738.43 E 2919 24o5,74 N 1790.36 E 2998 2465,59 N 1842,18 E 3078 2527,50 N 1893,88 E 3158 75~.72 N 1945.45 E 3238 2050,07 N 1995.96 E 3318 18 N 36 16 E 69 N 36 26 E 13 N 36 33 £ 83 N 36 39 E 58 N 36 45 E 33 N 36 50 E 24 a 36 55 E 24 N 36 59 E COMPUT~TIOt,i OA'.I'~.]; lO-SEP-84 PAGE DAT~ OF SURVEY: 24-dUb-B4 KELDY BUSHING ELEVATION{ IN'I'EF, PULATIgD YAbUEb I~'OR ~.;VEN 10() FEEl' /dF NEA,iUREL~ PEPTit TRUe: SUB-SEA C[.1URSE AfiU~ED VF'.RTICAI. VERTICAL DEVIATIfi~'~ AZ.i[~LJTh DEPTft DFPTH DEPTH DEG::. NIN bEG VP~RTICAL DOGI~EG SECT1C..h SEVERITY FEET D~G/') O0 000,00 6490.74 6419.74 53117 lO0,O0 6550,77 6479,72 53 17 200 00 6610,~3 65~9.81 :53 ~7 300 00 6670,92 0599.~2 52 53 400 O0 6'131,32 b60o,32 52 42 500 O0 6701,~6 6720,86 52 4~ 600 O0 6853.06 67B2,0~ 152 8 700 O0 6914,,tl 0843,41 51 59 800 O0 6976,09 6905,09 52 8 900,00 7037,U0 6966,80 51 33 N 40 6 g 3397,67 +1 aO 6 ~; 3477.62 N 40 6 E 3557,50 N 40 6 ~ 3637.37 N 40 6 E 3717,02 N 40 6 E 3796,5B N 39 32 g 3875,61 N 39 ~7 E 3454.55 N 40 6 E N 39 32 E 4111,88 O,bl O,b9 0,26 0,50 1,69 0.46 0,69 0,56 ~,~4 IO00,Oo 7099.74 7028.74 51 3.3 ~100.00 7162,01 7091.01 51 33 1200 O0 7224,58 7153.5U 50 59 1300 O0 72B'I.55 7216;55 5059 400 O0 7350,~8 '/~79~68 5025 '500 O0 741445 7343,45 5025 '600 O0 747~5 ~407.45 4~ 50 '700 O0 7543.38 7a72~SB 4910 :800 O0 7609,40 '153[~.40 48 26 '900 O0 7676,29 7605.29 47 42 N 39 32 E 4190.35 N 39 32 E 4208,57 N 38 57 E i346.57 N 38 57 ~ 4424,24 ~ 3~ 40 F 4501,78 N 30 23 E 4578,81 ~,! ]8 23 E 4655.64 N 37 48 E 4731,69 N 37 4a ~] 4806.80 N 38 23 E 4881,13 0,05 1,17 0,~2 U.,90 ,13 0.57 0,85 0,99 1,68 .000 O0 7744.17 '1673,17 4b 57 .100 OU 7~13,29 7747.79 45 39 ,200 O0 7883,53 7812.53 45 15 ,300 O0 7954.01 ';~3.01 45 31 ,400 O0 8023,'76 7967,76 45 52 '500 O0 R092.20 dO21.~O 47 33 ,600 OO 8159,33 8088.33 4~ 7 ,700 O0 ~2~5.07 ~64.0'; 49 50 .800 O0 828B,90 8217,9U 50 46 .900,00 R351.37 ~?U0.37 51 34 N 3~ 23 E 4954.56 N t~ 57 E 5026,82 N 39 63 E b097,9B N 40 6 E blbS,R8 N 40 6 ~ 5240,50 N 40 6 ~ 6313.34 ~ 39 36 E 5387,41 a ~9 32 ~ 6462.74 N 3~ 67 E 5539,71 N 37 %~ 5' 6617.78 0,~1 1.24 0.49 0,~0 0,96 i.23 1.73 1,55 2,03 000 O0 8q11,9~ 8'3~0.0~ 53 2q 100~00 846~,8~ ~398.88 55 34 200 O0 300:00 8580.05 0509.06 57 42 400,00 8631.ol 85u0161 60 9 500,00 600,00 R72G.u5 ~655.85 63 39 700.o0 R769,19 800 O0 nd09.1~ ~7~8.lu &u 27 891:0~ 8845.62 8'1'/4.52 60 27 ~3 37 ~8 E 5697.31 N 37 21 F 5778,83 ~ 30 40 F 5801.89 ~! 3b 5 E 6945.70 ~' 3o 5 ~: o031.33 N 30 2~ g b118.60 N ]b 5 ~ b2~7,6J N 3~ 5 E ~472.6! 1,74 1.~6 0,91. 1,97 1,77 1,~5 3.24 1,~8 0,00 O,OO 71,00 FT ,(.)RTH/fOUT~ EAST/WEST DIS~, AZIMUTH FEET 2{~33,b9 N 2151'652 g 3557,93N'3712 ~94~7 N 203,19 E 363~,74 N ~716 E 2955,61 N 2254.56 E 3717,35 N,,37 20 .E 30lb,b2 N 230b,69 E 379b,87 N 37 23 E 3077,30 N 2356,39 E 3875'87 26 E 3~37,93 N 2407,00 E 3954~77 N 37 29 E 3196.~5 N 2457.~5 E 403~,12 N 37 32 E 3258.76 N 2507;~6 E 4~2,04 N 37 34 E 3379.b6 N 2b07.'16 .E 4268,70 N37 39 E 3439,95 N 2057,14 E 4346,68 N 37 41 E 3500,30 N 2706,04 E 4424 ~4 N ~7 42 E 3660.70 N 2754,~9 E 4501 87 N 37 4~ E 3620,96 N 2802,67 E 4578 90 N ~7 44 E 3~1,20 N 2850,36 E 4655 72 N 37 45 E 3'/41,08 N 2B97,23 E 4731 77 N 37 45 E 3~00,43 N 2943.27 E 4806 88 N 37 4~ E 3058,94 N 2989,11E 4881,22 N 37 45 E 3910,44 N 3034,'/9 g 4954,64 N 37 46 E 3972,84 N 3079,97 E 5026,90 N37 47 E 402'1,07 N 3125,12 E 5090,05 N 37 48 E 40~2,04 N 3170,93 E 5168,93 N ~7 50 E 413b,78 N 3217 19 E 5240,54 N 37 52 E 41c)2,51 N 3264:16 F 5313,37 N 37 54 E 4249,22 N 3311,88 E 5~87,43 N ~7 55 E ) ~307,34 N 3359.85 E 5462,76 N 37 57 E. 43~b,84 N 340~,70 E 5539,72 N 37 58 .E' 4427,~'/ N 3~57,38 E 56X7.79 N 37 59 E 4~90.Ul N 3500.01 ~: 5697.32 N 37 58 E 4555,44 N 3555,71 E 5778,85 N 37 58 E 4o21.56 N 3005.98 E 5861.91 N 37 57 E 4o8~,9'1N 3056.85 E 5945.72 N 37 5b E 475~.14 N 3706,ql E 6031,~6 N 37 55 E 4~?~,59 N ]757,99 E 6118'~4 N 37 5~ E 4~99.~6 N 38~0.77 K 6207.14 N 37 52 E 4972.5~ N 3664,60 E 6297~69 N 37 51E 5~46.~2 N 3918,52 E 6389,30 N 37 49 E 51~t.0] N 3957,68 E 6472,70 N 37 48 ~ C('lt,~ Pu'r A~ 1, C!N uA'i'E ] )RILL 6ITE' 15'lb ~UD~OE aA¥ fORTH SLOPE, ALASKA DAT~ OF SURVEY: K~bbY BO$~IN6 EbE'VATIUN] ENGINEER~ ~AI'HI~RT iNTEHPOLA'r£D VAi,,UE~ FOR EVEN 1000 FE~iT OF PiEASOR~D D~PT TRUE SUB-SEA COURo CAI~URFD VFRTICAL VERTICAL DEVI'ATi[la AZImU'Pti DEPTH DEPTH DEPTH DES 0.00 0,0o -71.00 0 0 ~000,00 g99.9~ 92~,98 0 24 !000,00 1999.97 1928.97 O, 0 ~000.00 ~997.~1 2926.31 9 44 [000 00 3943,32 3~7~.32 31 4 ~000 O0 4649.b6 4578,56 51 33 ~000 O0 52~0.4~ 5209~45 ;50 59 ~000 'OO 5898,73 5817,73 52 ~2 ~000 00 6490,74 ~419.74 53 17 )000 O0 7U99,74 7028,74 51 33 71,00 FT )000.00 7'144,17 7673,1'1 4b b7 LO00,O0 841.1'98 8.]40,98 53 29 L891,00 ~14.5,52 8774,52 6b 27 VERTICAL, DOGLEG K~,C 'ANGULAR COORDINATES HORIZ, DEPARTURE SECTION S~V~RiT'X N[]RTH/S[ILITH EAST/WEST DiST, AZIMUTH FELT D~G/1. O0 FEET FEET F~E~ ~i 0 0 E 0.00 ~i 80 22 ~ -3.67 S 83 16 K -1.56 N !U 15 E 36,72' N ~0 56 E 338.25 N 33 48 E 1032,34 N 39 32 E 1807,51 N 41 15 ~ 2599,91 N 40 6 E 3397.67 N 39 ~2 E 1190,3~ U t8 23 E 4954,56 N 37 48 E 569'1 N ]o 5 E 0472,61 0o00 0,00 N 0,23 b,04 $ 0,49 1,04 b,22 S 5,40 E 8 2,/5 31,67 N 19,13 E 36 2.72 301.45 N 163,74 E 343 U,99 ~8~,9'/ N 544,42 E 1039 0.78 1507.57 N 1006 07 E 1812 , 0,37 2104,28 N 1529~87 E 2601 0,51 2711,35 N 2048,53 E 3398 0.65 3~19,18 N 2557.99 E 4190 0.00 E O.O0,,.,N:?:,,,:~O 0 E E 5 07$ 5 32 E ~40 57 E ~ N31 SE: 30 E lq .31 35 E ) N;i':,36~ I E 50 N 7 E 0.81 1,74 0,00 3916,44 N 3034,79 E 4954,64 4490.81 N 3506.01 E 5697,32 5114,03 N 3967.~8 E 6472,70 N 37 46 E N 37 5~ E N37 48 E l)irtc n: 4a'E Ol : 7Z . 70 ' C ('i ~ p ;j 'r, a T l 0 h T R U E V FRT j CAI.., DEPTH D A T E: 0 O0 71 O0 00 371 O0 471 01 571 O1 671101 771,02 871,02 71 171 2'11 3 '11 471 571. bTl 7 '11 . O0 , uO . O0 , O0 .00 . V(.) FOR WVWN 100 SUB-SEA C()LIPjE VERT.TCAb DEVIAT.i()i~ AZIMUTh DLPI:H DEG M'I~ DEG MIN 971,02 [07},02 L17 ,02 L271,03 L371.,03 L471,02 L5'11,03 L671,03 1771,03 [871,04 97 107 117 12 'l 137 147 157 107 1 'l 7 187 1,VO 1,00 I ,O0 1,0() I ,00 1.00 1 1.0() 1 ,O0 t971 03 ~071~04 ~171.04 2271,05 ~371,06 ~471,07 2571.0~ 267~ 12 2771!51 2872 23 1.97 207 217 227 237 247 257 267 277 287 1.00 1 .O0 1 1.Ut) 1 i,00 1,00 1 9vO,O0 O 0 1000,00 0 34 ll. UO.O0 0 3~ 1200,00 0 34 139o.00 O 0 1400,00 0 34 1500.00 0 34 16V0,00 0 34 1700,00 U 34 i800,00 O 0 2973 33 '89 3279,6~ ~382 59 3486~22 3590,73 3697,11 3805 49 3916:82 297 307 31 't 327 337 3'~7 367 377 387 1,00 1.00 1.VO 1.~0 1.00 1.bO l.u(l 1,'OO lqO0,O0 0 0 2000.00 0 34 2100,00 0 34 2200.0O 0 34 2300,00 1 8 2¢0(),00 O bO 2500.00 0 3a 260n.00 3 36 2700,00 5 49 2~00.00 7 29 V~RTI. CA6 bECTI()N 10-S~P-84 DAT~ OF Su~VE'Y: 24-~0h-84 K~LbY BUSHING E~EYATION: ~NGINEER: RATH~RT F~ET OF SUB-SEA D~PTH I)L}GbEG ~HCTANGUbAR COO3RDINATEM. HORIZ~, D. EPARTURE SgVERII'~ NO~Ttl/SOUTH EA6 /WEST DiMT, A~IMUTH l) g G / 1 O 0 F ~ E T F E g X F E E'T ~:: ::S~:S~:.i DgG M I N 0.00 O,VO 0,0() N 0,00 E -O.Ob O.Og 0,03 S 0,06 W -0.46 0,19 0,48 S 0,14 W -O,R3 0.16 0,95 S 0,12 W '1,25 0,21 1,51 S 0,10 W -1,85 0,19 2,24 S 0,14 W '2,54 0,20 3,1'1 S 0.08 W '3,14 0.31 4,05 S 0,08 E '3,63 0,42 4,OB S O,lO E '3,86 0,37 4,98 S 0,10 E -3.75 O.ll 5,05 S 0,36 E -3.38 0,23 5,0(.) S 0,90 E -2,92 0.10 4,~8 $ 1,48 E '2,53 0,56 4,86 S 2,10 E -2,25 0,18 4,~8 S 2.58 F 1,93 0,20 4,90 $ 3,13 E . '1,55 0,43 4,94 S 3,79 E '1,38 0,17 5,20 $ 4,40 E -1,31 0.43 b.bO S 4,90 E '1,42 0,17 5,88 $ 5,19 E -1,54 0,13 O,lb S 5.36 E '1,17 0,47 6,0'1 S 5,b4 E -0,35 0.22 5,04 S b,~8 E 0.39 0,76 5.06 S 7.~5 F: 0.20 0,28 0,45 S 8,05 E -0.49 0.45 'i,94 S 9.33 E '1,11 0,23 9 07 S 9,77 E 0,97 b,18 7:33 S 1. O,92 E 9,32 1,73 0,~9 N 13,97 E 20,1~ 2,00 12,55 ~ 10,70 E 32.R7 2,47 77,31 N 1~.~5 F 48.77 3,05 4~.50 N 22,28 E og.2U 1.30 62.92 N 31,91 E 92.13 l,b7 ~2,05 N 4~,90 E 115.73 1,46 lO4.~6 N 53.~2 E 142,05 2.00 129,75 N 6%,'13 F 1'11.75 4.03 lbb,~'/ N 70,16 F: 207.56 2,54 188,52 N 95,96 E 249,02 2,39 224.31 N 117,50 E 297,51 3,53 2(,b,21 N 142,65 E PAGE 5 71,00 FX o.o7s7 . 0,50 ~..1~ 25 W 0,96 57 1,52 ~ 3 40 W 2,25 S '3 34 W J,l? 8 1 26 W .4,05 S ! il g 4,69 ~ 1 10 E 4,98 $ I 10 g 5,06 S 4 2 E 5.08 ~ 10 12 E 5,10 ~ 16 54 E 5,30 $ .23 23 g 5,51 S 27 50 g 5,81 S 32 ~2 g 6,23 S 37 30 E 0,81 S 40 12 g 7,37 S 41 42 E 7,84 S 41 25 E ~,16 ~ 40 59 E 8 42 5 43 53 E 9:02 S 49 39 E 9,67 S 54 12 g 10,80 $ 53 16 E 12.25 6 49 36 g 13,~3 S 47 8 E 13,16 $ 56 7 g 14,00 N 86 21E 20.89 N 53 4 E 32,95 N 34 2 E 49,77 N 26 35 E 70,55 N 26 5~ E 93,59 m 27 58 E 117,87 N 27 10 £ 145 O0 N 26 30 E 175:35 ~ 26 28 E 211,54 N 26 58 E 253,22 N 27 38 E 30Z,02 N 28 11E ,TbANTIC RICttFI. ELD ~RILb ~SITF 15-16 'RUDdOE BAY. IORTH ,SLOPE, AbA,SKA PAGE t.)AT~ OF SURVEY: 24-0Ub-84 K~LbY BUS~ING EbEVATIONI ~NGINEER; RATH~RT ItNIEkPOLaTi',;D VALOF. 5 ~'OH ~VEE 100 FI~ET O'F SOB-SEA DI~PTH 71,00 FT VERTICAL DOGLEG e(ECTANGUf~AR COURUINA'£'E,5 HORI~, :DEPARTURE SECTION SEVERITY NfI[{TH/6OUTH LAST/WEST DLST, A~IMUTM ~'EET DEG/lOO FEET FEET FEE~,, ,~:[f,G ~IN N 30 56 ~ 354.96 N 32 2 E 420.02 N 32 39 M 494.90 ~ 32 39 ~ 5~3,63 N 33 13 E 684.38 N 33 4B E 803.99 bi 33 48 E 1.059,~1 N 34 22 E 1182,73 ~' 35 31 E 1306.54 TRUE SUB-SEA COUR,SE ;A~t.IRED 'VERTICAl., V~:'R*I"ICAh DEVlATi, Oa DEPTH DEPTH DEPTH DEG ~032 ~9 3971,00 3900.o0 31 45 ~151:96 4071.00 4000,00 34 54 ~411 12 4271,00 42~0,(,)0 43 55 ~553 40 4371,00 4~00,00 47 34 t709 63 4471,00 4400.00 1872 98 4571.00 4500.00 52 i034 43 4~71,U0 4600,0{y 51 21 ~193 56 4771,00 4700.00 50 59 i35~:85 4871,00 4800,00 51 ~3 ~51~ 69 4971,00 4qOf).OU 50 i670 11 5071,00 5000"00 50 59 i828 ~8 5171,00 blUO,O0 50 25 ~984 99 5271,00 5200,00 50 59 i145 ~0 5371.00 5300,06 51 33 i308 54 5471,00 5400.00 52 47 )474 50 5571.00 bbO0.O0 53 7 )640 85 5671,00 5600,00 52 ~805,4'1 5771.00 5'700,00 52 )970.71 5871,00 5800,00 52 PlJ5 83 5971,00 5900.00 52 ~]01:32 6071.00 oO00.OO 52 ~467~25 6171.00 ~100.00 52 48 ~633.4(' 6271,00 ~00.00 52 ~800.00 6371,00 ~300,00 53 17 ;967,05 6471.00 0400.00 53 17 ~133.78 6571.00 6500.00 5J 17 }300 13 6671.00 ~600.o0 52 ~4~5:53 6771,00 o700.0~ 52 ~2 ~629130 6~71,uo b8oO.OO 52 ~79~ 7~ 6971,00 o900,00 52 }953 70 7071.00 7000,00 51 )114 37 7171.00 7100.00 )273 79 7271 O0 '?~O0.OU 50 59 ~431 8~ 7371~00 'i300.00 50 )588 45 7471.00 7400,00 49 ~742:00 7571.00 7500.00 )892:11 7~71,00 7600,0~ 47 53 )039 03 7771.00 7'100.00 4o 2a )182.22 7871.00 '/800.00 46 35 55 E 1424.82 37 48 E 155~.67 3~ 57 E 1675,08 39 32 E 1795.85 40 6 F7 1920,96 4.1 15 E 2049,90 41 49 E 2182,18 41 49 E 2314,82 41. ~9 F 2445.31 41 15 E 2576'62 41 15 E 2707,86 40 40 E 2830,54 40 40 g 2971,82 40 6 E 3104.47 40 6 E 3237,56 4U 6 E 3371.30 4.0 6 ~ 3504,62 40 6 F 3637.47 40 6 ~ 3769.1,4 39 ~3 F 389~.77 4.0 ~ F 4026.75 39 32 E 4154.07 39 15 E a2'19.77 3~ 57 E 4403,91 3~ 23 F 4526.34 3~ 23 E ~646,82 37 a8 F 4763.32 3~ 23 E e875.27 39 32 E 50~5.36 2,67 2.81 3,41 2,44 2,94 0,32 1,25 0,56 0,08 jlb,88 N 172,40 E 359,87 N ~28 37 E 371,82 N 2()6,b0 E 425.~2 N29 2 E 435,32 N 240,88 E 500.45 510,18 N 295,21 E 589 43 Ni0 3 E 695,13 N 350,15 E 690 694,9'1N 416,65 E 810 802,14 N 488.74 E 939 ~I N,~I 21 E .} 907,34 N 559,43 E 1065 94 N 31 39 E 1009,66 N 629,12 E 1189 62 N 31 55 11]0,96 N 700,59 E 1~1~ 42 N 32 14 E 1,64 0,71 0,59 O,B1 0.91 0.46 1,11 u,b6 0,25 12~1,51 N '172,15 E 1436.05 N 32 30 E 1309,29 N 840,55 E 1559,13 N 32 5~ E 14(:)4,85 N 923,04 E 1680,96 h 33 18 E 149B,Sb N 999,26 E 1801,17 N 3~ 41E 1594,93 N 1079,12 E 1925,09 N 34 4 E 1~92,~5 N 116~,57 E 205'4,01 N ~4 $0 ~ 1791,79 N 1251 40 E 2185~62 N 34 55 E 1890.71 N 1340:20 E 2317.52 N ~5 19 E 19~,26 N 1427'28 E 2447,51 N 35 40 E 208~,7'! N 1514,46 E 2578,41 N 35 58 E U,b6 U,16 0.89 0,31 0,61 u,qO O.bO 0.47 0.73 2185,73 N lbO0,91 E 2709,$1 N ~6 13 E 2285.45 N 1087.17 E 2840.74 N36 26 E 2385.93 N 1773.40 E 2972.81 N 36 37 E 24[{7,0o N 1859,47 E 3105,29 N 36 47 E 25~8,'Y2 N 1945 45 E 3238.24 N 36 55 E 2691,15 N 2031155 E 3371,06 N 37 2 E 2793,16 N 2117,bl E 3505,08 N ~7 9 E } 2~94,~5 N ~203,26 E 3~37,85 N 37 16 E. 2995,66 N 228~,08 E 3769,~4 N ~? ~2 E 1996,~0 N 237i,2~ E 3899,0~ N 37 27 E 0,37 0,80 0,43 0,63 0,86 0.04 0,98 1,06 3193.38 N 2453.29 K 4026.95 m 37 31 g 3291,23 N 2534.84 E 4154,23 N 37 36 E 338~.23 N 2614.~6 E 4279.90 N 37 39 E 348~ 48 N 2693,27 E 4404,01 a 37 42 E 3579:88 M 2770.02 E 4526.43 N 37 43 E 3674,27 N 2844,90 E 4646.90 N 37 4~ E 3766.07 N 2916.64 E 4763,41 N 37 45 E 3~5~,36 N 2986,47 E 4875,~6 N 37 45 E 393~.ol N 3052,46 F 4982,99 N 37 46 E 401~,18 ~ 3117,03 E 508~,43 N 3? 48 E ~TLANTIC I~.I. CiiF'.i.t.~ibD Ct.jPaP~.r~Y )RIL~ 51'I"F 15-16 ~IO~TI.{ ,5[.,OpLI, AI~A~KA PAGE 7 ' DA'I'k, UF SURVEI/: 24-dUI~-84 K~[..i~Y BUSHING EbEVA'£IUN: 7X.O0 F~ ~NGINEP,.iR: ~A'fHE;RT 1N'I'[,.;IXPUI,ATt:.i!} VAI,b[~iL~ t~[)t.~ k;V~;t~,: 100 F'L:t,;'i' ,UF ,';uB-S~A DgPTH TRUE SUB ~AlSllt'CFb VEI:iTICA[, VE:RflCAL DEVIA']'I(~i~ D~PTH DEPTH Oi~P'l' H DEG 0.34 1.o4 1.59 1 2.02 1.~.5 1.90 409b,21 N 3182,09 g 5186,18 N ~7 50 E 417q.~'1N 3249,37 E 5290,37 N 37 53 E q259,34 N 3320,25 E 5400.56 N ~'7 50 E ~3~9,94 N 3394,9! F 5517,92 N 37 58 E 4qq7,79 N 3472,79 E 5042 97 N 37 58 E 455~./3 N 3556,70 E 5780 48 N37 58 E 4~77.40 N 3~47 35 E 5931 ~ N ~? 56 E 4a14.Sl ~ 3747:~3 E 610~ 53 N~7 53 E 497b.~0 N 386~,9~ E 6301 77 ~w }7 5~ E 511.4.03 N 3967.~8 E 6472 70 N37 48 ~ 2324,22 7971,00 7900.00 4_5 49 ~468.71 ~071, Of.) oooc:,O0 4'7 3617.57 8171.00 8100,00 48 29 3771,79 8~71.0() 8~c.. O0 50 25 3931,92 8371,~9 8300,00 52 2~ 1101,98 8471,0o 84Vt'~, O0 55 34 t283,04 8571.00 8500,00 57 17 1480,50 8071,00 b600,0() al 18 [704.46 8771,0() U700.O0 60 lq [89~.,00 884b,52 8774,52 60 27 }, ,TLANTIC RICHFIEhD CO~.~PAI..Y 'RUDHOE ~A¥ DRTH ~[,,OPE, ALASKA I, NTERPL)LATED VALUES [~'Oi~ CHL)SI~N HURiZON~ UCU TOP 6AG TOP 6HURbIk TOP SHUBGIK TOP SHUBBIK 'TOP SADI,EROCHIT TOP ZONE TOP ZONE GAB/OIL CONTACT TOP ZONE lb PBTD TOTAL DEPTH MEASUREI') DEP'I' H TVD l()q31.O(.) B045.17 10452,00 8059.59 1057~,~0 ~1q4,67 10722.00 82~9,25 10792,0(' 62~3.84 I0841,00 8314.6q 10862,U0 ~327.7~ 1090O,O0 8351,37 1.1124,U0 84~3.3~ 11254,00 8555.28 11534,U0 8696,4J 11622,00 b736,53 11.~26,00 ~819,57 SUB-SI~:A 797,4,17 7988,59 80'13,67 816~,25 8212.84 8243.64 P25b~'14 8280.37 8412.36 8484.'2~ ~62b,43 ~u65 53 8748 57 8774 52 SURFACE bOCA~lON ORIGIN= 854 FN~~6SFWb R~CTANGIJUAR COORD,~N.A~ES 4153,87 4165,54 4236.64 4320,32 43~2,03 4391.67 4404.48 4427.87 457~,20 46~7.75 4862 66 N 4915i55 N b065 88 N 5114.03 m 3231 6b E 3 ~ gg 33?0 ,,55 g 3404 79 g 342~ 74 g 343 00 g 345~ 38 E 35b 80 g 3632 87 g 3775,82 E 38~,50 l~ 39 ,57 E 3967,68 E ~,ARKE~ ,.SA.(~ HIV,F,,N 6HUBLIi~ A TOP 6ADI,gR~CH I'~' TOP ZON~ 3 TOP zn~E 2 GA~/O~6 CONTACT TOP ZO~E 1~ TOTAL D~PTH (DRILLER) DATE; PAGE I)ATW UF SURVEY: 24-0U6-84 KELLY BuSHiNG E~EVA~ION{ ENGINEER{ RA'~HERT ASU FI[:..I, ['}lg P T FIF,.,' ' ' '" H TVF) P, bl [.,t, ',,' Ki,:~ ["' R i,.)I~! SUB-SEA 10'122.~0 ~239,?b 8168.25 10792.0o U?B3.H~ B212.84, 10641'00 8314.64 ~243.~4 10862,00 8327,7~ 8256,7~ 1,090{,,00 ~351,37 828U 37 11~.24.U0 84,83,30 8,412!36 11534,00 ~696,43 8625,~3 11,622,gO 8736,53 8665,53 1~891,00 8845,52 8774,52 71,00 =FT U~ 432o 32 ~ 4362 O~ N 4391 67 N 4404 48 N 4427 87 N 4571 20 N 4657 75 N 49~5 55 N 91~4 03 N 3370'$5 E 404 79 E 428 74 g 343g O0 ~ 3457 38 g 382 0 E ,) ~ll{iii,T" :;l i', !' ;'IdJJ SCHLUMBEROER ATLANT I C R I CHF I ELD COMPANY DRILL SITE PRUDHOE BAY NORTH SLOPE. ALASKA JUNE Z'7, ! 984 TVW PLOT FROM OCT DATA JOB REFERENCE · WELL: DRILLSITE 15-16 SURFACE LOCATION' 854 FHL & 165'FWL VERTICAL PROJECTION -4__I'W~_ -__~fg~__ -1__0~_ O0 l__O00 ~ ~ 41300 i ii "' , ,," , , I ,,,, iJ,l ,il, i 111 ii It I I1 i!ii ilii iii! ili~ ~ili l~it liii Jill i!~ ~1 li~ I Ill Il ]i ! ii l!ll lill !I~| liJl !ill Jill !il! fill iitl il! ?Ii! ;; I [1 I J I ! I ! ! I ! I ! i ~ ! I jlfTJ i [; I ] [ i I ! !; I i I I } i 1 I ! I; i Iii !~!i ..ii ~: , !Ii! 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I~ D~_ [~1~i { { ~ ~ ~ . JJ !JJJ }~ J{Jl {J llliil! ] IliJ ~ { iiii .... 1I{ '!i '~ii - 1 .... ]~ i T,i j~jl jill LI ' ' i 11 1{II !Ii EA6T 11'?~' i! p~ PROJECTION ON VERTICI:ll,. PLI:INE OF RZIPIOTH 91] 6CIa. ED IN V~Rq'ICIq. I:)[]a'rl,,16 HORIZ SCt:N_E = 1/]CX:]O IN/FT WELL' DRILLSITE 1,5~16 SURFACE LOCATION: ~l$4 FNI~ & ),(~l~ HORIZONTAL PROJECTION -401XI Suggested form to be inserted in each 'Active well folder to d~.eck for timely compliance with our regulations. · -- Operator~ Well Name a~d Number Reports and Materials to be received by: , y-~ 7--~ Date' Required Date Received Remarks " Core Description Registered Survey Plat Drill Stem Test Reports ---'~ ARCO Alaska, In{~''~' Post Office ,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 27, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 15-16 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to pull the 4-1/2" tubing, clean out to PBTD, and re-run the 4-1/2" completion assembly. Since we expect to start this work on October 1, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Si ncerelh, T. L. Fithian Area Drilling Engineer TLF/JG/tw GRU1/L62 Enclosures RECEIVED s£P 2 Alaska 0ii & Gas Cons. commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLxI~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21115 OTHER [] 4. Location of Well Surface: 854' FNL, 165' FWL, Sec.22, T11N, R14E, UH 5. Elevationinfeet(indicate KB, DF, etc.) RKB 71' 12. 9. Unit or Lease Name Prudhoe Bay Uni~. 10. Well Number Pull Tubing ~1 Other ~ Pulling Tubing (Note: Report multiplecomp et~ons' on Form 10-407 with a submitted Form 10-407 for each completion.) 15-16 11. Field and Pool [] [] [] I6. Lease Designation and Serial No. ADL 28306 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Prudhoe Bay Fi eld Prudhoe Bay Oil Pool 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to perform the following workover on DS 15-16: 1. Kill well. 2. RU workover rig. 3. Pull 4-1/2" completion string. 4. Clean out to PBTD. 5. Re-run 4-1%2" completion assembly. 6. Secure well & release rig. RECEIVE SEP 2 81 41 Alaska Oil & Gas Cons. C0rn~ ission Anchorage A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 1, 1984 14. I hereby certify that thel~regoing is true and correct to the best of my knowledge. Signed " , Title Area Drilling Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/SN61 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALas'ka, Inc F'.O~ Box Anchorage, ALas'ka 995t 0 DA'I-E' £'eptember tS,. i9°.,.,4 F~'.E'"F-E~F~ENCF · ARCO Ca~:ed Hc, Le F:'ina L.s S-29-~ 6-aS-84,= S-'6-- ,~ ..-~"z._o,~ S-9~/ No Dale S-98~ 7-8-84 S-98- 7-8-84 4-t 0-- 8-4-84 4-28- 7-27-84 5-i 6'~' 6-27-84 5-i 6-- 6-28-84 5--t 6~ 6-"~8--~;4, .... .,-~-.t F- ¢.-,,..4 _4 .~-- I 'Y- 8-2-84 ~'~'-.-i 7-~ 7--22-84 ~ t?' 7-2t -84 .,~'.-- i ?~ 7-2t -84 . ~~ i gn and ¥' e '!: u i" n '~ h e CBI_/VD E:F'L DIL Monitor CNL.. CH (EpitPlermaL) CNI_ CI--i ('rherma I.) CCL./Perf Record CCL/F'erf Record GC'T' Gyro We L L 5'urvey CBL/VD CCL/Perf Record CCL/Per f Record CBI._/VD GCT Gyro WeLl. ~J~u¥'vey CET L. og CET Log CBL./VI) at'±ached copy a:; 'Feceii:~'~- I:;:ec ~.: i vF, d ~' ~' _ I.~, .......~~'-' ~~ HAVE A NICE DAY~ I<eLLy McFarLand Anchorage ATO-~ 4~°F 'T'RANZ. ~-'$ 6 7 R u n t Run t R u n '7 R u n Y R u. nt R u n t F:,' u n R LJ. n i Run 2 Run t ... I:~'. u n t o'f da'~'a. 5' c h ~;' c h ;?;' c h ,:., (_ h 5'.:: h :.9 c h ..? c h :.; c h ,? c h :'.: r-h S(: h ,"Z c h ,.? c t"., ,'~ c: h ,~"~ ,. I) I ;';' l' R I BLJT I ON Chevron ExpLoration Services' Ex tension ExpLorntion Exxon Getty Marathon Hob i L Nob i L E & F' Phi L L ips- i::'ruclhoe Bay We I. L R A D 5'oh i o State of ALaska F i L e.s ~ STATE OF ALASKA "ALASKA'?"~ AND GAS CONSERVATION CC"'~MISSION ~i~ ' MONTHLY REPORT'OF DRILLING AND WORKOVER OPERATIO 1. Drilling well~ Workover operation 4. Location of Well 854' at surface 2. Name of op. erator 7. Permit No. ARCO Alaska, Inc. 84-74 3. Address 8. APl Number P. 0. Box 100360, ^ncho'rage, AK 99510 50- 029-21115 FNL, 165' FWL, Sec.22, T11N, R14E, UH 6. Lease Designation and Serial No. ADL 28306 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 15-16 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool June 84 For the Month of. , 19__ 5. Elevation in feet (indicate KB, DF, etc.) 71 ' RKB ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1530 hrs, 06/06/84. Drld 17-1/2" hole to 2520'. Ran, cmt, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,865'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,891', as of 06/25/84. OH logs. Ran, cmtd, & tstd 7" lnr f/10,496' - 11,848'. Drilled cmt to 11,826' PBTD. Displace to brine. Ran CBL. Ran 5-1/2" completion assy. Secured well & RR 06/30/84. Left open 9-5/8" x 13-3/8" annulus for injection. 13. Casing or liner run and quantities of cement, results of pressura tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. Instld w/1910# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/FS ~ 2495'. Cmtd w/1900 sxs Perm "E"+400 sxs Class Il ell · 9-5/8" 47.0#/ft, L-80, BTC csg w/FS @ 10,848'. Cmtd w/500 sx Perm "G" cmt. 7", 29.0#/ft, L-80, BTC csg f/10,496' - 11,848'. Cmtd w/300 sx Class "G" cmt. 14. Coring resume.and brief description NONE - 10,851 ' - 10,826', GR to 2495'. JUL 1 !084 Alaska Oil & Gas C0¢ls. Co~]mission Ar~ct~.r.,rage 15. Logs run and depth where run DIL/BHCS/SP/GR f/11,852' LDT/CNL/GR/Cal f/11,872' CBL f/11,785' - 10,400'. Gyroscopic Survey. - 11,747' ~ 90° phasing. - 11,737' @ 90° phasing. - 11,717' @ 90° phasing. (1~6~ DST data, perforating data, shows ~of H2S1, miscellaneous data n #1, shoot f/11,777 - 1,767' & f/11,757' Gun #2, shoot f/11,767' - 11,757' & f/11,747' Gun #3, shoot f/11,737' - 11,727' & f/11,727' I::)e Cd ir~ dup I~'cate With the Alaska 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /.,--, _ .... TITLE Area Dri 11 ing Engineer Submit in duplicate NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 JMM/MR1 3 DS 15-16 DRILLING HISTORY NU 20" diverter. Spudded well @ 1530 hrs, 06/06/84. Drld 17-1/2" hole to 2520'. Ran 62 jts, 13-3/8" 72#/ft, w/FS @ 2495'. Cmtd 13-3/8" csg w/1900 sx Perm "E" cmt + 400 sx C'lass "G" cmt. ND 20" diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.2 ppg EMW - ok. Drld 12-1/4" hole to 10,865'. Ran 274 jts 9-5/8" 47#, w/FS @ 10,848'. Cmtd 9-5/8" csg w/500 sx Perm "G". Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 11.2 ppg EMW - ok. Drld 8-1/2" hole to 11,891', as of 06/25/84. I Ran DIL/BHCS/SP/GR f/11,852' - 10,851' LDT/CNL/GR/Cal f/11,872' - 10,82.6. G,.'- Ran 31 jts 7" 29#/ft f/10,496' - 11,8'48'. Cmtd 7" lnr w/380 sx Class cmt. Drld cmt to 11,826'PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to brine. Ran CBL f/11,785' - 10,400' Ran Gyro. ND flow nipple. NU 13-5/8" flange. RIH w/4" guns (4 spf) ~ shoot f/11,777' - 11,767' & f/11,757' - 11,747' @ 90° phasing. POOH. RIH w/gun #2. Shoot f/11,757' - 11,767' & f/11,747' - 11,737' @ 90° phasing. POOH. RIH w/gun #3. Shoot f/11,737' - 11,727' & f/11,727' - 11,717' @ 90° phasing. ND 13-5/8" flange. NU flow nipple. Ran 5-1/2" completion assy w/tail @ 10,544', pkr @ 10,492', & SSSV @ 2227' Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to '5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Leave 13-3/8" x 9-5/8" annulus open for injection w/non-freezing fluid protection. Secured well & released rig @ 0700 hrs, 06/30/84. JUL 1 ? 'd9 4 Alaska Oil ~ Gar; OO~s ' ' 'C°~ndssion JMM/DH13.tw ARCO Alaska, ItL Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 13, 1984 Reference: ARCO Open Hole Finals * D.S. 12-28 3-25-84 CDL/CNL D.S. 15-16 6-24-84 6-24-84 6-19/24-84 6-24-84 6-24-84 CPL/Cyberlook BHCS/OR DIL/SFL LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) Run 1 2" & 5" GO Run 2 5" Sch Run 2 2" & 5" Run 1/2 2" & 5" Run 2 5" Run 2 5" * These two logs were re-ran by Gearhart so they will coincide with the LIS tapes already distributed. gn and return the attached copy as receipt of data. Friday the 13th is back again, have a safe one! Kelly McFar land ATO- 1429F Trans. f~267 DISTRIBUTION ~'~ev~o~ D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon-....? · Mobil ~' ~ ' - Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith 'Sohio Sta~e of Alaska GEARHART INDUSTRIES, INC. July lO, 1984 Arco Alaska Inc. P.O. Box 10-360 Anchorage, Alaska 99510 To Whom It May Concern: These 2"/100 and 5"/100 Compensated Density Compensated Neutron Logs for Well DS 12-28 are being re-distributed so that they will coincide with the LIS tapes that have been distributed. The only change is this log uses the OH GR rather than the CH GR. Sorry for the inconvenience. Regards, David W. Douglas Computing Center DWD/sjt Enc. Post Office Box ¢~0.2436 Anchorage, Alaska 99510 Teleohone 907-562-2538'- ARCO Alaska, Ir Post Offlc= =ux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 19, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 15-16 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to perforate the Sadlerochit with the rig on location. Since we expect to start this work soon, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Sincerely, ~]~?T..L~c~Fi thi an Area Drilling Engineer JBK/GRU7/L98'tw Enclosures RECEIVED JUN 1 919B4 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA [ _AND GAS CONSERVATION CC ,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Aln_~ka; In~.. 3. Address p_ O. Box IOOq, R¢); Anqhnrage~ AK 99510 4. Location of Well Surface: 854' FNL, 165' FWL, Sec.22, TllN, R14E, UN Proposed Target: 1320' FNL, 1320' FEL, Sec.15, T11N, R14E, UM 5. Eleyation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 84-74 $. APl Number 50-- 029-2!!!5 9. Unit or Lease Name 1IL 1£ 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool .... , Pod ..,.,., 12. Check Appropriate Bo~'~o ,v~u~ Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of stating any proposed work, for Abandonment see 20 AAC 25.105-170). ) ARCO Alaska, Inc., proposes to perforate the Sadlerochit interval using wireline casing guns with the rig on location. The well will have kill weight fluid in the wel]bore while perforating; in additon, a wireline lubricator will be installed and tested for surface pressure control. Following completion of perforating activities, tubing will be run and the wellhead installed and tested. The tubing then will be displaced to crude oil and brought on-line in the normal-fashion after rig release. Perforation intervals will be forwarded to your office at a later date. Due to the timely nature of this activity, ARCO Alaska, Inc. would appreciate your prompt review. Estimated Start: June 22, 1984 RECEIVED JUN 9 J984 A/aska Oil & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. T~~'elow for ~on use Title Areo Drilling Engineer Conditions of Approval, if any: 6 / ?~._ ~:~/~.f.- Approved by ~eturn~ BY O;der of COMMISSIONER the Commission Date ~ ~2 I ~ ............. Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU7/SN41 MEMORANDUM State of Alaska A!~SKA OIL A~!D GAS CONSERVATION COMbIISSION THRU: Lonnie C. Smith Conmis sioner FROM: Doug Amos ~ Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: June 12, 1984 D.41.22 Witness BOP Test at ARCO's DS 15-16 Well, Sec. 22, TllN,R14E,UM, Permit No. 84-74 on Parker Rig No. 176. Thursday, June 7, 1984: After witnessing the BOP test at DS 3-29, ~ travei~d t~o '-ARCO~'S~'~S 15-16 well to stand by for the BOP test there. Friday, June 8, 1984: The BOP test commenced at 4:00 pm and was ConclUded at 5:30-~. There were no failures and I filled out an AOGCC BOP test report which is attached. In summary, I witnessed the successful BOP test at ARCO's DS 15-16 well. Attachment 02-001A(Rev. 10/79) O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well ~ ~,~, }~_~ ;U Permit 9~i ~ .. Location: Sec ~ T}}~ R~Jd~ ~ __~,~, ~~asing Set ~ ~9~'..ft. ~cation, Genera! ~ ......... O~ ......... ACCUMU~TOR SYST~ Well Sign General Housekeeping_ Reserve pit Rig Full Charge Pressure_ ..... _~_~./.~{~_~_dP_--~_ psig Pressure After Closure~_psig 200 psig Above Precharge Attained: min.~ sec Full Charge Pressure Attained:_ ......... .~=___min~sec Controls ~ Maste.~ BOPE Stack AnnUlar Preventer .~Rams .,ind Rams. b/~ / H.C.R. Valve / / Kill Line Valves~__ Test Pressure Upper Kelly_.__~_~___Test Pressure.__.~t_~___- Lower KellL__./..~.?est Pressure Ball Type / ~est Pressure Inside BOP~ ] Test Pressure Choke Manifold / est Pressure NO. Val. ves No. f lange~. Adjustable Chokes Hydrauically operated choke.___h_~ ......... Test Results: Failures _ _.._ Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: .and ibution - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Ir: Post Offic~ ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 17, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - DS 15 Wells 16-19 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG' tw GRU7/L57 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED MAY 2 1984 Alaska 011 & Gas Cons. Commissio~t Anchorage CERTIFICATE OF SURVEYOR I HERE BY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISIO.N AND ALL DIMENSIONS AND OTHER DETAILS ARE _CORRECT. j ,f,, y~.,.. , Dote ? Surveyor ' / / ASBUILT WELL LOCATIONS WELL No. 16 Lat. 70° 17',52.919",, Long. 148°34 ?_6.072 WELL No. 17 Lot. 70° 17' 54.078" Long. 148° 34' 26.78Z" WELL No. lB _ _ Lot. 70° 17"~5.5.235:_,, _ Long. 148°34 27.493 EL. 32.80 · Y 5, 960, 630.76 X 676, 08B.19 EL. 32.55 Y 5, 960,748.01 X 676,061.11 EL. 32.60 Y 5,960,865.04 X 676, 033.95 WELL No. 19 EL. 32.50 Lo t. 70° 17' 56.389" Y 5,960~ 981.75 Long. 148°34' 28.196'' X 676,007.10 GYRO ASBUI LT Lot. 70° IT' 42:.940" Y 5, 959,620.3 __ Long. 148°34'21.186'' X 676,279.6 NOTES · 1. Elevotions ore ARCO dotum M.L.L.W. Z. All distonces ore grid. 3. X,Y coordinotes ore Alosko Store Plone Zone 4. RECEIVED MAY 2 3 1984 Alaska Oil & Gas Cons. Commission Anchorage LHD SrSOCIATES 1 *,NC. HP~e~: , 1~,~,,CA _ ARCO Alaska, Inc. ASBUILT DRILL SITE No, 15 WELLS 16, 17, 18, 19 LOCATED IN PROTRACTED SECTION ZZ, T II N, R 14 Et U.M. May 18, 1984 Mr. T. L. Fithian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 15,16 ARCO Alaska, !nc. Permit Mo. 84-74 Sur. Loc. 854'F~TL, 165'FWL, Sec. 22, TllN, R14E, tM. Btm~hole Loc. l143'FNL, 1375'FEL, Sec. 15, TllN, R14E, UM. Dear Mr. Fithian: EnClosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, ve!oc~ty surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as ~portant for the spawning or. migration of anadromous fish~ Operations in these areas are subject to AS !6.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior ~o commencing operations you may be c~ntacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. T. L. Fithia~ Prudhoe Bay Unit DS 15-16 -2- May 18, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. in the event of suspension or abandonment, please give this office adequate advance notification so that we may have a Witness present. C. V. Chatterton BY ORDER OF THE CO~Mlg$1ON Chairman of Alaska Oil and Gas Conservation Commission be Enclosure CC* :., Department of l~ish & Game, Habitat Section w/o encl. Department of EnVironmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 14, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 15-16 Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 15-16 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on June 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Since~ T. L. Fithian Area Drilling Engineer TFL/JG-tw GRU7/L44 Enclosures RECEIVED MAY 1 6 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '~'~', STATE OF ALASKA ~'- · ALASKA O,- AND GAS CONSERVATION CO,,,~vllSSlON PERMIT TO DRILL 20 AAC 25.005 DRILL 13~X lb. Type of well EXPLORATORY [] SERVICE [] REDRILL [] DEVELOPMENT OIL E~X SINGLE ZONE la. Type of work. 2. Name of operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 854' FNL, 165' FWL, Sec.22, T11N, R14E, UM At top of proposed producing interval 1320' FNL, 1320' FEL, Sec. 15, T11N, R14E, UM (~ Target) At total depth 1143' FNL, 1375' FEL, Sec. 15, TllN, R14E, UM 9. Unit or lease name Prudhoe Bay Unit 10. Well number 15-16 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 40' I ADL 28306 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 7-1/2 mi, NW of Deadhorse 5-6 well 120' (~ surface feet 16. Proposed depth (MD & TVD) 11,748' MD, 8924' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2600 feet. 21 14. Distance to nearest property or lease line miles 1143 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 50 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 06/15/84 3200 psig@__ . Surface 3950 ..psig@ 8800 ft. TD (TVD) Hole 30" 17-1 / 2" 12-1/4" 9-.' 8-1/2" Casing Weight 20" 91,5# 13-3/8" 72.0# 9-5/8" 47. O# ;/8" x 13i 7" '3/8" Arc1 29.0# SIZE CASING AND LINER Grade Coupling I Length H-40 Weld 80' L-80 BTC 12470' L-80 BTC 110837 ' i c Pack / L-80 BTC ~1182' 22. Describe proposed program: SETTING DEPTH MD TOP TVD 30' I 30' 30' I 30' 29' ~ 29' 10566' I 8168' MD BOTTOM TVD 110' I 110' 2500' I 2500' 10866' I 8361' I 11748' ! 8924' I QUANTITY OF CEMENT (include stage data) 2000# Poleset 2300sx CS III & 400sx CSI 500 sx Class "G" & 300 sx CS I 400 sx Class "G" ARCO Alaska, Inc., proposes to directionally drill this well to 11,748'MD (8924'TVD) to produce from the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 4-1/2", 12.6#, L-80 tubing and packer will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud. DS 15-16 will be 120' away from DS 15-6 at the surface. There are no other wellbores closer than 200' anywhere along the proposed well course. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption of the disposal process (i.e., rig move or shutdown of disposal process for an extended period of time). ~ SIGNED ~, Z~ ¢~ .... TITLE Area Drill ing Engineer DATE ~'.//~//~ ¢ The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required I Directional Survey required APl number I--lYES ~4XIO I-lYES .,[~NO I ~YES [-1NO 50- O?~- -bjJ/~-- Approval date J Permit number ~ ~' ' 5/}}~/~r,,/~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~/~.-/- ~~ by order of the Commission Form 10-401 6 Submit in triplicate 1000 2000 3000 4000 5000 6000 7000 8000 900O 10000 D81¢'-" "-'"' 0 1000 2000 3000 4000 5000 6000 7000 S/R,- 165 FWL & 85B FNL of Sec.22, Ti]N, R14E, IN . THL- 1320 FNL & 1320 FEL of Sec. 15, TllN, R14E, UM 13-3/8' CA,SIN~/TYD = <OP TVO - 2.$ [ *7.5 12.5 17.5 22.!> 27 ,5 FT(TO T ~RGET) A YERA~E $o DEe 10 __ K-lO TVD - 6~'10 MD -- 84'17 DEP -- 3764 __ K-6 TYD ,,- 737'1 14D -- 0:~17 OE~ - 4448 LCU liD-- 1101 MC -- 10417 DEP · 5.130 SAG Rr 'ER TVD - 821~ MD -- 10740 [)Fp ,-- 8841 SHUI ,UK TVD "032 t~ MD "' 10812 )EP -- iteO H/.' CAS -e TVO - 13e', Mo - ,oee. .E, - 1e37 TM, SAD~)C ~rr TVO -e3. MO - loee~oEP -6641 ,ONTACT TVD - 1001 MD -- 11335 DEP TARIET TVD - I17¶ MD · 11117 DEP - i130 IAI! IADLEROCHIT ~fD - 1101 MD -- 11e..48 D.EP - .e.2~3,0. "% ,.... iJi4 m~& -41 ,Al II ""' ii ii · .................................... i .............. ', , ~ ..... ,. , ,i , , ii ...... iI i · · . 0 10130 2000 3000 4000. 5000 6000 7000 VF. RTI CRL SECT I ON 8000 0 1000 2000 3000 ,~000 5000 6000 ~_. 7000 800O 9O00 10000 8000 RECEIVED MAY 1 Alaska Oil & Gas Cons. Commission Anchorage 'mllm~ E - W COOROINRTES o - t~ 0 1000 200~ 3000 4:000 5000 6000 SI-L- 165 ~ fi 854 FNL of: Sec 22, i Ti]N, R14E, I THL- 1320 FNL & 1320 FEL .of I i- ' , I Sec. 15, TllN, R14E, ,, -.~ ~,DS1516 / / - ' /~ Target' . TVI)= 8871' , MD= 11,506' - ! DEP= 6129' ' . I II I l . - l.- i RECEIVED . ~. MAY 1s i984 ~ J,laska Oil & Gas ~ons. Commission ~ Anch~ rage -10013 0 1000 201~ 3000 ~000 5000 6000 E - IA COOROINRTES U~I~-I~ ~.~ F. - N COOROIN~TF.S '400 -300 -200 - 1 O0 0 1 O0 200 300 400 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I] I 3995 3933 096 15-16 x .,~30~3289 .. "80~.1.~ 1 t~ - .too ~. . q .- ,. - ,,'~ O0 . . : . . :: _ .. -_ .. . C[IV[D M ~V 1 ~ lOoA · ., '" Alaska Oil ~ Gas Cons. Oom~issiorl ~nchora~e . i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 0 0 0 -900 -300 -200 -100 0 ]00 200 300 400 PREVENTOR BLIND SPOOL P['PE 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1SO0 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the tim~ and pressure remaining after all units are closed with charging pump off. '4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 10. 11. 12. 13. 14. 1S. 16. 17. 1. Fill BOP stack and .manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark ramming joint with predetermined plug seating d~pth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. -5. -In each of the following tests, first hold a 2S0 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 minutes. Bleed pressure to zero. 7. Open amm~ar preventer and close top set of pipe rams. Increase pressure to S000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase p~essure to $000 psi and hold for at least 3 mirmtes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of p~pe rm~. Increase pressure to S000 psi below the bottom set of pipe rams and hold for at least 3 min- utes. Test reamining untested manifold valves (if any) with $000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe rMms. Back off running joint and pull out of hole. Close blind rmns and test to 5000 psi for at least 3 mir~tes. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling pos it ion. Test standpipe valves to $000 psi. Test Kelly cock~ and inside BOP to $000 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perfom complete BOPB test once a week and func- tionally operate BOFE daily. 18. MAY 1 6 1984 A~aska 0il & 8as C0,s, C0mmissi0o /\~chorage Revised 2/21/84 SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC'. SCHEMATZC I0" HYD. (]PR. BALL VALVE WELL BORE (SEE DETAIL) I0" HYD. OPR. BALL VALVE ALL 90* TURNS ARE "TEE" CUSHION I ~LL QBORE I RESERVE PIT AREA NOTE' FLOWLINE DR ILL ING R I SER 20" 2OOO PSI WP ANNULAR PREVENTOR ~mo" DIVERTER LINE 'Valves on diverter lines open automati- cally when the annular preventer is closed. -- DR ILL lNG SPOOL 20" CONDUCTOR PIPE I 0" HYDRAULIC OPERATED BALL VALVES "DETAIL" · CHECK LIST FOR NEW WELL PERMITS Company Lease & Well-No. ITEM APPROVE DATE YES NO REMARKS (3) Admin ~(.~ thru 11) (10 and 11) (12 thru 20) 1. Is the permit fee attached .......................................... 2. Is well to be-located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedieated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included .... ;~-~- 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ 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 surface casing protect fresh water zones ....... Will ali. 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 well bore separation proposed ........................... (5) BOPE 1 thru 24) 21. 22. 23. 24. Is a diverter system required .................................... ~f~' Are necessary diagrams of diverter and ~{ equipment attached . ~ ..... Does BOPE have sufficient pressure rating - Test to .5~z~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. ,7: ,. . _ .... Additional, Remarks: Ci~_~M'$ Geology: WVA~ JK~ JAL rev: 12/08/83 6. CKLT Engin~ e~ering: BEW INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREAI NO. SHORE ........ Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. .o ~,VP ~1o.t.~07 VEPlFIF'ATIr~i~~ LT~T!,~,~G PAGE SEPVICW NA~E :EDIT DATE : _~4Ii0t?~ ORIGIN : CONTinUATION ~ :01 PR~V~O~S RFEL : CO~FNTS ~ EOF ** FT[,~' HEADER ** FILE !~ ~ ,~E :EDIT .001 SE~V~CF NA~E VERSION ~ : DA~E : ~AXI~U~ t,,ENGT~ : 102a wILE ~,[ ypw : ** INFOR~{ATION RFCDRDS ** ~N~M CONTFNTS CN : BRCO At,ASKA INC WN ~' 15-16 mN : PRUDHOE BAY RANG: 14~,~. TOWN: I ~ ~ SECT: 9,2 COUN: N,SLOP~ UNIT TYPE CATk] $IZh; CODE 000 000 OIB O65 000 000 0!0 065 000 000 012 065 OhO 000 004 065 00() 000 004 065 OmO 000 002 065 000 000 012 0~5 000 000 ua6 065 000 000 00~ 065 I',VP 01.0,~.!07 VE,PlFICATI;fqi',~ I.,TSTIt"~(.; PAGE 2 , , ALASKA CF!k~P!.~ m I ~(; WEI~I, = D,S. 15'16 FIFLD : PRUDHOE BaY COI~NTY : NORT~ S~.OPE BOROUGH ,]OB N0~:~FR AT ACC: 6Q5~0 RUN #1 & #~, DATF ~,OGGED: 24 Jl~.~ 1984 LDP: T H~.LSTFAD ~ERGF ~EPGP ~EPGF ~RGE ** D~T~ FOPMAT RECORD ** ENTRY ~¥PE SIZE REPR CODW ENTRY 2 1 ~6 u 4 1 66 1 9 ~ 65 ,lIN 16 1 b6 1 0 I 66 O DATU~ SPECIFICATION BI, KICKS '~NF.N S. FRVI'"'E SFI-'~VICE II~,ITT API ~IPT AT-.'."][ A[-)'I I:"IT,[.,] SI%E SPL REP.';' ID OPDFR ~ LOG TYPE CLA~,S M(JD ~,~n, CODF, PR~ ( OCTAL OC, O nO 0 n ??n Ol o o 1 20 ~.6 0 0 120 a. 4 o n nln O1 0 o 31 n 01 0 0 520 80 0 o tin 01, 0 n 310 01 0 0 ? !~ O C 1 0 n 35n n2 0 0 356 O1 0 0 420 O1 0 0 090 no 0 0 890 00 0 n 35~ 01 0 O ~30 ~1 0 0 330 ~0 0 n 00000000000000 00000000000000 OaO00000000000 00000000000000 00000000000000 O0000nO0000000 00000000000000 00000000000000 00000000000000 00000000000000 OOO00000000000 00000000000000 0PO00000000000 00000000000000 00000000000~00 00000000000000 00000000000000 DATA DEPT SP GR ~RAT ~NCNL DEPT SP NRAT NCNL DEPT Sp GR NR5T WCNL DEPT Sp NCNL ¸ .p, GR SP ..1,1q00 0000 SFI,U -099:2500 47 .~437 CALl 3004.0000 wCNL 11P, 00. 0000 SFI..,U -1 . 1064 70. 2500 CALI ~.244 ,L 2660. 0000 FCNL 1.1700,0000 SFI..,U -14 °141 GR ~. 5 S 40 R N F~' g 3514.0000 ~CNb ]1600,0000 -59.0000 20.4688 CALl ~.~293 ~NPA 3060.0000 PC~L -099.2500 IDD -99° . 7500 ['."il.' '~. O 43 ('.) ~,' P H I 087. oono II .7109 ILD 66, n7 ¢;0 [.; .T O. 1 250 ?. 35o4, NPHI 1127.0000 · m'2. 0 ~ 0000 TLD 10: 4()63 BT g , 3906 ~HOB ?. 6895 1,! 37,0000 6,47?7 II.,D 8 1 , 0000 9t= 11,02- 4, PHOB 021. 5000 7,74 61 I 1] O 7 .';'..':', 6, 25 ... -999.2500 ILM -099.9500 C~ 2.1797 DR~O 31.7871 PEF 16 4219 TL~~, '13:0000 GR 2. 5664. DRHO 21 . 7'773 t>EF 171.6250 ILM 85.5000 G~< P.6641 DRHO 25.7324 P~W 182.7500 IL}A' 94.R750 CR P,2539 DRHO 26.0531 PEF 6.2969 74.0000 2.601.6 DRHO 2~.fi()04 pew 10.2'734 '70.~750 -999,2500 -099,2500 -0,0454 14t,5000 10,0687 b6.9750 0,0581 11.6953 2~.156.2 6 .1875 0,0757 16,~2~I 46,3438 19.4063 -O,OOR8 4.6133 6 [172 81 000 0 0767 9 1797 8,32gl 72,5625 LVD nlo ~-.'02 VEDtF'I. CATln~,i L. TS.TiNG PACE 4 GR ",1R 1~ 'IL' NC NL SP GR NRaT NCNL DEPT SP NCNL SP NCNL DEPT SP NCNL DEPT SP NRAT DEPT MR~T 'NCNL DE..r SP ~RAT NCNL DEPT SP GR ,p DE.T 65.6875 CA~.I ~.~37 PNPA 2359.0000 FCNi, 11300.00n0 SFI.,U -b1.~4~8 nR 1R.a375 CALl !..7471 9NDA 3748.~000 FC~b 1200 0000 SF~U 19.6875 CAT,! oooo 1 100 . 0000 -22.a, 531 3'7.°.062 CALl 2,9529 3038,0000 ]0900.0000 SFI,,U 7~.7b00 ~R 96. ~'t50 CALl 3 ,02 34: f~NRA 316~,O000 FCN[, I0700 O000 SFI,U -42'&563 ~R ~ - -099,2500 CA~.,i '99q.25~0 ~CML 1°6P-7° °°°°:332o cRSF'lr'U -C~9~ 2500 CAf,..,;[ -~99 ~500 ~C L ]0$00 r',OO0 SF[,U 2 ,,::,, 390b Ck 10.q062 RHOB 3.0'723 ~'.P~I 767,500(3 58~.5000 ILO 20.21~7 Pl.' 1.q248 ~'PH]' la47.~000 16.3125 P't ~.6797 RHOB 1,59~6 ~PgI 2682.0000 80.6250 ILD 42,3125 BT 2.5059 ~'PHI 1212.0000 119.6250 29.95~1 PT 8,67q7 PHOB 2.433b 124~.0000 26,9687 167,6250 D']' g.7734 RHOB 3.2520 97a..0000 lOB 5000 IbD 56' ,3'7~0 PT -qgg 2500 ~H~B -099' ' ,2500 "~PNI -999.95n0 ~ 9687 116 3125 -099,2500 RHOB q99.PSO0 ~!PHi -999.2500 2,5332 103.9375 DT -099'2500 0078 ]i,~D 8~'~125 BT 2.6230 DRHO 2000.0000 Ib~ 9~.3'750 CR ~,2277 DRNO 14.0902 659.0000 't5,1250 2.3965 DRHO 11.1328 PEP 153,1250 96.6250 2,2559 22,4009 348.2500 99.3125 GR 2,1.816 DRHO 23.4375 PEiF 18.5313 92.4375 ¢:R ~ 3 '%96 DRHO 34.O. 332 4~,781..3 IL~ .8125 Gk -999.2500 DRWO 2500 PgF 2 ,, 5664 T -099.9.500 (7R -999. 2500 , .. P ", ;-, - O 9 g 2500 g 2,4 '185 -g99. 2500 -999 ~ 50 ,.'.) -094: ,5oo 3, 1445 -99q. 2500 0.0122 9.~922 76,0000 20.2187 -0.0024 5,9922 88.3125 19,3125 -0.0049 6,5195 41 4688 42:3125 '0,0020 7,2187 68,2500 29,9531 0 0000 10:2056 9,R594 ]b7.6250 0,0088 11.8828 55 81.25 63'~ , 50 '999, O0 -O99. 2500 2,6035 -990.2500 -099,2500 -099.2500 2,4844 -q99,2500 -999 2500 -ggg' .25n0 3,0906 -o99.7500 LVP O,ln.HO'2.. VlL~IF'[CA~IDi,~ L.,TB~'T~,.~G PAGE 5 C,R NRAT DEPT SP ~R NRAT ~C~I~ BEPT GR NRAT WCNb ,P WRAT ~CNL -99a.7500 CAI,I -o90.psno R:qPA -099.7500 WCNI. 10400.0000 SFT,Li -50.OOOO C~ -990.2500 CAT, I -999.2500 qNPA -099.2500 FCNL ]0200 O000 ,FT,b -999.~500 CAI,I -~9a.2500 RNPA -~99,7500 !O?On.eooo ,FT,U -999.7500 CA[,I -999,7500 FC~IL DEPT 10~00.0000 SFI, U SP -64.~125 OR ~R -~9o.95m0 mAI, I MRAT -o9o,75n0 ~NPA ~CNL -~gg,PSO0 ~CNL DEDT ,P NCNb DEPT SP ~R NRAT WCNL EPT P C,R T NR~ ~CN L D E P T ~R MRAT ~ C N L SP ~O00n -999 -99~ -099 nooo SFT,U nO00 c~R - ~ N P A. 9500 ~CIL'b 9~,00 -26 -~99 -,?9° -999 0000 SFLU 7500 ~R 2500 CALl 2500 Pf'~iP~ 2500 FCNL 9~00 -32 -999 97 O0 -21 -o9m 0000 ,FLU ?344 GR 500 CALI .500 ~NPA ~500 FCNL 96U0 0000 SFT.,U -15:7109 GR -99° -o90 .750 .250 6.219 95.187 -999 250 -09o~250 208, -099. -999. . -~99 -999' , -999, 6, 116. -999. -09a. -999. -99q, 4, 1.35. -c~9a '999. 187. 5, 142. -99 . -999. 769 25O 25O 0938 5000 2500 950O 2500 8555 0000 2500 ?50o ?500 8359 ~,875 500 · 50 (} 250O 22 25O0 2500 25OO 9141 ~7~0 2500 2500 ~750 2500 ?50O 250O 4766 PT TLD DT RHn~ k',PH I TbD D T ~'PWl RI-iDB ~'PHi Pt,' PHOB TbD DT RHO[5 ILD DT T LD D I' T L D D T -999.2500 D~.HO -°9a. 2500 6.1328 IL~ -q99.2500 -999.7500 -q90.2500 PEP 3.6641 ILH -999.2500 GR -999.25n0 DRNO -999.7500 DEF 4.5352 IbM -09e.2500 GR -099.2500 DRNO -999.2500 PEF 4.5234 ILg -999.2500 GR -999.2500 DRMO -999.2500 nyF -990:,,500 GR -999.2500 DRHO 2.521,5 -~99. 2500 '999, ~500 -099 ~ · ~, 50(3 PEiF 3,7129 Ibg -999'2500 GR -999.2500 DRHO -q99.PSO0 3.8145 I b -099.2500 GR -099.7500 ORHO -999. ?500 PE',F 2.0273 :[ b,~< -090.2500 CR :999 2500 099:2500 5.80~6 -a99 2500 -999i2500 -099 ~500 3.8867 99 2500 '099,7500 <!.6602 -099,2500 -~99,2500 -99~ .2500 4.4766 -999,2500 -999,~500 -999.~500 4,7070 -999.2500 :999,~500 999,. 500 2 9102 -999 2B00 O :9 g soo 2500 3,8184 -999.7500 '999,2500 '999.2500 3,~'730 -a99,.500 -999,2500 -999.2500 2,0586 -n90,25o0 LVP OlO.NO? 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T -999.2500 PNRA NCNL '099.25n0 FCNL DE I 900G,O000 SFLO S? -46.~875 ~R :~ -999 ?500 CAL.i AT -o9q~?5nO RN~A ~CNL -~99.2500 FCNI., ' 1 DEPT 8900 SP -57 OR -999 ~RAT -090 N:CNL -999 9000 SFI.,U 6875 2500 CALl 2500 ~500 DEPT 8800 SP -59 ~R '999 NRAT -999 NC~L -~9~ DEPT SP 87~.,0000 SFLU -999.9500 -°90.2500 -09q,2500 2.~2~0 87.~750 -099 2500 -999~7500 -o99.7500 3.0215 ~5.~.375 -999.2500 o~o 2500 -999.~500 2.24O2 90.7500 -999,2500 -~99.2500 -99o.~500 ?,~219 96.0000 -990.~500 93:R .5 -999 250O -o90' 25n0 0961. 2500 2500 534. 625 -999 25O0 -g9~:~Sft(') -999,2500 3.4:746 ~05,5000 -999 250u -099'2500 . -999,2500 6,2969 9o.nooo RHOB RHOB D T RHOB N p b' I ?HOB ! 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TSTING PAGE 7 GR -q99.7500 CALl NRAT -q90.7500 P!~PA wC~L -999,2500 FC%~L DEPT 8600.0Uo0 SP -50.7BI3 c,.~ GR -~90.2b00 NRAT -099.75n0 NCNL -999.~5~0 FCNb DEPT 8500,0000 SF!.,U SP -55.3750 OR ~R ~9~ .9,500 CALl NCNL -99q,2500 FCNb DEPT 8400.0000 SFLU SP -67.1562 GR GR -q99.2500 CALl, NRAT -09~.~5o0 PNP~ NCNL -~9~,~500 FCNL DEPT 8200 0000 SFI,,U SP -59i4.0~3 ~R GR -999 2500 CALl ~R~T -999.9500 ~a~A NCML -999,~500 FC~.~L DEPT 8000,000[) SFT,U SP 27.~175 CR GR, -q~g,~SnO CALl NCNL -q99.75o0 FCNL ~R -99q 2500 CAI 1, %TCNL -999. ~500 FCML, ,,p DE.. T 7800 0000 .~Ft.u' Sp -21 :~'7~.o ~a -099,7500 -090.2500 -090.2500 5.5352 77,62~0 -99a.7500 -o9o.2500 -090.25OO 3.5508 110.o375 Ogo 2500 -99o,2500 4.9766 112.~!.95 -999,2500 -990.7500 -999,2500 4 7852 ~00:9375 -a99.250o -090.2500 -990.~500 4 99 -099 -999 . '999, -990. '999. -999 . -999, 0 -999 -090, 82 , 5898 8125 2500 2500 7500 000 ?50O 2500 2500 7930 9500 2500 6465 7500 2500 2500 2500 .... 781 ~ 750 I hD DT NP~I ILQ TLD DT RHOB ~,~PH I I LO r,) T ~' P g i I LD DT ~HOB NPHI. :[ 1,, D P T [,' T -99q.2500 DR[{(] -099.2500 DEW 6.3672 -099,7500 -o99,2500 -999.2500 PEF 3.8984 -999,2500 -990,2500 DRHO -099.2500 5.5977 Ibm -099.2500 GR -°90,2500 DRHO -999.2500 PEF 5.3633 TL, U -999,25o0 GE -999.2500 ORNL] -090.2500 5.3047 -099.2500 :090,2500 DR~O q9q.?500 R.a437 TL~ -999'2500 DRHO -°99.2500 ~.1055 IbM -999.25~0 -999,~500 990.2500 DEF 3.R457 -999.2500 ~R -999,2500 -090.2500 3,5684 -999,2500 .-~99 2500 .99'.2500 6,2344 -099 2500 19 9i 5oo ~90 ?500 3,7148 -999,25n0 -999 2500 -999:2500 5 4844 -999i25n0 -999 2500 -999.?500 5 ~109 -0 915 oo -999, 500 -999.2b~0 5,~406 -999,,500 -999,~§00 -99Q. 500 .-99o 2500 o99'~25~() I . -q9'9..500 -999,2500 -090.2500 3,8672 -999,2500 -999,2500 -q99.~500 3,4492 DEPT 'I700.o000 SP -44.7813 ~R -999.2500 CAI.1 NRAT -999,7500 PNPA NCN[., -999,7500 WC~L DEDT 7600.0000 SF.LD S? 80,0675 NRAT -999,7500 ~N~A NCNb -q99,2500 -099 2 62 -999 -999 -099 55 -999 -090 -999 DEPT 7200 0000 SFI, U 5 s? 65:6875 c.~ 6o GR 999'2500 CALl -099 NR~T 1990: ?500 PNPA -999 ~CNL -~9q,2500 PC~.b -o99 DEPT 7400 OOC. 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T -9~6:~50() PNPA NC~I,~ -,q9~. 9500 FCNL DEPT 6000 . 0000 SP -? . 0793 -999.250{3 -09o.~5n0 3.5215 ~1,5e75 -o9Q.~5ou -999.25o0 3.5957 73.nooo -999,~5oo -999.~5oo -099.2500 TLD D T !LD PHnB KPMI 6 0313 43:!250 DT -q99.2500 RHOB -99Q.2500 -°9° 2500 2 6348 -999,7500 -999.7500 -o99.~500 3 &3R7 47: -,999.~500 o90.25~0 -990. 2500 60.~187 -999 250:(:.) -990:2500 -o99.750o ~.0957 75.000o -999,7500 -~9~.~500 -~q9,'2500 P,~449 6~,. 000 '099,2500 '99~.~500 -090.2500 2. 6641 I b D PHgB T DT 1: L D [? T I ,b r~ T I~ D -99q.~500 DRMO -q~a.2500 PEF 2.4805 lb -990.25oo GR -999,2500 DRHO -999.2500 2.9355 -~99.2500 (;R -999.2500 DRHO -09~.2500 DEF 2.8535 -999.2500 -999,2500 DRHO -~99.2500 3,3809 -a9a.2500 CH. -099.2500 DR['~O -999.2500 2.6758 Ti,~ -q99.2500 ~R -999.2500 DRHO -a99.2500 PEF 2.0801 IL'~'~ -999'2500 OR -999.2500 DRHO -999.2500 PEF 0293 -99¢~: 2500 -o99. 2500 DRH[] -09q,2500 PEF 8945 -o99.25n0 -999.2500 -999.2500 2 8496 -qgq~2500 -999 2500 -9 : soo 3.33~0 -999.2500 -999.2500 -99q.2500 3.5332 -999.2500 :2 9, soo .99.~500 3.1895 '999,2500 -999,~500 -099.2500 .2,~875 -999, ~500 .-999 500 3,0449 -999.~500 -~99,2500 -99~.2500 2,3320 099,25~0 :999,2500 -999.2500 2,~250 -999,.500 -999,~'500 -999. 500 2,o215 -~99.2500 [,VP O]o. N0? VEplp'ICAT],o,N I'..,TSTiV, G PAGE 10 GR -o99.?500 CAI, I NRAT -99o.2500 P~IPA ~CNI,, -990.2500 FC~L DEPT 5900.0000 SFr. U SP 2].gUO0 CR GR -99q.7500 CALl NRAT -09~.~500 ~,~A NC~L -999.2500 FCNb DEPT 5800.0000 SFl, b SP -39.n3~3 GA GR -090.9500 CA~,I NRAT -o99.~500 ~NRA NCNb -99q,7500 FCNL DEPT 5700.0000 SP -58.2500 CR GR -999.2500 CALI NRAT -e99,~500 RNPA WCNL -~99.P500 ~C~!L -o99 .7500 RHOB 2.7266 lbD 76.6875 DT 2999 P500 RHOB ~99~5o0 MPHI -99q,2500 1~.4922 TLD 36 0938 DT '~99:~500 3,0449 IbD 41,~250 DT -999,P500 ~HOB -999.7500 ~'PWI -999.~500 OEPT 5600 0000 gF~,,U 3 SP -31:1562 GR .~0~ R -999.25o0 CALl -999 RAT -o9~. ?500 ~N'RA -O9O NCML -999.2500 FCNb -~99 0000 gFLU 7813 00 CALl 25~0 DEPT 5500 8P -47 GR -99~ NRAT -099 NCML -999 DE ~ 5400, 000 SFLIJ SP -56,..438 GR GR -999 2500 CAIil ~R~T -~9o~ · 2500 PN~!A NCNL -999.2500 FC~tL DEPT 5300 0000 S~I,J SP -7~06,~5 CR ,.099,~500 NCNb -990.2500 ~C~[,~ 0000 P500 2500 FCNL DEPT 520:0 SP -70 MGR T -99~ RA -999 ~CNL -090 5100,0~000 ,SFLu -23. i zSO GR 3 56 -099 -090 -099 ~5801 TLD ,25n0 RHOB ,2500 724. 6 I.L O ~6~7 . ~ o ~: P P I 2500 TLD mT 2500 RHOB 'q99:~500 ~PRI ,~3. 625 ..1 -099.9500 DEPT 3,1602 ILD 40.3750 DT -999,2500 RHDB -°9°.2500 NPHI "999.~500 82. 2695 ILD ~750 DT -099.7500 DRHO 3.2676 Ih~ -q99.2500 GR -999.2500 DRMD -°9~.7500 PEF 10.0391 II, M -099,2500 GR -999.7500 DRHO -099.7500 PEr 1,1123 -999.2500 GR -999,2500 DRHO -999.2500 3,6563 IbM -q99.2500 ~R -999,2500 DRHO -o9q.2500 PEF 2,4297 IbM -099.25n0 GR 99. 7500 09~,1055 Tb~ - .2500 ¢]R -999 25...0 DRHO -o90:7500 PEF !. 2'134 ILM, -°99. 2500 ¢~R ,.999,2500 DRHO -~99 ,2:~ .... 0 I 6709 IbM qgo' -,....,.,2500 GR -999,2500 DRHO -090.~500 3.9102 -099,2,500 -999.2500 -o99.2500 3.0547 -999.2500 -999,2500 -099.2500 9.4531 99.2500 '999.2500 1 3779 -~99i2500 -999~500 -099 2500 3,6523 999,5009~9,2500 999,2500 2,6426 '990.2500 c~99,~500 -'099. 500 3,~688 -g99,.5o0 -g99,25.00 -o9g.2500 1.,4014 -999,2500 -099,2500 -q99.2500 1,8887 -999,2500 -999,~500 -999. 500 3,7754 -990,2500 LVP OlO.t!02. VEPfV,tCAT.[OI'~ t,TSTING PAGE 11 GR NCNL DEDT S? (IR NRAT NCNL DEPT S? NCNL DEPT SP NCNL -090.9500 CAI,I -°9°.7500 ~NRA -a90.2500 WCNL 5000.0000 SFt.,U -54.46t~ C.,R -09c~ 2500 CALl -99g,~500 FCNb 4mO0 0000 -7a: 1 250 -09a.2500 CA 1', Ji. -990.75()0 -090.2500 DEPT 4700.0000 SP -4~.71~8 CR ~RAT 090"2500 NCNL g99~2500 FC~L DEPT SP MRAT WCML DEPT sP SR N CN L OEPT sp GR T N C N L DEPT SP ~R ~R~T ~C~L 4500.0000 SfLL -35.~562 -99~ ~500 CAI I -o90:2500 -090.2500 FC~,'L 4400.0000 S~'I.U 29.65~3 CR -990,7500 PCNL -63. 750 GR ,.,099, ~500 CALl -o99.2500 .. C L .. F ' N -990.25n0 1~.4.297 27.8594 -990,2500 -99q.2500 -999,2500 5.0469 4&.0313 -999.25O0 -999.7500 3,~223 77.9375 -099,2500 -099,2500 '099.2500 990. 250O -a99. 2500 4.32B1 5~,.6875 -a90,2500 o9a.)500 -099,250O 5.1.641 76.~625 -a99,7500 a,, 7344 '/~" 3125 I -99~9.2500 -ag , -999,2500 DEPT 420o OOO0 SF'r,tJ 3,9893 S? -2~' 73.d. 4 GR 77 31.25 IL.r> D 'f H p N I ,~,, p ~41 lb,ri. 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PbO0 ~JPHI -~9o.2500 4100,n000 -30.O0~,2 eR -990.2b00 CAI, I -099.~500 rC~b 5,1875 ILD 71.31P5 DT -99~.2500 PHOB -999.2500 4200 0000 SFLU 67:~125 ~R -~99.2500 CALl -o9o.~500 PNPA -o9~.2500 ~CNI.~ 5.7383 ILD 62,53~3 PT -O99.9500 RHOB -099.2500 3nOn 0000 SFI,U '54:750() GR -099.P500 CALI -o9~,25n0 PNRA -e99.7500 FC~!L 3~00,0000 SFt, b -o9o,750U ~NPA -~90,9500 FCNL 6.3945 ILO 55.1875 DT -~99.~500 PHOB -09~.2500 -o99.?$0(.? 4.0000 66.q375 DT -o9~.?500 RHOB -~90.2500 -~9~,2500 3600. 0000 SFI,L! - t~4,, 5625 GR -o9q,~500 CALl -o9a.?!500 ~ I,,~ ~' a -~9o, 2500 FCNL 6. 0664 TI.,D 57.4:375 DT -99o 2500 -999: 25OO 35~0,0000 SFI.'U -24,a531 CR -O99,2500 CAI,! -~9~.7500 RNR~ -~99.2500 ~C~L 4.0703 77. -999. 2500 -Og0. 2500 -99~, 2500 .999,2500 CALl ?500 RNPA ?500 FCNL. 2,640 6 ~ b D 76.0675 PVi? ~ ' -999,.9.500 . HOB -°9q, 2500 x;P}'l I -999,250o 3300,7~000 8FI, U 8t. 3 ~,R 3,7 3 R 3 'I L ~ 65.~ 875 r)'i' -o99.2500 DRHU -o99.7500 Dh:F 5,n820 Ii,~ -o99.p500 qk -e99,25o0 DRanO -o9e,7500 PEF 3.0918 IL~ -999.7500 -999,2500 -o99,2500 PEF 3,5508 Ib~ -ogg.2b0o GR -999.2500 DRHO -990,7500 Pf;F 3.6484 -999,2500 GR -~99.2500 DR/~O -999,2500 , 8477 -n9. , 2500 -999. ,, 500 -°9°., 2500 2,B945 -q99,750() '999,2500 DRHO 3.517~ IL~~ -09~.2500 GR -999.2500 -999.2500 PLF 2.6797 -g99.2500 -999.2500 DRHO -099.7500 PEF .999.5547 It, M .PSo0 GR -99~.2500 -990.2500 5,1.758 -q99.2500 -099 250O 3.7285 -999.2500 -999.2500 -999,2500 4,2461 -O9a,2500 -999:2500 4,5000 -999.2500 -egg 2500 -699; 2500 3 951.2 -~99,2500 -~99,2500 -999.2500 -999. "00 -99O, 2500 -o99,2500 3,6055 -999,2500 -999,~500 -o90. 500 2,3379 -999.2500 :999,~500 999.2500 2,9062 -q99,25~0 LVP 010.~,;0,? VEPlFtf"ATI, n~s I.,ISTIWG PAGE 13 GR -990.2500 CALI ~R~T -990.~500 RNPA NC~)L -o90.25n0 ~CNL OEPT 3700.0000 SFI,U SP -37.9b~7 GR 6R -999.7500 CALl NR~T -09~,~500 Pb,~A ~CNL -99~.~500 PC~L: bEP~' 3100.0000 SFf,U SP -54.71~8 GR -¢9~.7500 CAf,I MRAT -q90,'250() R!'4RA MCNL -c~99,~500 DEPT 3000.0000 SP -23.5000 ~R -~99.7500 CALl NRAT -090.~500 RNRA NCNb -099.P5o0 FCML DEPT 2~00 0000 SFLU GR -99O ~500 CALl MRAT -09Oi7500 ?NRA NCNL -~99 ?500 WCNL :DEPT 2gO0.OOno SFLU SP 57.~875 CR 6R -099 ?500 CAf,.[ ~CNL -999:7500 MCteL DEPT 2700 00o0 SFLLi SP -61:4375 (.]R C~R -~9~ ~5o0 CALl NRAT -09q:P500 ~NPA ~CNI, gg~ 2500 ~C,~L :,DE, T 2 ()o.0000 SFf,U S P 4, g, A %', 75 G R ~ -990.2500 CAI,,]' NCNb -~9q. 2500 wC~.tI, :DEPT 2500 'SP GR WRA~' -990 NCNb -~90 0000 SFl,U 0 CAf,I ~5 0 FC~L p,! 2460,5000 SVLU -20'7656 6R -o99. 2500 P~qOb -qgq,PS00 ~PWI -gOO. ?500 3.2910 lbo 70.6250 PT -°99.2500 RHOB -~99.?500 ~PNI -999.?500 2.71.~$ II.,n 73.~375 DT -999.2500 PHOB -990.7500 ~PWI -o99.7500 2.9697 TLn 60.9375 DT -990.7500 -~90,7500 ~Pt,{'l' 1.,83~9 ILD 4~ 7813 I .9o9 2500 -999 33:B97~8 -o99 ?500 RB'OB -099'2500 ~P~I' -999. 2500 .1 250 DT 2500 250O 2( 00. 0000 ILD 27 .17~g -g99. 2500 -o9q. 2500 2.6582 Ih~ -og9.Pb00 GR -999.2500 DRHO -990.750() PEF 2.1523 II.,~ -999.7500 GR -999.2500 DRHO -a9q. P500 2.5938 ILH -999.2500 GR -099.9500 OR~O -999.2500 PEP 5879 ILl4 2,500 DRHO -990.7509 1.0107 II,~ -999.750o GR -999,2500 DRHO -o99.7500 PEV 8'755 IL~ 999 2500 DRHO :o99'2500 PEF -o99.2500 GR -999.2500 DRF~O -o9c).~500 p~:F 2000 ~00r) -o9c' ~ 500 GR -999, Pbf)O DRP. O -999.'2500 DEF 2000.0o00 -r~90. 250O 2500 -99~225oo 2.7637 -q99.2500 -999.2500 -999.2500 2,8867 -999,2500 -999,~500 -~99,7500 2.5742 -099.2500 -999.2500 -999.7500 ~.,8643 -090.2500 -090,2500 999.2500 1,1.699 -999.2500 '999,~500 -999 .... 500 0,~868 -090, .... 500 :099,2500 o99,2500 3,0313 -999.2500 -999.2500 -990.2500 49,7188 -g99.2500 -o99,2500 27.5156 -999.2500 LVP 01~.!;07 VEq]~IC'~,~'mlnN I,.,IGT[I~!(; PAGE 14 ~R NR~,T ~ C~I~ ~ -o9_o.75no C'A).I -099. 2500 · ..qgq. 25o0 -g9q.~500 PHOb -99g.2500 ** FILW TRAI[,EP ** FIt,E NAiF :FDTT .Onl VERSIOn: # : DATE : ~A~I~UU I, ENGTH : ~024 ~ILE TWPF NEYT FILE ~AME : EOF ********** -999.2500 DRNO -o99.2500 PEF -q99.2500 -99q.2500 ** TAPE SERV%CF MAHE :EDIT DATE :P4/10t~8 ORIGIN :o000 TAPE CONTIN~ATION ~ :01 NEXT ~AP~ NA~E : CO~MFNTS : SERVICE NA~E :EDIT DA~E :~4/10/~8 ORIGIN : COMT~NUATION ~ EOf' EOF . .............................. . RECEIVED * ALASKA COMPUTING CENTER * . .............................. OCT 1 5 1998 ...................... ] ......- sc,~mGm ........ Ala~a Oil & Gas C, ons. .............................. COMPANY NAFIE : ARCO ALASKA, INC. WELL NAME : D.S. 15-16 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292111500 REFERENCE NO : 98501 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/ 6 ORIGIN : FLIC REEL NA~E : 98501 CONTINUATION # : PREVIOUS REEL : CO~ENT : ARCO ALASKA, DS15-16, PRUDHOE BAY, API #50-029-21115-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/ 6 ORIGIN : FLIC TAPE NAME : 98501 CONTINUATION # : 1 PREVIOUS TAPE : COMFiENT : ARCO ALASKA, DS15-16, PRUDHOE BAY, API #50-029-21115-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S. 15-16 API NUFiBER: 500292111500 OPERATOR: Arco Alaska, Inc. LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES TAPE CREATION DATE: 6-0CT-98 JOB NUFiBER: 98501 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: A WORTHINGTO SURFACE LOCATION SECTION: 22 TOWNSHIP: 1 iN RANGE: 14E FNL: FSL: 165 FEL: 854 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 71. O0 DERRICK FLOOR: 70. O0 GROUND LEVEL: 41. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 8. 500 7. 000 11848.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (FiEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUFiBER: PASS--ER: DATE LOGGED: 28-JUN-84 LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 11729.0 11723.5 11717.0 11716.0 11712.5 11710.0 11707.5 11703.0 11701.0 11696.5 11696.0 11690.5 1i 674.5 11672.0 11658.5 11656.5 11650.5 11648.5 11647.5 11646.0 11644.0 11641.0 11640.0 11635.0 11634.5 11631.5 11628.0 11625.0 11624.5 11621.5 11619.0 11618.5 11616.0 11602.5 11601.5 11596.0 11592.0 11591.5 11589.5 11588.0 11584.0 11582.5 11575.5 11572.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88885.5 88888.5 11726.5 11724.0 11716.5 11716.5 11712.0 11711.5 11708.0 11703.5 11702.0 11694.5 11694.5 11688.0 11674.5 11673.0 11658.5 11659.0 11651.5 11650.5 11647.0 11645.0 11645.0 11640.5 11640.5 11634.0 11636.5 11630.0 11630.0 11624.5 11623.5 11621.0 11620.5 11617.0 11616.5 11615.0 11603.5 11602.0 11596.0 11596.5 11593.5 11593.5 11589.5 11591.0 11588.5 11584.0 11584.5 11578.5 11574.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 11571.0 11573.0 100.0 101.5 102.0 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 15-16 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAF~A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAM~IA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11727.5 11569.5 RST 11741.5 11570.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1244213 O0 000 O0 0 i 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 1 1 i 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1244213 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: ** DATA ** DEPT. 11834.000 NBAC.RST -999.250 FBAC. RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF.RST DEPT. 11500.000 NBAC. RST -999.250 FBAC.RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF.RST -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SBNA. FIL TRA T. FIL BSAL . RST SFNC. RST TENS. RST GR.BCS -999 250 SBNA.FIL -999 250 TRAT. FIL -999 250 BSAL.RST -999 250 SFNC.RST -999 250 TENS.RST -999 250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 49.469 -999.250 -999.250 -999.250 -999.250 -999.250 81.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 2 DEPTH INCREMENT: 0.5000 FILE SOlV~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: GRCH 11730.0 11548.5 RST 11741.5 11548.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH 88888 0 11731 0 11728 0 11723 0 11720 5 11718 5 11714 5 11712 5 11710 5 11710 0 11708 5 11707.5 11702.5 11701.0 11700.5 11697.5 11696.5 11692.5 11685.5 11684.0 11681.5 11678.5 11677.5 11674.0 11672.0 11669.5 11669.0 11668.5 11664.0 11663.5 11655.5 11654.5 11653.5 11651.5 11649.0 11648.5 11645.5 11643.5 11641.5 11639.5 11635.0 11633.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST .............. 88888.0 88888.5 11718.5 11712.0 11709.5 11708.0 11700.5 11697.0 11694.5 11685.5 11682.5 11679.0 11673.0 11669.0 11664.0 11654.0 11651.5 11641.0 11634.0 11731.5 11729.0 11724.0 11722.0 11716.0 11711.5 11708.0 11703.5 11701.5 11695.5 11685.0 11679.0 11674.5 11671.0 11670.0 11664.5 11659.0 11656.0 11654.0 11651.0 11648.0 11645.0 11641.0 11636.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PA GE: 11629 11627 11625 11621 11618 11614 11612. 11606. 11603. 11599. 11595. 11594. 11591. 11590. 11589. 11589. 11582. 11582. 11574. 11572. 11571. 100. $ 0 11630.0 5 11630.0 0 11624.5 5 11623.5 5 11617.5 5 11616.5 0 11612.5 0 11607.0 11606.5 0 11604.0 5 11601.0 0 11596.5 5 11593.5 5 11589.5 5 11593.5 5 11588.5 0 11591.0 5 11583.5 0 11585.0 5 11578.5 0 11574.5 0 11573.0 0 102.5 102.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2ANDGRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11741.500 NBAC. RST 2626.075 FBAC.RST 3365.934 SBNA.FIL SFNA.FIL 19.751 SBFA.FIL 42.491 SFFA.FIL 17.071 TRAT. FIL IRAT. FIL 0.496 CIRN. FIL 1.292 CIRF.FIL 2.676 BSAL.RST SIBF. RST 51.300 TPHI.RST 36.223 SFFC.RST 14.839 SFNC. RST SIGM. RST 14.836 DSIG.RST 2.491 GRCH. RST -999.250 TENS.RST CCL.RST -0.002 CRRA.RST 1.990 FBEF. RST 55.400 DEPT. 11548.000 NBAC. RST 2505.338 FBAC.RST 3364.797 SBNA.FIL SFNA.FIL 23.568 SBFA.FIL 47.399 SFFA.FIL 19.875 TRAT. FIL IRAT. FIL 0.414 CIRN. FIL 0.723 CIRF. FIL 1.914 BSAL.RST SIBF. RST 74.431 TPHI.RST 34.252 SFFC.RST 17.526 SFNC.RST SIGM. RST 17.132 DSIG.RST 4.957 GRCH. RST -999.250 TENS.RST CCL.RST 0.014 CRRA.RST 2.407 FBEF. RST 60.346 47.140 0.970 81.178 17.613 1499.000 59.679 0.908 140.472 20.822 1492.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 3 DEPTH INCREF~TT: 0.5000 FILE SUF~VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11729.5 11580.5 RST 11743.0 11582.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFIBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88887.5 88890.0 11736.0 11738.0 11731.0 11731.5 11726.0 11726.0 11721.0 11722.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 10 11716.0 11716.5 11712.5 11712.0 11710.5 11712.0 11708.0 11708.0 11703.5 11704.0 11697.5 11697.0 11696.5 11695.0 11687.5 11685.5 11678.5 11679.0 11676.0 11675.5 11674.0 11674.5 11670.5 11671.5 11669.0 11668 . 5 11664.0 11665.5 11656.5 11659.0 11649.5 11650.5 11649.0 11651.0 11644.5 11646.5 11644.0 11645.0 11639.5 11640.5 11635.5 11634.0 11634.5 11636.5 11629.0 11630.0 11627.5 11629.5 11625.0 11624.5 11623.5 11623.5 11618.5 11617.5 11618.0 11616.5 11612.5 11612.0 11603.0 11604.0 11595.5 11596.5 11592.0 11593.0 11591.0 11593.0 11590.5 11592.0 11589.5 11591.0 11587.5 11588.5 11583.0 11583.5 11582.5 11584.5 100.0 100.5 102.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 3 i 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 12 ** DATA ** DEPT. 11743.000 NBAC.RST SFNA.FIL 19.802 SBFA.FIL IRAT. FIL 0.491 CIRN. FIL SIBF. RST 52.429 TPHI.RST SIGM. RST 14.977 DSIG.RST CCL.RST -0.001 CRRA.RST DEPT. 11580.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST CCL.RST -999.250 CRRA.RST 2658.311 FBAC.RST 40.670 SFFA.FIL 1.259 CIRF. FIL 36.357 SFFC.RST 2.297 GRCH.RST 1.998 FBEF. RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC. RST -999.250 GRCH.RST -999.250 FBEF.RST 3427.986 SBNA.FIL 17.190 TRAT. FIL 2.671 BSAL.RST 14.977 SFNC. RST -999.250 TENS.RST 58.395 -999.250 SBNA. FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST 56.313 TENS.RST -999.250 46. 048 O. 969 84.173 17. 680 1451. 000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : OOiCO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 11730.0 RST 11741.5 STOP DEPTH .......... 11575.5 11578.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 13 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFIBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88888.0 88888.5 11735.0 11735.5 11732.5 11731.5 11726.5 11727.5 11722.5 11724.0 11719.0 11722.0 11716.5 11716.5 11714.0 11716.0 11711.5 11712.0 11709.0 11711.5 11706.5 11708.0 11702.5 11703.5 11700.5 11701.0 11699.5 11701.0 11697.0 11697.0 11696.5 11695.5 11684.5 11685.0 11678.0 11678.5 11674.5 11675.5 11674.5 11668.0 11670.0 11664.0 11664.0 11655.5 11659.0 11651 . 5 11654.0 11650.0 11651.5 11648.0 11650.5 11645.5 11647.5 11645.0 11646.5 11643.5 11645.0 11639.5 11640.5 11639.0 11640.5 11634.5 11634.5 11634.0 11636.0 11627.5 11627.0 11629.5 11624.5 11625.0 11623.0 11623.5 11618.0 11616.5 11617.5 11617.5 11616.0 11615.0 11612.0 11612.0 11603.5 11604.5 11599.0 11600.5 11590.5 11593.0 11588.0 11588 . 5 11590.0 11583.5 11584.0 11582 . 0 11584.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 14 11578.0 11577.5 100.0 99.5 $ 102.5 REMAR3Ag: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) DEPT FT 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 15 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELI~I CODE (HEX) CIRF FIL 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMRST CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11741.500 NBAC.RST 2667.877 FBAC.RST SFNA.FIL 17.593 SBFA.FIL 75.643 SFFA.FIL IRAT. FIL 0.483 CIRN. FIL 0.601 CIRF. FIL SIBF.RST 137.919 TPHI.RST 31.219 SFFC. RST SIGM. RST 16.090 DSIG.RST 1.528 GRCH.RST CCL.RST 0.000 CRRA.RST 1.962 FBEF. RST DEPT. 11575.500 NBAC.RST -999.250 FBAC. RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF.RST 3212 478 16 425 1 524 15 669 -999 250 60 442 -999 250 -999 250 -999 250 -999 250 53 232 -999 250 SBNA. FIL TRA T. FIL BSAL. RST SFNC. RST TENS. RST SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST TENS.RST 98. 921 O. 831 280. 766 17.196 1674. 000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILETYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 5 DEPTH INCRE~IENT: 0.5000 FILE SU~F~L~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11729.5 11564.5 RST 11742.5 11566.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11736.5 11733.0 11727.0 11722.5 11719.0 11717.0 11714.5 11713.0 11710.0 11707.0 11702.5 11697.0 11693.5 11681.5 11679.0 11675.0 11673.0 11671.0 11668.0 11656.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88889 5 11738 0 11732 0 11727 5 11724 0 11721 5 11716.5 11712.0 11694.5 11675.5 11716.0 11711.5 11708.0 11703.5 11695.5 11682.5 11678.5 11674.5 11671.0 11669.5 11659.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 17 11651.0 11654.0 11649.5 11650.5 11648.5 11651.0 11645.5 11647.5 11644.5 11646.5 11639.0 11640.5 11634.5 11636.5 11633.5 11634.0 11627.0 11629.5 11625.0 11627.0 11624.5 11625.0 11617.5 11617.0 11602.0 11601.5 11593.5 11595.5 11590.5 11588.5 11590.0 11593.0 11588.0 11590.5 11584.5 11583.5 11582.5 11585.0 11577.0 11577.5 100.0 100.5 102.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 18 TYPE REPR CODE VALUE .............................. 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 Ti{ATFIL 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 SIGMRST CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 CRRARST 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST CCL.RST 11742.500 NBAC. RST 2836.542 FBAC.RST 3555.758 SBNA.FIL 99.989 17.561 SBFA.FIL 76.894 SFFA.FIL 17.583 TRAT. FIL 0.812 0.488 CIRN. FIL 0.592 CIRF. FIL 1.462 BSAL.RST 284.731 139.967 TPHI.RST 29.808 SFFC. RST 16.987 SFNC.RST 17.372 17.424 DSIG.RST 1.516 GRCH. RST -999.250 TENS.RST 1555.000 0.000 CRRA.RST 2.022 FBEF. RST 61.413 DEPT. 11564.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT.FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF. RST -999.250 TPHI.RST -999.250 SFFC. RST -999.250 SFNC. RST -999.250 SIGM. RST -999.250 DSIG.RST -999.250 GRCH. RST 84.438 TENS.RST -999.250 CCL.RST -999.250 CRRA.RST -999.250 FBEF. RST -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 19 ** E~D OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INC~: 0.5000 FILE SUF~VlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11730.5 11582.5 RST 11741.5 11585.0 $ CURVE SHIFT DATA - PASS TO PASS (f4EASUR3F29 DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: I .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88888.5 88888.5 11736.0 11736.5 11732.5 11732.0 11726.5 11727.5 11722.0 11724.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 2O 11715.0 11715.5 11714.5 11716.0 11711.5 11712.0 11709.5 11711.5 11705.5 11707.5 11702.0 11703.5 11698.5 11700.5 11697.0 11697.5 11696.5 11696.5 11688.5 11689.0 11674.0 11676.0 11673.0 11673.5 11663.5 11666.5 11655.0 11659.0 11649.0 11650.5 11648.0 11650.5 11645.0 11647.5 11643.5 11646.5 11643.0 11645.0 11639.5 11641 · 5 11633.5 11636.0 11632.0 11633 . 0 11626.0 11628.5 11625.5 11627.0 11624.0 11624.5 11622.5 11623.5 11617.5 11617.5 11611.5 11612.5 11610.5 11612.0 11591.5 11593.5 11591 · 0 11593.5 11589.5 11591.5 11586.5 11588.5 11585.0 11588.0 11583.5 11584.0 100.0 100.5 103.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHBORAXPASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) ....................................................................................... O0 000 O0 0 6 1 1 4 68 0000000000 DEPT FT 1244213 NBAC RST CPS 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1244213 00 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 BSALRST PPK 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF RST CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI RST PU-S 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC RST CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC RST CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 SIGMRST CU 1244213 00 000 O0 0 6 1 1 4 68 0000000000 DSIG RST CU 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 GRCHRST GAPI 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 TENS RST LB 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 CCL RST V 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 CRRARST 1244213 00 000 O0 0 6 1 1 4 68 0000000000 FBEF RST UA 1244213 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 22 ** DATA ** DEPT. 11741. 500 NBAC. RST SFNA.FIL 18. 739 SBFA.FIL IRAT. FIL O. 483 CIRN. FIL SIBF. RST 137. 824 TPHI.RST SIGM. RST 18 . 286 DSIG. RST CCL. RST 0 . 000 CRRA. RST DEPT. 11582.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST CCL.RST -999.250 CRRA.RST 2641. 81. O. 36. 2. 2. -999. -999. -999. -999. -999. -999. 711 FBAC.RST 430 SFFA.FIL 552 CIRF. FIL 825 SFFC. RST 007 GRCH.RST 028 FBEF. RST 250 FBAC.RST 250 SFFA.FIL 250 CIRF. FIL 250 SFFC.RST 250 GRCH. RST 250 FBEF. RST 3573.024 SBNA.FIL 18.677 TRAT. FIL 1.277 BSAL.RST 17.350 SFNC.RST -999.250 TENS.RST 62.686 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST 116.642 TENS.RST -999.250 100.540 0.890 280.581 18.072 1499.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUF1BERS RST 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 23 Rb2~%RKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~4 CODE (HEX) DEPT FT 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC RST CPS 1244213 O0 000 O0 0 7 1 I 4 68 0000000000 FBAC RST CPS 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT RSAV 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT RSAV 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNRSAV 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 CIRFRSAV 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 BSALRSAV PPK 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI RSAV PU-S 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUI4~ SAMP ELEM CODE (HEX) SIGM RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG RSAV CU 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH RST GAPI 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF RSAV UA 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 CRRARSAV 1244213 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11741. 500 NBAC. RST 2277. 719 FBAC. RST 3319. 175 SBNA. RSAV 49. 308 SFNA.RSAV 19. 767 SBFA.RSAV 39. 032 SFFA.RSAV 17. 396 TRAT. RSAV O . 968 IRAT.RSAV 0.497 CIRN. RSAV 1.278 CIRF. RSAV 2.673 BSAL.RSAV 82.293 SIBF. RSAV 51. 718 TPHI.RSAV 36.104 SFFC.RSAV 15.160 SFNC. RSAV 17. 625 SIGM. RSAV 15.166 DSIG.RSAV 2. 300 GRCH. RST -999. 250 FBEF. RSAV 55. 547 CRRA . RSA V 2.002 DEPT. 11569.500 NBAC.RST -999.250 FBAC. RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999. 250 DSIG. RSAV -999. 250 GRCH. RST 13.161 FBEF. RSAV -999. 250 CRRA. RSAV - 999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE ' 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO IJ~ST FILE : **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 25 FILE HEADER FILE NUFIBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUF~ER : 1 DEPTH INCREMFIVT: 0.5000 FILE SUF~N~RY VENDOR TOOL CODE START DEPTH ........................... RST 11780.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 11516.0 31 -MAY-98 8Cl -205 1149 31 -MAY-98 11750.0 11764.0 11546.0 11741.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY RST RESERVOIR SATURATION $ TOOL NU~ER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 11848.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WEL~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 26 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Tied into SWS Cement Bond Log dated 6-28-1984 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 27 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) DEPT FT 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CS PSl F/HR 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PSl V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CRRAPS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS1 S 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PSl V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS1 1244213 00 000 00 0 8 1 1 4 68 0000000000 RCAKPS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS1 V 1244213 00 000 O0 0 8 1 1 4 68 0000000000 FPDE PSl V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS1 V 1244213 00 000 O0 0 8 1 1 4 68 0000000000 FSCR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS1 S 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS1 PSIG 1244213 00 000 O0 0 8 1 1 4 68 0000000000 HVPV PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS1 UA 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 GDCUPS1 MA 1244213 00 000 O0 0 8 1 1 4 68 0000000000 EXCU PS1 UA 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS1 UA 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS1 UA 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 3fHV PS1 V 1244213 O0 000 O0 0 8 i 1 4 68 0000000000 XPSV PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS1 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 X~2V PS1 V 1244213 00 000 O0 0 8 1 1 4 68 0000000000 RXFR PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS1 1244213 00 000 O0 0 8 1 1 4 68 0000000000 RXRC PS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS1 MA 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS1 PPK 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1244213 O0 000 00 0 8 1 1 4 68 0000000000 CIRNPS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 CIRFPS1 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 28 NA~4E SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELb~4 CODE (HEX) ....................................................................................... O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1244213 CIRFFIL 1244213 O0 DSIG PS1 CU 1244213 O0 FBAC PS1 CPS 1244213 O0 IRAT PS1 1244213 O0 IRAT FIL 1244213 O0 NBAC PS1 CPS 1244213 O0 SFNA PS1 CU 1244213 O0 SFFA PS1 CU 1244213 O0 SBNA PS1 CU 1244213 O0 SBFA PS1 CU 1244213 O0 SFNA SIG CU 1244213 O0 SFFA SIG CU 1244213 O0 SBNA SIG CU 1244213 O0 SBFA SIG CU 1244213 O0 SFNA FIL CU 1244213 O0 SFFA FIL CU 1244213 O0 SBNA FIL CU 1244213 O0 SBFA FIL CU 1244213 O0 SIBF PS1 CU 1244213 O0 SFNC PS1 CU 1244213 O0 SFFC PS1 CU 1244213 O0 SIGMPS1 CU 1244213 O0 SIBF SIG CU 1244213 O0 SIGM SIG CU 1244213 O0 TRAT PS1 1244213 O0 TRAT SIG 1244213 O0 TRAT FIL 1244213 O0 GR PS1 GAPI 1244213 O0 RDIX PS1 1244213 O0 CRNI PS1 KHZ 1244213 O0 CRFI PS1 K~Z 1244213 O0 RSCS PS1 1244213 O0 CTM PS1 DEGC 1244213 O0 XTM PS1 DEGC 1244213 O0 TAV PS1 KV 1244213 O0 FICU PS1 AMP 1244213 O0 CACUPS1 AMP 1244213 O0 BUST PS1 1244213 O0 BUSP PS1 1244213 O0 RSXS PS1 1244213 O0 TPHI PS1 PU 1244213 O0 TPHI SIG PU 1244213 O0 CCLC PS1 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 000 O0 0 8 1 1 4 68 0000000000 V 1244213 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PA GE: 29 DEPT. 11780.500 CS.PS1 1875.489 TENS.PSI NPDE. PS1 1446.038 NSCE. PS1 2.748 CRRA.PS1 AQTM. PS1 0.661 CHV. PS1 201.096 CP5V. PS1 C~I2V. PS1 -12.250 RCFR.PS1 0.000 RCLC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 FSCE. PS1 2.253 FSCR.PS1 -0.267 AQTF. PS1 HVPV. PS1 158.936 BMCU. PS1 31.640 GDCU. PS1 NBEF. PSI 24.994 FBEF. PS1 50.236 NPGF. PS1 BSTR.PS1 50.429 BSPR.PS1 1.103 MARC. PSi XP5V. PS1 5.069 XP2V. PS1 12.114 X~2V. PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 SFFA.PS1 -999.250 SBNA.PS1 -999.250 SBFA. PS1 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS1 -999.250 SFFC. PS1 -999.250 SIGM. PS1 SIGM. SIG -999.250 TRAT. PS1 -999.250 TRAT. SIG GR.PS1 33 . 647 RDIX. PS1 37413. 000 CRNI.PS1 RSCS. PS1 8463.000 CTM. PS1 65.918 XTM. PS1 FICU. PS1 2. 329 CACU. PS1 2. 515 BUST. PS1 RSXS.PS1 8878.000 TPHI.PS1 -999.250 TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CI42V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XP5V. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 RSCS.PS1 FICU. PS1 RSXS.PS1 11516.000 1453.782 1 322 -12 250 0 000 2 011 159 103 22 718 65.999 5.081 0.000 129.717 1.031 0.443 11.940 0.179 12.219 12.227 0.173 14.496 8463.OOO 2.327 8878.000 CS.PS1 NSCE. PS1 CHV. PS1 RCFR. PS1 RTDF. PS1 FSCR. PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC.PS1 TRAT. PS1 Ri)IX. PSI CTM. PS1 CACU. PS1 TPHI.PS1 1733.536 TENS.PSi 2.827 CRRA.PS1 200.248 CP5V. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.218 AQTF. PS1 30.761 GDCU. PS1 54.773 NPGF. PS1 1.142 MARC. PSi 12.116 XM2V. PS1 0.000 RXAK. PS1 2.432 CIRN. PS1 2.978 DSIG. PS1 0.445 NBAC. PS1 67.245 SBFA. PSi 5.301 SBFA.SIG 61.662 SBFA.FIL 10.415 SIGM. PS1 0.777 TRAT. SIG 44357.000 CRNI. PS1 70.801 XTM. PS1 2.503 BUST. PSi 22.317 TPHI.SIG 1350.000 2.010 5.050 0.000 1389.161 0.661 60.996 0.985 0.000 -12.387 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 461.008 65.918 3.000 -999.250 1445 000 2 411 5 074 0 000 1391 603 1 322 60 073 0.999 0.000 -12.376 0.000 1.027 2.127 2529.781 45.276 3.577 44.685 10.391 0.012 448.959 70.313 3.000 0.535 NPHV. PS1 NSCR. PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA. PS1 SFNA. SIG SFNA. FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 1469.728 0.521 12.158 0.000 1369.325 142.398 7.890 0.993 199.885 0 000 22 439 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 229.364 95.031 3.000 -0.010 1475.831 -0.369 12.165 0.000 1372.720 147.691 8.975 1.004 200.052 0.000 20.711 3 039 3304 542 14 022 0 445 14 603 70 110 0.971 0.774 186.448 94.987 3.000 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 3O **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUf4~ER : 2 DEPTH INCREMENT: 0.5000 FILE SUFmfARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11776.0 11496.0 RST $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIt4~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPH~) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 31 -MAY-98 8C1-205 1149 31 -MAY-98 11750.0 11764.0 11546.0 11741.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 31 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE Tb~4PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11848.0 PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Tied into SWS Cement Bond Log dated 6-28-1984 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 32 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CS PS2 F/HR 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVPS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS2 V 1244213 O0 000 00 0 9 1 1 4 68 0000000000 NSCE PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS2 S 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 C~2V PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKPS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVPS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS2 V 1244213 00 000 O0 0 9 1 1 4 68 0000000000 FSCR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS2 S 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS2 PSIG 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS2 UA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 33 NAME SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) ....................................................................................... GDCU PS2 MA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 EXCUPS2 UA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS2 UA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS2 UA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS2 V 1244213 O0 000 O0 0 9 i 1 4 68 0000000000 XPSV PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 XI~2V PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 R3fLC PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU PS2 MA 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BSALPS2 PPK 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BSALSIG PPK 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS2 CPS 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1244213 O0 000 O0 0 9 1 I 4 68 0000000000 SIGMSIG CU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 34 NA~E SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELI~4 CODE (HEX) RDIX PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS2 KHZ 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS2 KHZ 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS2 DEGC 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 XTM PS2 DEGC 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TAV PS2 KV 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS2 AMP 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS2 AMP 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS2 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1244213 O0 000 O0 0 9 1 i 4 68 0000000000 CCLC PS2 V 1244213 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11776.000 CS. PS2 NPDE.PS2 1455.079 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.211 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 2.038 FSCR.PS2 HVPV. PS2 159.180 BMCU. PS2 NBEF. PS2 26.598 FBEF. PS2 BSTR.PS2 42.986 BSPR.PS2 XPSV. PS2 5.089 XP2V. PS2 PJfLC. PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 73.470 RDIX. PS2 RSCS.PS2 8459.000 CTM. PS2 FICU. PS2 2.349 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 1473.900 2.831 200.370 0.000 0.000 -0.239 34.277 52.760 1.152 12 129 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 48181.000 71.777 2.510 -999.250 DEPT. 11496.000 CS.PS2 1393.441 NPDE. PS2 1456.224 NSCE. PS2 2.765 AQTM. PS2 1.322 CHV. PS2 200.612 CM2V. PS2 -12.240 RCFR.PS2 0.000 RCAK. PS2 0.000 RTDF. PS2 0.000 FSCE.PS2 1.987 FSCR.PS2 -0.201 HVPV. PS2 159.514 BMCU. PS2 32.843 TENS. PS2 1288.000 NPHV. PS2 CRRA.PS2 1.984 NSCR.PS2 CPSV. PS2 5.069 CP2V. PS2 RCLC. PS2 0.000 RCRC. PS2 FPHV. PS2 1394.044 FPDE. PS2 AQTF. PS2 0.661 SF6P. PS2 GDCU. PS2 59.356 EXCU. PS2 NPGF. PS2 0.999 FPGF. PS2 MARC. PS2 0.000 XHV. PS2 XM2V. PS2 -12.368 RXFR.PS2 RXAK. PS2 0.000 SHCU. PS2 CIRN. PS2 -999.250 CIRF. PS2 DSIG.PS2 -999.250 FBAC. PS2 NBAC. PS2 -999.250 SFNA.PS2 SBFA.PS2 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS2 SIGM. PS2 -999.250 SIBF. SIG TRAT. SIG -999.250 TRAT. FIL CRNI.PS2 442.069 CRFI.PS2 XTM. PS2 71.289 TAV. PS2 BUST. PS2 3.000 BUSP. PS2 TPHI.SIG -999.250 CCLC. PS2 1474.610 0.125 12.143 0.000 1374.017 149.817 7.890 1.003 199.885 0.000 17.886 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 222.863 94.888 3.000 0.010 TENS.PS2 1486.000 NPHV. PS2 1483.155 CRRA.PS2 2.283 NSCR.PS2 -0.546 CP5V. PS2 5.065 CP2V. PS2 12.173 RCLC. PS2 0.000 RCRC. PS2 0.000 FPHV. PS2 1396.485 FPDE. PS2 1375.276 AQTF. PS2 1.322 SF6P. PS2 152.780 GDCU. PS2 60.029 EXCU. PS2 8.140 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 35 NBEF. PS2 24.895 FBEF. PS2 BSTR.PS2 42.515 BSPR.PS2 XPSV. PS2 5.085 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 142.067 BSAL.SIG CIRN. FIL 0.590 CIRF. FIL IRAT. PS2 0.409 IRAT. FIL SFFA.PS2 21.836 SBNA.PS2 SFFA. SIG 0.523 SBNA.SIG SFFA.FIL 21.632 SBNA.FIL SFNC. PS2 24.634 SFFC. PS2 SIGM. SIG 0.378 TRAT. PS2 GR.PS2 21.156 RDIX. PS2 RSCS.PS2 8463.000 CTM. PS2 FICU. PS2 2.328 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 56.822 NPGF. PS2 1.133 MARC. PS2 12.121 X~2V. PS2 0.000 RXAK. PS2 2.083 CIRN. PS2 1.492 DSIG.PS2 0.405 NBAC. PS2 62.686 SBFA.PS2 3.118 SBFA.SIG 65.111 SBFA.FIL 19.073 SIGM. PS2 0.893 TRAT. SIG 57400.000 CRNI.PS2 74.463 XTM. PS2 2.502 BUST. PS2 37.400 TPHI.SIG 0.997 FPGF. PS2 0.000 XPIV. PS2 -12.377 RXFR.PS2 0.000 SHCU. PS2 0.624 CIRF. PS2 4.713 FBAC. PS2 2520.414 SFNA.PS2 54.884 SFNA.SIG 4.208 SFNA.FIL 55.955 SIBF. PS2 19.062 SIBF. SIG 0.017 TRAT. FIL 450.302 CRFI.PS2 72.009 TAV. PS2 3.000 BUSP. PS2 1.037 CCLC. PS2 0.996 200.115 0.000 21.822 1.443 3319.977 27.213 0.641 27.598 75.077 0.845 0.940 197.284 94.941 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE~ER FILE NUFi~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER : 3 DEPTH INCREmENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... RST 11796.0 11529.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 36 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 31 -MAY-98 8C1-205 1149 31 -MAY-98 11750.0 11764.0 11546.0 11741.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 11848.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Tied into SWS Cement Bond Log dated 6-28-1984 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 37 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 10 I 1 4 68 0000000000 CS PS3 F/HR 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NPHVPS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 38 NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) NPDE PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NSCE PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CRRAPS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NSCR PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 AQTMPS3 S 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CHV PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CP5V PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CP2V PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CM2V PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RCFR PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RCLC PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RCRC PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RCAKPS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RTDF PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FPHVPS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FPDE PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FSCE PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FSCR PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 AQTF PS3 S 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SF6P PS3 PSIG 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 HVPV PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BMCU PS3 UA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 GDCU PS3 MA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 EXCU PS3 UA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NBEF PS3 UA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FBEF PS3 UA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NPGF PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FPGF PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BSTR PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BSPR PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 MARC PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 XHV PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 XPSV PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 XP2V PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 X~2V PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RXFR PS3 1244213 00 000 O0 0 10 1 1 4 68 0000000000 RXLC PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RXRC PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RXAKPS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SHCU PS3 MA 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BSALPS3 PPK 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL SIG PPK 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNPS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNFIL 1244213 00 000 O0 0 10 1 1 4 68 0000000000 CIRF FIL 1244213 00 000 O0 0 10 1 1 4 68 0000000000 DSIG PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 NBAC PS3 CPS 1244213 O0 000 O0 '0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELEM CODE (HEX) ....................................................................................... SFNA PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFNC PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SFFC PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM SIG CU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT SIG 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RDIX PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CRNI PS3 KHZ 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CRFI PS3 KHZ 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RSCS PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CTM PS3 DEGC 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 XTM PS3 DEGC 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TAV PS3 KV 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 FICUPS3 AMP 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CACU PS3 AMP 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BUST PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 BUSP PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 RSXS PS3 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI SIG PU 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 CCLC PS3 V 1244213 O0 000 O0 0 10 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 11796.000 NPDE. PS3 1455.957 NSCE. PS3 AQTM. PS3 0.661 CHV. PS3 CM2V. PS3 -12.231 RCFR.PS3 RCAK. PS3 0.000 RTDF. PS3 FSCE. PS3 2.005 FSCR.PS3 HVPV. PS3 159.912 BMCU. PS3 NBEF. PS3 28.024 FBEF. PS3 BSTR.PS3 44.873 BSPR.PS3 CS.PS3 1441.730 TENS.PS3 817.000 NPHV. PS3 1489.259 2.822 CRRA.PS3 2.015 NSCR.PS3 -0.153 201.339 CPSV. PS3 5.030 CP2V. PS3 12.173 0.000 RCLC. PS3 0.000 RCRC. PS3 0.000 0.000 FPHV. PS3 1394.044 FPDE. PS3 1374.932 -0.434 AQTF. PS3 0.661 SF6P. PS3 153.400 36.328 GDCU. PS3 60.340 EXCU. PS3 7.101 56.473 NPGF. PS3 1.003 FPGF. PS3 1.003 1.113 MARC.PS3 0.000 XHV. PS3 199.885 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 4O XP5V. PS3 5.089 XP2V. PS3 RXLC. PS3 0.000 RXRC. PS3 BSAL.PS3 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS3 -999.250 IRAT. FIL SFFA.PS3 -999.250 SBNA. PS3 SFFA.SIG -999.250 SBNA. SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS3 -999.250 SFFC. PS3 SIGM. SIG -999.250 TRAT. PS3 GR.PS3 107.669 RDIX. PS3 RSCS.PS3 8459.000 CTM. PS3 FICU. PS3 2.334 CACU. PS3 RSXS.PS3 8878.000 TPHI.PS3 DEPT. 11529.500 CS.PS3 NPDE. PS3 1456.643 NSCE. PS3 AQTM. PS3 1.102 CHV. PS3 CM2V. PS3 -12.240 RCFR.PS3 RCAK. PS3 2.000 RTDF. PS3 FSCE.PS3 1.982 FSCR.PS3 HVPV. PS3 159.729 BMCU. PS3 NBEF. PS3 25.381 FBEF. PS3 BSTR.PS3 45.073 BSPR.PS3 XPSV. PS3 5.082 XP2V. PS3 R32LC. PS3 0.000 RXRC. PS3 BSAL.PS3 130.019 BSAL.SIG CIRN. FIL 0.985 CIRF. FIL IRAT. PS3 0.442 IRAT. FIL SFFA.PS3 13.176 SBNA.PS3 SFFA.SIG 0.273 SBNA.SIG SFFA.FIL 13.420 SBNA.FIL SFNC. PS3 13.755 SFFC. PS3 SIGM. SIG 0.180 TRAT. PS3 GR.PS3 89.023 RDIX. PS3 RSCS.PS3 8463.000 CTM. PS3 FICU. PS3 2.293 CACU. PS3 RSXS.PS3 8878.000 TPHI.PS3 12.114 XM2V. PS3 -12.368 0.000 RXAK. PS3 0.000 -999.250 CIRN. PS3 -999.250 -999.250 DSIG. PS3 -999.250 -999.250 NBAC. PS3 -999.250 -999.250 SBFA.PS3 -999.250 -999.250 SBFA.SIG -999.250 -999.250 SBFA.FIL -999.250 -999.250 SIGM. PS3 -999.250 -999.250 TRAT. SIG -999.250 60230.000 CRNI.PS3 455.912 73.731 XTM. PS3 71.289 2.505 BUST. PS3 3.000 -999.250 TPHI.SIG -999.250 1757.305 TENS.PS3 2.780 CRRA.PS3 200.612 CP5V. PS3 0.000 RCLC. PS3 0.000 FPHV. PS3 -0.027 AQTF. PS3 32.995 GDCU. PS3 59.842 NPGF. PS3 1.052 MARC. PS3 12.121 XPI2V. PS3 0.000 RXAK. PS3 2.404 CIRN. PS3 2.789 DSIG. PS3 0.440 NBAC. PS3 59.231 SBFA.PS3 2.925 SBFA.SIG 59.631 SBFA.FIL 11.597 SIGM. PS3 0.799 TRAT. SIG 67254.000 CRNI.PS3 73.242 XTM. PS3 2.504 BUST. PS3 24.644 TPHI.SIG 1446.000 2.358 5. 060 O. 000 1396. 485 1. 102 60.237 1.000 0.000 -12.368 1.000 0.983 2.265 2472.478 44.563 5.004 46.343 11.427 0.012 445.245 72.266 3.000 0.591 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA. PS3 SFNA. SIG SFNA. FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 TAV. PS3 BUSP.PS3 CCLC.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 TAV. PS3 BUSP. PS3 CCLC.PS3 0 000 19 837 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 226.244 95.175 3.000 0.000 1488.038 0.093 12.180 0.000 1376.306 154.439 8.236 1.000 200.218 0.000 22.195 2.791 3307.594 16.229 0.300 16.167 70.230 0.960 0.802 188.844 94.987 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 41 **** FILE HEADER **** FILENAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 4 DEPTH INCREDfF2Fr: 0.5000 FILE SU~UL~Y VENDOR TOOL CODE START DEPTH ........................... RST 11764.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 11523.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMARAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 31-MAY-98 8C1-205 1149 31-MAY-98 11750.0 11764.0 11546.0 11741.0 TOOL NUFIBER ........... CGRS-A RST-A 8.500 11848.0 PRODUCED FLUIDS 9. O0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 42 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Tied into SWS Cement Bond Log dated 6-28-1984 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-i998 16:20 PAGE: 43 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CS BX1 F/HR 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX1 LB 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NPHVBX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NPDE BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NSCE BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CRRABX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NSCR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 AQTMBX1 S 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CHV BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CPSV BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CP2V BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CM2V BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RCFR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RCLC BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RCRC BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RCAKBX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RTDF BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FPHVBX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FPDE BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FSCE BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FSCR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 AQTF BX1 S 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SF6P BXl PSIG 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 HVPV BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 BMCU BX1 UA 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 GDCU BX1 MA 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 EXCU BX1 UA 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NBEF BX1 UA 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FBEF BXl UA 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 NPGF BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FPGF BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 BSTR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 44 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) BSPR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 MARC BX1 1244213 O0 000 00 0 11 1 1 4 68 0000000000 XA~/ BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 XPSV BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 XP2V BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 ~2V BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RXFR BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RXLC BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RXRC BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RXAKBXl 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SHCU BX1 MA 1244213 O0 000 00 0 11 1 1 4 68 0000000000 BSALBX1 PPK 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL SIG PPK 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNBX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CIRFBXl 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 DSIG BXl CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX1 CPS 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 00 0 11 1 1 4 68 0000000000 NBAC BX1 CPS 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA BX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA BXl CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA BX1 CU 1244213 O0 000 00 0 11 1 1 4 68 0000000000 SBFA BX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF BX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFNC BX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SFFC BX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SIGMBX1 CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM SIG CU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT SIG 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX1 GAPI 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RDIX BXi 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CRNI BX1 KHZ 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CRFI BX1 KHZ 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RSCS BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CTM BX1 DEGC 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 XTM BX1 DEGC 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TAV BX1 KV 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 45 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) ....................................................................................... FICUBX1 AMP 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CACU BX1 AMP 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 BUST BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 BUSP BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 RSXS BX1 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX1 PU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI SIG PU 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 CCLC BX1 V 1244213 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11764.500 CS.BX1 1449.275 TENS.BX1 1681.000 NPHV. BX1 NPDE.BX1 1451.341 NSCE. BX1 2.916 CRRA.BX1 1.994 NSCR.BX1 AQTM. BX1 0.661 CHV. BX1 200.854 CP5V. BX1 5.060 CP2V. BX1 CM2V. BX1 -12.250 RCFR.BX1 0.000 RCLC. BX1 0.000 RCRC. BX1 RCAK. BX1 0.000 RTDF. BX1 0.000 FPHV. BX1 1389.161 FPDE.BX1 FSCE. BX1 2.066 FSCR.BX1 -0.181 AQTF. BX1 0.661 SF6P.BX1 HVPV. BX1 159.912 BMCU. BX1 37.500 GDCU. BX1 60.996 EXCU. BX1 NBEF. BX1 29.830 FBEF.BX1 59.468 NPGF. BX1 1.004 FPGF. BX1 BSTR.BX1 36.311 BSPR.BX1 1.093 MARC.BX1 0.000 XHV. BX1 XPSV. BX1 5.069 XP2V. BX1 12.129 XI42V. BX1 -12.387 RXFR.BX1 RXLC. BX1 0.000 R3fRC.BX1 0.000 RXAK. BX1 0.000 SHCU. BX1 BSAL.BX1 -999.250 BSAL.SIG -999.250 CIRN. BX1 -999.250 CIRF. BX1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.BX1 -999.250 FBAC. BX1 IRAT. BXI -999.250 IRAT. FIL -999.250 NBAC. BX1 -999.250 SFNA.BX1 SFFA.BX1 -999.250 SBNA.BXl -999.250 SBFA.BX1 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. BX1 SFNC. BX1 -999.250 SFFC.BX1 -999.250 SIGM. BX1 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. BX1 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.BX1 40.682 RDIX. BX1 137144.000 CRNI.BX1 444.345 CRFI.BX1 RSCS.BX1 8459.000 CTM. BX1 58.106 XTM. BX1 56.152 TAV. BX1 FICU. BX1 2.407 CACU. BX1 2.515 BUST. BX1 3.000 BUSP.BX1 RSXS.BX1 8878.000 TPHI.BX1 -999.250 TPHI.SIG -999.250 CCLC. BX1 DEPT. 11523.500 CS.BX1 1453.356 TENS.BX1 1522.000 NPHV. BX1 NPDE. BX1 1452.027 NSCE.BXl 2.912 CRRA.BX1 2.444 NSCR.BX1 AQTM. BX1 1.102 CHV. BX1 200.491 CPSV. BX1 5.060 CP2V. BX1 CM2V. BX1 -12.250 RCFR.BX1 0.000 RCLC. BX1 0.000 RCRC.BX1 RCAK. BX1 0.000 RTDF. BX1 0.000 FPHV. BX1 1389.161 FPDE. BX1 FSCE. BX1 2.105 FSCR.BX1 0.159 AQTF. BX1 1.102 SF6P.BX1 HVPV. BX1 159.848 BMCU. BX1 34.185 GDCU. BX1 60.133 EXCU. BX1 NBEF. BX1 27.027 FBEF. BX1 66.056 NPGF. BX1 0.999 FPGF. BX1 BSTR.BX1 48.955 BSPR.BX1 1.124 MARC. BX1 0.000 XHV. BX1 XP5V. BX1 5.080 XP2V. BX1 12.131 X~2V. BX1 -12.375 RXFR.BX1 RXLC. BX1 0.000 RXRC. BX1 0.000 RXAK. BX1 0.000 SHCU. BX1 BSAL.BX1 172.729 BSAL.SIG 2.608 CIRN. BX1 0.864 CIRF. BX1 CIRN. FIL 0.875 CIRF. FIL 2.700 DSIG.BX1 1.341 FBAC.BX1 IRAT. BX1 0.437 IRAT. FIL 0.437 NBAC.BX1 2593.048 SFNA.BX1 1474. -0. 12. O. 1371. 146. 6. 0 2OO 0 31 -999 -999 -999. -999. -999 -999 -999 -999 222 94 0 1473 0 12 0 1371 146 7 0 200 0 34 2 3352 15 610 027 173 000 537 491 707 997 127 000 869 250 250 250 250 25O 25O 250 250 888 888 000 010 390 372 158 000 995 491 371 998 025 000 539 651 723 014 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 46 SFFA.BX1 13 SFFA.SIG 0 SFFA.FIL 12 SFNC. BX1 12 SIGM. SIG 0 GR.BX1 53 RSCS.BX1 8463 FICU. BX1 2 RSXS.BX1 8878 165 SBNA.BX1 69.297 SBFA.BX1 235 SBNA.SIG 3.200 SBFA.SIG 848 SBNA.FIL 71.856 SBFA.FIL 606 SFFC. BX1 11.277 SIGM. BX1 166 TRAT. BX1 0.742 TRAT.SIG 254 RDIX. BX1 143460.000 CRNI.BX1 000 CTM. BX1 58.594 XTM. BX1 395 CACU. BX1 2.512 BUST. BX1 000 TPHI.BX1 19.899 TPHI.SIG 53.908 SFNA.SIG 4.240 SFNA.FIL 55.233 SIBF. BX1 11.242 SIBF. SIG 0.011 TRAT. FIL 461.278 CRFI.BX1 57.437 TAV. BX1 3.000 BUSP.BX1 0.490 CCLC. BX1 0.305 14.537 87.773 1.103 0.734 188.822 94.979 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NT]F1BER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 5 DEPTH INCREMENT: 0.5000 FILE SU~W~RY VENDOR TOOL CODE START DEPTH RST 11783.5 $ LOG H~ADER DATA DATE LOGGED: SOFTWARE VERSION: TIFIELOGGER ON BOTTOM: TDDRILLER (FT): STOP DEPTH .......... 11510.5 31 -MAY-98 8Cl -205 1149 31 -MAY-98 11750.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 47 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 11764.0 11546.0 11741.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY RST RESERVOIR SATURATION $ TOOL NUM~ER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8.500 11848.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): Tied into SWS Cement Bond Log dated 6-28-1984 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 48 Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 3 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CS BX2 F/HR 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX2 LB 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NPHVBX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NPDE BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NSCE BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CRRABX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NSCR BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 AQTMBX2 S 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CHV BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CPSV BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 49 NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CP2V BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 C~2V BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RCFRBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RCLC BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RCRC BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RCAKBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RTDF BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FPHVBX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FPDE BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FSCE BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FSCR BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 AQTF BX2 S 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SF6P BX2 PSIG 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 HVPV BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BMCUBX2 UA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 GDCUBX2 MA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 EXCU BX2 UA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NBEF BX2 UA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FBEF BX2 UA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NPGF BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FPGF BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BSTR BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BSPR BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 MARC BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 XHV BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 XP5V BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 XP2V BX2 V 1244213 O0 000 O0 0 12 i 1 4 68 0000000000 X~42V BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RXFRBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RXLC BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RXRC BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RXAKBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SHCU BX2 MA 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BSALBX2 PPK 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BSALSIG PPK 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CIRNBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CIRFBX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CIRFFIL 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 DSIG BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX2 CPS 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 NBAC BX2 CPS 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 50 NAME SERV UNIT SERVICE API API API API FILE NUMB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELM CODE (HEX) SBFA SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFNC BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SFFC BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX2 CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM SIG CU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT SIG 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX2 GAPI 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RDIX BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CRNI BX2 KHZ 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CRFI BX2 KHZ 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RSCS BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CTM BX2 DEGC 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 XTM BX2 DEGC 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TAV BX2 KV 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 FICUBX2 AMP 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CACU BX2 AMP 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BUST BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 BUSP BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 RSXS BX2 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX2 PU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI SIG PU 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 CCLC BX2 V 1244213 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. BX2 1451.760 NSCE. BX2 A Q TM. BX2 C~2 V. BX2 RCAK. BX2 FSCE, BX2 HVPV. BX2 NBEF. BX2 BSTR . BX2 XP5 V. BX2 RXLC. BX2 11783.500 CS.BX2 4368.933 TENS.BX2 817.000 NPHV. BX2 1469.728 2.890 CRRA.BX2 2.009 NSCR.BX2 -0.652 0.441 CHV. BX2 200.370 CP5V. BX2 5.060 CP2V. BX2 12.129 -12.250 RCFR.BX2 0.000 RCLC.BX2 0.000 RCRC. BX2 0.000 0.000 RTDF. BX2 0.000 FPHV. BX2 1384.278 FPDE.BX2 1372.605 2.132 FSCR.BX2 -0.375 AQTF. BX2 0.441 SF6P.BX2 146.491 159.180 BMCU. BX2 36.914 GDCU. BX2 60.668 EXCU. BX2 6.312 29.327 FBEF. BX2 58.907 NPGF. BX2 0.998 FPGF. BX2 1.003 42.282 BSPR.BX2 1.162 MARC.BX2 0.000 XHV. BX2 199.885 5.079 XP2V. BX2 12.129 X~2V. BX2 -12.387 RXFR.BX2 0.000 0.000 R3~C.BX2 0.000 RXAK. BX2 0.000 SHCU. BX2 31.869 BSAL.BX2 -999.250 BSAL.SIG -999.250 CIRN. BX2 -999.250 CIRF. BX2 -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.BX2 -999.250 FBAC.BX2 -999.250 IRAT. BX2 -999.250 IRAT. FIL -999.250 NBAC. BX2 -999.250 SFNA.BX2 -999.250 SFFA.BX2 -999.250 SBNA.BX2 -999.250 SBFA.BX2 -999.250 SFNA.SIG -999.250 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 51 SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. BX2 -999.250 SFFC.BX2 -999.250 SIGM. BX2 SIGM. SIG -999.250 TRAT. BX2 -999.250 TRAT. SIG GR.BX2 260.485 RDIX. BX2 145661.000 CRNI.BX2 RSCS.BX2 8459.000 CTM. BX2 58.594 XTM. BX2 FICU. BX2 2.407 CACU. BX2 2.505 BUST. BX2 RSXS.BX2 8878.000 TPHI.BX2 -999.250 TPHI.SIG DEPT. 11510.500 CS.BX2 NPDE.BX2 1451.303 NSCE. BX2 AQTM. BX2 1.322 CHV. BX2 CM2V. BX2 -12.260 RCFR.BX2 RCAK. BX2 2.000 RTDF. BX2 FSCE.BX2 2.135 FSCR.BX2 HVPV. BX2 159.587 BMCU. BX2 NBEF. BX2 27.449 FBEF. BX2 BSTR.BX2 45. 625 BSPR.BX2 XP5V. BX2 5. 077 XP2V. BX2 RXLC. BX2 O . 000 RXRC. BX2 BSAL.BX2 177.014 BSAL.SIG CIRN. FIL 0.749 CIRF. FIL IRAT. BX2 0.429 IRAT. FIL SFFA.BX2 16.009 SBNA.BX2 SFFA.SIG 0.299 SBNA.SIG SFFA.FIL 16.213 SBNA.FIL SFNC. BX2 16.154 SFFC. BX2 SIGM. SIG 0.242 TRAT.BX2 GR.BX2 18.622 RDIX. BX2 RSCS.BX2 8463.000 CTM. BX2 FICU. BX2 2.442 CACU. BX2 RSXS.BX2 8878.000 TPHI.BX2 1651 075 2 893 200 248 0 000 0 000 -0 254 34 131 62.691 1.032 12.123 0.000 2.552 2.257 0.424 76.040 4.492 74.257 14.684 0.770 153138.000 59.814 2.511 23.710 TENS. BX2 CRRA. BX2 CPSV. BX2 RCLC. BX2 FPHV. BX2 AQTF. BX2 GDCU. BX2 NPGF. BX2 MARC. BX2 X~2 V. BX2 RXAK. BX2 CIRN. BX2 DSIG. BX2 NBAC. BX2 SBFA . BX2 SBFA. SIG SBFA. FIL $IGM. BX2 TRAT. SIG CRNI . BX2 XTM. BX2 BUST. BX2 TPHI.SIG -999.250 -999.250 -999.250 457.934 57.617 3.000 -999.250 1535.000 2.284 5.069 0.000 1390.382 1.322 59.830 0.992 0.000 -12.381 0.000 0.736 1.736 2588.554 62 209 4 239 54 307 14 583 0 014 445 053 58.431 3.000 0.631 SIBF. BX2 SIBF.SIG TRAT. FIL CRFI.BX2 TAV. BX2 BUSP.BX2 CCLC.BX2 NPHV. BX2 NSCR.BX2 CP2V. BX2 RCRC. BX2 FPDE.BX2 SF6P.BX2 EXCU. BX2 FPGF. BX2 XHV. BX2 RXFR.BX2 SHCU. BX2 CIRF. BX2 FBAC. BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI.BX2 TA V. BX2 BUSP. BX2 CCLC. BX2 -999.250 -999.250 -999.250 227.978 95.031 3.000 -0.010 1474.610 -0.526 12.180 0.000 1373.063 146.832 7.342 0.997 199.966 0.000 34.001 2.282 3499.569 17.767 0.534 18.086 89.591 1.087 0.778 194.865 94.968 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 52 **** FILE HEADER **** FILE NAFIE : EDIT .013 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUPiBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREFIENT: 0.5000 FILE SUF~N~RY VENDOR TOOL CODE START DEPTH RST 11780.5 $ LOG HEADER DATA STOP DEPTH .......... 11531.0 DATE LOGGED: SOFTWARE VERSION: TIFIE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAf4~ARAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 31 -MAY-98 8Cl -205 1149 31 -MAY-98 11750.0 11764.0 11546.0 11741.0 TOOL NUMBER CGRS-A RST-A 8.500 11848.0 PRODUCED FLUIDS 9.00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 53 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Tied into SWS Cement Bond Log dated 6-28-1984 Pumped 165 BBL seawater then logged three baseline passes Pumping 1 BBL/min while logging Annulus appears gas-filled so pumped another 135 BBL seawater at 5 BBL/min and attempted more basline passes, annulus still gas filled. Client decision to move ahead with Borax passes Pumped 100 BBL Borax followed by 40 BBL crude Logged three Borax passes Pumped another 70 BBL crude Packer at 11699 feet in NOT leaking Borax-seawater overlays shows Borax in squeeze perfs from 11714 - 11740' either channeling fluid or squeeze perf breakdown Unable to determine GOC due to gas in annulus. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 3 68 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 54 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CS BX3 F/HR 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX3 LB 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NPHVBX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NPDE BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NSCE BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CRRABX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NSCR BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 AQTMBX3 S 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CAW BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CP5V BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CP2V BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CM2V BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RCFR BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RCLC BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RCRC BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RCAKBX3 1244213 O0 000 O0 0 13 i 1 4 68 0000000000 RTDF BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FPHVBX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FPDE BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FSCE BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FSCR BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 AQTF BX3 S 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SF6P BX3 PSIG 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 HVPV BX3 V 1244213 O0 000 O0 0 13 I 1 4 68 0000000000 BMCU BX3 UA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 GDCUBX3 MA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 EXCUBX3 UA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NBEF BX3 UA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FBEF BX3 UA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NPGF BX3 1244213 O0 000 O0 0 13 1 _ 1 4 68 0000000000 FPGF BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 BSTR BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 55 NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) BSPR BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 MARC BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 XHV BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 XPSV BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 XP2V BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 XM2V BX3 V 1244213 O0 000 O0 0 13 1 I 4 68 0000000000 RXFRBX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RXLC BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RXRC BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RXAKBX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SHCUBX3 MA 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 BSALBX3 PPK 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 BSAL SIG PPK 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNBX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CIRF BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNFIL 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CIRF FIL 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 DSIG BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX3 CPS 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT FIL 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 NBAC BX3 CPS 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA FIL CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA FIL CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA FIL CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA FIL CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFNC BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SFFC BX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SIGMBX3 CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM SIG CU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT SIG 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FIL 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX3 GAPI 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RDIX BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CRNI BX3 KHZ 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CRFI BX3 KHZ 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RSCS BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CTM BX3 DEGC 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 XTM BX3 DEGC 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TAV BX3 KV 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 56 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CI_.d~S MOD ~ S~'~IP ELI~I CODE (HEX) FICUBX3 AMP 1244213 00 000 00 0 13 1 1 4 68 0000000000 CACUBX3 AMP 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 BUST BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 BUSP BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 RSXS BX3 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX3 PU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI SIG PU 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 CCLC BX3 V 1244213 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 11780.500 CS.BX3 1285.714 TENS.BX3 670.000 NPHV. BX3 NPDE. BX3 1451.646 NSCE.BX3 2.901 CRRA.BX3 2.015 NSCR.BX3 AQTM. BX3 0.441 CHV. BX3 200.127 CP5V. BX3 5.069 CP2V. BX3 CM2V. BX3 -12.270 RCFR.BX3 0.000 RCLC. BX3 0.000 RCRC.BX3 RCAK. BX3 0.000 RTDF. BX3 0.000 FPHV. BX3 1389.161 FPDE.BX3 FSCE.BX3 2.145 FSCR.BX3 -0.432 AQTF. BX3 0.441 SF6P.BX3 HVPV. BX3 159.912 BMCU. BX3 36.621 GDCU. BX3 60.012 EXCU. BX3 NBEF. BX3 29.593 FBEF. BX3 59.635 NPGF. BX3 0.995 FPGF. BX3 BSTR.BX3 43.597 BSPR.BX3 0.940 MARC. BX3 0.000 XHV. BX3 XP5V. BX3 5.069 XP2V. BX3 12.114 XM2V. BX3 -12.407 RXFR.BX3 RXLC. BX3 0.000 RXRC.BX3 0.000 RXAK. BX3 0.000 SHCU. BX3 BSAL.BX3 -999.250 BSAL.SIG -999.250 CIRN. BX3 -999.250 CIRF. BX3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.BX3 -999.250 FBAC. BX3 IRAT. BX3 -999.250 IRAT. FIL -999.250 NBAC.BX3 -999.250 SFNA.BX3 SFFA.BX3 -999.250 SBNA.BX3 -999.250 SBFA.BX3 -999.250 SFNA.SIG SFFA. SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. BX3 SFNC.BX3 -999.250 SFFC.BX3 -999.250 SIGM. BX3 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. BX3 -999.250 TRAT.SIG -999.250 TRAT. FIL GR.BX3 193.694 RDIX. BX3 155533.000 CRNI.BX3 458.971 CRFI.BX3 RSCS.BX3 8463.000 CTM. BX3 60.059 XTM. BX3 58.594 TAV. BX3 FICU. BX3 2.417 CACU. BX3 2.529 BUST. BX3 3.000 BUSP.BX3 RSXS.BX3 8878.000 TPHI.BX3 -999.250 TPHI.SIG -999.250 CCLC.BX3 DEPT. 11531.000 CS.BX3 1765.551 TENS.BX3 1508.000 NPHV. BX3 NPDE. BX3 1452.943 NSCE.BX3 2.917 CRRA.BX3 2.268 NSCR.BX3 AQTM. BX3 0.661 CHV. BX3 200.612 CPSV. BX3 5.050 CP2V. BX3 CM2V. BX3 -12.231 RCFR.BX3 0.000 RCLC.BX3 0.000 RCRC. BX3 RCAK. BX3 0.000 RTDF. BX3 0.000 FPHV. BX3 1394.044 FPDE.BX3 FSCE. BX3 2.091 FSCR.BX3 0.089 AQTF. BX3 0.661 SF6P.BX3 HVPV. BX3 159.554 BMCU. BX3 33.672 GDCU. BX3 59.924 EXCU. BX3 ArBEF. BX3 26.412 FBEF. BX3 59.906 NPGF. BX3 0.997 FPGF. BX3 BSTR.BX3 44.888 BSPR.BX3 1.137 MARC.BX3 0.000 XHV. BX3 XPSV. BX3 5.082 XP2V. BX3 12.125 X~2V. BX3 -12.365 P~XFR.BX3 RXLC. BX3 0.000 RXRC. BX3 0.000 RXAK.BX3 0.000 SHCU. BX3 BSAL.BX3 165.005 BSAL. SIG 2.655 CIRN. BX3 0.577 CIRF. BX3 CIRN. FIL 0.600 CIRF. FIL 1.448 DSIG.BX3 3.375 FBAC.BX3 IRAT. BX3 0.409 IRAT. FIL 0.410 NBAC.BX3 2628.794 SFNA.BX3 1472.169 -0.086 12.187 0.000 1373.063 147.003 6.312 1.003 200.127 0.000 34.146 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 227.756 95.031 3.000 0.000 1472.169 0.241 12.143 0.000 1372.567 147.344 7.417 1.007 200.063 0.000 35.750 1.325 3375.521 23.267 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-0CT-1998 16:20 PAGE: 57 SFFA.BX3 23.255 SBNA.BX3 75.542 SBFA.BX3 SFFA.SIG 0.780 SBNA.SIG 3.395 SBFA.SIG SFFA.FIL 22.380 SBNA.FIL 72.580 SBFA.FIL SFNC. BX3 22.504 SFFC. BX3 19.897 SIGM. BX3 SIGM. SIG 0.485 TRAT. BX3 1.063 TRAT. SIG GR.BX3 104.242 RDIX. BX3 162083.000 CRNI.BX3 RSCS. BX3 8463.000 CTM. BX3 60.547 XTM. BX3 FICU. BX3 2.410 CACU. BX3 2.510 BUST. BX3 RSXS.BX3 8878.000 TPHI.BX3 40.782 TPHI.SIG 62.701 SFNA.SIG 5.811 SFNA.FIL 59.098 SIBF. BX3 20.118 SIBF. SIG 0.023 TRAT. FIL 449.767 CRFI.BX3 59.440 TAV. BX3 3.000 BUSP.BX3 1.258 CCLC.BX3 0.599 24.867 84.523 1.111 0.975 198.302 95.031 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .013 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 98/10/ 6 ORIGIN : FLIC TAPE NA~E : 98501 CONTINUATION # : 1 PREVIOUS TAPE : COM~N~r : ARCO ALASKA, DS15-16, PRUDHOE BAY, API #50-029-21115-00 **** REEL TRAILER **** SERVICE NAF1E : EDIT DATE : 98/10/ 6 ORIGIN : FLIC REEL NAME : 98501 CONTINUATION # : PREVIOUS REEL : COMMEIFr : ARCO ALASKA, DS15-16, PRUDHOE BAY, API #50-029-21115-00 PROGRAM: LIS REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Tue 11 SEP 90 3:00pm WELL DATA FILE: C:\CLIFF\W04574.WDF ECC: 4574.00 SIg-lb COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: D.S. 15 - 16 FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 11260.000 11800.000 0.500 NUMBER OF CURVES: 20 DEPTH BKL BKS CCL CSS GR ISS LS MON MSD RIN SG~ SPD SS G1 RATO G2 RBOR GElS RICS COMPANY: ARCO ALASKA INCORPORATED WELL:D.S. 15 - 16 FIELD:PRUDHOE BAY COUNTY:NORTH SLOPE STATE:ALASKA TAPE INFORMATION FILE:PASS 1.001 FILE INTERVAL: START= 11800.000 END= 11260.000 DEPT 11800.000 11775.000 11750.000 11725.000 11700.000 11675.000 11650.000 11625.000 11600.000 11575.000 11550.000 11525.000 11500.000 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR -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 -999.250 -999.250 -999.250 -999.250 300.000 20.705 978.625 24575.672 26.850 2029.198 0.380 36.896 406.866 25.177 18.398 9.797 0.000 19.998 966.154 24136.336 28.939 2027.497 0.651 36.952 515.735 24.959 18.577 9.709 0.000 21.526 1030.828 24531.816 26.270 2026.860 0.626 37.172 570.405 23.765 18.630 9.902 0.000 13.999 17.117 2024.642 112.193 16.775 740.400 13.999 11.495 2026.231 271.065 13.796 2450.343 40935.512 0.246 20.212 11.620 8.711 3464.046 47886.687 0.262 19.103 11.574 6.721 0.000 13.999 2655.585 42155.859 44.593 2026.421 0.303 23.737 221.681 15.925 11.899 6.878 0.000 13.999 3239.344 46413.594 26.412 2024.490 0.347 19.061 206.077 14.339 11.703 6.739 0.000 13.999 3847.169 48145.336 23.297 2023.744 0.223 16.382 224.730 12.506 10.988 6.814 140.400 14.234 4435 29.995 2022.296 0 254.452 11.846 10 0.000 13.999 2750 51.986 2025.084 0 211.698 15.298 12 0.000 13.999 4958 14.033 2021.628 0 190.265 10.788 10 0.000 13.999 1792 47.557 2019.068 0 273.521 19.294 16 .863 52520.492 .130 15.158 .767 6.455 .586 41928.047 .365 24.435 .464 6.442 .687 53430.941 .100 14.464 .533 5.946 .376 34636.285 .547 35.409 .396 6.456 3560.724106549.375 16288.812301716.187 1.635 3554.275106701.375 16194.812301352.062 1.605 3510.117106019.750 16205.234300586.437 1.603 12933.527111317.687 25165.266296904.750 1.401 15468.535127423.250 29389.008335937.312 1.389 10532.910131661.750 25964.043351049.750 1.396 14775.152123394.125 28397.941336433.125 1.394 17386.285121075.312 30054.289329076.500 1.404 20200.551131230.750 33470.004351600.687 1.378 10420.883132826.187 25881.867361963.375 1.442 20804.414132776.437 34205.152359375.937 1.394 5472.434139274.750 22419.195365079.000 1.551 G2 BKL -999.250 -999.250 342.075 136.171 329.369 155.607 344.264 115.931 3567.988 42.328 4387.988 109.753 2281.687 174.984 4231.516 133.951 5979.160 101.496 7501.227 139.978 2220.932 127.822 8099.863 67.579 538.931 128.776 11475.000 0.000 13.999 5190.074 56623.066 21908.094138164.562 8298.891 16.953 2022.880 208.534 10.911 0.114 10.559 14.752 35893.359375092.687 5.952 1.389 11450.000 0.000 13.999 49.498 2020.268 298.773 18.965 1934.577 36663.066 0.817 34.552 15.782 6.385 6008.727142445.500 23264.379370036.187 1.554 11425.000 0.000 13.999 18.882 2021.503 188.786 11.685 4635.949 54177.703 0.200 15.023 10.703 5.978 20872.355130028.437 34040.937359608.625 1.389 D.S. 15 - 16 DEPT CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR 11400.000 0 41 263 .O0O .602 .501 13.'999 1905.644 36830 2022.023 0.335 35 19.314 16.003 6 .707 5859 .296 23336 .246 1 .957142742.812 .719371564.687 .562 11375.000 0 16 224 .00O .694 .175 13.999 5540.836 56927 2021.816 0.200 15 10.253 10.373 5 .887 22086.992139643.625 .101 36136.766372068.562 .677 1.380 11350.000 0 17 213 .000 .752 .254 13.999 5299.484 56577 2023.667 0.206 15 10.647 11.151 5 .398 20997 .683 35798 .720 1 .852143927.000 .180377990.250 .415 11325.000 11300.000 0.000 19.847 244.431 0.000 15.223 275.169 13 2021 10 14 2022 9 .999 4999.707 54183 .871 0.112 15 .839 10.707 5 .108 6264.914 58784 .419 0.204 14 .389 10.210 5 .285 20533 .362 34123 .828 1 .922133214.812 .117363769.750 .384 .645 22873.145148119.750 .618 37785.781384667.687 .606 1.398 11275.000 0.000 0.000 0.000 0.000 0 0.000 .0.000 0.000 0.000 0 0.000 0.000 0.000 5.000 -1 .000 0.000 .000 0.000 .000 11260.000 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999 .250 -999.250 .250 -999.250 .250 -999.250 -999.250 -999.250 WELL DATA FILE: ECC: C:\CLIFF\W04575.WDF 4575.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D.S. 15 - 16 Top of Well: Bottom of Well: Level Spacing: 11260.000 11740.000 0.500 80.210 614.788 119.904 7815.418 69.143 G2 BKL 584.578 123.942 8229.684 80.401 7490.059 78.473 7512.418 101.888 8794.293 75.342 0.000 0.000 -999.250 -999.250 NUMBER OF CURVES: 20 DEPTH BKL BKS GR ISS LS RIN SGMA SPD CCL CSS G1 G2 GElS MON MSD RATO RBOR RICS SS FILE:PASS 2.002 FILE INTERVAL: START= 11740.000 END= 11260.000 DEPT 11740.000 11715.000 11690.000 11665.000 11640.000 11615.000 11590.000 11565.000 11540.000 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR -999.250 -999.250 -999.250 300.000 57.167 380.289 0.000 15.856 149.922 0.000 22.373 211.417 0.000 26.957 214.321 0.000 31.175 262.452 27.900 33.321 237.302 0.000 34.759 312.990 0.000 31.777 362.593 0.000 56.677 304.483 -999.250 -999.250 -999.250 14.999 2090.621 25.233 14.999 2034.459 16.258 14.999 2038.011 14.962 2039.298 13.799 14.999 2040.192 12.472 14.999 2040.165 14.397 14.963 2038.415 11.546 14.999 2039.203 14.069 14.999 2036.972 15.530 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 932.376 23502.449 3496.715100822.437 0.623 36.512 15555.406278658.187 17.764 9.542 1.616 2352.404 .38264.406 11773.375103783.687 0.260 19.522 23393.043272299.250 11.566 8.714 1.405 2906.244 43430.617 12120.187122797.875 0.261 21.920 26243.598320199.250 12.261 7.128 1.427 3253.670 44953.113 15514.012115797.000 0.189 17.182 27929.262312769.062 12.000 6.832 1.416 3647.152 45462.238 16666.766114244.937 0.198 16.308 28472.633314550.750 10.980 6.698 1.408 2987.265 43002.363 12919.086119826.500 0.265 20.537 26301.750324312.625 12.538 6.821 1.437 4070.661 47167.156 17709.906119671.812 0.154 14.932 30005.277328301.750 11.419 6.659 1.411 2988.136 41939.379 13068.406119054.250 0.168 19.051 26108.566314514.250 11.669 7.027 1.430 2432.213 38023.562 8316.637132811.687 0.676 25.424 24023.156347543.875 15.987 6.542 1.571 G2 BKL -999.250 -999.250 369.050 107.351 3276.536 50.826 2883.353 121.356 5065.316 156.593 5741.840 127.049 3354.830 140.776 6725.789 127.046 3736.307 253.594 1726.261 168.183 11490.000 0.000 14.999 1763.365 33624.785 5122.883132834.000 524.930 54.564 2038.281 252.823 19.078 0.377 35.861 16.149 6.509 11465.000 0.000 14.999 4822.074 50979.133 19.591 2038.109 0.159 14.042 258.257 10.573 10.383 5.970 11440.000 0.000 14.999 1527.060 31230.105 55.468 2039.274 0.116 36.643 269.302 20.429 17.094 6.435 11415.000 0.000 14.999 25.848 2038.636 224.322 11.190 4563.707 51168.410 0.145 15.660 11.593 6.167 11390.000 0.000 14.999 38.173 2038.768 230.729 12.106 4057.707 48783.941 0.455 18.235 10.441 5.947 11365.000 0.000 14.999 28.783 2038.988 242.957 11.922 4167.359 49647.254 0.172 17.808 11.054 6.098 D.S. 15 - 16 DEPT 21428. 391346763 . 375 1.574 11340.000 20770.988123746.312 32861.832339792.250 1.400 11315.000 4613.547128743.562 20284.617346520.500 1.576 11290.000 19244.203126719.375 32282.316344247.125 1.410 11265.000 17251.508129096.875 30741.324345897.250 1.370 11260.000 16822.391132172.125 30913.988349528.937 1.401 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR 0.000 14.999 5341.652 54027.000 21.607 2039.183 0.253 15.265 272.689 10.124 10.237 5.748 0.000 14.999 4163.656 49319.773 27.729 2038.862 0.195 17.042 257.729 11.801 12.313 6.025 0.000 14.999 5503.129 53926.285 18.725 2039.871 0.100 15.376 243.952 9.797 10.488 5.777 20552 34187 1 16945 30626 1 20446 34294 1 0.000 0.000 0.000 0.000 0 0.000 0.000 0.000 0.000 0 0.000 0.000 -3.000 5.000 -1 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999.250 -999 C:\CLIFF\W04576.WDF 4576.00 WELL DATA FILE: ECC .328133398.000 .562356302.562 .373 ARCO ALASKA INCORPORATED D.S. 15 - 16 .621128331.437 .406346213.375 .448 COMPANY NAME: WELL NAME: FIELD: LOCATION: .891136819.125 .891361122.937 .397 .000 0.000 .000 0.000 .000 .250 -999.250 .250 -999.250 .250 126.674 8288.852 110.512 430.137 153.671 6902.199 119.844 5809.473 93.203 5203.277 78.450 G2 BKL 7564.941 69. 614 5610.531 121. 148 7451.008 72.422 0.000 0.000 -999.250 -999.250 Top of Well: 11360.000 Bottom of Well: Level Spacing: 11720.000 0.500 NUMBER OF CURVES: 20 DEPTH BKL BKS CCL CSS GR ISS LS MON MSD RIN SGMA SPD SS G1 G2 GElS RATO RBOR RICS FILE:PASS 3.003 FILE INTERVAL: START= 11720.000 END= 11360.000 DEPT 11720.000 11695.000 11670.000 11645.000 11620.000 11595.000 11570.000 11545.000 11520.000 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR -999.250 -999.250 -999.250 300.000 20.061 122.141 0.000 15.435 82.570 0.000 18.806 126.428 0.000 18.063 129.017 0.000 16.669 158.864 0.000 11.789 147.102 0.000 40.841 188.511 0.000 17.907 170.399 -999.250 -999.250 -999.250 13.999 2005.823 16.682 17.998 2006.294 16.915 17.998 2005.660 18.312 17.998 2005.528 14.9.62 17.998 2002.526 14.241 17.998 2003.715 12.717 17.998 2004.695 18.481 18.998 2002.731 12.376 -999.250 -999.250 -999.250 2378.667 0.279 11.802 2251.689 0.278 12.993 2032.659 0.417 12.561 2671.601 0.211 11.410 2748.477 0.188 11.922 3406.471 0.235 10.693 16.97.672 0.457 14.392 3310.779 0.266 11.516 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 39696.879 12373.586108059.000 ].8.919 24385.316287314.187 9.297 1.413 38135.168 11223.215108379.750 21.020 23381.348290263.875 9.459 1.438 37209.875 9466.586115280.250 22.821 22913.500294660.312 9.669 1.442 39930.711 14004.254105803.187 16..603 25119.695286512.312 8.886 1.443 39206.301 13799.426108628.875 15.871 25122.387293064.375 9.035 1.472 43215.547 16779.293111036.875 14.250 27911.242296360.750 8.579 1.417 31465.160 7006.559111779.000 22.712 20074.367297999.812 9.413 1.549 41032.352 14772.051113243.687 15.423 26453.273297214.875 8.668 1.452 G2 BKL -999.250 -999.250 3582.658 53.803 2810.813 40.620 2157.047 38.073 4653.660 48.514 4904.039 56.697 6648.613 59.209 1636.196 76.328 5391.945 74.963 11495.000 0.000 18.998 988.674 25300.496 3650.580110168.250 295.200 50.257 215.646 11470.000 2003.015 25.537 11445.000 0.581 17.211 11420. 000 0.000 18.998 2982. 19.964 2002.984 0. 141.538 13.185 11. 11395.000 0.000 18.998 1265. 49.510 2003.506 0. 171.486 23.136 16. 11370.000 0.000 18.998 3447. 17.993 2002.918 0. 138.659 12.218 10. 0.000 18.998 1081. 44.908 2005.756 0. 174.853 24.346 17. 11360.000 300 0 0 .000 0.000 0. .000 0.000 0. .000 0.000 -3. -999.250 -999.250 -999. -999.250 -999.250 -999. -999.250 -999.250 -999. WELL DATA FILE: C ECC: COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 37.191 16838.758291428.000 9.983 1.582 336 39321.336 14088.180110227.312 209 15.597 25532.129300599.187 245 9.163 1.442 210 29377.547 304 34.227 974 9.724 4853.863118465.437 19048.125301644.062 1.594 300 42110.445 16334.332107317.125 174 14.645 27179.887295953.125 823 8.536 1.414 349 26260.082 3835.890114898.687 338 36.541 17520.977298978.312 327 5.627 1.294 000 0.000. 0.000 0.000 000 0.000 0.000 0.000 000 5.000 -1.000 250 -999.250 -999.250 -999.250 250 -999.250 -999.250 -999.250 250 -999.250 -999.250 : \CLIFF\W04577.WDF 4577.00 ARCO ALASKA INCORPORATED D.S. 15 - 16 11360.000 11730.000 0.500 123. 044 5133.918 48.264 558.O55 139.475 6292.551 58.687 401.753 107.547 0.000 0.000 -999.250 -999.250 NUMBER OF CURVES: 20 DEPTH BKL BKS CCL CSS GR ISS LS MON MSD RIN SGMA SPD SS G1 G2 GElS RATO RBOR RICS FILE:PASS 4.003 FILE INTERVAL: START= 11730.000 END= 11360.000 DEPT CCL GR BKS SPD MON RATO LS MSD RICS SS SGMA RIN G1 CSS RBOR GElS ISS G2 BKL 11730.000 11705. 000 11680.000 11655.000 11630.000 11605.000 11580.000 11555.000 11530.000 11505.000 11480.000 11455.000 11430.000 11405.000 11380.000 -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 -999.250 -999.250 -999.250 -999.250 0.000 51.637 204.238 0.000 17.393 126. 015 0.000 20.720 141.071 0.000 17.584 165.346 26.250 15.974 161.889 0.000 21.269 141.411 5.100 21.723 160.885 0.000 19.532 206.543 0.000 52.376 204.549 0.000 19.499 179.487 0.000 30.657 191.615 0.000 23.510 157.293 0.000 43.981 234.140 0.000 14.334 0.000 16.998 505.933 11212.348 2012.456 1.097 39.926 22.020 34.264 10.451 16.998 2013.754 17.863 16.998 2013.993 14.392 16.998 2012.670 13.499 16.998 2011.941 10.630 16.998 2011.287 14.476 16.998 2009.090 13.494 16.998 2009.245 9.848 16.998 2008.199 25.097 16.998 2010.355 9.109 16.998 2007.960 12.370 16.998 2011.557 12.345 16.998 2010.678 15.329 0.000 0.000 0.000 1297.102 68386.250 8709.664292441.250 2.002 1008.305 17995.910 4438.789 67951.500 0.487 25.764 11803.664290264.250 30.492 10.062 1.845 1487.241 21384.355 6925.137 71174.625 0.406 19.505 14032.527301025.937 21.625 9.934 1.678 1708.001 23001.582 8783 0.217 16.900 15014 18.764 9.896 1 .922 67122.562 .687291280.375 .615 2377.272 25244.719 11598 0.189 13.983 17212 17.102 8.895 1 .305 68905.875 .289297824.437 .597 1632 0 17 .394 23540.590 8721 .360, 17.516 15169 .568 9.739 1 .145 68022.750 .391291771.000 .573 1540 0 20 .344 20734.055 7837 .166 16.885 13745 .819 9.834 1 .914 63577.594 .316288197.250 .711 2574 0 17 .964 25419.641 11844 .221 12.840 17523 .550 9.136 1 .434 69752.500 .270302909.937 .649 465 0 32 .090 11626.391 1281 .613 43.536 9209 .909 10.522 1 .306 73256.187 .387298002.062 .954 2929 0 17 .330 26652.645 12938 .294 12.763 18557 .041 8.961 1 .180 71772.875 .828319760.375 .637 1787 0 24 .894 22188.957 8226 .288 16.554 14854 .794 9.913 1 .137 70990.562 .074302513.062 .829 1921.848 23447.203 10369 0.400 15.183 15936 17.658 9.349 1 .281 66407.000 .305297541.687 .598 1076.340 16684.605 4120 0.879 23.397 11859 29.971 10.088 1 .098 74799.250 .113315294.187 .898 0.000 0.000 0.000 0.000 -3.000 5.000 0.000 0.000 0.000 0.000 -1.000 -999.250 -999.250 118.094 96.488 874.980 30.791 1931.931 43.380 2887.988 43.972 4586.309 35.301 2873.587 44.581 2638.892 57.459 5054.926 65. 150 96.340 136.800 5604.129 50.042 2792.761 81.289 3950.366 61.977 1009.148 141.677 0.000 0.000 11360,000 -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 -999,250 -999,250 -999.250 -999,250 WELL DATA FILE: ECC: C:\CLIFF\W04578,WDF 4578.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D,S, 15 - 16 Top of Well: Bottom of Well: Level Spacing: 11360,000 11730,000 0,500 -999,250 -999.250 NUMBER OF CURVES: 20 DEPTH BKL BKS CCL CSS GR ISS LS MON MSD RIN SGMA SPD SS G1 G2 GElS RATO RBOR RICS FILE:PASS 5,003 FILE INTERVAL: START= 11730,000 END= 11360,000 DEPT 11730,000 11705,000 11680.000 11655,000 11630,000 11605,000 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR -999,250 -999,250 ~999,250 300,000 41,474 269,948 0,000 17,799 171,764 -999,250 -999, -999,250 -999, -999,250 -999, 15,998 495, 2008,030 1, 23,137 33, 15,998 841, 2007,363 0. 18,779 33, 0,000 15.998 1441, 25,319 2005,414 0, 167,815 14,996 21, 0,000 15,998 1743, 19.900 2002.967 0. 148,802 .13,489 18. 0,000 15,998 2422, 18,586 2002,784 0, 178,087 10,509 17, 250 -999,250 -999,250 -999.250 250 -999,250 -999,250 -999,250 250 -999,250 -999,250 864 11500,148 1248,434 72773,875 639 43,516 9071,930297388,312 687 10,467 2,031 832 15785,469 3400,205 68329.000 720 28.907 10774.695287380.125 099 10,175 1,928 750 21640,547 6929,984 72186.437 332 20,039 14121.984298181,812 930 9,847 1,675 760 23498,031 9127,590 68860.250 250 16,624 15453,250288256.000 389 9.654 1,611 388 25461.125 11470,184 69042,500 160 13,654 17270,543296158,437 155 8,801 1,613 G2 BKL -999,250 -999.250 49.001 130.149 555,227 30.897 1868.777 53.385 3057,119 53,847 4670.652 50,590 11580.000 0.000 26.418 168.403 11555.000 572.100 21.349 146.597 11530.000 0 24 160 .000 .477 · 048 11505.000 0 57 226 .OO0 .978 .926 11480.000 0 23 178 15.998 1703.077 24024.695 2003.936 0.398 16.353 14.177 17.205 9.913 11455.000 0 31 188 9554 15720 1 11430.000 0 27 157 15.998 1579.554 20631 2001.675 0.271 17 13.026 20.498 10 11405.000 0 47 227 .293 7695 .093 13720 .071 1 11380.000 15.998 2585.030 25085 2002.674 0.120 12 9.694 17.512 9 11360.000 .121 67590.000 .418289114.437 .58O .281 64689.023 .320288815.625 .677 .551 11927.969 70400.562 .863 17534.855300287.250 .065 1.618 15.998 494.133 11637.848 1299 2002.067 0.778 43.497 9148 23.514 32.083 10.087 2 .000 15.998 2885.598 26618.590 12967 .624 2002.873 0.138 12.763 18679 .671 9.227 16.902 8.989 1 .000 .485 .707 .000 .846 · 048 .000 · 142 .209 0.000 0.000 0.000 -999.250 -999.250 -999.250 WELL DATA FILE: C ECC: 15 2000 12 .998 1683.259 21880 .161 0.249 17 .936 25.102 9 .348 8028 .113 14712 .775 1 15.998 2086.624 24496 2003.574 0.358 14 11.836 17.741 9 15.998 1037.407 16422 2000.462 0.827 23 15.689 30.191 10 .456 73021.500 .020294600.500 .002 .602 73625.062 .473315936.187 .633 .848 71416.875 .762301526.562 .827 .984 11188.637 66790.625 .363 16633.141294551.625 .225 1.637 .141 3960 .580 11670 .188 1 0.000 0.000 0.000 0 0.000 0.000 0.000 0 0.000 6.000 5.000 -1 -999.250 -999.250 -999 -999.250 -999.250 -999 -999.250 -999.250 -999 : \CLIFF\W04579. WDF 4579.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: ARCO ALASKA INCORPORATED D.S. 15 - 16 .250 -999 .250 -999 .250 -999 11360.000 11730.000 0.500 .672 75447.750 .750312404.937 .916 .000 0.000 .000 0.000 .000 .250 -999.250 .250 =999.250 .250 3371.897 79.281 2517.607 50.745 5085.840 63.088 86.785 132.520 5571.500 75.297 2593.605 106.229 4392.762 62.862 901.502 132.269 0.000 0.000 -999.250 ~-999.250 NUMBER OF CURVES: 20 DEPTH BKL BKS CCL GR ISS LS MON RIN SGMA SPD SS CSS G1 G2 GElS MSD RATO RBOR RICS FILE:PASS 6.003 FILE INTERVAL: START= 11730.000 END= 11360.000 DEPT 11730.000 11705.000 11680.000 11655.000 11630.000 11605.000 11580.000 11555.000 11530.000 11505.000 11480.000 11455.000 CCL SPD LS SS G1 GElS GR MON MSD SGMA CSS ISS BKS RATO RICS RIN RBOR -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 -999.250 -999.250 -999.250 -999.250 300.000 16.998 500.162 10929.227 48.686 2049.827 1.159 43.635 279.795 21.895 34.287 10.403 0.000 16.889 759.763 15545.465 24.633 2021.218 0.608 30.173 181.392 20.435 33.872 10.109 0.000 27.877 169.:741 16.998 2078.311 36179.449 2022.485 0.201 22.478 17,414 13..316 9.421 0.000 16.762 2502 27.210 2022.942 0 140.583 15.823 11 0.000 15.998 3283 27.574 2021.801 0 156.890 12.644~ 11 0.000 16.653 2615 26.098 2022.816 0 160.706 15.488 11 0.000 15.998 2320 29.921 2020.298 0 193.225 15.926 12 0.000 15.998 3387 29.805 2021.004 0 162.954 12.132 11 0.000 15.998 1007 66.997 2019.819 0 285.563 25.315 17 0.000 15.998 3867 25.794 2021.081 0 218.523 11.588 10 .388 39504.105 .268 18.459 .822 9.120 .578 41517.773 .111 15.280 .244 8.539 .768 40425.398 .255 17.964 .018 9.154 .362 36982.547 .349 19.595 .948 9.383 .415 41145.766 · 288 15. 041 .182 8.521 .517 25442.078 .614 38.777 .199 9.552 .763 44852.570 .168 14.289 .758 8.566 0.000 16.998 2062.438 34398.664 45.792 2019.109 0.514 21.653 1211.655 72753.812 8856.039294893.750 2.066 3121.174 69527.687 10606.852286148.687 1.981 9600.816110346.687 22297.027295474.875 1.459 12862.031107958.687 24595.305290568.562 1.433 15609.887108852.062 26669.125294291.437 1.429 13912.297107010.625 25283.266288799.562 1.400 10968.512109500.625 23109.746296577.187 1.472 15454.496112746.250 2.6766.855298872.187 1.426 3501.045112373.125 17021.168295618.062 1.576 17518.715118657.250 29286.469313108.625 1.405 9112.109113092.937 21871.395299439.812 G2 BKL -999.250 -999.250 53.057 110.710 456.310 55.083 2317.434 53.120 3859.627 74.316 5750.770 96.857 4617.187 49.962 3008.027 83.821 5768.926 71.427 237.119 131.707 6923.820 75.915 2312.840 127. 131 230.913 16.556 15.733 11430.000 0.000 16.234 2988.981 28.106 2020.539 0.203 165.210 13.908 11.601 11405.000 0.000 16.889 1476.284 60.799 2018.913 0.533 199.419 20.343 16.436 11380.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 6.000 11360.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9.425 41453.336 15.419 8.988 30264.027 29.512 9.558 1.577 15807.852107464.375 26638.875296156.000 1.468 5481.473116853.000 19399.520308509.937 1.589 0.000 0.000 0.000 0.000 0.000 0.000 5.000 -1.000 -999.250 -999.250 -999.250 End of execution: Tue 11 SEP 90 3:00pm Elapsed execution time = 27.95 seconds. SYSTEM RETURN CODE = 0 -999.250 -999.250 -999.250 -999.250 -999.250 6006.418 83.199 801.714 119.331 0.000 0.000 -999.250 -999.250
