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186-119
MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~ STATE OF ALASKA ALASt OILAND GAS CONSERVATION (.,,JMMISSION WELL COMPLETION' OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED D( SERVICE [] Plugged back for redrill 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-119 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21614 4. Location of well at surface 9. Unit or Lease Name 929' SNL, 341' EWL, SEC. 19, T11N, R15E "I~~; 10.Prudh°ewell NumberBayUnit At Top Producing Interval ,1, ~~ ~ 18-14 1659'NSL, 1572' EWL, SEC. 19, T11N, R15E ~ i'~--~,¢I 11. Field and Pool At Total Depth ~ i' Prudhoe Bay Field/Prudhoe Bay Pool 1157'NSL, 1754'EWL, SEC. 19, T11N, R15E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 50' ADL 28321 '12. Date Spudded 13. DateT. D. Reached 14. Date Comp., Susp. orAband. {15. Water Depth, if offshore 116. No. of Completions 10/22/86 I 11/5/86 2/15/95 N/A feet MSL Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10075'MD/8823' TVD'18705' MD/7810'TVD YES [] NE) []I None feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/CNL/GR/SP, GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 1540 # Poleset 10-3/4" 45.5# J-55/L-80 Surface 3452' 13-1/2" 2200 sx CS 111/400 sx CS II 7-5/8" 29. 7tt L-80 Surface 9296' 9-7/8" 300 sx Class "G" 5-1/2" 17# L-80 8990' 10075' 6-3/4" 200 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) None None 8961' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9289'-9994' 115 cuft Class "G"-squeezed to 1500 psi 8705;8850' 120 SX Class "G'; squeezed to 2000 psi 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not yet on production N/A Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED M/~R 2. 0 1995 At~ska Oil & Gas Cons. Commission Anchora -- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKER. FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9313' 8281' . Base Sadlerochit 9974' 8757' RECEIVED MAR 2 0 199,5 Ataska Oil & Gas Cons. Commission 31. LIST'OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .... ~~I~ TitleDrJl/jngEngJneerSu.oervi$or Date -/'~ -//~' -?--~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1- Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 18-14 DESCRIPTION OF WORK COMPLETED PRE SIDETRACK PLUG & ABANDONMENT 2/2/95: RIH & tagged PBTD at 9994' MD. 2/3/95: -Cement was pumped fullbore to Plug & Abandon the lower wellbore prior to Sidetracking: MIRU & PT equipment. Loaded the wellbore w/Seawater & Crude, then pumped 20.5 bbls of 13.5 ppg cement down the tubing to plug the lower wellbore & abandon the perforation interval located at: 9932 - 9972' MD (Z1) Ref. Log: BHCS 11/4/86. Followed cement w/55 bbls Seawater Flush, followed by 26 bbls Crude, followed by Shutdown. Attained 1500 psi maximum squeeze pressure & placed an estimated 5 bbls cement behind pipe. Left estimated top of cement at 9230' MD. Rigged down. 2/5/95: RIH & tagged cement at 9289' MD. PT tubing to 1500 psi;bled 60 psi/30 min. RIH w/tubing cutter & cut the 3-1/2" tubing at 8928' MD. POOH w/cutter. Rigged down. 2/6/95: Circulated 363 bbls Inhibited Seawater down tubing & up IA, followed by 82 bbls Diesel cap down IA & 18 bbls Diesel cap down tubing. Rigged down. Left the lower wellbore Plugged & Abandoned w/cut tubing for Sidetracking. RECEIVED MAP, 2. 0 i995 At~ska. Oil & Gas Cons. Commission Anchor~ -. WELL: BOROUGH: DS 18-14. UN!T: NORTH SLopE FIELD: ?RUDHoE BAy L~SE PR~HoE BAy PEri T: 50 - ~PROVAL: 02113/95 (1) _TD : l o075 PB:lO038 02/14195 T,,D..:IO075 ( 2) =~:10038 02115195 (3) ?D: 8735 ~:10038 DAILy OPERATioAA~ PAGE: 1 ACCEp T: SPUD: RELEASE: OPERA TI ON: DRLG RIG: WO/c RIG. NABORs 2ES · NABORs 2ES BLEE DING DOW ?yE ~IS a~ CHEEZ R/D .2. ~U~ED ~ ~PV ~.. '~KIN TO~ ~AWATER; RU [ 8-3A TAKING ON TO PUMp OUT SHUT DOWN ANS SLIHHoLE T ~ ~U~ " ' ZPPLE U ' _TEST ~ _ P 13 -- ' ~G ~ ~GER INaCTIoN L~ IN GO0~ -' POH, ~,.. GE CHEMICAL ~z JT CHEMICAL u MILLING SEC CHEMI~,~ ~OH ~y n~'o CSs . ' ~ ~?t Z~c~.~r°~ ~ ~/~,, ~ ~ C~s ~ ~ouz~' ur ~o~~'o ?sz~s o. o , ZNSTAr.~ ._~, LOWR~ -- z-~oz, p~,.~ R RIG ~.n~ 2 JTS ~ OL UP A~ LLT~ WEAR ~..~ ~ Up~_~u~, TEe~ ~:~u~ OF .... ~'~ CUT --~ZLL R~ WI ' ,u/u Y V~L%' ~z' 0 LINE ~A ~-~u~ 0 10 0 %NG . ZCK U R SE FL N BOT ' PPG ~TUB P 3 ,, CUTTi~ _ UID yr~ TOM ~, ~ILLI~,~, - ~ 89~n, 1/2 8700 i'~ SECTIon, -~um POIN~ ~un TO 8~ FLUID ~'O 8 ~, *'' CUm ~-- ~ =ROM ~ 'uu' ~f ~POT 7oo . 3~, t uUT 7 ~/o..TM TO F= '- ~zRCU~.n~ ~ CUT .... ~o" CA~_ -- TO 6~ _ ~U~LL SECTION RECEIVED MAR 20 1995 A.laska Oil & Gas Cons. Commission Anchor~ · WELL : DS 18-14 OPE~%,TION:~ RIG : NABORS 2ES PAGE: 2 02/16/95 (4) TD: 8500 PB: 8750 02/17/95 ( 5) TD: 8900 PB: 7962 02/18/95 (6) TD: 9407 PB: 8335 PICK UP KICK OFF BHA MW: 0.0 CONTINUE CUTTING SECTION 8735-8750' - 595AL 50' 7-5/8 CASING CUT OUT. CIRC 20 BBL OF LOW VISC SWEEP @ 385 BPM 3200 PSI - MONITOR WELL - WELLSTABLE - PUMP SLUG. POOH - LAY DOWN JARS & DC - LAY DOWN SECTION MILL. MAKE UP 3-11/2" MULE SHOE - TIH WITH OPEN ENDED DRIPP PIPE. WASH 8694-8850'. CBU AND BALANCE MUD WT. @ 10.0 PPG. SPOT BALANCE CMT PLUG - 120 SC CLASS G W/.15% FL-52 + .8% CD-32 + .08% A-2 + .5 GHS FP-12L MIXED @ 17.0 PPG - 20 BBL CMT SLURRY PUMPED 10 BBL WATER AHEAD - 2 BBL WATER BEHIND - CIP @ 2012 HRS. POOH 12 STANDS - EST TOP CMT 8500'. CIRC 1 DP VOL. LONG WAY - CLOSE RAMS & AND HESITATE SQUEEZE CMT. - PRESSURE UP TO 2000 PSI WITH 3 BBL OF FLUID PUMP - HOLD PRES FOR 1 HR - PRESSURE @ 1650 PSI AFTER 1 HR - BLED OFF PRES - APPROX 3 BBL FLUID BACK. PUMP SLUG - POOH - L/D 49 JTS 3-1/2" DP. PULL WEAR BUSHING - WASH OUT BOP STACK - INSTALL TEST PLUG. TEST BOP: TEST ALL RAMS, LINES AN VALVE TO 250/5000 PSI - TEST HYDRIL TO 250/2750 PSI - TEST KELLYU, LOWER & UPPER KELLY VALVE AND TIW VALVE TO 250/5000 - ALL OK - TEST WITNESS WAIVED BY DOUG AMOS OF AOGCC - INSTALL WEAR BUSHING. PICK UP KICK OFF BHA. DRLG MW: 0.0 CONTINUE P/U KICK-OFF BHA - TEST MWD. TIH WITH 3-1/2" DP. SLIP & CUT DRILL LINE. CONTINUE TIH WITH DP - TRIP SLOW DUE TO HIGH WIND. PICK UP KELLY AT 8463' - WASH DOWN TAG FIRM CMT @ 8620' - CLEAN OUT CMT 8620-8702' - ROP 70 TO 120 FT/HR. CHANGE SHAKER SCREENS TO PREVENT MUD LOSS - CIRC BOTTOMS UP. ORIENT & KICK OFF TO LEFT - SLIDE 8702-8750' ROP 5-7 FT/HR BOTTOM OF WINDOW @ 8750' DRL 8750-8900' - ROP 15'/HR SLIDING - 20'/HR ROTATING S~Y AT 8847' 38.4 DG INCLINATION - NO DIRECTION DUE TO METAL INTERFERENCE. DRILLING MW: 0.0 DRILL 8900-9407' M~ - BUILD ANGLE AND TURN TO LEFT - DIRECTIONAL AZIMUTH SVY IS NOT VALID DUE TO METAL INTERFERENCE - TROUBLE BUILDING AND MAINTAINING ANGLE 8900-9200' - SLIDING WITH LITTLE REACTION - PUMP LOW VISCOSITY SWEEPS EVERY 4 HRS TO HELP HOLE CLEANING. ~, 2. 0 '~99b Oil & Gas Cons. Gomm'~ssion Anchorz ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging X Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other X Plugback for Redrill 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 929'FNL, 341'FWL, Sec. 19, T11N, R15E At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E At effective depth 1183'FSL, 1744'FWL, Sec. 19, T11N, R15E At total depth 1157 " FSL, 1754' FWL, Sec. 19, T11N, R15 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service JAN 20 't995 Oit & Gas Cons. Commission Anch0rz '~ 6. Datum elevation (DF or KB) 5O RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-14 9. Permit number 86-119/90- 703 10. APl number 50- 029-21614 11. Field/Pool Prudhoe Bay Field~Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10075 feet Plugs (measured) 8823 feet 10038 feet Junk (measured) 8799 feet Length Size Cemented Measured depth 80 16 1540# Poleset 115' 3402 10-3/4" 22oo sx cs ~/~ & 4oo sx cs 1~ 3452' 9246 7-5/8" 350 sx CI 'G' 9296' 1085 5-1/2" 200 sx CI 'G' 10075' measured 9932- 9942', 9942- 9972' ORIGINAL True vertical depth 115' 3452' 8268' 8823' true vertical 8649 - 8675', 8675- 8755' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80, PCT w/tail at 9050' MD Packers and SSSV (type and measured depth) Baker FB-1 packer at 8950' MD; Otis 3-1/2" FMX SSSV at 2007' MD 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is tr e and correct to the best of my knowledge. Signed /~¢I ¢ ~ Title Drilling Engineer Supervisor - ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ? BOP Test Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- Jl/~ Original Signea Bt, Approved by order of the Commission David W. Johnston Date/-/~" f~ J Approva_l N..o. Approved C py ~.s'--- ~eturngcJ, Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE -'~, BP EXPLORATION ARCO Alaska, Inc. To:. From' Subject' AOGCC Zeljko Runje Prudhoe Bay Drilling MB 12-1 Plug and Abandonment of Well DS 18-14 January 3, 1995 o Pre-rig work: Cut the 3-1/2" tubing as close to the packer as possible. KOP will be at 8700' MD so it will have to be cut @ 8925' MD Kill the well, freeze proteCt and set a BPV. Test intermediate casing pack-off to 5000 psi. 2. Move in drilling rig. Test 7-5/8" intermediate casing pack-off if not done during pre-rig work. 3. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. 4. Install a BPV and test tree plug. Remove the production tree. 5. Install BOP's and test to 5000 psi. Remove the test plug and BPV. 6. Pull and lay down the 3-1/2" tubing from top of fish to surface. ( Chemical injection line must be handled and disposed of carefully ) 7. P/U bridge plug. RIH and set it at 8900' (~ 200' below proposed 7-5/8 section). P&A well by using down squeeze method as follows' a, Establish injection rate prior to pumping cement Pump total of 11 bbls of P & A cement Unsting out of bridge plug and POOH. The objective of this P & A is: ac b. pared bY:Drilling~ E~~ BP Exploration (Alaska), Inc. Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 Squeeze away 2.38 bbls of cement slurry ( 2.38 bbls = rathole volume ) Cover up perfs and up to 100' MD above the perfs ( 5.6 bbls ) Will pupm 30% of excess ( 2.38 bbls ) Total of 11 bbls of slurry -- JAN 2~ 0 ~995 ~,,,~s~,a ~ & Gas Cons. commiss'ton Anchors Co-Operators, Prudhoe Bay Unit ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 Well:IS-lA Spud Date:10/28/86 Original RKBE:50' Top of Formation: 9313' Annular Fluid:6.8 Diesel/8.5 SW Reference Log:BHCS Date:il/4/86 CO Alaska, Inc. - Pruclhoe --""y API %: 50-029-21614-00- Completion: 10/9/90 Hanger TYlOe: FMC Gert IV Max Hole Angle: 48° @ MD: 10000' Tie In: Type:PRODUCER Status:Workover Hanger:26' Angle @ TS:40° Angle @ TD:49° Date: 00/00/00 ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) Depth Description 1 2007 J-1 2 8943 3 8950 4 9038 5 9049 6 9050 ,O-1 7 9050 9046 G-1 3-1/2" Otis FMX TRSV SSSV Nipple ID=2.813" 3-1/2" Baker Locator Seal Assembly 7-5/8" x 3-1/2" Baker F-1 Production Packer 3-1/2" Otis XN No-Go Nipple ID=2.75" 3-1/2" Baker Shearout Sub 3-1/2" W/L Re-entry Guide 3-1/2" Tubing Tail ELM Tubing Tail (Logged 10/10/90) Min ID: 3-1/2" Otis XN No-Go Nipple ID=2.75" I-1 J-2 J-3 J-4 J-5 J-6,7 Casing and Tubing (C) Size weight Grade 1 10-3/4" 45.5% L-80 2 7-5/8" 29.7% L-80 3 5-1/2" 17# L-80 3-1/2" 9.39 L-80 ToD Bottom Description 0' 3423' Casing 0' 9296' Casing 8990' 10075' Liner 0' 9050' Tubing-IPC Gas Lift Information (G) MD TVD Stn Mandrel Valve 3552' (3552') 1 CA-KBUG CA 6043' (5824') 2 CA-KBUG CA 8040' (7292') 3 CA-KBUG CA 8719' (7821') 4 CA-KBUG CA T~e BK BKO-3 E EKED valve Type CA CEV C-2 Chemical Injection Information (I) MD TVD Stn Mandrel 8836' (7913') 1 CA-KBUG Latch Port TRO Date BK-2 1/4" 1700 BK-2 5/16" ORIF BK-2 INTEGRAL Latch Port TRO Date BK-2 1/8" 3000 10/27/90 P-1 Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF 1 9932- 9942 IA 10 6 9942- 9972 iA I 30 10 Date Comments 12/08/89 RPERF 10/05/90 RPERF FRAC 10/12/90 BALL SEALER TREATMENT 10/10/90 Datum 8600' SS= 9815' MD PBTD=10038' 8700' SS= 9963' MD TD=10075' Revision Date: 05/21/93 by PTB Reason: 4D CONVERSION Previous Reason: 03/13/91 0-3 Well 18-14 Gas Cons. Commission Anchor~- ARCO AlASkA, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-17-92 REFERENCE: A~ -',O MAGNETIC TAPE(S)WITH LISTINGS Please sign and return the attached copy as receipt of data. RECEIVED BY ~____~ Have A Nice Day! ' Sonya WAll~ ce APPROVED__, ATO-1529 Trans# 92156 Sch # CENTRAL FILES (CH) CHEVRON D&'M D SCHWARTZ (OH/GCT] # EXXON MARATHON MOBIl. # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ,~IASKA TEXACO RECEIVED AUG 0 ~ 1992 Alaska Oil & Gas Cons. Commission Anchorage P.O.Box 10(L360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS £~_?' ~4-7 / 2-7-92 USIT-Cement ~ L4-7 - 2-7-92 USIT-Corrosion ~ 5-6 ~/ 2-11-92 Collar-Perf ?o~ >~ 9-44 / 2-12-92 Collar-Perf ~> ** 11-3A J 2-9-92 CNL z~ t 13-25 ~ 2-22-92 CCL (Peri) fz~l f14-5A ~ 2-9-92 CNL 14-5A ~ 2-10-92 Collar-Peri ~//~ 18-14 ~/ 2-20-92 Dual Burst TDTP Color Run 2, 5" Run 2, 5" Run 1, 5" R.n 1, 5" Rim 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Rl~_n 1, 5" Please sign and return the attached copy as receipt of data~ RECEIVED BY ~~' Have A Nice Day~ Sonya Wallace ATO-1529 Sch Sch Arias Sch Sch Sch # CENTRAL FTTF-S # CHEVRON D&M # EXTENSION EXPLORATION # EXXON. MARATHON # MOBIL # PT~-T.TPS PB WELL FILF~ R&D #BPX # STATE OF ALASKA TEXACO ** The correct API# for 11-3A is 50-029-20666-01. RECEIVED MAR 1 2. 1992. Alaska Oil & Ga~ Cons. Commission Anchorage ARCO ALASKA, INC. F'.O. BOX ~OO~60 ANCHORAGE, ALASKA 99510 DATE: 7-26-9~ REFERENCE: ARCO CASED HOLE FINALS t-tO 6-26-9~ PROD PROFILE 2-t2 6-29-9t PROD PROFILE :3-33 6-26-9i PROD F'ROFILE 9-0 6-i9-9i LEAK DETECT ~'~/~9-38__..._ 7-t-9t INJ PROF"I'LE ~'~/0' I ~.~-44 6-t 9-9t F'ERF RECORD J2-3 6-t5-9J COLLAR LOCATOR ~ 4-3~ 6-~ 5-9~ PERF LOG J 4-37 6-~ o-gJ F'IT$ ~5-6 6-28-9t PITS ~ 8-t 4 6-24-9~ PITS RUN t, 5" RUN t, 5" RUN t, 2"&5" RUN t, 5" RUN t, 5" RUN t, 5" RUN RUN t, 5' RUN J, 5' RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COPY A3' RECEIF'T OF DATA. HAVE A NICE DAY! $ONYA WALLACE AT0-t529 AFiPROVED TRAN$$ 9t~27 CAMCO CAMCO CAMCO CAMCO CAMCO HL$ HL$ HLS HR$ CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL ~ F'HILLIF'~ F'B WELL F'ILES R & D .I. ~ BF'X STATE OF' ALA~KA TEXACO RECEIVED './gL £ 9 1991 · 41a~ka Oil ~ ~as Cons. Anchorage Commission !::' F;.: (:) ':.:') L.:.; C 'i" :i: (:)i".i J::' F;.: {Z)F' :iZ i... iii: r" r",. ~ ,.', i:;, ," ~::, ~::' ~:;, ~::' :...:...'~...M. "~ ..." i ~..., ..~ ]: N,..i F:' F;.: (:)F' ]: i... iii: (.]: t)i.., i... A .:;.: ,." F:' iii: F;.: F:' i::' F;.: (:).()(.J (::: ']" ;{: (:)N i::' i:;.'. C)i::' ]: L. iii: ']" iii H F:' iii: F;.: A 'f'~,..:,~i:;'..,..~::' ~ !: ' i':" i.." "':, i':' 'T' r" .-'". '] ....... i ;; i ... ~... "i: '.. .b' ~:.. i:;. L.. .t. ,..., F'.. :i: N-...i F:' F;:. Ei F:' :[ i... ii-" ,;::' ,i:;'..... ,.,r"¢ i"... i,., i ~:::: T ]: f"i ,,:i'..~ F:' ¢:;', ..."' F:' ]: i... iii: · ' i'.j ~ i::, ': '"i '"::' ': i r" .L ¢-. -,..: :. ~ :..'...- I .~ ..... i... iii; ¢'.'~ K :i::, iii: 'i" iii: E: 'i" ]: 0 N .,'"i i ' (". i:', ," ::, E:' i", C :.: ,._ L. .--~ -.. '.. ., J ,...r'.., i::' J:-:..' 0 iO(J. :...r" ]." .]: 0 J"i j::' fL' .... F'i j::' :j: ,... ,...i ,..~ ii!; t,'.J iii; L. F;..' Y i::' i:L: (:) lC, LJ '.:.': "i" :j: Ci J"'-i F:' i:;-.' 0 J::' ]: i... Iii: i::' iR: C))} t.J (3 "f' :[ (] N F:' t:;; (:)F:' ]: L.. E F:' F;: ]: ,'.;:.: hi A N A L.. '¥' ;i¢ ]: i... E R K ):::' iii: 7' r..:.: C'f' :i: C) N L. iii: ,~':'~ K :(';, iii: ","' E E:'f' ]: C',' F' F;,' Ci );) i..,..j r': T.,.'r (] N F:' i:;,,,.Ci F :[ ,... ,_~ t::' F;.: i!i: E: iii; :i: V iii;).?,' :(-2.: Y .... :.,~~ .............. H ~'.":; V iii: r:':'~ i'"'," :i:,...:...r' ~::' :C, A Y ~ ,? i..i ~':'-'; F;.: (] N i,,..1 :i; L.,? (;) N ¢',T() .... i5:29 ', C: ',4 ~ STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC AISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, T11 N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, TllN, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 50 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 18-14 9. Permit number/approval number 86-119/90-703 10. APl number 50 - 029-21614 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10075 feet Plugs(measured) 8823 feet Effective depth: measured 10038 feet true vertical 8799 feet Junk(measured) Casing Length Size Cemented Conductor 80' 16" 1540# Poleset Surface 3402' 10-3/4" 2200 sx CS III & 400 sx CS II Production 9246' 7-5/8" 350 sx CI 'G' Liner 1085' 5-1/2" 200 sx CI 'G' Perforation depth: measured 9932-9942'; 9942-9972' true vertical 8649-8675'; 8675-8755' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, PCT w/tail @ 9050' MD Measured depth True vertical depth 115' 115' 3452' 3452' 9296' 8268' 10075' 8823' RECEIVED DEC 2 o l~O ,~Jas, Na;Ojl & Gas Cons. ¢0mmissi0~ Packers and SSSV (type and measured depth) Baker FB-1 packer @ 8950' MD; Otis 3-1/2" FMX SSSV @ 2007' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ecti0n Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in. 2141 19567 0 Tubing Pressure 711 15. Attachments Copies of Logs and Surveys run Daily RepOrt of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service, . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE DS 18-14 FRACTURE TREATMENT OF ZONE 1 DESCRIPTION OF WORK COMPLETED 10/10/90: MIRU & PT CT to 5500 psi. perforations at: 9932 - 9942' MD 9942 - 9972' MD Pumped a Perforation Breakdown Treatment through Ref. Log: BHCS 11/4/86. Pumped: a) 150 bbls Seawater w/Surfactant & 250 Ball Sealers, followed by b) 98 bbls Slickwater Flush, @ 15 bpm, followed by c) Shutdown. ISIP @ 1700. Surged well twice to unseat balls, & resumed pumping: d) 102 bbls Slickwater, @ 15 bpm, followed by e) Shutdown. ISIP @ 1700. Ran Temperature Log. Rigged down. 10/12/90: MIRU, & PT equipment to 10000 psi. Pumped a propped fracture treatment through open perforations at: 9932 - 9942' MD Ref. Log: BHCS 11/4/86. · 9942 - 9972' MD Surged well, then pumped: a) 100 bbls 40# Gelled Pre Pad, @ 20 bpm, followed by b) Shutdown. ISIP @ 1680. Resumed pumping: c) 280 bbls Cross Linked Pad, @ 20 bpm, followed by d) 140 bbls Slurry w/proppant concentrations of 2 to 12 ppg, followed by e) 97 bbls 40# Gelled Flush, followed by f) Shutdown. Placed a total of 30,500 lbs of proppant into the formation. Rigged down. 10/13/90: Replaced DG LV's w/LG LV's. Returned well to production, and obtained a valid production test. ARCO AL. ASKA, INC, !::'~0~ BOX tGOS6(~ A N C HC)I::.:A[~.E, A I... A,S'I( A 9 9'.:, I)AI"E ' t t-'2-'9(') F:tE F' E F:-: E N E: E ' A I'R C 0 C A $ Iii] D H (] I.. Iii] F:' i N A L. $ F:' L. IE A 3' E ,.S' I [.; N "~' .... ' ....................... "~ ......... ~..~ I ,~ i.~ I"~ [:. I t...~ Kli'~ ,,,t 'l~li:,= ~'~,-i J ! ~-'~L. I"1 I::. ~.) I"~ I:: .... b. I ¥ li!] D D Y t.-i A V [.ii A N I E:IE I) A Y. ' & (las Cons. Commission Anchorage ,::.':" ~-.~ I...,...'"" ~ '"~ i.....ri F:' F:' Ii!: E: t< Iii: A 'f' 0 .... ,i, _;. ,:..':-:' ":, (;:,, C [)I::'Y A S R E [; E I F' l' [.'iF' I) A T A. A F:' F' F:..' [) V Iii] i) ~:,~4'~'....'~ 'i"R ANS :,~: C A M C [J [;A M C [) C A f,"i C 0 i) I S i' F.: I D !. "f' ]] r3 N '"' C E N'!" F:..' A 1.. I::' ! L.. E S ~" C t"1 Ii.". V F..' 0 N !} ,:"!,: H -,,."" E X ]" [..il N ;};.: ]1 f').. N E X F' i... 0 F;.: A i" I [) i',.l.. '"' E X X 0 N hi R F;.: A T H [) N :ii: H (3)3 ! i._ STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMIS,~ION REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Operation Shutdown__ Alter casing __ Repair well Stimulate __ Plugging __ Re-Perforate X X Pull tubing X Other X Workover 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, T11N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, T11N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11N, R15E, UM 6. Datum elevation (DF or KB) 50' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 1~-14 feet 9. Permit number/approval number 86-119 / 90-740 10. APl number 50-029-21 61 4 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 10O75' 8823' feet feet Plugs (measured) None Effective depth: measured 1 0038' true vertical 8799' feet feet Junk (measured) None Casing Length Size Conductor 8 0' 1 6" Surface 3423' 1 0-3/4" Intermediate 92 96' 7 - 5 / 8" Liner 1 085' 5-1/2" Perforation depth: measured 9932'-9972' Cemented 1540# Poleset 2200 sx CS III & 400 sx CS II 350 sx Class G & 300 sx AS I 200 sx Class G Measureddepth True ve~icaldepth 115' 115' 3452' 3452' 9296' 8268' 8990'-10075' 8043'-8823' true vertical 8729'-8756' 13. Tubing (size, grade, and measured depth) 3-1/2", L-80, tbg w/tail @ 9050' Packers and SSSV (type and measured depth) Otis 'FMX' sssv @ 2007', Baker 'F-I' pkr @ 8950' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED .Oil & Gas Co~s. ~.t~issiO_[l ', Anchora~ 14. N/A Prior to well operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *Workover Well History Copies of Logs and Surveys run __ Daily Report of Well Operations X* 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 ~)~ev 05/17/89 Title Drillincj Analyst Date SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field PRUDHOE NAY Auth. or W,O. no._.-,,.,..,. ICounty, parish or borough NORTH SLOPE ILease or Unit ADL: 28321 ITitle WORKOVER lState AK API: 50-029-21614 Operator ARCO Spudded or W.OA~pT JARCO W.I 21.0000 Date 9/25/90 Hour 2100 HRS Date and depth as of 8:00 a.m. 09/26/90 ( TD: 0 Complete record for each day reported A[~3I 4 2 ) NU BOP. RU FLANGES. 5-1/2"@10075' MW: 8.5 Seawater HOOK UP TO KILL WELL. PULL BPV. BLEED GAS TO PB:10038 SUPV:DRU 09/27/90 ( TD: 0 PB:10038 SUPV:RWO 09/28/90 ( 'TD: 0 PB:10038 SUPV:RWO 09/29/90 ( TD: 0 PB:10038 SUPV:RWO RECEIVED 09/30/90 ( TD: 0 PB:10038 SUPV:RWO 3) 4) 5) 300#. PUMP OPEN SSSV. KILL WELL W/ 407 BBLS 8.5# SEAWATER. UNABLE TO PUMP INTO FORMATION W/ 1500#. OBSERVE WELL. SET BPV. ND TREE. NU BOP. RIG ACCEPTED AT 2100 HRS, 9/25/90. DAILY:S52,452 CUM:$52,452 ETD:SO EFC:$816,452 RIH W/ 3-1/2" DRILL PIPE. 5-1/2"@10075' MW: 8.5 Seawater N/U BOP'S. PULL BPV. INSTALL TEST PLUG. TEST BOP'S. PULL TEST PLUG. M/U LANDING JT. BOLDS. PULL TBG FREE W/ 75,000#. PULL HGR TO FLOOR. L/D HGR AND LANDING JT. CPU W/ 8.6'PPG SEAWATER. POOH L/D 3-1/2" TBG AND COMP EQUIP. R/U FLOOR TO P/U 3-1/2" DP. SET WEAR BUSHING. STRAP AND M/U BHA #1 W/ 3-1/2" DP. DAILY:S27,056 CUM:$79,508 ETD:SO EFC:$843,508 POOH. 5-1/2"@10075' MW: 8.5 Seawater RIH W/ 3-1/2" DP. CUT LIP GUIDE ON OVERSHOT HANGING ON CSG COLLAR. RIH W/ 3-1/2" DP. SLM. TAG PBR AT 8923' WORK OVERSHOT OVER FISH TO 8927'. PULL UP TO 175K# TO SET GRAFFLE. S/O TO 130K#. ROTATE OUT CH-ANCHOR W/ 17 TURNS. POOH. LAY DOWN FISH AND BHA #1. STRAP AND M/U BHA #2. RIH W/ 3-1/2" DP. P/U KELLY. TAG PKR AT 8937'. MILL ON PKR TO 8939'. RELEASE GRAFFLE. POOH W/ MILL AND PRT. DAILY:S27,952 CUM:$107,460 ETD:SO EFC:$871,460 POOH. 5-1/2"@10075' MW: 8.5 Seawater POOH W/ MILL AND PRT. L/D BHA #2. JUNK BASKET FULL OF METAL. STRAP AND M/U BHA #3 W/ 6-1/2" MILL AND PRT. RIH W/ 3-1/2" DP. TAG PKR AT 8939'. MILL ON PKR F/ 8939' TO 8940' CHASE DOWN HOLE TO 8950'. CBU. OBSERVE WELL. WELL STATIC. POOH. L/D BHA #3. NO RECOVERY OF FISH. STRAP AND M/U BHA #4. RIH. SLIP AND CUT DRLG LINE. RIH AND TAG FISH AT 8967'. SPEAR INTO FISH. POOH. FISH HANGING UP IN COLLARS. DAILY:S26,572 CUM:$134,032 ETD:SO EFC:$898,032 MILL ON JUNK. 5-1/2"@10075' MW: 8.5 Seawater POOH. L/D BHA #4 AND FISH (7-5/8" BDT PKR). RIH W/ 4-3/4" DC. L/D SAME. STRAP AND M/U BHA #5. RIH. TAG TOP OF LINER AT 8988' COULD NO WORK THROUGH P/U KELLY AND ATTEMPT TO WASH AND ROT. NO SUCCESS. POOH. L/D 4-3/4" MILL. STRAP AND M/U 4-5/8" MILL. RIH AND TAG FILL AT 9910'. P/U KELLY. WASH AND MILL ON JUNK F/ 9940' TO 9947' DAILY:S27,826 CUM:$161,858 ETD:SO EFC:$925,858 The above is correct For for~ preparatio~"and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 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 a;I 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 Irequently 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 ARCO ALASKA INC. County or Parish NORTH SLOPE Field Lease or Unit PRUDHOE BAY DS 18-14 Date and depti~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. AUDI 4 7 IState AK Well no. 10/01/90 ( TD: 0 PB:10038 SUPV:RWO 10/02/90 ( TD: 0 PB:10038 SUPV:RWO 10/03/90 ( 9 TD: 0 PB:10038 SUPV:RWO 10/04/90 ( 10 TD: 0 PB:10038 SUPV:HMP 10/05/90 ( 11 TD: 0 PB:10038 SUPV:HMP 10/06/90 ( 12 TD: 0 PB:10038 SUPV:HMP The a'dove is correct M/U RTTS ADN RIH. 5-1/2"@10075' MW: 8.5 Seawater WASH AND ROT ON JUNK AND FILL F/ 9947' TO 10030'. P~ 50 BBL HEC SWEEP. CBU TWICE W/ 2 HEC 50 BBL PILLS. POOH. L/D 34 JTS 3-1/2" DP. STAND PIPE IN DERRICK. M/U 5'1/2" RTTS AND RIH. DAILY:S29,544 CUM:$191,402 ETD:SO EFC:$955,402 POOH W/ RTTS 5-1/2"@10075' MW: 8.5 Seawater RIH W/ 5-1/2" RTTS. POOH. RIH W/ BIT, TAGGED FILL @ 10022' WASH & REAM TO 10030'. CBU, PUMP 50 BBL HEC PILL, CBU. POOH. RIH W/ 5-1/2" RTTS. SET RTTS @ 9903', ATTEMPT TO TEST ANNULUS, BLED OFF 500 PSI. RESET RTTS @ 9899', BLED GFF 500 PSI. UNSET RTTS & POOH, RTTS NOT SETTING PROPERLY. DAILY:S48,619 CUM:$240,021 ETD:S240,021 EFC:$764,000 LOCATING DRILL PIPE WASHOUT 5-1/2"@10075' MW: 8.5 Seawater RESET RTTS @ 9867', ATTEMPT TO TEST ANNULUS, BLED OFF 500 PSI, HAD RETURNS UP DRILL PIPE. RELEASE RTTS & POOH. REDRESS RTTS & RIH TO 7847' TESTING EVERY 10 STDS. LOCATE DRILL PIPE WASHOUT BETWEEN 6208'-6396', L/D STDS # 54 & 55. DAILY:S27,540 CUM:$267,561 ETD:S267,561 EFC:$764,000 RIH W/REP AND TEST PKR 5-1/2"@10075' MW: 8.5 Seawater POOH AND TSTD DP FOR LEAKS. NO LEAK FOUND. RIH W/2-7/8" DP AND 3-1/8" DC. TSTD TO 2800 PSI. POOH. PU 5-1/2" RBP AND 7-5/8" RETRIEVAMATIC. RIH. DAILY:S32,014 CUM:$299,575 ETD:SO EFC:$1,063,575 MAKING PERF RUN #2 5-1/2"@10075' MW: 8.5 Seawater CONTINUE RIH W/RBP. SET AND RELEASE F/SAME. TEST CASING 3000 PSI. OK. POOH LDDP. RU SHOOTING FLANGE. R/U WESTERN ATLAS. RIH W/ 3-3/8" PERF GUN. PERF F/ 9942' TO 9972' W/ 4SPF, 180 DEG PHASING. DAILY:S34,838 CUM:$334,413 ETD:S334,413 EFC:$764,000 RUNNING 3-1/2" COMPLETION 5-1/2"@10075' MW: 8.5 Seawater POOH W/ PERF GUN. RUN GAUGE RING / JUNK BASKET TO TOL @ 8992'. M/U BAKER PACKER & TAIL PIPE ASSEMBLY. RIH & SET PACKER @ 8950' R/D ATLAS WIRELINE. R/U AND RUN 3-1/2" COMPLETION ASSEMBLY. DAILY:S179,419 CUM:$513,832 ETD:S513,832 EFC:$764,000 For form prepa~ati~-n and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supt. ARCO Oil ann 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. Field PRUDHOE BAY Auth. or W.O. no, AS3897 I Accounting District County or Parish lState ARCO ALASKA INC. I NORTH SLOPE ! I tease or Unit I ADL: 28321 I Title I WORKOVER cost center code I Well no, DS 18-14 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as ot 8:00 a.m. 10/07/90 ( 13: TD: 0 PB:10038 SUPV:HMP API: 50-029-21614 A.R.Co. W.I, rTotal number of wells (active or inactive) on this Icost center prior to plugging and I 21. 0000 labandonment of this well Date IHour I Prior status if a W,O. 9/25/90 I 2100 ERS iComplete record for each day reported AUDI 4 RIG RELEASED @ 22:00 HRS 5-1/2"@10075' MW: 8.5 Seawater SERVICE RIG. FIN RNG 3-1/2" COMPLETION. STING INTO PACKER & VERIFIED. P/U & FREZZED PROTECTED W/ 150 BBLS DIESEL W/ INHIBITOR. LAND TBG & RILDS. TEST TBG TO 3800 PSI FOR 30 MIN, TEST ANNULUS TO 3000 PSI FOR 30 MIN. SET BPV. N/D BOPS, N/U TREE. TEST CIM & SSSV LINES TO 5000. TEST TBG HGR PACKOFF TO 5000 PSI. TEST TREE TO 5000 PSI. PRESSURE UP ANNULUS TO 1000 PSI, PRESSURE TBG TO 3900 PSI AND SHEARED SHEAR OUT SUB. BLED OFF PRESSURES. SET BPV. SECURE WELL. RELEASED RIG @ 22:00 HRS 10/6/90. 3-1/2" OTIS "FMX" SSSV @ 2007', BAKER "F-I" PKR @ 8950', 3-1/2" OTIS "XN" NIPPLE @ 9038', END OF TBG TAIL @ 9050' DAILY:S61,382 CUM:$575,214 ETD:S575,214 EFC:$764,000 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method PB Depth K nd of r g IType completion (single, dual, etc.) IOfficial reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on lest Gas per day '~ump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sign% ~,~ i'~ I~a~ \~(.C~ ITM , Drillinfl Supt, For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO ALASKA, INC. P.O. BOX t00,560 ANCHORAGE, ALASKA 995t0 DATE' ~ 0-4 9-98 REFERENCE' ARCO CASED HOLE FINAL2 ~-5 9-9-90 PERF RUN ~ , 5' 2-4 8-t6-90 PERF RECORD RUN t, 5' * S-25 ~¢-~i-90 COLLAR/F'ERF' RUN t , 5' 5-5 9-t -90 PERF RECORD RUN 9-44 ~-~-9~ COLLAR RUN ~, 5" ~ ~-22 9-7-9~ PERF RUN ~, 5' *~ ~_ ~-8B ~ ~-7-.9~ COLLAR/PERF' RUN ~4-S4 ~0-~-90 PERF RECORD RUN ~ 5-6 ~ 0-4-9~ CCL RUN ~ 5-6 ~ ~-~ 2-9~ VERTILOG RUN ~-~ ~O-~A c~ PERF RECORD RUN ~ 8-~ 4 ~ ,3,-4-.~0 COLLAR/PERF RUN ~8-~4 ~ 0-4-90 PRODUCTION PACKER RUN PLEA.'i."E ,".¢I6N AND RETURN THE ATTACHED COF'Y AS RECEIF'T OF:' DATA., HAVE A N I £'ALI_Y FtO F" F EC::I<; E R ATO-t 529 ' AF'F'F;:.OVE D ~ TRAN,.,.~ 9,'.~4 O,:D' HL$ I-.IL~ ATLA,¥ HL$ ATLA2 I--tL2 A'f'LA:7 A'I'LA~' ATLA2 2CH A 'fLA.? A '1' L A._',:: D i 3'TR I BUT ]: ON ~ CENTRAl_ FI!_E2 41-' C H IF. V R O N D & M ~,.~ EXTEN2Ir~N_ EXPLORATION · ~, EXXON MAF;:A'f'I-~O N ~ HOB I L RECEIVED "" F'H :[ L. L. Z P ~'' PB WELL F'IL .~, 2 '~ 1990 R & D ~ B F: X Alaska 0ii & Gas Cons. Commission ¢ 2 T ATE 0 F ¢~ L A '~:' I??h°rage I"EXACO * THE AF'I~: FOR 23-25 *:~ THE COITRECTED WELL NUMBER FOR THIs* L t2-8, THE AF'I¢ CORRECT A2 I2 i::' ,. 0 ~ ii: 0 iX i ,3,':'::, S 6 ':b A N (2: H .) F:A G E, ?3 L A £ K A 9 9'::; i (:;, F'WDW i ....2,.'-~ 9---":,2(-)'-.-9(-) F:' W ii:) W i .... 2 A 9'-' 2 2 .... '.:.,' (-) HAVE A N'J:Cii.' DAY! S A L.. L.. '( Fi 0 F:' F' i!i:-,':.'.' i-.':.' E P. ATO-~ ":::--29 D I S I' R I B U Z ]: 0 N · ,,-'"' C': i!i: N T F;:. A i... F' .,.'r i._ E S · :'. K: H i::' V F: Fi N b & M -,.'"'~:_'X"-',"[:.:i"-i$ I ~"'~i"--~.. . EXF:'LOF;.'.AT I F~N_ . :,"; E X X 0 N MARATHON .. :~.' M 0 B I L F't-I 'r ~ i T F:' S F:' l'-:: H iii: L.t... F ]: i... E i:;.: ,t-. b :il: .BPX ;}?-I'A'!'E ("iF AL_A£'KA T E X n C.'.' (] RECEIVED OCT 1 9 lg90 Alaaka 011 & a~s Con~. Commission Anchorage STATE OF ALASKA ALAbr,,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska, Inc... 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate X Other .~. 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, T11N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, T11N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11 N, R15E, UM 6. Datum elevation (DF or KB) RKB 50' 7. Unit or Property name Prudhoe Bay Unit f~t 8. Well number 18-14 9. Permit number 86-119 10. APl number 50-029-21 61 4 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 1 0075' feet Plugs (measured) None 8823' feet Effective depth: measured 1 0038' feet Junk (measured) None true vertical 8 7 9 9' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 1 6" 1540# Poleset 1 1 5' 11 5' Surface 3423' 1 0-3/4" 2200 sx CS III & 3452' 3452' 400 sx CS II Intermediate 9296' 7-5/8" 350 sx Class G & 9296' 8268' 300 sx AS I Liner 1085' 5- 1/2" 200 sx Class G 8~1~.. j,~ ~,,7~;~, f~;'-8823' Perforation depth: measured 9 932'- 9 972' KEI .EIV true vertical 872 9'-8 75 6' S E P 1 1 1990 Tubing (size, grade, and measured depth) 3-1/2" L-S0, tbg w/tail @ 9048' ~J~,OJ~ & Gas Coils. GOmtl[t[SS[Ot't , , ,mchorage Packers and SSSV (type and measured depth) Camco 'TRDP' sssv @ 2249', Brown '4H' pkr @ 8961' 13. A~achments Description summary of proposal Detailed operation program _ BOP sketch .~X 14. Estimated date for commencing operation 9/20/90 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best 15. Status of well classification as: Oil X Gas __ Suspended _ Service of my knowledge.~__~__~~'2) ISis]ned ~(~~ ~~~ Title Drillin~l Analyst FOR COMMISSION USE ONLY I Conditions~of approval: Notify Commission so representative may witness Date Plug integrity_ Mechanical Integrity Test BOP Test Location clearance _ Subsequent form require 10-z~~+ Approved by the order of the Commission Commissioner IApproval No. , Date ~.// . .~9~ Form 10-403 Rev 0~l~/r~ed Copy ORIGINAL SIGNED BY IONNIE C. SMITH SUBMIT IN TRIPLICATE PRIOR TO RIG 1. Rig up E-Line. RIG PROCEDURE . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. DS 18-14 WORKOVER SUMMARY RIH, shoot circulating holes at 8940'MD. Rig down E-Line. MIRU workover rig. Pull BPV. Circulate seawater around. Kill well with seawater and by bullheading if required. Pump HEC pills as necessary to control fluid loss. Set BPV. Nipple down tree. Nipple up and test BOP. Test surface casing packoff to 1500 psi, test 7-5/8" packoff to 3800 psi. Pull BPV. Pull and lay down 3-1/2" tubing. Tubing seals have been sheared. RIH with overshot and retrieve PBR and K-Anchor. RIH with mill and PRT. Mill over and retrieve packer/tailpipe assembly. RIH with mill and clean out to PBTD at 10038' MD.~ ??~ ~. ??~'~_//~&, RIH with 5-1/2'' RTTS and test casing to 3000 psi. J Rig up E-Line. Perforate 40' of well bore, perforations will be oriented. Rig down E-Line. RIH and clean out to PBTD. Displace well with clean fluid and treat with corrosion inhibitor. Make up 7 5/8" X 3 1/2,, packer assembly with 3 1/2. tailpipe. Test packer to 3000 psi. RIH with packer on drill pipe and set packer at 8950' MD. POOH and lay down drill pipe. Run 3 1/2" completion assembly with SSSV, GLMs, and chemical injection mandrel at 8850' MD. Space out tubing. Freeze protect tubing and annulus with diesel. Land tubing. Test tubing to 3000 psi for 30 minutes. Test annulus to 3000 psi for 30 minutes. Nipple down BOP. Nipple up tree. Test tree to 5000 psi. Pressure down tubing and shear the solid disc shear out sub. Secure well, set BPV. Release rig. Estimated BHP · Planned Workover Fluid Seawater 3740 psi @ 8800' TVD REEEIVED S EP 1 1 1990 Alaska, 0il & Gas Cons. C0m~ss~0t~ Anchorage 13-5/ ' 5000 PSI BOP STACK I I ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 3 1.13-3/8" CASING HEAD 2.9-5/8" CASING HEAD 3.5000 PSI TUBING HEAD 4. 13-5/8"- 5000 PSI BLIND RAMS 5.13-5/8" - 5000 PSI PIPE RAMS 6.13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 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 THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING RECEIVED S EP 1 1 1990 NaSA.Oil & Gas Cons, Commissio[~ BOP STACK TEST Anchorage 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETION/ WORKOVER OPERATIONS, PERFORM COMPLETE BOP TEST EVERY 21 DAYS AND FUNCTION TEST BOP WEEKLY. DAM 8/4/89 REVISION OF11/21/86 BOP SCH (FOR:AUDI 4,NORDIC 1) STATE OF ALASKA -- ,, ALASKA _AND GAS CONSERVATION CC .,IlSSION i APPLICA'I-ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon SuSpend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, T11N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, T11 N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11 N, R15E, UM 6. Datum of elevation(DF or KB) 50 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 18-14 9. Permit number 86-119 10. APl number 50 - 029-21614 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10075 feet Plugs(measured) 8823 feet Effective depth: measured 10038 feet true vertical 8799 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 1540# Poleset 115' 115' Sudace 3402' 10-3/4" 2200 sx CS III & 400 sx CS II 3452' 3452' Production 9246' 7-5/8" 350 sx CI 'G' 9296' 8268' Liner 1085' 5-1/2" 200 sx CI 'G' 10075' 8823' RECEIVED Perforation depth: measured 9932-9952'; 9952-9972' S E P - ,5 1990 true vertical 8649-8661'; 8661-8755' Alaska 0il & Gas Cons. Comm[ssiOt~ Anchorage Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, PCT tubing @ 9047' MD; 3-1/2", 9.2#, L-80, tubing tail @ 9048' MD Packers and SSSV (type and measured depth) BeT 4H packer @ 8961' MD; Camco TRDP SSSV @ 2249' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: September 1990 16. If proposal was verbally approved Oil X Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer FOR COMMISSION URI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /V" ~' L} Date JAppr°val Nc~, ~ ..-?'~ ,~- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Cupy Returned J'"l SUBMIT IN TRIPLICATE Drill Site 18-14 Zone 1 Fracture Treatment Preliminary Procedure ARCO Alaska Inc. proposes the following procedure: This procedure commences after the Rig Workover and reperforations. 1. Perform perf breakdown treatment using ballsealers to open all perforations in the perforated intervals 9932'-9972' MD (referenced to BHCS log dated 11/4/86). 2. Pump fracture treatment to above intervals using gelled water and intermediate strength proppant at 20 bpm. Preliminary pump schedule is listed below. a. 100 bbl Prepad and shutdown. b. 280 bbl Pad c. 140 bbl Slurry at 1-12 PPG d. 96 bbl Flush . RDMO fracturing service company. Cleanout excess proppant to PBTD with CTU if needed. Place well on production. RECEIVED S E P - 5 1990 Alaska Oil & Gas GoDs, CommisSiO[] ~nchorage 6 5 4 3 2 COILED TUBING UNIT BOP EQU ! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~X)0 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS -6.5000 PSI 4 1/16" STUFFING; BOX 2 RE(EiVED s E P - 5 1990 0il & Gas Cons. commission ;Anchorage ~NIRELINE BOP EQUIPMENT 1. 5,000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5,000 PSI WlRELINE RAMS (VARIABLE SIZE) .1. 5000 PS~ 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC. F'.O. BOX t0056¢ ANCHORAGE, ALASKA 995t ¢ DATE' REFERENCE- t2-27-89 ARCO CASED HOLE FINALS 4-6 t '~-.--- t 4-89 COLLAR/F'ERF RUN 5-i 8 I 2-6-89 COLLAR RUN ~-i° i°-t8-89 F'ERF' RECORD RUN ~ · 4.% i2-52 t2-5-89 - F'RODtJCTION PROFILE I;,'UN i ?.T,-27 t 2-t 7-89 COLLAR RLJN i5-29 i2-ti-89 LEAl{ DETECT:ION RUN i4-i7 t2-i¢-89 LEAK DETECTION RUN i4-28 12-i7-89 TUBING CUTTER RECORD,"" . -'- RUN t7-5 t2-9-89 LEAK DETECTION RUN i8-t4 12-8-89 F'ERF RECORD RUNS F'LEA3E SIGN AND RETURN THE ATT~,.,HED COF'Y A~ RECEIPT OF' DATA. RECEIVED BY ~~-~ HAVE A NICE DAY! SALLY HOFFECKER '~ 529 A]U-t RECEIVED EC~81~t] I'~ ~., A ~.~ S' .~ 89~2-- AI~ Oil & Gas aon~ ~.~]~ .... ~chomge DISTRIBUTION CENTRAL FILES CHEVRON 'D &' M EXTENSION EXPLORATION' EXXON MARATHON MOBIL .. · · ~; . . · .' PHILLIPS F'B WELL FILES R & D ~- BF'X ~ $TAI'E OF ALASKA -~ TEXACO A'T'LA3" .., ~.-~ ~ U U '~CH CAMCO A'¥L_A:? C A M C 0 C A N CO ~" C H C A M C (3 ~ C H ARCO Alaska, Inc. Prudhoe Bay ~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 4, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18~14, Approval No. 9-105 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/MJB/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 18-14) W1-3 RECEIVED OCT l 11939 Alaska 0ii & Gas Cons. Commission .. ~nchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany AR3B .6132-C STATE OF ALASKA ALASKA 'LAND GAS CONSERVATION CC MISSION REPORT OF SUNDRY WELL OPt--RATIONs'` 1. Operations performed: Operation shutdown Stimulate ~ Plugging Perforate X Pull tubing Alter casing Repair well ~ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 929'FNL, 341' FWL, Sec.19, T11N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, T11N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 50' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 18- 14 9. Permit number/approval number 86- 119/9- 105 10. APl number 50 - 029 - 21614 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10075 feet Plugs(measured) true vertical 8823 feet Effective depth: measured 10038 feet true vertical 8799 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 1540# Poleset 115' 115' Surface 3402' 10-3/4" 2200 sx CS III & 400 sx CS II 3452' 3452' Production 9246' 7-5/8" 350 sx CI 'G' 9296' 8268' Liner 1085' 5-1/2" 200 sx CI 'G' 10075' 8823' Perforation depth: measured 9952 - 9972' true vertical 8661 - 8755' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, Tubing @ 9047' MD; 3-1/2", 9.2#, L-80, Tubing Tail 9048' MD Packers and SSSV (type and measureddepth)BOT4H Packer @ 8961' MD'; Camco TRDP SSSV @ 2249' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-MO Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1246 9891 0 - 1257 Subsequent to operation 0 0 0 - 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~~¢~--~,,~~- Title Operations Engineering Manager Form 10-404 Rev 06/15/88 Date '~/OC~/~ SUBMIT IN DUPLICATE D.M. FIFE .,~ DS 18-14 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 3/2/89 : MIRU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 9932 - 9972' MD Ref. Log: BHCS 11/4/86. Pumped the following treatment: 39 bbls 12% HC1 w/10% Xylene, followed by, 40.7 bbls 12-3% HC1-HF, followed by 24 bbls 12% HC1. Displaced w/Meth-Water. POH. Rigged down. 3/6/89 : The Squeeze was performed as follows : MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 20 bbls cement, squeezing perforations : 9932 - 9972' MD Ref. Log: 11/4/86. Contaminated cement with 47 bbls contaminant. Cleaned out contaminated cement from WB. 3/17/89 : Reperforated' 9952 - 9972' MD Ref. Log' 11/4/86. Cement fell down hole creating a bridge above the reperforated interval after shooting perfs. Subsequent broaching attempts have been unsuccessful. ARCO ALASKA, INC~ F'.O. BOX i00~6~ ANCHORAGE, ALASKA DATE' REFERENCE: 4-4-89 ARCO CASED HOLE FINALS -9 3-t~-89 LEAK DETECTION RUN 2-t? 3-22-89 TEMP 6 GAMMA TIE-IN RUNS 5-~3 3-~2-89 LEAK DETECTION RUN &- t 2 3-25-89 COLLAR/F'ERF RUN 6-t 4 3-t 8-89 COLLAR/PERF RUN ?-t4 3-~2-89 LEAK DETECTION RUN 9-t& 3-2?-89 TUBING CUTTER RUN ~ -24 3-t 5-89 TEMP RUN ~ -24 3-t 9-89 COLLAR/F'ERF RUN 2-32 3-~ 6-89 CBT RUN 2-~2 3-t &-89 CET R!!N 5-8 J-t 3-89 PIT/PRODUCTION RUN 5-25 3-~-89 P'RODUCTION PROFILE RUN 8-t4 3-~?-89 PERF RECORD RUN 8-~ 5 J-~ 7-89 PRODUCTION RUN 8-t5 3-t 8-89 DUAL BURST TDT-P RUN 8-20 3-2&-89 COLLAR/PERF RUN t62, 2'65' t, 2'&5' i, t, 5' t, 2'65' t, 5' t, 5' 1, 5' 1, 5' t, 5' t, 5' PLEASE £IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY__ HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 APF'ROVED .~___ DISTRIBUTION CENTRAL FILE~ CHEVRON D & M EXTENSION EXXON MARATHON MOBIL EXPLORATION PHILLIPS PB WELL FILES R 6 D BPX STATE OF ALASKA TEXACO CAMCO O'FI$ CAMCO ATLA~ A'i' LA~' CAMCO ATLAS' CAMCO ATLAS SCH SCH St21-1 CAMCO ~'CH $CH $CH ATLAS~ ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 7, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18-14 Permit No. 8-211 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 PI(DS 18-14)W1-3 WELLS3/ll0 ARCO A~aska, ~nc. is a Subsidiary of At~anticRichfie~dCompa.¥ ARSB 6132-C STATE OF ALASKA -' AL, ,AOILANDGASCONSERVATIONCOMMI, ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate ~ Other 2. Name of Operator 3. Address P.O. Bo× 100360~ Anchorage, At( 99510 4. Location of well at surface 929' FNL. 341' FWL, Sec. 19 TllN R15E, ~ At top of productive interval ' ' 1659' FSL, 1572' FWL, Sec. 19, TllN, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, Ti1N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, TllN, R15E, UM 5. Type of Well: Development ~- Exploratory __ Stratigraphic i Service __ 6. Datum elevation (DF or KB) ~0' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 18-14 9. Permit number 8-211 10. APl number 50-- 029-21614 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3423' 10075 feet 8823 feet 10038 feet 8799 feet Size 16" 10-3/4" Production 9296' 7-5/8" Liner 1085' 5-1/2" Plugs (measured) Junk (measured) Cemented Measureddepth ~ueve~icaldepth 1540# Poleset 115' 115' 2200 sx CS III & 3452' 3452' 400 sx CS II 350 sx Class G 9296' 8268' 200 sx Class G 8990-10075' 8043-8823' PedorationdeCh: measured 9932-9972' trueve~ical 8679-8705' SS ~bing(size, gmde, and measureddepth) 3½", L-80, tbg w/tail @ 9048' MD PackersandSSSV(typeandmeasuredde~h) 4H pkr @ 8961', TRDP SSSV @ 2249' MD 13. Attachments Description summary of proposal ')k Detailed operations program __ BOP sketch 14. Estimated date for commencing operation March 1~ 1989 16. if proposal was verbally approved Name of approver Date approved Service ,,,,,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~C~~,~~ Title operations Ensineerin~ Manager FOR COMMISSION USE ONLY 15. Status of well classification as: Oil )(' Gas__ Suspended __ Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance i ~/(_:,; Zj._ Mechanical Integrity Test __ Subsequent form required 10- ~.p~,'oved Copy Returned '-'~"~'~' ~!GNED BY Approved by order of the Commissioner LONN!E C. SMITH .;. ~, - Commissioner I Approval No. E~ Form 10-403 Rev 06/15/88 W[T,T,S3/110 D. H. F:ife, 263-4278 SUBMIT IN TRIPLICATE DS 18-14 CTU Cement Squeeze AFE# AP 1107 Preliminary Procedure 1. Make a slickline tag run to verify the PBTD. 2. Perform a dispersed xylene/HC1 acid wash to clean the perforations. 3. Surge well using a 3-1/2" surge disk. 4. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 5. Pump 20 bbls of cement followed by 2 bbls of water and 20 bbls of contaminant, ttold 5100 psi (bottom hole) squeeze pressure for 60 minutes. Squeeze off all of the perforations as follows: Zone Present Perforations S PF lB 9932-9972 6 6. Immediately jet or reverse out the contaminated cement. 7. Reperforate as follows: Zone Perforations S PF lB 9932-9972 FSD 8. Test the well. (Ref.: BHCS' 11-4-86) (Ref.: BHCS' 11-4-86) Reperf Other Well Information: Current status: On production. Expected static bottomhole pressure: 3763 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. 6 5 4 3 2 COILED IUB[NG UNIT BOP EO~U ! PME Ni 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~)00 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL]NE BOP EOUIPMEN'I' 1. 5,000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5,000 PSI WlRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5,000 PSI 4 1/6" FLOW TUBE PACK-OFF ~- STATE OF ALASKA - AL ,<A OIL AND GAS CONSERVATION COMM iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutOown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time exlens~on __ Stimulate __ Change approved program ~ Pull tubing m Variance ~ Pedorate ~ Other 2. Name of Operator 3. Acldress ?. O. Bo× [00360~ 4. Location of well at sudace A29 FNL. 341' FWL t top of productive interval ' 1659' FSL, 1572' FWL, Sec. At effective depth 1183' FSL, 1744' FWL, Sec. At total depth 1157' FSL, 1754' FWL, Sec. Anchorase, AK 99510 Sec. 19, TllN, R15E, UM 19, TllN, R15E, UM 19, TllN, R15E, UM 19, TllN, R15E, UM 5. Type of Well: Development Exploratory Stratigraph~c Service 6, Datum elevation (DF or KB) ~0' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 18-14 9. Permit number 9-211 10. APl number 50-- 029-21614 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true verticaJ Effective depth: measured true vertical Casing Length Conductor 80' Surface 3423' 10075 feet 8823 feet 10038 feet 8799 feet Size 16" 10-3/4" Production 9296' 7-5/8" Liner 1085' 5-1/2" Plugs (measured) J u nk (measu red) Cemented Measureddepth ~ueve~icaldepth 1540# Poleset 115' 115' 2200 sx CS III & 3452' 3452' 400 sx CS II 350 sx Class G 9296' 8268' 200 sx Class G 8990-10075' 8043-8823' Pedorationdepth' measured 9932-9972' truevertical 8679-8705' SS ~bing(size, grade, and measureddepth) 3½", L-80, tbg w/tail @ 9048' MD PackersandSSSV(typeandmeasureddep~) 4H pkr @ 8961', TRDP SSSV @ 2249' MD 13. Attachments Description summary of proposal .~_ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation March 1~ 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ..~ Gas__ Suspended Service 17. I hereby Certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~_~ ~ Title Operations [n~ineer Ma~aser "~ FOR COMMISSION USE ONLY in~ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ /x ~, ... Mechanical Integrity Test __ Subsequent form required .10- ~z~ c/- &pproved Copy Returned .... 0RIGINA['5~NED BY -~'~ ?- ~ .~ Approved by order of the Commissioner LONNtE C'. SMITH Commissioner Date Date Form 10-403 Rev 06~ 5/88 WELLS3/llO D. M. Fife, 263-4278 SUBMIT IN TRIPLICATE DS 18-14 CTU Cement Squeeze AFE# AP 1107 Preliminary Procedure 1. Make a slickline tag run to verify the PBTD. 2. Perform a dispersed xylene/HC1 acid wash to clean the perforations. 3. Surge well using a 3-1/2" surge disk. 4. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 5. Pump 20 bbls of cement followed by 2 bbls of water and 20 bbls of contaminant. Hold 5100 psi (bottom hole) squeeze pressure for 60 minutes. Squeeze off all of the perforations as follows: Zone Present Perforations S PF lB 9932-9972 6 6. Immediately jet or reverse out the contaminated cement. 7. Reperforate as follows: Zone Perforations S PF lB 9932-9972 FSD 8. Test the well. (Ref.: BHCS: 11-4-86) (Ref.: BHCS: 11-4-86) Reperf Other Well Information: Current status: On production. Expected static bottomhole pressure: 3763 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. 4 COILED TUB]~NG IJH]T BOP EgU ] PHEN? 1. ~)00 PSi ?" W£LLHF. AD CONNECTOR 2. ~)00 PSI 4 1/16" PIPE P,A~S 3. ~)C)0 PSI 4 1/6" I'~RAULIC SLIPS 4. ~N)00 PS1 4 1/6" SH~ $. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 H]REL]NE BOP EOU]PMENT i 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" L UBR~TOR 4. 5000 PSI 4 1/6" FL~ TUBE PACK-OFF ARCO ALA~'KA, INC· F'~ O~ BOX ANCHORAGE, ALASKA DATE' t 2-22-88 REF'ERENCE' ARCO MAGNETIC TAF'E,S' W/LII"i'ING 2'-~-88 CH' CNL (3 F'ASS) & TEMF' (5 F'ASS) JOB~?~04~ 2-2-88 CFI: CNI._ (~ F'A~'~') & H-I.. AVG· JOB~'?~.048 PLEASE £IGN AND RETURN THE ATTACHIED COF'Y AS RECEiF'T OF DATA, ~'CH ,.~'CH RECEIVED BY .... HAVE A NICE DAY! SALLY HOFFECKER ATO-t 529 TRAN$ ~887 APPROVED ..... DISTRIBUTION CENTRAL FILE~' (CH) CHEVRON D & M TAMIIA$ BROWN (OH) EXXON MARATHON MOBIL F'B WELL FILE&' SAF'C STATE OF ALASKA I'EXAO0 DATE' ! 2-9-88 A,~: t:;.:ECE ? i.::'T OF." DATA ,. t"IAV~:',.. A ,,~'~:[CE DATM, Z,AI. .... Y HOFF'ECKEF:..'. A'i"O .... i 52? '~ ,].-' 0 .... AF'F:'ROVE:D D :[ ;~¢ 'T R l B tJ T :[ 0 N ,_.[:.N, r',r:~!_ FtI_E~-: C H E V R 0 N EXTE;*.-i;~.':Ef'iN n",.-'i-,~ o~:;',"-.';"~!qN .. 1_/'..1' i--....t :;-I t .-. E X X 0 N H A i'--'.: A THON MOBIl_ .F'I..t T i._I., l F'e .,. ,.., F'B WELL. FI!._!:_"Z !7 & D ;"..7 A F' C Z. TATE OF' ALA,'b'I(A T E X A C 0 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 2, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18-14 Approval No. 8-211 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 18-14)W1-3 REcEiVED DEC o 7 ~g~i ,.?Jas~ Oil & 6as Cons. (;ommiss'ton WELLS3/62 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B --6132-C .... STATE OF ALASKA AL,, ,A OIL AND GAS CONSERVATION COMMIL REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Perforate __ Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other V/ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service TllN, TllN, R15E, UM R15E, UM TllN, R15E, UM 6. Datum elevation (DF or KB) 50' RKB 7. Uni~or Pr,qperty name ~rudnoe Bay Unit 8. Well number 18-14 9. Permit number/approval number 8-211 10. APl number 50-- 029-21614 11. Field/Pool 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, At effective depth 1183' FSL, 1744' FWL, Sec. 19, At total depth 1157' FSL, 1754' FWL, Sec. 19, TllN, R15E, UM feet Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing ~ngth Surface 80' Intermediate 3423' 10075 feet 8823 ~et 10038 feet 8799 Size 16" 10-3/4" Production 9296' 7-5/8" Liner 1085' 5-1/2" Plugs (measu red) Junk(measured) Cemented 1540# Poleset 2200 sx CS III & 400 sx CS II 300 sx Class G 200 sx Class G Measureddepth 115' 3452' 9296' 10075' .~uevedicaldepth 115' 8269' 8824' Perforation depth: measured 9932-9972' true vertical 8730-8756' Tubing (size, grade, and measured depth) 3½", L-80, 9.2#,tbg w/tail @ Packers and SSSV (type and measured depth) 4H pkr @ 8961' MD~ TRDP SSSV @ 13. Stimulation or cement squeeze summary Intervals treated (measured) 9048' MD 2249' MD Attached RECEIVED DEC Treatment description including volumes used and final pressure 0il & 6as Cons. C0mmissior~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1890 19144 0 1352 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~/' 1388 9278 0 16. Status of well classification as: Oil V/ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, 1186 Service Sig ned. _/~_d~'/~'~~/~ Form 10-404 Rev 06/15/88 WELLS3/62 Do Mo Title Operations Engineering Manager Date Fife, 263-4278 SUBMIT IN DUPLICATE DS 18-14 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 4/1 2/88 4/17/88 4/20/88 5/7/88 5/9/88 5/12/88 Performed acid wash as follows: MIRU CT. Pressure tested equipment to 4000 psig. RIH and washed perforations from' 9932-9972' MD Ref. Log: BHCS 11/4/86 Pumped treatment as follows: 1. 25 bbls gelled water, displacing CT. 2. 60 bbls crude, displacing wellbore 3. 23.5 bbls 12% HCI/xylene 4. 24 bbls 12%-3% HCI-HF 5. 24 bbls 12% HCI 6. 20 bbls diesel to flush POH. Returned well to production. Performed CTU cement squeeze as follows: MIRU CT. PT equipment to 4000 psi. Fluid packed well w/seawater. Pumped 15 bbls FW followed with 24 bbls cement, squeezing perforations: 9932-9972' MD Ref. Log: BHCS 11/4/86 Attained 1500 psig squeeze pressure. Contaminated cement w/26 bbls contaminant followed by 120 bbls gel water and 205 bbls seawater. Performed same day cleanout of contaminated cement. RD, leaving 750 psi at wellhead. Made tag run to 11031' PBTD (SLM). N2 lifted to 3000' for reperforating. Reperforated: 9932-9972' MD Ref. Log: BHCS 11/4/86 N2 lifted well to flow. Attained new production capacity. Oil & Gas Cons. uo~.,~.,s ..... DMF/O041 4 ANCHOR'&CE . AI..~.~'K ~ 995t DATE' 5-1 S-R8 ARCO CA.~.F..B HRI.F FTNAI.. ..... ,]" . ?::.?. ........... ~: f". ,L4 F ",," F-,.' (3 T) X, N .~ L- v ';~ r; ig ,? T t-t ?9 h-'X F:'t Fi F;: A 7' T i'i N -,r ~. ,'. ~ ~.. ~ . . M f') ~-?, T !. ARCO At...A~KA, P,O, BOX t00S60 AWCHORAGE, DATE: 4-I8-88 REFERENCE: ARCO PRESSURE D~TA t8'I"4 ~ '~4-°° BHP-,.~TAT .T. C GRADIENT BHF'-,S'FAT I C. GrkADTENT F'I...EA,.~E ,.~.T. GN AND R.F..I'IJR'N THE A'I'TAI:iI.-i:FD COF'Y A,.~ RECEIPT OF DATA, I;,' F;/3.. E I V E ]~ BY (, F'I~.--.Gf;Y BENNIE:T' ~,laska Bit & Ga~ Cons- A 'f' O -'- I 5'.2 c) /xnr:!:o-:x!e 'FRANS' A F:' I::' I;'. f.I f'~ T :,7'¥ R' T !~l IT 'r I/Id C A H C El CENTRAl.. F I I...E,.~ EXTF.-N,~TOlg EXF'I_.ORAT'[ I'lN EX¥ON HARATHON MOBIL ~ r.:' I-4 l: t.. I,. '1: F'.~ F'EI IdF:'l. t..FII ~'"- -,-" ,S' A F'C ~ .?fATE Ftl:: AI_.A,S'KA ~ T [-:' y A (~.f;I ARCO Alaska, Inc Prudhoe Bay ~ngine~hYing Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 23, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. ChattMn' Re- DS 18-14 Permit Number' 86-119 Attached is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DMF'sd Enclosures cc' Standard Alaska Production Co. File P1(18-14)W1-3 ARCO Alaska, inc. is a Subsidiary of AllanticRichfieidCompa.y AR3B -6132-(3 STATE OF ALASKA ALASK., OIL AND GAS CONSERVATION COMM.,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~, Re-enter suspended well % Alter casing :~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing -' Amend order ~_ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post 0ffice Box 100360, Anchorage, AK 99510 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, TllN, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec. 19, T11N, R15E, UM At total depth 1157' FSL, 1754' FWL, Sec. 19, T11N~ R15E, UM 11. Present well condition summary 10075 feet Plugs (measured) Total depth: true measured vertical 8823 feet 5. Datum elevation (DF or KB) 50' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 18-14 8. Permit number g6-1 19 9. APl number 50-- 029-21614 10. Pool Prudhoe Bay 0il Po0 Effective depth: measured 10038 feet true vertical 8799 feet Junk (measured) Casing Length Size Cemented Conductor 80' 16" 1540# Poleset Surface 3423' 10-3/4" 2200 sx CS 111 & 400 sx CS 11 Production 9296' '7-5/8" 350 sx Class G Liner 1085' 5-1/2" 200 sx Class G Measured depth 115' 3452' 9296' 8990-10075' ~ue Vertical depth 115' 3452' 8268' 8043-8823 Perforation depth: measured 9932' - 9972'MD true vertical 8679' - 8705'SS Tubing (size, grade and measured depth) 3½", L-80, tbg w/tail @ 9048' Packers and SSSV (type and measured depth) 4H pkr @ 8961', TRDP SSSV @ 2249' 12.Attachments Description summary of proposal Detailed operations program ;~ BOP sketch 13. Estimated date for commencing operation April 1, 1988 14. If proposal was verbally approved Name of approver Su]~sequent Work Reported on Date approved 15. I hereb~,C'~ertify tha/t'}the/f~rec,~ing is true and correct to the best of my knowledge ..Signed ~¢~'/~,~~ Title Operatiorls Engineerin~ Manage~ate ~/~/~"~ Commission Use Only Conditions of approval Notify commission so representative may witness ,~ Plug integrity ~ BOP Test [] Location clearance Approved by ORtO)NAL SIGNED BY tf~NNIF ~. SMITH Approved Copy Returned .-.. Commissioner Form 10-403 Rev 12-1-85 STAT16/gN 1R-14 r). M. Fife (263-427R~ IApproval No. by order of the commission Date =.,~.-',~-/~' Submit in triplicate DS 18~ 14 CTU Cement Squeeze Project AFE# 797961 1. Make a slickline tag run to verify the PBTD. Last PBTD was 10001' MD (ELM) on 2-24-88. 2. RIH with CT. Wash the perforations with full strength mud acid. Flow well to produce out all the acid. Cleanout fill to 10038' MD. 3. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 4. Pump 15 bbls of cement followed by 2 bbls of water and 30 bbls of contaminant. Hold 5100 psi squeeze pressure for 60 minutes. 5. Jet or reverse out the contaminated cement. ' erforate as follows: 9932-9972 (Ref.: BHCS 11-4-86) 7. Test the well. ill 2 1. 5000 PSI 7" WELLHEAD CONNEC'IOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ! H:IREL]NE BOP EOU]PHENT ,._ 6 5 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS ,3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS ,5. 5,000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX COILED TUBING UNIT BOP EOU ] PHENT ALASKA OIL AND GAS CONSERVATION COMMISSION Telecopy No. (907) 276-7542 November 16, 1987 Re .. A D M I N I S T R A T I V E A P P R O V A L N O. 213.11 Waivers to Rule lla of Conservation Order No. 165 for Prudhoe Bay Unit wells DS 18-9, DS 18-14 and DS 18-19. D F S cheve Operations Engineering Manager ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Scheve: By application dated November 10, 1987, on behalf of ARCO Alaska, Inc, you requested a waiver to Rule lla, Conservation Order No. 165 for Prudhoe Bay Unit wells DS 18-9, DS 18-14, and DS 18-19. These wells are producing from only one interval in zone 1. Since all flow would necessarily enter from this zone, a productivity profile as required by Rule lla of Conservation Order No. 165 is not needed until additional zones may be perforated. Therefore, under authority of Rule 2 of Conservation Order No. 213 the Commission hereby waives the requirement of Rule lla of Conservation Order No. 165 for Prudhoe Bay Unit wells DS 18-9, DS 18-14, and DS 18-19. Sincerely, ~ W W Barnwell Commissioner BY ORDER OF THE COMMISSION jo/3.AA213 ARCO Alaska, In Prudhoe Bay ~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: DS 18-9 Permit Number- 86-61 DS 18-14 Permit Number' 86-119 DS 18-19 Permit Number' 86-94 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/CKH-sd Enclosures CC' Standard Alaska Production Co. JoAnn Gruber, ATO 1478 File P1(DS18-9)W1-3 Pl(DS18-14)W1-3 P1(DS18-19)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR31~-6132-C STATE OF ALASKA AL/-,. .,A OIL AND GAS CONSERVATION CO,. ..IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order Perforate [] Other'~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. .. 50' RKB feet 3' A~od~e~Soffice Box 100360, Anchorage, AK 99510 6. Unit or ~.~)crl~Ven~a~/ Unit 7. Well nu~e[8_l4 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19, T11N, R15E, UN At top ~of productive interval 1659 FSL, 1572' FWL, Sec. 19, T11N, R15E, UM A[~¢i~s~_e, pt~744' FWL, Sec. 19, T11N, R15E, UM Att%t~ld~l~, 1754' FWL, Sec. 19, T11N, R15E, UM 8. Permit number 86-119 9. APl n u r~_ 21614 50-- 10. Pool Prudhoe Bay Oil Pool 11. Present well condition .summary Total depth: measured true vertical Effective depth: measured true vertical 10075 feet 8823 feet 10038 feet '8799 feet Casing Length Size Conductor 80' 16" Surface 3423' 10-3/4" Productio'n 9296' 7-5/8" Liner 1085' 5-1/2" Plugs (measured) Junk (measured) Cemented Measured depth 1540# Poleset 2200 sx CS 111 & 400 sx CS 11 350 sx Class G 200 sx Class G 115' 3452' 9296' 8990-10075' Wue Vertical depth 115' 3452' 8268' 8043-8823' Perforation depth: measured 9932' 9972'MD true vertical 8679' - 8705'SS Tubing (size, grade and measured depth) -'" L-80 tbg w/tail @ 9048' 2 , , Packers and SSSV (type and measured depth) 4H pkr @ 8961', TRDP SSSV @ 2249' 12.Attachments Description summary of proposal Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver N/A Date approved 15. I hereby.certify that the foregoing is true and correct to the best of my knowledge Signed ~~~ ,~(~9~ Title Operations Engineering ManagerDate Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test _[] LocatJo~ clearance I ^pprovea (.;opy Retu~r~ed~ :: --: ?:", - ~ Gommissionor ~TAT16/~N 1R-I& %. P. KPmner (263-47951 by order of the commission Date Submit in triplicate~r~ In accordance with Conservation Order No. 213, ARCO Alaska, Inc. requests the following: Permission to waive the production profile prescribed in Conservation Order 165, Rule 11a. Only 40' of perforations were shot in Zone 1, thereby eliminating the need for a spinner survey. At this time, no other perforations are planned. However, if additional perforations are needed, a production profile will be run upon completion of the additional perforations. ARCO Alaska, Inc· P.O. Box t00360 Anchormge, A[askm 995'10 DATE' September 2, t987 REFERENCE: ARCO Cm.sed Hol. e F'inal. ... 5" :3- ? 8 .... 't 9- 8'7 M e ;,'~ o r y I::' L r', w m e .!.- e r R u n 'i , ~,..'"', --,...'-. ,.,~a R - ~ 8 - 8 '7 F' u ~,l p i n T e i~ p ~ ~. u r v e y R u n ~ , .5 ' 'i8--t4 EJ -.. 2 (-7) -- 8 '7 F'u. mp in Temp, Survey Run ,t 5" F, .J, '- $ c: h ,~ c h S'c h F:'l. ea.se sign and r'eturn the attached Copy a.s receipt of data, D I ,:'.:: 'f' R · '" [': e n t r a I. I::' i L e s '"' · ,. F:'hi L Lip I) & M I:;-'. & I) '"' E x '1' e n.s': i c', n I::~ x I::' L ,"; r a 't i ,'", n:,": ,!? c:, h i o 'Il' · ......... ""...l!~ X X 0 i'i :JJ: ~' 't'. ,.':,.. '1: e 0 'f' A L a s' I,( a t'-'i a r' a 't h o n :',,':. "!" e x a ,[:: o :,",: t"i o I:.', i L ARCO Alaska, Inc, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve OPerations Engineering Manager September 1, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18-14 Permit No. 7-276 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company Pi(DS 18-14)W1-3 RECEIVEO SEP o 1 Alaska 0ii & Gas Cons. Commissl0r~ Anchorage WELL S 2 / 16 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B 6132.-C STATE OF ALASKA ALA~,.~A OIL AND GAS CONSERVATION COk .SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate~ Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Tnc 3. Address P. O. Box 100360; Anrhnr~g¢.; AK 99510 4. Location of well at surface 9, 9' F L 41' F. Se 19 TllN R15E UM )A21: top ~)1'~ ~o~uctive in~6Crva, C. , , , 5. Datum elevation (DF or KB) 50' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Wellnumber 18-14 8. Approval number Feet 1659' FSL, 1572' FWL, Sec. At effective depth 1183' FSL, 1744' ~,¢L, Sec. At total depth !!57' FST_.~ ]_75A' FWI.: gc, r~. 11. Present well condition summary Total depth: measured true vertical 19, TllN, R15E, UM 19, TllN, R15E, UM lq: T11N: RISE~ UM 7-276 9. APl number 50-- D?q-?1614 10. Pool Prudhoe Bay Oil Poo1 10075 feet 8823 feet Plugs (measured) Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3423 ' Intermediate Production 9296' Liner 1085' Perforation depth: measured feet 10038 feet 8799 Size 16" 10-3/4" 7-5/8" 5-1/2" Junk (measured) Cemented Measured depth True Vertical depth 1540# Poleset 115' 115' 2200 + 400 Sx 3452' 3452' 9296' 8268' 8990-10075' 8043-8823' 350 Sx 200 Sx 9932-9972' true vertical 8679-8705' ~bing(size, grade and measured depth) 3~",. L-80, tubing w/t~il @ 9048' FacKers and $SSV(type ana measured depth) 4H packer @ 8961', TRDP SSS¥ @ 2249' SE? ('' '-' '" .... 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 700 700 0 Casing Pressure 2700 12690 0 ~bing Pressure 280 1500 14. Attachments Daily Report of Well Operations-;t~ Copies of Logs and Surveys Run Il 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2¢'~~ f~ Title Operations Engineer Manager Form 10-404 R~v. 12-1-85 WF, LLS2/16 2'. M. Vitucci, ATO-1508, 2656358 Date ~/,¢-" ? Submit in Duplicate DRILL SITE 18-14 SELECTIVE STIMULATION PROCEDURE TREATMENT DATE: 7/19/87 1. MI and RU pump trucks, transports, N2 unit, and CTU. 2. RIH with CTU to 9150'. Fluid packed coil-production tubing annulus. . While reciprocating the CTU from 9930' to 9975', pumped 2500 gals of 15 % HCI w/additives. 4. Pulled the CTU to 9930' and pumped the following: A. B. C. D. E. F. G H. 1500 gals of 13-1/2% HCI - 1-1/2% HF w/additives 1500 gals of 2% NH4CI water 500 gals of 2% NH4CI water w/CMHEC blended with - 200 # of oil soluble resin - 15 gals of liquid oil soluble resin - Non-ionic Surfactant 1250 gals of 15% HCI w/additives 2500 gals of 13-1/2% HCI - 1-1/2% HF w/additives 2500 gals of 2% NH4CI water 500 gals of xylene 1000 gals of diesel w/10% EGMBE 5. Lifted the well with N2 immediately following the diesel stage. 6. RD and released equipment. . Tested well for new capacity and obtained a valid well test. ARCO ALas'kin, Inc. F:',.O. Box J OOS60 Anchorage, A I. aska DATF: Apri L ~;6~ ~987 I.~i.-.F. EI-~E-NCI~:. AI.,:CC Ca.sed I--Io I.e F'i na I. i-t6 :3-22."-87 CoI. Lar & F:'erf, Log Run t, ':5" (;ear ~. ~ ~) · . (' ~ ~ ~ .. ~--~8 "~ ~-.c]7 CoLLar & F:'er'f' Log Run ~, . [;ear ~. CeLLar & F'erf Lc, g Run ~ " Gear 4- ~ 7 :~-... 8..--87 C o [ !. a rL o g ( 5' e '~ F:' I. u g ) R u n '~ , 4 .... ~7 S-25--87 Col. l. ar Log (Dump Cemen'~) Run ~, 5" Gear 8'-9 S-..27-87 Co[Jar & Perf. Log Run ~, 5' Gear ' S- 7 P 8-~4 ~8-8 .... o[[ar & Perf Log Run ~, .5" Gear 8 .... ~ 9 :5---~ 9.-..87 Co [ Ia'," & F:'erf. Log Run ~ , 5' Gear F'l. ea.'::.':e s'ign and re'l'urn 'l'he a'l'tache(:l cop',,, a.s' receip't of dai'a, .......................................................... ,:;.'. ¥, ,-', ,:.? , APR '-I 191 7& Gas Cons. Commission ATO. .... 'l ..,,::.':~'""~: ~, _/ ~aska Oil Anchorage · 'r i:',/,. ~..I ~." .,. o ":' ") ") z~ ' '"'""~"'~ '""-" ~"'"":' ~'::~ I::' I:) !" 0 V e d ...................... .!.~ .......................................................... D I ~: T F;,' I B U T I 0 N ARCO Alaska, Inc. Prudhoe Bay ~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 20, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 18-14 Permit No. 86-119 Dear Mr. Chatterton: Attached is the Application for Sundry performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JLB/jp Attachment cc: Standard Alaska Production Company PI (DS 18-14)W1-3 Approval detailing work to be Oil & G;~s O,~ns. Cornmissm~'~ ARCO Alaska, Inc= is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALAS~... OIL AND GAS CONSERVATION COMh,.,sSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Fi Suspend ~ Operation Shutdown Fl Re-enter suspended well ~ Alter casing !:! Time extension F1 Change approved program ~ Plugging [] Stimulate ~ Pull tubing Fi Amend order ~ Perforate !-! Other 2. Name of Operator ARC. fl Alaska ~ Thc, 3. Address Post Office Box 100360, Anchoraqe, AK 99510 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19 T11N R15E UM At top of productive interval ' ' ' 1659' FSL, 1572' At effective depth 1183' FSL, 1744' At total depth 1157' FSL, 1754' FWL~ Sec. 19, T11N~ R15E, UN 11. Present well condition summary FWL, Sec. 19, T11N, R15E, UM FWL, Sec. 19, T11N, R15E, UM 5. Datum elevation (DF or KB) 50' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 18-14 feet 8. Permit number F~6-119 9. APl number 50-- 029-21614 10. Pool Total depth: measured 10075 feet true vertical 8823 feet Effective depth: measured 10038 feet true vertical 8799 feet Casing Length Size Conductor 80' 16" Surface 3423' 10-3/4" Producti on 9296' 7-5/8" Liner 1085' 5-1/2" Plugs (measured) Junk(measured) Cemented Measured depth 1540# Poleset 115' 2200 sx CS 111 & 3452' 400 sx CS 11 350 sx Class G 9296' Prudhoe BaS Oil Pool 200 sx Class G 8990-10075' ~ue Vertical depth 115' 3452' 8268' 8043-8823' Perforation depth: measured 9932' - 9972'MD true vertical 8679' - 8705'SS Tubing (size, grade and measured depth) 3½", L-80, tbg w/tail @ 9048' Packers and SSSV (type and measured depth) 4H pkr @ 8961', TRDP SSSV @ 2249' 12.Attachments Description summary of proposal [] A!aska 0il & G,% Cons. Anci':(:~ge Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation April, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereb,ylcertify t.~at the foregoing is true and correct to the best of my knowledge Signed 2¢~~}/~ Title Operations Engineering Manager Date - Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test ~ Location clearancel Approved by Form 10-403 Rev 12-1-85 ,. tho corniness}on ~ato ~,. cato SPK (263-4795) DESCRIPTION OF PROPOSED WORK ARCO Alaska, Inc. intends to perform a selective mud acid stimulation on DS 18-14. The stimulation will be performed as follows: 1. Obtain valid well test. 2. MI & RU pump trucks and transports. 3. Stimulate well as follows: ae e , 1000 gals of g~%H~l_w~d~i~% ~ ~%%m~%~da~J~~ 2000 gals of d ~_ zed w/N2 = r 2000 gals of 2% NH,C1 wate atomized w/No 700 gals of 2% NHA~i gelled water and 700# of stimulation grade benzoic acid~flakes 1000 gals of 15% HC1 w/additives and atomized w/N2 2000 gals of 6% HC1 - 1½% HF w/additives and atomized w/N2 2000 gals of 2% NH~ water atomized w/N~ 1000 gals of diese% w/5% EGMBE atomize~ w/N~ Displace to formation with dead crude atomized w/N2 4. Return well to production immediately. 5. Obtain new capacity. 7 JLB2/86 STATE OF ALASKA "~- (~ 11 ~ G iN A L ' ALASK:" ,. i ~_ AND GAS CONSERVATION , ..'." :~IlSSION (~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG w 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-119 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21614 4. Location of well at surface 9. Unit or Lease Name 929' FNL, 341' FWL, Sec.19, T11N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1659' FSL, 1572' FWL, Sec.19, TllN, R15E, UM 18-14 At Total Depth 11. Field and Pool 1157' FSL, 1754' FWL, Sec.19, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 50' ADL 28321 ALK 2319 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/22/86 11/05/86 03/18/87' N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 10,075'MD, 8823'TVD 10,038'MD, 8799'TVD YES [~ NO [] 2249' feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run D I L/BHCS/CNL/GR/SP, GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 1540# Pol eset 10-3/4" 45.5# -55-L-80 Surf 3452' 13-1/2" 2200 sx CS Ill & 400 sx CS II 7-5/8" 29.7# L-80 Surf 9296' 9-7/8" 300 sx Class G 5-1/2" 17.0# L-80 8990' 10,075' 6-3/4" 200 sx Class 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9932'-9972'MD 8729'-8756'TVD 3-1/2" 9048' 8961 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 0° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST .... Date First Production I Method of Operation (Flowing, gas lift, etc.) 03/18/87 DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 04/01/87 6.0 TEST PERIOD ~ 191 186 0 37°t 972. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 282 9'00 24-HOUR RATE ~ 764 743 0 28 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APR 2 ~'! 1987 Alaska 011 & (~a$ CONS. C0mmissi~ Anchorage WNOTE: Dril]ed RR 11/08/86. Tubing run 01/07/87. Form 10-407 Rev. 7-1-80 WC2: 44: DAN I CONTINUED ON REVERSE SIDE Submit in duplic~ 29 ..... . r~.- .... . -, GEOLOGIC MAR~'~ ': ' ~ RMATION"TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad I erochi t .' ;' ~931~ ~ 8281 ~ N/A " - ' / Base Sad]erochi t 997~~ 8757 ~ ,. . ; . j :~,, . . ,. · · · · . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and Correct to the best of n~y knowledge Signed ~ (~j~/~_/~..? .~.~,,. 'Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10407 .... STATE OF ALASKA '-~ ALAS, ~ OIL AND GAS CONSERVATION COM, 5SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska: Inc. 3. Address Post Office Box 100360~ Anchorage, AK 99510 4. Location of well at surface 929' FNL, 341' FWL, Sec. 19 T11N R15E UM At top of productive interval ' ~ ' 1659' FSL, 1572' FWL, Sec. 19, T11N, R15E, UN 5. Datum elevation (DF or KB) .~0' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 18-14 8. Approval number At effective depth 1183' FSL, 1744' FWL, Sec. At total depth 1157' FSL~ 1754' FWL, Sec. 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3423' Production 9296' Liner 1085' 19, T11N 19~ T11N 10075 8823 10038 8799 Size 16" , R15E, UM , R15E, UM 9. APl number 50-- 029-71614 10. Pool Prudhoe Bay. 0i] Pool feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 1540# Poleset 115' 10-3/4" 2200 sx CS 111 & 3452' 400 sx CS 11 7-5/8" 350 sx Class G 9296' 5-1/2"_ 200 sx Class G 8990-10075' ~ue Vertical depth 115' 3452' 8268' 8043-8823' Perforation depth: measured 9932' - 9972'MD true vertical 8679' - 8705'SS Tubing (size, grade and measured depth) 3½", L-80, tbg w/tail @ 9048' Packers and SSSV (type and measured depth) 4H pkr @ 8961', TRDP SSSV ¢ 2249' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~/~~ Title Operations En.qineerin§ Manager Date Form 10-404 Rev. 12-1-85 Submit in Duplicate Well 18-14 was perforated on 3/18/87. It has been tested at 800 BOPD but is shut-in pending stimulation and additional perfs. I~ TEI-E£O Teleco Oiifield S ~s of Alaska Inc. 6116 Nielson Anchorage, AK 99502 (907) 562-2646 November 10, 1986 JOB#544 TAK ARCO ALASKA WELL: DS 18 - Well #14 PRUDHOE BAY PARKER 141 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to ARCO. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ~JJ~,'J' COMPANY TELECO OILFIELD SERVICES JOB 544 SURVEY CALCULATIONS Date 11/10/86 Page 1 Company: ARCO ALASKA ~ell: DS 18 WELL #14 Location: PRUDHOE BAY Rig: PARKER 141 rELECO Job # 544 TAK Grid Correction: ~agnetic Declination: total Correction: Proposed Direction: 0.00 degrees 31.25 degrees 31.25 degrees 159.84 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE IN TO VERTICAL 3884.00 0.0 137.1 S 42 54 E 3884.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD SURVEYS 4416.00 8.7 148.4 S 31 36 E 4413.41 46.39 38.53S 29.67E 48.63 S 37.606E 1.633 4666.00 16.0 157.2 S 22 48 E 4657.46 99.37 86.01S 54.08E 101.59 S 32.160E 3.007 4856.00 24.3 159.6 S 20 24 E 4835.67 164.74 146.80S 78.15E 166.31 S 28.028E 4.389 4228.00 5.7 143.1 S 36 54 E 4226.91 23.55 19.06S 16.42E 25.16 S 40.748E 0.374 4041.00 5.3 137.1 S 42 54 E 4040.77 6.69 5.32S 4.93E 7.25 S 42.842E 3.376 TELECO Job # 544 TAK 11/10/86 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 5090.00 26.4 159.6 S 20 24 E 5047.13 264.93 240.72S 113.03E 265.93 S 25.152E 0.897 5296.00 27.5 154.3 S 25 42 E 5230.75 358.14 326.60S 149.57E 359.22 S 24.606E 1.282 5484.00 33.0 156.8 S 23 12 E 5393.09 452.54 412.77S 188.75E 453.88 S 24.574E 3.001 5703.00 37.1 160.3 S 19 42 E 5572.34 578.23 529.79S 234.72E 579.46 S 23.896E 2.084 5986.00 43.0 154.0 S 26 00 E 5788.87 759.95 697.44S 305.37E 761.36 S 23.646E 2.527 6188.00 44.4 149.8 S 30 12 E 5934.91 898.14 820.51S 371.09E 900.53 S 24.335E 1.595 6424.00 45.6 148.4 S 31 36 E 6101.79 1062.09 963.70S 456.78E 1066.48 S 25.360E 0.659 6609.00 47.0 147.7 S 32 18 E 6229.60 1193.01 1077.19S 527.56E 1199.44 S 26.094E 0.805 6922.00 45.0 152.2 S 27 48 E 6447.01 1414.75 1272.02S 640.27E 1424.07 S 26.718E 1.215 7139.00 46.0 156.8 S 23 12 E 6599.11 1568.81 1411.67S 706.88E 1578.77 S 26.599E 1.580 7371.00 40.2 157.5 S 22 30 E 6768.43 1727.09 1557.69S 768.41E 1736.91 S 26.257E 2.508 7496.00 36.7 158.2 S 21 48 E 6866.31 1804.75 1629.67S 797.71E 1814.43 S 26.081E 2.821 7628.00 37.1 158.6 S 21 24 E 6971.87 1883.98 1703.36S 826.89E 1893.46 S 25.894E 0.353 7844.00 37.5 158.2 S 21 48 E 7143.69 2014.84 1825.07S 875.07E 2024.01 S 25.617E 0.217 8279.00 39.6 158.2 S 21 48 E 7483.87 2285.82 2076.81S 975.64E 2294.56 S 25.163E 0.483 8654.00 38.4 160.3 S 19 42 E 7775.30 2521.79 2297.48S 1059.25E 2529.91 S 24.752E 0.476 9005.00 38.8 161.4 S 18 36 E 8049.61 2740.73 2504.34S 1131.08E 2747.92 S 24.306E 0.226 TELECO Job # 544 TAK 11/10/86 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 9188.00 39.9 163.1 S 16 54 E 8191.12 2856.66 2614.85S 1166.45E 2863.22 S 24.041E 0.841 400 800 TELECO 0 i 1S i ~ 1 d S~rv i c~s PLAN VIEW 0 400 800 1200 1600 2000 2_400 · '-- ~,..c K/ Ai~C[ , ~ ?~, ~ ~ S[:AL.E - ~ ,_.~. , ~ ~-~¢~-, I. t .. , _ ,,-~' t ~. ~.- · - --~ .... t ...... ,., k I I l .... ~---~ ~ ~ ' 'I I ~'~ ---~-~ ._::~,, ~ i~ .... ..... . __.~__. ~ .._, .1 , -- ~-.-;---~--~ I ....... , F i 1200 160D 2000 2400 2800 @200 9500 EAST TE~ECO Oil~:i~ld S~rvic~s VERT I CAL PROJECT I ON 0 3000 4000 5000 0000 7000 8000 9000 10000 11000 12000 1000 2000 9000 4000 5000 6000 VERTICAL SECTION (~t) SUB-SURFACE DIRECTIONAL SURVEY [~ UIDANCE [~ONTINUOUS {~OOL F ~,:3 o 6 1987 Alaska Oil & Gas ConS. Commissior~ Anchom99 Company ARCO ALASKA, INC. Well Name Ds 18-14 (929' FNL~ 341' FWL~ SEC 19~TllN,R.~5E,UM) Field/Location PRUDHOE BAY~ NORTH SLOPE, ALASKA Job Reference No. 72109 Logoed By: MCBRIDE Date il-NOV-86 Computed By: KRUWELL GCT DIRECTIONAL suRvEY CDSTOMER LISTING FOR ARCO ALASKA, INC. D.So ~18-14 PRUDHOE BAY NORTH SLOPE~ALASKA SURVEY DATE: 11-NOV-86 ENGINEER: M. MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 20 DEG 10 MIN EAST COMPUTATION DATE: 10-DEC-86 PAGE I ARCO ALASKA, INC. DATE OF SURVEY: 11-NOV-86 D.S. #18-14 PRUDHOE BAY NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 50.00 ,FT INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGOLAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -50.00 0 0 N 0 0 E 100.00 100.00 50.00 0 7 N 30 29 W 200.00 200.00 150.00 0 5 N 36 39 W 300.00 300.00 250.00 0 4 N 72 0 E 400.00 400.00 350.00 0 23 S 32 43 E 500.00 499.99 449.99 0 30 S 17 59 E 600.00 599.99 549.99 0 15 S 22 31 E 700.00 699.99 649.99 0 16 S 41 27 E 800.00 799.99 749.99 0 17 S 42 18 E 900.00 899,99 849.99 0 19 S 38 58 E 0.00 0.00 0.00 N 0.00 E -0.20 0.15 0.18 N 0.11 W -0.38 0.08 0.33 N 0.19 W -0.49 0.33 0.44 N 0.23 W -0.15 0.29 0.18 N 0.04 E 0.64 0.33 0.53 S 0.41 E 1.32 0.24 1.20 S 0.56 E 1.73 0.03 1.54 S O.B2 E 2.19 0.14 1.91 S 1,15 E 2.68 0.14 2.30 S 1,51 E 0.00 N 0 0 E 0.21 N 31 41 W 0.38 N 30 3 W 0.49 N 27 14 0.18 N 12 39 0.67 S 37 35 1.33 S 25 0 1.75 S 27 57 2.23 S 31 1 E 2.75 S 33 11 E 1000.00 999.99 949.99 1100.00 1099.99 1049.99 1200.00 1199,99 1149.99 1300.00 1299.99 1249.99 1400,00 1399.99 1349.99 1500.00 1499.99 1449.99 1600.00 1599.98 1549.98 1700.00 1699.98 1649.98 1800.00 1799,98 1749,98 1900,00 1899,98 1849,98 0 16 S 23 57 E 0 3 S 40 7 W 0 9 N 62 7 E 0 15 N 78 11 E 0 4 S 23 0 E 0 4 N 62 39 W 0 6 N 13 49 W 0 8 N 8 26 W 0 6 N 31 OW 0 6 N 55 6 W 3.20 0.10 2.76 S 1.77 E 3.53 0.30 3.08 S 1.87 E 3.50 0.14 3.01 S 1.95 E 3,50 0.05 2.87 S 2,34 E 3.60 0.25 2.87 S 2.62 E 3.64 0.04 2.94 S 2.56 E 3.50 0.07 2.82 S 2.47 E 3.27 0.08 2.58 S 2.45 E 3,04 0.11 2,35 S 2,40 E 2.87 0.06 2.23 S 2.26 E 3.28 S 32 39 E 3.60 S 31 14 E 3.59 S 32 53 E 3.71 S 39 9 E 3.89 S 42 27 E 3.90 S 41 5 E 3.75 S 41 14 E 3.56 S 43 33 E 3.36 S 45 29 E 3.17 S 45 18 E 2000.00 1999.98 1949.98 2100.00 2099.98 2049.98 2200.00 2199.98 2149.98 2300.00 2299.98 2249.98 2400.00 2399.98 2349.98 2500.00 2499.98 2449.98 2600.00 2599.98 2549.98 2700.00 2699.98 2649.98 2800.00 2799.97 2749.97 2900.00 2899.95 2849.95 0 7 N 5 23 W 0 12 N 39 50 E 0 14 N 47 52 E 0 11 N ~,5 26 E 015 N 83 0 E 0 20 S 78 56 E 0 21 S 75 51 E 0 32 S 71 50 E 0 46 S 73 5 E 1 8 S 78 35 E 2.74 0.18 2.12 S 2.16 E 2.55 0.14 1.88 S 2.25 E 2.38 0.06 1.59 S 2.56 E 2.23 0.16 1.33 S 2.84 E 2.18 0.20 1.17 S 3.16 E 2,41 0.05 1.21 S 3.70 E 2.74 0,10 1,35 S 4,29 E 3.19 0.20 1.55 S 5.02 E 3.89 0.36 1.91 S 6.09 6 4.90 0,33 2,36 S 7.79 E 3.03 S 45 32 E 2.94 S 50 7 E 3,02 S 58 8 E 3.13 S 64 49 E 3.37 S 69 43 E 3.89 S 71 49 4.50 S 72 34 5.26 S 72 49 E 6.38 S 72 34 E 8.1~+ S 73 9 E 3000.00 2999.94 2949.94 3100.00 3099.92 3049.92 3200.00 3199.92 3149.92 3300.00 3299.90 3249.90 3400,00 3399.89 3349.,89 3500.00 3499.87 3449.87 3600.00 3599.85 3549.85 3700.00 3699.84 3649.84 3800,00 3799.83 3749.83 3900.00 3899.81 3849.81 1 I S 80 56 E 0 44 S 83 14 E 0 43 S 86 27 E i 0 N 85 9 E 1 6 N 79 26 E 1 6 N 77 51 E 0 59 N 74 10 E 0 50 N 73 46 E 0 49 N 75 20 E 1 3 S 88 49 E 5.84 0.13 2.68 S 9.62 E 6.59 0.20 2.91 S 11.20 E 7.16 0.18 3.05 S 12.46 E 7,69 0.34 3,06 S 13,96 E 8.03 0.45 2.74 S 15.83 E 8.32 0.06 2.36 S 17.68 E 8.53 0,12 1.93 S 19.49 E 8.67 0.39 1,49 S 21.07 E 8.78 0.10 1.08 S 22.52 E 9.04 1.31 0.80 S 24.03 E 9.99 S 7~ 24 E 11.57 S 75 26 E 12.83 S 76 15 E 14.29 S 77 37 E 16.06 S 80 10 E 17.84 S 82 22 E 19.58 S 84 21 E 21.12 S 85 56 E 22.54 S 87 14 E 24.04 S 88 5 E ARCO ALASKA, INC. D.S. //18-14 PRUDHOE BAY NORTH SLOPE~ALASKA COMPUTATION DATE: 10-DEC-86 PAGE DATE OF SURVEY: Il-NOV-86 KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN S 44 40 E S 41 12 E S 40 28 E S 39 41 E S 33 15 E S 22 6 E S 20 12 E S 23 10 E S 21 31 E S 20 3O E 50.00 FT 6000,00 5792,15 5742,15 43 1 S 27 27 E 785,69 6100.00 5864,98 5814.98 43 34 S 29 37 E 853,41 6200,00 5937,03 5887,03 44 30 S 30 10 E 921,76 6300.00 6007.97 5957.97 44 57 S 30 36 E 991.12 6400.00 6078.50 6028.50 45 23 S 31 1 E 1060.78 6500.00 6148.45 6098.45 45 5~, S 31 18 E 1130.94 6600.00 6217.56 6167.56 46 3(~' S 31 27 E 1201.83 6700.00 6285.73 6235.73 46 50ml~ S 31 25 E 1273.57 6800.00 6355.78 6305.78 44 31 ~.28;~ E 1343,77 6900.00 6426.82 6376.82 44 5 ~ 27 E 1413.52 7000.00 6497.35 6447.35 45 2~ ~3-~27~'J'~7 E 1483.78 7100.00 6567.20 6517.20 45i~~5 ~ ~24~7 E 1554.91 7200.00 6636.82 6586.82 45 4 ~ ~-~3--.-7 E 1626.58 7300.00 6708.49 6658.49 42 S~_22 ',~ E 1696.19 oo.oo _. s 5000.00 4965.52 4915.52 26 12 5100.00 5055.11 5005.11 26 41 5200.00 5143.90 5093.90 28 5 5300.00 5232.09 5182.09 27 51 5400.00 5319.54 5269.54 30 42 5500,00 5404.17 5354,17 33 38 5600.00 5486.12 5436.12 36 0 5700.00 5566.42 5516.42 37 18 5800.00 5644.23 5594.23 40 30 5900.00 5718.93 5668.93 42 37 S 20 47 E 233.29 S 21 15 E 277.70 S 23 54 E 323.65 S 26 2 E 370.62 S 25 18 E 418.81 S 23 8 E 471.92 S 21 26 E 529.19 S 20 35 E 588.78 S 22 42 E 651.53 S 24 0 E 717.92 4000,00 3999.73 3949,73 3 57 4100.00 4099.32 4049.32 5 38 4200,00 4198,83 4148,83 5 40 4300,00 4298.32 4248.32 6 5 4400.00 4397.54 4347.54 8 22 4500.00 4496.16 4446.16 10 23 4600,00 4594,00 4544,00 13 42 4700,00 4690,28 4640,28 17 43 4800.00 4784.21 4734.21 21 52 4900.00 4875.64 4825.64 25 34 12.07 3.65 2.93 S 20.37 0.31 9.56 S 29.63 0.13 17.04 S 39.15 1.lO 24.77 S 50.91 3.25 34.56 S 67.28 2.39 49.26 S 87.87 3,90 68,64 S 114.82 5.00 93.58 S 149,01 3,42 125.24 S 189,44 2.30 27.04 E 27.19 S 83 49 E 33.05 E 34.41 S 73 51 E 39.55 E 43.06 S 66 41 E 46,11 E 52,34. S 61 45 E 53.58 E 63.76 S 57 10 61.01 E 78.41 S 51 4 67,98 E 96,61 S 44 43 78.23 E 121.97 S 39 53 91,22 E 154.94 S 36 4 E 163.09 S 105.43 E 194.20 S 32 52 E 0.52 1.41 1.97 2.00 4.53 3.77 1.87 2.67 2.98 2.63 204.04 S 121.12 E 237.28 S 30 41 E 245.58 S 136.86 E 281.14 S 29 7 E 288.08 S 154.39 E 326.84 S 28 11 E 330.79 S 174.35 E 373.92 S 27 47 E 374.19 S 195.94 E 422.39 S 27 38 E 422.81 S 217.63 E 475.53 S 27 14 E 475.95 S 239.06 E 532.62 S 26 40 E 531.64 S 260.26 E 591.93 S 26 5 E 590.00 S 283.39 E 654.53 S 25 39 E 651.09 S 309.60 E 720.96 S 25 25 E 2.66 0.49 1.23 0.84 0.51 0.99 0.78 2.45 2.31 0.68 712.44 S 339.17 E 789.05 S 25 27 E 772.39 S 372.33 E 857.45 S 25 44 E 832.52 S 406.89 E 926.63 S 26 2 E 893.32 S 442.51 E 996.92 S 26 21 E 954.17 S 478.90 E 1067.61 S 26 39 E 1015.35 S 515.81 E 1138.86 S 26 55 r 1077.04 S 553.48 E 1210.93 S 27 Ii 1139.43 S 591.68 E 1283.90 S 27 26 E 1200.95 S 627.80 E 1355.15 S 27 35 E 1263.17 S 660.70 E 1425.53 S 27 36 E 1.19 3.00 1.81 1.98 3.62 0.23 0.78 0.73 0.63 1.17 1325.90 S 693.71 E 1496.41 S 27 37 E 1389.96 S 725.60 E 1567.95 S 27 33 E 1455.83 S 754.13 E 1639.56 S 27 23 E 1519.96 S 781.43 E 1709.07 S 27 12 E 1580.69 S 806.43 E 1774.52 S 27 1 E 1637.64 S 828.74 E 1835.39 S 26 50 E 1693.67 S 849.66 E 1894.85 S 26 38 E 1750.06 S 870.93 E 1954.79 $ 26 27 E 1806.44 S 893.12 E 2015.16 $ 26 18 E 1863.01 S 915.65 E- 2075.87 S 26 10 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOOTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN COMPUTATION DATE: lO-DEC-55 PAGE 3 AR.CO ALASKA, INC. DATE OF SURVEY: 11-NOV-86 D.S. ~18-14 PRUDHOE BAY NORTH SLOPE ,ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 50.00 ,FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7260.18 7210.18 38 49 8100.00 7337.96 7287.96 39 12 8200.00 7415.16 7365.16 39 27 8300.00 7492'38 7442.38 39 21 8400.00 7570.13 7520.13 38 35 8500.00 7648.64 7598.64 37 58 8600.00 7727.31 7677.31 38 28 8700.00 7805.53 7755.53 38 31 8800.00 7883.83 7833.83 38 13 8900.00 7962.22 7912.22 38 35 S 21 53 E 2126.54 S 22 20 E 2189.36 S 22 28 E 2252.88 S 22 31 E 2316.35 S 22 47 E 2379.18 S 22 31 E 2441.06 S 22 2 E 2502.76 S 21 13 E 2565.03 S 20 36 E 2627.23 S 19 39 E 2689.32 0.61 0.86 0.68 0.71 0.49 0.86 0.79 0.87 0.73 1.25 1920.65 S 938.73 E 2137.78 S 26 Z E 1978.88 S 962.38 E 2200.49 S 25 56 E 2037.65 S 986.59 E 2263.93 S 25 50 E 2096,31 S 1011.00 E 2327.37 S 25 44 E 2154.36 S 1035.19 E 2390.17 S 25 39 2211.48 S 1059.15 E 2452.03 S 25 35 2268.64 S 1082.49 E 2513.66 S 25 30 2326.52 S 1105.53 E 2575.83 S 25 24 2384.66 S 1127.62 E 2637.83 S 25 18 E, 2442.94 S 1149.03 E 2699.67 S 25 11 E 9000.00 8040.31 7990.31 38 41 9100.00 8118.07 8068.07 39 31 9200.00 8194.89 8144.89 39 55 9300.00 8271.42 8221.42 39 46 9400.00 8347.96 8297.96 40 44 9500.00 8422.75 8372.75 42 12 9600.00 8496.26 8446.26 43 17 9700.00 8568.34 8518.34 44 23 9800.00 8638.93 8588.93 45 47 9900.00 8707.51 8657.51 47 50 S 18 45 E 2751.77 S 18 12 E 2814.63 S 17 29 E 2878.58 S 17 25 E 2942.88 S 17 38 E 3007.15 S 18 30 E 3073.47 S 20 46 E 3141.25 S 20 30 E 3210.58 S 20 26 E 3281.39 S 20 44 E 3354.15 1.12 1.21 0.39 1.18 1.33 2.46 1.59 0.68 1.34 2.83 2501.94 S 1169.54 E 2761.80 S 25 3 E 2561.60 S 1189.43 E 2824.28 S 24 54 E 2622.56 S 1208.94 E 2887.80 S 24 44 E 2683.95 S 1228.30 E 2951.66 S 24 35 E 2745.32 S 1247.63 E 3015.52 S 24 26 E 2808.52 S 1267.89 E 3081.45 S 24 17 E 2872.24 S 1291.02 E 3149.05 S 24 12 E 2937.09 S 1315.56 E 3218.26 S 24 7 E 3003.43 S 1340.33 E 3288.93 S 24 2 E 3071.57 S 1365.85 E 3361.56 S 23 58 E 10000.00 8773.69 8723.69 48 52 10075.00 8823.01 8773.01 48 52 S 20 51 E 3429.13 S 20 51 E 3485.62 0.00 0.00 3141.65 S 1392.51 E 3436.43 S 23 54 E 3194.44 S 1412.63 E 3492.85 S 23 51 E COMPUTATION DATE: lO-DEC-86 PAGE ARCO ALASKA~ INC. DATE OF SURVEY: il-NOV-86 D.S. m18-14 PRUDHOE BAY NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 50.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASDRED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR 'COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 0.00 0.00 -50.00 0 0 1000.00 999.99 949.99 0 16 2000.00 1999.98 1949.98 0 7 3000,00 2999.94 2949.94 1 1 4000.00 3999.73 3949.73 3 57 5000.00 4965.52 4915.52 26 6000.00 5792.15 5742.15 43 7000.00 6497.35 6447.35 45 24 $000.00 7260.18 7210.18 38 49 9000.00 8040.31 7990.31 38 41 N 0 0 E 0.00 S 23 57 E 3.20 N 5 23 W 2.74 S 80 56 E 5.84 S 44 40 E 12.07 S 20 4'7 E 233.29 S 27 27 E 785.69 S 27 37 E 1483.78 S 21 53 E 2126.54 S 18 45 E 2751.77 0.00 0.10 0.18 0.13 3.65 0.52 2.66 1.19 0.61 1.12 0.00 N 0.00 E 0.00 N 0 0 E 2.76 S 1.77 E 3.28 S 32 39 r. 2.12 S 2.16 E 3.03 S 45 32 ~ 2.68 S 9.62 E 9.99 S 74 24 E 2.93 S 27.04 E 27.19 S 83 49 ~' 204.04 S 121.12 E 237.28 S 30 41 ) 712.44 S 339.17 E 789.05 S 25 27 ~. 1325.90 S 693.71 E 1496.41 S 27 37 : 1920.65 S 938.73 E 2137.78 S 26 2 E 2501.94 S 1169.54 E 2761.80 S 25 3 E 10000.00 8773.69 8723.69 48 52 10075.00 8823.01 8773.01 48 52 S 20 51 E 3429.13 S 20 51 E 3485.62 0.00 0.00 3141.65 S 1392.51 E 3436.43 S 23 54 E 3194.44 S 1412.63 E 3492.85 S 23 51 E COMPUTATION DATE: lO-DEC-86 PAGE 5 ARCO ALASKA, INC. DATE OF SURVEY: Il-NOV-86 D.S. #18-14 PRUDHOE BAY NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 50.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES MDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 0.00 0.00 -50.00 0 0 N 0 0 E 50.00 50.00 0.00 0 18 N 31 23 N 150.00 150.00 100.00 0 5 N 24 13 W 250.00 250.00 200.00 0 5 N 21 9 W 350.00 350.00 300.00 0 12 S 50 45 E 450.00 450.00 400.00 0 27 S 29 17 E 550.01 550.00 500.00 0 24 S 10 33 E 650.01 650.00 600.00 0 13 S 39 58 E 750.01 750.00 700.00 0 16 S 41 25 E 850.01 850.00 800.00 0 17 S 43 23 E 0.00 0.00 0.00 N 0.00 E -0.06 1.43 0.05 N 0.03 W -0.30 0.16 0.27 N 0.14 W -0.45 0.13 0.40 N 0.23 W -0.40 0.39 0.38 N 0.12 W 0.22 0.13 0.15 S 0.23 E 1.05 0.34 0.93 S 0.49 E 1.53 0.11 1.38 S 0.67 E 1.96 0.04 1.73 S 0.98 E 2.43 0.07 2.10 S 1.33 E 0.00 N 0 0 E 0.06 N 31 19 W 0.30 N 28 11 W 0.46 N 30 1 W 0.40 N 17 54 ~ 0.27 S 57 54 ~ 1.05 S 27 51 / 1.53 S 25 53 E 1.99 S 29 38 E 2.49 S 32 15 E 950.01 950.00 900.00 1050.01 1050.00 1000.00 1150.01 1150.00 1100.00 1250.01 1250.00 1200.00 1350.01 1350.00 1300.00 1450.01 1450.00 1400.00 1550.01 1550.00 1500.00 1650.02 1650.00 1600.00 1750.02 1750.00 1700.00 1850.02 1850.00 1800.00 0 18 S 28 56 E 0 12 S 16 57'E 0 3 N 40 52 E 0 15 N 68 23 E 0 10 S 88 46 E 0 4 S 36 26 W 0 5 N 42 26 W 0 8 N 0 6 W 0 8 N 12 54 W 0 6 N 54 15 W 2.96 0.15 2.54 S 1.66 E 3.42 0.29 2.96 S 1.85 E 3.52 0.i4 3.07 S 1.87 E 3.49 0.13 2.94 S 2.12 E 3.54 0.30 2.84 S 2.54 E 3.65 0.20 2.93 S 2.62 E 3.58 0.19 2.90 S 2.50 E 3.39 0.14 2.71 S 2.46 E 3.15 0.07 2.46 S 2.43 E 2.95 0.09 2.29 S 2.33 E 3.03 S 33 12 E 3.50 S 32 1 E 3.59 S 31 19 E 3.62 S 35 48 E 3.81 S 41 47 E 3.93 S 41 45 E 3.83 S 40 48 E 3.66 S 42 18 E 3.46 S 44 39 E 3.27 S 45 34 E 1950.02 1950.00 1900.00 2050.02 2050.00 2000.00 2150.02 2150.00 2100.00 2250.02 2250.00 2200.00 2350.02 2350.00 2300.00 2450.02 2450.00 2400.00 2550.02 2550.00 2500.00 2650.02 2650.00 2600.00 2750.03 2750.00 2700.00 2850.04 2850.00 2800.00 0 4 N 46 27 W 0 8 N 20 50 E 0 15 N 47 56 E 0 13 N 46 2 E 0 12 N 60 47 E 0 18 S 84 54 E 0 20 S 77 18 E 0 25 S 75 32 E 0 38 S 70 24 f 1 1 S 74 3 E 2.81 0.16 2.19 S 2.19 E 2.63 0.12 2.00 S 2.18 E 2.46 0.17 1.74 S 2.39 E 2.30 0.06 1.46 S 2.71 E 2.17 0.21 1.22 S 2.97 E 2.27 0.16 1.17 S 3.41 E 2.58 0.07 1.28 S 4.00 E 2.94 0.12 1.43 S 4.62 E 3.52 0.19 1.72 S 5.51 E 4.36 0.58 2.14 S 6.83 E 3.10 S 44 58 E 2.96 S 47 24 E 2.96 S 53 58 E 3.08 S 61 47 E 3.21 S 67 34 E 3.60 $ 71 4 ~ 4.20 S 72 15 4.84 S 72 47 ~- 5.77 $ 72 37 ~ 7.16 S 72 37 : 2950.05 2950.00 2900.00 3050.07 3050.00 3000.00 3150.08 3150.00 3100.00 3250.09 3250.00 3200.00 3350.11 3350.00 3300.00 3450.12 3450.00 3400.00 3550.14 3550.00 3500.00 3650.16 3650.00 3600.00 3750.17 3750.00 3700.00 3850.18 3850.00 3800.00 1 3 S 80 20 E 0 56 S 81 42 E 0 43 S 83 32 E 0 50 S 87 46 E 1 5 N 79 7 E 1 4 N 78 43 E 1 5 N 76 20 E 0 59 N 75 20 E 0 51 N 73 54 E 0 52 N 77 36 E 5.38 0.04 2.53 S 8.72 E 6.25 0.25 2.81 S 10.48 E 6.89 0.29 2.99 S 11.84 E 7.40 0.61 3.07 S 13.12 E 7.87 0.28 2.93 S 14.85 E 8.18 0.10 2.56 S 16.75 E 8.44 0.12 2.15 S 18.62 E 8.61 0.60 1.70 S 20.35 E 8.72 0.28 1.27 S 21.82 E 8.88 0.24 0.92 $ 23.25 E 9.08 S 73 47 E 10.85 S 74 58 E 12.21 S 75 50 E 13.48 S 76 50 E 15.14 S 78 51 E 16.94 S 81 17 E 18.74 S 83 24 E 20.42 S 85 14 E 21.86 S 86 39 E 23.27 S 87 44 E COMPUTATION DATE: lO-DEC-86 PAGE 6 ARCO ALASKA~ INC, D.S. ~ 18-14. PRUDHOE BAY NORTH SLOPE ~ ALASKA DATE DE SURVEY: il-NOV-86 KELLY BUSHING ELEVATION: ENGINEER: M, MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN S 56 32 E S 42 0 E S 41 10 E S 40 21E S 37 38 E S 26 24 E S 19 17 E S 22 41 E S 22 I E S 20 5 E 50.00 FT S 20 55 E 225,64 S 21 10 E 275,14 S 24 8 E 326.90 S 26 25 E 380,05 S 24 14 E 437,32 S 21 43 E 503.36 S 20 33 E 576.41 S 22 50 E 656.46 S 25 29 E 746,64 S 29 31 E 839.33 S 30 14 E 934.39 S 30 55 E 1032.55 S 31 18 E 1132.52 S 31 29 E 1235.73 S 29 0 E 1338.14 S 27 48 E 1436.48 S 25 31 E 1537.22 S 23 5 E 1640,06 S 22 24 E 1733.32 S 21 0 E 1813.32 S 20 20 E 1887.94 S 21 27 E 1963.51 S 21 47 E 2039.97 S 21 51 E 2118.35 S 22 20 E 2199.20 S 22 37 E 2281.50 S 22 44 E 2363.11 S 22 30 E 2442.12 S 21 52 E 2520.85 S 20 41 E 2600,47 7608.61 6950.00 6900,00 36 58 7733.95 7050.00 7000.00 37 10 7859.85 7150.00 7100.00 37 29 7986.93 7250.00 7200.00 38 ~4 8115.55 7350,00 7300.00 39 19 8245.11 7450.00 7400.00 39 27 8374.23 7550.00 7500.00 38 44 8501.73 7650.00 7600.00 37 58 8629.02 7750.00 7700.00 38 33 8756.86 7850.00 7800.00 38 29 6218.24 5950.00 5900.00 44 39 6359.52 6050.00 6000.00 45 10 6502.23 6150.00 6100.00 45 57 6647,40 6250,00 62.00,00 47 4 6791.89 6350.00 6300.00 44 41 6932.77 6450.00 6400.00 45 5 7075.28 6550.00 6500,00 45 50 7218.87 6650.00 6600.00 45 17 7355.72 6750.00 6700.00 40 52 7483.83 6850,00 6800,00 36 50 4982.70 4950.00 4900.00 26 8 5094.28 5050.00 5000.00 26 38 5206.91 5150.00 5100.00 28 10 5320.27 5250.00 5200.00 28 8 5435,68 5350,00 5300.00 31 44 5555.59 5450,00 5400,00 35 7 5679,44 5550,00 5500,00 36 54 5807.59 5650.00 5600.00 40 43 5942.38 5750.00 5700.00 42 55 6079.31 5850,00 5800.00 43 28 3950.20 3950.00 3900.00 I 58 4050.45 4050.00 4000.00 5 17 4150.93 4150.00 4100.00 5 41 4251.43 4250.00 4200.00 5 49 4352.02 4350.00 4300.00 7 6 4453.12 4450.00 4400.00 9 37 4554,87 4550,00 4500,00 12 2 4657.94 4650.00 4600°00 15 58 4763.28 4750.00 4700.00 20 38 4871.64 4850.00 4800.00 24 48 9.76 3.97 1.17 S 15.92 1.54 5.98 S 25.09 0.18 13.36 S 34.46 0,12 20.96 S 44'.71 2.81 29.35 S 59.15 2.47 41.81 S 77.84 3.76 59.17 S 102.71 3.87 82.44 S 135.66 3.89 177.32 3.47 25.12 E 25..15 S 87 19 E 29.90 E 30.49 S 78 41 E 36.39 E 38.76 S 69 50 E 42,89 E 47,74 S 63 57 E 49.79 E 57,79 S 59 29 ~' 57.71 E 71,27 S 54 4 64.66 E 87,64 S 47 32 ~ 73,46 E 110.42 S 41 42 E 112.83 S 86.28 E 142.03 S 37 24 E 151.71 S 101.27 E 182.40 S 33 43 E 0,71 1,34 1,80 2,42 2,47 2.35 1,75 2,76 2,42 0,88 196.89 S 118.40 E 229.74 S 31 1 E 243.18 S 135.93 E 278.60 S 29 12 E 291.06 S 155,72 E 330,10 S 28 8 E 339,29 S 178.55 E 383,40 S 27 45 E 391,09 S 203,62 E 440,93 S 27 30 E 451,91 S 229,57 E 506.88 S 26 55 E 520,06 S 255,93 E 579.62 S 26 12 E 594.55 S 285,30 E 659.46 S 25 38 E 677.25 S 321.67 E 749.76 S 25 24 E 759.99 $ 365.28 E 843.22 S 25 40 E 0.81 0.81 0.94 1.11 2.46 0.82 3.27 2.95 3.58 1.73 843.60 S 413.35 E 939.42 S 26 6 E 929.53 S 464.08 E 1038.95 S 26 31 E 1016.72 S 516.65 E 1140,46 S 26 56 E 1106,53 S 571,51 E 1245.40 S 27 18 E 1195.96 S 625.06 E 1349,45 S 27 35 E 1283.66 S 671.51 E 1448.69 S 27 36 F 1373.86 S 718.12 E 1550.22 S 27 35 1468,24 S 759,44 E 1653,02 S 27 21 ~ 1554,28 S 795,70 E 1746,11 S 27 6 E 1628,62 S 825,31 E 1825,80 S 26 52 E 0.84 0.59 0.79 0.82 0.54 0.43 0.79 0.85 0.57 0.75 1698.52 S 851.45 E 1899.99 S 26 37 E 1769.12 S 878.40 E 1975.19 S 26 24 E 1840,24 S 906.56 E 2051.42 S 26 13 E 1913.04 S 935.68 E 2129.61 S 26 3 E 1987.99 S 966.12 E 2210.32 S 25 55 ~ 2064,11 S 997.59 E 2292,54 S 25 47 E 2139.52 S 1028,97 E 2374,09 S 25 41 E 2212,46 S 1059.56 E 2453,09 S 25 35 E 2285.41 S 1089.27 E 2531.73 S 25 29 E 2359.62 S 1118.18 E 2611,15 S 25 21 E VERTI~CAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN COMPUTATION DATE: 10-0EC-86 PAGE 7 ARCO ALASKA, INC. DATE OF SURVEY: 3. Z-NOV-86 D.S. ~18-14 PRUDHOE BAY NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: M. MCBRIDE 50. O0 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES MDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8884.39 7950.00 7900.00 38 30 9012.41 8050.00 8000.00 38 40 9141.51 8150.00 8100.00 39 48 9272.07 8250.00 8200.00 40 5 9402.68 8350.00 8300.00 40 47 9536.85 8450.00 8400.00 42 31 9674.38 8550.00 8500.00 44 9 9815.90 8650.00 8600.00 46 1 9963.98 8750.00 8700.00 48 52 10075.00 8823.01 8773.01 48 52 S 19 50 E 2679.60 S 18 37 E 2759.53 S 17 47 E 2841.12 S 17 30 E 2924.97 S 17 38 E 3008.90 S 19 42 E 3098.27 S 20 36 E 3192.69 S 20 26 E 3292.81 S 20 51 E 3402.00 S 20 51 E 3485.62 0.48 0.40 0.79 1.19 1.43 2.30 1.16 1,48 0.00 0.00 2433.79 S 1145.73 E 2689.99 S 25 12 E 2509.30 S 1172.02 E 2769.51 S 25 2 E 2586.81 S 1197.62 E 2850.60 S 24 50 E 2666.85 S 1222.91 E 2933.87 S 2~ 38 E 2746.99 S 1248.16 E 3017.26 S 24 26 : 2831.96 S 1276.03 E 3106.16 S 24 15 2920.34 S 1309.28 E 3200.40 S 24 8 3014.12 S 1344.32 E 3300.32 S 24 2 ~ 3116.29 S 1382.84 E 3409.33 S 23 55 E 3194.44 S 1412.63 E 3492,85 S 23 51 E COMPUTATION DATE: lO-DEC-86 PAGE 8 ARCO ALASKA, INC. D.S. #18-14 PRUDHOE BAY NORTH SLOPE,ALASKA MARKER TOP SAG RIVER TOP SHUBLIK TOP SAOLEROCHIT TOP ZONE 3 TOP ZONE 2 TOP ZONE 18 BASE SADLEROCHIT G/O CONTACT PBTD TD DATE OF SURVEY: Il-NOV-86 KELLY BUSHING ELEVATION: 50.00 .FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 929 FNL, 341 FWL, SEC 19, TllN, R15E, UM TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 9175.00 9230.00 9313.00 9452.00 9562.00 9843.00 9974.00 9818.00 10038.00 10075.00 8175.71 8125.71 2607.28 S 1204.12 8217.88 8167.88 2640.95 S 1214.73 8281.42 8231.42 2691.8T S 1230.78 8387.10 8337.10 2777.93 S 1258.02 8468.49 8418.49 2847.98 S 1281.88 8668.75 8618.75 3032.45 S 1351.15- E 8756.59 8706.59 3123.35 S 1385.53 8653.99 8603.99 3013.54 S 1343.67 8798.68 8748.68 3168.40 S 1402.70 8823.01 8773.01 3194.44 S 1412.63 COMPUTATION DATE: lO-DEC-86' PAGE 9 ARCO ALASKA, INC. D.S. ~lB-14 PRUDHOE BAY NORTH SLOPE~ALASKA MARKER TOP SAG RIVER TOP SHUBLIK TOP SADLEROCHIT TOP ZONE 3 TOP ZONE 2 TOP ZONE lB BASE SADLEROCHIT G/O CONTACT PBTD TO DATE OF SURVEY: il-NOV-86 KELLY BUSHING ELEVATION: 50.00 ENGINEER: M. MCBRIDE ~~~ STRATIGRAPMIC SUMMARY MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 929 FNL, 341 FWL, SEC 19, TllN, R15E, UM TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 9175.00 9230.00 9313.00 9452.00 9562.00 9843.00 9974.00 9818.00 10038.00 10075.00 8175.71 8125.71 2607.28 S 1204.12 E 8217.88 8167.88 2640.95 $ 1214.73 E 8281,42 8231.42 2691.87 S 1230,78 E 8387.10 8337.10 2777.93 S 1258.02 E 8468.49 8418.49 2847.98 S 1281.88 E 8668.75 8618.75 3032.45 S 1351,15 E 8756.59 8706.59 3123.35 S 1385.53 E 8653.99 8603.99 3013.54 S 1343.67 E 8798.68 8748.68 3168.40 S 1402.70 E 8823.01 8773.01 3194.44 S 1412.63 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10075.00 8823.01 8773.01 HORIZONTAL DEPARTURE 'DISTANCE AZIMUTH FEET DEG MIN 3492.85 S 23 51 E SCHLUMBERGER 0 [ RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC WELL O.S. F ! ELD PRUOHOE BAY COUNTRY USA RUN 1 DATE LOOOEO 11 - NOV - 86 REFERENCE FS1R. 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SCqLED IN VERTICAL DEPTHS HORIZ SCALE = ]/ 1000 IN/FT CURVE DATA LOCATED IN THE APPENDIX ARCO ALa.~.;'ka, Inc~ F:',,O, Box 'i00~60 Anchorage, ALasl,,a DATE' Apr i I. 6, ]987 R E F' E R E N C E · A R C 0 P r e.s'.s' u r e D a '~ a 6 - 'i 2 S -29 -87 ,'.';' 't a -!: i c G r a d i e n -I: 'i ]-2 S-~-'i 4-'87 Surf'ace F:'re.'...;~.;ure F:'a I. [off ~ 8-.-~ 4 S-2~-.-.87 Sta~.' i c Grad i en'~ ~ 8 -' 'i ~;:. S - ,= ''~ "z.., _. ,.,° ",, ,.:~" ~' a '1' i c (;- r' a d i e n 'l' 0.1: is' A r c o 0-1: is' F:'Leas'e .~;igr; and ret:u'r'n the a~."~.ac:hed copy as' rec:eipt' of cla+.a, F;:ece i red By ......................................................... I-~(:;VE: A HI:C["' DAY! F,'os'a r~ne Peel.: A'T'O .... ~ 529 Cen'l:rat Fri Le~ Chevron '"' I) ' M Ex'l'ension Exploration -~-~' Ex xon Harm ~hon ~: Nob i l Phi F'B WeLL F'i les R & I) Sohio $~at'e of ALa_~l<a Texaco i:;: ,'.:-:' (:: e i v' (-? cl i::: I-.! C: N i... ,"'.~..: ';'.,:.., "r~ ...": '-..,:,' .:?~ i" i .:':i i:) [ e 'fl, ~':;: ¥', -'.:: [ '~',. '::...' I::' Y'' 1< .... i .";" ~":' · :./ ..; ... ,~,~,. ~ ~ C:lii:'i" i... c, ::.:.~ C lii:'i" i...,:::,.':~; '~ .- R.ECE !,¥E ?_ . · r' ,:.:..', ~: '...i '~')4"i i' h ,:,? a '!' i' a (:: !"~ (.:.:, d c' r.,j::: v '-"'?,J,sSk~ Oil & Gas Cons. .... STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COMb $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~.' Stimulate [] Plugging ~ Perforate [] Pull tubing Alter Casing ~ Other~ 60HPLETE 5. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 929' FNL, 341' FWL, Sec.19, T11N, R15E, UM At top of productive interval 1659' FSL, 1572' FWL, Sec.19, TllN, R15E, UM At effective depth 1183' FSL, 1744' FWL, Sec.19, T11N, R15E, UM At total depth 1157' FSL~ 1754' FWL, Sec.19, T11N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 10075 'MD 8823 ' TVD Effective depth: measured 10038 'MD true vertical 8799 'TVD RKB 50' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 18-14 8. Approval number 614 9. APl number 50-- 029-21614 10. Pool Prudhoe Bay 0il Pool Casing Length Conductor 80' Surface 3423' Production 9296' Liner 1085' feet feet feet feet Plugs (measured) Junk(measured) None None Size 16" 10-3/4" 7-5/8" 5-1/2" Cemented 1540# Poleset 2200 sx CS Ill & 400 sx CS II 350 sx Class G 200 sx Class G Measured depth 115'MD 3452'MD 9296'MD 8990'-10075'MD None Perforation depth: measured true vertical None Tubing (size, grade and measured depth) 3-1/2", L-80, tbg w/tail @ 9048' Packers and SSSV (type and measured depth) 4H pkr @ 8961', TRDP SSSV @ 2249' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) RECEIVED o 4 1987 Alaska Oil & Gas Cons. C0mmissbr~ Anch0ra~e Treatment description including volumes used and final pressure 13. N/A Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure True Vertical depth 115'TVD 3452 'TVD 8268 ' TVD 8043 ' -8823 ' TVD Prior to well operation Subsequent to operation 14. Attachments tcomp~ etJ on wel ! HJ story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ I/0 ' ~ Title Date ~:-~-o / vv,v.,,.~[')'~/' ~.,~,~ ~ ~ ,~.,..,,~ Associate Engineer Signed Form 10-404 Rev. 12-1-85 (DANI) $W0/164 Submit in Duplicate Tubing Pressure 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. District ICounty or Parish I Alaska Field ILease or Unit I Prudhoe Bay Auth. or W.O. no. ITitle I AS0405 North Slope Borough ADL #28321 Accounting cost center code State Alaska IWell no. 18-14 Completion WWS #1 Operator ARCO Alaske, Inc. 1930 Hrs. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. Old TD 1/07/87 1/08/87 Released rig Classifications (oil, gas, etc.) Oil API 50-029-21614 [A.R.Co. Wll. rTotal number °f wells (active °r iiactive) °n this Icost center prior to plugging and I 21.66% labandonment of this well Date I Hour Prior status if a W.O. 1/06/87 ! 0730 Hrs, Producing method Flowing Complete record for each day reported 5½" @ 10,075'-8990' 10,038' PBTD, Lnd 3½" tbg 9.7 ppg NaC1 Accept rig @ 0730 hrs, 1/6/87. ND tree, NU & tst BOPE. Tst 7-5/8" x 5-1/2" csg to 3000 psi. RU DA, make 2 GR/JB ms. RU & rn 286 its, 3½", 9.3#, L-80 EUE 8RD tbg w/SSSV @ 2249', 4H Pkr @ 8961', TOL @ 8990', TT @ 9048'. (Chisel fell & left dn hole while rn'g tbg.) Lnd tbg. ND BOPE, 5½" @ 10,075'-8990' 10,038' PBTD, RR Diesel Displ tbg w/diesel. Tst tbg & pkr to 2500 psi; OK. NU & tst tree to 5000 psi. RR @ 1930 hrs, 1/7/87. New TD Date 1/07/87 RECEIVED 0 6 1987 Alaska Oil & Gas Cons. Cornmissio~ Anchorafle PBDepth 10,038' Kndofrig Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abovejs correct?% ~,~ s,g, t \\.\ Date ITitle 1128187 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, A R C 0 A I. a s' I.,' a, I ¥'~ c ,. A n c h o r a g e..',, ~ A ~ a .'.; I,, a DATE: Decemb~-'-:'r 8 , ~9° R E F:' Ii!iR li!] N C E" A F;,' C 0 M a g n e 't i c T a p e.s' w / I. i .'...; 't i n g D I ~' T R I B LJ T I 0 N (::, 'f" (:i a t a, · "' C e'n '~' r a !. F i 1. e Chevron D & H Extents-ion ExpLorat'ion · "' E x x o n '11' Mar a thon F:'hi I. !. ip '-;' F'B We L L I::'i Les' I:;.'. & D 4: $ o h i o ~."t' a ~' ~::, of ALa.'..;l<a T e x a c o 1. Type of Request: STATE OF ALASKA ALASKA ,.,.L AND GAS CONSERVATION COMMI:..ON APPLICATION FOR SUNDRY APPROVALS Abandon ;_- Suspend - Operation Shutdown ~ Re.enter suspended well Z~' Alter casing - Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing- Amend order- Perforate-- Other -' 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchoraae. AK 99_51 4. Location of well at surface 930 ' FNL, 341' FWL, Sec. 19, T11N, R15E, UM 5. Datum elevation (DF or KB) 50 ' RKB 6. Unit or Property name Pr~ldhn~ Bay [Init 7. Well number 18-14 feet At top of productive interval 1386' FSL, 1430' FWL, Sec. 19, At effective depth 1219' FSL, 1669' FWL, Sec. 19, At total depth 1197' FSL, 1676' FWL, Sec. 19, T11N, R15E, UM(Approx) TllN, R15E, UM(Approx) T11N, R15E, UM(Approx) 8. Permit number 86-119 9. APl number 50-- 029-21 614 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical I 0075 'MD feet 8874 ' TVD feet Plugs (measured) None Effective depth: measured I 0038 'MD feet true vertical feet 8846 ' TVD Casing Length Size Cemented Conductor 80 ' 1 6" Surface 3423 ' 1 0-3/4" Producti on 9296 ' 7-5/8" Liner 1085 ' 5-1/2" Junk (measured) None Measured depth True Vertical depth 1540# Poleset 115'MD 115'TVD 2200 sx CSI I I & 3452'MD 3452'TVD 400 sx CS II 350 sx Class G 9296'MD 8274'TVD 200 sx Class G 8990'-10075'MD 8038'-8874'TV Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED i.:. C '- 8 1986 Alaska Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program -' BOP sketch Well History (including Addendum~ dated 11-15-86) 13. Estimated date for commencing operation December, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~[JJ_~C~. Title Ass°elate Engineer. F Commission Use Only (DAM) SA/1 64 Date Conditions of approval Approved by Notify commission so representative may witness I Approval No. ~. Plug integrity ~ BOP Test -- Location clearanceJ .............. by order of :,. :'.'.~f;:: ~: ~,:'::'~?~,,;:~, ~[ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Inatructlone: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O, no. AS0405 Parker #141 ARCO Alaska, Inc. 10/23/86 tO/24/86 10/25/86 thru [0/27/86 455.52E 10/28/86 [0/29/86 ICounty, parish or borough North Slope Borough IteaseADL t/28321 or Unit Title Drill lstate Alaska we,lng_ 14 AP1 50-029-21614 IDate [Hour 10/22/86 1500 Hrs. Complete record for each day reported ARCO W.I. · 21 66% JPrior status if e W.O. 16" @ 115' 1311, (1211'), Drlg Wt. 8.9, PV 19, YP 55, PH 8.5, WL --, Sol 6 ~ccept ri~ @ 0900 hfs, 10/22/86. NU dtverter. 10/22/86. Drl 13-1/2" hole to 1311'. Spud well @ 1500,hrs,,~ 16" @ 115' 3473, (2162'), Prep to rn 10-3/4" Wt. 9.3, PV 17, YP 24, PH 8.5, WL --, Sol 8 Drl & surv to 3473', short trip, C&C hole f/csg, POE. RECEIVED 10-3/4" @ 3452' 6061, (2588'), LD DD Wt. 9.0, PV 3, YP 7, PH 8.5, WL 16, Sol 5 Rn 4 ]ts, 10-3/4", 45#, J-55, 77 ]ts, 10-3/4", 145.5# L-80 BTC tag w/ES @ 3452', FC @ 3385'. Cmt w/2200 sx CS III & 400 sx CS II. Displ using rig pmps, bump plug. ND diverter sys. NU & tst BOPE. RIH, DO FC & cmt. Tst csg @ 3425' to 2000 psi. DO cmt, FS & 10' new formation to 3483'. Conduct formation tst to 15.5 ppg EMW. Drl to 3896', DD 9-7/8" hole to 6061'. 4041', 5.3",~S42.9E, 4040.77 TVD, 6.69 rS,. 5.31S, 4.93E 4416', 8.7°,~S31.6E, 4413.41TVD, 46.43 rS, 38.64S, 29.45E 4856', 24.3'¥~S20.4~, 4835.70 TVD, 164.82 VS, 147.47S, 76.56E 5296', 2l~5"~S25.7E, 5230.81TVD, 358.15 rS, 327.16S, 148.07E 5986', 43";, S26E, 5789.04 TVD, 759.81VS, 697.77S, 304.05E ..... , .... ~s CONS, Cornrnissio; Armhora.cie 10-3/4" @ 3452' 6997', (936'), DD Wt. 9.4, PV 6, YP 6, PH 9.0, WL 6.3, Sol 8 Drl & surv to 6997' . 6188', 44.4°, S30.2E, 5935.11TVD, 897.96 rS, 6424', 45.6", S31.6E, 6101.99 TVD, 1061.90 VS, 820.79S, 369.81E 963.96S, 6922', 45°, S27.8E, 6447.27 TVD, 1414.47 VS, 1272.15S, 639.11E 10-3/4" @ 3452' 7564', (567'), CBU Wt. 9.5, PV 12, YP 6, PH 10.0, WL 5.4, Sol 9 Drl & slide f/6997'-7218', POH, #2 cone missing. RIH, rm 60' to btm, wrk past junk, drl to 7564', CBU. 7139', 46°, S23.2E, 6599.41TVD, 1568.50 VS, 1411.79S, 705.66E 7496', 36.7°, S21.8E, 6866.62 TVD, 1804.44 VS, 1629.76S, 796.56E The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 1 i,/24/86 J Zit,e Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnterint" 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 liCounty or Parish iState Alaska North Slope Borough Field Lease or Unit Prudhoe Ba7 ADL t/28321 Date and depttl as of 8:00 a.m. 10/30/86 10/31/86 11/01/86 thru 11/03/86 11/04/86 11/05/86 11/06/86 Alaska JWetl no, 18-14 Complete record for each day while drilling or workover in progress (SS) (SS) 10-3/4" @ 3452' 7875', (311'), Drlg Wt. 9.7, PV 13, YP 6, PH 10, WL 5.4, Sol 9 Drl & surv 9-7/8" hole to 7721', C&C mud (9.7 ppg in/6.8 ppg out). to 9.9 ppg & drl to 7875'. 7628', 37.1°, S21.4E, 6972.17 TVD, 1883.67 VS, 1703.45S, 825.73E I0-3/4" @ 3452' 9070', (1195'), Drlg Wt. 9.9, PV 16, YP 7, PH 10, WL 5.2, Sol 12 Drl & surv 9-7/8" hole to 9070'. 7844', 37.5°, S21.3E, 7144.00 TVD, 2014.52 VS, 1825.15S, 873.92E 8654', 38.4°, S19.7E, 7775.61TVD, 2521.43 VS, 2297.48S, 1058.24E Wt up 7-5/8" @ 9296' 9400', (330'), Drlg Wt. 9.4, PV 12, YP 6, PH 11.5, WL 6.8, Sol 7 Drl to 9300', short trip, C&C, POOH, LD DP. RU & rn 215 its, 7-5/8", 29.7#, L-80 BTC csg w/FS @ 9296', FC @ 9204'. Cmt w/350 sx Cl "G" w/3% KC1, .3% CD-31, 1.1% FL-28, .2% A-2 & 1GHS FP-6L. Displ using rig pmps, bump plug. ND BOPE, set slips, instl pack-off & tbg head. Tst to 3000 psi. NU BOPE. RIH, tst csg to 3000 psi. DO flt equip & cmt + 10' new hole. Conduct formation tst to 13.3 ppg EMW. Drl to 9400'. 9005', 38.8°, S18.6E, 8049.93 TVD, 2740.37 VS, 2504.34S, 1130.06E 9188', 39.9°, S16.9E, 8191.44 TVD, 2856.29 VS, 2614.84S, 1165.41E 7-5/8" @ 9296' 10,001', (601'), Drlg Wt. 9.3, PV 13, YP 5, PH 10, WL 5.4, Sol 7 Drl & surv 6-3/4" hole to 10,001'. 9448', 40.5, 8390.04 TVD, 3023.64 VS RECEIVEg 7-5/8" @ 9296' 10,075', (74'), Drlg Alaska 0il & Gas Cons. Commission wt. 9.3, PV 14, YP 6, PH 10, WL 5.6, Sol 7 Anchorage Drl to 10,050', short trip, C&C, POOH. RU DA, rn DIL/BHCS/CNL/GR/SP f/10,050'-9296'. Rn GR f/9296'-3500', RD DA. TIH, drl rathole. 10,050', 49°, 8817.18 TVD, 3445.35 VS 5-1/2" @ 10,075' 10,075', (0'), WOC Wt. 9.3+, PV 16, YP 6, PH 10, WL 5.3, Sol 7 Circ, POH. RU & rn 27 its, 5½", 17#, FL4S csg w/FS @ 10,075', FC @ 10,040', LC @ 9960', TOL @ 8990'. Cmt w/200 sx C1 "G". Displ using rig pmp, bump plug. RIH w/6-3/4" bit & csg scrpr to 7991', WOC. The above is correct rDate Title 11/24/86 Drilling Supervisor For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 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. Accounting cost center code District Alaska Field Prudhoe Bay Auth, or W.O, no. AS0405 County or Parish Lease or Unit Title North Slope Borough State Alaska J Well no. ADL #28321 J 18-14 Drill Parker #141 API 50-029-21614 Operator ARCO Alaska, Inc. Spudded or W,O. begun Spud A.R.Co. W.I. 21.66% Date 10/22/86 I otal number of wells (active or inactive) on this est center prior to plugging and I bandonrnent of this well I our j Prlor status If a 'W.O. I 1500 Hrs. Date and depth as of 8:00 a.m. Ll107/86 11/o8/86 Complete record for each day reported 5-1/2" @ 10,075' 10,075', (0'), Drl LC Wt. 9.1+, PV 15, YP 6, PH 10.5, WL 14.1, Sol 6 WOC. RIH, tag cmt @ 8724', wsh to 8740'. Drl cmt f/8740'-8987' TeL, circ hole cln, POOH. RIH w/csg scrpr, drl cmt stringers f/8987'-9150' & firm cmt to 9959', tst csg to 3000 psi. DO plugs & LC. 5-1/2" @ 10,075' 10,075' TD, 10,038' PBTD, RR 9.4 ppg NaC1 DO cmt f/9961'-10,038', tst csg to 3000 psi. Pmp 9.4 ppg brine. Re-tst csg to 3000 psi; OK. Fill top 400' of 7-5/8" w/diesel. ND BOPE, NU & tst tree to 5000 psi. RR @ 0400 hfs, 11108186. Alaska Oil & Gas Cons. Commissio~ Anchorage Old TD Released rig 0400 Hrs. Classifications (oil, gas, etc.) 0il Producing method Flowin$ Potential test data New TD Date I PB Depth 10,075 ' JKind of rig I 11108186 tType completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit 10~038' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day P~Jmp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDet~ 11/24/86 JTi.e Drilling Supervisor ADDENDUM WELL: 11/12/86 18-14 Rn CET/GR f/10,036'-8795' w/o pressure & w/1000 psi. Rn GCT gyro @ 200', pull up, hung up below tree in wellhead. Pulled loose. (Note: k~en removing tbg hgr, ck pin end of pup jt f/damage caused by GCT tl.) PU new GCT tl w/o anchor arm, RIH, log f/9957'-48', RD Schl. ~aska Oil & Gas Cons. Anchorage Date C) C) .,. .i. June 18, 1986 Telecopy: (907) 276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 18-14 ARCO Alaska, Inc. Permit No. 86-119 Sur. Loc. 930'.FNL, 341'FWL, Sec. 19, TllN, R15E, b~4. Btmhole Loc. 1265'FSL, 1474'F~L, Sec. 19, TllN, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverrmaentaI agencies priOr to commencing operations at the well site. 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 Conm~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ ~ V. C~amtert'on Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~ISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o enci. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C~. ,IMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry [] Deepeni-iI Service [] Developement Gas [] Single Zonei,~._,Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 50', PAD 17'GL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 28321 ALK 2319 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 930'FNL,341 'FWL,Sec.19,T11N,R15E,UM(approx) Prudhoe Bay Unit Statewide At top of productive interval 8. Well nu ,mber Number 1386'FSL, 1430'FWL, Sec.19, T11N, R15E, UN 18-14(producer) #8088-26-27 At total depth 9. Approximate spud date Amount 1265'FSL, 1474'FWL, Sec.19, T11N, R15E, UN 06/19/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ( planned ) 9994 'MD ,~41' ¢ surface feet L2-3 117 '¢7880 'TVD feet 2560 f8869'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 Kickoff depth 4100 feet Maximum hole angle 400 Maximum surface 3020 psig At total depth (TVD) 3900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-hO W~.d ~O' 33' 33' !!3' !!~' 290 ft3 Pc~,~sct /~c;_&~ I -RCI IRTf~ ~'~R7' 11'4' 11'4t '4&CIO '4r~CI(3' b. f3CI ~× C_l~ C 9-7/8" 7-5/8" 29.7# L-80 BTC 9963' 31' 31' 9994 8869' 300 sx Class C CONTINGENCY LINER: 6-3/4" 5-1/2" 17.0# , L-80 FL4S 1040' 8954~' 8072' 9994' 8869' 100 sx Class G Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°r~;TM RECEIVED Intermediate Production JUN 1_ 7 1986. Liner Perforation depth: measured Alaliik& 011 & Gas Cons. Commission Niclmrage true vertical 20. Attachments Fil~n~ fee ~Property plat [] BOP Sketch '~ Diverter Sketch [] Drilling program~!~L~ ~_~ Drilling fluid program [J2~k~Time vs depth plot [] Refraction analysis [] Seabed report F_3 20 AAC 25.050 requirementsjj~,~. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /- . Title Regional Drilling Engineer Date Commission Use Only (JRR) PD/PD278 ~ I A5~--n u.~ .1~~ I Approval date j See cover letter Permit Number ?'L:-I ! ~- '~/~'~ [ 06/;[8/86 for other requirements Conditions of approval Samples required [] Yes [:~...No Mud Icg required E~ Yes ..~No Hydrogen sulfide measures [] Yes [] No Directional survey required i~ Yes E~ No Required working pre ure for BOP · . M; Other: by order of Approved by Commissioner the commission Date Fnrm 1f'l-4f~1 Rc.v 12-1-R.~ SubS, ~ triplicate DS 18-14 DRILLING PROGRAM .1.. Set i6" 'conductor and cement. . 2. M IRU Nabors Rig 26E,. 3. Drill 13-1/2" hole 'to 3500'MD(3500'TVD). 4. Set 10-3/4" casing *and cement to surface. Test casing to 2000 psi. Pe~df.orm l'eakoff tes;t. .... " ', ~ ' ' 5. Install 13-5/8", 5000 psi, RSRRA BOP stack . Drill 9-7/8" hole to 41'O0'MD. Kick off and'~buil'd .2.5°/100' S20°10'E to 39051'. 6. Hold and continue drilling 9-7/8" hole to 9994'MD(8869'TVD). 7. Run open hole logs. 8. Set 7-5/8" casing and cement. Displace cement with 9.4 ppg brine. Test casj.ng to 3000 psi. Spot 400' diesel cap. 9. .Secure .well and release rig. 10 Run cased hole logs. 11. MIRU completion rig. 12. Run 3-1/2" completion assembly. Set packer above Sadlerochit. Perforate with tubing conveyed guns and drop same. 13. NU tree and test to 5000 psi. 14. Secure well and release completion rig. ·. NOTE: · a. Reserve pit fluids will be disposed of down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. If hole conditions warrant, 7-5/8" casing will be set IO'TVD above the Sadlerochit and a 5-1/2" contingency liner set at TD. c. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. d. Maxi*'~m~_~face pressure is based upon recent BHP surveys and a full column of gas to TD (0.10 psi/ft). e~. Existing wells within 200' of the proposed well are: L2-3, 117' at '' *;' ~;'~**~'~ 7~80'~VDii~ina~171 ' at 8239'TVD. PD/PD278a:tw DS 18-14 MUD PROGRAM Plas Density Vi sc. Depth (TVD) #/gal (CP) Yield Point Initial 1OM #/100 ft Gel Gel FL CC/30M Surf 8.8 Funnel to to 100- 10-3/4" 9.2 250 Csg Point % % pH and Oil Solids ,Type of Mud 40-60 30+ 50+ 25 0 8 Operate all solids removal equipment to maintain PV as low as possible. cement contamination. .SET 10-3/4" CAS lNG 2 2 5 25 to to to to 4 5 10 10 10-3/4" Csg Shoe 8.8 to to Mi nimum K-lO 9.4 Possible Operate all solids removal equipment to maintain weight as low as possible. K-lO 9.2 10 6 4 8 15 to TD to to to to to to (7-5/8"Csg Pt) 9.8 20 10 8 12 10 Gel-Benex Spud Mud Pretreat with Bicarb or soda ash for 3.5 Low Sol ids to Non-dispersed 6.5 4 pH 9-10 to Low Solids/Non-Dispersed 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaners and centrifuges PD/PD278b:tw RECEIVED JUN 1 7 1986 Alaska Oil & Gas Cons. Commission Anchorage DS 18-- TYPICAL MUD PIT SCHEMATIC PIT 7 AGITATOR i i WATER TANK AGITATOR DE S ILTER PIT 3 ~ATORS RECE JU l --'] AlaSKa OII & (~a$ PILL Ancho PIT PIT 6 DEGAS~ AGITATOR PIT 5 SAND I SHAKERS TRAP I CUTTINGS CONVEYOR PIT 4 AGI PIT 2 CENTRIFUGE AGITATOR PIT 1 ;ER IVED (DRAWING NOT TO SCALE) 1. System is equipped with a drilling fluid pit level indicator with.both visual and audio warning devices located in the immediate area of the driller's console. 2. System is equipped with a drilling fluid flow sensor with a read-out convient to the driller's console. ~NNUL~k:I · PREVENTOR PIPE RRHS BLIND DRILLING SPOOL P['PE RRM$ 1. 10. 11. 12. 13. 14. 15. 16. 17. I$-$/$'~BOP STACK DIAGRAM ;ccumulator Capacity Test Check and fill acct~ulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1SO0 psi downstream of the regulator. Observe time, then close all units simultaneously and record the tim~ and pressure remaining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing tim~ and 1200 psi remaining pressmre. 13-5/8" BOP Stack Test 18. 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 predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 5. Close annular preventer and upstream valves. 4. Functionally test chokes. 6. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of $ minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum o£ 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 S000 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 r~ms. Incresse pressure to 5000 psi below the bottom set of pipe r~ms and hold for at least 5 min- utes. Test reamining untested manifold valves (if any) with $000 psi upstream of valve and zero pressure Bleed pressure to zero. Open bottom set of pipe r~. Back off running joint and pull out of hole. Close blind r~ms and test to S000 psi for at least 3 m~tes. Bleed pressure of£ all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and insid~ BOP to 5000 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOPB test once a week and func- tionally operate BOPE daily. RECEIVED JUN 1 7 1986 Alaska 0tl & Gas Cons. Commission Anchorage Revised 2/21/84 D81814 w 1000 2000 3000 4000 50C 6000 700( 0 0 1000 2000 3000 4000 5000 6000 8000 0 1000 2000 3000 4000 5000 6000 7000 8000 ARC13 ALASKA, INC. !lCALI= I IN - 1l~013 Fl,_ SHL: 930'!FNL, 341' SE 0.19, T11N, R 6E, UM (APPROX) THL: 1386' =SL, 1430' F~/L, RFC 1t:1_ ',11N_ RlfiF. Il ~ ~_~ 10-3/4' CASING TVD ~' 3500 ' ' (OP TVD- 41 10 2.5 17,5 22.:5 /:'.5 ' s ~o D,~G ,o ~,N E 3168 FI'(TO TARGET) i'~.,.~ AVERAGE ANGLE 37..5 EOC T~rD -- 6569 MD ' 56845~ED~I~3~IN ~ K-lO TVD "' 6925 MD "7461 DEP - 1665 LCU"VD~'8110 MI ~.9004 DEP ~'2654 SA(. RIVER TVD -- B205 MD -- 91:!8 DEP -- 2733 TOP SADIIEROCHIT TVQ~=i 302 MD "9254 DEP "2814 Slit IBLIK TVD -- 8:~48 MD -- 918z DEP -- 2769 G[/O CONTACT TV ~ - 8665 MD ~' 9727 DEP -- 3117 '~. , TARGET I VD - 8714 MI)- 979~ DEP - 1166 = = F IT T' =-8762 MO -= 9854 DEP 3198 BAS~. SADLEROC.I~ ,T~ ID -% ?-5i6' CASi~_q, :n ~n Mn 9.q;~4 n;~ '=,~? 9000 TD TVD - ~869 MD - 9914 D'EP - 328~ - o I ooo 2000 3000 4000 sooo ~ooo ?oo~ VERTTCBL SECTION lO000 CE: W RECEIVED JUN 1 7 1986 Alaska Oil & Gas Cons. Commission Anchorage ~J - N UUU~UIINfqlC~J o -2000 -1000 0 ~- 1000 2000 5 - ] 4000 5000 ! i i i i i i i i i i i i i i i i i J i i t i i I i i i i i t i i ! i i i i i i J j i i i i ! i i .~HI' l::l~fl' ~1 Il ~41' ~WI S1[C.19, TllN, F 1SE, UM (API'ROX) THL: 1386' FI ;L, 1430' FW .. SEC.19, Tlll 1, R1fE, UM .... , os 8 TARGET TVD ~ 8714~ DEP ~ 3158' , ,,, :", , I , , , , , , , , ,', , , ' ' .... ' ..... ~ ' ' ' ' ' ' ' ' .... ' ........ ' ' ' ' ' ' ' ' ' ' ' ' 'il -2000 -1000 0 1000 2000 3000 4000 w cz) 0 z E - N OOORD INRTES RECEIVED JUN 1 7 1986 Alaska Oil & Gas Cons. Commission F, - N COORDINRTES ..~ -2000 - 1000 lO00 2000 ~000 ~000 5000 DS OS OS 1 DS o° ~~3 ~ / ~,..~n' ~lll 341' FWI DS 1[. ~F 'N~' S~C.19, TllN, F15E, UM(API'ROX) ~~~)9~ THL:1386'F',~L, 1430'FW., 1 ~ _ ~ ~ ~ [~9 SEC.1*, Tl11~, R16E, UM 18 °8 ~9~ ~21 I i TARGET zDS 18-3 38C ~ TVD = 8714 o ~ F NBN/IkP~- TMD -- 9791 ,'303 7[ ;~41089 ' 8~10 ES 5-16 ~ - [ 5 lS-1 ~ - I ,, , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ,i~, 7~ . U'UJ .... -2000 -1000 0 1000 2000 3000 4000 5 3(10 E - N COORDINRTES RECEIVED JUN 1 7 1986 Alaska 011 & Gas Cons. Commission Anchoraoe -S00 1--] - N L;UUI"(U 1 I',11-'1 .L -P. O0 -10"-- 0 100 "--' 500 400 W Z C~ LO CD -200 -i00 0 100 200 300 400 £ - H COORO I N2TES R EC E IV E D 31 JUN 1 ? 1986 Alaska Oil & Gas Cons. Commlssbo Anchorage 800 ~900 !00.0. Z100.. 2200 2300 2400 2500 2600 2700 500 600 700 800 \ \ ~'\7300 \ \ 7 400 \ \ \ 500 \ \ ~7600 \. RECEIVED 900 -- 1000 1100 1800 7470 75O0 I I I 1 900 7600 20O0 7700 7800 2100 7900 220O '§oo 2300 JUN 1 7 1986 Alaska 01t & Gas Ca~. CommJssio,~ s2o~aOOO B300 S B ~ O0 8400 ~, 8200 8500 ~ 8300 Anchorage \ I ann 1 nnn 11 O0 I2400 _ 2500 _ 2600 l 2700 ARCO Alaska, Inc. Post Office Box 200360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ^pril 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat- DS 18 IWells 5, 8, 9, 12, 14, 19) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, ~. Gruber Associate Engineer JG/tw GRU1/06 Enclosure RECEIVED APR 2 AlasKa Oil & Gez Cons. ¢ommissior, ARCO Alaska. Inc is z S,'bsldiary of AtlantlcRichftetdCo~gan~, III I II I II // ,' ; , /~,)~ '"""'""' "~l · :1 , ....... ~ I. ~ATE PLANE C~RDINATES ARE ZONE 4. . ~ALL GEODETIC POSITIONS ARE BASED ON ~D 19~7. ~ S PU~D BASED ON PROTRACTED VALU~ ~ ~ I ~ ~ ~ I~ ~ OF THE SECTION CORNER POSfflONS. I i II II i I I I I STATE PLANE COORDINATES ~[ODETIC POSITION ~/8 PLANT COORDINATES 9 486' FNL 342' FEL 5,961,37~.92~691,406.24 170°i7'56~"J48°26'59J~4" 2125 425 8 603'FNL 312' FEL 5,961,257.55 691,459.~2 ~70°i7'55.~9~'148°26'58-235" 2005 425 5 951' FNL Z21' FEL 5,9~,.911 .~4 691,558.57 ; 70017'. 51.96~'148°26'55 .600'' 1645 19 1358'FNL Il6' ~L 5,960,507.66 691~654.~5 i ~17'.47.9~"14~26'52.526" .IZ25 425 14 929' FNL 341' FWL 5,960,947.74 692,100.14 7~17'52.1~'~148;26'39.208"tl525 975 ' ,,I , ,, 1 12 1161' FNL 401 FWL ~ 5,960,717.041692,166 29 70o;7'49.~5 ~148o2637.452 i!2S5 975 FEL= ~OM EAST SECTIO~ ~w~= r.o. w~s~ s~c~o, b~.E APR 2 1 !985 Alasl~ Oil & G~ Cons. Comm~ssmr I II I i ~ m ii II I I CERT~I:ATE ~ SUP~EYOR. ~~~. AS-BUILT ~ELL LOCATION ..... ,,~, .,.. ,:...p~,~ D.S. 18 RESISTERED AND LICENSED TO PRaCTICErS.,~'-'' ' '%,-~'J . ' . ..... ..... ..._,..., kL~SK& A~D THAT THt5 PLAT Re. ~ HOWARD J. SHERMAN ~ ' IT (3) Admin Permit . eeeeeeeeeeee'eeeeeeeeeeeeeeeeeeeeeeeeeee . 2. well b lo d fi 1 ' . , :~Is to e cate ' a. e ned poo ............................. thru 8) .- '3. Is well located proper distance from property line .................. (1.4 thru 22) (~. thru 'i 3),. 10. : - (10' and 1~)~ 12. 13. .(23 thru 28) (6) OTHER _~,~' ([29 thru 31) Geology: JAL EngiBe~ering: LCS ~BEW MTM ,~ HJH ~ rev: 04/03/86 6.011 4. Is well located, proper distance from other wells .................... 5. Is sufficient undedicated acreage available-in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ~ ................................ 8. Can permit be approved before ten-day wait .......................... 'ES Does operator have a bond in force .................................. ~ ,, Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does 'the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. .zig. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well-to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is diverter system required' a eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of , ---r.L_i BOPE attached. ~ Does.BOPE have sufficient pressure rating - Test to ..~O~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of HgS gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................ ~ Are seismi~ analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Company~ LIBRARY TAPE CURVE SPECIFICATIONS Well D.S. 18-14 Field County, S~a~e Pr6dhoe Bay North Slope, Alaska DaCe 11/4/86 Curve Name (Abbrev.) . -- Log~ Used Standard Curve Name Scale i · RFOC Resistivity Focussed DIFL .2 - 2,000 RILD ResistivitY Medium ind. " ,: RILD Resistivity Deep " " " ,, GR Gamma R~y "J 0-100, 100-200 AC Acoustic Log AC 150 - 50 SP Self Potential ' DIFL -100 - 100 · . GR1 Gamma Ray CN/CDL 0-t00, 100-200 CAL Caliper " '0 - 16 CN Compensated Neutron ' 60 - 0 CORR Correct ion " -.25 - .25 DEN Bu!k Density " 2 - 3 PORD Denisty Porosity " "60 - 0 C'~p~NY:A>CO,._, ~L.!qKA~ ~YN~w . ~ELC: 3.$.1c~-14 =!{LD:m~UDHO~ 8~Y COUNTY:N.SLOm: FILE:M~IN .001 FILE INTE --:mT Ac ,, .:c: IO06F.UO0 I 905.7. $99 1 004.7 10557.J0'3 100Z7.OOO ? · 975 q.~J. Z46 .) I dL}d (. ',JO U 79.17_~ ~-)4 ?. 000 ~. 934. ,f:2.7~7 9P27,J03 ~.G:;4. 53.5 =~ 93 :~7 .CO''~ ?. ;/3~, · ~ I --,. ZI ? . ? .... , m ,-; -v 4;73, }I .953 0 '~' s,, ~, ~ _:,. _~! ,11S 7~ I~1,2.27: -~' ,' 57'. ]3-: 30.173 :.., 727.5'05 -} 9 71 7. ,.:9'"' ':· ,c lS. 798. 737 9 3 9707.333 70.455 ..- ,' , >-; ; :~ 96 8 ?. 300 5. :¢ ~.4 '~ ?~ ..:,,81 ~"=1/ !3r . _~S 1-'~ .3! ~' c.-~ ,.-'i o~.12~ *.'?5' PRU3~92 F, ~ L',' R l L 7;' 16'3 ':--~'~ 1 O ¢~ -Su~..OOr, 5 U -~ 9497.000 9 -'-. d 7. Uu _, 9q. 77.00~ 9.67.303 0 - 5 .~ u 94.57 '.30'~ ] 9¢4 · LI . i 24.536 ;::/1 · ,-,, :,, ,:. 7 · ,3 O 3, 'f.; 4 I :JS...bT 5 ~437,009 3. '-'~ ,:,, :.,, ~ ,. ). 532 ~41 /'. UUO J .v,54 '-~" .! 1 ' .O Z · t, 1 4 q ,..30.77 .Z 939 F. '30:3 10-i.124 .2~PT ,,"AL ~C ! !5 t , ~ 6 O 92'~7 300 3 087 4TM 1 'J2,4 ~ 2 3 F. 9 0 ? CZ 1 7. ,38 ? 52 .~+23 9 3.}'8~ -.'- .2 43.103 0.03 n...-263 10000 ~207.000 3.~3) 9187.000 3.~83 ;}177,06.7 .~. -3_:; 9167.00J 41 · 75,7;~&~ 2·2ti 1270:5;..---J..- 915 ?. 50;2 _ . ---' .' :~ P*,J3mOE 5~¥ NO~., H ,; ', 4 '? · ',j 3 :·;:_,5 · 9057. 003 ~ ) I · .{,~.0 p yUl /.dUU ?Ju, .,-, -, ~¢7.:303 ~77.000 a ,~07 · OC'O 51 .C55 0.2 14 '~ 3,EeS. ~57 000 3.9c'4 115 ~R OGRA;~I=L,~ LTM S :, -V. ] 15067.;3.33 :.973 13~.~23 41 .! ,O.: 0 I 00~7. 003 3 .S73 1 3:.::. 32¢ 4.1 .105 O.OOO 13027.033 3.c73 13017.33 I 0307.3'3'3 :' · ,~ 3! .02t 17.033 1t5 2?= P-747.~00 ~. ~"'~,, 01 .0~.6. 9n 21'; ??27. DO0 x · 97; 64. !40 9907.000 5.97P ~. 3,3 .~' 1 c f?. ~ 3 (, I 3. '-] O 9 .>'. -$ ,./-.,. 01- 3 6.1 3 6 dUO :4 4';,7 :i0 1 0:.3' .07J 3b~5.5 dUO · 90.18¢ £7.C11 1 32 · 49n ,~0a ·'71 b 970-7 ~.v3 ~ ~7,~ ;7.':JJ35 ~6.122 i ', 737. 333 '~ · :-;7 3 21,/, :~,.5t0 9727.0.00 3. .9Pn -60 · '.-,x ~717, . ,50"- _~ . c7:- 102.17~ ~707.300 3.973 74 9087 30* ~ 973 34 AS~ 0. 000 t 5¢,26~, ~35, . ":17 9v67.003 ;.97~ 333 -'. 07'7 '~ !{ . ;: * '-)5~7 000 ""z ~77 21 017 · .,, · - , i 9~07 · 0!}9 c4.5;~'~_. ?O'~ .1 41 · ~'557,003 7.c77 2!.1~3 7~.2~t ~3Z.795 ~537,000 ,:z, c, 7: 2't ~, 5 2 ?. 3 3 l, '? . -, 7 v 7 :~. "-'_-' ._ 73. 773 ~,59. 951 7. 009 2. ~77 25. 573 -c~. I ~, ? I e3. :-7'3 ~2.711 416.!~0 - :.. · · ...-, ~ . ·, .- m --' · ',~; -,- - -61 .813 9,477. 303 ~.s77 19.392 94.'57.003 3.97~ .~6.0;1 7 % · ¢'; [-.* -> ':' _* : . .5 4 ~ 303 '~. ~7 ::, I';x 924 41~.zlC: 9~+37.003 3.977 20.3S7 '-03.0,~1 9417.30,..3 ;. c27,~ e-5.0~t :7.. 33 i" I :."-.). 6 C. :'--. I 9 · 000 17.556 -57, ;.33 t , '. .... '>7:~ c'~ 75,_; 17',742 -a7.',t77 :-,) 7. / 8 "- 7;> q7~ . · ' "3 ":'- 0 ',:+ 9 9387 -300 3 ~7'~ ._,~· -,, -.' 5 7 · .30 C " 7 47.36-' 92a7.00g ~.975 . , .::,. 5.5 ": 5 .550 -ti2.587 ~ . 42.50~ O.CO0 I .212 -119.24~ 9207.000 3. 973. 44.775 91"37..3'33 '5. :~77 41 ·4 -~c b4.77) O.n'nn,~.¢u 9187.003 ~.07~, 1~2.606 c 1 77.30 0 -'::..; ? ~ 7 2. ~ 5 50.0~'7 O. 0,,, ~, -91 67.,.,no0 3 . c~7S 713 · ~,';,~o.... ~14.7·00,3 3 97 '~ .3:30 1~C.63.5 10. 000- 5! .259 -11! "",' 377. ,3:3 '3 ; · :~ 7 F O.OOC O~.pT_ r',., .&L ~ :.3 v 7.02 ) :... :.,. ";' 7 ,"0357.00 9057. 330 3.~73 !~4.ZI'~ 901 7. 300 .3. -~v,:..... 1C~ . 544. 52.43.~ ~ · m · ~'97 Ou3 3 97'7 ~!.~9) 5 ~. 6,31 5977 000 ~ 976 ¢'¢07.3."J] 52.335 3.0~0 c 123i -: ? 160 -5:~6 t3 nO''~ 5~.5'z7 -111 · ,ii .¢ 447 119 53~ t3 ' 9.90C 0.900 l .863 -112.6o0 ~957.003 3.%7o $~ 5<1 ? · s, v .:.. 52.167 1 7 9 7 -~ -- 0 .O00 - ,~,~n lo3.,50~ 19.0nc 50. x7-' -111 9.900 ;O.-O,OO.; 3 ::: PiLE: GRP~.SS 3;] ¢. LE iNTE~VAL: 'J310 ,3,]o " .';' 2 5 L'. C3 3 o~ ~,2 4 0..3..-.}$ 7?. 1 2'; 7175.0'],3 I I 9 · .3fi ' OaPT 877~.300 68.743 8.740,000 8° · t ~ ' l -' ~ 87;2_6,300 8B.31 3 ~3716. 003 90.6~9 S706,300 32.467 8596.000 ~P.933 8676,000 ~obo,OoO V'l.U'l ?' 864~. O:.J9 9a.35Z .d6Z6.OO3 11~.152 8610.000 115.Z76 8505.003 iP4.tC3 ~550.009 t:2,3.t17 ~535.33:3 132.1~3 ,5526.000 Ia!.06'3 ,~16.300 13t .£71 5506.0'39 11"3.~3C 5~S6.000 10S.332 8.7~.090 12~, .55~ 54~5.003 14o.263 £45~.0,,39 - 93.29~ Sa.a. 6.O03 5436.300 5~.:~. .:30.3 S410.OOO ~405,000 105.613 53~6.000 130.1°3 ' 'PRUDH05 ~&Y '-'NO;;TH 7'6· OOU 1 ,~ :'-' · ~1 S 830~. 000 ! 1 7. elo ~3~0,000 10~ 5276.'J00 5~5¢ U2Z~.OOO 3210.300 ,~2-06.000 t14,48~ -'-3196. 003 11'5.247 5175.003 65.73/, ~1'46.00:] 73.520 3126.000 61.411 S 1'1'6 O0n . ~ 1'0~ . 000 6~. '964 30¢~. O0~,. 75 . ;58 5015.003 ,3306. O0'~. os . ~i... 7 c~-7' 6.300 ~0.!6S 79~6.203 c.'.b 5. 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',¢.,. 75 .JO3 50.031 4q. 66.0C3 5,_~,. 4~6.000 4~36.303 a425.002 ~1o.303 4,06 · 000 5 ~. 21 ~ a3.35.000 ~.52~ DE~T GR q. 36o. C;O0 4536. O00 3 3. 134: :: 45Z~.000 32.00~ ~-51 6. 003 27.10~ 4266.000 4 4,Z "'" ~ · ddd 4216.000 54.151 4196.003 55.03~ 41 dO .UUO ,;,,4 ..~, 41Z6.003 54.867 414O,;.JUd 4U·Y;~J ~td6.OUd ~6.146 a,a3o. 399 3o.511 q. dO0.O:33 ~:"~"- 2'31 S99:~.000 3s.651 395~.,303 ~.$.689 3~4,.~ . 30 3 3~3~.003 3~Z6.003 39t 6. 009 3~Sae · O0 9 .... : ?,7 :~U3~''' '~: ~ a Y---NO?.. Tm DEPT G~ 35~.003 ~!.20~ ~5a5. 300 ..... .~ ;z56 . L)''~ ,-~ ...... ,~w 4~' 71 :j 377o.3C0 5FbO.U,UU /,,.7.127 4.5.495 5/16.00U 54. 54'5 5FL)6.OOU 3676.rJ00 3°.15F ~abo .009 55~'8.000 57. /UU 5~00. UOU 56.40 7 3~46.000 5;.o4g ]o3,b. OuO 5o~O.UUU j57c..OJ3 i~.':'. '" 3556. O0q.,¢ 50 .44d 354-5. ;30, 3 ,,.,, I .121 5535.303 352~.003 3516' ¢3 47 7~3 .., 3506.000 54~.00U 347o.003 47.710 3460.003 32.5ZG 3464.500. 2-~. .~10_ ALASKA COMPUTING CENTER ~mmmmmmmMmm~mmmmmmm~m~mmmmmm~ ~------- SCHLUMBERGER COMPANY NAME : ARCO ALASKA., INC, FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE ~ ALASKA API NUMBER : 50-029-21614'00 REFERENCE NO : 92151 RECEIVED AUG 0 5 1992 Naska Oil & Gas Cons. Commission Anohorage Tame verification Listing ;chlumberger Alaska Computing Cemter 9-jUb-1992 06:55 **** REEL HEADER **** SERVICE ~AME : EDIT DATE : 92/07/ 9 ORIGIN : FLIC REEL NAME : 92151 CONTINUATION # : P~EVIOI/S REEL COMMENT : ARCO ALASKA ING,PRUDHOE BAY,18-14,500292161400 **** TAPE HEADER **** SFRVICE NA~E ~ EDIT DATE : 92/07/ 9 ORIGIN : FLIC TAPE NAME : 92151 CONTINUATION ~ : PREVIOIJS TAPE COMMENT : ARCO ALASKA ING,PRUDHOE BAY,l~-14,500292161400 TAPE HEADER P~UDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: APl NUMBER: OPEPATOR: LOGGING COMPANY': TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP~ RANGE~ FNL: FEL: FWL: EI.,EVATION(FT FROM MSL O) KELLY BI,)SHING~ DERRICK FLOOR: GROUN~ LEVEL: WELL CASING RECORD SURFACE LOCATION ~$T STRING 2ND STRING 3RD STRING PRODUCTION STRING 500292~61400 ARCO ALASKA. INC. SCHLUMBERGER WELL SERVICES 9-~UL-92 921 ! M,MCBRIDE K,MORRIS ~9 50,00 49,00 ~7.00 OPEN HOLE CASINGIZ D~ibbERS CASING BIT SIZE (IN) $1E (,ii~) DEPTH (FT) WEIGHT (LB/FT) 7,625 9296,0 29,,00 PAGE: tis Tape Veriflcatton Listing ;chlumberoer AlasKa ComPuting Center g-JUL-1992 06:55 CURVE SHIFT DATA - AbL PASSE8 TO STANDARD(HEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BCS PBU CURVE CODE: GR RUN MUMBER~ PASS NURSER: bOGGING COMPANY: BASELINE DEPTH 88 8 0 9905 9904 9899 9894 9872 9857 9827 9824 9810 9783 9743 9742 9705 9679 9662 9662 9607 9584 9533 =-=--=----EQUIVALENT UNSNIFTED DEPTH---------- GRCH 8R889 0 5 9905,5 5 0 5 0 9858,0 5 5 9825.5 0 9810.5 5 9784,5 5 5 9744.0 5 5 9680.5 0 9662.5 0 9608.5 0 0 9532,5 9517,0 9497,0 ~00,0 # REMARKS: 9534.0 9498,0 ~0~,0 TDTP 88889.0 9906,0 9899,5 9894,5 9872.5 9827,5 9744,0 9706,5 9663,0 9585,0 9534,0 95~7,5 100,5 THE OPEN HOLE INFORMATION SUCH AS LOGGING COMPANY' ~UN NUMBER & PASS NUMBER WAS NOT INCLUDED WITH THE TAPE SUPPLIED BY THE CLIENT THE DEPTH ADJUSTMENTS ~HOWN ABOVE REFLECTS CASED ~OLE GR TO O. EN HOLE GR AND C ,SED HOLE SIGH TO OPEN HOLE GR FIELO ENGINEER'S REMARKS: T~E~ ~NTO S~C aCOUST~bO~ Of ~-04-86. PUMPED IN DE~.D CRUDE TO p~SPLACE GAS IN BOREHObE. VOL[ ~ES PUMPED AS FOLLOWS. PASS ONE: 243 BBb, 0,2 B/M AT 400 PSI PASS T~O~ ~50 BBL, 0.~ B/~ ~ AT 400 PSI PASS THREE: 254 BBb-.0,2 B/~ AT 400 PSI TOTAL INJECTED VOLUblE AT END OF LOG = 260 BBb, PAGEI ,,IS Tape Verification Listing ;chlumberger Alaska Computing Center **** FILE HEADER ***~ FILE NAME ~ EDIT ,00~ SERVICE : FLIC VERSION : 001Ad7 DATE : 92/07/ 9 MAX REC SIZE FILE TYPE : LO LAST FILE : 9-JUL-Ig92 06:55 PAGE{ FILE HEADER EDITED CURVES Depth shifted and clipped curves for each pass ~n separate files, 0.5000 PASS NUMBER: DEPTH INCREMENT FILM SUMMARY PBU TOOL CODE TDTP START DEPTH 995~, 0 STOP DEPTH 9496,0 9496,0 # CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE. FOR SHIFTS PBU CURVE CODE: PASS NUMBER: -~--------EQUIYALENT UNSHIFTED BASELINE DEPTH RMMARKS~ THEIS FILE CONTAINS THE FIRST PASS OF THE TDTP TO PASS SHIFTS WERE APPLIED TO THIS DATA' $ FORMAT DATA NO PASS ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 84 4 66 ,IS Tape Verification Listing ;chlUmberqer AlasKa Computing Center 9-JUb-1992 06:55 PAGEI 5 66 6 73 7 65 8 68 0.5 9 65 FT 1t 66 12 12 68 13 66 0 14 65 FT 15 66 6B 16 66 0 66 0 mmmmmmmmmmmmmmommmmmmmmmmmmmmm ** SET TYPE - CHAN ** .,,.-.-.-.-...,---.----,.-..-..--...,...-.-..--,........................................ ~E SERV U IT SERVI E AP1 AP1 API API ILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD 'NUMB SA~P ELEM CODE (HEX) DEPT FT 425451 O0 000 O0 0 1 I I 4 68 0000000000 SIGM TDTP CU 425451 O0 000 O0 0 t ! 1 4 65 0000000000 TPHT TDTP PU-S 425451 O0 000 O0 0 ! 1 ! 4 68 0000000000 SBHF TDTP CU 425451 O0 000 O0 0 I 1 I 4 68 0000000000 SBHN TDTP CU 425451 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 425451 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 425451 O0 000 O0 0 I I 1 4 68 0000000000 TRAT TDTP 425451 O0 000 O0 0 1 I 1 4 68 0000000000 SDS! TDTP CU 425451 O0 000 O0 0 1 I I 4 68 0000000000 BACK TDTP CPS 425451 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 425451 O0 000 O0 0 1 I I ~4 68 0000000000 TCAN TDTP CPS 425451 O0 000 O0 0 1 1 1 ,4 68 0000000000 TCAF TDTP CPS 425451 O0 000 O0 0 1 I 1 4 68 0000000000 T~.ND TDTP CPS 425451 O0 000 O0 0 1 1 1 4 68 0000000000 T.FD TDTP CPS 425451 O0 000 O0 0 1 I ! 4 68 0000000000 TSCN TDTP CPS 425451 O0 000 O0 0 I I 1 4 68 0000000000 TSCF TDTP CPS 425451 O0 000 O0 0 1 1 I 4 68 0000000000 INND TDTP CPS 425451 O0 000 O0 0 I I i 4 68 0000000000 INFD TDTP CPS 425451 O0 000 O0 0 I I 1 4 68 0000000000 GRCH TDTP GAPI 425451 O0 000 O0 0 I I 1 4 68 0000000000 TENS TDTP LB 425451 O0 000 O0 0 1 1 I 4 68 0000000000 ** DATA. DEPT. SD$I.TDTP TCAF.TDTP T$CF.TDTP TKNS..TOTP 9952.000 39,156 0'201 26052'246 5281..507 t145,000 SIGM.TDTP D' SIGC,T ~P BACK,TDTP TCND,TDTP INND.TDTP 1015 , . 9 .936 3~629.695 189.295 TPHI.TDTP ~IBH,TDTP FBAC'TDTP TCFD,TDTP INFD'TDTP ]1'298 SBHF.TDTP 12421'i§ TCAN'TDTP 533. ~ TSCN.TDTP GR:CH'TDTP 13 8 0 . 2 B 1 '999'250 ~I$ Ta~e Verif~.cation £,isting ~chlUmberger Alaska Computing Center 9-UUL-1992 06:55 PAGE= DFPT, 9500.000 SIGH TDTP 1!,154 TPHI,TDTP SBHN,TDTP 40.899 SIGC:TDTP 0.597 SIBH,TDTP SDSI"TDTP 0,180 BACKiTDTP 133 649 FBAC.TDTP TCAF,TDTP 32692.863 TCND,TDTP 37458~03! TCFD,TDTP TSCF,TDTP 6688,824 INND,TDTP ]259,048 INFD,TDTP TE~S,TDTP 1155.000 DEPT, 9496 000 SIGH TDTP li.171 TPHI,TDTP SDSY,TDTP 0,160 BACK TDTP 13 9 FBAC.TDTP TCAF TDTP 34675.945 TCND.TDTP 37949.063 TCFD,TDTP TSCF:TDTP 7092.008 INND,TDTP 3300,865 INFD.TDTP TENS.TDTP ** E~}D OF DATA 15 512 SBHF,TDTP 40 899 TRAT.TDTP 29 ~17 TCAN.TDTP 14707 17 TSCN.TDTP 574 002 GRCH.TDTP 13.796 SBHF.TDTP 43.105 TRAT.TDTP 31.260 TCAN.TDTP 15093,~60 TSCN TDTP 549,783 GRCH',TDTP 35.938 ~.939 63403,586 o 41 33,3'73 io848 64072,77~ **** FILE TRAILER FILE NA~E : EDIT ,001. SERVICE : FLIC V~RSION : O01A07 DATE : 92/07/ 9 ~AX REC SIZE : 1024 FILE TYPE = bO LAST FILE : **** FI:bE HEADER **** FILE NA~E = EDIT ..002 SERVICE : FLIC VERSION DATF = 92/07/ 9 M.~.X REC SIZE : FI[,E TYPE = LO L~ST FI~E EDITED CURVES DePth shifted and CllpOed curves for each pass ~n separate f$.les,~ PASS NUMBER= 2 DEPTH INCRKME~.f 0 5000 # FILE SUMMARY PBU TOOL CODE TDTP START DEPTH 9938,0 STOP DEPTH 9496,0 9496,0 Tape Yerification Listing ;chlumberger Alaska Computing Center 9-jUL-1992 06~55 PAGE:" CURVE SHIFT DATA - PASS TO PA$SfMEASURED DEPTH) ~ASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER% 1 BASELINE DEPTH 9921 5 9906[5 9906 0 9900 0 9858,5 9846,0 9828.5 9782.0 9744'5 9707.0 9684.0 9664 5 9641:0 9612 0 9608:5 9586.0 9564.0 9563':5 9499,0 100,0 REMARKS: ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 9921.0 9904,5 9898.5 9857.0 9527,0 9742.5 9681.5 9639.0 9610.0 9607.0 9905,0 9844.5 9780,5 9705,5 9663,0 9584.0 9562,5 9561.5 9497,5 98,0 98,5 THIS FILE CONTAINS PASS TWO OF THE TDTP'i THE. DEPTH ADJUSTMENTS SHOWN ABOVE REFLECTS PASS 2 GRCH TO PASS t GRCH AND PASS2 SIGM TO PASS 1 SIG~.,. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECE)RD ~ ** SET TYPE - 64ES ** TYP~ REPR CODE VALUE ! 66 0 2 66 0 3 73 84 4 66 5 66 6 7~ 7 65 ~I$ Tape verification Listing ~chlumberger AlasKa Computing Center 9-JUG-1992 06:55 PAGE= 9 65 ll 66 !2 12 68 ~) 66 0 i4 65 FT 15 66 68 16 66 1 0 66 ! ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCESS. ID ORDER # LOG TYPE CLASS MOD NUMB SAMP E5EM CODE (HEX) mmmImmmmmmmmmImmm~Im-mmmmmmImI~mmmm~Im~II--Immmmm-mmm~I~I~IIII~mm~--~m-N-I-)INI-Im DEPT FT 425451 O0 000 O0 0 2 1 1 4 68 $IGM TDTP CU 425451 O0 000 O0 0 2 1 i 4 68 TPHI TDTP PU-$ 425451 O0 000 O0 0 2 1 1 4 68 IBHF TDTP CU 425451 O0 000 O0 0 2 1 1 4 68 SBHN TDTP CU 42545i O0 000 O0 0 2 1 1 4 68 SIGC TOTP CU 425451 O0 000 O0 0 2 I I 4 68 $IBH TDTP CU 425451 O0 000 O0 0 2 1 I 4 68 TRAT TDTP 425451 O0 000 O0 0 2 1 ! 4 68 SDSI TDTP CU 425451 O0 000 O0 0 2 I I 4 68 BACK TDTP CPS 425451 O0 000 O0 0m 2 I 1 4 68 FBAC TDTP CPS 425451 O0 000 O0 0 2 1 1 4 68 TCAN TDTP CPS 425451 O0 000 O0 0 2 1 I 4 68 TCAF TDTP CPS 425451 O0 000 O0 0 2 1 i 4 68 .TCND TDTP CPS 425451 O0 000 O0 0 2 i 1 4 68 TCFD TDTP CPS 425451 00 000 00 0 2 1 1 4 68 TSCN TDTP CPS 425451 O0 000 O0 0 2 ! I 4 68 T$CF TDTP CPS 425451 O0 000 O0 0 2 1 1 4 68 INND TDTP CPS 425451 O0 000 O0 0 2 1 ! 4 68 INFD TDTP CPS 425451, O0 000 O0 0 2 I I 4 68 GRCM TDTP GAPI 425451 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000 00000 O00ggO0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TENS TDTP bB 425451 00 000 O0 0 2 1 1 4 68 0000000000 , . ** DATA ** DEPT. 995~.000 SBHN.TDTP 3 .822 IDSI.TDTP 0,237 TCAF.TDTP 25530,398 T$CF TDTP 5162.010 T~NS:TDTP 1150.000 SBHF,TDTP .m .. 22 TRAT'TDTP BACK,TDTP 169.478 FBAC'TDTP 4~'Z14 TCAN,TDTP TCND,TDTP 38103'875 TCFD,TDTP i190 37 TSCN,TDTP INND,TDTP 2899'977 INFD'.TDTP 473:~22 GRCH,TDTP 2~ 85 65992 84 13343'::168 -999,250 ~IS Tape Verification Listing ;chlumberger Alaska Computing Center 9-JUb-1992 06:55 DEpT, 9500,000 SIGM.TDTP lo.851 TPHI,TDTP SBHN.TDTP 45,480 SIGC,TDTP 0 692 SIBH,TDTP SDSI.TDTP 0,162 BACK,TDTP 190:511 FBAC,TDTP TCAF,TDTP 32733.594 TCND,TDTP 37638' 367 TCFD,TDTP T$CF.TDTP 6690.976 INND,TDTP 3289.506 INFD,TDTP TENS,TDTP 1155,000 DEPT. 9496,000 SIGM.TDTP 11,117 TPN! TDTP SBHN.TDTP 44.480 SIGC,TDTP 0.925 $IBH:TDTP SDSI.TDTP 0.171 BACK,TDTP 188 044 FBAC,TDTP TCAF,TDTP 36234'594 TCND,TDTP 37848~359 TCFD,TDTP TSCF.TDTP 7399,146 INND.TDTP 3262.742 INFD,TDTP TENS.TDTP 1130.O00 END OF DATA 15 159 SBHF,TDTP 47 682 TRAT.TDTP 41 360 TCAN,TDTP 1.4749 506 TSCN,TDTP 560 1125 GRCH.TDTP 1~ 441 SBHF.TDTP 4 953 TRAT,TDTP 40 420 TCAN,TDTP 156~8 631 TSCN.TDTP 562 077 GRCH.TDTP PAGE: 3],930 1.928 63106,594 12899.432 31.936 33 311 1 781 64525 844 13176 252 37 000 **** FILE TRAILER **** FILE NAME : EDIT ,002 SERVICE ~ FLIC VERSION : O01A07 DAT~ : 92/07/ 9 MAX REC SIZE : 1024 FIL~ TYPE ~ LO L~ST FILE : **** FILE NEADER **** FILE NAME ~ EDIT ,003 SERVICE : FLIC VERSION : OO1A07 DAT~ : 92/07/ g MAX REC SIZE : 1024 FILE TYPE ~ LO LAST FILE : FILE HEADER FILE NUNBER: EDITED CURVES DeDth Shifted and cllDped curves ~or each Das$ iD separate PASS NUMBER~ 3 DEPTM INCREMENT 0,5000 # FILM SUMMARY PBU TOOL CODE ~m,~mmmmmmmmm ~RCH TDTP START DE.~ rH 993B,0 9952.0 STOP DEPT~4 9496,0 9496,0 ~IS Ta~e Verification Listing ;chlumberger AlasKa Computin~ Center g-JUG-1992 06:55 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODES GRCH -- ...... --EQUIVALENT UNSHIFTED BASELINE DEPTH ''''~'''''''8~R8 9918 0 9906~0 9905 5 9894~5 9858,0 9828,5 9827 5 9810 5 9744 0 9706 5 9698 0 9663 5 9640 0 9585'0 9562 5 9498:5 9498,0 100,0 # GRCH TDTP 88888.0 88887,0 g918.0 9g05,0 9905.0 9894.0 9857.0 9827,5 g826.5 9810,0 9742,5 9705,5 9696,5 9662,5 9639,0 9584.0 9561,5 9497,5 9497,0 99,.0 99,0 THIS FILE COgTAINS PAS8 3 OF THE TDTP, THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECTS PASS GRcH AND PASS 3 SIGM TO PASS ! $ LIS fOR. ~T DATA PAGE~ DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EL ** · TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 5 66 6 73 7 65 8 68 0 5 9 66 12 .IS Taoe Verification Listing ;chlumberger Alaska Computing Center 9-JUL-IS92 06:55 PAGE~ 10 REPR E VA UE 12 68 13 66 0 14 65 PT 15 66 68 16 66 i 0 66 ** SET TYPE - CH~N ** _ E SERV IT SERVICE API AP1 AP1 AP ILK NUMB MI]MB S E REPR pR ESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) D~PT FT 42545! nO 000 00 0 ] I ! 4 68 0000000000 $IG~ TDTP CU 425451 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 425451 O0 000 O0 0 3 ! ! 4 6~ 0000000000 SB~F TDTP CU 425451 O0 000 O0 0 3 1 1 4 68 0000000000 SBMN TDTP CU 425451 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 425451 O0 000 O0 0 3 I 1 4 68 0000000000 $IBH TDTP CU 425451 O0 000 00 0 ] I 1 4 68 0000000000 TRAT TDTP 425451 O0 000 O0 0 3 I I 4 68 0000000000 SDS! TDTP CU 425451 O0 000 O0 0 3 1 ! 4 68 0000000000 BACK TDTP CPS 425451 O0 000 O0 0 3 1 I 4 68 0000000000 FBAC TDTP CPS 425451 O0 000 O0 0 3 t I 4 68 0000000000 TCAN TDTP CPS 4254~! O0 000 O0 0 3 I I 4 68 0000000000 TCAF TDTP CPS 425451 O0 000 O0 0 ] 1 I 4 68 0000000000 TCND TDTP CPS 425451 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 425451 O0' 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 425451 O0 000 O0 0 3 1 1 4 68 0000000000 T$CF TDTP CPS 425451 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 425451 O0 000 O0 0 3 i 1 4 68 0000000000 INFD TDTP CPS 425451 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 425451 O0 000 O0 0 3 I 1 4 68 0000000000 TENS TOTP LB 425451 00 000 00 0 3 1 .1 4 68 0000000000 ** DATA ** SBHN:TDTP 38.731 SIGC.TDTP . SDST.TDTP 0'247 BACK.TD~P 22 TCAF TDTP 24893.320 TCND'TDT~ 3~753,555 TSC'F:TDTP 5027.742 IMND.TDTP ..07.058 TENS.TDTP li45.000 DEPT, 9500.000 SBHN.TDTP .43.040 SDSI TDTP 0.216 TCAF:TDTP 29565'.270 T~C~' TDTP 6037.988 TENS:TDTP J. 160,O00 SIGM.TDTP 10.785 $IGC,TDTP 0.449 BACK.TDTP 226.669 TCND'TDTP 36002'875 IMND.TDTP 3248.618 TPHI,TDTP SIBH,TDTP FBAC.TDTP TCFD.TDTP IMFD.TDTP TPHI.TDTP SIBH,TDTP FBAC,TDTP TCFD.TDTP INFD.TDTP ]2' 381 8' ? 31 56.986 11690.'053 483.686 t6.394 43. 504 47 ~!o~ 13915' 57:3. 96~ SBHF.TDTP TRAT.TDTP TCA~{. TDTP TSCN, TDTP GRCH, TDTP 1~t86,92:2 ..999,;250 TCAN,TDTP 5846~ 773 TSCN;TDTP !:!939 193 GRCH'TDTP 41 875 .I$ Tape verification Listing ichlumberger Alaska Computing Center g-JUL-1992 06:55 PAGE: 11 D~PT. 9496,000 SIG~ TDTP SBHN.TDTP 44.337 SIGC:TDTP SDS!.TDTP o.152 BACK.TDTP TCAF.TDTP 39262 242 TCND.TDTP TSCF.TDTP 8018~322 INND.TDTP TENS.TDTP 1170.000 11,529 TPHI.TDTP 0.720 SIBH.TDTP 221.073 FBAC,TDTP 40285.352 TCFO.TDTP 3164.223 INFD'TDTP 13.879 SBHF.TDTP 45.83] TRAT.TDTP 45.706 TCAN.TDTP 166389.52~ TSCN.TDTP 55 . GRCH,TDTP 34,549 1,842 72339,625 14773.541 40.375 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VFRSION : 001A07 DATE : 92/07/ 9 MAX REC SIZE : 1.024 FIL~ TYPE : LO LAST FIDE : **** FILE HEADER **** F~LE NAME : EDIT ,004 SERVICE : FLIC YERSION : 001A07 DATE : 92/07/ g MAX REC SIZE : 1024 F!L~ TYPE : LO LAST FILE : F~L~ HEADER FILE NUMBER~ 4 AVERAGED CURVES Compensated ~eutr~n: Arithmetic average of edited Passes for all CU'TVeS,' PulSed Neutron~ Unaveraged edited Pass 1 aamma ray and backround counts'; arithmetic average of edited static Dasellne passes for all or, beT curves, ' DEPT!~ INCREMENT 0,5000 P~SSES INCLUDED IN AVERAG~ PBU TOOL CODE PASS NUMBERS TDTP ~, 2, 3, REMARKS: THE ARITHMETIC AVERAGE OF PASSES ! 2. & 3 ~AS COMPUTED ' . ~ STMENT$ WEREA~ AFTER ALL D...~PTH ADJU PLIED, $ ' LIS FORMAT DATA Tape verification Listing ~chlumberqer AlasKa Computing Center 9-JUb-1992 06:55 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ...... .... TYPE CODE VAbUE m~mm,mm~m{m~m~m~m~m~mmm~m~mm~mm{m~m~m~mmmmm~mom~ I 66 0 2 66 0 4 66 5 66 6 73 7 65 8 68 0,5 11 66 12 12 13 66 0 14 65 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** · NAME SERV UNIT SERVICE API APl AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # hOG TYPE CLASS MOD NUmB SAMP EhEM CODE (HEX) DEPT FT 425451 O0 000 O0 0 4 1 1 4 68 $IG~ PNAV CU 425451 O0 000 O0 0 4 I i 4 68 TPH! PNAV PU-S 425451 O0 000 O0 0 4 1 I 4 68 SBHF PNAV CU 42545~ O0 000 O0 0 4 I I 4 68 SBHN PNAV CU 425451 O0 000 O0 0 4 1 1 4 68 SIGC PNAV CU 425451 O0 000 O0 0 4 1 I 4 68 $I'B~ PNAV CU 425451 O0 000 O0 0 4 I I 4 68 TRAT PNAV 425451 O0 000 O0 0 4 I I 4 68 SSS~ PNAV CU 425451 O0 000 O0 0 4 I I 4 68 BACK PNAV CPS 425451 O0 000 O0 0 4 I 1 4 68 FBAC PNA*V CPS 425451 O0 000 O0 0 4 I 1 4 68 TCAN PNAV CPS 425451 O0 000 O0 0 4 1 ! 4 68 TCAF PNAV CPS 425451 00 000 O0 0 4 1 1 4 68 TEND PNAV CPS 425451 O0 000 O0 0 4 1 I 4 68 TCFD PNAV CPS 425451 O0 000 O0 0 4 1 I 4 68 TSCN PMAV CPS 425451 O0 000 O0 0 4 1 1 4 68 TSCF PNAV CPS 425451 O0 000 O0 0 4 1 I 4 68 INND PNAV CPS 425451 O0 000 O0 0 4 1 1 4 68 INFO PNAV CPS 425451 O0 000 o0 0 4 1 I 4 68 G~CH PNAV GAPI .425451 O0 000 O0 0 4 I 1 4 68 TENS PNAV ~B ~25451 O0 000 O0 0 4 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000:000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 · ,IS Tame Verification Listing ~chlumberger AlasKa Computing Center DATA g-JUL-lq92 06155 DEPT 9952.000 SIG~f PNAV 13.344 TPHI.PNAV SBHN:PNAV 38.566 $IGC:PNAV 1.145 SIBH.PNAV SDSI.PNAV 0.228 BACK.PNAV 105.936 FBAC.PNAV TCAF.PNAV 25489.441 TCND.PNAV 38591.852 TCFD.PNAV TSCF,PNAV 5156,570 INND.PNAV 3065.137 INFD,PNAV TENS.PNAV 1146.552 9500.000 43.135 0 8b 6471.949 1156.551 SIGM.PNAV $IGC.PNAV BACK.PNA¥ TCND.PNAV XNND.PNAV DEPT SBH,:PNAV SOSI.PNAV TCAF.PNA¥ TSCF.PNAV TENS.PNAV SIGM.PNAV SlGC PNAV BACKiPNAV TCND PNAV INND PNAV DEPT. 9496.000 S~HN.PNAV 43.872 S..$I,PNAV 0.161 TCAF~PNAV 36720.586 T~CF.PNAV 7502,408 TENS.PNAV 1139,886 END OF DATA 10.929 0.580 3265.397 TPHI.PNAV SIBH.PNAV FBAC.PNAV TCFD.PNAV INFD.PNAV {.1,271 0 59 383690 31.517 SBHF.PNAV 38.566 TRAT.PNAV 28.913 TCAN.PNAV 12002.768 TSCN.PNAV 496.706 GRCH.PNAV 15.687 SBHF.PNAV 44.024 TRAT.PNAV 29 617 TCAN PNAV 14455:895 TSCN:PNAV 569.275 GRCH.PNAV PAGE: 607 66457"203 11444,445 '999.250 33. 413 61650,820 12602.318 22.141 TPHI,PNAV 13,371 SBHF.PNAV 33,741 8IBH,PNAV 44 959 TRAT,PNAV 1,823 : . 66972 719 FBAC.PNAV 3! 260 TCAN PNAV . TCFD,PNAV 15788.441 TSCN,PNAV ~3683,3~b XNFD.P'~AV 557.076 GRCH.PNAV {6 38 . .9 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 00~A07 DATE : 92/07/ 9 MAX, REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME ~ EDIT .00.5 SERVICE : FLIC VERSION : 00lA07 DATE : 92/07/ 9 MAX REC SIZE ~ 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw baCKground Pass in last file PASS NUMBER= ,IS Tape Verification Listing ;chlumberoer AlasKa Computing Center 9-JUL-1992 06:55 PAGE: 14 DEPTH INCREMENT: -.5000 # FILF SUMMARY VENDOR TOOL CODE START DEPTH ~;'''''''TP ........ '';~''''99 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT)~ ~OTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USEO (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP AUXILL ARY TDTP TDTP $ NDE GENERATOR TDTP TDTP SONDE DETECTOR TDTP TDTP CARTRIDGE TDTP BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH(FT) LOGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE ~' M IE. PE~ ATURER (D~GF): FLUID LEVEL FT) FLUID RATE AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: C~OKE ~EUTRON TOOL TSOL TYPE (EPITHERMA~ OR THERM~L)~ MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9494.5 20'FEB'92 CP 32.6 1100 20-FEB-92 9954.0 9959.0 9495.0 9952.0 1800,0 NO TOOL ~{UMBER ATM AA 160 TNG-P-~36 TND-P-75 TNC'P-141 SHH EB 542 q~96,0 DEAD CRUDE THERMAL SANDSTONE 2.65 BLDELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT)I Tame Verification bistinq ;chlumberoer Alaska Computinq Center 9-JUG-1992 06:55 PAGE~ 15 8LUELINE COU~)T RATE SCALES SET BY FIELD ENGINEER FAR COUNT RA'rE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS)! 150000 NEAR COUNT RATE LOW SCALE (CPS), NEAR COUNT RATE HIGH SCALE (CPS)~ 40000 TOOL STANDOFF REMARKS: TIED INTO BHC ACOUSTILOG OF 11-04-86. PU~PED IN DEAD CRUDE Ti3 DISPLACE GAS IN BOREHOLE. VOLi!~ES PUMPED AS FOLLOWS: PASS ONE: 243 BBL, 0.2 B/M AT 400 PSI PASS T~O: 250 BBL, 0.2 B/M AT 400 PSI PASS THREE: 254 BBb, 0,2 B/M AT 400 PSI TOTAL INJECTED VOLUME AT END OF bOG = 960 BBb. $ LIS FORMAT DATA ** D~TA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB TYPE REPR CODE VAbUE ! 66 0 ~ 66 0 3 73 256 4 66 7 8 68 0,5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT {.5 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NA~ S~RV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS ~OD NUMB SAMP EDEM CODE (H~X) DE~T FT 425451. 00 000 00 0 5 1 1 4 68 0000000000 S!G~ PSi CU 425451 O0 000 O0 0 5 1 1 4 68 0000000000 STDT PS1 425451 O0 000 O0 0 5 1 I 4 68 0000000000 ~I$ Tame verification Listing ;Chlumberger AlasKa Computing Center 9-JUL-1992 06:55 PAGE: 16 NAM~ ERr UNIT SERVICE I &PI APl PI f'ILE NUMB NUMB S ZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ... ..... [..... ...... .... .... .... ......................... .... .-........,,,......... TPHI PS PI! 42 451 00 000 00 0 5 ! 1 4 68 0000000 ISHU PS1 V 425451 00 000 00 0 5 1 1 4 68 0000000000 SFFD ~ND PSI SBHF PS1 SBHN PS! FTDT PSI NTDT AFFD ABFD PS! AFND PSi ABND SlGC PS1 $IBR MMOF TRAT SDS! PS1 FBAC PS1 TCA~ PS1 TCAF PSi TCND TCF~ PS1 TSC~ PSi TSCF PSl INND INFD RN1 RN2 RN3 PSi RN4 PS1 RN5 RN6 RN7 PS1 RN8 RN9 PS1 RNIO PSl RN!! RN12 RNI3 RN14 PS1 RN15 RN16 RF1 PS! RF2 RF3 RF4 PSi RF5 RF6 PS1 RF7' PS~ RF8 PS1 CU 425451 O0 000 O0 0 5 1 1 4 68 CU 425451 O0 000 O0 0 5 1 I 4 68 CU 425451 O0 000 O0 0 5 1 1 4 68 CU 425451 O0 000 O0 0 5 1 I 4 68 CPS 425451 O0 000 O0 0 5 ! I 4 68 CPS 425451 O0 000 O0 0 5 ! 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 I 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CU 425451 O0 000 O0 0 5 I 1 4 68 CU 425451 O0 000 O0 0 5 1 1 4 68 425451 O0 000 O0 0 5 1 1 4 68 425451 O0 000 O0 0 5 1 1 4 68 CU 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 I 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 I I 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 00 0 5 1 I 4 68 CPS 425451 O0 000 O0 0 5 1 I 4 68 CPS 425451, O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 42545~ O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 ! 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 ! I 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 ~ 4 6~ CPS 425451 O0 000 O0 0 5 ! 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 I 4 68 CPS 4~545! O0 000 O0 0 5 1 1 4 68 CPS 425451 00 000 00 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 ! 1 4 68 CPS 425451. O0 000 O0 0 5 I 1 4 68 CPS 425451 O0 000 O0 0 5 1 1 4 68 CPS 425451 O0 000 O0 0 5 1 I 4 68 CPS 425451 O0 000 O0 0 5 1 i 4 68 CPS 425451 O0 000 O0 0 5 I ! 4 68 CPS 42545i O0 000 O0 0 5 1 I 4 68 CPS 425451 O0 000 O0 0 5 1 ! 4 68 CPS 425451 O0 000 O0 0 5 I 1 4 68 0000000000 0000o00000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000 000 oooog ooo 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 :IS Tane Verification Listino ~chlumberger Alaska Computing Center 9-jUG-Ig92 06~55 PAGE: !7 ....... ;mm; .... mmmmm, ..... mm;m .... mmmmmm,llm.---,~l, mm~lmmmm~)mmmml)~,mmm',-'mmm~mm'm'mmm.mmmm{{mmmmmmmmmmmmimmm"N#mmm!------- N RV UN I ~RV ICE API PI API APIUMBSpILE N NUmB IZE REPR PROCESS ID ORDER ~ LOG TYPE CbASS MOD NUMB SAMP EbEM CODE (HEX) PS1 CPS 4 51 O0 0 0 O0 5 1 1 4 68 0 000000 RFIO PSI CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RFI1 PS1 CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RFI2 PSI CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RFI3 PSi CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RF14 PSi CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RF15 PS! CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 RF16 PS! CPS 425451 O0 000 O0 0 5 1 1 4 68 0000000000 GR PSI GAP! 425451 O0 000 O0 0 5 1 1 4 68 0000000000 TgN$ PS! LB 425451 O0 000 O0 0 5 1 ! 4 68 0000000000 ~m~mmmmmmmmm"mmmmmmmmmmmmmmmm~mmmmmmm~mM~mmmmm~mmmmmmmmmm~mmm~mm~mmmmmmm~mm~mmm~ ** DATA DEPT iSHU Psl SBHN PSI ABFD PS1 BACK PS1 TCND PSi INMD PS1 RN3.P$1 RN?.PS1 RMII.PS1 RNiS~PS1 n~,PSl RFT.P$1 DEPT. iSHU PSi SBHN ABFD PSi SIB~ PSi BAC~'PS1 I'R~3.pS! RNT.PS1 RM!!.P$~ RN15.PSI RF3.PS1 RFT.PS! R~lI.PS1 RFiS'PS~ 9965 O0 $IGM,PS1 258'470 FTDT~P$1 1.I02 AFND,PS1 344 646 MMOF'P$1 I :367 FBAC,P$1 -195.688 TCFD.P$! -0,522 INFD,PSi 1070.076 R~4.P$! !728.219 RNS,P$! 3536 932 R~12,P$1 3082]386 RN16.P$! 321.970 RF4'PSi 553.977 RFS'P$I 1231'061 RF12.~PS! {325.757 RF16.P$1 9500.000 SIGM..PSI 35.156 SFFD,PS1 4!.021 FTDT.PSI 189.762 AFND'PS! 41,021 MMOF,P$I 131.704 FBAC,PS1 40203'508 TCFD,P$1 3231,106 INFD.'P~I 1149.840 RN4,PS{ 1646,635 RNS,PS1 3433:,493 RN12'PSi 3493.589 RNI6,PS1 438.368 RF4,PS1 815.972 RFS'P$1 1575.521. ~F12,PS1 2777.777 RFI6.PSI 448 o'ooo 27,808 ' -0,044 9.141 -!11.018 -0'311 1619' ~ 4043,~60 1254' 35 4~4 015 402 462 1463 068 625 000 9 922 70~,,8 3 .826 1'320 31'261 167~.555 · .475 1~62'660 981~570 3890,2~4 9 9 1966,1~6 1588,542 STDT.P$1 $FND.P$1 NTDT.P$1 ABND, PS1 TRAT,P$1 TCA. N.P$1 TSCN,P$i RNI,PS1 RNS.P$1 RNg.:P81 RNI3,PB1 RFi'PS1 RFS,PS1 RFg~PSl RF13,P81 GR.PS1 STDT.P$I SFND.P$1 NTDT,P$1 ABND,P$1 TRA. T,P$1 TCAN'PS1 TSCN.PS1 RNI.'P$1. RNS,P$1 RNg,:P$1 RN13,PS! RFI,P$1 RFS'P$1 RF9,P$1 RF13.P$1 GR,P$1 66 000 22 725 0 000 2 729 0 000 0 000 0.000 1060.606 17 .:772 4758..522 383.523 572,.9 7 795,444 1799,~242 26,313 66,000 I1.92) 39,852 213 256~688 ~!91..420 973 558 1794 ~872 16 493 598 58 9 819 16,:500 TPHI PSi $BHF:PSi AFFD'P$1 SDSI.P$1 TCAF.P$1 R~ .PSi RM!O,P$1 RN14,PS1 RF2.P$1 RF6.PS1 RFIO,P$! RF!4,P$! TEN$oP$1 TPHI.PSX $BRF,P$1 AFFD-P$! $IGC.P$! :SDSl,PSi TCAF,P$! T$CF'P$! RN2,P$1 R~6'P$1 RN!O,P$1 RN14.'PS1 RF2~P$1 RF6,P$1 RFI4,PS! TKN$,PSI 0 000 477 0 000 0 000 104 490 522 77, 68 183~' O0 1'3:,g22 35i764 0 ::14::0 go 40034'3~9 8190 i0,8 360 ~t27i404 460~, 30,960 850,694 946~:80 2960'A69 1095,000 Tape verification Listln~ ;cblumberger AlasKa Computing Center 9-jUG-~992 06:55 tB DEPT. 9q94,500 SIGH.PS1 ISHU,PS1 35,156 SFFD.PS1 SBHN,PS1 43,090 FTDT,PS1 ABFD,PS1 192,967 AFND,PS1 SI8",P$1 43'575 ~MOF,PS1 BaCK,PS1 139.355 FBAC,P$1 TCND,PSl 41091,414 TCFO,PS1 INND,PS1 3350 056 IMFD,PS1 ~N3,PS1 1221:955 RN4,PS1 ANT.PS1 1586 538 RNS,PS1 RNll,P$1 3393:429 RNI2,PSl RN15.PS1 3349 359 RN16.P$1 RF3,PS! 407:986 RF4.PS1 RF7,P$1 716.146 RFB,PS1 RFlI.PS! 1566,840 RF12,PS1 RF15,PS1 2556.423 RF16.PS1 10 071 1!i063 21 268 707 844 1,278 29,617 17621.582 554 544 1706 7~1 933 94 3990 1638 6 2 598 958 425,347 1961,805 1323,785 STDT.PS1 SFND,PS1 NTDT,PS1 ABND,PS1 TRAT,P~I TCAN,PS1 TSCN,PS1 RN1,PS1 RN5,PS1 RN9 RN13~PS1 AFl,PS1 RF5,PS1 RF9,P$1 RF13,PS1 GA,PS1 66.000 TPHI.PS1 12.931 SBHF.PS1 43.174 AFFD.PS1 602.093 SIGC.PS1 1,737 SD$I,PS1 74252 063 TCAF.PS1 15174 453 TSCF.PS1 929 487 RN2,PS1 1802 2103 4647 360 651 915 2469 16 885 RN6.PS1 365 RNIO.PS1 436 RNI4,PSI 24] RF2.PS1 042 RF6.PSI 799 RFIO.PSI 618 RF14,PS1 359 TENS,PSi 11,640 33,688 188,356 0,736 0,132 8737 99 123 840 2023 237 2271 34 461 960 889 757 954 86! 2769 097 1160 000 ** END OF DATA FILE NA~E : EDIT .,005 SERVICE : FLIC V~RSION : O01A07 DATE : 92/07/ 9 MAX REC SIZ~ : 1024 FI.bE TYPE : LO LAST FILE **** FILE HEADER FILE NANE : EDIT ,006 SERVICE : FLIC VERSION : O01A07 D~TE : 92/07/ g ~AX AEC SIZE : 1024 FILE TYPE : LO LAST FII,E FILE HEADER FILE NUMBER 6 RAW CURVES Curves and Ioq header data for eaChr pass in separate files; raw bac~grou, nd Pass in last f~le PASS NUMBER: 2 DEPTH INCREMENT{ -,5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH STOP DEPTH -...--.-------.- --...-.-.. TDTP 9496,0 ,IS Tape Verification Listing ;chlumberger Alaska ComPutlnq Center 9-jUL-1992 06:55 PAGE: 19 $ # LOG HEADER DATA DATE LOGGED: ~OFTWARE VERSION: TIME LOGGER ON BOTTOm: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTO)4) VENDOR TOOL CODE TOOL TYPE TDTP AUXILLIARY SEAS TDTP TDTP SONDE GENERATOR TDTP TDTP SONDE DETECTOR TDTP TDTP CARTRIDGE TDTP $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN).,' DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT)~ BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE TEMPERATURE (DEGF)~ BOTTOM HOLE TEMPERATURE (DEGF)~ FLUID SALINITY [PPMI: "~V FLUID LE EL. FT) FLUID RATE AT WELLHEAD (BPS): WATER CUTS (PCT): GAS/OIL RATIO: CMOKE (DEL): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: 'MATRIX DENSITY HOLE CORRECTION 20-FEB-92 CP 1100 20-FEB-92 9954,0 9959,0 9495,0 TOOL NUMBER AT~ AA 160 THO-P-236 TND-P-75 TNC-P-141 SHH EB 542 9296.0 DEAD CRUDE THERMAL SANDSTONE 2,65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORHALIZING WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER' FAR COUNT RATE · $.A:L~.~ CCPS): 0 FAR COUNT RATE HIGH SCAL....M (CPS): 15000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 40000 ~IS Tape Verification Listing ;chlumberger AlasKa Computing Center O-JUL-199~ 06:55 PAGEI 2O TOOL STANDOFF (IN): ~E~A~KS: TIE{) INTO BHC ACOUSTILOG OF 11-04-86. PUMPED IN DEAD CRUDE TO DISPLACE GAS IN BOREHOLE, vOLUMES PUMPED AS FOLLOWS: PASS ONE: 243 BBb, 0.2 B/M AT 400 PSI PASS TWO: 250 BBL. 0.2 B/M AT 400 PSI PASS THREE{ 254 BBL, 0.2 B/M AT 400 PSI TOTAL INJECTED VOLUME AT END OF LOG : 260 BBb. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 2~6 4 66 5 66 7 65 9 65 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX} DEPT FT 425451 O0 000 O0 0 6 1 ! 4 68 0000000000 SIGU PS2 CU 425451 O0 STDT PS2 425451 O0 TPHI PS2 PU 425451 O0 IS~U PS2 V 425451 O0 SFF~ PS2 CU 425451 O0 SFMD PS2 CU 425451 O0 SBHF PS2 CO 425451 O0 SBHN PS~ CU 425451 O0 000 O0 0 6 1 00o O0 0 6 1 000 O0 0 6 1 o00 oo 0 6 000 O0 0 6 000 O0 0 .6 000 O0 0 6 1 000 OO 0 6 1 4 4 4 4 4 4 4 4 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ;¢hlumher~er Alaska Computing Center 9-JUL-1992 06:55 PAGE: 21 NAME $ SERVICE I AP1 API APl FILE NUmB NUM SIZE EPR pROCESS ID ORDER # bOG TYPE CLASS MOD NUB4B SAMP ESEM CODE (BE2() ~,~ ~c~ ~,~ oo ooo oo o~ ~ ~ , ~ ~c~ ~~ ~~ oo ooo oo o~ ~ ~ ~ ~ ~ ~ ~ ~~ oo ooo oo o~ , , ~ ~, ,~,.~ ~ c,~ ~~, oo ooo oo o~ , , ~ ~, ~,, ~c~ ~~, oo ooo oo o~ ~ , ~ ~ ooo0oo0ooo o00o0000o0 o000000000 oo00000000 oo00000000 oo00000000 0o0000o000 ooo000o000 0000000o00 o000000o00 0000o0000o 00000o0000 o000000000 0o000o0000 oo0o000000 0o00000o00 00000000oo 000000000o 0000000000 0000000o00 o000000000 o000000000 000000oo00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000000§000 o00000 000 0000000000 o000000000 o000000000 0000000000 0000o00000 00000o0oo0 000o0000oo 00000000o0 0o0000o000 000o000000 0000000o00 0000000000 0000000000 0o00000000 o0000o0000 0000000000 o0ooo0oo0o 0o0000000o 00000o0o0o 00000o000o Tape Verification Listino 9-JUL-1992 06:55 ~chlumber~er AlasKa Computing Center PAGE: 22 ID ORDER # LOG TYPE CLASS MOD NUNB SAMP EbEM CODE (~X) mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmm~mmmm~mmmm~m~m~mmmmmmm~m~mm~mmm~ RFX5 P$2 CPS 425451 00 000 00 0 6 1 1 4 68 0000000000 RF16 P$2 CPS 425451 00 000 00 0 6 1 1 4 68 0000000000 GR P$2 GAPI 425451 00 000 00 0 6 ! 1 4 68 0000000000 TENS PS2 5B 425451 O0 000 O0 0 6 1 I 4 68 0000000000 DATA DEPT. 9965.000 SIGM.PS2 ISHU.PS2 36.000 SFFD.P$2 SBHN.PS2 43.090 FTDT,PS2 ABFD.PS2 192.967 AFND,PS2 SIBH .PS2 43 575 ~Ac~l~s2 1~91~55 TCND.PS2 41091.414 TCFD INND,P$2 3350'055 INFD:PS2 R~7.PS2 1614.~83 R~8~PS2 ~Nl!'PS2 3503.788 RNI2,P$2 RN15.P$2 2921.401 RN16.P82 RFI,P82 255.682 RF4,PS2 RFT,PS2 5~5,.568 RFS,P$2 RFII.PS2 121 .856 RF!5.P$2 13!~ RFI~'Ps2 .553 DEPT. 9500,000 SIGM,PS2 ISHU,.PS2 34.719 SFFD.PB2 SBHN,P$2 46'386 FTDTiP$2 A~FD.PS~ 152'$42 AFND,P$2 EISa'PS2 49.598 MMOF~PS2 TCND*PS2 ]t25 : 05 TCF .PS2 NND,PS2 3218 654 INFD*PS2 IRN3,PS2 1171:875 RN4,P$2 EN7,PS2 ~62,847 RNS*PS2 RNII.P$2 3164.062 RN12,.PS2 R~I5 P$2 1931.423 RN16.PS2 RF3 PS2 340.545 RF4,P$2 RF7 PS~ 432.692 RFS,P'S2 RFI1P$~ 108i,731 RFI2 RF!5,PS2 697.115 RFI6.'PS2 DEPT, ISHU.PS2 I~HN PS2 FD PS~ $IB~ PS2 BACK P$2 TCND PS2 INNO PS2 10.071 il.063 21 268 707~844 2~.278 17621 '617 .582 554,544 1482,007 980,114 3996.212 1463 06~ 42! 401 411 932 1453 598 6~4 470 15 1!6 16:476 1~.833 68 ,538 1 .422 40 5~7 lOl~ 781 5 858 !7!8 750 34 ,902 ' 744 408 654 1169 87~ 368,590 9496,000 SIGh. PS2 10,040 37.313 SFFD.PS2 !0.868 43,878 FTDT.P$2 20 862 205.099 :~ND,...S2 707~452 44.903 MMOF,PS2 1,536 188'953 FBAC.PS2 37,954 9.oo8 STDT,P$2 SFND.PS2 NTDT,PS2 ABND,P$2 TRAT'PS2 TCAN,PS2 TSCN,PS2 RNI.PS2 RN5,PS2 RN9.,P$2 EN1 PS2 RF5,P$2 RFg. Ps2 RF13.,PS2 GR,PS2 ETDT,PS2 SFND,P$2 NTDT,PS2 ABND,PS2 TR.AT,P$2 TCAN,PS2 TSC~,PS2 RNI'PS2 RNS,PS2 RNg,P$2 RN1]*P$2 RFI...~PS2 RF5,PS2 RFg,PS2 RFt3,PS2 GR,P~2 STDT.PS2 SFND.PS2 NTDT.PS2 ABND,PS2 TRAT'PS2 TCAN,PS2 TSCN,PS2 RNI,PS2 66 000 43 1'7~7 74252.061 15174.453 970,644 1756,629 1993.371 4507.575 350..379 520.833 729,167 53! 6 'ooo 19,005 34.280 557,~954 40!33~,227 8197:895 8.89.757 1731~1771 2161~:458 3433~,160 280.~449 536,859 765,224 1165.865 40*406 66..000 12,:947 589.6~7 74367,. !5182-641 941.840 TPHI.P$2 SBHF.P$2 AFFD.PS2 SIGC.PS2 TCAF.PS2 TSCF PS2 RN2 PS2 RN6 P$2 RNIO PS2 RN14 PS2 RF2 PS2 RF6 PS2 RFiO PS2 RF14 PS2 TENS P$2 TPHI.P$2 EBHF,P$ AFFD,P$1 SIGC.PS2 SD$I,PS2 TC.AF.PS2 TSCF.P$2 ~N2.PS2 RNS'PS2 RN10,PS2 RNi4.PS2 RF2,PS2 RF6,PS2 RF!I,P$2 RFI .PS2 TENS,PS2 TPHI,P$2 SBHF..PS2 AFFD.PS2 SXGC*PS2 SDSI,PS2 TCAF,P$2 TSCF*PS2 RN2*PS2 I ,640 ~,.688 42756'04~ 8737,799 149,64.0 2040. 4228,219 46'440 714;962 767'~045 1685~ 06 I 4 4 17330' 8 3540' 3! 170, 80 2009~ 48 2144~097 2942.?08 1.105.769 liS0 000 11' 5 ' 21 42731'594 8724,002 159.960 Tape verlficatJon Listing Ichlumberger AlasKa Computing Center g-JUL-lEg2 06:55 RN3.PS2 11.93.576 RN4.PS2 165] 646 RNS,PS2 PNT.PS2 16~4.5~3 AMS.PS2 972~222 RNg,PS2 RNII,PS2 3337,673 RN12,PS2 3949'652 RN1],PS2 RNI5 P$2 3511,285 RN16,PS2 1796 875 RFI,P$2 RF3:PS2 396,635 RF4,PS2 616~987 RF5,PS2 AFT,PS2 741.186 RFS.PS2 440 705 RF9,PS2 RF!I.PS2 1602,564 RF12,PS2 1971:154 RFI3,PS2 RF15.PS2 2572.i]5 RFI6.PS2 1334.135 GA,PS2 END OF DATA ~692.708 RN6.PS2 2 26 PS2 4652:777 673.077 RF6.PS2 893°429 RFI~ P$2 2520,032 nfl :PS2 29.578 PAGE: 23 1996.528 2230 902 4526 909 46 440 817 308 945 5i3 2784 455 1165 000 **** FILE TRAILER **** FTL~ NAME : EDIT ,006 SERVICE : FDIC VERSION : O01A07 DATE ~ 92/07/ 9 ~AX REC SIZE : 1024 F~LE TYPE : bO LAST FILE : ***,* FILE HEADER **** FILE NAME : EDIT ,007 SERVICE : FDIC VERSION : 001A07 DATE : 92/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO FILE MEADER FIL. E NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background Pass in last file PASS ~UMBER: 3 DEPTH INCREMENT: -.5000 FIbE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9966,0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE YERSION: TIME DOGGER ON BOTT:O~: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH 9494,5 20'FEB'g2 CP 32,6 1100 20-FEB-92 9954,0 9959.0 ,IS Tape Ver~,fication Listing ;chlumberger Alaska Computing Center g-JUL-lg92 06~55 PAGE: 24 TOP LOG INTERVAL BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE "'"'"'"'"" TDTP AU×I RY MEA$ TDTP TDTP DE GENERATOR TDTP TDTP SONDE DETECTOR TDTP TDTP CARTRIDGE TDTP $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEHPERATORE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): CHOKE (LEG): NEUTRON TOOL TOOL TYPE (~PITNERMAL OR THERMAL): ~ATRIX~ ~ATRIX DENSITY: HOLM CORRECTION (IN): 9495.0 O o52 o 18 0.. NO TOOL TND-P-75 TNC-P-14! SMH EB 542 9296.0 DEAD CRUDE THERMAL SANDSTONE 2,65 BLUELINE COUNT RA..,E NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT ~'.ATE LOW SCALE (CPS~ 0 FAR COU~T RATE.HIGH SCALE (CP8]~ 1.5000 NEAR COU~!T RATE bO~ SCALE (CP~) 0 NEAR COUNT RATE HIGH SCALE (CPS~ 40000 TOOL STANDOFF (IN): H RE~ARKS: TIED INTO B. C ACOUSTILOG OF PU~PED IN DEAD CRUDE TO D~SPLACE GAS I~ BOREMObE, VODIiME8 PUMPED AS FOLLOWS. PASS O.E.: 243 BBb, 0 B/M ~T 400 PSI PASS TWO: 250 BB5, . B/~AT 400 PSI Tape ver~.fication Listing ;chlumberger AlasKa Computin~ Center 9-JUb-1992 06:55 PASS THREE: 254 BBb, 0,2 B/M AT 400 PSI TOTAL INJECTED VOLUME AT END OF LOG : 260 58L, $ LIS FORMAT DATA PAGEI 25 ** OATA FORMAT SPECIFICATION RECORD SET TYPE - 64ES TYPE REPR CODE VALUE 1 66 0 2 66 0 ] 73 256 4 66 5 66 6 73 7 65 ~ 68 0,5 9 65 FT !1 66 4 ~2 68 13 66 0 14 65 FT 15 66 68 t6 66 0 66 ** SET TYPE - CHAN ** . N~M~ SERV UNIT SERVICE APl API APl AP1 FIDE NUMB NUMB SIZE REPR PROCESS ID ORDER 9 LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) DEPT FT 425451 O0 000 O0 0 7 1 I 4 68 $IG~ PS3 CU 425451 O0 000 O0 0 7 I 1 4 68 STDT PS3 425451 O0 000 O0 0 7 1 1 4 68 TPH! PS3 PU 425451 O0 000 O0 0 7 1 1 4 68 IS~U PS] V 42545~ O0 000 O0 0 7 J. I 4 68 SFFD PS3 CU 4~5451 O0 000 O0 0 7 1 1 4 68 SFN~ PS~ CU 4254~1 O0 000 O0 0 7 ! 1 4 68 SBHF PS3 CU 425451 O0 000 O0 0 7 t 1 4 68 SBHN PS3 CU 425451 O0 000 O0 0 7 I I 4 68 FTDT PS3 CPS 425451 O0 000 O0 0 7 I 1 4 68 NTDT PS3 CPS 42545~, O0 000 O0 0 7 1 1 4 68 AFFD PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 ABFO PS3 CPS 425451 O0 000 O0 0 7 I I 4 68 AFND'PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 ABND PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 $IGC PS3 CU 425451 O0 000 O0 0 7 1 I 4 68 SIB~ PS3 CU 425451 O0 000 O0 0 7 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000OO0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tape Verification Listing ~chlumberger Alaska Computing Center g-JUL-1992 06:55 PAGEI 26 _ SERV API AP! AP API FIbE NUMB UMB SIZE PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) T.AT PS3 425451 O0 000 O0 0 ? 1 i 4 68 0000000000 SOS! PS3 CU 425451 O0 000 O0 0 7 ! i 4 68 0000000000 BACK PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 FBAC PS3 CPS 425451 00 000 00 0 7 1 1 4 68 0000000000 TCA~ PS3 CPS 425451 O0 000 O0 0 7 I 1 4 6e 0000000000 TCAF PS3 CPS 425451 O0 000 O0 0 7 i 1 4 68 0000000000 TCND P$3 CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 TCFD PS] CPS 425451 O0 000 O0 0 7 I I 4 68 0000000000 TSCN PS3 CPS 425451 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 425451 O0 000 O0 0 7 I ! 4 68 0000000000 INND PS3 CPS 425451 O0 000 O0 0 7 1 i 4 68 0000000000 INFO PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 RN1 PS3 CPS 425451 O0 000 O0 0 7 ! I 4 68 0000000000 RN2 PS3 CPS 425451 O0 000 O0 0 7 ! 1 4 68 0000000000 3 PS3 CPS 425451 O0 000 O0 0 7 1 1 4 68 0000000000 N4 P$3 CPS 425451 O0 000 O0 0 7 i I 4 68 0000000000 RN5 PS3 CPS 425451 O0 000 O0 0 7 ! 1 4 68 0000000000 RN6 PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 R~7 PS3 CPS 42545! 00 000 00 0 7 ! ! 4 68 0000000000 RN8 PS3 CPS 425451 O0 000 O0 0 7 i 1 4 68 0000000000 RN9 PS3 CPS 425451 O0 000 O0 0 7 ! I 4 68 0000000000 RNIO PS] CPS 425451 O0 000 O0 0 7 1 1 4 68 0000000000 RNll PS3 CPS 425451 O0 000 O0 0 7 1 1 4 68 0000000000 RN12 PS3 CPS 425451 O0 000 O0 0 7 i I 4 68 0000000000 ~13 Ps3 cps 4~5451 oo 000 oo 0 v I 1 4 6a 0000000000 R 14N PS3 CPS 425451 O0 000 O0 0 ? ! 1 4 68 0000000000 R~15 PS3 CPS 425451 O0 000 O0 0 7 ! I 4 68 0000000000 RN16 PS3 CPS 425451 O0 000 O0 0 7 ! I 4 68 0000000000 RF1 PS3 CPS ,425451 O0 000 O0 0 ? 3 1 ,4 68 0000000000 ~F2 PS3 CPS 42545~ oo 000 O0 0 ? t 1 4 ~e 0000000000 RF3 PS3 CPS 42545t 00 000 O0 0 7 !: Z 4 6'8 0000000000 RF4 PS] CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 RF5 PS3 CPS 42545! O0 000 00 0 7 ! ! 4 68 0000000000 R~6 PS3 CPS 425451 O0 000 O0 0 7 ~ I 4 6~ 0000000000 RF7 PS3 CPS 42545.1 O0 000 O0 0 7 ! I 4 ~$ 0000000000 RF8 PS3 CPS 425451 O0 000 O0 0 7 1 1 4 6e 0000000000 RF9 PS3 CPS 425451 O0 000 O0 0 7 1 I 4 68 0000000000 RF!O PS3 CPS 425451 O0 000 O0 0 7 1 ! 4 68 0000000000 RFI1 PS3 CPS 4:25451 O0 000 O0 0 7 1 I 4 68 0000000000 RFI~ PS3 CPS 425451 O0 000 O0 0 7 I 1 4 68 0000000000 RFt3 PS3 CPS 425451 O0 000 O0 0 7 ! 1 4 68 0000000000 RFi4 PS3 CPS 425451 00 000 O0 0 7 1 1 4 68 0000000000 RF~ PS3 CPS 425451 O0 000 O0 0 7 I ! 4 68 0000000000 RF.~. PS3 CPS 425451 On 000 O0 0 7 1 1 4 68 0000000000 G~ PS3 GAPI 425451 O0 000 O0 0 7 1 I 4 68 0000000000 T~NS PS3 LB 425451 O0 000 O0 0 7 I. I 4 68 0000000000 tis Tape Verification bistlno ;cblUmberoer Alaska Computing Center DATa DEPT. 9966.000 $IGM.PS3 ISHU.PS3 33.406 SFFD.PS3 sBHN.PS] 43.878 FTDT.PS3 ABFD.PS3 205.099 AFND PS3 SIBH.PS3 44.903 M~4OF:PS3 BRCK PS3 188.953 FBAC.PS3 TCND~PS3 40781.422 TCFD.P$3 INND.PS3 3239.008 INFD.P$3 RN3.PS3 1013.257 RN4.PS3 ~N? PS3 1638.257 RNS.PS3 RN11:P$3 3309,659 RNt2.PS3 RN15.PS3 2992.424 RN16,PS3 RF3.PS3 284.091 RF4 PS3 RF7 PS] 582.386 RFS:PS3 RFll:PS3 1141,098 RF12,P$3 RFIS.P$3 1325.757 RF16.P$3 DEPT 95o0.000 SBHN.PS3 43 040 FTDT.P$3 ABFD.PS3 185:473 AFND.P$3 $IB, P$3 43 504 MMOF.P$3 BRCE:PS] 226:669 FBRC.P$3 TCND PS3 36002 875 TCFD,P$3 INND:PS3 32483618 INFD.P$3 R"3.PS3 1189 ~36 RN4'PS3 RN7.PS3 1631:~4.5 RN8;P$3 RN![.P$3 3528.646 RN12'P$3 RN15.PS3 3493.923 RN16.PS3 RF3.PS3 388.622 RF4.P$3 RF7.PS3 665.064 RFS"P$3 RFI!.PS3 140~.250 RF12,P$3 RF~5.PS3 172 ,756 RF16.Ps3 DEPT IS~U' $BHN'PS3 .PS3 ABFD PS3 B~CK.P$3 TCND.PS3 I. NN~*PS3 ~NT.PS3 RNIS.PS3 ~F3.PS3 RFTiPS3 RFll~P$3 RF!5.PS] 9494.500 37.750 44.992 199.2~7 '46,803 212 616 41421 234 891 1618 590 3369 3890'224 392.628 757.211 1578.526 2560'096 SIGN,PS3 SFFD,PS3 FTD?.PS3 AFND2PS3 M{OF,.P$3 FB~C.PS3 TCFD'P$3 INFD P$3 RN4 P$3 RNSPS3 Rg~2 P$3 RN16 P$3 RF4 RF8 PS3 RF12 PS3 RF16 PS3 q-dUI,-1992 06:55 10.040 STDT.PS3 10.868 SFND.P$3 20.802 NTDT,PS3 707 4~2 RBND.P$3 1:5 6 TRAT.P$3 37.954 TCAN.PS3 17651.207 TSCN.P$3 593 178 RNI.P$3 15241 21 RN5.P$3 942 235 RNg,P$3 3934 659 RN13,P$3 1491.477 RFI,P$3 464.015 RFS.P$3 378.788 RF9.PS3 1406,250 RFI3,P$3 667.614 GR.PS3 16' 13915 295 573 868 1614 583 1054 688 40!9 097 1948 785 5O8 8!4 448 1642 628 893 429 10 542 11 277 2 70~ 010 ~0 47 3 5~ 364 !666 667 997,596 4028,429 556, I STDT.P$3 SFND.PS3 NTDT.P$3 ABNO.PS3 TRAT.P83 TCAN.P$3 TSCN'P$3~ RNi.P$3 RN5,PS3 RN9.P$3 RN13,PS3 RF1.PS3 RF5,PS3 RF9,P$3 RF13,P$3 UR.PS3 STDT,P:$3 SFNO,PS3 NTDT.~PS3 ABND,,P$3 TRAT'PS3 TCAN*P$ T$CN..P$~ RN!*PS3 RNS,P$3 RN9~P83~ RNi3,PS3 Rtl.PS3 RFS,PS3 RFg. PS3 RFI3*PS3 GR,PS3 66 000 12 947 43 251 589 627 I 740 74367 063 15182 641 932 765 1633 522 203~.250 4569.128 345.644 487 689 1742,424 45,563 .000 36 '894 .498 570.925 1 977 58460:773 I1~I~.193 .500 [848'958 2065,972 4592.014 328.526 637'019 9 3.461 ,250 66 000 593 143 1751 836 877 404 1810 897 2!3~ 423 460 371 6 87 89~.429 25~2"103 .'438 TPHI.P$3 $BHF.PS3 AFFD.P$3 $IGC.PS3 $P$l.PS3 TCAF.P$3 TSCF.PS3 RN2.P$3 RN6.PS3 RNIO.P$3 R~14.PS3 RF2.PS3 RF6.P$3 RFIO.PS~ RFI4,P$ TENS.PS3 TPHI,P$3 SBHF,P$3 AFFD,P$3 $IGC,P$3 SD$I*P$3 TCAF,P$3 TSCF.PS3 R.N2*P$3 RN6.P$~ RN10*P$3 RNI4,P$3 RF2.P$3 RF6,P$3 RFIO.P.$3 RFi4.P$) TENS.PS3 TPHI.P$3 SB~F,PS3 AFFD.P$3 SlGC.P$3 SDSX*P$3 TCAF.P$3 T$CF.P$3 .P$3 ~P$3 RF2.PS3 RF6~P$3 RF!0*P$i RFI4'P$ TENS~p$3 PAGEI 27 11.665 29.378 188.037 0,721 0.136 42731.594 8724,002 t96,080 1960,227 2140, 41,280 6!0,795 776'515 1832.386 850.000 16 394 30 381 144 075 0 449 0 216 29565 270 6037 988 ~58 6'70 2126 736 2196 ,:180 4414,063 42'570 729~167 937,500 20'91 * 346 !160,000 6 14,7 43450.~359 8870,600 020 i 35' 417 ~178' ! 19, 39 4791'666 .340 97 .' 564 11 5'000 Tape Verification Listing ;cblumberger Alaska Computin~ Center 9-jUL-1992 06:55 PAGE: 28 ** END OF DATA **** FILE TRA!bER **** FILE NAME : EDIT ,007 SERVICE : FbIC VERSION DATE : 92/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 92/07/ 9 ORIGIN : FbIC TAP~ NAME : 92151 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA ING,PRUDHOE BAY,18-14,500292161400 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 92/071 9 ORIGIN ~ FLIC R~EL NAME : 92151 CONTINUATION # PREVIOUS COMMENT : ARCO ALASKA ING,PRUDHOE BAY,18-14'500292161400 AbABKA COIqPtJ?]:NG 15-Dg¢-1988 12~06 PAGEI SERVICE NAM~ ~ BD~T DATE RIEL NAME : 73049 CONtINUATiON t PREVIOUS REEL COMMENT t bi8 TAPE, RRCO DoSe 19"14, AP! ~50-029-,~614 TAPE HEADER N Alqt~ t ~DIT I 2/t5 ~9 # 1 ~APE 'I ~18 TAPE, ARCO e.8, 19'-t4~ apl ~bE t bO ! ?ape Verification Llat~n~ c~lum~erqer Alaska Co~t~n~ Center 15-DEC-19~$ 12~06 DF: 49, GL: 17, BAY' !K~RK 039 PAGEt 2 ?ape Ve~oat~on ~tln~ FIRST TO 5AST READINGI 11514' TO 10643' XRST TO 5AST READING~ -l~le ,5' TO iOOi'7,0' PAS~ XRST TO bAST READXNG PASS 44 (,T~4 TO bAST R,EAOXNGt 2~9.$' TO 10039,5' ,0" TO 1003'4,5' 9,093," PAGEt Tape Verification Ltst~n9 chlumoer~er Alaska Computlna Center ~5-DgC-~988 ~2~06 TABLE TYPE I CURV I CH&NN:E~ NAIqE id~EUTRON RATIO L N~u'rRoN RAT:tO EUTRON RATIO ~ ?aPe Veriftca~lon Lis~ing lumberqer AI&$Ka Computin.~ Center FORMAT SPECIFICATION RECORD TYPE 12106 PAG~I Xum~er~er A aslca ¢omput][nn~ Center 15-DEC-1988 12~06 NAMF. SERV UNIT SERVICE AP1 A~PI AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ORDER t LOG T=PE CLASS MOD NUMB SAMP EbEM CODE (HEX) PAGEI 6 R?NIq Cente~ lli Ii!'",. Center 15-DEC-3988 12~06 DI 9 o00 ~9 1465 000 5~ 59 ~F lum~erqer Alasi~ ¢o~putln~qa Center N~H! -999 CN, H~A **** FZLE TRAI c~ium~erc~er las~ Comput 15-DEC-198~ 12106 FIRST TO LAST PAGE~ lO ,4 !NC, P~W'L :or :P:rovlnce Tape Verii~!¢&:tion_ L;iS~in~ Center ac~luml~etqer AlasKa comput nq 15-DEC-1988 12{06 PAGEt ~4 tape Verl~tcatlon ~tstlnQ ~lumberge£ lamka Computing ~enter I$?ape Verlt!cation blsting e~lu~eerger AlaSka eomputin~ Center D~ 9400 000 PPRE TPlL 0 15-DEC-19g8 12106 3092 950 Gt GR GR PAGEI 1,t Iumuerger ask:a Comput IN TRAI~DI~ 73049 ~18 TAPE, Center 15-DGC-1988 12:06 ARCO O,S, ill'ii, APl l~rOeO~gd, 216i4 I~AGE{ 14
