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Home My WebLink About189-0550 0 PLUGGING a LOCATION CLEA_R~CE REPORT State of Alaska .ALASKA 0IL & GAS CONSERVATION COHMISSION · :4e=,c-=::c'~_m To File: zoi No Well Name 7-0o Note casinq~$, wt~ death, c:::,C, vol, Perf i~Ca~ra!a - ~ps: ~ Review the well file, and' c~ent on plugging, well head sUatus, ~%nd location c!eara~ce - provide loc. clear, code. };ell head cut off: Marker pcs~ or plats: Location Clear~cs: Conclusions: ~ Code / Signed · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil__ Gas__ Suspended_ Abandoned_X Service_ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 89-55 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~.,"'~'"~-~.,;'~ 50-029-21948 4 Location of well at surface i,;l~~l~' 9 Unit or Lease Name 871' FNL, 326' FWL, Sec 19, T11N, R15E, UM. ~!~17.,~ PRUDHOE BAY UNIT At Top Producing interval~!~ 10 Well Number 2109' FNL, 472' FWL, Sec 20, T11N, R15E, UM. 18-25 At Total Depth ~,~. 11 Field and Pool 2367' FSL, 2277' FEL, Sec20, T11N, R15E, UM. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc,) !6 Lease Designation and Serial No. 48' RKB ADL 28321 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 5/27/89 6/18/89 8/17/97 (P&A) N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12885' MD / 8747' TVD 12650' MD / 8731' TVD YES_X NO__ 1997' feet MD 22 Type Electric or Other Logs Run AMS/TCC/CAL/GR/CBT, MWD/GR/CNL/RES log 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30,, 2150 Sx Poleset - 13-3/8" 68# K-55/L-80 Surf 3840' 17.5" 2500 Sx CS III & 600 Sx Class G - 9-5/8" 47# L-80 Surf 10047' 12.25" 750 Sx Class G - 7" 29# L-80 9720' 11873' 8.5" 610 Sx Class G - 4-1/2" 11.5# L-80 11492' 12803' -. Uncemented Slotted Liner - -- , 24 Per[orations open to Production (MD+'r'VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 3-1/2" Tbg 11511' 11518' Upper section of Slotted Liner interval left uncemented for I post CTD Extension production: 11717 - 12650' MD; 8705- 8731' 7'VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED Bottom section of Slotted Liner interval P&A'd w/Cement at: 12650 - 12767' MD; 8731 - 8739' 7-VD 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7/13/89 Plugged & Abandoned (8/17/97) Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR N/A - TEST PERIOD__ I Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) - 24 HOUR RATE _X 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. Form 10-407 I~je Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Top Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 10167' TRUE VERT DEPTH 8293' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase, N/A 31 LIST OF ATTACHMENTS Summary of 18-25 Pre CTD Extension Plug & Abandonment. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~.~.~ "~, ~ Enaineerina Sunervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injecti~ E C E I V E D Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". , .i ~ } Form 10-407 ,~laska 0ii & Gas Cons. C0mmissim't Anchorage 18-25 DESCRIPTION OF WORK COMPLETED PRE CTD WELLBORE EXTENSION PLUG & ABANDONMENT 8/17/97: MIRU CTU & PT equipment. RIH w/nozzle & tagged top of fish (four 4-1/2' Centralizer Arms & Bull Plug lost 9/15/92) at 12770' MD. PU & pumped 9 bbls of 17 ppg Class G cement on top of fish to place a cement plug in the 4-1/2" slotted liner to 12650' MD in preparation for CT Wellbore Extension Drilling operations. POOH. RD. CTU Drilling Operations commenced to drill to the new 18-25A bottom hole location on 9/27/97. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 REFERENCE: 41ask~ Oil ... ~n:;oc,;'~;' c~,~,~ion ARCO ~~D ~0~ ~ /2-16A 9-25-93 ~-Ii~ ~2-16A 9-26-93 ~?¢ 3-29 9-19-93 7o-qz '4-1 9-23-93 V ~-h 4-4 9-17-93 75-v'/ 4-7ST 9-19-93 ?~-to 4-8 9-23-93 ob-qa 4-16 9-13-9~3 ~-2~ 9-5A 9-16-93 /~5~tfl~ 9-29 9-15-93 /9-35A 9-17-93 q ~' ~l ~9-35A 9-18-93 \9-35A 9-!9-93 ?O-~Z 9-42 9-14-93 ~o--/Z,~ 9-44 9-15-93 /12-22 9-25-93 E~-Ea:) \12-22 9-26-93 ~l~ 12-30 .9-22-93 7~-~3 14-4 9-24-93 ~i~ I 14-31 9-20-93 ~2-o7 15-2 9-14-93 ~z-~O 15-18 9-21-93 ~Z-~a 16-29A 9-24-93 ~-~¥S 17-12 9-22-93 ~S5 18-25 9-20-93 SBT/GR/CCL I~.o- I ~li o Collar (c-l'cb ~os~O-tO~l 0 Production ~qoo -q% ~ CNL ~ z~O-~ Perf Record ~l~o-I ;~so Run Run Run Run Run 9 1, 1, 1, 1, Perf Record ~o-~zz~ R~m 1, Inj Profile]Sf, nlY~'m.~)~l~r~Run 1, ~ ~tect/T,~vl~i~a R~ 1, ~ucflon/a~,~N~],~ Rim 1, ~ Detect~>}7~/~,~ R~n 1, Pe~Record %l~ll~ R~ 1, Pe~ Record %la-~107~ R~ 1, ~od ~offie l~17*~/e~ R~ 1, ~od ~o~ele~~~ R~ 1, Jewe~ i~l ccc R~ 1, Pe~ Record 5q0o-q%o R~ 1, POG~ ~t/~G ~ch R~ 1, Pe~Record ll~o~l~5~ R~ 1, ~oducflon ~-q~o R~ 1, ~od~offie[~]~laa Rim 1, B~er ~~ble Packer R~ 1, ~oduc~onl~l~l~~~ 1, ~od ~offie ~o~tz~o R~ 1, 5" Atlas 5" Sch 5" Sch 5" Sch 5" Sch 5" Ioloo 2" ~-l°~5 Sch l"&5" Sch ~-~ l"&5" Sch 5" Sch 5" . Sch l',&5" .Sch 5" ~ ~$~r'l Sch 5" l~-m~ Sch 5'~0-~- Sch 5" Sch 5" ,z~o - ~ Sch 5" Sch 5" Sch 5" l~vd~ Sch 5,, I ~-~azso Sch 5" ~m-tzz~z Sch 5" 2~a>llUt Sch 5" Sch Have A Nice Day! Sonya Wallace ATO-1529 Please sign and return the attached copy as receipt of data. RECEIVED BY / Trans# 93118 # CENTRAL FILES # CHEVRON # BPX # STATE OF ~KA # PHILLIPS # LILLIAN TIULANA # EXXON # MOBIL ~ STATE OF ALASKA ~-. ALASKA ¢ 'AND GAS CONSERVATION CO' iSSION REPORT OF SUNDRY WELL OPEr,.ATIONS Pull tubing Alter casing Repair well Other 6. Datum of elevation(DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 5. Type of Well x 48 RKB feet Development Exploratory Stratigraphic Service AUG ) 1 1EIgl) 4. Location of well at surface 871' FNL, 326' FWL, Sec. 19, T11 N, R15E, UM At top of productive interval 2109' FNL, 472' FWL, Sec. 20, T11N, R15E, UM At effective depth At total depth Alaska 0il & Gas Cons. :Anchorage 2367' FSL, 2277' FEL, Sec. 20, T11N, R15E, UM 7. Unit or Property Prudhoe Bay Unit 8. Well number 18-25 9. Permit number/approval number 89-55 10. APl number 50 - 029-21948 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12885 feet Plugs(measured) true vertical 8747 feet Effective depth: measured N/A feet true vertical N/A feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2150# Poleset 110' 110' Surface 3792' 13-3/8" 2500 sx CS III & 600 sx CIG 3840' 3491' Production 9999' 9-5/8" 750 sx CIG 10047' 8252' Liner 2153' 7" 610 sx CIG 11873' 8723' Slotted Liner 1311' 4-1/2" 12803' 8741' Perforation depth: measured Slotted Liner: 11717-12767' true vertical Slotted Liner: 8705-8739' Tubing (size, grade, and measured depth) 3-1/2", 9.3# L-80, PCT @ 11511' MD Packers and SSSV (type and measured depth) 7" TIW SS Mech Set Packer @ 11518' MD; 3-1/2", Camco TRDP SSSV @ 1997' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 956 9693 0 -- Subsequent to operation 956 9335 0 -- Tubing Pressure 1696 1228 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. _ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 1f'l."4R/4 KRF c.n: RW .IWP 18-25 DESCRIPTION OF WORK COMPLETED OIL BASED MUD REMOVAL & FOAMED ACID STIMULATION 7110193: MIRU CTU & PT equipment. Loaded wellbore w/1% NH4Cl Water & RIH w/CT. Tagged bottom at 12760' MD, then PU & reciprocated an Oil Based Mud Removal treatment across the slotted liner at: 11717' - 12767' MD (Z1B) Ref. Log: CBT. Jetted 202 bbls MCOB (Mud Cleaner "OB") @ 2.5 bpm, followed by 32 bbls 1% NH4CI Water, followed by Shutdown for I hour soak. Resumed pumping Nitrogen @ 3000 scfm, and flowed back drilling mud & solid returns. Shutdown after pumping a total of 250 mscf of N2, and recovered 475 bbls of returns. POOH w/CT. Rigged down. 8/3/93: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/1% NH4CI Water & RIH w/CT to tag bottom at 12743' MD, then reciprocated a multiple stage Foamed Acid Stimulation Treatment, through the horizontal slotted liner at: 11717' - 12767' MD (ZIB) Ref. Log: CBT. Pumped Preflush: a) 25 bbls 1% NH4CI Water w/foamer & N2 @ 3700 scfm down CT backside, followed by b) Shutdown. Resumed pumping Preflush: c) 151 bbls 1% NH4 CL Water w/foamer & N2 @ 3700 scfm down CT backside, followed by Stage #1 down CT consisting of: d) 100 bbls 15% HCI w/N2 injected @ 500 scfm, followed by e) 50 bbls 12% HCl - 3% HF w/N2 injected @ 500 scfm, followed by f) 25 bbls 1% NH4Cl Water w/foamer, followed by Stage ~2 down CT consisting of: g) 75 bbls 1% NH4 CL Water w/foamer & N2 @ 3700 scfm down CT backside, followed by h) 100 bbls 15% HCl w/N2 injected @ 500 scfm, followed by i) 50 bbls 12% HCl - 3% HF w/N2 injected @ 500 scfm, followed by j) 35 bbls 1% NH4Cl Water w/foamer, followed by Stage #3 through Stage #6: k) consisting of steps 'g through j' above repeated for four more cycles, followed by I) 100 bbls 1% NH4CI Water Overflush, followed by m) Shutdown. POOH w/CT. the treatment. Moved the CT nozzle location uphole in 100' increments before pumping each stage of Rigged down. Flowed well. Returned well to fulltime production & obtained a valid welltest. AU G 1 199, ,Alaska Oil & Gas Cons. Comm'~ssi, o~ Anchorage ARCO ALASKA, INC, F',O, BOX 'i~0360 ANCHORAGE, ALASKA DATE' 8-~9-8~~ , REFERENCE' ARCO PRESSURE DATA 3-t :5 7-'27-8,° BHF'--SI'AI'IC GRADIENT CAMCO 3-33 '7-i4-89 BHF'--STATIC GRADIENT CAMCO 4-2 7--8-89 BHF'--SI'ATIC GRADIENT (W/'ATTACH.) CAMCO 7-5 7-i9-89 BHF'--£TATIC GRADIENT CAMCO T-FA 7--3i -8~ BHF ....F'BU HRS 7-8 '7-29-89 BHF ....STATIC GRADIENT CAMCO 7-i6, 8--5'-89 BHF ..... STATIC GRADIENT CAMCO 7- i 4 '7-29'-89 BHF ....PBU HRS 7-27 7-25--89 BHF'--S'FAT IC GRADIENT CAMCO '7-5~ 7-23-8~ BHF ....STATIC =RADIENT CAMCO 9-2,1 7/t4-i5/8~ BHF ....STATIC GRADIENT CAMCO 9-~8 8-i '2-89 BHF'--STA'FIC GRADIENT CAMCO ii-2 7-7-89 BHP--STA'rlC GRADIENT HRS ti-7 7-9.-89 BHP--STATIC GRADIENT HRS ii-J6 7-i~-89 BHF ....SI'A'FIC GRADIENT HRS ii-J7 8-ii-89 BHP--FLOWING GRADIENT CAMCO i 2-~ 7 ~ . -~S-.89 BHP--STAI'IC GRADIENT CAMCO i4.-19 8-i~-89 BHP--STATIC GRADIENT CAMCO i4-22 8-i7-89 BHF'--STAI'IC GRADIENT CAMCO i4-~6 7-29-89 BHF'--FLOWING GRADIENT CAMCO i4-39 8-i~-89 BHF ....STATIC GRADIENT CAMCO i5-i5 7-2i-89 BHP--STATIC GRADIENT CAMCO iG.-i 2~ ' ~) 1-~.6-89 BHP--STATIC GRADIENT CAMCO i 6.-2~ 7.-i S-89 BHF'--STATIC GRADIENT CAMCO i8-25 7-.iS-89 BHP--STATIC GRADIENT CAMCO PLEASE £IG N AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARAI'HON MOBIL F'HILLIF'S F'B WELL FILES R & D BF'X STATE OF TEXACO ALASKA STATE Of ALASKA ALASKA ,-~L AND GAS CONSERVATION C(~,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS .ri SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 'Classification of Service Well 4. Location of well at surface 871' FNL, 326' FWL, 5ec.19, T11N~ ELSE, UH At Top Producing Interval 2109' FNL~ 472' FWL~ 5ec.20, TllN, R15E~ UM At Total Depth 2367' FSL, 2277' FEL, Sec.20, TllN~ ELSE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 48' 6. Lease Designation and Serial No. ADL 28321 12. Date Spudded 05/27/89 17. Total Depth (MD+TVD) 1 2885 'MD/8747 'TVD 13. Date T.D. Reached I 06/18/89 18. Plug Back Depth (MD+I'VD) I N/A 7. Permit Number 89 ~55 8. APl Number 50- 029-21948 9. Unit or Lease Name Prudhoe Bay Unit. 10. Well Number 18-25 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 06/29/89 I N/A feet MSL 1 19. Directional Survey I 20. Depth whereSSSV set I 21. Thickness of Permafrost YES [] NO []I 1997' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run AMS/TCC/CAL/GR/CBT_, MWD/GR/CNL/RES log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP ! BOTTOM ?0" 91;5~ H-~0 SurfI !10' q-5/R" 47# L-80 Surf l !00~7' 7" 29~ I,-RO 97?dwi 11R73,, 4-1/2" 11.5~ L-BO 11497'1 24. Perforations open to Production (MD+TVD of Top and 8ottom and interval, size and number) Slotted Liner Completion HOLE SIZE 90!, ! 7-!/2" ! 2-!//+" R-l/?" ---- CEMENTING RECORD 2! 50# Po!eset 2500 750 sx C!ass G Slotted Liner TUBING ~ECO~D AMOUNT PULLED w C!as~ G 25. SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 11524 ' 11518 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, 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 Flow Tubing Press. Hours Tested Casing Pressure PROI~UCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF IWATER-BBL WATER-BBL j RATIO I CHOKE SIZE GAS-OIL t OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None (Dani) WC6/055 RECEIVED 0 ') 989 A~aska Oil & Gas Cons. C0mmissi0n ,Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 3O. NAME Top Sadl erochit GEOLOGIC MARKERS MEAS. D E,PTH 10167' TRUE VERT. DEPTH 8293' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History, MWD (2 copies) I hereby certify that the foregoing is true and correct to the best of my knowled~je I NSTR UCTI ONS 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. ltern 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: tf no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "lnltisl Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field PRUDHOE BAY Auth. or W,O. no. AS2882 County, parish or borough NORTH SLOPE ILease or Unit ITitle ADL: 28321 DRILL & COMPLETE [ SIa~,K DS 18-25 IWel~ no. API: 50-029-21948 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 05/28/89 ( TD: 1033'( 1 SUPV:RO 05/29/89 TD: 2316'( SUPV:RO 05/30/89 1~: 3865'( SUPV:RO 05/31/89 ( TD: 3865'( SUPV=RO 06/01/89 ( TD: 4375'( SUPV:RO 06/02/89 ( TD: 6250'( 1 SUPV:RO 06/03/89 ( TD: 7365'( 1 SUPV=RO ARCO W.I. IDate I Hour 21 · 0000 Pr or status if a W.O. 05/27/89 14:00 Complete record for each day reported NABORS 28E .) 133) :) :83) ) 49) .o) DRL W/ DYNA DRL MW: 8.8 VIS:102 NO DIVERTER. ACCEPT RIG ~ 0800 HRS, 5/27/89. MIX SPUD MUD. SPUD AT 14:00 HRS, 05/27/89. DRLD TO 545'. TRIP F/ BIT. DRLD F/ 545' TO 972'. TRIP F/ BIT. DRLD W/ DYNA DRL ~ 1033'. ACCEPT RIG AT 08:00 HRS, 05/27/89. DAILY:S91,270 CUM:$91,270 ETD:S91,270 EFC:$3,325,000 DRLD W/ DYNA DRL AT 2316' MW: 9.2 VIS: 64 DRLD W/ DYNA DRL TO 1562'. SURVEY. TRIP F/ BIT. DRLD W/ DYNA DRL TO 2316'. DAILY:S75,769 CUM:$167,039 ETD:S167,039 EFC:$3,325,000 CIRC AT 3865' 13-3/8"% 3840' MW: 9.3 VIS: 58 DRLD W/ DYNA DRL TO 2316'. SURVEY. TRIP F/ BIT, BHA. DRLD F/ 2316' TO 3865'. SHORT TRIP F/ CSG RUN. DAILY:S65,725 CUM:$232,764 ETD:S232,764 EFC=$3,325,000 WELDING ON BRADENHEAD 13-3/8"~ 3840' MW: 9.4 VIS: 57 FINISHED 26 STD SHORT TRIP. C AND C MUD. POH. R/O AND RAN 97 JTS 13.375" 68~ LB0 BTC CSG. CIRC CSG VOL. CMT'D W/ 2500 SX COLD SET III ~ 12.2 PPG FOLLOWED BY 600 SX CLASS G ~ 15.8 PPG.BUMPED PLUG. FLOATS HELD. CIP ~ 2300 }iRS 5/31/89. DID TOP JOB W/ 100 SX COLD SET II 8 15.8 PPG. TOP JOB CIP ~ 2330 HRS 5/31/89. R/D CSG EQMT. SET CSG SLIPS W/ 245000 LBS. WELDING ON FMC GEN 4 BRADENHEAD. DAILY:S326,705 CUM=$559,469 ETD:S559,469 EFC:$3,325,000 DRILLING AT 4375 13-3/8"% 3840' MW: 8.8 VIS: 30 WELDED ON GEN 4 BRADENHEAD. TESTED TO 1100 PSI. N/U BOPE. TESTED BOPE TO 5000 PSI. SET WB. P/U BHA. WIH TO 3679'. TESTED CSG TO 2500 PSI FOR 30 MIN. DRLD CMT & NEW FORM TO 3875'. RAN LOT - 14.4 PPG EMW. DRILLED TO 4375'. DAILY:$88,S89 CUM:$648,058 ETD:S648,058 EFC=$3,325,000 ) DYNA DRLG AT 6250' 13-3/8"8 3840' MW: 9.1 VIS: 30 75) DRYA DRLD F/ 4375' TO 6250'. DAILY:S58,395 ) DRILLING AT 7365 15) DRILLED TO 6791' 7365'. DAILY:S50,950 CUM:$706,453 ETD:S706,453 EFC:$3,325,000 13-3/8"8 3840' MW: 9.1 VIS: 36 . POH. CHANGED BHA AND BIT. TIH. DRILLED TO CUM:$757,403 ETD:S757,403' EFC:$3,325,000 The above is correct For form preparati .... ddistribution, ~'~ ~Jb~ ~ i '~' ~ ~ see Procedures Manual, Section 10, ~ ~, Drilling, Pages 86 and 87. 1989 A[,chomgo AR3B-459-1-D ITitle Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish JStateAK NORTH SLOPE Lease or Unit DS 18-25 PRUDHOE BAY Date and depth as of 8:00 a.m, 06/04/89 ( TD: 8118'( SUPV:TJ 06/05/89 ( TD: 8750'( SUPV:TJ 06/06/89 ( TD: 8931'( SUPV:TJ 06/07/89 ( TD: 0'( SUPV:TJ 06/08/89 ( TD: 9911'( SUPV:TJ 06/09/89 ( TD:10013' ( SUPV:TJ 06/10/89 ( TD:10071' ( SUPV:TJ 06/11/89 ( TD:10071' ( SUPV=TJ Complete record for each day while drilling or workover in progress NABORS 28E JWell no. 8) 753) 9) 632) o) 181) 1) 0) 2) 911) 3) 102) 4) 58) 5) 0) The above Js correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 DRILLING AT 8118 13-3/8"@ 3840' MW: 9.7 VIS: 36 DRILLED TO 7825'. POH. CHANGED BHA AND BIT. TIH. DRILLED TO 8118'. DAILY:S66,563 CUM:$823,966 ETD:SO EFC:$4,148,966 POH FOR BHA CHANGE 13-3/8"~ 3840' MW: 9.9 VIS: 40 DRILLED TO 8452'. POH AND CHANGED BHA & BIT. TIH. DRILLED TO 8750'. DAILY:S52,200 CUM:$876,166 ETD:S876,166 EFC:$3,325,000 GIH W/ ANGLE BUILD ASSY 13-3/8"@ 3840' MW:10.1 VIS: 43 POH. CHANGED BHA. WIH. WASH AND SVY F/ 8750- 8750'. DRILLED F/ 8750-8931'. ANGLE NOT BUILDING. POH AND CHANGE BHA. GIH W/ A~GLE BUILDING ASSY. DAILY:S57,644 CUM:$933,810 ETD:SO EFC:$4,258,810 DRILLING AT 9540 13-3/8"~ 3840' MW:10.2 VIS: 43 WIH TO 8931'. DRILLED TO 9317'. POH FOR BHA CHANGE. WIH TO CSG SHOE. CUT DRILL LINE. WIH TO 9317'. DRILLED TO 9540'. DAILY:S54,898 CUM:$988,708 ETD:S988,708 EFC:$3,325,000 DRLG AT 9911' 13-3/8"~ 3840' MW:10.2 VIS: 47 DRLD F/ 9540' TO 9784' DROP SURVEY. POOH F/ BHA CHNG. RIH AND WASH AND REAM F/ 9490' TO 9550'. DRLD F/9784' TO 9798'. POOH TO CHNG OUT BROKEN ROTARY CHAIN. RIHAND REAM 15' TO BTM. NO FILL. DRLD F/ 9798' TO 9911'. DAILY:S51,191 CUM:$1,039,899 ETD:S1,039,899 EFC:$3,325,000 TIH W/ NEW BIT AND BHA 13-3/8"@ 3840' MW:10.2 VIS: 51 DRLD F/ 9911' TO 10013'. LOST 800 PSI PUMP PRESS. SURVEY. POOH. TWISTED OFF AT DYNA DRL. TOP OF FISH AT 9991'. PU TRI STATE 10-3/4" OVERSHOT AND RIH. WASH OVER AND LATCH ON FISH AT 9991'. POOH W/ FISH. LD SAME. PU BIT AND BHA AND RIH. DAILY:S58,148 CUM:$1,098,047 ETD:S1,098,047 EFC:$3,325,000 LAND CSG 9-5/8"@10047' MW:10.2 VIS: 44 TIH TO 9883'. DRLD TO 10071'. SHORT TRIP. CBU. POOH TO RUN 9-5/8" CSG. RU AND RUN 237 JTS OF 9-5/8" 47~, L80 BTC CSG W/ FS AT 10047' AND FC AT 9957'. LAND CSG. RU TO CIRC. DAILY:S304,596 CUM:$1,402,643 ETD:S1,402,643 EFC:$3,325,000 DRLD CMT 9-5/8"@10047' MW:10.1 VIS: 36 RU AND CIRC. PUMP 50 BBLS GAF. DROP PLUG. PUMP 750 SXS OF CLASS "G" CMT AT 15.8 PPG. DROP PLUG. DISP AND BUMP PLUG W/ 3000 PSI. CIP AT 13:30 HRS 06/10/89. INSTALL PACKOFF. TEST SAME. ND BOPE'S. INSTALL TBG SPOOL. NU BOPE'S. PU 8-1/2" BHA AND RIH. TAG CMT AT 9924'. TEST CSG TO 3000 ITitlo Arichora o AR3B-459-2-B INumber all daily well hislory forms consecuHvely [Page no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Instruclions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "hlterlm" sheets when filled out but not less frequenlly than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ot oil strin§ until completion. District Field ARCO ALASKA INC. ICounty or Parish IStatezl~ NORTH SLOPE Lease or Unit DS 18-25 PRUDHOE BAY ~te and depth Complete record for each day while drilling or workover in progress asof8:~ a.m. NABORS 28E DAILY:S96,012 CUM:$1,498,655 ETD:S1,498,655 EFC:$3,325,000 06/12/89 ( .6) DRLG AT 10237' 9-5/8"@10047' MW= 8.9 VIS= 47 TD=10237' ( 166) DRLD FC AND CMT TO 10014'. TEST CSG TO 3000 PSI. DRLD CMT SUPV:TJ AND SHOE, AND 10' NEW FORM. CBU. PERFORM LEAK OFF TEST. EMW ~ 12.5 PPG. CLEAN MUD PITS. CHNG OVER TO OIL BASE MUD. DRLD F/ 10081' TO 10237'. DAILY:S42,458 CUM:$1,541,113 ETD:S1,541,113 EFC:$3,325,000 06/13/89 ( .7) TIH sLOWLY 9-5/8"@10047' MW= 9.1 VIS= 55 TD=10655' ( 418) DRILLED FROM 10237 TO 10454. POH. CHANGED BHA. TIH. DRILLED SUPV=RO TO 10655'. BIT TORQUED UP. POH. HOLE TAKING MUD. CHANGED BHA. TIH. HOLE TAKING MUD AT I BPM. DAILY:S72,851 CUM:$1,613,964 ETD:S1,613,964 EFC=$3,325,000 06/14/89 ( 8) DRL AT 11000' 9-5/8"~10047' MW: 8.9 VIS: 47 TD:10930'( 275) RIH TO 6133'. MONITOR WELL,FILL BACKSIDE. RIH TO 10006'. SUPV:RO MONITOR WELL, FILL BACKSIDE. DISPLACE WELL TO OIL BASE MUD. NO LOSS. RIH TO 10568' REAM F/ 10568' TO 10655'. NO FILL. CIRC AROUND 20 BBL LCM PILL. DRLD F/ 10655' TO 11000'. DAILY=S61,362 CUM:$1,675,326 ETD:S1,675,326 EFC:$3,325,000 06/15/89 ( 9) DRLG AT 11,210' 9-5/8"@10047' MW: 8.9 VIS= 53 TD=11210'( 280) DRLD F/ 11000' TO 11117' POOH. CHNG BIT, BHA. RIH. CDL. SUPV=RO REAM F/ 11074' TO 11117'. DRLD F/ 1117' TO 11210'. DAILY:S59,761 CUM:$1,735,087 ETD:S1,735,087 EFC:$3,325,000 06/16/89 ( :0) OBSERVE WELL 9-5/8"@10047' MW: 8.8 VIS: 41 TD:11588'( 378) DRILLED TO 11492. POH FOR BHA CHANGE. WIH. LOST 30 BBLS MUD SUPV:TJ WHILE GIH. DRILLED TO 11588'. CIRC AT 11588' LOSSING 1BPM MUD. SPOT LCM PILL. POH TO 10047'. OBSERVE WELL. LOSING 2-3 BPH. WIH TO 10320' LOST RETURNS. SPOTTED LCM PILL AT 10320'. POH TO 9946'. OBSERVE WELL FOR MUD LOSS. DAILY:S58,000 CUM:$1,793,087 ETD:S1,793,087 EFC:$3,325,000 06/17/89 ( 1} POOH 9-5/8"@10047' MW: 8.9 VIS: 52 TD:11866' ( 278) OBSERVE WELL. RIH . DRLD F/ 11588 TO 11713'. PUMP PILL. SUPV:TJ POOH. CHNG MWD AND RIH. WASH 30' TO BTM. DRLD F/ 11713' TO 11866'. DAILY:S51,067 CUM:$1,844,154 ETD:SI, S44,154 EFC:$3,325,000 06/18/89 (!2) DRLG AT 12717' 9-5/8"~10047' MW: 8.9 VIS: 47 TD:12717'( 851) SURVEY. TRIP F/ BHA CHNG. CDL. REAM F/ 11741' TO 11866'. SUPV:TJ DRLD F/ 11866 TO 12717'. DAILY:S52,660 CUM:$1,896,814 ETD:S1,896,814 EFC:$3,325,000 IWell no. For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supt. AR3B-459-2-B s[P l§89 Ar~ch0rageNumber all dsily well history f ........... lively las hey are prepared for each well, Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish JState AK NORTH SLOPE Lease or Unit DS 18-25 PRUDHOE BAY IWell no. Date and deptll as of 8:00 a.m. 06/19/89 ( TD:12885' ( SUPV:TJ 06/20/89 ( TD:12885' ( SUPV:TJ 06/21/89 ( TD:12885' ( SUPV:TJ 06/22/89 ( TD:10200'( SUPV:TJ 06/23/89 ( TD=11860'( SUPV:TJ 06/24/89 ( TD=12885 PB:12885 SUPV:RO 'Complete record for each day while drilling or workover in progress NABORS 28E 168) -)4) O) .)5) 0) .)6) 0) .)7) L660) 28) RIH W/ MILL 9-5/8"@10047' MW: 8.9 VIS= 46 DRLD F/ 12717' TO 12885'. CBU. PUMP PILL. SHORT TRIP AND RE-LOG MWD GR/CNL/RES LOG F/ 11428' TO 11751'. CBU. POOH. PU 3.5" DP AND RIH. DAILY=S133,070 CUM:$2,029,884 ETD:S2,029,884 EFC:$3,325,000 POOH LDDP 9-5/8"@10047' MW: 8.9 VIS: 47 PU 3.5" DP AND RIH. CBU. PUMP PILL AT 12885. POOH TO 12135'. CBU. PUMP AND DISP FORM-A-PLUG CMT PLUG (39 BBLS). POOH. PU 8.5" BHA AND RIH. TOP OF PLUG AT 11660'. CBU. WASH AND DRESS PLUG F/ 11660' TO 11873'. CIRC HOLE CLEAN. POOH F/ 7" LNR. DAILY:S108,792 CUM:$2,138,676 ETD:S2,138,676 EFC:$3,325,000 POOH W/ LRN RUNNING TOOL 7"@11873' MW= 9.0 VIS: 47 POOH LD 5" DP. RU AND RIH W/ 7", 29#, L80 BTC CSG W/ FS AT 11873',TOL @ 9720',& FC AT 11825'. CIRC AND COND. CMTD W/610 SX CLASS "G" CMT AT 15.8 PPG. SET LNR HGR W/ 1500 PSI AT 9731'. RELEASE F/ LNR HGR AND INFLATED CTC ECP W/ 2800 PSI. CIP AT 05=30 HRS, 06/21/89. POOH W/ LNR SETTING TOOL. DAILY:S167,122 CUM:$2,305,798 ETD:S2,305,798 EFC:$3,325,000 DRL CMT TO 10200' 7"@11873' MW: 8.8 VIS: 47 POOH. LD TIW RUNNING TOOLS. CHNG BHA. TIH AND TAG CMT AT 9402'. DRLD CMT STRINGERS F/ 9402' TO 9631'. DRLD FIRM CMT F/ 9631' TO 9721' CIRC HOLE CLEAN. POOH. LD DP, BHA. PU 4-3/4" BHA AND RIH. TAG CMT AT 9721'. (TOL) DRLD FIRM CMT STRINGERS F/ 9721' TO 10200'. DAILY=S56,719 CUM:$2,362,517 ETD:S2,366,773 EFC:$3,320,744 RU SOS 7"@11873' MW: 8.8 VIS: 45 DRLD CMT F/ 10200' TO 11784'. CIRC AT 11784'. TEST LNR LAP TO 3000 PSI. LOST 125 PSI. DRLD FC AND CMT TO 11860'. CIRC HOLE CLEAN AT 11860'. TEST CSG AT 11860' TO 3000 PSI. LEAK OFF TO 1500 PSI. PUMP PILL AND POOH TO LOG. PU LOGGING TOOLS AND RIH ON 3-1/2" DP. DAILY:S44,459 CUM=$2,406,976 ETD=S2,406,976 EFC=$3,325,000 ClRC AT 12885 7"@11873' MW: 8.90BM WIH W/ DP TO 9624'. R/O SCHLUM. AND WIH W/ W/L PROBE. WIH W/ DP TO 11860'. RAN AMS/TCC/CALY/GR/CBT F/ 11860 TO 9720'. POH W/ WL. R/D W/L. POH W/ DP AND . LOGGING TOOLS. INSTALLED VBR RAMS. WIH W/ 6-3/4" BHA. CUT AND SLIP DRILL LINE. DRILLED CMT F/ 11860-11878'. DRILLED FORMA-PLUG F/ 11878-11958'. WASHED TO 12885'. NO FILL. CBU AT 12885' DAILY:S74,923 CUM:$2,481,899 ETD=S2,481,899 EFC:$3,325,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B JTitleJ~,~y ~ Orilling Supt. sip 1 1989 II daily well history forms consecutively as they are prepared for each well. Page no, ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less'frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field ARCO ALASKA INC. ICounty or Parish Stats NORTH SLOPE Lease or Unit DS 18-25 PRUDHOE BAY Date and depth as of 8:00 a.m. 06/25/89 ( TD:12885 PB:12885 SUPV:RO 06/26/89 ( TD:12885 PB:12885 SUPV:RO 06/27/89 ( TD:12885 PB:12885 SUPV:RO 06/28/89 ( TD:12885 PB:12885 SUPV:RO 06/29/89 ( TD:12885 PB:12885 SUPV:RO Complete record for each day while drilling or workover in progress NABORS 28E )0) ~2) ~3) ATTEMPT TO SET PKR. 7"@11873' MW: 8.90BM C & C MUD. SHORT TRIP. CBU. POH L/D BHA. INSTALLED SHEAR RAMS. P/U 4-1/2" SLOTTED LINER AND 2-1/16" WASH STRING.WIH W/ SLOTTED LINER. CIRC AT 11874'. LINER GIH TIGHT. LINER STUCK AT 12803' (82' OFF BTM). ATTEMPTING TO SET 4-1/2 X 7" PACKER. DAILY:S48,711 CUM:$2,530,610 ETD:S2,533,486 EFC:$3,322,124 POH W/ RTTS PACKER 7"@11873' MW: 8.90BM ATTEMPTED TO SET 4-1/2" X 7" TIW PACKER. RELEASED F/ PACKER. POH W/ RUNNING TOOL AND WASH STRING. P/U 7" RTTS PACKER TO TEST LINER TOP. WIH TO 7" LINER TOP AT 9721'. COULD NOT GET INTO LINER TOP. POH. LEFT RTTS PACKER IN HOLE. WIH W/ OVERSHOT. LACTHED PACKER. POH W/ RTTS PACKER. DAILY:S46,005 CUM:$2,576,615 ETD:S2,576,615 EFC:$3,325,000 TEST LNR LAP 7"@11873' MW: 8.90BM POOH W/ RTTS. MU TRISTATE 6" MILL AND BHA. RIH TO 11,484'. CBU. POOH. LD MILL AND JARS. MU 7" RTTS. RIH TO 9830'. SET RTTS. PREP TO TEST LNR LAP. DAILY:S62,735 CUM:$2,639,350 ETD:S2,639,350 EFC:$3,325,000 POH L/D DP 7"@11873' MW: 8.9 OBM TESTED 7" LINER LAP TO 3000 PSI. BLED OFF TO 2800 PSI IN 30 MIN. TIH TO 11494' TESTED LINER AND LAP TO 3000 PSI. BLED OFF TO 2800 PSI IN 30 MIN. POH W/ PACKER. WIH W/ OVERSHOT SEAL ASSY. TESTED 4-1/2"X7" PACKER TO 3000 PSI. BLED OFF TO 200 PSI IN 30 MIN C&C OB MUD. POH AND L/D DP. DAILY:S59,640 CUM:$2,698,990 ETD:S2,698,990 EFC:$3,325,000 TEST TEST 7"@11873' MW: 8.90BM POOH. LDDP. RU AND RIH W/ 362 JTS OF 3-1/2" TBG. SPACE OUT AND LAND. VERIFY POSITION. TEST 3-1/2" X 7" X 9-5/8" ANN W/ 3000 PSI. LD LANDING JT. SET BPV. ND BOPE. NU FMC GEN IV TREE AND TEST SAME TO 5000 PSI. (CAMCO 'TRDP' SSSV @ 1997', TT @ 11524, 7" SS MECH SET PKR @ 11518' (SLOTTED LNR). DAILY:S219,336 CUM:$2,918,326 ETD:S2,918,326 EFC:$3,325,000 IWell no. The above is correct For for~tn preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B ]~1 daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final 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. I Accounting cost center code District / Stat~LK ARCO ALASKA TNC. County or Parish NORTH SLOPE Field ILease or Unit PRODHOE BAY I ADL: 28321 Auth. or W.O. no. ITitleDRILL · AS2882 & COMPLETE API: 50-029-21948 DS 18-25 IWell no. Operator A.R.Co. W.I. ARCO 21.0000 Spudded or W.O. begun Date SPUD 05/27/89 Date and depth as of 8:00 a.m. 06/30/89 ( 3 TD=12885 Complete record for each day reported NABORS 28E Iotat number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well IPrlor status if a W.O. our 14:00 RIG RELEASED 7"@11873' MW: 8.90BM TEST TREE. CLEAN PITS AND RIG DOWN. RIG RELEASED AT 10:30 PB:12885 SUPV:RO HRS, 06/29/89. DAILY:S44,245 CUM:$2,962,571 ETD:S2,962,571 EFC:$3,325,000 Old TD I New TD PB Depth Released rig J Date K nd of r g Classifications (oil, gas, etc.) Producing method Potential test data Type completion (single, dual, etc.) Off c a reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct seeF°r f:r: ;reparati .... P .... d .... M .... Drilling, Pages 86 and AR3B-459-3-C ~0[~J~JSSj~ber a,, da,,y we,, h,story, .... C ...... tlvely Pag .... /as they are prepared, ..... h well. I Dlvl'~on of AllanflcRIchfleldCompsny ARCO Alaska, In( Prudhoe B~,~ dngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 27, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Ac.5 · Re: DS 18-25 Permit No. 89-55 Dear Mr. Chatterton: Attached is a petition to seek a waiver to Conservation Order 165, Rule l lA which pertains to the requirement of obtaining initial production profiles on new wells. PBU DS 18-25 is a new "high angle" well and is completed with a 4-1/2" slotted liner from 11873-12769' MD (25'ss). However, this interval penetrates only Zone 1 within the Sadlerochit formation. Because this well penetrates only one zone and obtaining the production profile on this well will require using a coil tubing unit, ARCO requests a waiver of Conservation Order 165, Rule 11 A for PBU DS 18-25. If the GOR in this well increases in the future, then a CTU conveyed production profile will be executed for diagnostic purposes. If you have any questions pertaining to this waiver request, feel free to contact C. K. Hurst at (907) 263-4354. Very truly yours, D. F. Scheve DFS/MKM/O05 :ljm .RECEIVED Attachment cc: J. S. Dietz, BP Exploration Pl(DS18-25)Wl-1 iU'L 2 1:989 glaska 0il 8, Gas Cons. C0mmissloa Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B 6132~G Drill Site 18-25 ARCO Alaska, Inc. requests the following: Permission to waive the production profile requirement as prescribed in Conservation Order 165, Rule l la. The reason we request this waiver is that this well is currently open to flow within Zone 1 only of the Sadlerochit formation. Additionally this well is a high angle well with a 4-1/2" slotted liner and thus a coil tubing unit will be required to run a production profile in this well. At this time, no additional perforations within Zone 1 or other zones are planned for this well. However, if additional perforations are needed and are subsequently shot and/or the GOR begins to rapidly rise, a l~roduction profile will then be run in this well. MKM/004 RECEIVED ,Alaska Oil & 6as 6ons, Oommissioa Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1988 Mr. W. D. McGee Regional Environmental Supervisor Northern Regional Office AK Dept. of Environmental Conservation 1001 Noble Street, Suite 350 Fairbanks, AK 99701 SUBJECT: Annulus Injection - Notification of New Wells Prudhoe Bay/Lisburne 'F Es 'l-' GEOL ASS¥~ ~¥A-~FiLE TECH Dear Mr. McGee: ARCO Alaska, Inc. on behalf of the Prudhoe Bay Unit owners, requests approval to utilize additional annuluses for disposal of excess fluids from reserve pits and drilling operations. This material will consist primarily of drilling fluids, rig wash water and snow melt. Wells will be drilled and completed as per 1988 annual report (4-18-88). Approval is sought for the following wells: * 18-23 * 18-24 * 18-25 Attached are well-specific summary sheets which indicate the surface hole location, anticipated injection depths, and anticipated start/stop dates for each well. Thank you for the prompt approval of. this notification. If you have any questions on this submission, please contact me at 263-4678 Sincerely, Barbara K. Byrne Permit Coordinator Attachments cc: ~ Bill Ba~well, AOGCC, Anchorage RECEIVED DEC ' 7 !988 kt~sk~ 0il & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlantlcRIchfleldCompany DRILL SITE 18 WELL 25 SURFACE HOLE LOGATION: 871' FNL, 326' FEL SEC 24, T11 N, R15E,UM INJ. DEPTHS (TVD): BEGINNING: 3500 TVD ENDING: 6750 TVD VOLUME, BBLS: ESTIMATED: 11 0,000 APPPROVED: ANTICIPATED START: 02 Feb 89 ACTUAL START: ANTICIPATE STOP: 15 Oct 89 ACTUAL STOP: DATE NOTIFICATION DATE APPROVAL DATE CUMULATIVE VOLUME~ BBLS 05 Dec 88 05 Dec 88 COMMENTS: TEL IIIIIIIIII ARCO AIJ~SI~ ~NCo ~LL: DS-3.8-25 PRUDHOB BAY R,~G: NABO~:~ 28-E MWD DIRECTIONAL SURVEY CALCULATIONS TELECO OILFIELD SERVICES, INC. 6116 NIELSON WAY ANCHORAGE, ALASKA 99518 (907) 562-2646 Teleco Oilfield E 6116 Nielson Wa~ Anchorage, AK 99502 (907) 562-2646 ~s of Alaska Inc. June 21, 1989 JOB #702 ARCO ALASKA, INC. WELL: DS-18-25 PRUDHOE BAY RIG: NABORS 28-E Attached please find a copy of the .computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Field Operations Supervisor JGM/el Enclosures A ~11~? COMPANY TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 6/19/89 Company: Well: Location: Rig: ARCO ALASKA DS 18-25 PRUDHOE BAY NABORS 28-E TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 702TAK 0.0° 30.8° 30.8° 103.8° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ****************************************************************************************************** TIE-IN TO VERTICAL 924 0 0.0 103.8 924.01 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO MWD SURVEYS 1047 123 2.2 '106.4 1046.98 2.38 0.66S 2.29E 2.38 S 73.91E 1.78 1167 120 6.5 100.1 1166.61 11.46 2.50S ll.19E 11.46 S 77.39E 3.60 1289 122 9.0 106.0 1287.48 27.90 6.35S 27.17E 27.90 S 76.85E 2.16 1414 125 10.4 107.1 1410.69 48.94 12.37S 47.36E 48.95 S 75.37E 1.12 PAGE 1 ~ompan¥: ARCO ALASKA, WelL: DS 18-25, Location: PRUDHOE BAY, Riq: NABORS 28-E ~eas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ****************************************************************************************************** 1542 128 13.0 102.9 1536.02 74.89 18.98S 72.45E 74.90 S 75.32E 2.14 1667 125 14.3 101.1 1657.49 104.38 25.09S 101.32E 104.38 S 76.09E 1.09 1794 127 18.3 102.0 1779.36 139.99 32.27S 136.23E 140.00 S 76.68E 3.16 1921 127 20.2 103.2 1899.25 181.85 41.42S 177.08E 181.86 S 76.83E 1.53 2048 127 24.9 99.0 2016.52 230.45 50.62S 224.86E 230.49 S 77.31E 3.91 2176 128 26.6 102.9 2131.81 285.97 61.24S 279.42E 286.05 S 77.64E 1.87 2304 128 30.9 105.0 2244.01 347.51 76.16S 339,~13E 347.57 S 77.34E 3.45 ~432 128 32.5 101.5 2352.92 414.74 91.53S 404.58E 414.80 S 77.25E 1.91 ~659 227 34.6 102.2 2542.09 540.12 117.31S 527.35E 540.24 S 77.46E 0.94 3041 382 36.7 103.2 2852.48 762.70 166.30S 744.51E 762.86 S 77.41E 0.57 3453 412 37.1 101.8 3181.96 1010.00 219.82S 986.01E 1010.22 S 77.43E 0.23 ]790 337 36.7 102.9 3451.46 1212.28 263.09S 1183.66E 1212.55 S 77.47E 0.23 ~138 348 36.2 103.9 3731.38 1419.02 310.99S 1384.79E 1419.28 S 77.34E 0.22 %652 514 36.2 103.6 4146.16 1722.59 383.15S 1679.66E 1722.80 S 77.15E 0.03 PAGE 2 66'0 ~89'9£ S 85'586~ HI~'§LS~ S69'AI6 Ag' 5865 I8 ' ASEA § ' E0I E' 55 56 9898 89'0 H£9'9£ S 58'5565 H6A'9E85 S90'A06 EL'5565 99'09IL E'EOI 5'55 §6 5658 §6'0 H§9'9A S 6L'I885 H98'9A£5 S59'968 69'I885 I5'080A 8'IOI L'E5 gEI A6~8 98'0 ~I9'9A S 6§'5185 H98'60£5 S59'588 95'0 H9g'9L S I0'0gL5 H9E' L995 SIS'IA8 Eg'5185 09'gL69 E'00I g'55 ~II ELI8 96'69A5 50'I889 8'00I 9'95 ~5I 8§08 56'0 ~0g'9A S I0'9£95 H£9'ELg5 SE8'A§8 86'5L95 5L'OL£9 9'00I 8'95 gSE 956A 95'0 H95'9A S 55'9055 H£9"'£095 SI6'958 55'9095 £9'0999 8'001 9'L5 g95 659£ 55'0 HEE'9£ S I8'96E5 MI0'00E5 S89'98£ I8'96E5 g0'89E9 E'EOI 5'85 065 96~£ II'0 M8I'9£ S I9'5§05 ~E0'§965 S9£'6E£ I9'5§05 £A'I965 5'90I E'85 099 9069 99'0 ~9E'9A S E6'I8£E ~££'E0£E S99'099 E6'ISLE 9g'gI9g 0'g0I 0'85 699 9999 55'0 M99'9L S 9L'669E ~0I'059E E£'0 .gL8 ' 9£ S 0I'§8IE .g00 ' 8gig 8I'0 HOI't£ S tE'096I MIS'016I .00I/B~P B~p ~g ~g ~sg ~sg A~!aOAOS oIbUV oou~s!Q M/H S/N uo!~ooS 'do bs~ 6o0 ~ansoIO sa~u!paooo i~o!~a~A H-SE SHO~N :b!H 'A~ 3OHOQHd :uo!~eoo7 'gE-8I SO :IIaM 'k~ASh"/~ OOM~ :iu~omoo ~£'0 ~£~'9L ~ ~L'L~EG ~8'EOgG Sg6'gLg~ 9£'L~Eg O~'§EE8 8'80~ £'69 E6 88g0 OE'I EIE[: ' 9L S O0 "I:L~:~; EIO 9 ' '1: E'[[; Sc_;8' 99gI 66' OLg~; c_;9' EOE8 8'80'i: 9'69 g6 ~; 6'I: 0 90'E M09'9L S E8'98I~ ~69'6[0§ SL6'SIgI 08'98I~ IE'ILE8 8'80I L'OL 96 C010 08'S H89'9L S 99'960S ~0E'E§69 S§['I6II E9'960S 89'6EE8 t'90I t'Ot 90E t000 t6'I ~[9'9L S E6'806~ ~96'~L£9 S8L'9£II I8'8069 E6'ISI8 8'80I 6'8§ 98I I086 89'I ~SL'9L S I6'E~L9 ~96'9E99 S~0'LSOI IL'E~L9 99'I~08 £'90I L'~§ LSI §I96 E§'E H98'9L S E9'0099 H9I"0899' SLS'G~0I 9E'0099 ~I'£96L 9'901 ~'[§ LSI 8E96 0I'9 .gLS'9L S OL'9§~ .ggC ' 8[E9 S09' IIOI 99' ~99 6E'9gSL ~'g0I I'69 I0E I9E6 09'E H08'9L S L['EI[9 .W§E ' 8619 S80'§86 8I'EIE9 9£'989£ £'86 £'I9 0£I 0906 90'I MOL'9L S 6E'§0E9 Hg~'E609 S§£'L96 9I'~0E9 96'E§~L 9'00I 0'L£ 98 0L88 £6'I Ht9'9t S 96'£§I~ H90'gg09 S6§'£§6 E8'[~I9 00'989£ §'IOI 9'9£ 0II 98£8 9I'I M£9'9L S E§'6809 HI£'6£6E 6E'I H89'9L S L9'9£09 H£8'LE6E SL0'£96 E~'6809 E8'~6EL 9'90I g'g[ 56 9L98 S'00' 0E6 ~g'9g0~ 9~'SICt 6'~0I £'9E L6 I8§8 A~SaOAOS aIBU~ ~ouw~s~o M/~ S/N uo~aS 'do '~aA ~z~ I~UI qqbuo~ u~do~ BoG aansoID s~u~plooD I~o~a~A snlA ~sanoD sea~ ~-8E SHOH~N :6~H 'A~H HOHGDHd :uo~oo~ 'SE-SI SG :II~M 'k~ASh"/~ ODH~ :Au~dmoD I~'0 H6E'SL S ~8'6ES9 ~ES'SI[9 S80'8S9I [6'8ES9 E6'L998 E'60I I'LL 86 6E'I ~§£'S£ S I9'~99 ~E§'SEE9 S66'9E9I ES'Z~99 96'§~98 8'80I 0'££ 06 ES'0 .gI ~ ' S/- S 86'99~9 .gE~' E~I9 SA£' 86§I 0['9~g9 LS'9E98 E'60I I'8£ 96 £0'I ~6~'~L S 0£'[§E9 ~£L'~§09 S[E'L9SI ~L'ESE9 0I'£098 ~'60I S'8£ ~6 6EEI 06'E ~9S'SL S 6Z'I919 ~££'996§ S~£'9~§I S6'0919 £I'68S8 9'60I S'6L E6 ~[II E~'E ~E9'SL S 0S'IL09 ~6~'I88S Sg~'LOSI 9I'I£09 E8'0£S8 8'LOI S'L£ ~6 [~0I' II'E ~69'~£ S 6E'086~ ~99"96£§ S£~'SL~I 00'086~ EI'6~8 ~'60I 8'~£ ~6 6~60' 8£'I H9£'§£ S 96'888S HII'80£~ SOE'8~gI ~L'888~ IE'~E§8 £'60I 8'IL ~6 ~§80' ~'I M~8'SL S ~'66L§ MIE'gE9S S£~'8I~I IE'66£S L6'96~8 ['60I §'g£ 96 09£0' ~['I ~E6'SL S L~'80£g ~86'9[§§ S0£'88£I 8['80L§ 90'L9~8 8'801 E'I£ §0I ~990' 86'I .wi0 ' 9£ S ~8'609~ .g§9' [~§ SgI'9~CI 6L' 609~ 6I'Eg~8 9'60I 0'0£ ~8 6§§0' 00'0 ~80'9L S 9S'I[SS ~9I'69~S EL'0 ~9I'9L S E£'[99S SL~'0[~I E~'I[~g 8g'E0~8 §'801 /-'89 §6 §t~0' S~' E0[I I[' ~gg £0' 8918 §' 80I t' 89 ~6 08[0' A~a~nsS ~IbU~ sou~s~ M/~ S/N uoT~o~S 'do '~aSA Tz~ IOUI q~bu~ q~d~G H-SE SHO~N :b~H 'A~ HOHGflHd :uo~g~oo~ 'gE-8I SG :IIOM 'k~IS¥/~ ODHV :Au~dmoo Company: A..RCO ALASKA, Well: DS 18-25, Location: PRUDHOE BAy, Riq: NABORS 28-E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 1605 92 79.0 108.8 8686.96 6618.55 1687.38S '~ 6400.92E 6619.60 S 75.23E 2.12 1697 92 81.0 108.8 8702.92 6708.80 1716.58S 6486.69E .6709.98 S 75.18E 2.17 1777 80 86.0 106.7. 8711.96 6788.07 1740.80S 6562.37E 6789.33 S 75.14E 6.77 1869 92 92.0 105.0 8713.55 6879.95 1765.91S 6650.81E 6881.26 S 75.13E 6.78 ~965 96 91.5 105.0 8710.61 6975.88 1790.77S 6743.49E 6977.21 S 75.13E 0.53 ~059 94 90.4 105.3 8709.05 7069.83 1815.34S 6834.21E 7071.20 S 75.12E 1.21 ~153 94 89.5 105.7 8709.13 7163.79 1840.46S 6924,~79E 7165.19 S 75.12E 1.05 ~246 93 88.2 105.7 8711.00 7256.72 1865.62S 7014.30E 7258.16 S 75.11E 1.40 ~334 88 87.5 105.3' 8714.30 7344.61 1889.12S 7099.04E 7346.10 S 75.10E 0.92 ~434 100 87.4 106.0 8718.75 7444.46 1916.07S 7195.23E 7445.99 S 75.09E 0.72 ~530 96 86.7 106.7 8723.69 7540.23 1943.07S 7287.23E 7541.83 S 75.07E 1.02 ~624 94 86.7 106.0 8729.10 7633.98 1969.50S 7377.27E 7635.64 S 75.05E 0.73 ~717 93 86.1 106.4 8734.94 7726.71 1995.40S 7466.40E 7728.44 S 75.04E 0.77 PAGE 6 Company: ARCO ALASKA, Well:. DS 18-25, Location: PRUDHOE BAY, Riq: NABORS 28-E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi . Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0' 2811 94 85.8 106.0 8741.58 7820.39 2021.57S ~ 7556.44E 7822.18 S 75.02E 0.52 PROJECTED T.D. 2866 55 85.8 106.0 8745.61 7875.19 2036.69S 7609.16E 7877.02 S 75.02E 0.00 PAGE 7 TE-,.LCO Oi 11: ie 1~ PLAN VIEW Sepvic~.o 1600 ~.600 ARCO ALASKA OS 18-25 PRUDHOE BAY NABORS 28-E JOB# 702TAK/O0 SCALE: ! inc~ = 1600 3200 feet :1600 3200 4800 r..n 0 C 6400 8OOO 9600 11200 12800 48 6400 8OO0 96OO 0 0 2000 4000 ~6000 LtJ c38000 >10000 12000 14000 16000 18000 TE CO OilfielO Ser¥ice~ VERTICAL PROdECTION 2000 4000 6000 8000 10000 12000 9~4 ' .0! deg ~~ ~7~.4~4 ~ ~0 · 4 (~g ARCO ~a~ · ~o.~ ,.g DS 18-25 43a ' 32.5 aeg PRUOHOE BAY . NABORS 28-E 4~ 3S.7 ~eg JOB~ 702TAK/O0 90 ' 36.7 aeg SCALE: ~ inch = 200O feet 449 ' 34.5 ~eg 95 ' 36.01 Oeg . 904 ' 38. ~ deg , ' 63~ ' 37.4 Geg ~ ~ ~817~ ' 33.5 deg VERTICAL SECTION (ft) JOB #702 ARCO ~KA, INC. WELL: DS-18-25 PRUDHOE BAY RIG: NABORS 28-E MWD DIRECTIONAL SURVEY CALCULATIONS TELECO OILFIELD SERVICES, INC. 6116 NIELSON WAY ANCHORAGE, ALASKA 99518 (907) 562-2646 TELECO1 Te~eco Oilfieid S~'-'~'es of Alaska Inc. 61 16 Nielson VVa. Anchorage, AK 99502 (907) 562-2646 June 21, 1989 JOB #702 ARCO ALASKA, INC. WELL: DS-18-25 PRUDHOE BAY RIG ~ NABORS 28-E Attached please find a copy of the ,computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G. M~p s~~ Field Operations Supervisor JGM/el Enclosures A ~,~JlJ'l' COMPANY TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 6/19/89 Company: ARCO ALASKA Well: DS 18-25 Location: PRUDHOE BAY Rig: NABORS 28-E TELECO Job # 702TAK Grid Correction: 0.0° Magnetic Declination: 30.8° Total grid correction: 30.8° Proposed Direction: 103.8° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' TIE-IN TO VERTICAL 924 0 0.0 103.8 924.01 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO MWD SURVEYS 1047 123 2.2 '106.4 1046.98 2.38 0.66S 2.29E 2.38 S 73.91E 1.78 1167 120 6.5 100.1 1166.61 11.46 2.50S ll.19E 11.46 S 77.39E 3.60 1289 122 9.0 106.0 1287.48 27.90 6.35S 27.17E 27.90 S 76.85E 2.16 1414 125 10.4 107.1 1410.69 48.94 12.37S 47.36E 48.95 S 75.37E 1.12 PAGE 1 Company: ARCO ALASKA, Well: DS 18-25, Location: PRUDHOE BAY, Rig: NABORS 28-E Meas Course True vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 1542 128 13.0 102.9 1536.02 74.89 18.98S 72.45E 74.90 S 75.32E 2.14 1667 125 14.3 101.1 1657.49 104.38 25.09S 101.32E 104.38 S 76.09E 1.09 1794 127 18.3 102.0 1779.36 139.99 32.27S 136.23E 140.00 S 76.68E 3.16 1921 127 20.2 103.2 1899.25 181.85 41.42S 177.08E 181.86 S 76.83E 1.53 2048 127 24.9 99.0 2016.52 230.45 50.62S 224.86E 230.49 S 77.31E 3.91 2176 128 26.6 102.9 2131.81 285.97 61.24S 279.42E 286.05 S 77.64E 1.87 2304 128 30.9 105.0 2244.01 347.51 76.16S 339.13E 347.57 S 77.34E 3.45 2432 128 32.5 101.5 2352.92 414.74 91.53S 404.58E 414.80 S 77.25E 1.91 2659 227 34.6 102.2 2542.09 540.12 117.31S 527.35E 540.24 S 77.46E 0.94 3041 382 36.7 103.2 2852.48 762.70 166.30S 744.51E 762.86 S 77.41E 0.57 3453 412 37.1 101.8 3181.96 1010.00 219.82S 986.01E 1010.22 S 77.43E 0.23 3790 337 36.7 102.9 3451.46 1212.28 263.09S 1183.66E 1212.55 S 77.47E 0.23 ~138 348 36.2 103.9 3731.38 1419.02 310.99S 1384.79E 1419.28 S 77.34E 0.22 3652 514 36.2 103.6 4146.16 1722.59 383.15S 1679.66E 1722.80 S 77.15E 0.03 PAGE 2 Company: ~RCO ALASKA, Well: DS 18-25, Location: PRUDHOE BAY, Riq: NABORS 28-E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 5057 405 35.6 102.9 4474.23 1960.06 437.59S 1910.81E 1960.27 S 77.10E 0.18 5449 392 34.5 107.4 4795.19 2184.98 496.27S 2128.00E 2185.10 S 76.87E 0.72 5995 546 36.0 105.7 5241.04 2499.73 585.95S 2430.10E 2499.74 S 76.44E 0.33 6464 469 38.0 105.0 5615.54 2781.92 660.66S 2702.33E 2781.92 S 76.26E 0.44 6904 440 38.2 104.3 5961.77 3053.41 729.36S 2965.02E 3053.41 S 76.18E 0.11 7294 390 38.3 102.2 6268.05 3294.81 784.68S 3200.01E 3294.81 S 76.22E 0.33 7639 345 37.4 100.8 6540.47 3506.33 826.91S 3407.43E 3506.33 S 76.36E 0.36 7924 285 34.8 100.4 6770.73 3673.98 857.82S 3572.47E 3674.01 S 76.50E 0.92 8058 134 34.4 100.8 6881.03 3749.96 871.81S 3647.26E 3750.01 S 76.56E 0.34 8172 114 33.5 100.2 6975.60 3813.52 883.42S 3709.86E 3813.59 S 76.61E 0.84 8297 125 32.7 101.8 7080.31 3881.69 896.43S 3776.86E 3881.79 S 76.65E 0.95 8392 95 32.3 102.2 7160.44 3932.72 907.04S 3826.79E 3932.82 S 76.67E 0.48 8484 92 33.2 102.5 7237.81 3982.47 917.69S 3875.41E 3982.58 S 76.68E 0.99 PAGE 3 0g'I 3~'9£ S 00'I£g§ 30~'IEIG S§8'9~EI 66'0£E§ G~'E0£8 8'80I 9'69 ~6 §610 90'g .q0~ ' 9£ S g8'~8Ig .q6~ ' 6[0g S£6' 8IgI 08'~8I~ IE'I£E8 8'80I £'0£ 96 £010 08'§ 38~'9£ S 9~'~60§ 30E'£§6~ S§£'I6II g~'~60§ 8~'6~E8 £'90I £'0£ 90g £000 £6'I 3g9'9£ S E6'806~ 396'§££~ S8£'~II I8'806~ E6'I§I8 8'80I 6'8§ 98I I086 8~'I 38L'9L S I6'EGL9 3~6'9E9~ SC0'£80I IL'g~L$ $~'I~08 £'90I L'~§ £8I §I96 g~'g 398'9A S E9'009~ 39I'08~ S£8'§~0I 9C'009~ §I'C~6£ 9'~0I §'C§ £8I 8E~6 0I'~ 3£8'9£ S 0£'~ 3gg'SgC~ S09'IIOI ~'~§~ 6E'9ES£ §'g0I I'6~ I0g I~g6 09'g .q08 ' 9£ S L£'EI£~ .q§g ' 86I~ S80'§86 8I'gI£~ ~£'~89£ £'86 g'I~ 0LI 0~06 ~0'I 30£'9£ S 6g'§0g~ 3E§'E60~ S§['£96 9I'§0g~ ~6'E§§£ ~'00I 0'££ 98 0£88 £6'I 3£9'9L S ~6'[~I~ 390'E~0~ S6~'£§6 ~8'[§I~ 00'~8~£ §'IOI ~'9£ 0II 9I'I 3£9'9L S £§'680~ 3I£'6£6C S£0'£~6 ~'680~ ~8'~6~L 9'~0I ~'~£ [6 ~£98 6['I 389'9L S A~'9C0~ 3£8'AE6[ S00'0g6 §C'9[0~ 9~'8I££ 6'COI g'~g L6 I8§8 .00I/fisP 6~p ~9~ ~sJ ~J ~ ~ 6~p fi~p ~a~J ~ ~!aaAoS ~IbU~ ~ou~s!G M/3 S/N uo!~oaS 'do '~aaA Iz~ IOUI g~bua~ g~dao ba~ ~oo a~nsoIO sag~u~paooo I~O~IaA an~ as~noo s~a~ 3-8g SHOS~N :b!H *A~8 MOHGQMd :uo!g~oo~ '§E-8I SO :IIaM 'kQIS%f/~ ODM¥ :AU~dmoo Company: ARCO ALASKA, Well: DS 18-25, Location: PRUQHQE....B%Y, Riq: NABORS 28-E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' .0380 92 68.7 108.5 8368.07 5443.31 1302.38S 5285.22E 5443.32 S 76.16E 0.72 .0475 95 68.7 108.5 8402.58 5531.52 1330.47S 5369.16E 5531.54 S 76.08E 0.00 .0559 84 70.0 109.6 8432.19 5609.79 1356.13S 5443.45E 5609.84 S 76.01E 1.98 .0664 105 71.2 108.8 8467.06 5708.38 1388.70S 5536.98E 5708.47 S 75.92E 1.34 0760 96 72.5 109.3 8496.97 5799.21 1418.47S 5623.21E 5799.35 S 75.84E 1.44 0854 94 73.8 109.3 8524.21 5888.75 1448.20S 5708.11E 5888.96 S 75.76E 1.38 0949 95 75.8 109.2 8549.12 5980.00 1478.43S 5794.66E 5980.29 S 75.69E 2.11 1043 94 77.5 107.8 8570.82 6071.14 1507.44S 5881.39E 6071.50 S 75.62E 2.32 1135 92 79.5 109.6 8589.17 6160.95 1536.35S 5966.77E 6161.39 S 75.56E 2.90 1229 94 78.5 109.5 8607.10 6252.75 1567.23S 6053.73E 6253.30 S 75.49E 1.07· 1325 96 78.1 109.2 8626.57 6346.30 1598.37S 6142.42E 6346.98 S 75.41E 0.52 1415 90 77.0 108.8 8645.96 6433.82 1626.99S 6225.52E 6434.61 S 75.35E 1.29 1513 98 77.1 109.2 8667.92 6528.93 1658.08S 6315.82E 6529.84 S 75.29E 0.41 PAGE 5 9 aDYd LL'O a~O'§L S ~'SELL ~0~'99~£ S0~'~66I I£'9~£L ~6'~£L8 ~'90I I'98 £6 LILE CL'O a§O'§L S ~9'§[9L MLE'LLCL S0§'696I 86'££9L 0I'6E£8 0'90I L'98 ~6 gO'I ~LO'§L S gS'I~fiL M£E'LSEL SLO'[~6I £E'O~G£ 69'gEL8 L'90I L'98 96 O£GE EL'O a60'GL S 66'G~gL a£g'G6IL SLO'916I 9~'~L fiL'8I£8 0'90I ~'L8 OOI ~£~g E6'0 ~OI'G£ S 0I'9~g£ M~O'660L Sgi'688I I9'~9£L O['~IL8 ['~OI G'L8 88 ~££g O~'I . aII'GL S 9I'SGEL ~0['~I0£ SE9'G98I EL'9GEL O0'IIL8 £'GOI E'88 £6 9~gg' GO'I aEI'GL S 6I'G9IL a6L'~E69 S9~'0~8I 6L'C9IL CI'60L8 £'GOI ~'68 ~6 £GIE' Ig'I aEI'GL S OE'ILOL aIg'~g89 S~['§ISI £8'690L GO'60L8 ['GOI ~'06 ~6 6GOE' g§'O MCI'GL S Ig'LL69 ~6~'£~£9 SLL'O6LI 88'§L69 I9'OIL8 O'§OI G I6 96 G96I' 8L'9 a£I'GL S 9E'I889 aI8'0~99 SI6'G9LI G6'6L89 ~G'£IL8 O'§OI O'E6 g6 698I' AL'9 a~I'G£ S £C'68L9 a£g'E9G9 S08'O~LI £0'88£9 96'II£8 £'90I 0'98 08 LI'E .qSI ' GL S 86'60L9 .q69 ' 98~9 SSG'9ILI 08'80L9 E6'EOL8 8'80I 0'I8 g6 L69I~ EI'E aGE'GL S 09'6199 ~E6'00~9 S8£'L89I §G'8199 96'9898 8'80I 0'6L g6 §09Il .OOI/b~P b~p ~s~ ~a~ ~8~g ~ ~ hap 5~p $~g K~a~A~S ~IbU¥ ~aU~S~ M/a S/N UoT~D~S 'dQ '~a~A ~z¥ IOUI q~Su~ q~d~Q a-SE SMO~N :6IH"~A~M aOHGflHd :uoIseoo~ 'fig-BI Sa :II~M '%IMS~/~ ODM¥ :aU~dmoD 00'0 agO'§L S EO'LLSL ~9I'609L S69'9[0E 6I'§LSL I9'~L8 0'90I 8'§8 fig 998E 'Q'~ Qa~Oa£OH8 g§'0 .~g0' ~£ S 8I' ggSL .~ ' 9§§L SL§'IEOE 6g'0ES£ 8§'I~L8 0'90I 8'~8 ~6 IISg' ~qTa~S ~IbU~ ~ou~sTQ M/a S/N UoT~DsS 'dQ '~eA Tz~ IOUI q~Su~ q~d~a ba~ boq sansoIO s~uipaooD i~oT~a~A ~na~ asanoD ~-8~ S~08~N :bTN' 'A~8 ~OHOflHd :uoT~ao~ '~E-8I SO :II~M '%DiSWig OD~¥ :AuudmoD TEL _SO 0 ~ 11: ~ e 1 d PLAN V.I Serv~ce~ 1600 ARCO ALASKA DS 18-25 PRUDHOE BAY NABORS 28-E JOB# 702TAK/O0 SCALE: 1 inch = 1600 feet 1600 3200 4800 6400 80OO 96OO 200 12800 1600 3200 48 6400 SO00 9600 (~:~) NOI/3~S 3VOII~A O00B1; Oep ;0' . PE6 00091; 000~1; O00gl; 0000'~ ITl 0009o ITl ooo9~ 00017 O00g 0008~ 0000~ 0008 0009 O00P 0008 NOIIOBPOUd ]VOIIU3A F:'~O. BOX t 0(.)36(.) ' OR ' ' 99~ ANCH.. AGE~ AI..A~KA t 0 D A T E: '7 - t 3; - 8 9 R ti!: F:'I.=.: R E: N C E: ~ R C 0 M ~ G N E T I C '['~ P E ( 3~ ) I,,j I 'i" H L. 15"T' ]: N G ( ,S' ) i ~1""2:~5 6/4"-i 8/:!ii:9 !'"iidD ..,JOB~"?('):;~ RLJN;~' ':?'-~.;.:'.i F:' I... E ;::~ 5' E 5' I (:; N A N D R E T LJ R N 'l'l"ilii: A'i" T A C t"! E: ][) C 0 F' Y A 5' R E C E I F"I" 0 F' D ~-f' A, i'li"l_ii:JC;O CENTRAL F'ILE,"~ (CH) CHEVRON D & M I'ANMA,S' BROWN (OH) EXXON MARA"I'HON MOBIL '"' F' H ]: L L I P F'B WELL FILES R & D ~ BF'X ~;"I'A"I"E OF AL. ASK~ t' E. XA ~.LJ ~5:C0 ALA2K~, iiqC. f:' ,. rj. B 0 X ~i ,3 (') '35 6 ;3 ANCH?iF,'AGE, AL~SK ~ 995 ~ ~'} DA]"E · 7-~ (.)-89 REFERENCE' ARCO CA,~ED HOI_E FINALS' 2- i 6 6-30-E~9 COLLAF~/'F:'ERF F:.LJN :5-2.'3 6..-28-89 Di[FF ]' ENF' RUM · '.5-:23 6-28-89 CiqL-GAMHA RUN 4- t 6.-"'~°-~:':~ Tli-'HF' 2URVEY F;tUN · .;-i2 6-3(~-89 bIFF '1" E:i~ F' RUN 4- 'J,~'" 6-3.:.)-!]9 CNL-GAMHA. J-;'UN, · 'J : 4-t 5 6-28-89 INJI~:C'['ION F'ROFILE F;'.UN'i, 4-3(') 6-3(.)-89 DIFF 'i"EMP RUN 'i 4-S(') 6-3(.)-89 CNL"'GAMMA t'~'.~JN i , 4-3i 6-28-89 D'.[FF TEMP RUN ~, 4-:3J 6-':28-89 CNL.-GAMHA RUN 'i, I i - 'J 5- 'i 8"-89 '1"ND RUN i J"~7 7-J-89 D 1-' FF TFMF' RUN t I-i '? '?-i-8'? CNL-GAHHA F','t. JN · "~' 2 -89 "~ ' , t 8-,..._:. 6- :5 C£ ] ('['LC) RUN Pt_EASE ;~IGN AND RETURN THE ATTACHED (.,dF f ALi' RECEIPT OF DATA HAVE A NICE DAY! 5" 5~ 5" 5" 5" 5" A'J'i_A2 A i'LA2 A CI T i £ Al'LA3" 0 i" :[ Z A'/'LA3' Aq'L. ALI' A'[LAZ HL~ ATLAS ATLAS ZCH D I S'I"R IBUT]:ON CENTRAL FILES CHEVRON D &.M EXTENSION' EXPLORATION EXXON- MARATHON MOBIL' F'HILLIF'5~ PB WELL F'II._E,S' R & D BF'X ;,.,"FATE OF' ALAS'KA TEXACO ARC() ALA3~KA, INC. F'~ O. BOX i'~(')3;6g~ ANCHORAGE, ALA~'KA ._ 995 ~ 6~ DATE' 7-i ;'.]-89 REFFRENCE' ARCO CASED HOLE FINALS' 2-i 6 6-30-89 COLLAR/F'ERF · -..o 6'-28-89 D l Fi-- l" E~F' '~-2S 6-28-89 CNL-GAMMA - ,,_ , ~ tJRVE 4 t 6--78-8':~ I"EHF' " " -Y 4-i 2 6--3(~-89 DIFF ...... rEMF' 4-i '2 6-,~(')- 89 CNL-GAMMA 4-i~5 6-28-89 I NJF::C'f'I ON PROFILE 4'-,'36' 8-3¢-89 DIFF TEMP 4-S¢, 6-3e-89 CNL-GAMMA 4-Ji 6-28-89 DIFF '¥EMF' 4-5t 6-28-89 CNL-GAMMA t i -t 5-i 8"-89 TMD ii-i7 7-t-89 DIFF TEMF' t t - ~ 7 '7- t -8'? CNI_-GAMMA t 8-25 6-2:5-89 CBT ('['LC) [-;'. U N R U N RUN RUN RUN RUN RUN RUN RUN RUN RUN F;:UN RUN RUN RUN i., i, i., t, i, i., t., i, i: i, i., t., i., i, PI_EASE ~IGN AND RETURN THE ATTACHED COPY AS' RECEIPT OF DATA 5" 5" 5" 5" 5" --, 5" 5" '2" &5" 5" 5" A 'i't_ A ~' A i'l_A:? A'f'LA$ 0 "1" '.r. A'f'LAS' R'i'LA:~ Oi" I 5' ~ f'I_AZ Ai-I_AZ AI't_AZ ATLA~· Al'LAS~ 2'CH RECEIVED BY , ____ £"A LL Y HOFFECKER APPROVED _ A'i"O-~ 529 TRANS'¢ 89 ,-,.;..]. ' ..,':' DIS'TRIBUTION CENTRAL FILE~ CHEVRON D&.M EXTENSION EXPLORATION EXXON MARATHON MOBIL'- , ~ F'HILLIF'$ PB WELL FILES' R & D -,,- BF'X ~ ~'I'ATE OF ALAS'I<A ~ TEXACO ANCHORAGE, AL.A~KA 995'i (~' R E F El R E N C E ' A R C'. 0 0 P E N H 0 L L.:-. F I N A L,~' F:' I... E A 2 E ,~' I g- i',t iq N ][) I:;..' E "l"(.J I:;.'. N TH E A 'i' T A C i"1E D C: O P Y A ,:'.." l:([-'il C: E I I::' T CI F' D A 'T'A ,. I.'lAVlii: A NICE DAY! A T 0- 'i .:'5 2 5.' $, t~gm~'~ 3" ' .... 2'." .2 D I $ T R I B U T I O N :~ C E N T R A L. F:' I I_ E S. "" L, HE. VRON ~ D & M ""-..E X '1" E N ,g I 0 N E X P L.. 0 R A T I O N ~ EXXON :If. MARATHON ~ Pi 0 B I L '"' F:' H i I_ L I F:' PB WELL FIL. E.~' · ~.~R & D -"- BF'X ~ .S'TATE OF ALA~,'I<A '" TEXACO NL 2F:'E N! .... ~-:,'F'E ,L , X,..q. Ff ,.?'"]"11 ..-J q'l L~ ~q $ ct I ] "11 H ,::I ,.~. N 01 .L Fl 81 ~.L $ I (I ANCHORA(.;E, AI...AL~'KA 995~ '~' RtE F:' E R E N C E · A F;: C.': 0 H A C; N E'T' I C T A P E ( ,,? ) W I 'i"H L.. I E:'T' I N (;. ( ,!}' ) F:' I... E A,~:; Ii{: ,?;' I (i~ N A N D R E i' LJ F;,' N T I"I Iii: A "l" 'T' A C I-'i E D C: (])J::J ]ll A 5' R E C E I P T 0 F' .{) A TA, D I ~i: '¥' R I B U '¥' I 0 N CENTRAL. F'II_IE$ (CH) CHEVRON D & I'i TAi"!MA,.? BI:;.:C'WN ( [)1'-! ) E X X 0 N HARA'T'HON MOBIL I::'H I L I_ I I::' 5' I::'B WEL. L FII...IE:;.k.' R & g ~'"' BF'X ,':Z '1" F.'~ i" E OF TEXACO 'i :': ..... "2; 'i 'i .... 2 i .... iii 9 i"'i W D '(') :1: F;:iii: ~"" 'i" ]: 0 N A i... ,~i: (.iR V iii: Y .1 t. i t..,-,-,~:,; ,:::, :~ :::'~ .... 2:5 6 .... 'i 9 .... :iii:".i~ i:.iW.O L:, .[ I:;.: Iii: C 'i" ]: 0 N A L ,'~.:,' U i:;..' V E ",,"' ...J 0 B :~ 'i;' ,::-) 7 I:;:Iii:CE:I:VED BY A P P R O v E D (.j~. i"R. AN$~- 892'7t D :1: :.:.,' i" F;..' I B U "l' ]: 0 N C E: N '1" i-i'. A L F: I I... E,~.~ (": I.-I Ii.:. V F;.'. 0 N D & M 11-' Iii: × '1- E N ,.? :t: 0 N Iii. × F:' I... 0 R A 'i" I 0 N I:i: X X 0 N H A F;.'. A 'i" H 0 N h'i 0 B :1: L F:'H I L L I F:' -,- P B W I.::: t... t... F' ]: I... E~,~-' ( 2 C 0 F:' I E ,., ~'' ) R & D · ..~" BF'X · "' ,S'TATE OF AL. ASKA T iii: X A C 0 F;.'. E F:' E I';: Ii:.' N C FZ ' ~'./NC'O 0 I::'E N I"t0 L. E F'.L' Nt:~l... Z' 6/4 .... 674 .... 6/4 .... 6/"4 .... ~878~ ~D: F:' I... ii!; A,~:'E ,.? .'t; ~;~ N ~:~ N D R E T U R N F;.'.E CE ;I; VF..D 'E~ Y RLJ'N;~' ? .... 'I9, 2' 'FVD ...... F;,'IJN '~.~ 7-'I 9 ,::', ..... ' ' .." 'i"VD Fi: iii.',~;' ;t; ,S' '}" 'J'. V l- T' Y (; ~ M M ~ + D 'j; 1:;.~ E C T i' 0 N ~.'~ L F~'IJN,? '? .... f 9, :2~ ~,q-) . .. !:;,'E,Z~?I,.?T.'I.' VI TY (;r::'Wtt'iA + 'D ':I; RE'r: T I:;,'!..IN,~:' '?-~ 9, 5" /,.~..'.., ...... THE' ~':tT'T'RCHED COPy ,q2 RECEI'F,T OF' DATA, -"I,j o r~ o. APPROVED .~._~. Afl ~::i-~"f,R l' B L J T J: 0 N ~ . '~ CEN r'RAL · ,. C: H E V R 0 N EX'1"EN,~;' ['ON EXF'L. ORA EXXON NARA'1'HON '"' F:' H I' L. L ;[ ::,-, F~. F:'B WE'L.L F'IL.E.',:~" · ~ R & D " 'FL".'. L. E C 0 7/..'.:.' L.. h' C C) TEL..E;CO 1"EL. E'C,'O May 19, 1989 Telecopy: (907)276-7542 ~.ir. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Almhorage, Alaska 99510-0360 Re: ?rudhoe Bay Unit DS 18-25 ~RICO Alaska, Inc. Permit No. 89-55 Sur. Loc. 871'FNL, 326'F%~L, Sec. 19, TilN, R15E, UM. Btmhole Loc. 2731'FNL, 2316'FEL, Sec. 20, TllN, R15E, U~-~. Dear Mr. Oostermeyar~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Conmlission 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. Very truly ~9.urs, Chairman o.f Alaska 0~1 and Gas Conservation BY ORDER OF T}IE COi~iISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. , ,.--., STATE OF ALASKA ~-'--, ALASK,~ IL AND GAS CONSERVATION L ,VlMISSION PERMIT TO DRILL 2O AAC 25.O05 i la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' , PAD 16'GL feet Prudhoe Bay Field 3. Ad;dress 6. Property Designation Prudhoe Bay 0i 1 Pool P.0. Box 100360, Anchorage, AK 99510-0360 ADL 28321 ~ TD 4. Location Of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 871'FNL, 326'FWL, Sec.19, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval (~ 8722'TVD) 8. Well nurpber Number 2600'FNL, 2850'FEL, Sec.20, T11N, R15E, UM DS 18-25 U-630610 At total depth 9. Approximate spud date Amount 2731'FNL, 2316'FEL, Sec.20, T11N, R15E, UM 05/26/89 $200,000 ,, "1~. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 18-14 55' 12792'MD 2316' @ TD feet ¢. 1380 'TVD/1382 'MD feet 2560 8748'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) 35 0/87 Kickoff deptH000'/710~,'TVD Maximum h'o~ 1~5o 0 e ang Maximum surface 2 9 7 5 psig At total depth (TVD) 3 8 5 0 psig 18. Casing program 'Settin~l Depth size Specifications Top Bottom Quantity of cement ........ Hole Casing Weight Grade ~ Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# '1-40 Weld 80' 30' 30' 110' 110' 2000# Poleset 17-1/2" !13-3/8" 68# k-55 'BTC 20' 30' 30' 50' 50' " 2000 sx c5 Ill & 68 -UU BIC ~5~U8' .50' .50 ' 155t5' 5500' bUU sx L;5 G i2-i/,+" '~-5/8;~ ' 4/~ L'-80 r~-'C/MOO ~uu/~+' -~u~ .~u~ i )i04: 8278; .~Ou sx ~.~ass b 6-i/2:: 7"'" 2'3¢ L-CO BTC i538: "804: 60'3: i 742: 66'35: 350 ~x Cld~ 0 8-1/2" 4-i/2:: 11.5#b-~8( ' FL4S 1250' 11542' 8693' 12792' 8748' Slotted liner 19. lO[al aeptn: measurea feet I~lUgS (measureo) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°r~:t°r RECEIVEE Intermediate MAY 1 5 ]98.0 Production Liner Alaska Oil & Gas Con$~.G~ depth: measured . ,. ~ch0rage:.?,~ Perforation true vertical 20. Attachments Filing fee [] Property plat ~ BOP Sketch [] Diverter Sketch ~' Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby..~.Rcertify t~going is~~_~j true and correct to the best of my knowledge Signed ,-,. Title Regional Drilling Engineer Date Commission Use Only ~.,~I,(JLH) PD3/078 Number I API number I Approval date I Soo cover letter Permit2?- ,~" ~" 50-- ~...?_ ,Z./~ ~'~' , 05/].9/89 for other requirements Conditions of approval Samples required [] Yes X No Mud Icg recrdi,r'eo' L-~'Yes ,,,li~No Hydrocjcn sulfide mea~ure~ ~ Ye~ ~i~"No Directional survey required /I;~i~Yes [] No Required working pressure for~C:~E G2M;~ 3M; /J~Ef SM; [] 10M; [] 15M Other:~~/~/~ -'~'~ "'~~,'1//~'~ ~ ~ J'- -- by order of Approvedby ~,~ ~,. ~~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 . J' Submit in' cate PBU DS 18-25 OPERATIONS SUMMARY 1. MIRU drilling rig. NU diverter and function test same. . Spud well and drill a vertical 17-1/2" hole to 1000'MD/TVD. Kickoff and build angle at 2.5°/100' at S76° 15'E to EOC at 2334' TVD / 2425' MD. Continue drilling the 17- 1/2" hole maintaining angle and direction to 3500' TVD / 3858' MD. 3. Set 13-3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test to 5000 psi. 4. Pick up 12-1/4" bit and BHA. Drill 10' of new hole and perform leakoff test. Drill 12- 1/4" hole maintaining angle and direction to 7108' TVD / 8297' MD (KOP #2). Build angle at 1.5°/100' at S 76° 15'E to 8278 TVD / 10104' MD (10' TVD above the top of the Sadlerochi0. Angle at this point should approximately 62.5°. 5. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. 6. Drill 10' of new 8-1/2" hole and perform formation integrity test to 12.5 ppg EMW. Switch to oil base mud, then drill 8-1/2" hole continuing to build at 1.5-°/100', to 8698' TVD / 11,742' MD (EOC #2). The angle should be 87.5-o at the end of the second curve. Maintain angle and direction until TD at 8748' TVD, 12,792' MD. Note: While drilling, the Sadlerochit will be logged with MWD tools as per program. 7. RIH and spot polymer/salt pill at the 7" liner point at 8698' TVD / 11,742' MD. Note: 7" liner point may change due to the depth of the GOC. 8. Run and set the 7" liner with an external casing packer above the 7" shoe. 9. Clean out the liner and pressure test to 3000 psi for 30 minutes. RIH with drill pipe conveyed cement evaluation logs. 10. Clean out the open hole to TD. 11. Run and set the packer and 4-1/2" slotted liner across the open hole. 12. Run 3-1/2" tubing with a GLMs at approximately 3600' TVD and 6050' TVD. Pressure tubing to 3000 psi. 13. Nipple up tree. Displace the tubing with diesel and the 3-1/2" x 9-5/8" annulus with gelled diesel down to thc GLM at 6050' TVD. R E C E I//E D 14. Release drilling rig. M~ ~; .[ 5 ~.~ 41aska Oil & Gas Cons, )! nt~h,~,..,.2; ",' PBU DS 18-25 OPERATIONS SUMMARY CONT. NOTE: a. Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Wells within 200' of the proposed well are: DS 18-14 55' DS 18-15 60' DS 18-13 158' DS 18-16 170' @ 1380' TVD / 1382' MD @ Surface to 1020'TVD /MD @ 1620' TVD / 1628' MD @ 1020' TVD/MD C. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi / ft). e. Based upon previous logs on DS 18, no potential productive zones are anticipated above 4000' TVD. f. No potential hazardous levels of H2S are anticipated in this well. RECEIVED Alaska,Oil.& Oas Cons,, Cc'tn~ission ' ~ ~nchoragd I.i,t w 0 CD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CD 0 0 0 0 0 0 - 0 0 CD 0 ~- ,Cd,-/'' Iv) ~ L.O t~ ~ ~ ~ TRUE VERTICAL DEPTH 0 0 0 _ 1'~ 0 0 0 _ ~0 0 hi 0 CO _ mt* 0 ~ 0 ~* 0 _ 0 0 0 _ O~ 0 0 0 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET z 2000 1000 1000 2O0O ARCO ALASKA, Inc. D.S. 18, Well No, Prudhoe Bay, North 25 Proposed Slope. Alaska 1000 0 1000 I I 2000 I WEST-EAST 3000 4.000 SURFACE LOCATION' 871' FNL. 326' FWL SEC- I9. TIIN. R15E SURFACE S 76 DEG 7273' (TO 15 HIN E TARGET) 5000 6OO0 TARGET TVD=8722 THD=12242 DEP=7273 SOUTH 1729 EAST 7065 TARGET LOCATION, 2600' FNL, 2850' FEL SEC. 20, TllN, RISE 7000 I 800~ 100 _ 50 _ ~ 50 _ 100 . 150 _ 200 _ 50 0 50 100 150 200 250 300 350 400 450 I I ! I I I I I,, ! I I i o0 O0 O0 ',~300 '~400 '~500 '~7'00 ~2090000 ~ \,,.oo I'~ ~' K° "'!''" ~'" 4' I I I i 0 50 100 I I I I I i i ' 1 50 200 250 300 350 400 450 _ lO0 5O 5O 100 _ 150 _ 200 DS 18-25 MUD PROGRAM DEPTH DENSITY FUNNEL YP INT. 10 min (TVD) (PPG) VIS (#/100sqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % % Surf 8.8 100 40 to to to to 13-3/8" 9.2 250 70 Csg Pt. 30+ 50+ 25 0 8 Gel - Benex Spud Mud DEPTH DENSITY PV YP INT. 10 min (TVD) (PPG) (CP) (#/100sqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % 13-3/8" 8.8 Minimum 2 2 4 25 to to Possible to to to to K-10 9.6 4 4 10 10 0 2 K-10 9.6 10 6 2 4 8 2 4 to to to to to to to to to 9-5/8" PT 10.4 20 10 4 10 6 5 15 Low Solids Non-Dispersed Low Solids Non-Dispersed DEPTH DENSITY PV YP INT. 10 min FL OIL (TVD) (PPG) (CP) (#/100sqft) GEL GEL (cc/30min) % SOLIDS TYPE % 9-5/8" 8.8 10 15 8 8 7 85 10 tO to tO tO tO tO tO tO tO TD 9.4 20 25 10 20 8 90 15 Oil Base The above properties are to act as a basic guidline, actual fluid properties are to be adjusted to the hole conditions encountered. NABORS 28E MUD SYSTEM SAND TRAP 4 BBLS PIT #1 TRIP TANK 130 BBLS 170 BBLS PIT #2 PIT #3 81 BBLS 137 BBLS PIT #5 117 BBLS PIT #4 179 BBLS PILL PIT 2O BBLS PIT #6 135 BBLS EQUIPMENT- DRILLING FLUID SYSTEM (3) DERRICK FLO LINE CLEANER PLUS SHAKERS (1) DERRICK MUD CLEANER (1) BRANDT CF-2 CENTRIFUGE (1) PIONEER MARK 1 CENTRIFUGE (1) DRILCO DEGASSER (1) DACRO GAS BUSTER ONE PVT SENSOR PER PIT (with both visual and audio warning devices) ONE AGITATOR PER PIT DRILLING FLOW SENSOR (with readout convenient to the driller's console) RECEIVED Alaska Oil & Gas Cons., Anchorage GSW 4/7/89 NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. SCHEMATIC FILL-UP LINE 'RISER IFLOWLINE I I / 2000 PS, / 10" BALL VALVE' ,' 10" BALL VALVE I I I I CONDUCTOR NOTE- ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINE RESERVE PIT WELL lO" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. l s-s/ " iooo ACCUMULATOR CAPACITY TEST I I REYE#TER~ I BLINDRAt'IS 1 DRI LLI #~ SPOOL I PIPERA"S 1 '"'" ~ ~ SPOOL PI PE RAHS ALL BOP EQUIPMENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME 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 12:00 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2:. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMI NED PLUG SEATING DEPTH. 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 2:50 PSI LOW PRESSURE TEST FOR A MINIMUM OF 3 MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FORA MINIMUM OF 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PI PE RAMS AND HOLD FOR AT LEAST 3 MI NUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. 11. BLEED PRESSURE.TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 12. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST 3 MI NUTES. 13. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANI FOLD AND LINES ARE FULL OF NON- FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 1 4. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRI LLI NG SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. bfi~tii Llbl ]~Ult N]~W WELL ITEM APPROVE DATE (2) Loc (.~j~thru 8f~$~ (8) ( 3 ) Ad m i n ~./3C_ f~/f-~ 9. (9 thru 13)' ' 10. (10 and 13) 12. 13 (4) Casg (14 thru 22) (23 thru 28) (6) OTHER ~--~ ~~ (29 thru 31) (6) Add: Geology: DWJ ~~_ Eng~Dee~In~ :" LCs ' / rev: 01/30/89 6.011 Company /vzz-~.~ /~~:z '~C,- , Lease & Well No. '" YES NO RE~S Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pOol · . .................... 3. Is wed] located proper distance from property line .................. 4. Is w~,[ located proper distance from other wells ........... ~' 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included .......... ...... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ' ~- Is administrative approval needed ................................... Is the lease number appropriate / ..................................... ~ Does the well have a unique nam~ and number . . ~_ ~ ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate .~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~5'dP~P~ psig .. Does the choke manifold comply w/A_PI RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are d~ta presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITI'AL GEO. UNIT oN/OFF ' POOL CLASS STATUS AREA NO. SHORE CD ~z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special 'effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: ARCO ALASKA INC. DRILL SITE 18 WELL #25 PRUDHOE BAY i I J I ! I i .I _ J I ! ! ........... l J ~__1 J ~i t I [ ** reel header ** service name :RGD date :89/06/28 origin :2300 reel name :702TAK continuation # :01 previous reel : comments :TELECO OILFIELD SERVICES PROPRIETARY FIELD TAPE ** tape header ** service name : RGD date : 89/06/28 origin :2300 tape name : 702TAK continuation # :01 previous tape : comments :RIG NABORS 28E ** file header ** file name :702 .001 service name : RGD version # : 1.24 date :89/06/28 maximum length :1024 file type :LO previous file : ** information records ** table type :TOOL MNEM STAT LENG WEIG HEIG GR ALLO 0.000 0.000 0.000 RSN ALLO 72.000 0.000 0.000 DCDS ALLO 360.000 0.000 0.000 ** information records ** table type :CONS MNEM STAT PUNI TUNI VALU BS UNAL CS I Z UNAL SD UNAL WMUD UNAL SHT UNAL BHT UNAL TD UNAL YEAR UNAL MONT UNAL DAY UNAL IN IN F LB/G DEGF DEGF F ** information records ** table type :CONS MNEM STAT PUNI SON UNAL RI UNAL R2 UNAL R3 UNAL R4 UNAL R5 UNAL R6 UNAL R7 UNAL R8 UNAL HIDE UNAL WN UNAL CN UNAL FN UNAL FL UNAL FL1 UNAL LUL UNAL ENGI UNAL WITN UNAL DFT UNAL LONG UNAL LATI UNAL STAT UNAL COUN UNAL DMF UNAL LMF UNAL PDAT UNAL APIN UNAL IN IN F LB/G DEGF DEGF F TUNI 8.500 9.625 8400.000 5.500 0.000 0.000 12900.000 89.000 6.000 28.000 VALU RES I STIVITY/GAMMA/D IRECTI ONAL DRILL SITE 18 WELL #25 ARCO ALASKA INC. PRUDHOE BAY ANCHORAGE BURTON/ST. PIERRE OLSEN ALASKA NORTH SLOPE RKB RKB 000 '0 000 '0 000 *0 000 '0 000 ' OOE:~ 000 '0 000 '0 000 '0 qONI 0§'8 ~'~I O~i'tI §E9'6 X~NQOD ¥Sfl ~N~ ~N~ ~N~ ~N~ ~N~ ~N~ ~¥N~ ~N~ ~¥N~ ~¥N~ ~¥N~ ~¥N~ ~N~ ~N~ ~N~ ~N~ ~N~ ~N~ ~N~ ~N~ I~,T, DD~I %t~tcIO Nf¥I IS8 gSO ESD ISD SSD~ SSM~ ~NOD I~N NMOA OINA 8NA 9NA 9S0 GSO ~SO gSO ISO I d l ......... ~ [ ' I I I - lI I I I I I I I NIgH OdSq NIgH O~SN ,T,S.gG IGOO 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'0 000'006gI 000'006EI 000'0 000'6~ 000'0~ 000'0 ~mg0 ** spaooaa uoT~wm, xo~u! ~ ~HO 7vNn ~5~HO ~¥N~ Sk~ o/aT ~ ~NQ EGS~ ~/8q qVgn EMD & ~Nn TGS~ TT1 TT1 DISA TT2 TT2 DISA TT3 TT3 DISA TT4 TT4 DISA TENS TENS DISA 12 DUMM DISA 13 DUMM DI SA 14 DUMM DISA 15 DUMM DI SA 16 DUMM DI SA 17 DUMM DISA 18 DUMM DI SA 19 DUMM DI SA ** information records ** T3 T3 T3 T3 T3 Ti Ti Ti Ti Ti Ti Ti Ti LLIN 1 SHIF LSPO 1 SHIF LDAS 1 SHIF LGAP 1 SHIF LSPO 1 NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB LLIN NEIT NB table type :FILM MNEM GCOD GDEC DEST DSCA 1 E2E -2- PF1 S2 2 EEE -2- PF2 D500 ** information records ** table type :AREA MNEM STAT 1 DISA 2 DISA 3 DISA 4 DISA 5 DISA 6 DISA 7 DISA 8 DISA ** data-format record ** entry blocks type 4 8 size 1 4 BEGI Zl Zl Zl Zl Z1 Z1 Zl Zl repr code 66 68 END PATT DEST Zl BLAN NEIT Z1 BLAN NEIT Zl BLAN NEIT Z1 BLAN NEIT Z1 BLAN NEIT Zl BLAN NEIT Zl BLAN NEIT Z1 BLAN NEIT entry 255 60.000 9 12 0 datum specification blocks WARNING the following table is Sub-Type 0 and the API mnem service service id order # DEPT GR RSN ROP SWOB RPM TCDS INC AZM TVD NS EW VS DLS in LIS Type unit api api log type FT 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 00 000 65 .liN 68 -9999.000 79 0 Datum Specification Block Codes may be Unreliable!!! api api file size spl repr class mod no. code 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 00 00 0 4 1 68 process level depth = 8400.0000 feet GR 1.0000 RSN RPM 1.0000 TCDS TVD 1.0000 NS DLS -1.0000 2560.3200 meters 1.0000 ROP 1.0000 SWOB 1.0000 INC 1.0000 AZM 1.0000 EW 1.0000 VS depth = 8450.0000 feet .... 2575.5600 meters GR 150.0000 RSN 2.8070 ROP -9999.0000 SWOB RPM -9999.0000 TCDS -9999.0000 INC -9999.0000 AZM TVD -9999.0000 NS -9999.0000 EW -9999.0000 VS DLS -9999.0000 depth = 8500.0000 feet 2590.8000 meters GR 170.2500 RSN 2.9600 ROP 81.2740 SWOB RPM -9999.0000 TCDS -9999.0000 INC -9999.0000 AZM TVD -9999.0000 NS -9999.0000 EW -9999.0000 VS DLS -9999.0000 1.0000 1.0000 1.0000 -9999.0000 -9999.0000 -9999.0000 62.6810 -9999.0000 -9999.0000 0~I9 'IL ~OMS 0999'0E dOH 068§'E saasam 00EL'EILE NSH 0000'I0g 0000'0068 = g~dap 0000'6666- 0000'6666- O~E~'6§ 0000'6666- SA 0000'6666- M~ 0000'6666- SN 0000'6666- }{ZV 0000'6666- DNI 0000'6666- SGD~ 0000'0 ~OMS 0160'IE dOH 0I~L'~ NSH 0000'g0g sI~m 008~'L69E ~a~ 0000'0988 GA,T, }{dH HD = qsdap 0000'6666- 0000'6666- 0IL6'§9 SA ~OMS 0000 0000'6666- M~ 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SOD~ 0000 00I£'0£ dOH 0C~6'E NSH 000g sla~ 00~g'~89E .... ~aa~ 0000'008 '6666- '6666- '6666- 'IgI 8 GA,T, HD = gsdap 0000'6666- 0000'6666- 0~tg'~9 SA ~OMS 0000 0000'6666- MH 0000'6666- SN 0000 0000'6666- DNI 0009'9II SOD~ 0000 00E9'~9 dOH 0§~L'E NSH 0000 saasam 0000'L99E .... Saa~ 0000'0gL '6666- '6666- '6666- '§SI GA,T, }{dH HD = g~dap 0000'6666- 0000'6666- 0C6~'69 SA ~OMS 0000 0000'6666- MH 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SOD~ 0000 0LI0'0S dOH 09~8'E NSH 0000 slaSa~ 009L'I§9E .... Saa~ 0000'00L '6666- '6666- '6666- ' GA,T, = g~dop 0000'6666- 0000'6666- 09§6'L9 SA ~OMS 0000 0000'6666- M~ 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SOD~ 0000 0~I9'69 dOH 0909'E NSH 0000 slasa~ 00EG'9~9E .... ~aa~ 0000'0~9 '6666- '6666- '6666- '99I STO }{dH HD = g~dop 0000'6666- 0000'6666- 0IL6'L9 SA ~OMS 0000 0000'6666- M~ 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SOD~ 0000 0~II'~9 dOH 0E0g'E NSH 0000 sI~a~ 008E'I~9E .... ~aa~ 0000'009 '6666- '6666- '96 'ALI 8 GA,T, = gsdap 0000'6666- 0000'6666- 06~I'~9 SA ~OMS 0000'6666-- 0000'6666- M~ 0000'6666- SN 0000'6666-- 0000'6666- DNI 0000'6666- SGDA 0000'86 0§89'CL dOH 08L9'E NSH 0C~'6gI sI~ 0090'909~ ~ 0000'0~8 S~O GA,T, = q~dap { ! ....{ [ ......... : [ ....... ~ [ ....... I I ! { [ ! I { I I I I I 0000'6666- SA 0000'6666- 0£8~'§§ ~OMS 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SGDA 0000'III 0~9£'~8 ~0~ 00~'gI NS~ 0000'6IE saa~a~ 000~'618~ .... ~a~ 0000'0§E6 GAJ, = g~dap 0000'6666- SA 0000'6666- ~ZV 06~0'§9 ~OMS 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 000~'£EI SOOA 0000'C6 0I~8'9~ ~0~ 0~8'6 NS~ 0000'6~E saa~a~ 009I'~08~ ~aa~ 0000'00E6 GA J, = g~dap 0000'6666- SA 0000'6666- ~Z~ 0£I8'~9 ~OMS 0000 0000'6666- MM 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SODA 0000 0COI'C£ dOM 06£0'6 NSM 0£99 sa~ 00E6'88£~ .... ~aa~ 0000'0§I '6666- '6666- '6666- 'ogE 6 GA,I, = g~dap 0000'6666- SA 0000'6666- NZ~ 0810'~9 ~OMS 0000 0000'6666- MM 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SODA 0000 0198'8E ~OM 09§8'~I NSM 000§ sa~a~ 0089'~4£E ~ 0000'00I '6666- '6666-- '6666- '09I 6 = 0000'6666- SA 0000'6666- NZ~ 0L~8'99 ~OMS 0000 0000'6666- MM 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SODA 0000 0C~g'g0I ~OM 0096'£ NSM 0000 s~a~ 00~'8§£E ~a~ 0000'0g0 '6666- ' 6666- '6II 6 GA,I, = g~dap 0000'6666- SA 0000'6666- NZ~ 08~L'09 ~OMS 0000 0000'6666- M~ 0000'6666- SM 0000 0000'6666- DNI 0000'6666- SODA 0000 0A~8'L6 ~0~ OLE£'~ NS~ 0008 saa~am 000g'~Lg ~aa~ 0000'000 '6666-- '6666-- '0 'L6g 6 GA,I, = g~dap 0000'6666- SA 0000'6666- NZ¥ 0II§'6g ~OMS 0000'6666- 0000'6666- MM 0000'6666- SM 0000'6666-- 0000'6666- DNI 0000'6666- SODA 0000'6666- 0I£~'E9 ~0~ 0£0§'~ NS~ 0000'£§g saa~am 0096'Lg£g .... ~aa~ 0000'0968 GA,I, = g~dap 0000'6666- SA 0000'6666- ~Z~ 0000'6666- 0000'6666- MM 0000'6666- SM 0000'6666- 0000'6666- DNI 0000'6666- SODA 0000'0 GA,I, { I I .... ~: [ [' I [ ...... ! 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I I I 0~8~'9§ ~OMS 0000'6666- SA 0000'6666- NZV 0EIA'g~ ~OMS 0000'6666- SA 0000'6666- NZV 0~g6'~§ ~OMS 0000'6666- SA 0000'6666- ~Z~ 08~0'9g 80MS 0000'6666- SA 0000'6666- ~Z~ 086I'9g ~OMS 0000'6666- SA 0000'6666- ~Z~ 0I~'Cg ~OMS 0000'6666- SA 0000'6666- ~Z~ 0~89'G~ ~OMS 0000'6666- SA 0000'6666- ~ZV 00E£'£~ ~OMS 068~'8§ dOM 0EI£'6 NSM 000§'ISE sI~$~ 00EC'I~6E $~g 0000'0§96 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SOD~ 0000'6666- 08I§'£9 dOM 0I~8'8 NSM 0000'I0£ sa~ 0080'9E6E ~ 0000'0096 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SGD~ 0000'I 0~9'6£ dO~ 0£6~'8 NS~ 0000'~E sla~a~ 00~8'016E ~aa~ 0000'0§g6 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SOD~ 0000'£II 0689'8~ dOM 0819'£ NSM 000§'E6E sI~ 0009'§68E ~ 0000'00§6 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SOD~ 0000'9II 000I'£~ dO~ 0886'A NSM 0000'9~g sI~ 009£'088E ~ 0000'0~6 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SGD~ 0000'6666- 0819'0§ dOM 09~'~I NSM 0000'E6I s~~ 00EI'§98E ~ 0000'00~6 0000 0000'6666- MM 0000'6666- SM 0000 0000'6666- DNI 0000'6666- SOD~ 0000 0£~G'69 ~OM 0~68'EI NSM 0000 s~~ 0088'6~8E .... ~ 0000'0~ '6666- '6666- '6666- 'GEE 6 0000 0000'6666- MM 0000'6666- SM 0000 0000'6666- DNI 0000'6666- SODA 0000 0~6~'~9 dOM 0E9E'~I NS~ 0L99 sa~ 00~9'~8E .... ~ 0000'00~ ' 6666-- '6666-- '£0I ' 6 = gsdap GA,I, = qsdap GA J, = q~dap GA,I, = g~dap GAin ~D = qsdap GA,I, = qsdap GA,T, = g~dap GAJ~ ~D = qsdap {. ! !:~ ..... [ [ ! ' [' f ! ! [ ....... ! I[ ! ! [ ! I I 0000'6666- SA 0000'6666- 09£~'8~ ~OMS 0000'6666- MX 0000'6666- 0000'6666- DNI 0000'6666- 0£66'£I dOM 09~0'0~ s~a~a~ 0000'8~0£ 0000'6666- SN 0000'6666- SODA 0000'0 NSM 0000'IgI ~a~ 0000'0000I GA,T, MD = gsdap 0000'6666- SA 0000'6666- ~Z~ 06Eg'6~ ~OMS 0000'6666- MX 0000'6666- 0000'6666- DNI 0009'~£I 0§09'9g dOM 09~8'9E s~a~ 009L'ECOC 0000'6666-- S~O SN 0000'6666- OAA SGDA 0000'~ ~dM NSM 00gL'0II MD ~aa~ 0000'0~66 = g~dap 0000'6666- SA 0000'6666- NZ~ 0~'g~ ~OMS 0000'6666- MX 0000'6666- 0000'6666- DNI 0000'6666- 068~'8§ dOM 0§Ag'8g sas~am 00gS'LI0g 0000'6666- SN 0000'6666- SGDA 0000'0 NSM 0000'CIg 0000'0066 GA,T, MD = gsdap 0000'6666- SA 0000'6666- NZ¥ 0098'G9 ~OMS 0000'6666- MX 0000'6666- 0000'6666- DNI 0000'6666- 08~g'Sg dOM 0£E£'~ saa~a~ 008E'g00g 0000'6666- SN 0000'6666- SODA 0000'6666- NSM 0000'I0g ~aa~ 0000'0986 GA,T, MD = gsdap 0000'6666- SA 0000'6666- NZ~ 069~'96 ~OMS 0000'6666- MX 0000'6666- ONI 0IgI'Sg dOM saa~a~ 00~0'£86E 0000'6666- 0000'6666- SN 0000'6666- 0000'6666- SODA 0000'0 0£89'A~ NSM 0000'98I .... ~a~ 0000'0086 GA,T, = g~dap 0000'6666- SA 0000'6666- NZ~ 0689'g§ ~OMS 0000'6666- M~ 0000'6666- DNI 0gCI'Cg dOM saa~m 0008'I£6E 0000'6666- 0000'6666- SN 0000'6666- 000E'SCI SODA 0000'6666- 06~8'9 NSM 000~'~g .... ~aa~ O000'O~L6 GA,T, = gsdap 0000'6666- SA 0000'6666- NZ¥ 08E§'9§ ~OMS 0000'6666- MX 0000'6666- DNI 0CL~'~9 dOM sla~am 009g'996E 0000'6666- 0000'6666- SM 0000'6666- 0000'6666- SODA 0000'0 0L~8'8 NSM 0~'~LE .... ~aa~ O000'OOL6 S~O MD = gsdap 0000'6666- SA 0000'6666- NZ~ 0000'6666- M~ 0000'6666- DNI 0000'6666- 0000'6666- SN 0000'6666- 0000'6666- SODA 0000'0 SqO OAA HcIM 08~£'~ 80~S 0000'6666- SA 0000'6666- NZ~ 0086'££ ~OMS 0000'6666- SA 0000'6666- NZ~ 0161'09 ~OMS 0000'6666- SA 0000'6666- NZV 0E60'6~ ~OMS 0000'6666- SA 0000'6666- }{ZV 0g£g'Ig ~OMS 0000'6666- SA 0000'6666- }{Z~ 0£0£'8£ ~OMS 0000'6666- SA 0000'6666- }{Z~ 0189'6C ~OMS 0000'6666- SA 0000'6666- }{Z~ OESO'Og ~OMS 099L'90I 6OH 0000'6666- NSH 00§E'£0I sI~$~ 00E6'69I~ $~ 0000'00901 0000 0000'6666- MH 0000'6666- SN 0000 0000'6666- DNI 0000'6666- SOD~ 0000 098E'~6 ~OM 0000'6666- NSM 0008 slaSa~ 0089'9gI5 .... ~aa~ 0000'0§~ '6666- · 6666I '6666- 0I 0000'6666- 0000'6666- MH 0000'6666- SN 0000'6666- 0000'6666- DNI 0009'EgI SOD~ 0000'0 0E99'£6 dOM 0000'6666- NSM 0000'08 sI~sm 0099'6~Ig .... $~ 0000'00£0I 0000'6666- M~ 0000'6666- 0000'6666- DNI 0000'6666- 0E9£'80I ~OM 0000'6666- s~~ 000E'gEI~ 0000'6666- SN 0000'6666- SOD~ 0000'6666- NSM 0008'8G ~ 0000'0GEOI 0000'6666- MH 0000'6666- ONI 0C98'G8 dOM sa~m 0096'80Ig MO = gsdap 0000'6666- MH 0000'6666- DNI 0~I8'99 dOM saaSam 00~£'C60~ SqQ QAm }{dM MO = gsdap HD = qsdap 0000'6666- MH 0000'6666- ONI 0E99'I§ dOM saasam 0089'8£0g GA,I, = g~dap 0000'6666- MH 0000'6666- OMI 016£'8I dOM slasam 009E'C90~ 0000'6666- S~O 0000'6666- SN 0000'6666- 0000'6666- SOD~ 0000'6666- }{dM 0000'6666- NSM 0~C'6£ MD ~aa~ 0000'00g0I = g~dap 0000'6666- 0000'6666- 0000'6666- 0000'6666- SN 0000'6666- SOD~ 0000'0 MSM 0000'9CZ gaa~ 0000'0gIOI 0000'6666-- 0000'6666' SM 0000'6666-- 0000'6666- SOD~ 0000'0 0000'6666- NSM 0000'9II .... ~aag 0000'00IOI 0000'6666- 0000'6666- 0000'6666- 0000'6666- SM 0000'6666- SQDZ 0000'0 NSH 0000'9EI ~a~g O000'O§OOI GA,I, }{dM MD = qsdap = g~dap GA,I, }{dM = qsdap 0000'6666- SA 0000'6666- NZ~ 0£9['6g ~OMS 0000'6666- 0000'6666- M~ 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SGOA 0000'6666- 0C~6'~£ 6OH 0000'6666- NSH 0000'89 s~asam 0009'9£Eg .... Saa~ 0000'0G£0I SqG ~O = gsdap 0000'6666- SA 0000'6666- NZ~ OE£~'E~ ~OMS 0000'6666- 0000'6666- M~ 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SODA 0000'0 000I'96 60%{ 0000'6666- NS%{ 0000'[A s~a~ 009~'I9E£ .... ~a~ 0000'00£0I S~IG (]AK %{D = g~dap 0000'6666- SA 0000'6666- NZ~ 0699'6~ ~OMS 0000'6666- 0000'6666- M~ 0000'6666- SN 0000'6666- 0000'6666- ONI 0000'6666- SGDA 0000'IgI 08E~'6£ 60%{ 0000'6666- NSH 0000'L9 sla~a~ 00~I'9~g~ .... ~aa~ 0000'0§90I (]AK %{0 = gsdap 0000'6666- SA 0000'6666- 0E9E'g~ ~OMS 0000'6666- M~ 0000'6666- 0000'6666- DNI 0000'6666- 08~£'9I~ 40%{ 0000'6666- saa~a~ 0088'0~E~ 0000'6666-- SN 0000'6666- SGDA 0000'6666- NS%{ 0000'~9 Saa~ 0000'0090I S~IG GA,T, %{0 = qsdap 0000'6666- SA 0000'6666- NZ~ 0IgC'0~ ~OMS 0000'6666- 0000'6666- M~ 0000'6666- SN 0000'6666- 0000'6666- DNI 000E'£~I SGDA 0000'6666- 08IE'~II 60~ 0000'6666- NS%{ 0000'L9 sI~a~ 00~9'§IE~ ~aa~ 0000'0~§0I %{0 = gsdap 0000'6666- SA 0000'6666- NZ~ 0669'6g ~OMS 0000'6666- 0000'6666- M~ 0000'6666- SN 0000'6666- 0000'6666- DNI 0000'6666- SGDA 0000'0 00~'88 40%{ 0000'6666- NSH 0000'69 s~a~a~ 000~'00E~ .... ~aa~ 0000'00~0I %{0 = gsdap 0000'6666- SA 0000'6666- NZ~ 0880'££ ~OMS 0000' 0000'6666- M~ 0000'6666- SN 0000' 0000'6666- DNI 0000'6666- SGDA 0000' 0EL£'£6 40%{ 0000'6666- NS~ 0000' s~a~am 009I'~8IS .... Saa~ 0000'0§~0 6666-- 6666-- 6666-- £0I I GA,I, = gsdap 0000'6666- SA 0000'6666- NZ~ 0000' 0000'6666- M~ 0000'6666- SN 0000' 0000'6666- DNI 0009'E§I SODA 0000' 6666-- 6666-- 6666-- (/AK 0000'9£ ~OMS 0000'6666- SA 0000'6666- NZ~ 006['£g ~OMS 0000'6666- SA 0000'6666- NZ¥ 0I~'I~ ~OMS 0000'6666- SA 0000'6666- NZ~ 0089'I~ ~OMS 0000'6666- SA 0000'6666- }{Z~ 0106'CC ~OMS 0000'6666- SA 0000'6666- }{Z~ 0£§8'AC ~OMS 0000'6666- SA 0000'6666- }{Z~ 09gE'CC ~OMS 0000'6666- SA 0000'6666- }{Z~ 0g£I'0~ ~OMS 0000'8I dOH 0000'6666- NSH 0It~'ggI s~aSam 00E§'86£S Saa~ 0000'0gill 0000'6666- 0000'6666- MH 0000'6666- SN 0000'6666- 0000'6666- DNI 000~'89I SODA 0000'0 09gg'~I ~OH 0000'6666- NSH 0000'E6I s~a~a~ 008E'~8~ ~aa~ 0000'00III 0000'6666- 0000'6666- MH 0000'6666- SN 0000'6666- 0000'6666- DNI 000E'§9I SODA 0000'0 08EI'£I dOH 0000'6666- NSH 0000'99I sa~a~ 00~0'89£C ~aa~ 0000'0§0II 0000'6666- MH 0000'6666- DNI 016§'gI dOH saa~am 0008'Egg~ 0000'6666- 0000'6666- SN 0000'6666- 0009'I9I SOD~ 0000'0 0000'6666- NSH 0000'ISI .... ~sa~ 0000'000II 0000'6666- MH 0000'6666- DNI 0£E8'~I dOH saa$a~ 009§'££g£ 0000'6666- 0000'6666- SN 0000'6666- 0008'6gI SOD~ 0000'0 0000'6666- NSH 0000'69I ~aa~ 0000'0~60I 0000'6666- MH 0000'6666- DNI 0696'8~ dOH saa~m OOEg'EEg~ 0000'6666- 0000'6666- 0000'6666- 0000'6666-- SN 0000'6666- SQD~ 0000'6666- NSH Saa~ 0000'0060I 0000'6666- MH 0000'6666- OMI 0gS£'Eg dOH saa~am 0080'£0gg 0000'6666- 0000'6666- SM 0000'6666-- 0000'6666- SOD~ 0000'6666-- 0000'6666- NSH 0000'99 .... ~aa~ 0000'0~80I 0000'6666- MH 0000'6666- OMI 00~'88 dOH s~aSa~ 0098'I6ES 0000'6666- 0008'I~I 0000'6666- 0000'6666-- SM 0000'6666-- SODA 0000'0 NSH 0000'§9 ~aa~ 0000'0080I = gsdap GA,I, = gsdap SqO GA J, }{dH HD = gsdap SqO GA,I, }{dH HD = gsdap S~G GA,I, }{dH HD = qsdap SqO GA,I, }{dH = gsdap SqG GA,I, }{dH HO = gsd~p SqO GA J, }{dH HO = g~dap 0000'6666- SA 0000'6666- NZV 0§89'££ 80MS 0000'6666- MM 0000'6666- 0000'6666- DNI 0008'89I 09CE'~II ~OH 0000'6666- saa~a~ 000g'~0g£ 0000'6666-- SN 0000'6666- SODA 0000'6666- NSH 0£CC'6£ Sang 0000'00~II SqG GAAI, = gsdap 0000'6666- SA 0000'6666- NZV 0A9£'99 ~0MS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 0£06'6£I dOB 0000'6666- s~~ 0096'68~ 0000'6666- SqO SN 0000'6666- OAA SODA 0000'6666- }{dB NSB 0000'£9 BD ~a~g 0000'0~II = g~d~p 0000'6666- SA 0000'6666- MM 0000'6666- }{Z~ 0000'6666- DNI 0g§~'£~ ~OMS 0~g9'g~I dOB 0000'6666- 0000'6666- 0000'6666- 0000'6666- SN 0000'6666- SGDA 0000'0 NSB 0000'I6 Saag 0000'00~II GA J, BO = gsdap 0000'6666- SA 0000'6666- MM 0000'6666- }{Z~ 0000'6666- DNI 08£~'8~ ~OMS 0I£E'~8 dOB s~$~m 008~'6g~g 0000'6666- 0000'6666- 0000'6666- 0000'6666- SN 0000'6666- SODA 0000'6666- NSB 0000'C8 ~aa~ 0000'0~II GA J, BO = gsdap 0000'6666- SA 0000'6666- MM 0000'6666- ~Z~ 0000'6666- DNI 0699'~ ~OMS 0gC£'III dOB s~$~m 00~g'~g 0000'6666- 0000'6666- SN 0000'6666- 0000'6666- SODA 0000'6666- 0000'6666- NSB 06E~'0£ .... gaag 0000'00CII SqG GAAI, BD = gsdap 0000'6666- SA 0000'6666- M~ 0000'6666- ~Z~ 0000'6666- DNI 0§0~'££ ~OMS 0§08'~§I dOB s~a~am 0000'6E~E 0000'6666-- 0000'6666- SM 0000'6666- 0000'6666- SODA 0000'0 0000'6666- NSB 0000'C8 .... gaag 0000'0GEII S~G (]AA BD = g~dap 0000'6666- SA 0000'6666- MH 0000'6666- NZ~ 0000'6666- 0NI 0C8E'9C ~OMS 0g~6'gg dOB slaSa~ O09L'CI~C 0000'6666- 0008'6§I 0000'6666- 0000'6666-- SM 0000'6666-- SODA 0000'6666- NSB 0000'§8I $~ag 0000'00gII GA,I, = g~dap 0000'6666- SA 0000'6666- M~ 0000'6666- ~ZV 0000'6666- DNI 0000'6666- 0009'E~I 0000'6666-- SM 0000'6666- SODA 0000'0 SqG 0£6£'8£ ~OMS 0069'86 dOB 0000'6666- NSM 0A99'66 s~aSa~ 00EI'£E9C $a~g 0000'006II = gsdap 0000'6666- 0000'6666- 0£6C'~ 0000'6666- SA 0000'6666- MM 0000'6666- SN 0000'6666- }{Z~ 0000'6666- DNI 0000'6666- SGD~ 0000'6666- ~OMS 0986'£0I dOM 0000'6666- NSM 0000'06 saa~ 0088'II9~ .... ~ 0000'0§SII GA,T, = qsdap 0000'6666- 0000'6666- 0~6~'I~ 0000'6666- SA 0000'6666- MM 0000'6666- SN 0000'6666- }{Z~ 0000'6666- DNI 0000'6666- SGD~ 0000'0 ~OMS 06~6'E~I dOM 0000'6666- NSM 00§~'98 sa~a~ 00~9'96G~ ~aa~ 0000'008II GA,T, = 0000'6666- 0000'6666- 09£6'6~ 0000'6666-- SA 0000'6666- MM 0000'6666- SN 0000'6666- }{Z~ 0000'6666- DNI 0000'6666- SGD~ 0000'6666- ~OMS 08~£'EOI dOM 0000'6666- NSM 000~'~II saa~am 000~'I8~ ~aa~ 0000'0~£II GA,T, }{dM = q~dap 0000'6666- 0000'6666- 09~'8~ 0000'6666- SA 0000'6666- MM 0000'6666- SN 0000'6666- NZ~ 0000'6666- DNI 0000'6666- SGD~ 0000'0 ~OMS 0§8~'~I dOM 0000'6666- NSM 0009'89 sla~ 009I'99Gg .... Saag 0000'00£II GA,T, }{dM = qsdap 0000'6666- 0000'6666- 00§0'£C 0000'6666-- SA 0000'6666- MM 0000'6666- SM 0000'6666- ~Z~ 0000'6666- DNI 0000'6666- SGDA 0000'0 ~OMS 0~Ag'g0I dOM 0000'6666- NS~ 0000'§A saa~a~ 00E6'0~£ .... ~aa~ 0000'0§9II GA,T, = 0000'6666- 0000'6666- 0gSg'I~ SA ~OMS 0000'6666- 0000'6666- MM 0000'6666- S~ 0000'6666- 0000'6666- DNI 0000'6666- SGOA 0000'0 096I'0~ dOM 0000'6666- NSM 000~'I~I sla~a~ 0089'§~§~ .... Saa~ 0000'009II GA,T, M~ = g~dap 0000'6666- 0000'6666- 0~I£'£C SA ~OMS 0000'6666- 0000'6666- MM 0000'6666- SM 0000'6666- 0000'6666- DNI 0000'6666- SGDA 0000'6666- 00E0'SII dOM 0000'6666- NSM 000~'~6 s~a~a~ 00~'0gg~ .... ~aa~ 0000'0ggII S~G GA,T, = qsdap 0000'6666- SA 0000'6666- ~Z~ 0819'£9 80MS 0000'6666- MM 0000'6666- 0000'6666- ONI 0000'6666- 08~§'I8 ~OM 0000'6666- saa~ 0008'C~L~ 0000'6666- SN 0000'6666- SOOA 0000'0 NSM 0£99'£II gang 0000'0§ggI GAAT, = ggdap 0000'6666- SA 0000'6666- ~Z~ 06II'89 ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 09§9'IEI ~OM 0000'6666- saa~ 009~'8I£~ 0000'6666- SN 0000'6666- SODA 0000'6666- NSM 0£99'90I Saag 0000'00ZgI GA,T, MD = gsdap 0000'6666- SA 0000'6666- ~Z~ 09§6'99 ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 00g8'III dOM 0000'6666- 0000'6666- SN 0000'6666- SGDA 0000'6666- NSM 0009'AEI ~aag 0000'0~IgI (]AA ~dM = g~dap 0000'6666- SA 0000'6666- ~Z~ 0ISI'EC ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 0g0g'gL ~OM 0000'6666- saa~a~ 0080'889£ 0000'6666- SN 0000'6666- SODA 0000'6666- NSM 0CCC'GOI ~aag 0000'00IgI (]AA MD = gsdap 0000'6666- SA 0000'6666- NZ~ 0ES£'gg ~OMS 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- OMI 0000'6666- SODA 0000'0 06~8'I9 ~OM 0000'6666- NSM 0A99'96 s~a~a~ 0098'E£9~ .... ~a~ 0000'0g0gI SqG GA,T, MO = gsdap 0000'6666- SA 0000'6666- NZ~ 0~§9'§~ ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 0EEI'§£ ~OM 0000'6666- s~a~a~ 0009'£§9g 0000'6666-- SM 0000'6666-- SODA 0000'6666- NSM 00gg'g0I $~a~ 0000'000gI GA,T, MO = gsdap 0000'6666- SA 0000'6666- NZ~ 0£99'6~ ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 090£'86 ~OM 0000'6666- s~a~ 009g'~99~ 0000'6666-- SN 0000'6666-- SODA 0000'6666-- NSH 000§'£II ~aag 0000'0§6II OAT, MD = g~dap 0000'6666- SA 0000'6666- NZ~ 0000'6666- MM 0000'6666- DNI 0000'6666- 0000'6666- 0000'6666- SM 0000'6666- SODA 0000'0 SqO GA,T, 0~8I'6~ 80MS 0~11'88 ~0~ 0000'6666- ~S~ 0000'~0I s~a~ 00EL'§§8£ ~a~ 0000'0~9EI ~O = g~dap 0000'6666- SA 0000'6666- NZ~ 00~I'~ ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 06~'9£ ~0~ 0000'6666- s~a~a~ 008~'0~8~ 0000'6666- SN 0000'6666- SGDA 0000'0 NS~ 0000'0II Saa~ 0000'009EI GA,T, = q~dap 0000'6666- SA 0000'6666- NZ~ 066£'Ig 80MS 0000'6666- 0000'6666- MM 0000'6666- SN 0000'6666- 0000'6666- DNI 0008'89I SGDA 0000'0 06E6'E6 ~O~ 0000'6666- NS~ 0000'~0I saa~a~ 00~E'~E8~ .... ~a~ 0000'0§~EI GAAT, = q~dap 0000'6666- SA 0000'6666- NZ~ 0E6E'8~ ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 0~I~'~0I ~O~ 0000'6666- saa~a~ 0000'018~ 0000'6666- SN 0000'6666- SODA 0000'0 NS~ 0000'66 Saa~ 0000'00GEI GA,T, = qsdap 0000'6666- SA 0000'6666- NZ¥ 0~§'Ig ~OMS 0000'6666- MM 0000'6666- 0000'6666- DNI 0000'6666- 09£6'$9 ~0~ 0000'6666- s~a~ 009£'~6£C 0000'6666-- SN 0000'6666- OAK SODA 0000'0 NS~ 0009'68 Saag 0000'0N~EI = gsdap 0000'6666- SA 0000'6666- NZ~ 0§C£'0g ~OMS 0000'6666- MM 0000'6666- DNI 0696'CII ~OM saa$am 00EN'6£££ 0000'6666- 0000'6666- SN 0000'6666- 0000'6666- SODA 0000'6666- 0000'6666- NSM 0009'£0I .... ~aa~ 0000'00~I GA,T, ED = gsdap 0000'6666- SA 0000'6666- NZ~ 090I'£~ ~OMS 0000'6666- MM 0000'6666- DNI 0~IC'~0I ~0~ saaSa~ 008E'~9£~ 0000'6666-- 0000'6666- SN 0000'6666- 0000'6666- SOD~ 0000'0 0000'6666- NS~ 0008'90I .... ~aa~ 0000'0~I GAAT, ~O = gsdap 0000'6666- SA 0000'6666- NZ~ 0IC£'6~ 80MS 0000'6666- MM 0000'6666- 0000'6666- OMI 0000'6666- 00C~'£6 ~OM 0000'6666- s~a~ 00~0'6~£~ 0000'6666-- SM 0000'6666-- SODA 0000'6666-- NS~ 0000'CII Saag 0000'00£gI GA,T, = qsdop (YI: ~d~$ ~IT~ ~EOI: q~6ueI 8E/90/68: ~E'I : ~ UO~Sa~A I00' EOL: ainu 0000'6666- 0000'6666- 0000'6666- 0000'6666- 0000'6666- 00£9'~ 0000'6666- 0000'6666- 0§96'~ 0000'6666- 0000'6666- 08I§'£~ 0000'6666- 0000'6666- 09~£'~ 0000'6666- 0000'6666- SA ~Z¥ ~OMS 0000'6666- M~ 0000'6666- DNI 0000'6666- ~OM saaSam 00g6'Ig6C 0000 0000'6666- SM 0000 0000'6666- SODA 0000 0000'6666- NSM 0000 .... ~a~ 0000'006 '6666- S~O '6666- OA~ '6666- N~M '6666- MD EI = g~dap SA NZ~ ~OMS 0000'6666- M~ 0000'6666- 0000'6666- DNI 0000'6666- 0E6~'C8 ~OM 0000'6666- sI~a~ 0089'916C 0000'6666- SN 0000'6666- SOD~ 0000'6666- NSM 0000'6666- ~aa~ 0000'0~SgI SA ~Z~ ~OMS 0000'6666- M~ 0000'6666- 0000'6666- DNI 0000'6666- 06E£'6§ dOM 0000'6666- s~agam 00~'I06g GA,I, = g~dap SA 0000'6666- M~ 0000'6666- ~Z~ 0000'6666- DNI 0000'6666- ~OMS 0I~I'£~ ~OM 0000'6666- s~a~a~ 000E'988~ 0000'6666- SM 0000'6666- GA~ SGDA 0000'0 NSM 0000'8~I ~aa~ 0000'008gI = g~dap SA 0000'6666- MM 0000'6666- ~Z¥ 0000'6666- DNI 0000'6666- ~OMS 0080'~£ ~OM 0000'6666- s~~ 0096'0£8~ 0000'6666- SN 0000'6666- SOD~ 0000'6666- NSM 0000'6II ~aa~ 0000'0~£gI SA 0000'6666- MM 0000'6666- ~Z~ 0000'6666- DNI 0000'6666- 0000'6666-- SN 0000'6666-- SOD~ 0000'6666-- NSM 0000'SII $aa~ 0000'00£EI 0000'6666-- SN 0000'6666-- SOD~ 0000'6666-- GA,I, MD = gsdap GA J, = gsdap GA J, (NOTE'. ** REEL HEADER ** **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 89/07/03 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 89/07/03 ORIGIN OF DATA: 1825 TAPE NAME: PBU-EOA CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/03 MAX. RECORD LENGTH: 1024 FILE TYPE: 18 PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# L0G TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRC MWD AAPI 0 0 0 0 1 4 0 1 68 SFD2 RPT G/C3 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 CNF0 MWD COUN 0 0 0 0 1 4 0 1 68 CNF1 MWD COUN 0 0 0 0 1 4 0 1 68 CNN0 MWD COUN 0 0 0 0 1 4 0 1 68 CNN1 MWD COUN 0 0 0 0 i 4 0 1 68 GRA MWD AAPI 0 0 0 0 1 4 0 1 68 GRB MWD AAPI 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 GRA2 RPT AAPI 0 0 0 0 1 4 0 1 68 GRB2 RPT AAPI 0 0 0 0 1 4 0 1 68 GRC2 RPT AAPI 0 0 0 0 1 4 0 1 68 EWR2 RPT OHMM 0 0 0 0 1 4 0 1 68 RATE RPT FT/H 0 0 0 0 1 4 0 1 68 NPS2 RPT P.U. 0 0 0 0 1 4 0 1 68 NF02 RPT COUN 0 0 0 0 1 4 0 1 68 NFl2 RPT COUN 0 0 0 0 1 4 0 1 68 NN02 RPT COUN 0 0 0 0 1 4 0 1 68 NN12 RPT COUN 0 0 0 0 1 4 0 1 68 FXE2 RPT COUN 0 0 0 0 1 4 0 1 68 NPS MWD P.U. 0 0 0 0 1 4 0 1 68 SFD MWD G/C3 0 0 0 0 1 4 0 1 68 TVD CAL FT 0 0 0 0 1 4 0 1 68 NDIS TELECO FT 0 0 0 0 1 4 0 1 68 EDIS TELECO FT 0 0 0 0 1 4 0 1 68 DEVI TELECO DEG 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SISE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRC MWD AAPI 0 0 0 0 1 4 0 1 68 SFD2 RPT G/C3 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 ROP MWD FT/H '0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 CNF0. MWD COUN 0 0 0 0 1 4 0 1 68 CNF1 MWD COUN 0 0 0 0 1 4 0 1 68 CNN0 MWD COUN 0 0 0 0 1 4 0 1 68 CNN1 MWD COUN 0 0 0 0 1 4 0 1 68 GRA MWD AAPI 0 0 0 0 1 4 0 1 68 GRB MWD AAPI 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 GRA2 RPT AAPI 0 0 0 0 1 4 0 1 68 GRB2 RPT AAPI 0 0 0 0 1 4 0 1 68 GRC2 RPT AAPI 0 0 0 0 1 4 0 1 68 EWR2 RPT OHMM 0 0 0 0 1 4 0 1 68 RATE RPT FT/H 0 0 0 0 1 4 0 1 68 NPS2 RPT P.U. 0 0 0 0 1 4 0 1 68 NF02 RPT COUN 0 0 0 0 1 4 0 1 68 NFl2 RPT COUN 0 0 0 0 1 4 0 1 68 NN02 RPT COUN 0 0 0 0 1 4 0 1 68 NN12 RPT COUN 0 0 0 0 1 4 0 1 68 FXE2 RPT COUN 0 0 0 0 1 4 0 1 68 NPS MWD P.U. 0 0 0 0 1 4 0 1 68 SFD MWD G/C3 0 0 0 0 1 4 0 1 68 TVD CAL FT 0 0 0 0 1 4 0 1 68 NDIS TELECO FT 0 0 0 0 1 4 0 1 68 EDIS TELECO. FT 0 0 0 0 1 4 0 1 68 DEVI TELECO DEG 0 0 0 0 1 4 0 1 68 ** 1251 DATA RECORDS ** FROM 8000.00 TO 13000.00 FT ** FILE TRAILER** FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/03 MAX. RECORD LENGTH: FILE TYPE: 18 NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 89/07/03 ORIGIN OF DATA: 1825 TAPE NAME: PBU-EOA CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 89/07/03 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT