Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
195-131
PERH!T DATA T DATA ..... PLUS A R C 5 ~, L 7202 (~W'"ARC B HWD ~O~,~--- "?.~5---1 L..~ C O l','i P L ' ETIOi'q DATE ~ /Ij~ /tl.f/ ~,,,' ojV ¢8" Are dr'y Ai'"e wel'J We i 1 -i ,,s ch sarnple~ r'equ'¥r'ed? yes ~..And r-'ecei'ved? d i: C OHH E N T S we'll eot'ed? y e s ~A n a '1 y ::!:~ 'i s a: d e s c r" '¥ p'i:.: "i' on r" e c e '~' v'e ,.::1 'i: , , -iLe -rs F"eqL.!'i rede ves ~/' "in c o rn p i "i a n c e ~_~P I n '¥ 'L "i ,;~.~ 'I ARCO Alaska, Inc. Date' April 29, 1996 Transmittal #: 9680 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-11 !9 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. °~-5-/931Q-21 ARC5 ~'/5'-"/3 fl Q-20 ARC 5 ~?~,,~_~ Acknowledged: 10/18/95 5682-9325 09/12/95 4099-7290 DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 Alaska Oi~ & Gas Cons. Commission A~orage Clifton Posey Geology ATO - 1251 ChapmanZuspan NSK Wells Group NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10147 Company: 4/24/96 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1Q-20 ~ ?P.~'[ 95328 ARC5' 950912 I I 1 1Q-21 ~ ~)~(~ .~ 95355 ARC5 951018 I I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. PLUGGING & LOCATION CLEAR~.,~CE"REP©RT State of Alaska ..~LASF~K 0iL & GAS CONSERVATION COMMISSION · )',emcr=_r_d"_3. "'"c File' A~i ~7o. Note casinq size, wi, depth, cmt vc!, & procedure. Liner: Review the we!! file, and-comment on p!ug_cinq, we!! head status, and lo_cat!on cleara2zce -~rovide loc. clear, code. Well .head cut of-: ' ~ -- Marker Dos~ or plate: Location Clear~ce: ~ Code ARCO Alaska, Inc. Post Office Box 100~,,,~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Januao, 30, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: lQ-20 (Permit No. 95-131) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 20. If there are any questions, please call 265-6206. Sincerely, M. Zang Supervisor Kuparuk Drill Site Development MZ/skad lQ- STATE OF ALASKA Ab..~KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG .~us of Well Classification of Service Well OIL ~ GAS E~ SUSPENDED E~ ABANDONED [] SERVICE E~] 2 Name of OperaTor 7 Permit Number ARCO Alaska, Inc 95-131 3 Address P.O. Box 100360, Anchoracje, AK 99510-0360 4 LocaTion of weil at surface 1090' FNL, 1820' FEL, Sec. 26, T12N, R9E, UM A[ Top Producing Interval 1806' FSL, 647' FEL, Sec. 23, T12N, R9E, UM Al Total Depth 1964' FSL, 583' FEL, Sec. 23, T12N, R9E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 41' 6 Lease Designation and Serial No. ADL25634 ALK 2567 8 APl Number 50-029-22589 9 Unit or Lease Name KUPARUK RIVER UNIT 10 Well Number 1 Q-20 1 Field and Pool KUPARUK RIVER KUPARUK RIVER OIL POOL 12 Dale Spudded 05-Sep95 17 Total Depth (MD+TVD) 7353' MD & 6267'-I'VD 13 Date T.D. Reached 09-Sep-95 18 Plug Back Depth (MD+TVD) 3840' M D & 3490' TVD 22 Type Eleclric or Other Logs Run GR and resistivity 14 DateComp., Susp. orAbend. 15-Sep-95Abandoned 9 DirectionaJ Survey I-] 15 Water Depth, if offshore 16 No. of Completions NA feet MSL 1 20 Depth where SSSV set 21 Thickness of permafrosl NA feet MD 1500' APPROX CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 7-5/8" 62.5# 29.7# GRADE H-40 L-80 cement plug 6.75" plug set i 6705' 24 Perforations open to Production (MD+TVD of To inlerval, size and number) SETTING DEPTH MD TOP BTM Surf 121' Surf 4099' and Bottom and HOLE SIZE 24" 9-7/8" CEMENT RECORD 223 sx AS I 630 sx AS Ill & 320 sx Class G 25 TUBING RECORD SIZE DEPTH SET (MD) IPACKER SET (MD) 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PRODUCTION TEST of Operation (Flowing, gas lift, etc.) iMethod [27 Date First Production Date of Test Hours Tested Fiow 1-uDing Casing Pressure Press. 28 PRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL WATER-BBL OIL-BBL GAS-MCF IGAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO !OIL GRAVITY-APl (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Re,,,. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ,~--, 130. GEOLOGIC MAFI~EFCS FORMATION TESTS I NAME I Include interval tested, pressure data, all fluids recovered and grawty, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ! 1 I I ! 31. LIST OF A-I-f'ACHMENTS Schematic, Daily Well Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed " Title DATE"'~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well comoletion report and Icg 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". ./30/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: ! NELL'iQ-20 RIG'PARKER 245 ,.,~mm ID: AK8277 AFC AK8277 TYPE -- STATE'ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD:09/05/95 START COMP: BLOCK: FINAL: WI: 55% SECURITY'0 AFC EST/UL'$ 1200M/ API NUMBER: 50-029-22589-00 OM 09/05/95 ( 1) TD' 484' ( 484) SUPV'GR DAILY' 09/06/95 ( 2) TD',~ll0' (3626)~ SUPV'DWG DAILY' 09/07/95 ( 3) TD' 4110' ( 0) c UPV · JT DAILY: 09/08/95 ( 4) TD: 5260' (1150) SUPV: JT DAILY' 09/09/95 ( 5) TD: 6715' (1455) SUPV: JT DAILY · }9/10/95 ( 6) TD' 7353' (638) SUPV' Tm DAILY' 09/11/95 ( 7) TD' 7353' ( 0) SUPV' JT DAILY' 09/12/'95 ( 8) TD: 7~53' ( 0) SUPV' JT DAILY: MW: 9.0 PV/YP: 30/36 APIWL: 6.0 DRILL 9-7/8" HOLE @ 484' Move rig to lQ-20. Accept rig at 1630 hrs. 9/4/95. Drill cement in conductor from 88' to 95' Spud well @ 0300 hfs 9/5/95. Drill cement in conductor from 95' to 121' Drill 9-7/8" hole from 121' to 484' $130,346 CUM: $130,346 ETD: $0 EFC: $1,330,346 MW: 10.0 PV/YP: 24/36 APIWL: 5.8 SHORT TRIP TD 7-5/8 CSG PT. Drill 9-7/8" hole from 484' to 4110' $78,563 CUM: $208,909 ETD: $0 EFC: $1,408,909 MW: 10.1 PV/YP' 24/12 APIWL' 6.0 NU BOPE Run 7-5/8" casing. Cement well. $181,444 CUM: $390,353 ETD: $0 EFC: $1,590,353 MW: 8.8 PV/YP: 5/10 APIWL' 14.6 DRILLING Test BOPE. Wash and ream to 3984' Drilled from 4220' to 5260'. $71,141 CUM: $461,494 ETD: $0 EFC' S1,661,494 MW: 9.1 DRILLING Drilled from 5260' to 6715'. $75,220 CUM: $536,714 ETD: PV/YP' 12/ 6 AP!WL: 6.8 $0 EFC' $1,736,714 MW: 10.8 PV/YP: 25/10 APtWL: 3.2 CIRCULATING TO CONTROL WELL Drilled from 6715' to 7353'. Circulating gas cut mud. Shut in well. Monitor pressure. $94,098 CUM: $630,812 ETD: $0 EFC: $1,830,812 MW: 11.5 PV/YP' 28/10 AP!WL' 2.8 CIRCULATING TO CONTROL WELL. Shut in well and monitor pressure. Circulating to control well. $110,146 CUM' $740,958 ETD' $0 EFC' $1,940,958 MW: 12.5 PV/YP: 34/15 APIWL: 2.0 CIRCULATING Continuing to have well control problems. Final weight up to 12.5 ppg. $90,075 CUM: $831,033 ETD:~'%~.'%,-~~ ......... ~ ~._~O~V~E. Gi:'.~ .... ~:.~ $2,031,033 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 2 ':~/i~ 95 ( 9) 1353'( 0) ~I~ DAILY: 09/14/95 (10) TD' 7353' ( 0) SUPV' DCL DAILY: ~.al~ ~/95 ( 11) TD' 7353' ( 0) SUPV' DCL DAILY. · -,c~./'!6/9~ ~, ( 1~2) ~' 6~05' ( 0) SUPV ' JT DAILY: 09/17/95 (13) ?D: 6705' ( 0) SUPV' JT DAILY: 09/18/95 (14) ?D' 3840' ( 0) ~rV d l' DAILY · HW: 12.5 PV/YP' 30/14 APIWL. 1.8 ~IRCULATING-PREP TO SPOT LCH Continue te have well control preblems. Honitering well. $76,605 CUM' $907,638 ETD' $0 EFC' $2,107,638 MW: 12.5 PV/YP: 34/16 APIWL: 2.2 CIRC 12.5 PPG MUD AROUND Finish circ out gas cut mud. Monitor well; well dead. Spot 50 bbl LCM pill on bottom. Preparing to set plug when complete returns were lost. Circulating 12.5 ppg mud w/18 ppb LCM. $92,224 CUM: $999,862 ETD: $0 EFC: $2,199,862 MW: 12.5 PV/YP' 21/18 APIWL' 3.0 PREP TO SET P & A PLUG Test cement lines. Spot balanced cement plug acress the Kuparuk sands. Tag cement plug @ 7082' Circulate te clean hole and prep for second cement plug. $124,537 CUM: $1,124,399 ETD: $0 EFC: $2,324,399 MW: 12.5 PV/Y?' 17/19 APIWL: 4.4 ATTEMPT TO SET CEMENT RETAINER Spot balanced cement plug. Tag cement at 6705' Attempt to set cement retainer. $82,061 CUM: $1,206,460 ETD: $0 EFC: $2,406,460 MW: 0.0 PV/YP' 0/ 0 APIWL' 0.0 LDDP Set retainer at 3908'. Cement. Test casing. OK. Displace well to diesel. $269,437 CUM: $1,475,897 ETD: $0 EFC: $2,675,897 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 HOVE RIG TO 1Q-26 Hove rig to 1Q-26. Release rig @ 2030 hrs. 9/17/95. $310,084 CUM: $1,785,981 ETD: $0 EFC: $2,985,981 End of WellSummary for Well:AK8277 K~ ARUK RIVER UNIT WELL Final P & A Program 16" CONDUCTOR AT 121' CEMENTED TO SURFACE Halliburton EZSV (CI cement retainer) set @ 3908' Pressure-tested with water in the casing to 1000 psi, 9/1 7/95. 3 bbl cement on top. Estimated PBTD _+3840'. ALL DEPTHS ARE MEASURED DEPTHS Top hydorcarbon is C Sand @ 7095' ARCO Alaska, Inc. KRU 1Q-20 :::::::::::::::::::::::::::::::::::::::::::::::::::: ,:.[.:.~.:.~.:.~.:.~.:.~.:.~.:.~.:.~.:.~.:.~, .~.:.~.:.~.:.¥.F:.~.:.F-¥.~.:.F.~, ::::::::::::::::::::::::::::::::::::::::::::::::: ~:.F.~.:.~.:.~.:.~.:.~.:4.:.F.F.~.:.~, ,:.F:':':':':':':':'¥4, ::::~: 12.5 ppg :~:i:~ mud ~::::~: , . ., ... , . ':?:T:'F'FT:'F:T:'F'~':'F:T ~:.~.:.~.:.~.:.[.:.~.:.~.:.~.:.~.:.~.:.~.:.. .i.~.i.~-~.~.i.~.i.~.~.~.~.~.~-~.~.~-i.~. TD @ 7353' faC7-5/8', 29.7#, L80 SHOE AT 4099' emented with 703 sx AS III nd 320 sx Class G to surface Cement plug for kick off later in the DS lQ program' 450 sx Class G · +51 50' 3908' 6-3/4" OPEN HOLE Cement Plug: Total' 283 sx Class G Tagged plug at 6705' on 9/15/95 DKP 9/18/95 COMPANY ARCO ALASXA~ iNC, ~HLL NAME !0-20 LOCATION i XUPARUX LOCATION 2 ALASKA DA?Z: 13-S~P-75 MAGNeTiC D~CLINA?iON 27,7Z ~RID CONV~R~NC~ AN6L~ 0,00 WILL A?~ ~ Ak AP! ~ Date~r~~L~ SURVEY ANALYS!E ?VD INC CHG CUMI.~ CHB ft ft dog I2!.0 121,00 0,00 301,5 301,55 0,25 659,7 659,73 0,16 !031,1 t031,0J 0,03 1395.8 1395,74 1,43 1767,? 1765.6! 4.39 1861,4 1856,37 4.51 1952.7 I943,48 2,78 2045,4 2030,92 0,82 2137,4 2117.02 1,71 2229,7 2201,7~ 4,00 2324,3 2285,67 3.86 ~2415,7 2363,~7 3,43 250~,3 2441,77 2,23 2694,? ?fs~,q~ 0 ~q 2968,8 2813.30 2,18 3336.0 3101.65 1,17 3706,3 3387,42 1.35 3888,9 3527.92 -0,94 4026,7 3635,t0 -0,62 4219,1 3785,92 -0,45 4314.! 3860.65 -0,02 4497.5 4006,47 -!,63 4779.2 4234.89 -1.42 4957,9 4383.24 -2,35 5026.0 4439,~9 3,13 5232,J 4605.52 3.25 ~,~. ..... o~ -1,16 _,..~798,? 6062o8 52E9,75 -0.70 6248,5 5386,02 66!6~5 5672,94 -1.57 6805,7 5523~4~ -!,48 ~987,2 5%8,50 0,66 7228,2 .5i63,.$7 ! ,~ .~ CH~ CU~A!~ CH~ -- -- deg/!OOft deg deg -- deg/!OOft 0.00 0,00 0,00 0,00 0,00 0.25 0,14 -M,69 -88,67 -49.~,~ 0,41 0,05 61,01 -27,68 17,03 0,45 0,0t 64,50 36,81 !7,37 1,88 0,39 4,31 41,12 1,18 2,87 I,!0 -!8,20 22,92 -20,06 5,03 2,33 -9,17 13,75 -?,88 7.23 2.~ !0,94 24,69 11,82 1t,62 4.~'j~ 6,8? 31,58 7,18 I6,I3 4,83 -0,72 30.87 -0,77 18.72 3.05 -0.42 30.45 -0.46 19.74 0.87 -3.51 26.94 -3.79 21,45 1,86 -1,58 25.36 -1,7I 25.45 4.33 -0.5! 24.85 -0,56 29,31 4,09 -1,28 23,57 -1,35 32,74 3,75 0,24 23,81 0,26 34,~.. 2,~.~ 0,15 23,9^. 0,1~. 35,50 0,2? 2,62 2~,58 !,41 37,67 0,79 -3,54 23,04 -I,29 38,84 0,32 2,05 25,0? 0,56 40,19 0,37 -5,37 19,72 -1,45 39,24 -0.52 6,12 25,84 3,35 38,62 -0,45 0,!7 26,00 0,12 38.18 -0.23 -3.4? 22.52 -!.81 38.!5 -0,02 -6,55 15.~7 -6,89 36,52 -0,8? 3,61 19,58 1,97 35,10 -0,5i 2,30 21,88 0,82 32.74 -!.32 -3,31 !8.5~ -1,85 35,88 4,60 4,t6 22,73 6,1! 39,13 1.57 1,32 24.05 0.64 41,44. .,_~I ?, -1,63 22,4! -0,88 40,28 -0,62 ':-"" ;'n,08 -' '~.~,. .., ,,24 39,47 '0,44 1.31 21,39 0,72 38,77 '0,25 -6,70 14,69 '2,44 37,~,,. -O,Xr~... ~,85 , 24,34 5,w~ .~ 39,66 !,i! -4,4~ I?,85 38,09 -O,~J -~,38 ~q+47 -3,~' . ~o ,,~ ,69 37,27 0,36 . ?,89 23,5? . 34,5? -t,~I -2,34 2!,25 -0,97 IQ-2O n~ ,. CLuoURE TOOL FACE DLS DLSRT ft deq de~ilOOft deq/lOOft~2 0,00 0,00 0,00 0.00 0,37 0,00 0,14 0,08 2,10 98,20 0,10 0,01 2,78 118,65 0,12 0,0I 0.00 0,00 0.39 0,07 0,07 48,43 !,36 !,07 0,70 20,89 2.42 1.13 !.13 I]3.,45 2.68 0,29 -0.57 i7.85 4,72 2,12 0.55 5.55 ¢.83 0,12 -7,65 2.77 3.05 1,95 -I0,82 56,40 1,54 1,63 -12,74 18,67 1,96 0.46 -!4.25 3,17 4.33 2.57 -3,86 2,57 4,13 0,21 -16.15 2,18 3,75 0.42 -!7,21 2,23 2.38 1,47 -21,99 7!,70 0,8~ 0,82 -27,80 45,58 1.!1 0,09 -15,35 9,22 0,47 0,17 -31,72 70,50 0,9~ 0,I4 -31,77 !05,92 2.20 0.66 -36,60 170,25 0,46 1,27 -39,83 103,03 !,15 0,36 -33,1~ 48,30 4.26 3,27 -26,63 128,12 !.49 !,51 -20,85 137,60 0,69 0,28 -16,59 143,21 1.67 0,55 -15,25 38.58 5.74 5,98 -36.2~ 92,9! !.S2 1,99 -!7,80 25,!7 1,37 0.13 -14,67 127,95 !,02 0,19 -10,59 I34,52 0,64 0,21 3,43 !01,96 1,5.5 0,34 -i6.77 14,43 3,27 II,27 56,I7 !.9I 0.75 23,53 !13.86 2.50 0,2! 34,92 1!!,52 ';,44 36,00 70,37 1,02 '?,95 t04,37 1,25 IQ-20 ************* CIRCULAR ARC mETHOD******** MD. TVD TNA CH6 CUMINC CHG I kATE AZM CH6 CUMAZM CHG ~u.,_ RATE it ft de~ deq deg/!OOft deq deg deg/!OOft CLOSURE TOOL FACK DLS DLSRT f~ dmq ~e~/lOOf~ PROJECTED TO TD 73~3.3 6266.67 0.00 34.~9 0,00 0,00 21.25 0,00 38,46 ?0.02 . !995 i'38PM ARCO ALAS~fA INC ARCO Alaska, Inc. FACSI ILE TRANSMISSION Date: c~ 'T~me: _ __ Number of Pages (Cover ,-): ~to. 3345 31 IlIl II II IIII II · ; I; .... ' "" ii I II II · .·" |.', ..... ,, ,, :1 Il Il ii I~1II II II Il I! II II II II II II II II ....... i! i .... II iii II Id ....... From: ~-~e v~'~' e.. ~"~e_~3 k Phone: ~f~-% ~-( ~ Location: Location: Copies To: -- r Kuparuk Odll Site Development FAX #: Phone #: P. O. BOX 100360 ANCHORAGE. AK 99510-0360 FAX # 907 265-6224 ATO- 12O9 · _! 2q~- 14-33 i Subject: Comments: SEP '! 8 ]995 Oil & Gas Cons. Commission ~chorage 1995 l'39PM , ARCO ALASKA INC' .vv Third Plrty Spill RepOd Kupl,'uk River Field }to. 3345"'" '?. 3/4 '"'- level 1, I.evit ~ Follew-p~ l~fer~ltl~. - ' ' - ~ -'- - ' --: .... - - ' _ .... S?II~ Ig submit ~he f~llQ~g inf~mili~n ~ Re~wr~ ~l ~le~.al or re~cle I~mi~on(e) SlOpetBkln-o lobe ~ ~ ' ---gl- m' ' ~ * .... -'--- '~ ~ ' " - ' - ~--~""~"'"'-,.'~.,-'~2 A. ~ -, .... - ......... " ' ~hty .1~ A~eR i~ll elm I~ ~olomn~p, - --~ , -- , , -.,,~, ~,~ - .- ,., -,... (,.,. ~,,.,.,.,,.~- ~~_. ~-z J- ~- - . ..... ' -- I ---- s-'~-..~,~,,:... , __ SEP 't 8 1995 L OUm~rW~Wllm.{T ' if V,~, a,~ ot wmm~r, V~o m wml~: . .. swf.~ w,m ~ wm~;Ala~ .Oil .& Gas Co~s. · ~u~ ~ .pil, ~e ~umm of ~m g~ m O~gmmr. ~ i, lp~lo or o~m~ ~bnce~; AMa Oope~oni of ~vkonmenlmlbnm,~. S.£P '! 8 ]995 _Al. as~ ¢il.& 6as Cons. Commission "~chorago . 1995 l'39PM ARCO ALASKA INC ,RUK RIVER UNIT WELL lQ-.-., Final P & A Program No. 33~,5 P. 2/4 "Diesel to 2000' ' for freeze protection 16" CONDUCTOR AT 121' CEMENTED TO SURFACE Fresh Water Halliburton EZSV (CI cement retainer) set @ 3908' Pressure-tested with water in the casing to 1000 psi, 9/17/95 15.8 ppg cement 7-5/8", 29.7#, 1.80 SHOE AT 4099' Cemented with 703 sx AS III and 320 sx Class G to surface Cement plug for kick off later in the DS lQ program: 450 sx Class G _+5150' - 3908' ALL DEPTHS ARE MEASURED DEPTHS Top hydorcarbon is C Sand @ 7095' ARCO Alaska, inc. KRU 1Q-20 'q.":'i':i':'i:'..:- ::."':i':'hi':i' ""l"'¥";'"l"'~'"';'"'-""t'","'"l' '-~!'!'!+!'~'!-:'!'~'!+i+~?!'~'i':" '," ~':'~':']'."~":'~'."]'?!",'~':'7:'!'. .:.L:.-" :.i.:,L',i:.L:.L:,[,:J,:,L:J .:.[- :, ;... _,. ;. :..,.; -j.;j .._.!'!'! 12.5 ppg :i:::: i'i'i mud ':'_-i.:.,..:.v...:.:.-:.;.,.:..:.:.:..:.~.:]]/l .!.i-.',i.!+_:'i.!._:-!.i.!.i-_'.i,!.f.!.i.!. ,:,L:,~,:J,:,L:,i:.L:,L:,i,:J,:,L:,! ':'ht;':"~:';::?ri:'?:?:i:':..-:'i ':"-::!':[:T:T-'T:T:T-'T:T:': fi,~! cement TD @ 7353' 6-3/4" OPEN HOLE Cement Plug= Total: 283 sx Class G Tagged plug at 6705' on 9/15/95 .. Gas Cons. Commission Anchorage DKP 9/18/95 Blair Wondzell Sr. Petroleum Engineer September 14, 1995 Subiecb Blair, KRU Well lQ-20 Hole Problems pr't; q~- (Facsimile only) Per your request, this fax is to fill you in on the operational problems we've been experiendng on KRU lQ-20. The permit number for this well is 95-131. Pressure reduction has been ongoing for about three months on DS lQ in preparation for the infill program, which began at the end of August with the drilling of 1Q-24. Based on our recent pressure information from offset wells and knowledge of the surrounding faulting, lQ-20 was believed to be in a very low-pressure, fairly isolated fault block. We believed the BHP to be less than 3200 psi and planned to drill with a corresponding mud weight of 10.4 ppg. This should have provided us with at least 150 psi of trip margin and overbalance to both the A and C Sands. On 9/9/95 we drilled through the C Sands with 10.4 ppg mud without problems. When we penetrated the A4 interval the rig took a kick (final kill weight = 12.5 ppg) at 7353' MD/6259' TVD. The well was shut in and we proceeded to kill the well slowly, weighting up in several incremental stages to try and avoid lost circulation problems. We did see some losses near the beginning of the operation, but the well stabilized and the final kill weight was achieved on 9/11 without seeing any further losses. From the beginning we began adding fine lost circulation material to the mud to reduce the chances of lost circulation (Ultraseal, Barofibre; up to 10 ppb in system). We had a 5" TFI turbine and Slim 1 MWD equipment in the hole, and so were limited on what LCM could be safely used without risk of plugging the drillstring. The well appeared stable at 12.5 ppg and the rig began tripping out of the hole to pick up a rotary assembly with no MWD, which would enable us to finish the last few hundred feet of the well while adding coarse LCM. We saw slight losses on the short trip, but they appeared to be caused by some packing off experienced around 6900' MD. No gas ;*,,as seen on bottom after the short trip and the trip out was smooth. When running in with the rotary BHA we began seeing severe losses once below the surface casing shoe. We continued tripping while keeping the hole full. An LCM pill helped regain circulation and oil and gas were circulated out of the wellbore at reduced pump rates. Once the well appeared to stabilize we tripped back out of the hole on 9/13 to PU open-ended drill pipe and P & A the Kuparuk section. The severe losses and high mud weight combined to make any chances of successfully completing 1Q-20 very slim. If you have questions or comments on any of the above please call me at 263-4183. Drilling Engineer CC: M. Zanghi K1 (lQ-20) Wl Well File ATO-1276 ATO-1205 SEP 1 8 Gas Cons. C0mml~!nn ' ~cl'iorage. '" MEMORANDUM TO: David John~,'- Chairman'--" THRU' Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 15, 1995 FILE NO' NAXJIOCD.DOC FROM' Lou Grimaldi,.~J'~ SUBJECT: Petroleum in~-"'pector Open Hole Cement plug Arco well #1Q-20 Kuparuk River Field PTD #95-131 Friday, September 15,1995: I verified the depth of the open hole abandonment plug on Arco's well 1Q-20 in the Kuparuk River Field. This was the second plug laid at this particular interval due to insufficient height of the first plug. The top of cement was located at 6705' RKB with the top of K10 located at 7095' RKB. A tag with drillpipe of 10K down with the pumps running at 3 BPM was observed. The plug appeared very solid with no indication of sticking when the drillpipe was picked up. SUMMARY: I witnessed the successful tag of the open hole abandonment plug on Arco's well #1Q-20 in the Kuparuk River Field. Attachments- NAXJIOCD.XES cc: Mike Zanghy (Kuparuk drilling Supt.) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plug And Abandonment Report Operator: Operator Rep.: Lease No.: Arco Alaska Inc. James TranthemlDenise Petrash Well No.: 1Q-20 Sec. T-R Total Depth: 7353 Well Name: PTD No.: Elevation: Date: 1 Q-20 95-131 9/15/95 Meridian: Mud Wt.: 12.5 ppg. CASING DATA: Drive Pipe: O.D." Set @: Conductor: O.D." Set @: Intermediate: 7 5/8 O.D." Set @: 4099' ft. With ft. Surface: ft. Prodctn: Penetration O.D." Set @: O.D." Set @: 121 PLUGGING DATA: 1. Open Hole Plugs: #1 plug 7353' to 7082', #2 plug 7082' to 6705'. Top of K10 C sand at 7095'. Tag performed with Drillpipe 10K down pumps running at 3 BPM. 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet REMARKS: Well will be suspended pending new plans for sidetrack. Distribution: odg - Well File c - Operator c- DNR/DOG c - Database c - Rpt File c- Inspector Inspector (s) · Louis R. Grimaldi FI-000 (Rev. 3/93) NAXJIOCD.XLS AL/ ~ OIL AND GAS CONSERVATION COMM ~N APPLICATION FOR SUNDRY APPHOVALS ,. 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 _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1090' FNL, 1820' FEL, Sec. 26, T12N, R9E, UM At top of productive interval Ik0 R i G 1806' FSL, 647' FEL, Sec. 23, T12N, R9E, U At effective depth At total depth 1964' FSL, 583' FEL, Sec. 23, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7353' feet 6259' feet NAL 6. Datum elevation (DF or KB) RKB 41' Pad level 94' feet 7. Unit or Property name KuDaruk River Unit 8. Well number 1Q-20 9. Permit number ~J5-131 10. APl number 50-029-22589 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7353' feet 6259' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth Length 80' 4O58' measured None true vertical Size 16" 7-5/8" Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 250 Sx AS I 630 sx AS III & 320 sx Class G Measured depth True vertical depth 121' 121' 4099' 3690' RL , ;VED SEP 1 4 1995 Gas Cons, Commission Anchorage 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch _ 14. Estimated date for commencing operation ~)/1 3/9,5 Oi~ X Gas 16. If proposal was verbally approved Name of approver Blair Wondzell Date approved 9/13/9." Service Sicjned V k,'~ Title Drill Site Dev. Supv. -. FOR COMMISSION USE ONLY Conditions of approval: Notify~'ommission so representative may witness Plug integrity L---/' BOP Test__ Mechanical Integrity Test _ 15. Status of well classification as: _ Suspended Approved by the order of the Commission IApproval N Location clearance __ I.. Subsequent fo.r~ require 10- ~(..)'7' Approved ~opy jngmal $ignecl By - · Returned, Form 10-403 Rev 08/15/88 SUBMIT IN TNiP'LfCAT~: KRU lQ-20 Plug and Abandon 6-3/4" Production Hole Kuparuk River Unit Well lQ-20 was drilled to Kuparuk target location 1806' FSL, 647' FEL, Sec. 23, T12N, R9E, UM as planned under Permit #95-131, API #50-029- 22589. While drilling through the Kuparuk A4 Sand the well took a kick and the mud was weighted up from 10.4 ppg to 12.5 ppg. We pulled the BI-IA and ran back in with a rotary assembly to finish the hole. Once past the surface shoe at 4099' MD we experienced heavy lost circulation. Circulation was eventually regained on bottom at a reduced flowrate. Any further attempts to drill or case this hole section are considered high risk and not economic to pursue. For this reason, AAI requests approval to plug and abandon the Kuparuk formation. The surface casing will be used to sidetrack lQ-20 to another Kuparuk location. However, we are still evaluating how far from the original location we should drill, so Parker Rig #245 will move off of lQ-20 to finish drilling other wells on DS lQ until a decision can be made. A balanced cement plug will be left across the Kuparuk formation per AOGCC regulation 20 AAC 25.105 (f) (1). We will also spot a kickoff plug across the - surface shoe. Kill weight mud will be left in the hole with diesel across the permafrost for freeze protection. Please see the attached procedure for specific in£ormation. Verbal approval to begin P & A operations was given by Blair Wondzell of the AOGCC on 9/13/95. Approval to sidetrack the well to the alternate location will be requested via a Permit to Drill form 10-401. If you have any questions or comments regarding the attached procedure, please contact myself at 263-6206 or the Drilling Engineer, Denise Petrash at 263-4183. SEP 1 4 1995 Alaska O~l & Gas Cons. Commission Anchorage KUP~RUK RIVER UNIT WELL Final P & A Program 1Q-.~0 16" CONDUCTOR AT 121' CEMENTED TO SURFACE Top hydorcarbon is C Sand @ 7095' 7-5/8", 29.7#, L80 SHOE AT 4099' Cemented with 703 sx AS III and 320 sx Class G to surface Cement plug for kick off later in the DS lQ program: 150 sx Class G 45OO' 390O' OPEN HOLE ':T:T:'~':T:'!':T:T:T:T:T:' .~,~.~.~.~.~,~.~.~.~. ':'?:'i':'i':'h'i':'i':'?:'i':'i':'h' · i'i' 12.5 ppg :q: mud i:i: 6-3/4" .:.~...:...:...:...:...:...:...:...:...;... ':'{':'F:'~':'!':'~':'~':'F:'!':'~':?:' ...~...~...~.,.!...~...~...~...!...~...~... -~.~.~.!.~.~.~-~-~.i' '":'"['"I"':"':'"~'"~'*'~'"~"'~'" .:.L:.L:.!.:.!.:.L:.!.:.L:.L:.{.;.!.:. .:.i.:.i.:.i.:.i.:.i.:.i.:.i.:.!.:.i.:.i.:. Cement Plug' 130 sx Class G 7353' - 6835' SEP 'l 4 1995 Alaska Oil & Gas Cons. Commission Anchorage TD @ 7353' ARCO Alaska, Inc. KRU 1Q-20 DKP 9/13/95 ARCO Alaska, Inc. Prepared By: Approved By: Plug & Abandonment Procedure KRU 1Q-20 (C) AFC# AK8277 Drilling ~zn ine/er Dn I~e' ' ~~upervisor Date Described below is a procedure to sidetrack KRU Well 1Q-20. We are abandoning this location due to well control and lost circulation problems. As of now, we are planning on P & A'ing the Kuparuk formations, setting the kickoff plug at the shoe, and moving to the next well (1Q-26). The proposed plug and abandonment procedure has been verbally approved by the AOGCC (Blair Wondzell, 9/13/95). AOGCC requires cement from 50' below the base to 100' above the top of hydrocarbons, and that we notify an inspector in time to witness the setting and tagging of the plug. Pluo and Abandon Kuoaruk: -- 1. RIH with 4", open-ended drill pipe to TD. 2. Circulate and condition the mud until it is clean and evenly weighted (minimum two bottoms up). . Lay a balanced cement plug in the 6-3/4" open hole from TD to a minimum of 100' above the top of the hydrocarbons. Keep non-pumping time to an absolute minimum; the A and C Sands are believed to be cross-flowing and seem to be under control only while pumping, due to our high slimhole ECDs. Minimizing non-pumping time will help prevent any contamination from entering the annulus before and during laying the plug. Lay the plug as follows: Pump: 22.0 bbls 11.0 ppg weighted ARCO spacer 22.9 bbls Class G (130 sx) cement slurry 7.8 bbls 11.0 ppg weighted ARCO spacer 59.8 bbls 12.5 ppg mud displacement TD: Top C Snd: Estimated top of plug in 6-3/4" hole: Estimated top of plug in 7-1/2" hole: 4" DP capacity: 6-3/4" hole capacity: DP x hole capacity: MW: Hole angle: 7353' MD 7095' MD 6835' MD (260' above C Sand) 6934' MD (if hole washed out; 160' above) 0.009996 bbl/ft 0.04426 bbl/ft 0.02872 bbl/ft 12.5 ppg 34° . Set 5. . Cement Slurry: Type: Weight' Yield' Additives: Volume: -Class G 17.O ppg 0.99 cu ft/sk 0.100 gal/sx D47, 0.45 % D65, D800 retarder as required for 3 hr thickening time @ 140° (lab tests currently in progress) 130 sacks Total spacer required: 29.8 bbl of 11.0 ppg Notes: · Cement is batch mixed. · 22 bbl weighted spacer will result in a maximum of 50 psi pressure drop in the annulus. (Well flowed at 12.3 ppg, which is a 65 psi drop from kill weight of 12.5 ppg.) This volume will provide >700' of separation between the mud and cement slurry. Drop drillpipe wiper plug before the 7 bbl water spacer to aid in keeping the cement slurry from becoming contaminated while pumping down the drillpipe. (No plug catcher on drillpipe.) Be as close on bottom as possible as the cement enters the annulus (while leaving room for the DP wiper plug to drop out). Consider underdisplacing by 1 - 2 bbls to ensure the drill pipe doesn't U-tube. At planned displacement volume, 17.0 bbl of cement will be in the annulus and 5.9 bbl will be inside the drillpipe when pumping is stopped. Pull 5 stands out of the cement to _+6375'. Circulate and reciprocate DP while WOC; if desired, drop drillpipe wiper plug to aid in cleaning out cement. You should see some of the spacer at BU. Watch for any signs Of influx into the wellbore. Although we suspect the sands to be crossflowing within the Kuparuk, the A Sand could easily be crossflowing to another weak zone higher up the wellbore. If this is true, gas could migrate up through the cement plug and cause another well control incident. Be alert for signs of gas or oil in the mud. After waiting on cement for ~ hrs, RIH and tag cement plug (DS currently running lab tests to determine optimum WOC time before tag). Notify AOGCC representative in advance to witness tag. CBU to check for any signs of gas or oil in the mud. Kickoff Pluq at Surface Shoe: POOH to 4950' MD. Spot 20 bbl viscous pill. POOH to 4500'. Circulate and even out mud weight (minimum of two bottoms up). Lay a balanced cement Plug in the 6-3/4" open hole and 7-5/8" casing from 4500' to 4000' as follows: Pump: 23.0 bbls 11.0 ppg weighted ARCO spacer 26.9 bbls Class G (156 sx) cement slurry 7.6 bbls 11.0 ppg weighted ARCO spacer 30.6 bbls 12.5 ppg mud displacement PBTD: Top of viscous pill: Surface shoe: +_6835' MD 4500' MD 4099' MD Estimated top of plug in 7-5/8" casing: Estimated top of plug in 7-5/8" casing: 4" DP capacity: 6-3/4" hole capacity: DP x hole capacity: 7-5/8" casing capacity: DP x casing capacity: MW: Hole angle: Cement Slurry: Type: Weight: Yield: Additives: 3900' MD (6-3/4" open hole) 4000' MD (hole washed out to avg. 7-1/2") 0.009996 bbl/ft 0.04426 bbl/ft 0.02872 bbl/ft 0.04591 bbl/ft 0.03037 bbl/ft 12.5 ppg 38° Volume: Class G 17.0 ppg 0.99 cu ft/sk 0.100 gal/sx D47, 0.45 % D65, D800 retarder as required for 3 hr thickening time @ 80° (lab tests currently in progress) 156 sacks Total spacer required: 30.6 bbl of 11.0 ppg Notes: · Cement is batch mixed. · 23 bbl weighted spacer will result in a maximum of 50 psi pressure drop in the annulus. This volume will provide >700' of separation between the mud and cement slurry. · Be as close to 4500' as possible as the cement enters the annulus · Consider underdisplacing by 1 - 2 bbls to ensure the drill pipe doesn't U-tube. At planned displacement volume, 20.1 bbl of cement will be in the annulus and 6.8 bbl will be inside the drillpipe when pumping is stopped. 7. POOH to _+3450' MD. Reverse circulate DP clean. . . POOH to ___1700' MD (below base of permafrost) and circulate diesel to surface for freeze protection. Continue POOH. Top off 7-5/8" casing with diesel. NU tubinghead, adapter and master valve. Move rig to 1Q-26. If there are any questions about this procedure please call me at x4183. D. K. Petrash Drilling Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 29, 1995 Terry Jordan, Senior Drilling Engineer ARCO Alaska, Inc. Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-20 ARCO Alaska, Inc. Permit No 95-131 Surf Loc 1090'FNL, 1820'FEL, Sec. 26, T12N, R9E, UM Btmhole Loc 2202'FSL, 441'FEL, Sec. 23, T12N, R9E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to ddll does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE)' must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. Yours very truly, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ,N_Abr~ Oi,_ ,4~ID GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill D 1 b Type of Well Exploratory I--] Stratigraphic Test E] Development Oil X Re-Entry E] Deepen I--I Service D Development Gas r-I Single Zone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage~ AK 99510-0360 ADL 25634, ALK 2567 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.O25) 1090' FNL, 1820' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1809' FSL, 606' FEL, Sec. 23, T12N, R9E, UM 1Q-20 #U-630610 At total depth 9. Approximate spud date Amount 2202' FSL, 441' FEL, Sec. 23, T12N, R9E, UM 9/1/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Q-15 7776' MD 1809 ~ TD feet 11.8' ~ 600' MD feet 2560 6559' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 1 500' feet Maximum hole angle 39,1 8° Maximurn~rface 2184 pslg At total depth (TVD) 3300 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~l Weight Grade Couplin~l Length MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' :b?.00 CF 9.875" 7.625" 29.7# L-80 LTC 4034' 41' 41' 4075' 3690' 630 Sx Arcticset III & HF-ERW 320 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOE 7029' 41' 41' 7070' 6012' HF-ERW 6.75" 3.5" 9.3# L-80 EUE8rdM 706' 7070' 601 2' 7776' 6559' 240SxClass Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat E] BOP Sketdn X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] RefraclJon analysis I--I Seabed report i--] 20 AAC 25.050 requirements X 21. I hereby certifyjthat the for~,going is true and correct to the best of my knowledge Signed ~'~~. Title Drill Site Develop. Supv. Date ~"-~ ~,~ v ' ~..~J . ~ Commission Use Only PermiL.Number . ¢~1,4~,PI number ~.-~,, .,.., I Approval d'Ate /~ _-. I See cover letter for -I I~;'/,.~ ~/Y"~ I other requirements Con~litions of approval Samples required E] Yes ~ No Mud log required r"] Yes [] No Hydrogen sulfide measures ~1~ Yes D No Directional survey required ,~ Yes D No Required working pressure forBOPE E] 2M [] 3M [~ 5M E] 10M E] 15M Other: -.:0RIGINAE SIGNED B, by order of Approved by ~ RUSSELL A. DOUGLASS Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in tri[~licate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1Q-20 · · 1 , 1 Gl 1 = · 10· 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,075')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,776') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement tapered 5-1/2" x 3-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test tapered 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Pressure test SBE/XO. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well 1Q-20 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drillina Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.1 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,184 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1Q-20 is 1Q-15. As designed, the minimum distance between the two wells would be 11.8' @ 600' MD. Annular Pumping Activities: Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1Q-20 surface/production casing annulus will be filled with diesel after setting the 5-1/2" x 3-1/2" tapered casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1Q-20 be permitted for annular pumping occurring as a result of the drilling project on DS lQ, per proposed regUlations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drillin~l Area Risks: Risks in the 1Q-20 ddlling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.1 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. t jCreated by : brockway Date plotted : l 1-Aug-95 i PIot Reference is 20 Version #4. jCoordinates ore in feet reference slot #20. ITrue Vertical Depths are reference RKB (Parker #245). i A12CO ALASKA, Structure : Pad lQ Well: 20 Field ' Kuparuk River Unit Location : North Slope, Alaska I I V 400 _ _ 800 _ _ 1200_ _ 1600_ _ 2000_ _ 2400_ _ 2800_ _ 3200_ _ 3600_ _ 4000_ _ 4400_ 4800_ _ 5200_ _ 5600_ _ 6000_ _ 6400_ _ 6800 I 0 400 Scale 1 : 200.00 RKB ELEVATION: 95' SURFACE LOCATION: 1090' FNL 1820' FEL SEC 26 T12N R9E KOP 'FVD=1500 TMD=1500 DEP=O 3.00 B/ PERMAFROST TVD=1595 TMD=1595 DEP=2 6,00 12.00 15.00 Build 3 deg/lO0' 18.00 21.00 24.00 ~7.00 T/ UGNU SNDS TVD=2420 TMD=2460 DEP=2$6 30.00 33.00 56.00 39.00 EOC TVD=2707 TMD=2806 DEP=429 T/ W SAK SNDSTVD=3005 TMD=3191 DEP=673 B/ W SAK SNDS Tv'D=3490 TMD=3817 OEP=lO68 7 5/8" CSG PT TVD=3690 TMD=4075 DEP=1231 AVERAGE ,59.18 ANGLE DEG K-lOTdD=4840 TMD=5558 DEP=2168 K-5 'TVD=5595 TMD=6532 OEP=2784 HRZ Midpoint TVD=5750 TMD=6732 DEP=2910 TARGET - T/ UNIT D .-T~/D~OIZ- TVD=6036 TMD=7101 DEP=3143 T/ UNIT C 'P/D=6090 TMD=7171 DEP=3187 T/ UNIT B TVD=6163 TMD=7265 DEP=3246 T/ UNIT A WD=6287 TMD=7425 DEP=3348 T/ A5 SNDS TVD=6307 TMD=7451 DEP=3364 B/ KUP SNDS 'rvo=6404 TMD=7576 DEP=3443 \ TD /~]~I/2'' CSG PT TVD=6559 TMD=7776 DEP:3569 I I I I I I I I I I I I I I I I 800 1200 1600 2000 2400 2800 3200 5600 Vertical Section on 22.72 azimuth with reference 0.00 N, 0.00 E from slot #20 scale 1: 12§,00 0 250 East 500 750 I I I I I TD LOCATION: 2202' FSL 441' FEL SEC 25 T12N R9E N 22.72 DEG E 5569' (TO TARGET) TARGET LOCATION: 1809' FSL 606' FEL SEC 23 T12N R9E Coe/~9 %"~" -Sbk ,sboo,.s' --> 1000 1250 1500 I I I I 3500 _ _3250 _ _3000 _2750 _ _2500 _ _2250 _ _2000 _ 1750 1500 1250 _1000 75O _ _ 500 _ _ 250 _ _ 0 A I I Z Created by : brockway lDate plotted : 7-Aug-g5 Plot Reference is 20 Version #4. Coordinates are in feet reference slot #20. True Vertical Depths are reference RKB (Parker #245). --- Baker Hughes INTEQ --- ARCO ALASKA, Structure : Pad lQ Well: 20 Field : Kuparuk River Unit Locotion : North Slope, Aloska 6OO 560 520 480 440 400 _ 360 _ /k - 320 _ _ 280 _ 240 _ - 200 _ - 160 _ 120 _ 80_ <== West Scole 1 · 20.00 · 360 ,320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 320 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 2000 18O0 2800 1800 3 1600 2O0 "~x2800 1400 1200 lOOO 800 1000 800 1400 1600 1600 4000 2800 ~-600 24OO ~200 2000 1800 Z600 ~400 ~200 38OO I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 560 520 280 24-0 200 160 120 80 4-0 0 40 80 120 160 200 240 280 520 West co,e - o.oo 600 56O 52O 480 _ _ 440 _ _ 400 _ _ 360 - /k _ 320 I _ _ 280 I _ _ 240 Z _ 0 _ 200 I - _ 160 _ _ 120 _ _ 80 _ _ 40 0 hO 80 0 0 iCreeted by : brockw(]y Dote plotted : 7-Aug-95 IPIot Reference is 20 Version #4. iCoordinotes (]re in feet reference slot #20. iTrue VerUcol Depths ore reference RKB (Porker #24-5). i --- Baker Hughes INTEQ ARCO ALASKA, ][nC. Sfrucfure : Pod lQ Well: 20 Field : Kuparuk River Unit Location : North Slope, Alaska Scale 1-50.00 East ==> 200 1 O0 0 1 O0 200 3QO 400 500 600 700 800 900 1000 I 1 O0 1200 1500 1400 1500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 2200_ -- 2100_ - 2000_ -- 1900_ -- 1800_ _ 1700_ -- 1600_ /X - 1500_ - 1400_ C 1300 , J ~ - 12oo_ - 11oo_ _ 10oo_ -- 900 ~ 8O0 700 _ © c; - 600 _ .. -- -- 500 _ 6400 6000 5800 54OO 5200 5000 ~000 I I I I I I I I I I I I I I I I I I I I I I 200 100 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1 ,~00 1400 1500 Scale 1 ' 50.00 Eo s _22O0 - _2100 _2000 _1900 -- _1800 -- _1700 -- 1600 1500 1400 _1500 _ _1200 - _11oo lOOO 900 800 _ 700 _ Q 600 ~ 500 0 .KU ARUK RIVER UNI'I 20" DIVERTER SCHEMATIC I I 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOLWITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OFANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 2(7' - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 ,6 , 5 4 13 5/8" 5000E ,JP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THATACCUMULATOR 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 PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 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. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'II'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 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 3000 PSI FOR 3 MI NUTES. 12, TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" -5000 PSI ANNULAR ?ELL PERMIT CHECKLIST // WELL NAME GEOL AREA UNIT# PROGRAM.' exp [] dev~redrll [] serv [] ON/OFF SHORE o~J ENGINEERING lo 3. 4. 5. 6. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ APPR 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23° If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ _~. ....... 26. BOPE press rating adequate; test to ~ psig~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ...... ..~ 29. Is presence of H2S gas probable ........... ~ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y/~ ~. ~ 32. Seismic analysis 9f shallow gas zones .......... ~/ N ~,- ~~ - ~ 33. Seabed condition survey (if off-shore) ........ / N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] / GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOWfjo - A:~FORMS~cheklist rev 03/94 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : lQ-20 FIELD NAIVZE : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22589-00 REFERENCE NO : 95328 151 t LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/19 ORIGIN : FLIC REEL NAME : 95328 CONTINUATION # : PREVIOUS REEL : CO[~ENT : ARCO ALASKA INC., KUPARUK lQ-20, API #50-029-22589-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/19 ORIGIN : FLIC TAPE NAME : 95328 CONTINUATION # : 1 PREVIOUS TAPE : COfZ~_2VT : ARCO ALASKA INC., KUPARUK lQ-20, API #50-029-22589-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN1 ......... JOB NUMBER: 95328 LOGGING ENGINEER: NICOLS OPERATOR WITNESS: MORRISON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING lQ-20 500292258900 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 19-APR-96 BIT RUN 2 ......... 95328 NICOLS TRANTHAM BIT RUN 3 26 12N 9E 1090 1820 95. O0 95. O0 54.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4099.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 3RD STRING PRODUCTION STRING REMARKS: Well drilled 07-SEP through 12-SEP-95 with ARC5 only. All data was collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGEDMWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH MWD 4022.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ No depth shifts applied per Dave Shafer. $ STOP DEPTH 7353.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... BIT RUN NO. MERGE TOP MERGE BASE 1 4022.0 6058.0 2 6058.0 7353.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OPH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~4~ O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OHI~ O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OHlek~ O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OP~4~ O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7353.000 ROP.MWD 66.000 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 DEPT. 7000. 000 ROP.MWD 61. 875 FET.MWD O. 778 GR.MWD RPXX.MWD 1.439 RPX.MWD 1.475 RPS.MWD 1.490 RPM. MWD RPD. MWD 1. 624 DEPT. 6000. 000 ROP.MWD 152. 308 FET.MWD O. 475 GR.MWD RPXX.MWD 2.122 RPX.MWD 2.146 RPS.MWD 2.169 RPM. MWD R PD . MWD 2.203 -999.250 -999.250 103.284 1.531 70.199 2.188 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: DEPT. 5000.000 ROP.MWD RPXX.MWD 2.770 RPX.MWD RPD.MWD 2.953 DEPT. 4022.000 ROP.MWD RPXX.MWD -999.250 RPX.MWD RPD.MWD -999.250 90.000 FET.MWD 2.789 RPS.MWD 0.714 2.822 180.000 FET.MWD -999.250 -999.250 RPS.MWD -999.250 GR. MWD RPM. MWD GR. MWD RPM. ~D 91. 800 2. 882 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE Iv-UMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCRE~FAVT: O. 5000 FILE SOF~4ARY VENDOR TOOL CODE START DEPTH ........................... MWD 4022.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~fEMORY or REAL-TIME): STOP DEPTH 6120.0 08-SEP-95 IDEAL 4. OB09 MEMORY LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ 7353.0 4022.0 6120.0 80 38.6 39.5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER ARC5 ENP1 6. 750 4099.0 BOREHOLE CONDITIONS MUD TYPE: LIGNO MUD DENSITY (LB/G): 10. 40 MUD VISCOSITY (S) : 58.0 MUD PH : 9.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 10.0 RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) '. 2. 700 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 350 MUD CAKE AT (biT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE~IARKS: ************ RU/V 1 ************* DRILLED INTERVAL 4110' - 6123' RES TO BIT: 56.54'; CR TO BIT: 61.46' ************ RUN 2 ************* DRILLED INTERVAL 6123 ' - 7353 ' RES TO BIT: 56.54'; GR TO BIT: 61.46' TD WELL @ 20:00 09-SEP-95 DATA FROM DOWNHOLE MEMORY, V4.0B09 SOFTWARE $ LIS FORMAT DATA 75.0 75.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APRil996 08:46 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXXLW1 0P2~4 O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OP~4~ O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 RPD LW1 OH~ O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6120. 000 ROP.LW1 110. 000 FET. LW1 O. 778 GR.LW1 RPXX. LW1 2.374 RPX. LW1 2. 367 RPS. LW1 2. 442 RPM. LW1 RPD. LW1 2. 596 DEPT. 6000. 000 ROP. LW1 152.308 FET. LW1 O. 475 GR. LW1 RPXX. LW1 2.122 RPX. LW1 2.146 RPS.LW1 2.169 RPM. LW1 RPD . LWl 2. 203 DEPT. 5000.000 ROP.LW1 90.000 FET. LW1 0.714 GR.LW1 RPX~. LW1 2. 770 RPX. LW1 2. 789 RPS. LW1 2. 822 RPM. LW1 RPD. LW1 2. 953 79.225 2.547 70.200 2.188 91. 797 2. 882 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: DEPT. 4022. 000 ROP. LW1 RPXX. LW1 32.707 RPX. LW1 RPD. LW1 1000. 000 180. 000 FET. LW1 O. 000 1000. 000 RPS.LW1 1000. 000 GR. LW1 RPM. LW1 S. 825 1000. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~fBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 6021.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 7353.0 12-SEP-95 IDEAL 4. OB09 MEMORY 7353.0 6022.0 7353.0 80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 34.6 39.5 TOOL NUMBER ........... ARC5 ENP1 6. 750 4099.0 BOREHOLE CONDITIONS MUD TYPE: LIGNO MUD DENSITY (LB/G): 10. 40 MUD VISCOSITY (S) : 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 10.0 RESISTIVITY (OPff4~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 700 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.350 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 4110' - 6123' RES TO BIT: 56.54'; GR TO BIT: 61.46' ************ RUN 2 ************* DRILLED INTERVAL 6123 ' - 7353 ' RES TO BIT: 56.54'; GR TO BIT: 61.46' TD WELL @ 20:00 09-SEP-95 DATA FROM DOWNHOLE MEMORY, V4. OB09 SOFTWARE $ LIS FORMAT DATA 75.0 75.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: 9 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 RPXX LW2 OH~4M O0 000 O0 0 3 1 1 4 68 0000000000 RPX LW2 Otff/k4 O0 000 O0 0 3 1 1 4 68 0000000000 RPS LW2 OPff4~ O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 OH~ff4 O0 000 O0 0 3 1 1 4 68 0000000000 RPD LW2 Oh?4M O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 7353 . 000 ROP. LW2 66. 000 FET. LW2 1 . 194 GR. LW2 78. 292 RPXX. LW2 3. 881 RPX. LW2 3. 941 RPS. LW2 3.913 RPM. LW2 3. 921 RPD . LW2 4. 041 DEPT. 7000. 000 ROP.LW2 61. 875 FET. LW2 O. 778 GR.LW2 103.287 RPJ~X. LW2 1. 439 RPX. LW2 1. 475 RPS. LW2 1. 490 RPM. LW2 1. 531 RPD. LW2 1. 624 DEPT. 6021.500 ROP.LW2 180.000 FET.LW2 0.000 GR.LW2 6.291 RPXX. LW2 103.344 RPX. LW2 1000.000 RPS.LW2 1000.000 RPM. LW2 1000.000 RPD. LW2 1000. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-APR-1996 08:46 PAGE: 10 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/04/19 ORIGIN . FLIC TAPE NAME · 95328 CONTINUATION # : 1 PREVIOUS TAPE : COf~f~NT : ARCO ALASKA INC., KUPARUK lQ-20, API #50-029-22589-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/04/19 ORIGIN : FLIC REEL NA~E : 95328 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC., KUPARUK lQ-20, API #50-029-22589-00
