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185-215
Ima ect Well History File' COver~l~l~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _J _~_~'- ~-_~ ~' Well History File Identifier DIGITAL DATA Organizing (done) RESCAN n Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [3 Poor Quality Originals: NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ ' Logs of various kinds [] Other Scanning Preparation ~:~ x 30 = ~2 ~) + c:~-,.-~ = TOTAL PAGES ~ BY: BEVERLY i~_.~ VINCENT SHERYL MARIA LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED F,LE: COU.T.ATC.ES NUM.ER,N SCAN.,.G PREPARAT,ON: Y'. YES PAGE BY: ~ BREN VINCENT SHERYL MARIA LOWELL DATE: IJ,~'O~/S/~j~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCE~MARIA LOWELL DAT (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES) NO NO Re'Scanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ned.wpd PLUGG!- ~ .= & LOCATION CLA.~RA~CE REPORT State cf Alaska ~ots casia= si---s, wU, de.mUh, cra: '-Long Csq: 2er~ inns?zais - tops: Review the well file, and-cc=men= on plugging, well head s ua=us, ~d !oca=icn clearance - p=ovide loc. clear, co.de~ ~~ .:~~/ -. ...... Well head =at off: -- · ~arker ~os~ or pla=s: LocaUion Clearance: Code Signed PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 July 19, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3J-07 P&A (85~215 / 301-125) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the recent P&A drilling operations on 3J-07. If You have any questions regarding this matter, please contact me at 263-4135 or Brian Noel at 265- 6979. Sincere~ ///~ T. Brockway ~ Interim Drilling Engineering Supervisor PA1 Drilling TAB/skad ORiG1NAL · " STATE OF ALASKA ~-'. A,_,-,SKA OIL AND GAS CONSERVATION C~ .,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! well Classification of Service Well Oil [~ Gas r~ Suspended D Abandoned [~] Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 85-215 /301-125 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21438 4. Location o! well at surface 9. Unit or Lease Name 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM ~ ~i (asp's 519545, 6002573) Kuparuk River Unit At Top Producing Interval ~J~l~. · ". i' 10. Well Number 1217' FNL, 1130' FEL, Sec. 9, T12N, R9E, UM~ -i; 3J-07 At Total Depth ~' 11. Field and Pool 1492' FNL, 1354' FEL, Sec. 9, T12N, R9E, UM ~ (asp's 517633, 6000186) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 79.6 RKB feetI ADL25630 ALK2563 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, If offshore 16. No. of Compietlons October 4, 1985 October 10, 1985 5/24/01 P&A'd I N/A feet MSL 0 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21, Thickness of Permafrost 7650' MD/6575'TVD 6948' MD/6020' TVD YES ~l No []'1 N/A feetaD 1700' (approx) 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5ff H-40 79.6' 115' 24' 183 sxAS II 9-5/8" 36# J-55 79.6' 3490' 12.25' 1005 sx AS III & 295 sx Class G 7" 26# J-55 79.6' 7633' 8.5" 435 sx Class G & 250 sx ASI bridge plug set at 6849' MD cement retainer set at 6948' MD 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) N/A N/A N/A Abandoned 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED cement retainer @ 6948' 30 bbls cement for retainer 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF iWATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JUL 1 9 ZOO1 Alaska Oil & Gas Cons, Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate -29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7070' 7133' TRUE VERT. DEPTH 6117' 6166' 6269' Base Kuparuk A 30. 7263' 7418' 6390' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravily. GOR, and time of each phase. N/A RECEIVED JUL 1 ZOO/ · Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations 32. I hereby cert?~th/~the following is t~e"~ajnd correct to the best of my knowledge. // / / Si~ned Idle Intedm Ddllin,q En,qin~rin.q Supentisor Tom Broclovay Questions? Call Bdan Noel 265-6979 Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Legal Well Name: 3,1-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 ,- ' .... ?-;;;;:;-:_:_ ;~ .-. ';;~.. :. /_':- :';i'~:;-h. 7~:.:i?~i~-i:F:'.,.-*..-' ~%;:: -';: ': :";:~:!i;--~-t .... ; ?.:-: - ........ ~-_ ?'~,~,~-.'~:. ,.'-:~'~:,','-': ~:':,',., '.,'.'::~:,-.-,: .. ~':-,:,-'. ':- ~ .... ' ...... ~'-'_ _ -Sub-- L--:'~::. -_' -:--:¢~i::';:--: i.: :. - - --;'-'?.~?.~?,;~';?;~?.:;'~ ;i:~;-:: :-;':!:';;-;'.;;':".~4- -~.--'-.: ..... :..¢..---:-..;;-:~}:~'.:;-;;,?:.?y:.;":';';.-:. '~.:-: - '?:;i:.; '.'-'-i.!~ ?~::.:. ~ '..7':?: -,'.'i:':,'7%:""'.- ".':;;:: -~ . "-' :':' ..... I / I , Set in flow back tnks. Berm up around rig & flow back tnks. Press test I I I flow back hard lines to 1000 psi. 18:00 - 21:00 3.00 WELOTL NUND ABANDN ' Retdeve bpv & vr plugs. Si & monitor / confirm well static. I Initial before bleed down = 81P/3.5/3.5 x 7"/9.625/7" = 400 / 200 / 0 i psi'/ 21:00 - 22:00 1.00j ^B~N~hiSFTY ABANDN Pre idb safety ! ops mseting. Review hook uo into production inlection I ~stem w! produ~on personnal. 22:00 - 00:00 2.00' WELCTL CIRC ABANDN ~ Disp well bore w/warm sea water ~ 3.5 bpm / 500 psi. After 260 bbl ! fluid [composed of 10% crude & 90% sea water] cleaned up to ~ moderately clean fluid - si & monitor well static for 15 minutes. X-over I [ to recovering returns to flow back tnk & pump an additional 100 bbl sea water until returns clean [incomplete rpt time]. I 6/2/2001 00:00 - 01:00 I 1.00 WELCTL CIRC ABANDN Complete circulating well bore to clean sea water. I · 3.00 01:00 - 04:00 i WELCTL NUND ABANDN RD circulation lines in cellar & lines to surface flow back tank. Set bpv in tree, nd tree. Make up blanking plug to mandrel. Nu hope. ! I 04:00 - 09:00 5.00 WELCTLil BOPE ABANDN i Aogccl Function24teSthr notifiedb°ps' Test. no show.b°pe 250 / 5000 annular 3000 psi 5 min. i NOTE: Unable to test lower pipe rams due to Interference of stick up of I blanking flange into lower pipe ram cavity. Will accomplish when out of i hole. i09:00 - 11:00 2,00 WELCTL BOPE ABANDN Pooh w/test jt & blanking flange. Pull bpv. RIh w/Idg jt & pull hanger / tbg string to floor w/56k lbs to string, no ovger puli.Set wear bushing. · 11:00 - 12:30 1.50 WELCTL~ClRC ABANDN Start 180 bbl cir for bu, after40 bbl away riser leaking, sd. i 12:30- 15:00 2.50 RIGMNT RGRP ABANDN Repair riserleak. 15:00 - 16:00 1.00 WELCTL ClRC ABANDN Restart cir for bottoms up, circulate 180 bbl @ 4 bpm / 450 psi. 16:00 - 21:30 5.50 ABANDN RTRV ABANDN Pooh w/existing completion, break out tbg accessories, visually insp ~ threads, installing thread protectors on pin end & standing back. ~ Recovered all completion from top seals In the seal assmby to hanger. ' i I The threads below the top seals were not damaged. There is no i iI ~ ~ immediate evidence of any cut [partial or otherwise] in the 31.47' joint ! I [ where the cut was attempted. Measurements of the "Baker Seal XO' ~ I [.33'], pupjt [6.11], Camco "W" nipple [1.95'] & full jt [31.47'] where cuts were located match w/old completion tally. 21:30 - 23:00 1.50 WELCTL BOPE ABANDN Complete bop test by testing lower pipe rams 250 / 5000psi. I Set wear bushing. , . I i , NOTE: Previously unable to test lower pipe rams w/blanking flange , i[ made up to mandrel - to tall, interferes w/closing rams. I ,23:00 - 00:00 !.00 ~B^ND~ TRIP 1 ^BANDN X-o~t floor equip for handling dril~ string. Pu csg ~rappor on hwdp & dp I I I tripping to 3.5" tbg cut @ sim of string. Printed: 7/11/2001 4:30:13PM Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: S/~1/200~ End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 6/2/2001 23:00 - 00:00 1.00' ABANDI~ TRIP ABANDN evidence of attempted cuts. 6/3/200t 00:00 - 06:00 i 6.00 ABANDI~ TRIP ABANDN Complete tih w/bit / scrapper to tag top of pkr @ 6919' rkb Nordic 3. 06:00 - 09:00I 3.00 ABANDN ClRC ABANDN Circulate bu @ 10 bpm / 1200 psi while cutting drlg line. After bu I i decrease rate to 3 bpm. Simultaneous eps: Cut & slip drlg line. 09:00 - 12:30 i 3.50 ~B~D~ IRIP ^BAND~ Pooh w/bit & .~mpper. 12:30-13:00 I 0.50 W~ITON ~:QIP :~B^N~N Wo Schlumberger-flattire. 1O:00 - 14:30" 1.50 AB^NDN RURD AB^NDN Ru Schlumberger for iunk basket run w/6.0 gage ring run. 14:30- 16:00 1.501ABAND TRIP i~B~NDN Schlumberger tripiunk b~ket to wi deplh of 6885'. Smooth run, minor II , trash recovery in basket. Did not tag packer due to shape of junk , ' I basket & id of packer. ' 16:00 - 17:00 [ 1.00 ABANDI~ TRIP ABANDN Schlumberger rih w/Baker cibp, run correlation log tieing in to cbl I dated 10x10x1985. Set cibp @ 6849', 2' above collar @ 6851' Pu 10 ! r ', sit down confirming cibp in place. Pooh w/setting tool, no damage to i I I same. Ld tools, rd schlumbergr. .17:00 - 18:00 I 1.00 WELCTL' OBSV !ABANDN Si w/blind rams. Test [charted] cibp / 7' csg to 3000 psi / 30 min. !! i. Aogcc notified - no show. i18:00- 18:30 I 0.50! ABANDI~ PLUG !ABANDN Pjsm concerning running whipstock. i i 118:30- 20:30 2.001/ABANDI~ TRIP , ABANDN Rih w/whipstockmill out assmby, hanging up in well hd [wearbushing]. I !I will not pass upper mill [6.151 "] Locate a bushing w/6.25" special bore. I ~ ,~ ,~ Check clearance on floor, Install same in stack. 20:30 - 00:00 3.50 ! ^BANDI~ IRIP AB~NDN Pick up milling as, mby & make up to whipstock. Continue pu bha & dp tripping in hole. 6/4/2001 00:00 - 04:00. 4.00 ABANDI~ TRIP ABANDN Complete trip to 6775', 75' above cibp. 04:00 - 05:30 i 1.50 ABANDN ClRC ABANDN Displace well bore & surface system to 12.5 ppg GEM mud - 8 bpm / I i I 2400 psi. Used 25 bbl spacer pill between SW & GEM mud. I 05:30-06:30I 1.00 ABANDN PLUG ABANDN Orient tool face to l4deg left of high side. Pumping@8bpm/2400psi I ~ Set down incrimentaly to 25k lbs over string - anchor did not set. ~ Repeated second ~me w/no result. Pulled pumps to 4.7 bpm [min i mwd flow rate]/2000 psi, set down on cibp & set anchor @ 12k lbs. I Continue to set do~n wt & shear off stud @ 30k lbs down wr. I ABANDN 06:30 - 09:30 ! 3.00 ABANDN MILL Cir / cond mud to 12.5 ppg. Large amts of fine sd on shakers, cleaned I !up in 1 hr. Erratic sw cut mud to 12.1 ppg noted. I 'MILL !09:30 - 18:00 I 8.50 ABANDt~ ABANDN Begin milling csg @ 60 rpm / 3-4 k lbs, 2800 psi / 5.5 bpm. Gradually i i~ i increased rpm to 80, bit wt to 9k lbs, rpms to 80. torque leveled off to '. j ] 9000ft-lbs 71000 fi-lbs. Continued to drlg formation to 6848'. Window: Printed; 7/11/2001 4:30.13 PM Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 W4/2001 09:30- 18:00 8.50~ABANDNMILL, ~ABANDN ~24- 68~', open hole to 6848'. 18:00 - 19:30 1.50' WELCTL OTHR ABANDN Circulate ~nd mud for leak off test. 19:30 - 20:00 0.50 WELCTL TRIP ABANDN Pull milling ~mby into ~g [68~ ]. ' WELCTL OTHR 2.50; 20:00 - 22:30 ABANDN Si on dp for FIT test. Made numerous a~emp~ to run w/~g pumps, ; ble~ back to 200 psi each time. SI chole / kill / mud manifold 2 X ~ r~undan~ & use bo~ test pump. Test be~er but still bled to 200 psi. EMW = 12.5 ppg +{200}/[.052 x 5927'~d] = 13.15 psi Unable to r~rd ~ ;vol pump~ or r~vered, however it was ve~ small. 22:~ - 23:30 J 1.00 WELCTL CIRC ~ANDN I RIH to td & s~t a 20 bbl "ultra' Iow fluid Io~ pill ~mposed of gel, fluid ! ~ Io~ agent, & light Icm. I 23:30- 00:~ 0.50~ WELCTL TRIP ABANDN J Pooh w/milling ~smby. ~ ~NOTE: have recovered 220 lbs steel by ~ hrs, ~ steel to rec = 6' x I ; 26 ppf = 156 lbs. Rate re~ve~ d~re~ uniformally w/ame, last 6 , ~ hr rec le~ than 20 lbs. ~5/200~ ~00:00 - 08:80 ~ a.50 ~h 1~1~ ~$~D~ ~ooh w/millln~ ~m~y. ~11 mill, in ~flo a~ run: load mlll ' middlo ~ S.875', up~r mill $.151'. Glean out bop,s ~ s~lc~ lop drlvo. ~0~:~0 - ~:00 0.$0 WffkGT OTH~ i~~ ~orm FII t~t: ~} chok~ / kill / mud mni~old w/2 x rodundant valvos. H~ ~p t~st pump. Impo~ ~fi0 p~i, a~r fi rain down to 2~0 ~ t ~ steady for5 min ~ 2~ ~i. ~ ~ EMW = 12.5 ~g + 230/[.052 x 5927' Wd] = 13.21 ppg EMW ~:00 - 05:30 ~ 1.50~ DRILL ~ PULD PROD Pick up additional 27 j~ 3,5' dp & stand back in deffeck. 05:30- 08:30~ 3.~j DRILL ~PULD PROD Make up bha ~ & test mwd. 08:30 - 12:00 3.50' DRI~ ~TRIP PROD RIH w/dp to top of win~w. 12:00 ~:00, 12.~ DRILL ~DRLG PROD Ream~m window-noproblem-DHg. & sliding. W6/2001 00:00 12:00 12.~ DRILL ~DRLG ~PROD DHII from7086-7220'. 12:00- 00:00 ~ 12.~ DRILL ~DRLG PROD ~DHII from7220-7560', ~/2001 '00:00 - ~:00 ' 6.~ DRILL ~DRLG I PROD ~DHg. from 7560 to ~40 MD. ~60 ~D. 06:00 08:00 2.~ DRILL ~CIRC ' PROD Pump hi Vis Sweep-Circ.-cond mud-Monitor well. 08:00 - ~:00 1.~ DRILL ~WIPR PROD Wiper Trip to ~ndow ~ 6810'. 09:00 - 11:~ 2.~ RIGMNTi RGRP PROD Se~ice top ddve & re.irs to same. 11:00 - 12:00 1.~ DRILL ~OBSV PROD Well appears to be flowing small amount-obsewe & shut in same-90~ ~ ~ on dp. 12:00- 13:30 1.50 DRILL TRIP PROD RIH to ~40'. ~ 13:30 18:00 ' 4.50 DRILL ~ClRC PROD Cim. & cond hole for liner-build mud ~. to 13~ while circ.-drill to 7740' ! i ~ile circ.. 18:00 - 19:30 1.50 DRILL TRIP PROD POH to shoe-no hole problems=hole t~ing corr~ ~ount of fluid. 19:30 - 20:00 0.50 DRILL CIRC PROD Pump d~ job & blow down top dHve. ~20:00 - 23:30 ~ 3.50 DRILL TRIP PROD POH w/bha ~. 23:30- ~:00 0.50 DRILL J PULD PROD 'Laydown BHA ~3. 6/8/2001 00:00 - ~:30,- 0.50 DRILL PULD PROD J Finish Laying Do~ BHA ~3. ~:30 - ~:00 ~ 3.50 CASE PULR PROD Rig up handling ~uipment & mn ~ its 4.5' 12.6~ L-80 nsct csg. -liner ~. 'hanger & packer. I ~:00 - 09:~ ~ 5.00 CASE j RUNL PROD RIH w/4.5" liner on 3.5' dp to 6725'. 09:00 - 10:~~ 1.~ CASE I OTHR PROD Circ. ~paci~ of liner & dp ~ window-pick up & make up cement head , Printed: 7111/2001 4:30:13 PM Legal Well Name: 3,.I-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 6/8/2001 09:00 - 10:00 1.00 CASE I OTHR i PROD on 1 it. dp & lay in 'V' door. 10'00 - 12:00 2.00 CASE RUNL {PROD RIH w/4.5' liner to 7725'-pick up cement head jt.-make up same & rig ! up cement lines. 12:00 - 14:30 2.50 CASE CIRC PROD Circ. Condition mud as per program to 7740'-reciprocate same. 14:30 - 16:00 1.50 CEMENT PUMP I PROD PJSM-Batch mix spacer & Cement-pump 5 bbls. CW100-test lines to i 4000#-pump 5 bbls. CW100-Pump 40 bbls. 14.0# mudpush XL-pump i 40 bbls. Class 'G' cement-15.8# Followed w/2 bbls. water to clear 1~:00 - 19:30 3.50 CEMENTt. DISP PROD Displace cement w/rig pump-bump plug-set hanger & packer-release ~rom liner-pump 10 bbls.mud long way-fig up & ro¥omo out 11 bbls. iI't , I 1bpm! cement-10 bbls. CW100 & 40 bbls. mudpush. Circ. 2 volumes dp @to clean cement out of dp. 10 119:30 - 00:00 4.50J DRILL PULD PROD j PJSM-Pump dry job-poh laying down 3 1/2' dp. 6/9/2001 00:00 - 04:00 4.0Ol DRILL . PULD PROD !Finish laying down 3.5' dp-hwdp & dc,s. ll04:00' 05:30 I 1.50 DRILL OTHR PROD PJsM.PUll wear ring-change out handling equipment-empty pipe shed-hold 05:30 - 11 ;00 5.50, CMPLT~ RUNT CMPLTN Run in hole w/3.5' completion as per program. 11:03 - 16:00 5.00 CMPLTI~ OTHR i CMPLTN Attempting test on annulus & packer-Pump away @ 1.16 bpm @ 900#-check all surface equipment-sting in w/seal assembly-test down i ~ I tbg. 3500# 15 mins. OK. (decision to run RetrieVo'matic on tbg. & test t 16:00 - 20:00 i 4.00 CMPLTI~ ClRC CMPLTN Circ. condition mud due to 10 bbl. loss to formation-stabilize wt. @ ,J 12.8# to prevent flow back. !20:00 00:00 4.00 CMPLTI~ OTHR CMPLTN POH w/3 1/2' completion string for retrlev'o'matic packer. 6/10/2001 I00:00 03:00 3.00 CMPLTI~ TRIP CMPLTN 1RIH w/Retriev'o'matic packer to 4310'. 03:00 - 03:30 0.50 CMPLTI~ DEQT CMPLTNI~ Set Packer & test csg. 'OK' 03:30 05:30 i 2.00 CMPLTN TRIP CMPLTN Continue running in hole to 6654'-tag packer & set @ 6652'. i05:30 - 06:30 ~ 1.00- CMPLTN DEQT CMPLTN Test csg. to 3500# 15 mins. 'OK'-release packer-set 25k down on i packer. 06:30 - 08:30 2.00 CMPLTN OTHR , CMPLTN Service top drive & cut drlg. line. j08:30 - 12:00 3.50 CMPLTN TRIP CMPLTN POH w/packer & lay down same. 12:00- 17:00 , 5.00 CMPLTN RUNT CMPLTN Rig up & RIH w/completion as per tbg. details. 17:00 - 19:00 ! 2.00 CMPLTN PCKR tCMPLTN i Stab into seal bore & drop bail to set packer. 19:00 - 20:30 1.50 CMPLTN PCKR CMPLTN Set packer & test tbg. 3500# OK-test annulus 3500~ OK. Shear PBR & shear Dump kill valve. 20:30 - 23:00 2.501CMPLTN ClRC CMPLTN Pump sweeps & displace well w/seawater @ 7.5 bpm-3000#. 23:00 - 00:00 ! 1.001CMPLTN SOHO CMPLTN Space out-make up hanger & landing it. Land hanger. 6/I 1/2001 00:00 00:30 0.501CMPLTN SOHO CMPLTN Land hanger & rilds. 00:30 - 03:00 2.50 CMPLTN NUND CMPLTN i Pull landing jt.-set BPV-nipple down bope & nipple up tree. 03:00 - 04:00 1.00 CMPLTN SEQT CMPLTN J Test packoff to 5000#-test tree 5000#. 04:00 - 06:00 2.00 CMPLTN FRZP CMPLTN i Pull test plug-rig up circ. hoses-pump diesel down annulus-'U' tube CMPLTN i diesel. 06:00 - 07:30 1.50 CMPLTN OTHR , i Rig down circ. hoses-set BPV secure well-prep for rig move. (rig 'released @ 0730 6/11/01. for move to 3G-19A. , I Printed: 7/11/2001 4:30:13 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _X Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface -v/r ~ '~/' 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1217' FNL, 1130' FEL, Sec. 9, T12N, R9E, UM At effective depth At total depth 1492' FNL, 1354' FEL, Sec. 9, T12N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 32.5' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3J-07 9. Permit number / approval number 85-215 ~ 10. APl number -,/ 50-029-21438 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Surface Surface Production Liner measured ffueve~cal Length 80' 3460' 7603' ./ 7650 feet Plugs (measured) 6575 feet ~ 7177 feet Junk (measured) 6201 feet Size Cemented Measured Depth True vertical Depth 16" 183 sx AS, 115' 115' 9.625" 1005 sx AS III & 295 sx Class G 3490' 3422' 7" 435 sx C~ass G & 7633' 6561' 250 sx ASI Perforation depth: measured 7128'-7134', 7158'-7165', 7279'-7300', 7322'- 7325',7325'- 7328', 7328'-7350' true vertical 6162'-6167', 6186'-6191', 6281'-6298', 6315'-6318', 6318,-632~SE~iVED Tubing (size, grade, and measured depth 3.5", 9.3#, L-80, @ 6965' MAY .L 0 ZOO1 Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 6937', No SSSV 13. Attachments Description summary of proposal __X Detailed operations program __ Alaska Oil & Gas Cons. Commission BOP ske~' 14. Estimated date for commencing operation 5/15/01 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Gas __ Service Suspended __ 17. I hereby certify that the foregoing is tree and correct to the best of my knowledge. Questions? Call Brian Noel 265.6979 Signed James Trantham Title: Drilling Engineering Supervisor ~--//--~,¢_~ /-7~,//~/-,~ 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- Date Prepared by Sharon AIIsuD-Drake Approval no. Approved by order of the Commission ORIGINAL SIGN~:, D Taylor Seam::'-, Commissioner Date ,-]..~' ,///~) / ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE KRU 3J-07 SUNDRY OBJECTIVE P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) CURRENT WELLBORE STATUS: Well 3J-07 was drilled and completed in 1985 as a 3-1/2" single gaslift completion, producing from the Kuparuk A sands. An ESP was installed in 1996 and after the pump failed a 3-1/2" gaslift completion was run in 2000. The well began making sand/rocks and after numerous but unsuccessful attempts to produce was shut in January 2001. The 3J-07 sidetrack is a wellbore replacement, moving the well approximately 300' to the southeast to recover the remaining reserves in the pattern. Well 3J-07 is currently shut in awaiting sidetrack. The tubing is blocked by sand/rock (bridge?) at 1450' with unknown fill amount below. WELLWORK (Prior to P&A): 1. RU ~oiled tubing and clean out sand/rocks in tubing and fill in 7" to as deep as possible. Last CT clean out on 1/20/01 reached 7118' CTM (suspect casing is collapsed or parted at this point). Confirm that sufficient injectivity into uncovered perfs exists for upcoming cement squeeze. 2. RU slickline unit. RIH gauge tubing (ID clearance for cement retainer) and tag fill. Obtain static BHP. P&A WORK (Pre-Rig): 3. RIH and pull 1" GLV from mandrels #1-3 (2606', 4095', and 5397' MD RKB) and run 1" DV in each mandrel. Pressure test 3-1/2" by 7" annulus. 4. RU CTU. RIH with cement retainer on CTU and set retainer at +/- 6948' MD RKB (middle of 10' pup joint of 3-1/2" tubing below Baker SAB-3 packer). 5. Squeeze 12 bbls of 15.8 ppg Class G cement below retainer (8 bbl for the tubing and 7" casing volume + 4 bbls into perfs). If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. 6. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor for any pressure build-up. 7. RU slickline unit. RIH and pull 1-1/2" DV from mandrel #5 at 6869' MD RKB, leaving an open pocket. 8. RU E-line unit. RIH and cut tubing at +/-6900' MD RKB (middle of full joint of 3-1/2" tubing above Camco 'W' nipple). Note: Plan to set bridge plug in 7" at +/-6850'. 9. Set BPV and VR plug. Remove well house and scaffolding. BDN 5/07/01 KRU 3J-07 Producer Proposed P&A 9-5/8" 36~ J-55 @ 3490' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 7" Baker 'Window Master Whipstock' top @ +/-6828' MD Bridge Plug Depth tied in with CET 10/19/85 7" Baker Bridge Plug set @ +/-6850' MD Tubing cut @ +/-6900' MD, middle of full joint 3-1/2" tubing above Camco ~/V' nipple. Abandoned Peds C/B-Sand Perfs 7128' - 7134' 7158' - 71 A-Sand 7279'-7300' 7322'-7350' 7"26#J-55@ 7633' Cement retainer set in 10' pup joint below packer @ +/-6948' MD Squeeze cement below retainer into perfs Note: Collapsed or parted casing at 7149' PBTD @ 7544' TD @ 7650' BDN 5/02/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing X Alter casing_ Repair well _X Other_ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 32.5' Rig RKE 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchora,cje, AK 99510-0360 Service ~ Kuparuk River Field 4. Location of well at surface: 8. Well number: 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UI~ 3J-07 At top of productive interval: 9. Permit number/approval number: 1217' FNL, 1130' FEL, Sec. 9, T12N, R9E, UM 85-215/300-040 At effective depth: 10. APl number: 50-029-21438 At total depth: 11. Field/Pool: 1492' FNL, 1354' FEL, Sec. 9, T12N, R9E, UM Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 7633' Plugs (measured) true vertical 6562' Effective Deptt measured 7177' Junk (measured) true vertical 6201' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 183 sx AS II 115' 115' Surface 3460' 9.625" 1005 s× AS Ill & 295 s× C~ass G 3490' 3422' Production 7603' 7 .... 435 sx Class G & 7633' 6561' 250 sx ASI Liner ** Appears mill exited 7" casing during clean out from 7152'-7171' (Kuparuk 'B' perforations). Perforation Depth measured 7128'-7134', 7158'-7165' **, 7279'-7300', 7322'- 7325',7325'- 7328', 7328'-75~'O' true vertical 6162'-6167', 6186'-6191' 6281 '-6298', 6315'~6318', 6318'-6320', 6320'-6~;7' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6965' Packers and SSSV (type and measured depth) Baker SAB-3 Pkr @ 6937', No SSSV RE£EIVE 1,3. Stimulation or cement squeeze summary -~i,L~Pt 2 1 2000 Intervals treated (measured] N/A das~a. Oi~ & Gas Cons. C05111If~ Intervals treated (measured) Anchorage 14. Representative Daily Average Production or Injection Dolo ©iI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Affochments 15. Status of well classification os: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _~ Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Date: 03/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3J-07WO RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:02/20/00 START COMP:02/20/00 FINAL: -- WI: 0% SECURITY:0 API NITMBER: 50-029-21438-00 02/20/00 (Cl) TD: 7650' PB: 7544' 02/21/00 (C2) TD: 7650' PB: 7544' 02/22/00 (C3) TD: 7650' PB: 7544' 02/23/00 (C4) TD: 7650' PB: 7544' 02/24/00 (C5) TD: 7650' PB: 7544' 02/25/00 (C6) TD: 7650' PB: 7544' RIG UP TO CIRC. THRU WING MW: 0.0 SUPV:M.C. HEIM Move rig from 1Y pad to 3J pad. PJSM. Rig up. Accept rig @ 1800 hrs. 2/20/2000 PUMPED 9.8# BRINE-MONITOR MW: 9.8 BRINE SUPV:M.C. HEIM Test hardline & valves. Bad valve block, change out and retest, OK. PJSM. Displace well to seawater and brine. N/U BOP'S MW:12.0 LSND SUPV:DONALD L. WESTER Continue to weight up clear brine. Pump mud displace brine. With mud at surface shut down. Continue circulating and raise mud weight to 12.0 ppg. AT ESP PUMP MW:12.0 LSND SUPV:DONALD L. WESTER Continue reverse circulating. N/D tree. N/U double gate w/ drilling spool. Function test BOPs. Pull tubing. PJSM. Continue to pull 2-7/8" casing and ESP. CONTINUE TO CIRC OUT GAS, MW:12.0 LSND SUPV:DONALD L. WESTER Continue to pull 2-7/8" tubing and esp cable. Clean out sand from 7089' to 7145'. Gas cut mud at surface. MILLING @ 7176' W/ 6" APE MW:12.0 LSND SUPV:DONALD L. WESTER Continue to circulate bottoms up 0 7145' lite gas cut mud. Try to clean out w/6-1/16" reverse circulating junk basket. Rough not making any hole. Pump dry job. POOH. Clean out junk baskets. RIH w/6" bit to 7145'. CBU. Try to clean out junk unable to get past junk at 7159'. RIH with 6 1/16" concave mill. Start milling @ 7152' [ AR 21 O00 Anchora[lo Date: 03/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/26/00 (C7) TD: 7650' PB: 7544' 02/27/00 (C8) TD: 7650' PB: 7544' 02/28/00 (C9) TD: 7650' PB: 7544' RUNNING 3-1/2' COMPLETION MW:12.3 LSND SUPV:DONALD L. WESTER Milling w/6-1/16" concaved mill from 7158' to 7171'. Mill appears to be outside 7" casing (Kuparuk 'B' interval). Getting back large pieces cement and formation. Possible collapsed or split 7" casing at 7149'. Stop fill clean out and decide to run completion. Pump dry job. POOH. L/D DP. PJSM. R/U to run 3.5" completion. R/D MOVE RIG OFF WELL. CL MW: 0.0 DOILW SUPV:DONALD L. WESTER Run 3.5" tubing and completion. Set packer, held ok. NU tree and test to 250/5000 psi. test tubing to 2500 psi. MW: 0.0 DOILW SUPV:DONALD L. WESTER Move off well clean up location. Release rig 8 0300 hrs. 2/28/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ 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 ../ ,/ ./ 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1217' FNL, 1130' FEL, Sec. 9, T12N, R9E, UM At effective depth At total depth 1492' FNL, 1354' FEL, Sec. 9, T12N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 80' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3J-07 9. Permit number / approval number 85-215 '/ 10. APl number 50-029-21438 '/ 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Surface Surface Production Liner measured true vertical Length 80' 3460' 7603' 7650 feet~v Plugs (measured) 6575 feet"// 7544 feet Junk (measured) RK Latch @ 7421' 6491 feet Size Cemented Measured Depth True vertical Depth 16" 183 sx AS II 115' 115' 9.625" 1005 sx AS III & 295 sx Class G 3490' 3422' 7" 435 sx C~ass e & 7633' 6561' 250 sx ASI Perforation depth: measured true vertical Tubing (size, grade, and measured depth 7128'-7134',7158'-7165',7279'-7300',7322'-7325',7325'-7328',7328'-7350' 6162'-6167',6186'-6191',6281'-6298',6315'-6318',6318'-6320', 2-7/8", 6.5#, L-80, @ 7026' Packers & SSSV (type & measured depth) None 6 (EIVED FEB 15 2000 Amlmoii&6ascons, 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 16. If-p ropo~(~~d Name of ap'prover' February 21, 2000 J 15. Status of well classification as: ~ ~ \ f~ ~.f,..~J Oil __X Gas__ Date approved Service Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedchipAlvo~/ ~ ~.~. ~ Title: DrillingEngineeringSupervisor Questions? Call Brian Noel 265-6979 Date Prepared by Sharon Al~sup-Drake 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- ORIGINAL SIGNED BY Approved by order of the Commission Robert N. Christenson Form 10-403 Rev 06/15/88 · Approval,n?,. SUBMIT IN TRIPLICATE 3J-07 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slickline unit. RIH and set standing valve in 3-1/2" 'D' Nipple @ 6,939' to isolate and protect pump. 2. RIH and pull GLV's and set DV's in GLM #2 @ 2561', GLM # 3 @ 3908' and GLM #4 @ 4944'. Pull CV from GLM #5 and leave open pocket. 3. Set BPV in tubing and install VR plug in annulus valve. 4. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: . . . . . . . . 10. 11. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits and displace well with seawater. Shut in and determine kill wt fluid requirements. Load pits and displace well with kill weight fluid. Ensure well is dead. ND tree. NU and test BOPE. POOH laying down 2-7/8" tubing, jewelry and ESP. PU 3-1/2" drill pipe, RIH with scrapper and bit and clean out fill to PBTD, POOH laying down DP. RIH with permanent packer and jewelry (as shown on attached schematic) on 3-1/2" tubing. Space out, land tubing hanger and set packer. PU and shear PBR. Space out and re-land tubing hanger. Pressure test tubing and annulus. ND BOPE. NU and test tree. Displace well with seawater. Freeze protect well with diesel. Lower Limit: Expected Case: Upper Limit: 5 days No problems pulling completion or cleaning out well. 6 days 8 days Difficulties pulling ESP due to sand. RECEIVED Alaska 0ii & Gas Cons. Commission Anchorage BDN 2/14/00 ARCO Alaska, Inc. GAUGE (6910.6911, OD:2.875) NIP (6939-6940, 0D:2.875) TUBING (0.6955, OD:2.875, ID:2.441) PUMP (6955-6983, OD:5.130) PUMP (6983-6990, OD:5.130) SEAL (6990-7004, OD:5.130) MOTOR (7004-7010, OD:5.620) Per[ (7128-7134) Per[ (7158-7165) Per[ (7279-7300) Perf (7322-7322) 1 1/2" DMY w/ RK Latch (7421-7422, OD:1.500) 3J-07 APl: 500292143800 SSSVType: Camco D Nipple GKA 3J-07 Angle ~ TS: 138 deg (~ 7079 Angle @ TD: 37 deg.@ _7650 .... Rev Reason: NEW GAS LIFT , DESIGN BY VG Last Update:l 1/25/00 Well Type: PROD Orig Completion: 10/11/85 Annular Fluid: Last W/O:_ 11/19/96 Reference Log:I Ref Log Date: Last Tag: 6477 TD: 7650 flKB Last Tag Date: 1/23/00 Max Hole Angle:_~46 deg @ 4600 Casing String - CONDUCTOR Size Top Bottom [ TVD Wt ]Grade 16.000 0 115 /__ 1~1511_ _ 62~50I H-40 Casing String - SURFACE Size Top t Bottom I ---TVD - wt I Grade 9.625 0 I 3490I 3423 _ 36.00 ] J-55 Casing String - PRODUCTION Size T~p Bottomt TVD Wt i Grade 7.000 7633 - 6~2 - 26~00 J-55 Thread Thread ..... Thread Tubing String - TUBING Size Top Bottom TVD Wt I Grade 2.875 0 6955 6026 6.50J L-80 Perforations Summary Interval 7128-7134 7158-7165 7279-7300 7322-7325 7325-7325 7325-7328 7328-7328 7328-7350 Gas Lift Mandrels/Valves Thread -- ABM-EUE . __ TVD Zone Status Feet SPF Date I Type_ Comment 6163 - 6168 C-1,UNIT 6 4 5/26/871APERF 90 deg. phasing; 2 1/8" EnerJet .... B 6187 - 6192 UNIT B _7_ 4.'5/26/87JAPERF 190 deg. phasing; 2 1/8" Ene~'Jet -- -- 6282 - 6298 A-3 21 1 5/26/87 APERF Zero deq. phasing; 2 1/8" EnerJet 6316- 6318 A-2 3 4 4/8/86 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6318- 6318 A-2 0 5 4/8/86 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6318 - 6320 A-2 3 4 4/8/86 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6320 - 6320 A-2 0 5 4~/86 IPERF ' 90 deg. phasing; 4" HJ II Csg Gu_n__ _ 6320- 6338 A-2 22 4 4/8/86 IPERF 90 deg. phasing; 4" HJ II Csg Gun Stn MD TVD Man Man V Mfr V ~ry~pe V OD 'Latch'P°rt TRO ' Date- Vlv Mfr Type Run Cp~m~e_n_! 1 129 129 McMurray FMHO DMY 1.0 BK 0.000 0 1/23/00 2 2651 2647 McMurray FMHO GLV 1.0 BK 0.125 1254 1/23/00 3 3908 3765 McMurray FMHO GLV 1.0 BK 0.156 1295 1/23/00 4 4944 4509 McMurray FMHO OV 1.0 BEK 0.250 0 1/23/00 (1) 5 6863 5953McMurrayI FMHO CV 1.0 BK 0.000 0 1/23/00I 1. Possible mandrel damage - see 1/8/00 WSR. Pressure tested OK 1/22/00. Other t , equip., etc.) - JEWELRY Depth I'TV~) ' :l'yl~e ' Description ID 6910 5990 GAUGE Baker 'Sentry' P & T 2.441 6939 6013 NIP Camco 'D' Nipple NO GO. 2.250 6955 6026 PUMP Centrilift Model 'GPMT'; Series 513 Tandem Pump #1 w/bolt on Head 0.000 6983 6048 PUMP Centrilift'NPSH' Pump #2 w/Integral Intake 0.000 6990 6054 SEAL Centrilift Model 'GSTB' Tandem Seal Section 0.000 7004 6065 MOTOR Centrilift Model 'KMEGI' Series 2_Mgt_oC 2~25 H.P .... ~0_.000~ Fish - FISH Depth Description 7421 1 1/2" DMY w/RK Latch I Comment I FISH in Rathole .... RECEIVED !'5 1 5 2000 (las Cons. C0n~~ Anchorage 3J-07 Proposed Completion 7" 26# J-55 @ 7633' N. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down. M. 3-1/2" 9.3~ L-80 EUE 8rd Mod tubing to the tubing hanger. L. 3-1/2" Camco 'DS' Nipple with 2.812" No-Go profile set @ +/- 500' MD (4616545). K. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBMM' mandrels w/DV's, spaced out as follows. GLM # MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD 6 TBD Note: Each GLM should have 6' L-80 handling pups installed. J. 3-1/2" x 1-1/2" Camco 'MMM' mandrel w/DCR-1 dump kill valve & RKP-2 latch (3000 psi casing to tubing shear). 6' L-80 handling pup installed on mandrel. I. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod tubing H. 3-1/2" Camco ~V' Nipple w/2.812" Selective profile (4247635). G. 3-1/2" Baker '80-40' PBR w/10' effective stroke (32K lb shear). 6' L-80 handling pup installed. F. Baker 'KBH' Anchor Seal Assembly w/3" ID. E. 3-1/2" x 7" Baker 'SAB3' Hydraulic Set Permanent Packer (5.968" OD x 3.25" ID). D. Pup Joint 3-1/2" x 10' L-80 EUE 8rd Mod tubing. C. 3-1/2" Camco 'D' Nipple w/2.75" No-Go profile (4831355). B. Pup Joint 3-1/2" x 10' L-80 EUE 8rd Mod tubing. A. Baker 3-1/2" shear out sub (3500 psi shear). Tubing tail @ +/- 7050'. C/B-Sand Perfs A-Sand Perfs PBTD @ 7544' TD @ 7650' 7128-7134' and 7158-7165' 7279-7300' and 7322-7350' BDN 2/14/00 ARCO Ala'skal inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3J-07 (Permit No. 85-215 & 396-213) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of sundry well operations for the recent workover on KRU 3J-07. The workover was to pull the existing completion and to install an ESP. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED FEB ,51997 Alaska 0il & (las Cons. Cou.mssion Anchorage STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Install ESP 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1217' FNL, 1130' FEL, Sec 9, T12N, R9E, UM At effective depth At total depth 1492' FNL, 1354' FEL, Sec. 9, T12N, R9E, UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB 8O' 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3J-07 9. Permit N-timber / Approval No. 85-215 396-213 10. APl Number 50-029-21438 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured 7650' feet Plugs (measured) true vertical 6575' feet Effective depth: measured 7544 feet Junk (measured) true vertical 6491 feet Casing Length Size Cemented Structural Conductor 80' 16" 183 sx AS II Surface 3460' 9-5/8" 1005 sx AS III & 295 sx Class G Intermediate Production 7603' 7" 435 sx Class G & 250 sx AS I Liner MD TVD 115' 115' 3490' 3422' 7633' 6561' Perforation depth: measured 7128'-7134', 7158'-7165', 7279'-7300', 7322', 7325', 7328', 7332'-7350' true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 7026' Packers and SSSV (type and measured depth) None 6162'-6167',6186'-6191' 6281 '-6298', 6315', 6318', 6320', E D FEB 5 1997 ,Alaska 0il & Ga~ Cong. Arichnr~g_~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation: 655 1751 892 Subsequent to operation: 1390 396 1548 Casing Pressure Tubing Pressure 1400 550 45O 75O 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 'L~~ ~. ~,,.,,._..._._ Title I::::~-LLr.-.I.. E~C.U~EER Date Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplicate Date: 1/28/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3J-07 RIG:NORDIC WELL ID: 998455 TYPE: AFC:--998455 AFC EST/UL:$ 510M/ OM STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:11/13/96 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21438-00 11/13/96 (C1) TD: 7544' PB: 7544' S UP V: WJP DAILY: $ 11/14/96 (C2) TD: 7544' PB: 7544' SUPV:WJP DAILY:$ 11/15/96 (C3) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ 11/16/96 (C4) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ 11/17/96 (C5) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ 11/18/96 (C6) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ 11/19/96 (C7) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ MONITOR WELL, WAIT ON SEA MW: 9.5 Move rig from 3J-10 to 3J-07. Accept rig @ 0900 hrs. 11/12/96. Kill well with brine. SW 43,800 CUM:$ 43,800 ETD:$ 0 EFC:$ 553,800 POH W/2-7/8" COMPLETION MW: 9.0 SW Circulate well to seawater. S/D and monitor. Circulate well to 9.0 ppg brine. Monitor well. N/D tree and NU BOPs. Test BOPE to 250/3500 ps'i. POH w/2-7/8" completion. 46,370 CUM:$ 90,170 ETD:$ 0 EFC:$ 600,170 RIH WITH BIT & SCRAPER MW: 9.1 NACL POH LD 2-7/8" tubing and jewelry. RIH with fishing tools. Release packer. Circulate once around. Gas at bottoms up, continued circulating until clear. Monitor well. Well static, no flow, no loss. POH. Recovered packer and tailpipe assembly. 34,234 CUM:$ 124,404 ETD:$ 0 EFC:$ 634,404 TESTING 7"X9-5/8" PACKOFF MW: 9.1 NACL Clean out junk and fill from 7288' to 7297' . Continue cleaning out fill from 7297' to 7541' PBTD. 47,119 CUM'$ 171,523 ETD:$ 0 EFC:$ 681,523 POH LDDP MW: 9.3 NACL Test 7" x 9-5/8" packoffs to 3000 psi, OK. Screw into storm valve & check for pressure, no pressure. Release storm packer & pull to floor. LD storm valve and packer. Monitor well. No pressure, but still have slow flow. RBIH. Wash and ream to 7541' PBTD. Circulate 9.3+ brine around. Started losing +/- 60 bbl/hr when 9.3+ got to surface. Mix and pump 40 bbl hi-visc sweep. Circulate around to clean out frac sand. Monitor well, static. 49,871 CUM:$ 221,394 ETD:$ 0 EFC:$ 731,394 RUNNING 2-7/8" COMPLETION MW: 9.3 NACL Change pipe rams to 2-7/8" & test to 250 psi & 3500 psi. RU to run 2-7/8" completion with Centrilift pump. Pre-job safety meeting. Start to run completion assembly with ESP. 31,200 CUM:$ 252,594 ETD:$ 0 EFC:$ 762,594 ND BOPE MW: 9.3 NACL Run 2-7/8" completion assembly with Centrilift ESP. Test tubing to 2500 psi for 30 minutes, lost 50 psi, OK. 187,779 CUM:$ 440,373 ETD'$ 0 EFC'$ 950,373 Date: 1/28/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/20/96 (C8) TD: 7544' PB: 7544' SUPV:DEB DAILY:$ RIG RELEASED MW: 0.0 DOILSW NU tree. Test packoffs to 5000 psi. Test tree to 250 psi and 5000 psi. Secure well. Release rig @ 1800 hrs. 11/19/96. 46,680 CUM:$ 487,053 ETD:$ 0 EFC:$ 997,053 End of WellSummary for We11:998455 TONY KNOWLE$, GOVEFINOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE . ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18, 1996 Mr. Mike Zanghi .~ Kuparuk Drill Site Dev. Supr. ARCO Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Waiver to the Packer Requirements of 25 AAC 25.200(d) to Allow Effective Electric Submersible Pump Completions in 3 KRU Wells Dear Mr. Zanghi: Your November 12, 1996 letter to the Commission requested a Waiver to the packer requirement of 20 AAC 25.200(d) so that electric submersible pumps (ESPs) could be used safely and efficiently in the Kuparuk RiVer Unit. This request is to allow ESP installations in KRU wells 3B-13, ~ & 3J-10. Regulation 20 AAC 25.200(d) requires that "All wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless otherwise specifically approved by the commission." ESP wells are completed with the pump set just above the zone. During pumping operations, the fluid being pumped serves to cool the pump; if gas enters the pump, the pump becomes gas locked and it over heats which results in pump failure. When Kuparuk River crude enters the wellbore, pressure decreases and gas breaks out of solution; this gas tends to rise and accumulate. When sufficient gas has accumulated so that it is sucked into the pump, the pump becomes gas-locked and it overheats because it no longer pumps fluid which would cool it. Therefore, the goal is to find a way to produce the.well safely so that gas does not accumulate where it can be sucked into the pump. One option is to set a packer high - 500' for example - this practice does not satisfy the intent of 25.200(d); this is a not a safe completion. ESP wells have to be pulled at intervals from a few months to a few years to change the pumps. It is very difficult to kill a well that has a packer installed at 500' because it is difficult to displace the gas that has accumulated in the annulus; the gas trapped under the packer makes the operation risky. Mr. Mike Zanghi ~Ku~. Dril l~ite~De¥:.,~ S up r. . A second oPtion is to set a'packer below the ESP. Again, this practice doe'~thOt'sitisf~ the intent of 25.200(d) and is an unnecessary operation. -:'~'~ ~, ."--' ~:-~,' . '~ ~ ~,i~.. :;,;,~ ~,. :'.;, !i. Subject wells are high water cut (60 to 70%) and possibly could not flow uiiass~sted, at least not at economical rates; therefore its in the State's be~t'-intei-~g~ii5 hag~ the~ wel'is ' completed with some form of assisted lift. The operators have determined that ESP completions are e-ffe~tive ih :~'~' ~'"'" ~ ~ "' ........ : ........ "?" ' · these-high water vol~e'.,KU.'-p~.wells,, :" .: ::..' ~-: -' Your request for a general waiver for Kuparuk wellS can.only be accomplished by a conservation order; however, the Commission can issue specific approvals~" The' Commission hereby waives the ,r. equirement for a pack~er,¢~K.~uparuk River Unit wells 3B- 13, 3J=,7?and 3J;l:07::~ ~ ~'_:-/.: :~ !'~:~,.'.-/:~: ,r.:~:.'~ .: ,?:~ ;::-,.~;,.,-:~ _: -.',,d~ c.~, ,,.-;,-i-::~:; ,;:~::.-'~' i . :_ i _. _.' ~r · - : .: · ; '.. Sincerel~i.:~;~ ~;; :.:.:..i ':vv .'.-':{ ,';.;~".~:-'.:i;J'? ::..,'!: ::. ,'!.,,':'-' !".i, ~r, ,:- :.;._ . , ;:;' .::i.:-.--' -; . !L ;_i:. ::;:::·' ,.::,:!' ::. :;!}::,' -::.:-!'~-'.;"~ :i.:.,:~ . .!.'.;,.:, .;. '·, CCi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing _ Change approved program _ 2. Name of Operator Suspend__ Operation Shutdown __ Re-enter suspended well_ Repair well _ Plugging __ Time extension _ Stimulate __ Pull tubing X Variance _ Perforate _ ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1217' FNL, 1130' FEL, Sec 9, T12N, RgE, UM At effective depth 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service _ At total depth 1492' FNL, 1354' FEL, Sec. 9, T12N, RgE, UM 12. 13. Other X Install ESP 6. Datum elevation (DF or KB) RKB 80' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3J-07 9. Permit number 85-215 10. APl number 50-029-21438 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 14. 16. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7650' feet Plugs (measured) 6575' feet 7544' feet Junk (measured) 6491' feet None Length Size Cemented 80' 16 · 183 SxASII 3460' 9-5/8' 1005 sx ASIII 295 sx Class G 7603' 7" 435 sx Class G & 250 sx AS I measured 7322', 7325', 7328', 7332'-7350' true vertical 6315', 6318', Tubing (size, grade, and measured depth) ORIGINAL Measured depth True vertical depth 100' 100' 3490' 3422' 7633' 6561' RECEIVED 6320', 6323'-6337' OCT 3 0 1996 2-7/8", J-55, 7066' Packers and SSSV (type and measured depth) Camco HRP-1-SP packer @ 6993', Camco TRDP-1A-SSA SSSV @ 1790' Alaska Oil & Gas Cons. commission Anchorage Attachments Description summary of proposal ~ Contact William Isaacson at 263-4622 with any questions. Estimated date for commencing operation November 11, 1996 If proposal was verbally approved Name of approver Date Approved Detailed operation program__ BOP sketch -- 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify ~at t..h/ej foregoing is true and correct to the best of my knowledge. Signed Title Drill Site Development Supervisor FOR COMMISSION USE ONLY Conditions of approval: [~fy Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~O~ Date (' IApprovaJ No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Sign~u r),,3vJrl W .lnhnqtnr, ORIGINAL Commissioner SUBMIT IN~RII~LICATE Approved Copy Returned KRU 3J-07 GENERAL WORKOVER PRO CEDURE PRE-RIG WORK: 1. RIH with wireline. Pull valve from bottom GLM leaving an open pocket. other GLM's. 2. Set BPV in tubing. Install VR plug in annulus valve. Dummy off all GENERAL WORKOVER PRO CEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH standing back 2-7/8" tubing, lay down all jewelry. 5. PU DP and RIH with overshot. Latch on to 'slick stick' and pull retrievable packer free. POOH with packer and tail-pipe assembly. 6. PU bit and scraper and RIH cleaning out well to PBTD. Circulate hole clean. POOH standing back DP. . RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 8. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 10/29/96 Casing, 7", 26#, J-55 $J-07 Proposed Comic,etlon I. 2-7/8' x 7-1/16' 5M FMC Eccentric tubing hanger with EFT penetrator for ESP cable and port for downhole gauge conductor wire. 2-7/8' L-80 tubing pup on bottom. H. 2-7/8' J-55 EUE 8rd Mod tbg to surface with 2-7/8' x 1 ' McMurry 'FMHO' mandrels w/DY's, spaced out as follows: GLM# MD-RKB 2 4950' 3 3900' 4 2650' 5 100' NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM (except the one at 100') should be made up with a 6' pup below and a LaSalle cable protector placed on cplg below pup, LaSalle ESP Cable spaced out as per procedure Cable splice from fiat to round cable adjacent to pup above pump LaSalle Protectolizers at each tan of ESP assembly C Sand B Sand G. 2-7/8' X 1' McMurry 'FMHO' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). F. Pup jt, 2-7/8' x 6' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. E. 1 jt of 2-7/8' J-55 EUE 8rd Mod tubing with Baker 'Sentry' downhole pressure / temperature gauge clamped onto tubing. Conducter Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. Install one LaSalle cable protector on cplg between the two joints. D. 2-7/8' Camco 'D' landing nipple with 2.25' No-Go profile. Standing Valve to be set in landing nipple as completion is being made up. C. Centrilift Model 'GPMT' Series 513 Tandem Pump with integral intake and bolt on head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift Model 'GSTB' Tandem Seal Section. A. Centrilift Model 'KMEGI' Series 562 Motor with Motor Lead Extension Cable. Bottom of motor set at +/-7030' MD RKB. RECEIVED C Sand Peds 7128' - 7134' 7158' - 7165' B Sand Peds OCT 3 0 1998 ~aska Oil & Gas Cons. Commission. Anchor~.ge A Sar A Sand Peds 7279'-7300' 7322',7325',7328'(single shots) 7332'-7350' PBTD @ 7544' WSI 10/29/96 STATE OF N.ASKA ALASKA OIL AND GAS ~ERVATION ~k,~.~lON REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown , Alter casing 5. Type of Well: Development X Exploratory _ Stratigraphic _ 4. Location of well at surface 890' FSL, 564' FWL, SEC.3, T12N, R9E, UM At top of productive interval 1217' FNL, 1130' FEL, SEC.9, T12N, R9E, UM At effective depth 1443' FSL, 1313' FWL, $EC.9, T12N, R9E, UM At total depth 1492' FNL, 1354' FEL, SEC.9, T12N, R9E, UM 12. Present well condition summary Total Depth: Stimulate ~ Plugging Perforate X Repair well Other 6. Datum elevation (DF or KB) RKB 80 7. Unit or Property name Kuparuk River Unit 8. Well number 3J-07 9. Permit number/approval number 85-215 / 7-340 10. APl number 50-029-2143800 measured 7650' feet Plugs (measured) true vertical 6 5 7 5' feet feet 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7544' feet Junk (measured) 6491 ' feet 13. Ca~ Length Structural Conductor 80' Surface 3 4 5 5 Intermediate Production 7 6 3 3' Liner Perforation depth: measured 7322'-7328', true vertical 6315'-6320', Size 16" 9-5/8" 7" Cemented Measured depth True vertical depth 183 SX AS II 100' 100' 1005 SX AS III & 3490' 3422' 295 SX CLASS G 435 SX CLASS G & 7633' 6561 ' 25O SX AS I 7332'-7350' 6318', 6323'-6337' Tubing (size, grade, and measured depth) 2-7/8" J-55 TBG w/TAIL @ 7066' Packers and SSSV (type and measured depth) HRP-1-SP PKR @ 6993' AND TRDP-1A-SSA SSSV@ 1790' Stimulation or cement squeeze summary PERFORATE A3 AND C SAND Intervals treated (measured) 7128'-7134', 7158'-7165', 7279'-7300' Treatment description including volumes used and final pressure COMPLETED PERFORATING ,aG AND C SAND THROUGH TUBING. Oil & Ga.~ [;m;s. Gc,;'t,;m' p''' ' 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Re_oresentafive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classification as: Water Injector----- 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 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE STATE OF ALASKA ~ ALAS. . OIL AND GAS CONSERVATION COM,. jSION 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 J~ Other [] 11. Present well condition summary Total depth: measured true vertical Name of Operator ARCO Alaska, Inc. Address P.O. Box 100360, Anchora§e, Alaska 99510 Location of well at surface 890' FSL, 564 FWL, Sec. 3, T12N, R9E, UN At top of productive interval 1217' FNL, 1130' At effective depth 1443' FSL, 1313' At total depth 1492' FNL, 1354' 7650' 6575' FEL, Sec. 09, T12N, R9E, UM FWL, Sec. 09, T12N, R9E, UM FEL, Sec. 09, T12N, R9E, UM feet feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 80' 6. Unit or Property name Kuparuk River Unit feeble 7. Well number 3J-07 8. Permit number 85-215 9. APl number 50-- 029-2]438 10. 'P°°lKuparuk River Oil Pool Effective depth: measured 7544 ' feet true vertical 6491' feet Casing Length Structural Conductor 80' Surface 3455' Intermediate Production 7633' Liner Perforation depth: measured true vertical Size 16" 9-5/8" 11 183 Sx AS II 1005 Sx A.S. III 295 Sx Class "G" Junk (measured) !.. ~.~ · , ...... '.. ,~-.. Cemented M~'~' ~[~,.'~ .'.' ,'~ '- lrue Vortical Oopth 100' 100' 3490' 3422' 435 Sx Class "G" 7633' 6561' 250 Sx A.S. I 7322'-7328' 7325' 7332'-7350' 6315'-6320' depth)631, ' , Tubing (size, grade and measured 8' 6323 -6337 2-7/8", J-55, tbg w/tail @ 7066' MD Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 6993' and TRDP-1A-SSA SSSV (a 1790' 12.Attachments Description summary of proposal [] Detailed operations program [] Perforate C Sand with thru tubing perforating guns. 13. Estimated date for commencing operation May 21, 1987 BOP sketch [] 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 ¢,~//~_~~ ~, ~ Title Commission Use Only Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by IAppr°va' N°' the commission Date~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. Post Office Bo~-00360 Anchorage, All ~, 99510-0360 :':' Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitta1 #5805 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~. Final Prints' CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL 1-03-86 Run ~1 5600 12-21-85 Run #1 4800 10-22-85 Run #3 8490 10-09-85 Run #2 6800 12-15-85 ' Run #1 5496 10-30-85 Run #1 5350 10-17-85 Run #1 5925 12-17-85 Run #2 8595 10-05-85 Run #1 6624 10-19-85 Run #1 - 6300' - 7521' - 8830' - 7406' - 6870' - 8342' - 7726' - 9110' - 8367' 5350 - 7527' Alas~ Oil & Gas Cons. Commission . ~ . A~ch0rago NSK Drilling Vault(1 film) Recei pt Acknowl edged: Distribution' ~ ~-~tate .of Alaska(+ 1.~ ~_ BPAE Chevron Mobil SAPC Union .. ARCO Alask-", inc. is a Subm~diary o! AllanticRichliel~tCompan¥ STATE OF ALASKA ~ ALASK~ OIL AND GAS CONSERVATION COMM~ ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other ' 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchoraq'e~ AK 99510 4. Location of well at surface 890'FSL, 564'FWL, Sec.3, T12N, R9E, UN At top of productive interval 1217' FNL, 1130'FEL, Sec.9, T12N, R9E, UM At effective depth 1443'FNL, 1313'FEL, Sec.9, T12N, R9E, UM At total depth 1492'FNL, 1354'FEL, Sec.9, T12N, R9E, UM Perforate~j~ Pull tubing 5. Datum elevation (DF or KB) RKB 80 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3J -7 8. Approval number Permit #85-215 9. APl number 50-- 029-21438 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7650 true vertical 6575 Effective depth: measured true vertical Casing Conductor Surface Length 80' 3455' 7633' Production 7544 6491 feet feet feet feet Size Cemented Measured depth I 6" 1 83 sx AS I I 1 00 'MD 9-5/8" 1005 sx AS I I I & 3490'MD 295 sx Class G 7" 435 sx Class G & 7633'MD 250 sx AS I Plugs (measured) None Junk (measured) None True Vertical depth I 00 'TVD 3422 'TVD 6561 ' TVD Perforation depth: measured true vertical 7322'MD 7328'MD 7325 'MD 7332' - 7350 'MD 6315'TVD 6320'TVD 6318'TVD 6323' - 6337'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7066'MD Packers and SSSV (type-and measured depth) HRP-1-SP pkr @ 6993' and TRDP-1A-SSA SSSV ~ 1790' 12. Stimulation or cement squeeze summary N/A I nte rvals treated (measu red) 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 (Completion Well History) Daily Report of Well Operations j~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Associate Engineer (DAM) SW0/018 Date Submit in Duplicate Feet '~-'~ STATE OF ALASKA ~-- ~ ALASK~:,,,)IL AND GAS CONSERVATION CuMMISSION ~, WELL COMI LETION OR RECOM L, EI'ION REI ORI' &ND LOG 1. Status of Well Classification of Service Well OiL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 7. Permit Number 2. Name of Operator ARCO Alaska, Inc. 85-215 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21438 4. Location of well at surface 9. Unit or Lease Name 890' FSL, 564' FWL, Sec.3, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1217' FNL, 1130' FEL, Sec.9, T12N, R9E, UM 3J-7 At Total Depth 11. Field and Pool 1492' FNL, 1354' FEL, Sec.9, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 80' RKB ADL 25630 ALK 2563 12. Date Spudded10/04/85 13. Date T.D. R eachedl 0/10/85 ~.. :tz~" Date c0~5% Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/21/86'..~.~ ) N/A feet MS L 1 17. TotalDepth(MD+TVD) 18-PlugBackDepth(MD+TVD)%19~'Direct'i'0-~'alSurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7650'MD,6575'TVD 7544'MD,6491 'TVD YES I~X NO []I 1790 feet MD 1700' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/FDC/CNL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" 6Z.5# H-tO Surf 100' 24" 183 sx AS II 9-5/8" 36.0# J-55 Surf 3490' 12-1/4" 1005 sx AS Ill & 295 s. Class G 7" 26.0# J-55 Surf 7633' 8-1/2" 435 sx Class G & 250 s; AS I 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) 7322 ' 2-7/8" 7066' 6993 ' 7325' w/1 spf 7328' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7332' - 7350' w/4 spf See attached addendum for fracture data. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATEDiIN OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Anchorage . .-% Form 10-407 * NOTE: Drlg completed 10/11/85. Tubing run & well perf'd 4/9/864' WCl/013 Submit in duplicate ~, Rev. 7-1-80 CONTINUED ON REVERSE SIDE - 29. NAME -: Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7070' 7133" 7263' 7418' TRUE VERT. DEPTH 6117' 6166' 6269' 6390' 30. FORMATION TESTS Include interval tested, pressure data, ail fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS 'Addendum (dated 4/28/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a Complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground leVel (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 "-! AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting State coat center code Alaska no. 3J-7 District ~County or Parish Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25630 Auth. or W.O. no. ~Title AFE AK0146 I Completion Nordic 1 API 50-029-21438 Operator IA.R.~. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun D~e Complete 4/8/86 Date and depth as of 8:00 a.m. Old TD 4/o9/86 Released rig Complete record for each day reported 0600 hrs. I otal number of wells (active or inactive) on thle~ est center prior to plugging and bandonment of this well our I Prlor status If e W.O. 1530 hrs. I 7" @ ~ Diesel in tbg & ann Accept rig @ 1530 hrs, 4/8/86. ND master vlv, NU & tst BOPE. RU Schl & perf f/7332'-7350' @ 4 Spf, 90° phasing & 1 shot each @ 7322', 7325' & 7328', RD Schl. Rn 2-7/8", 6.5# EUE 8RD AB MOD compl & Ind. Set pkr, tst tbg, ann & SSSV. Shear out SBR. ND BOPE, NU & tst tree. Displ ann & tbg to diesel. RR @ 0600 hfs, 4/9/86. (Note: SSSV @ /'7~3~', HRP pkr @ 7~Q~', TT @ 7066') Classifications (o11, gas, etc.) Oil New TO PB Depth Date 4/9/86 IKInd of r g Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~ ,Date__ ITit,e - I Drilling Superintendent For form preparation and distrib~.~on. see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: _~/21/86 3J-7 FRACTURE STIMULATION SUMMARY Begin Frac Work At: Frac Kuparuk "A" sand perfs 7332'-7350' & 7322', 7325' & 7328' in 8 stages perf 4/15/86 procedure using YF GO II gelled diesel sysem (Musol, 100 mesh sand & 20/40 mesh sand. Press'd ann to 1500 psi w/diesel. Tst ins to 8600 psi; OK. Stage 1: Pmp'd 25 bbls diesel w/5% U-66 Musol @ 2.3 BPM, 2650 psi. Stage 2: 50 bbls gelled diesel spacer @ 2.6 BPM, 2610 psi. Stage 3: 40 bbls gelled diesel @ 19.8 BPM, 5750 psi. Stage 4: 19 bbls gelled diesel w/1 ppg 100 mesh @ 20.2 BPM, 5780 psi. Stage 5: 65 bbls gelled diesel pad @ 20.1BPM, 5570 psi. Stage 6: 22 bbls gelled diesel w/3 ppg 20/40 mesh @ 19.8 BPM, 4950 psi. Stage 7: 44 bbls gelled diesel w/8 ppg 20/40 mesh, 17.0 BPM, 6200 psi. Stage 8: 48 bbls gelled diesel flush @ 15.3 BPM, final press of 2550 psi. System underflushed by 2 bbls, per frac procedure. Pmp'd 750# 100 mesh w/1 ppg, 2394# 20/40 mesh w/3 ppg & 10,842# 20/40 mesh w/8 ppg in formation leaving 500# of 20/40 mesh sand in well. Load to recover 288 bbls of diesel. Job complete @ 1546 hrs, 4/21/86. Turn well over to CPF-3 Production. Drilling Supervisor Date -- I I 4 m I~- · 15 · I$ 12' '11 6' · 5 4' 2' · I RE~FRVF PIT r NOTES · COORDINATES ARE A.S.E,ZONE 4 2. SECTION LINE DISTANCES ARE TRUE. .3 HORIZONTAL POSITIONS BASED ON THE D.S.-3J NORTH- WEST ~ SOUTHWEST WINDOW CORNERS PER F R.B.&ASSOC. 4. VERTICAL POSITIONS BASED ON TBM 85-7-27-1 PER LHD I~ ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- RlXX--3060 rev. ,~ .. I HERE~ CERTIFY THATIAM PROPERLY REGISTERED AND LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF A~ASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECTAS OF JULY 30~ 1985. AS ~'"'.LT LOCATED IN PROTRACTED SEC. :5, TI2 N, R9E, U. MER. 1- ¥= 6,002,422.54 X= 519,544.60 563' FWL, 740' ESL, 2-Y= 6,002,447.64 X= 519,544.66 563' FWL, 765' FSL, 3- Y= 6,002,472.5g X= 519,544.60 563' FWL, 790' 4- Y= 6,002,497.59 X= '519,544.63 564 FWL, 815' 5- Y- 6,002,522.57 X- 519,544.65 564 FWL, 840' 6- Y= 6,002,547.61 X= 519,544.65 564 FWL, 865' 7- Y= 6,002,572.61 X= 519,544.67 564 FWL, 890' FSL, 8-¥= 6,002,597.57 X= 519,544.68 564 FWL, 915 FSL, 9-Y: 6,002,672.63 X= 519,544.74 564 FWL, 990' FSL, 10- Y= 6,002,697.65 X= 519,544.74 565 ~L, 1015' 11- Y: 6,012,722.64 X= 519.544.73 13- Y= 6,0' ~,772.67 X= 5.19.-~4.78 565 F~,., 1090' 14- Y= 6,0~ :*,797.59 X= 519.:.44.78 565 F .... I115' 565 FWL, 1140' 16- Y= 6,002,847.58 X: 519.54A.80 ,4 ~ 565 FmL, II II CONDUCTORS 1-16 . LAT, 70025 04.020" LONG. 149°50'26.870" OG, 41.3, PAD 45.3 LAI. 70o25 04.266" LONG. I~9°50 26.866" 0G.41.0, PAD 45.6 LAT. 70°25 04.512" LONG. 149°50 26.866" FSL, OG. 40.9, PAD LAI. 70o25 04.758" LONG. 1~9°50 26.863' FSL, OG. ~0.8, PAD 45.5 LAl. 70o25 05.003" LONG. I~9°50 26.861" FSL, OG. 40.9 PAD LAI. 70°25 05.250" LONG. 149o50 26.859" FSL, OG. 41.0, PAD 45.4 LAI. 70°25 05.495" LONG. 149o50 26.856a OG. 41.l, PAD. 15.3 LAT. 70025 05.741" LONG. 149050 25.854" OG. 41.2, PAD. 45.3 LAT. 70o25 06.479" LONG. 149050 OG. 41.0, PAD 45.5 LAT. 70°25 06.725" LONG. 149050 26.845" FSL, OG. 41.0 PAD LAT. 70025 06.971" LONG. 149050 26.843" 565 F,L, 1040" FSL, OG. 40.7 PAD 45.3 12- Y= 6,002,7~7.62 LAT. 70025 07.217" X= 519,5~4.78 LONG. 149o50 26.840" 565 FW_, 1065'FSL, OG. 40.7, PAD 45.5 LAT. 70°25 07.463" LONG. 149°50 26.837" FSL, OG. 40.4, PAD 45.4 LAT. 70o25'07.708" LONG.149°50~26.836" FSL, OG. 40.3, PAD 45.5 LAT. 70°25'07.95~" LONG. 149°50'26.833'' FSL, OG. 40.1, PAD 45.0 LAT. 70o25'08.200" LONG. 149°50'26.831" 1165'FSL, OG. 40.D, PAD. 45.4 · ~, ARCO Alaskg, Inc. ~ ~' Kupo'ruk PrOj~cf CONDUCTOR AS- BUILT .. LOCATIONS ,, , Date:Aug.9,1985 JScal$: I : 500 ' ' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3J-7 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well History. When I do, I will forward a copy to you. Also, tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L122 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ r~. ALASKAL AND GAS CONSERVATION CO 'ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I1, Classification of Service Well Status of Well ' [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-215 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21438 4. Location of well at surface 9. Unit or Lease Name 890' FSL, 564' FWL, Sec.3, T12N, R9E, UM ~ Kuparuk River Unit At Top Producing IntervalI--~'~"~'~]! VEriFIED I lO. Well Number At Total Depth/ ~ 1 1. Field and Pool 1492' FNL, 1354' FEL, See.9, T12N, RgE, UM ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 80' RKBI ADL 25630 ALK 2563 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/04/85 10/10/85 10/11/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7650'MD,6575'TVD 7544'MD,6491 'TVD YES ~ NO [] N/A feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/FDC/CNL, 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 100' 24" 183 sx AS II 9-5/8" 36.0# J-55 Surf 3490' 12-1/4" 1005 sx AS III & 295 s~ Class G 7" 26.0# J-55 Surf 7633' 8-1/2" 435 sx Class G & 250 s~ AS I 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 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure !CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. :24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . .~ ~ ~ ~:, .~ ' Form 10-407 TEMP3/WC15 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29 .... ~: : . .:. : -. . . - . . .: : :. , -.' _ :-~ ~- ,. ...; ,.:,.. '.: . .. :' ' ' ' ;"~ :- GEoLOGIc MARKERS : - FORMA¥1ON TESTS" NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7070' 6i17' N/A Base Kuparuk C 7133' 6166' Top Kuparuk A 7263' 6269' Base Kuparuk A 7418' 6390' I i I 31. LIST OF ATTACHMENTS Gyros. copic Survey (2 copies) 32. } hereby certify that the fore§oin§ is true and correct to the best of my knowledge Signed,/~~~/ ~ Title Associate Engineer Date /2--/J-~>~' 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 i~ertinent to such interval. Item 25: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3J-7 Dear Mr. Chatterton' Enclosed is a copy of the 3J-7 Well Hi story to include wi th the Well Completion Report, dated 12/11/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L103 Enclosure cc' 3J-7 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company,~,"~' Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Repert'.' 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 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25630 Title Drill Istate Field Kuparuk River Auth, or W.O. no, AFE AK0146 Alaska IWell no. 3J-7 Parker 191 API 50-029-21438 Operator ARCO Alaska, Inc. Spudded 10/4/85 0330 hrs. Date and depth as of 8:00 a.m. t0/04/85 10/05/85 thru 10/07/85 Complete record for each day reported 16" @ 100' 382', (282'), Drlg Wt. 9.7· PV 18, YP 26, PH 10, WL 9, Sol 5 Accept rig @ 2330 hfs, 10/3/85. NU diverter sys. 0330 hfs, 10/4/85. Drl 12¼" surf hole to 382'. IARCO W.I. Prior status if a W.O. Spud well @ , .6°, N39W, 499.99 TVD, -0.48VS, 2.03N, 1.65W · .6°, S18W, 1499.96 TVD, -1.11VS, 5.74N, 5.02W , 4.7°, S73.6W, 2298.72 TVD, 5.39VS, 4.05S, 3.55W , 15.7°, S40.SW, 2783.82 TVD, 89.19VS, 50.51S, 78.23W , 28.5°, S45.5W, 3291.52 TVD, 294.52VS, 197.50S, 222.30W , 34.6°, S46.6W, 3576.46 TVD, 471.38VS, 320.44S, 350.72W · 38.4°, S46.9W, 3770.96 TVD, 614.44VS, 419.05S, 455.55W lO/O8/85 10/09/85 9-5/8" @ 3490' 6121', (1890'), Drlg Wt. 9.5, PV 10, YP 5, PH 10, WL 7.6, Sol 6 Drl & surv 8½" hole to 6121'. 4249', 45.8°, S38.3W, 4014.90 TVD, 834.49 VS, 581.15S, 604.61W 4709', 46.4°, S37.6W, 4333.86 TVD, 1165.63 VS, 842.52S, 808.45W 5174', 42.8°, S36.3W, 4664.95 TVD, 1491.52 VS, 1103.45S, 1004.72W 5765', 41.7°, S33.9W,-5102.42 TVD, 1887.16 VS, 1428.56S, 1233.21W 9-5/8" @ 3490' 7456', (1335'), Drlg Wt. 10.2, PV 16, YP 10, PH 9.5, WL 7.2, Sol 9 Drl & surv 8½" hole to 6810', POOH lk'g f/wshout, found in 57th std "E" DP, LD. PU locked drlg assy, TIH, drl to 7456'. 6079', 41.0°, S35.3W, 5338.14 TVD, 2093.53 VS, 1599.32S, 1351.01W 6737', 38.8°, S32.3W, 5843.34 TVD, 2512.66 VS, 1947.45S, 1588.69W The above is correct For form oeoa 'o and ~istribution. Drilling Superintendent 500' 1500' 2299' 2793' 3342' 3678' 3920' 56.24% 9-5/8" @ 3490' 4231', (3859'), Turbo drlg Wt. 9.1, PV 7, YP 10, PH 10, WL 8, Sol 4 Drl, DD & surv 12¼" hole to 3510', short trip to 1500', CBU, POOH. RU & rn 87 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3490', FC @ 3409'. Cmt w/ 1005 sx AS III, followed by 295 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, rtns good, bump plug. CIP @ 0345 hfs, 10/6/85. ND diverter sys. NU & tst BOPE. TIH w/8½" bit to FC, tst csg to 1500 psi; OK. DO FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 3957', turbo drl to 4231'. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" 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 indefinile or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data Jn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field ICounty or Parish Lease or Unit Title Kuparuk River Auth. or W.O. no. AFE AK0146 Parker 191 North Slope Borough ADL 25630 Accounting cost center code State Alaska JWell no. 3J-7 Drill API 50-029-21438 Operator cost center prior to plugging and 56.24% abandonment of this well IDate Hour Prior status 10/4/85 0330 hrs. ARco Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig if a W.O. 10/10/85 10/11/85 10/11/85 Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 9-5/8" @ 3490' 7650', (194'), LD 5" DP Wt. 10.2, PV 17, YP 8, PH 9, WL 6.4, Sol 9 Drl 8½" hole to 7581', 44 std short trip, C&C, TOH f/logs. RU Schl, log DIL/SFL/SP/GR/CAL/FDC/CNL f/7572' MD - 3490'. Drl to 7650', C&C, TOH f/7" csg. 7581', 37¼°, S40-1/4W, 6508.19, 3031.19 VS, 2366.S9, 1896.30W 7" @ 7633' 7650' TD, 7544' PBTD, RR Wt. 10.2, PV 17, YP 7, PH 9, WL 6.4, Sol 9 LD 5" DP. Chg rams to 7". RU & rn 175 its, 26#, J-55 HF-ERW BTC csg w/FS @ 7633'. Did not recip. Cmt w/435 sx C1 "G" w/3% KC1, .9% D-27, .3% D-13 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 2300 hrs, 10/10/85. ND BOPE, cut 7", NU & tst tbg head. Winterize w/50 bbls diesel. RR @ 0400 hrs, 10/11/85. New TD Date I PB Depth 7650' TD IKind of rig I 0400 hrs. Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7544' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length ~Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date [ Title For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent SUB. SURFACE DIRECTIONAL 8URVEY I~UIDANCE L~ONTINUOU$ ~.~OOL Company Well Name Fleld/I.e~&tlon ARCO ALASKA INCORPORATED 3J-7 (890' FSL, 564' ~W-L, S3, T12N, RgE, UM)_ ., ~:UP. ARIII<. NORTH SI.OPE. AT,ASWA J_o,l~ ,Flefer~nce No. 70987 Loaa~I B~ LESNIE 20-NOVEMBER-85 Com~ut~l BY; BOLAM Anus,or,g,, GCT DZ~:CTION&L SURVEY CUSTCMEP LISTING aRC3 aL.~SK~, INC. 3J-7 KUP~&RUK N3RT~ SLOPE,&LASKA METHODS OF COM~UT~TIGN TOOL LOC&TI3N: INTERPOLATION: VERTICAL SECTION: SURVEY DATE: 19 OCT 95 , ENGINEER: LESNIE 'T~NGENTI~L- 2VER&GEC OEVI&TI3N ~NO AZIMUTH LINEAR HORIZ. DIST. PROJ~CT~O ONT~ ~ TARGET AZIMUTH ']F S!2UTH 22 ~q IN WE ST 4RCO ALASKA, INC. 3J-? KUPARUK NORTH SLOPE,ALASK~ COMPUTATION INTE~POL4TEO V4LU~$ ~OR TRUE SUB-SEA qEASUREO VERTICAL VERTICAL DEPTH DEPTH DEmTH 0.00 0.00 -80.00 100.00 100,00 20.00 200.00 200.00 120.00 300.00 300.00 220.00 ~!0.00 400.00 320.00 0.00 300.00 ,20.00 0,00 600.00 520.00 700.00 700.00 620.00 800.00 800.00 720.00 900.00 900,00 820.00 1000.00 1000.00 920,00 1100.00 1100.00 1020.03 1200.00 1200.00 1120.00 1300,00 1299,99 1219.99 1400.00 1399.99 1319.99 1500,00 1499.98 1419.98 1600.00 1599.97 1519.97 1700.00 1699.96 1619.96 1800,00 1799.96 1719,9.5 1900.00 1899.95 1819.95 2000.00 1999.95 1919.95 2100.00 2099.95 2019,95 2 .00 2498.25 2418.25 2~"00. O0 Z:596.60 2516.60 2700.00 2.694,41 2614.41 2800,00 279~,- 29 2711.29 2900.00 2887,'07 2807.07 3100,00 30~',30 2995,30 3200.00 ~161,09 3087.09 3300,00 3257,04 3177.04 3400,00 3345,18 3265.18 3500,00 34'31,09 3351,09 3600.00 3515,13 3435.13 3700,00 3597.83 3517,83 3800.00 3678.92 3598.92 3900,00 3758.20 3678.20 COURSE DEVIATION 4ZIMUTH OEG MIN OEG MIN 0 0 N 0 0 E 0 7 $ 69 33 W 0 8 S 65 8 W 0 10 S 53 42 W 0 8 S 6 58 W 0 8 S 1 20 W 0 ,-~ S 7 9 W 0 7 S 0 59 E 0 6 S 17 48 ~ 3 6 S 21 12 E 0 6 S 28 55 E 0 5 S 21 24 E 0 15 S 20 54 W 0 23 S 20 40 W 0 45 S 23 13 W 0 48 S 9 59 W 0 40 S 0 20 W 0 33 S 9 37 '~ 0 41 ~ 37 35 - 034 1 0 25 S 54 38 =. 0 21 S 59 34 0 42 S 49 2 W 4 14 S 74 21 W 7 1 S 72 9 37 .S 70 50 W 11 9 S 57 20 W 13 13 S 46 54 W 15 kB S 40 40 W 17 41 S 42 58 W 19 39 S 43 32 W 22 0 S 44 37 W ~4 3c; ~ 45 43 W 2 ? 5 S 46 7 ~ 2'9 26 S 46 33 W 31 56 S 46 35 W 33 ~9 S 46 21 W ~4 58 S ~6 33 W 36 44 S 46 41 W 3:~ 14 S 40 57 W DATE: EVEN VERTIC SECTI FEE 21-NOV-85 . O. O, O, O, 1, 1, 1, 1. . 1. 2, 2. 3. 4. 6. 6. 7. 7. 100 FEET AL OOGL ON ,SEVE T OEG/ O0 16 35 61 89 OS 29 46 61 70 85 69 71 98 03 80 26 32 7.29 7.20 7.30 10.91 19.40 31.62 4~.16 68.55 93.28 121.96 153,95 189.31 228.82 272.29 319.26 370.10 423.9~ 479.88 538 598.60 DF EG RITY 100 ,00 .17 .lO .14 .07 .05 .10 .05 .0~ .02 .07 .38 .17 .33 .18 .09 .31 .31 .18 .13 .22 ,83 · 8,5 .07 .79 · 59 .80 .93 .39 .02 .80 .13 .27 .47 ,78 .10 D~TE OF SURV=Y: 19 OCT 8: KELLY BUSHING ELEV.~TiON: ENGINEER: L~SNIE 80.00 MEASURED DEPTH ~ECTANGUL~R C~ORDINATES H~RIZ. NORTW/SDUTH EaST/W~ST DIST, FEET F~ET ~E~T 0.00 N O.O0 a 0,00 0.08 S 0.15 W 0.17 0.15 S 0.37 W 0.,~0 0.2:~ S 0.52 W 0.58 0.51 S 0.76 W 0.92 0.75 S 0.77 W 1.09 1.02 S O. 30 W 1.29 1.25 S 0.~2 W 1.49 1.45 S 0.77 W 1.54 1.53 S 0.71 W 1.78 1.80 S 0.53 W 1.90 S 1.98 S 0.5~, W 2.05 S 2.21 S 0.55 W 2.20 S 2.83 S 0.33 W 2.95 S 3.76 S 1,30 W 3.)9 S 5,09 S 1.70 W 5.37 S 6.36 S 1,S2 W 5.62 S 7.45 S !. ]'Z+ W 7.65 S ~.43 S 1,28 W 3.53 S 9.22 S 0.45 W 9.23 S 9.71 S 0.17 10.08 S O, 74 10.44 S 1,01 11.78 S 2.99 14.91 S 12.41 19.09 S 26.37 27.04 S' 42.55 40.10 S 58.67 W 58.03 S 75,75 W 7'9.44 S 94~86 W 102.75 S 116,83 W 128.23 S 141.44 W 156.13 S 169,61 W 186.52 S 201.00 w 219.14 S 235,12~ W 25~.19 S 272.40 W 291.55 S 311.55 W 330.2~ S 352.39 W 370.50 S 394.90 w 412.1~ S 439.37 w 9.71 S I0.10 S lO.&9 S 12.15 S 1).40 S 82.~5 S 50,~2 S 71.07 S 95.43 S 123.73 S J:O.~RTURE &ZIMUTH 9:G MIN 0 0 E 60 19 W 68 32 W 55 46 W 5,5 6 W ~+5 12 W 37 56 W 33 17 W 23 35 W 19 22 W 15 9 W 13 5~ W 1617 W 19 7 W 1,~ 29 W 15 57 W 13 10 W ,3 38 W 2 52 W 4105 530 ~ 14 13 W 3~ 46 W 5~ 5 W 37 33 W 52 32 W 50 3 w 155.59 S 43 lg0.')2 S 47 ~9 W 230.54 S ~7 21 W 274.21 S ~7 $ W 321.42 S 47 1 W 372.58 S 46 53 W 425.77 S 46 54 W ~82.98 S 46 54!.49 S 46 49 602.~4 S 45 ARCO ALASKA, INC. 3J-7 KUPARUK NORTH SLOPE,4LASKA COMPUTATION DATE: 21-N0V-95 INTERPOLATED VALUES FOR EVEN 100 FEET OF TRU= SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4000.00 3536.35 3756.35 4100.00 3914.03 3834.03 4200.00 3989.25 3909.25 4300.00 4059.51 3979.51 4400.00 4128.91 4048.91 { 30.00 4197.98 4117.98 ~00.00 4265.93 4186.93 4700.00 4335.89 4255.59 4800.00 4404.~8 4324.9~ 4900.00 4476.22 4396.22 5000.00 4548.9'9 4468.89 5100.00 4622.29 4542.29 5200.00 4695.76 4615.76 5300.00 4769.21 46~9.21 5400.00 4842.85 4762.85 5500.00 4916.87 4836.87 5600.00 4991.05 4911.05 5700.00 5065.50 4985.50 5800.00 5140.23 5060.23 5900.00 5214.84 5134.84 COURSE VERTIC&L DOGLEG 95ViATION AZIMUTH SECTION SEVERITY DEG MIN DES MIN FSET DEG/IO0 33 47 S 46 41W 560.58 0.41 39 29 S 46 11 W 723.19 1.56 43 ~6 S 42 36 W 788.80 6.79 ~5 53 S 40 12 W 859.94 0.48 46 11 S 39 55 W 931.94 0.49 46 22 S 39 2'9 W 1004.25 0.54 46 25 S 38 39 W 1076.66 0.57 46 24 S 37 55 W 1149.02 0.59 &5 3'9 S 37 8 W 1221.34 3.21 43 58 S 35 50 W 1291.22 0.54 42 52 S 36 46 W 1359.74 0.40 42 ~4 S 36 17 W 1427.50 0.47 42 42 S ~5 46 W 1495.15 0.29 42 41 S 35 1~ W 1562.77 0.93 42 2,6 S 34 47 W 1630.14 0.72 42 10 S 3& 20 W 15'97.03 0.60 41 59 S 33 47 W 1753.68 0.48 41 45 S 33 16 W i829.97 0.47 41 40 S 32 55 W 1!395.38 0.30 41 38 S 33 1 W 1961.89 1.20 41 2 40 58 40 35 40 11 40 4 39 48 39 14 38 47 38 37 37 58 37 26 37 4,5 38 3 38 1~ 38 1 37 7 37 7 37 7 S 35 29 W 2027.44 0.88 S.,~4 58 W 2092.57 0.40 S 34 7 W 2157.92 0.78 S 33 24 W 2222.24 0.52 S 32 50 ~4 2286.17 0.50 S 32 4 W 2349.34 0.92 S 32 30 W 2412.82 1.95 $ 33 11 W' 2475.17 0.31 S 32 48 W 253'7.25 1.15 S 35 38 W 25~8.75 1.84 S 37 46 W 2659.76 1.05 S 38 46 W 2720.64 0.50 S 38 39 W 2782 . 15 O. 02 S 38 40 W £843.~2 0.55 $ 38 39 W 2905.74 1.21 S 40 1 W 2966.65 ~.00 S 40 1 W 3027.00 0.00 S 40 1 W 3057.18 0.00 6000.00 5290.03 5210.03 6100.00 5365.44 5285.44 6200.00 5441.10 5361.10 6300.00 5517.30 5437.30 6..~qO O0 5593.77 5513.77 0~00 5670.38 5590.33 ~00.00 5747~48 5667.48 6700.00 5825.27 5745.27 6800.00 5903.25 5823.25 6900.00 ~981.80 5901.80 ooo.oo 7100.00 '61'~0%24 6060.24 7200.00 62'I9.07 6139.07 7300.00 6297.7'7 5217.77 7400.00 6376.27 6296.27 7500.00 6455.~7 6375.57 7600.00 6535.30 6455.30 7650.00 6575.17 6495.17 P~GE DaTE OF SURVEY: 19 OCT 55 KELLY BUSHING ELEV&TION: ENGINEER: LESNIE -2 30. O0 FT MEaSUREC: DEPTH RECTANGULAR COORDINATES H,gRIZ. NC~T.e/SOUTH 5~ST/WEST DIST. =5ET FFET =E~T 454.81 S 484.90 W 564.82 498.20 S 530.54 W 727.79 ;44.77 S 577.05 W 793.58 59~.60 S 623.55 W 864.3~ 5~3.70 S 669.92 W 935.01 70'9.31 S 716.15 W 10D7.96 765.53 S 761.81W 822.36 .S 806.57 W 1151.95 879.70 S ~50.37 W 1223.~7 936.16. S 892.34 W 1293.32 991.56 S 932.97 W 1351.48 1045.07 S 973.~8 ~ 142~.95 1100.95 S 1013.36 W 1496.32 115,5.20 S 1052.77 W 1563.69 1211.5'~ S 1091.61 W 1630.32 1266.96 S 1129.76 W 169T.5i 1322.52 S 1167.30 W 1763.99 1375.17 S 1204.18 W 1830.14 1433.85 S 12~0.45 W 1695.96 1489.79 S 1276.56 W 1961.91 1544.21 S 1313.75 W 2027.44 1~97.81 S 1351.71W 2092.~7 1651.66 S 1389.81 W 2157.95 1705.49 $ 1424.78 W 2222.32 1759.45 S 1460.01 W 22~6.33 1813.66 $ 1494.55 W 2350.11 1~67.74 S 1528.16 W 2413.24 1920.31 $ 1562.58 W 2475.73 1972.83 S 1596.59 W 2537.98 2024.14 S 1631.24 W 259'9.63 2073.09 S ,1667.85 W 2660.72 2120.80 S 1705.73 W 272!.64 2158.81 S 1'744.22 W 2783.17 2215.92 S 1782.84 W 2844.87 2265.40 S 1821.42 W 2906.82 2312.48 S 1860.07 W 2967.73 2358.70 S 1898.89 W 3028.07 2381.80 S 1918.29 W 3058.24 3EPaRTURE ~ZiMUTH 95G MiN S 46 50 W S 4,5 43 W S 46 3~ W S 45 10 W S 45 42 W S 45 16 W $ 44 51 w S 44 26 W S 44 2 W S 43 37 W S 43 15 W S 42 56 W S 42 37 W S 42 19 W S 42 1 W S ~+1 43 W S ~1 25 W S 41 S 40 51W S 40 35 W 5 40 23 S 40 13 W 540 3 W S 3'9 52 53941 S 39 29 53'9 17 W S 39 8 S 38 58 S 38 51 S 38 49 w S 38 48 W S 38 48 W S 3~ 48 W S 3'3 4'7 W S 38 48 W S 33 50 W S 3~ 50 W ARCO ALASKA, INC. 3J-7 KUPARUK NORTH SLOPE,ALASK~ TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 1000.00 .2000.00 1999.95 3000.00 2981.79 .~O0.O0 3836.35 )0.00 4548.8,9 6uO0.O0 5290.03 ?000.00 6050.93 7650.00 6575.17 COMPUTATION DATE: 21-NOV-S5 INTERPOLAT:D VALUES FOR EVEN 1000 SUB-SEA CgU~SE VERTICAL V~RTICAL DEVIaTiON AZIMUTH SECTION DEPTH DEG MIN DEG MIN F:ET -80.00 920.00 1919.95 2901.79 3756.35 5210.03 5980.93 6495.17 0 0 N 0 0 : 0.00 o ~ s 2a 55 ~ 1.7~ 0 25 S 54 38 E 7.29 19 39 S 43 32 W 153.93 33 47 S 46 41 W 660.58 42 52 S 36 46 W 1359.74 41 2 S 35 29 W 2027.44 37 26 $ 37 45 W 2659.76 37 7 S 40 1 W 3057.13 FEET PaGE DATe 3~ SURVEY: 1'~ OCT 35 KELLY 6USHI~G 5LEV~T!ON: ENSIN:~R: L=SNI~ 3 30.00 ;T MEASUR~:~ D~PT_ DOGLEG Rr-CTANGULaR COORDI~4TES W3RIZ. 3::~ARTURE SEVERITY NOqTH/SgUT~ EAST/WEST DIST. AZI~UTH DEG/IO0 ~EET ?r-T ==_ET ]~G 0.00 0.02 0.13 1.93 0.41 O.aO O. ~:~ 1.05 0.00 0.0 1.8 9.7 102.7 454. ? 991.5 1344.Z 2073.0 0.00 E O.O0 0.53 w 1. ~S 0.17 E 9.71 116.33 W 155.5~ ~8~.90 W ..66,4. ~ 932.~7 W 1361.4B 1313.~5 ~ 2027.a4 16,57.~5 ~ 266~.'72 B.29 W 305'.~.24 t,4 O O ~ S 19 22 W S 1 1 k S ~8 40 W S 43 50 W S 43 15 W S 40 23 W S 3~ 50 W COMPUTATION DATE: 21-NOV-35 ~, ARCO ALASKA, INC. 3J-7 KUPARUK NORTH SLOPE,ALASKA PAgE ;OAT~: OF SU~¥=¥: 1:~ ']CT KFLLY SUShi.NS :-L'~v"-~TI?N: ~NSINEgP: LESNZ': iNTERPOLATED VALUES FOR EVEN 100 FEET OF SU~-SE~ DEPT~ COURSE VEqTICAL D3GL DEVIATION AZIMUTH SECTION S=VE DiG .MiN D;S MIN FEET DEG/ TRUE SUB-SE~ MEASURED VERTICAL VERTiCaL DEPTH DEmTH DEPTH E G R E CT 2 NGU L a R ~ITY NO~TH/S]UTH 100 FE~.T 0.00 0.00 -80.00 80.00 80.00 0.00 180.00 180.00 100.00 280.00 280.00 200.00 ~0.00 3~0.00 300.00 0.00 430.00 400.00 ,. ~0.00 5~0.00 500.00 680.00 680.00 500.00 780.00 780.00 700.00 880.00 880.00 800.00 0 0 N 0 0 E 0.00 O.OC 0.00 N 0 7 S 60 53 W 0.12 0.11 0.06 S 0 B S 66 3 W 0.31 O.O~ C.13 S 0 9 S 60 2 W 0.56 0.05 0.25 S O 9 S 15 57 W 0.84 0.17 0.46 S 0 8 S 1 9 E 1.04 0.0: 0.72 S 0 8 S 7 20 W 1.25 0.02 0.97 S 0 7 S 4 25 W 1.45 0.05 1.20 S 0 6 S 17 Z1 : 1.58 0.03 1.41 S 0 6 S 19 26 ~ 1.68 0.06 1.59 S 0.04 1.75 S O. 11 I .94 S 0.34 2.14 S O. 29 2.69 S 0.49 3.53 S O.ZO 4.81 S '0.22 5.12 S 0.21 7.25 S 0.24 8.24 S 0.24 9.09 S 980.00 9~0.00 900.00 1080.00 1080.00 1000.00 1180.00 1180.00 1100.00 1280.01 1280.00 1200.00 1380.01 1380.00 1300.00 1480.02 1480.00 1400.00 1580.03 1580.00 1500.00 1680.03 1680.00 1500.00 1780.04 1790.00 1700.00 1880.05 1880.00 1800.00 0 6 S 28 4 E 1.76 0 6 S 23 57 E 0 11 S .15 5 W 1.97 0 25 S 24 52 W 2.54 0 ~O S 25 50 W 3.47 0 49 $ 12 18 W 4.73 0 42 S 1 15 W 5.84 0 34 S 6 13 E 6.67 0 39 S 33 33 :. 7.20 0 3,6 S 51 30 5 7.33 0 24 S 52 50 E 7.30 0 22 S 58 3,3 : 7.22 O 21 S 4 5 ~ 7.14 3 36 S 73 40 W 9.78 6 31 S 70 29 W 17.42 ':~ 16 S 72 33 W 29.02 10 56 S 59 42 W 45.06 12 50 S 47 54 W 65.27 15 12 S 41 11 W 90.21 17 32 S 42 51 W 1'19.73 19 36 S 43 31 W 153.31 ZZ 9 S 44 41 W 191.24 25 0 S 45 48 W 234.81 27' 36 S 46 12 W 284.12 30 32 S -~,6 45 W 33'9.28 32 57 S 46 25 W 401.03 34 138 S 46 31 W 467.5,5 36 45 S 46 41 ~ 538.~5 38 29 S 46 57 W 615.76 39 2 S 46 24 W 695,56 0.10 9.63 S 0.10 10.01 S 2.84 10.31 S 3.48 1!.,41 S 2.63 14.17 S 2.53 18.14 S 3. '31 25.32 S 3.03 37.87 S 2.75 55.72 S 1.80 77.80 1 .. '~ 1 1102.28 $ 2.82 129.6'1 $ 2.43 160.34 S 2.03 194.76 S 2.65 232.95 $ 1.34 275.66 S 1.57 321.76 1.77 37!.06 0.74 423.96 S 0.80 479.00 S 1980.05 1980.00 1900.00 2080.05 2080.00 2000.00 2180.06 2180.00 2100.00 2280.12 2280.00 2200.00 L ~qO.53 2380.00 2300.00 1.49 2480.00 2400.00 d3.08 2580.00 2500.00 2685.22 2680.00 2600.00 2788.30 2780.00 2700.00 2892.59 2880-00 2800.00 ' oo.oo 3105.09 30"8,0~ 3000.00 3214.25 3~80~:00 3100.00 3325.86 3280"00 3200.00 3440.23 3380.00 3300,00 3557.99 3480.00 3400.00 3678.29 3580.00 3500.00 3801.35 3680.00 3600.00 3927.81 3780.00 3700.00 4056.06 3880.00 3800.00 g,] .00 CS'DP DINA T EAST/WEST 0 · O0 0.11 0.33 O.. ~7 0.75 0.77 0.79 0.,32 0.79 0.72 2.65 W 0.55 W 0.52 W 0.75 W !.ZO W 1.65 W 1.82 W 1.77 W 1.42 W 0.62 W 0.06 0.62 1.12 1.68 10.24 23.47 39.79 56.24 73.75 93..3.3 1',16.39 1"42-'81 173.92 209-57 249.80 294.99 343.40 395.49 452.00 510.46 HDqlZ. DIST. AZI?,IUT~ 0.00 N 0 0 E · ~ ~ ~ 5 ~ 1 W 0.33 S 55 59 W 0.62 S ,S~6 32 W ~5 .~ 47 5 W 1.25 S B9 7 W 1.46 S 34 tO ~ 1.52 S 2 '9 7 W 1.75 S Z4 25 W !.88 S 20 15 W 2.02 S 15 48 W 2.20 S 13 47 W 2.79 S 15 45 W 3.73 S 18 47 w 5.09 S lB 53 w 6.3'9 S 16 31 W 7.47 S 13 40 W 6.35 S 9 45 W 9.11 S 3 55 W 9 · 63 10.03 10.37 11.53 1'7.4~ 29.66 47.17 67.50 92.43 121.51 154.94 192.B5 236.56 286.10 341.57 403.74 470.59 ~ 4 2.30 519 · '7 1 700.90 4RCO ALASKA, INC. 3J-7 KUPARUK NORTH SLOPE,AL~SK4 COMPUTATION TRUE MEASURED VERTICAL DEPTH DEPTH 4187.13 3980.00 4329.47 4080.00 4473.94 4180.00 4518.96 4280.00 4~4.08 4380.00 (O 5 25 4,,80.00 . ~,2.40 4580.00 5178-55 4680.00 5314.6,3 4780.00 5,*50.26 4,'380.00 5585.12 4980.00 5719.42 5080.00 5853.28 5180.00 5986.72 5280.00 6119.29 5380.00 6251.14 5480.00 5382.00 5380.00 6512.51 5680.00 6641.88 5780.00 o o.oo 0.64 6480.00 75.50. O0 65'75,17 DATE: 21-NOV-S3 PA 3 E ~aTE O: SURVEY: 19 3CT 85 KELLY BUSHING ELEVATION: ENGINEER: L~SNIE INTERPOLATED VALUES FOR EVEN 100 FEET OF SU3-SEA DEPTH COURSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY OEG MIN D=G MIN FE=T DES/lO0 43 5 S 43 21 W 779.86 7.78 46 0 S 40 .B W 8~1.12 0.35 46 21 S ~9 38 W 985.39 0.35 46 25 S 38 31 N 1090.39 0.54 a5 22 S 37 32 W 1195.46 1.22 43 55 S 35 51 W 1294.~5 0.78 42 46 S 36 ~0 W 1388.50 0.~0 42 42 S 35 51 W 1480.65 0.26 42 38 S 35 10 W 1572.56 0.98 42 14 S 34 33 W 1663.81 O.~l 42 1 S 33 51 W 1733.79 0.49 41 41 S 33 10 W 1842.79 0.30 41 45 S 32 50 W 1931.04 0.40 41 2 S 35 17 W 201~.78 1.52 40 57 $ 34 49 W 2105.47 0.66 40 21 $ 33 43 W 2190.90 0.73 40 4 S 32 5'7 W 2274.68 0.37 39 44 S 31 55 W 2357,76 0.90 38 56 S 33 18 W 2439.00 0.84 38 45 S 32 45 W 2518.74 0.46 SUb-SE4 VERTICAL DEPTH 3900.00 4000.O0 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 ~700.00 4800.00 4900.00 5000.00 5100.00 5200,00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6495,17 37 58 S 33 3'* W 2597.35 1.90 37 25 S 3~ 9 W 2674.34 0,.91 37 59 S 38 42 W .2751.58 0.3~ 38 9 S 33 46 W 2829.85 0.46 37 59 S 38 42 W 2908.66 1,25 37 7 S 40 1 W 2985.14 O.O0 37 T $ 40 1 W 3057.1~ 0.00 50.00 FT RECTaNGULaR COORDINATES HDRiZ. NORTH/SDUTM EAST/WEST DIST. ~EET FEET FEET 53.3.15 S 571.02 W 784.65 514.79 S 637.22 W 335,45 6~4.77 S 704.13 w 776.27 S 770.37 W 1093.65 ~59.i2 S 835.13 W 1!9~.13 939.12 S 89~.49 W' 12~5.93 1014.64 S 950.22 '~ 1390.11 1089.15 S 100~.~4 W 1481.~8 1164.33 S 105~.51 W 1573.56 1239.43 S 1110.~5 W 156,4.38 1314.23 S 1161.76 N 1754.12 1338.98 S 1211.27 W 1542.94 1463.63 S 1259.70 W 1~31.08 1537.13 S 130~.70 W 2018.7'~ 1608,18 S 1358.96 W 2105.48 1679.19 S 1407.34 W 21'90.95 1749.73 S 1453.71 W 2274.32 1,~20,45 S 1~9~.7~ W 2358.04 1989.86 S 1542.56 W 243'~.48 1957.16 S 1586.51 W 2519.42 2023.00 S 1630.&2 W 2593.23 2084.60 S 1676.83 W 2~75.31 2144.94 S 1725.11 W 2752.59 2206,02 S 1774.09 W 2830,89 2267.68 S 1823,24 W 2909.74 2326.64 S 1871.97 W 2986.22 23~'1.80 S 1918.29 W 3353.24 3:P&RTUR= AZIMUTH OEG MIN S 46 41 W S 45 1 W S 44 4.6 W S 44 11W S 43 36 W 543 7 W S 4.2 41 W S ~.2 15 ~ S 41 32 W S 41 2,B W S 41 5 W S 40 43 W S 40 2a W S 40 11 W S 3'9 57 W S 39 43 W S 39 27 W S 39 13 W S 39 1W $ 3,_q 52 W S 3',~ 48 W S 32 47 1,1 S 3,,~ a9 N S 3% 50 W ARCO ALASKA, INC. 3J-7 KUPARUK NORTH SLOPE,ALaSKA MARKER TOP BASE 'OP BASE PBTD TO KUPARUK C KUPARUK C KUPARUK A KUP~RUK A COMPUTATION D4TE: 21-NOV-85 iNTeRPOLATED VALUES FOR CHOSEN H3RIZONS DEPTH ORIGIN= TVD DATE OF SUqV~Y: 19 OCT S5 KELLY ~USHiNG ELEV&TISN: ENGINE£q: LESNI: 20.00 SUE-SE~ 7070.00 6115.51 6335.51 7133.00 5165.29 ~056.29 7263.00 6268.eB 61~5.68 7~18.00 6~90.46 6310.46 75~4.00 6490.$~ ~10.65 7650.00 6575.17 ~4'75.17 SURF&CE LOCATION FWL, SEC 3, T1ZN, R95, RECT&NSOLAR COORDINATES '~gRTH/SOUTH ~AST/W3ST 2106.50 S 1694.24 2136.59 S 1718.41 2199.1,3 $ !768.52 2332.81 S 1877.15 ~ ;50 ~ 1918 29 UH ARCO ~LASKA, INC. 3J-7 KUP~RUK NORTH SLOPE,~L~SK~ MARKER TOP KUPARUK C RASE KUPARUK C DP KUPARUK & SASE KUPARUK A PBTD TD COMPUTATION DATE: MEASURED DEPTH BELOW KB 7070.00 7133.00 7263.00 7~18.00 7544.00 7550.00 21-NOV-SS DATE OF SURVEY: 1~ ']CT 35 KELLY 3USHIqG ELeVaTION: ENGINEER: LESNI~ 7 ~0.00 ORIGIN: 890' F3L, TVD FRgM KB SUB-Sc& 5116.51 6036.51 6166.29 6066.29 6268.68 618~.58 6390.46 5310.46 6490.65 6410.65 6575.17 64'~5.17 564' = REC NC SUR~aC£ LJCATIDN &T WL, SEC 3, T12N, T&NGULAR COORDINATES RT'H/SCUT~ E&ST/WEST I05.50 S 1.594.24 136.59 S 1718.~1 199.10 S 1768.52 274.0a S !~23.34 332.81 S 1877.15 3~1.80 S 191~.29 UM FINAL ,MEASUREO DEPTH WELL LOCATION 4T TO: TRUE SUS-SE~ VERTICAL VERTICAL DEPTH DEPTH ?650.00 6575.17 6495.17 HORIZ3NTAL DEPARTURE DISTANCE aZIMUTH FEET DES MiN 3055.24 S 3~ 50 SCHLUMBERGER 0 1REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL SJ-7 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000070987 WELL NAME: 3J-7 ~_.~ SURFACE LOCATION: 8 FST',, 564' FWL, S3, T12N, R9E, o! 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SuggeSted form to-be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, ~ELI~ NAI~ AND Reports and Materials to be received by: //---/~- Date Required Date Received Remarks Completion Report ~ ~~___ ~.~ ~ Ye~ :t~-~.~-Z_~ ~ , Samples Core Chips _ .-: Cbr~ -Description . Registered Survey ~c~~on S~rw~ Directional ~ S U r V e y Drill Stem Test RepOrts Production Test Reports /~.~~ Digitized Data L.FJ.04 ARCO Alaska, Inc. Post Office b...~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-13-85 TRANSMITTAL NO: 5442' RE. TURN TO: ARCO ALASKA, INC. KUPARUK OPEKATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. 'BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND FINAL 3J-7 3J-6 HEREWITH APE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ~IN~S /-SCHL/ OPEN HOL~/ O~. OF ~_")5" DIL/SFL-GR 10-09-85 RUN '#1 1750-7564 ~'2~ DIL/SFL-GR 10-09-85 ~UN 91 1750-7564 ~5~ DEN/NEU PORO 10-09-85 RUN ~1 6900-7538 ~2~ kDIL/SFL-GR DIL/SFL-Gk ~5~' DEN/N~:U-GR '~2~' DEN/NEU-GR "5'7- DEN/NEU-GR '~2"~y .~kDEN/NLU-GR '~CYBE RL OOK PORO PORO RAW PORO POkO RAW RAW PO RO PORO RAW RAW 10-02-85 RUN ~1 4314-8617 10-02-85 t~UN ~1 4314-8617 10-02-85 RUN ~1 7671-8592 10-02-85 ~{UN ~1. 7671-8592 10-02-85 I{UN %1 7671-~592 10-02-85 RUN %1 7671-8592 10-02-85 RUN ~1 7671-8592 09-25-85 RUN #1 4344-8642 09-25-85 RUN %1 4344-~642 09-25-85 I<UN %1 4344-8617 09-25-85 RUN ~1 4344-8617 09-25-85 RUN #1 4344-8617 09-25-85 RUN #1 4344-8617 09-25-58 RUN #1 7940-8600 09-17-85 RUN 09-17-85 RUN 09-17-85 RUN 09-17-85 RUN 09-17-85 RUN 09-17-85 RUN 09-17-85 RUN DIL/SFL-GR \ 5~JI D}:N/NEU-GR X25~.-~ DEN/N EU- GR CYBE~OOK 3J-4 ~ 2/,// DIL/SFL-GR DIL/SFL-GR ' ~ 5" DEN/NEU %2~ DEN/NEU ~5~ DEN/NEU '~2 'J DEN/NEU ~ % CYBE~OOK RECEIPT ACKNOWLEDGED: DISTt<IBUTION: DRILLING*DL W. PASHEk L. JOHNSTON EXXON MOBIL PHILLIPS OIL N~K CLEKK*~L J. RA'2~/~ELL*bL BPAE B. CURRIER CHEVRON D & M*bL %1 4300-8522 #1 4300-8522 91 4300-8496 #1 4300-8496 ~1 4300-8496 91 4300-8.4,9~6~ .... . . DATB.(/~ska~~0~ & G~s STATE OF ALA~KA*BL SOHIO /SE UNION VAULT/ANO* FILMS ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ~-.~ Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-07-~5 TKANSHITTAL NO: 5431 ~'T URN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~._Z~_N SMI T TED JCEIPT AND RETURN ~EN H~QLE LIS TAPES ~J'--8" i0-16-85 3J--7~'' 10-09-85 $F"-5~'' 10-20-85 3 F- 4 --"" 10-13- 85 F~-i6~,~ 09-29-85 $C- !5--'" 1-0- 08- 85 $~-!4 ---~ 10-15- 85 3~- 7~-'w~ 10-24-85 ~,4- 6 -~-' 10-18-85 BAr-5~''' 10-11-85 HEREWITH Alee THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. PLUS LISTING/ SCHL/ ONE COPY OF EACH }{UN 91 RUN ~1 RUN ~1 RUN 91 RUN 91 RUN ~1 RUN 91 RUN ~1 RUN 91 RUN %1 1748.0-7585. 1994.0-8647. 3030.0-6900. 3692.5-6851. 3816.0-7864. 4050 1948 3410 3952 .0-8425· · 0-7269. .0-7617 · 5- 8683 [ CEIPT ACKNO%~LEDGED: CURRIER- SVRON M DRILLING L. JOHNSTON ~O5IL NSK CLERK DISTKIBUTION /" J..!~AT~ELL VAULT/Al90 ARCO Alaska, Inc. is a Subsiolar¥ o! AtianticRichf~eldComl:)any ARCO Alaska, Inc. Post Office Bi 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer OG/tw GRU12/L80 Enclosures RECEIVED Alaska Oil & Gas Cons. Comm!ssion /Incllorag~ ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~. STATE OF ALASKA -- ALASKA C.. AND GAS CONSERVATION COI,..,llSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~ Workover operation [] !. Name of operator 7. Permit No. ARCO Alaska, inc. 85-215 3. Address 8· APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21438 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 890~ FSL, 564' FWL, Sec.3, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 80 ' RKB I6. Lease Designation and Serial No. ADL 25630 ALK 2563 For the Month of October ,19 85 10. Well No. 3J-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0330 hfs, 10/04/85. Drilled 12-1/4" hole to 3510'. Ran, cmtd & tstd 9-5/8" csg. Drilled 8-1/2" hole to 7581'. Ran logs. Continued drilling 8-1/2" hole to 7650'TD (10/10/85). Ran, cmtd & tstd 7" csg. PBTD = 7544'. Secured well & RR @ 0400 hrs, 10/11/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set @ 100'. Cmtd w/183 sx AS II. 9-5/8", 36.0#/ft, J-55, HF-ERW, BTC csg w/shoe @ 3490'. Cmtd w/1005 sx AS Ill & 295 sx Class "G". 7", 26.0#/ft, J-55, HF-ERW, BTC csg w/shoe 0 7633'. Cmtd w/435 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/7572' - 3490' 6.NoneDST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. i/I* ~ t/~ll[.~L-., .... E Associate Engineer [[-14-~ SIGNED ~ ~ H~L .... DATE NOTE--Report ~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU12/MR10 Submit in duplicate MEMORANDUM TO: T}~P,U: State of Alaska ALASKA OIL AND GAS CONSERVATION CO~;E'IISSION C. ~.~a~t terton Commissioner DATE: October 11, 1985 FILE NO: D.t-IRH. 78 TELEPHONE NO: FROM: Harold R. Hawkins Petroleum Inspector SUBJECT: BOPE Test ARCO, KRU, DS 3J-7 Permit ~qo. 85-215 Kuparuk River Field Sunday, October 6, 1985: While I was on the slope, subject of o~her reports, I~"witnessed the BOPE Test on 3J-7. There were no failures and I filled out an A.O.G.C.C. Report which is attached. In summary: I witnessed the BOPE Test on ARCO's KRU 3J-7 Well. The BOPE tests were perfomed satisfactorily by Parker's 191 crew. Attachment 02-00IA(Rev. 10/79) . o&G #4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well Operator ~.p f"/.? Well 3 7 Location: Sec Drilling Contractor Location, General General Housekeeping ~/( Rig f)/[ Reserve Pit t~/< Visual Audio Mud Systems Trip Tank Pit.Gauge ~ Flow'Monitor · . ~ Gag Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves Test Pressure -'- H.C.R. Valve Kill Line Valves . Check Valve · Representativ~ /~/W , 7-~/-/~' B ~"=~ Permit # ~--- 7~ Casing Set @ Ri~ ~/~/ Representative ~/~-/~ ACC~LATOR SYST~ Full Charge Pressure ~ ~ psig Pressure After Closure /~_{~ psig -- Pump incr. clos. pres. 200 psig . Full Charge Pressure Attained: /// min /~ sec. Controls: Master Remote ~/~ Blinds switch cover ~/~ Kelly and Floor Safety Valves Test Results: Failures t~wO&wK-~ Repair or Replacement of failed equipment to be made within Commission office notified. Remarks :_ ~/~/~ 9' /~---W z) ~ TT~ ~- / - Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves /.~ No. flanges ~ ~ Adjustable Chokes 7-/6// ~/~ Hydrauic,ally .operated choke ~/T Test T me I hrs. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor September 10, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3J- 7 ARCO Alaska, Inc. Permit No. 85-215 Sur. Loc. 564'.~L, 890'FSL, Sec. 3, T12N, R9E, UM. Btmhole Loc. 1438'FEL, 1459'FNL, Sec. 9, T12N, R9E, UM. Dear ~Ir. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional 'permits required by law from other governmental agencies prior to commencing operations at the well site. To aid 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 Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION be Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3J-7 Dear Mr. Chatterton- Enclosed are- An application for Permit to Drill Kuparuk a $100 application fee Diagrams showing the proposed horizontal projections of the wellbore o A proximity plot A diagram and description of the surface system A diagram and description of the BOP We estimate spudding this well on October any questions, please call me at 263-4970. Sincerely, J. B. Kewin Regional Drilling Engineer JBK/LWK/tw PD/L161 Enclosures 3J-7, along wi th and vertical hole diverter equ i pment 10, 1985, If you have RECEIVED SEP :LqS§ 131! & Gas Cor~s. Commlssto~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AllantJcRJchfieldCompany STATE OF ALASKA '--~- ALASKA O~L AND GAS CONSERVATION CO~,,,¢IlSSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY ~ SERVICE ~ DEVELOPMENT OIL ~X SINGLE ZONj,~ DEVELOPMENT GAS ~ MULTIPLE la. Type of work. DRILL [~X REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 564' FWL, 890' FSL, Sec.3, T12N, RgE, UM At top of proposed producing interval 1274' FEL, 1280' FNL, Sec.9, T12N, RgE, UM At total depth 1438' FEL, 1459' FNL, Sec.9, T12N, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 3J'7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 80', PAD 45' ADL 25630 ALK 2563 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3821 feet 3J-6 well 25~ ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7575' MD, 6497' TVD feet 2560 10/10/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2845 KICK OFF POINT 2180 feet. MAXIMUM HOLE ANGLE 40 oI (see 20 AAC 25.035 (c) (2) 3266 psig@ 80°F Surface psig@. ~3&cj ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program ! SIZE SETTING DEPTH QUANTITY OF CEMENT !Hole 24" Casing Weight 16" 62.5# 12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I Couplingl H-40 | Weld Length MD TOP TVD 3494' 80' 36' I 36' 36' 36' I I 35' I 35' 7540' I MD BOTTOM TVD 1161 116' 35301 3420' 7575'1 6497' I I (include stage data) ± 200 cf 1005 sx AS III & 295 sx Class G blend 300 sx Class G btend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7575' MD (6497' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2845 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3J-7 will be 25' away from 3J-6 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge Th e space %w for f'~c~nCsio"~- u~ef/ Samples required []YES XNO Permit number Form 10-401 (LWK) PD/PD161 TITLE Regional Drilling Engr. DATE CONDITIONS OF APPROVAL Mud Icg required I--lYES ~.NO Approval date '-/ // Directional Survey required I APl number KYES [-~NO 1 50_¢zq SEE COVER LETTER FOR OTHER REOUIREMENTS ,COMMISSIONER DATE September 10, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3J-7 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. KUPARUK RIVER UNIT 2_.0" DI VERTER SCHEMAT I C DE S CR I PT I ON i. 16" C~CTOR. 2. TAhaKO STARTER HEAD. 3. TABOO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TAr~KO UPPER QUICK-C~CT ASSY. 6, 20' 2000 PSI DRILLING SPOOL W/lO" OUTLETS. ?. IO" HCR BALL VALVES W/lO' ~' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF" ANNULAR PREVENTER. 8, 20" 2000 PSI Ah~ULAR PREVENTER. MAI NTENANCE & OPERAT ! ON ~_~ 4 I. LtPON INITIAL INSTALLATIO~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE Aht~LAR PREVENTER AND BLOW A I R THROUGH DI VERTER L I NES EVERY 12 HOURS. CLOSE Aha"~LAR PREVENTER IN THE EVENT THAT. AN Ih~'LUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY. MAh[JALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DOt~NWlND DIVERSION. DO NOT SHUT IN V~LL UNOER ANY CIRCUNE;TANCES,: ~ I {X~4~13~ R4 7 - ~ i i i ACCLIVU~ATC~- CApACTTY Q-EQ< AND F-iLl AC~O_M.J_ATCR F~VQIR .TO LEVEL WZTH ~IC FLUID. A,~ THAT AC~TCR F~ IS ~ P~I ~ TI~E, ~ Q_OSE ALL UNITS S~MJ_TA~C~Y ALL UN~T$ ARE CLOSED WTTH C3-~IN~ ~ CFF. 5 4 2 IS 45 SE~ O..QSINS TI~E AND 1;~::) PSI EEh/AIN~G FZL.L ~ s'rA(:X AN:) 'O-ExE 'h~EFIZ.D w3"i'H OEO< TNAT ALL LOX DONN ~ IN ll~m ! I-EAD F'LLLY F~'TRA~r]~. SF_AT ~ F~_UG IN W~I ~F_AD WITH RUNNING JT AhD E~JN IN LOCXI:K]NN LIllE VALVES ADJACENT 'TO BCP STAC~ ALL 4. .PRESSLRE UP TO ~Ha_D FCI~ 10 14[N. IN- LZhE VALVES. C3..O~E TOP PIPE RN~ AhD HC~ VALVES TEST. 'TO 250 PSI AN) ~ AS IN 5-rEP C33NTIN, JE TESTING ALL VALVES',, LIhES, A~ ~Q'9'H A 250 p~.l LC~ AhD 3C~ PSI HIOH. TEST AS IN I,,o"r A FU_L O,.. OS ;[ h,~ PoS~rTZVE SEAL ~. O',,LY 8.-{:PEN TOP PIPE ~ AhD O..OSE; l~rrrc~ PIPE RAN'B. TEST B01'FC]~ PIPE ~ TO 250 PSI AhD ~ PSI. I0. .O_C~__.BLIhD !~ AhD TEST TO 250 PSI AhD PSI. -J,~FO_D AhD LZhES /k~ FLU.. CD" FLUID. ~ ALL VALVES IN EI~ZL.LZhI~ POSITZChL · ,-12~ TES'r'-S'rAN~IPE VALVES, ~ ~¥o ~ ~Y COCKS, ERILL - ~-'PIPE ,~ VALVE, AhD Ih~IDE ~ TO ~ PSI AhD 13.' REC~ TEST lhF~ATIClN tin BLOWOLn' ~ 9'ES'T 0C~4~ I REV. 2 MAY 15,,1~5 - - ; ' ~ ; : - ; ' :', ' I ' ' , : ' , - - - ' · f . _. _ - _-. . _ . ._ J . , : , . = .~ :- :.L:-.; .... m~ ---- ' .... . ~ - -';--:- '~-''. ..... ~ ' '' ...... :.: -- - ...... : .... . ........ ~ _ - ........ -~ ...... : . : .' . . · ....................... ~ .- ...... . _.. : ....... - _ ......... ~ ..... : - ._ _ '~: ..... ; ..... : ............ ~--_ - . . ~ ......................... ~ ........ ; ................. ~ ........ - T~:-:_.~-_:- :__:_' _:.BASE"-=~="'~c=~_,~,,,,--,,~- _-TVD=-I 685 ....... '- 7 ........ ' ....."" ..... ~ ....... ' ' ' ..... . ..... ~' '-' ...... ~ ............................. ~ ......... . ~, ...... .; , .. ~.: .......... ~ ...... · ,._~ ....... . .... .......... - ..... z ............... - ; ........ ; ........ , ............. ~ ...... : ....... ;. .. ......... ~ - . ..... ~ ........ ........ - ..... KOP- ' TVD=2~ 80 .,-,~ ~,'"~=4' 80-:DEP=O ._-~. __' :_..-, -~ --~ ~: ' ' : ' ' ~ ' ' '-' .... -- . ~ - . · ~ '_ _ - ~ - _ ................... 3 TOP UGNU SNDS TVD=2260 _T~D=2260 DEP=2 -. ': ..... ~ .:.": .-~_":" '~ :-~__::~2~:: - ..... ; ....... ~. - =_. _. ~ ..... ~ - ~ .............. t~-'t~ : '~' PER 100 FT' ~ -" ' ...... -- - ~-- - : .... : ; ..... ; ' ' j .... '. :-' [' ' -C ' ' , ........... ; ..... ; - ' : ....... ' : ..... ' ' ' ' : - ; '',-- ' m ..... 3000 ~_~- ~' - TOP :~ SAK SNDS TVD=2940-:T~D=2962 DEP=158 : .... m ...... : -- .... 1:--~ ~- K-12 TVD=3220 THD=3280-.DEP=308.~- ' ...... '~ .......... ;,--- '.---:- :~ ..... :_ ........ ] -% ~'~ .. ; - _ - . _ , : -: :: . ~ ~ . : ~_ - ~ . : . · ...... , .... . : . _~ _ ~-~-:~ .... /-:~ -~ 39' {EOC (CSG 'P~T)-' ;TVD=3420-THD=3530 DEP=45Z J- --:: ; ·; .... ~ - -o:--~::,..-~ -=:-:- ~T-:: _ ---:-:::~-- :-- ..... : .... :---:--:-=- -:-/T_-.::=-:-:--?:' :-: .... T: ..... ._: ~::-- - :':- .:: -'- ; .... :"-' ' :'. ...... : ..... :-: .... :-: ~:'-'--'- ~~oo .... :_._~_ ...... ~: '-.:'-~ ~--~ -::'::!-:'--.:- ~ X' "~ AVERAGE'ANGLE~.-' : _' '~ - ' ~ ---l--' . ' : ' -~ .... ~ = '- ~-- '-- -~---~ ................. ~ .................... ' .......... ' ......... ~ .... ....... ~--~-' :-' ~-t -' ..... '"-~-:- ........... ' :':'~ :" ":': ' ; .... ' ' ....... :-~.-: ~ ........ '--t' ......... ~ ~---:-- ~-- .... ~ ....... ~-- - : ~ ..... '---i:-- : -:-; --~-' -~ ..... :-- ' .... : : - _--L.~_~ ....... __~ -___. .... : ~ ....... ~ .... : .... ~ ........ : ...... ; ....... ....... -m' . : .; ._ _ :. .... : ..... ~ TOP~PPR ~DS ;TYD.6048 ~6gBS ~P~701 ~-~:~:-~-:!: .... : ..... ~ ....... ~ ......... ~ ....... ~-'~--~-~-~=~: ~ ;-- TA~E~: CN~ ~TVD=62B4 T~D-Z29~ -:T;-~-~-:--:-:--I-'::--:--:--~-~ ..... ;:-'?: ...... ::;-:-:-~:--':'-:"~.: '}_~:~-~ASE~UP:.~DS- T. VD=6345&T~D-Z3Z~~~295, . ~ ~- ' T~ - ~ ~ '--_ -J ....... =-_: ......... ~ ; ...... -~ ..... ~-~ :__~_' ;-:~--:4 --=---=.-~-~ ...... ~- ' --' .....~ .....+-==- ~ ....... ........... .... :: .... ....... ~ ~_~-__~_-_~__ _ :~- - ~-~ ..... :~o~ -~-~-. .... ~~_~-'::__~_.m~_ ~ ..... ~...--- .-~~~-~-~--. ~ ~-~ ..... ~ ~ ~ ~- ' - ~ .... ~ ' ' . : .... ~..;_- · 4 .... ~-,-4-; - · .-=-~ ..... =~_~ ............. ~ ........ ~ ........ ~ ....... ~ ..... ~ - ~-- . , ~ ...... . _ . ~ : _ _ --~ ~ .... . . ~ ~ . , ~ ~ . : _L-7.~__L'~_~- '--L-~-:i-L-_SZ~:--_-_._KU IR K FIELD OFtTH;$LOP. E.- ACASKA--:.-- ',' -~.'. ~ . -~;~: ..... .... ,- '-- ~~.~ ........_?-:.-~-,~.~-~ .... __~ .... ....... ~ ....... ~ ........ j . - ~ . . , : _. - - _ _ ~ ...... ............. ~ - _ : ........ - ,. ......... .; . ..._.= ....... ~ ...... ' ~000 ' "2000 ~000 · - O ' ;,-" 1000 ................ ........ ~ ....... i ...... ' - ' -'-i ............. I .......... ~, .... :--~ ..................... ' - ........... ~ ....... : ....... - ......... - ~ .... - ..... - , _ .... : . . . ~ . ! .~URFA~ ............ _ __. _,._ . .: ......~ ..... - ' ......... - ............. ~ ........ :-~ 891' :FSL .~0' F~L--- ' ..... ~ ........ : ...... ~ ...... ~ ...................... ::~O '~ T12N R~ ~ ~ ' · T t.1 -:. i : ! . : · . , ?. : · j - : J. ARCO Alaska, inc. Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 'August 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchora§e, AK 99501 SUBJECT' Conductor As-Built Location Plats - 2J Pad Wells 1-16 Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU11/L07 Enclosure If RECEIVED AUG2 198§ Alaska 0ii & Gas Cons. Commis$1on Anchorage ARCO Alaska, Inc. Js a Subsidiary of AtJanlicRichfieJdCompany I$ II II ~e IO ~OTE~ I. COORDINATES ARE A.S.R,ZONE 4 R£~ERVIr AS BU CONDUCTORS 1-16 1- Y- 6,002,~22,$~ L~T. 70°25~0&.~20~ , X- 519,5~6.B0 LONG. 1~9°50'26.870" ~63~ FYi, ?k0~ FSL, 0G. ~1.3. PAD 2- ¥- 6,002,~?'~ L~l. ?0°25'0~.2~" X. 519.$~,66 LONG. l"g°50''25.~6~" $63' KWL, ?65' FSL, OG.~I.O..PAD GS.~ 3- Y- 6,00Z,~12.$g Lil. 70°25'0&.sX2" X= $1g,$6~.~0 LONG. 1~9°$0 ' 563' FWL, ?gO' FSL, OG. ~O.g. ~AD ~_ y. 6,002,~97.59 LAT. 70°25'J04,75B" X, 51g,54~,63 LONG, 16g°50'26.B63' 56&' FWL, 815' FSL. OG. kO.B, PAD 45.5 5- Y- 6,002,522.57 LAT. 70°25'05.003'' X= $19,5aa.65 LONG.,lag°SO'26.B61" 56&' FWL, $40' FSL, OG. ~0.9 PAD 6- Yo 6,002,5~7,61 LAI. 70°25'05.250" X= $]g,5~6.65 LONG, $64' FYL, 865' FSL, OG. ~.0, PAD ~. y. 6,002,572.61 LAT. ?0e25'05.&)5" X. 51g,5~,67 LO#§. 1&go50 56a' ~WL, 890' FSL, OG, 41.1, PAD. ~5.3 B' y. ~,002,5~7.57 LAT. 70°~5~05,7&~'' X= 51g,5~4.68 LOIG. 149°50 56~' FWL, 915 KSL, OG, '~1.2, PAD. ~$.3 g_ y. 6,002,672.63 LAl. 70°25'O~, Xm 51~,544.7~ LONG. I~g~50'aB.8~6'' 2. sECTION LINE DISTANCES ARE TRUE. 3 HORIZONTAL POSITRONS BASED ON THE D.S.-)J NORTH- WEST B SOUTHWEST wINDOW CORNERS PER F.R.I~ &~OC. * 4. VERTICAL POSITIONS BASED ON TBM 85-7-Z7-1 PER LHD & ASSOC· 5. O.G, ELEVATIONS tNTERP~OLATED FROM SIC DWG. CED - R~XX -~O60 r?v, 4~ RECEIVED .AUG 2 .!9B5 Alaska 0il & Gas Cons. Commission_ y,, 6, 002, ?~7. 62 Anchorage I HEREBY CERTIFY THATIAM PROPERLY REGISTERED AND LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA~ THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF JULY ~50~ 1985. LOCATED IN PROTRA4::'rl~D E4[C.~, TI~ N, RgE~ U. MER. i' 10- Y= 6,002,697,65 LAT. 70025106.725'' 565' FWL, 1015' FSL, OG. 41,0, PAD 11- y. 5,002,722.64 LAT. 70°25'0B.gTl'' X- 519,5~.73 LO#~. 149e$0 565' FWL, lO&O' FSL, OG. ~0.?, P~D LAT. 70°25~07.2 X= 51B,$~6.?B LONG, 565' FWL, 1065'KSL, OG. ~0.?, PAD 65.5 13- Y= B,002.772.67 LAT. ?0°25'0 X- 519,~.?B LONG. 1&9°50'26,B3?m 565~ FWL, 1D90~ FSL, OG, ~0.4, PAD 14- Y= 6,002.797.59 kal. ?0°25'O?.?OB'' X. 51g,5~.?B LONG.16g°50'26'B36" 565' FWL, )115' rSC, OG. &O,2, PAD 65.5 15- Y- 6,002,822.60 k~l, 70°25jO?.gG&'' X- 51g,5~.ao LONG. Ibg°$0'26'$33" S§$'FWL, 11,0~ FSL, OG. &0.1, PAD 65.0 )6- Y- 6,002,~47.58 LAl. 70025'0B.2oO" X- 519,5~L.BO LONG. }&9°SO'26.831~ 565' rWL, I165'FSL, OG. 40.0, P~D. ~5.~ imam% AR, CO Ku~aruk DRILL $ CONDUCTOR AS- B U I LT LOCATIONS I:)~ffm~ by: ~ D~I, ~' N~K i)5 - I$ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (9~ thru' ~2), . · '(i0 'and 12) ~ (13 thru 21) (22 thru 26) ' Company .../~, '~aO Lease & Well No. YES NO 'REMARKS 1 Is the permit fee attached e ' 3. 4. 5. 6e 7. 8. Is well to be located in a defined pool ............................ . Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool . ........... Is well to be deviated and is wellbore plat included ............ .. .. .~z~'~ --~-- .Is. operator the only affected party ........ ................ Can permit be approved before ten-day wait .[..:.1 ...... :... e 10. 11. 12. 13. 14. 15. 16., 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. D oper hav b nd in for oes . ator e a o ce .,,.,,,.,.,,,.,..,.,,,,,,,,,,,,,,, Is ervation ord needed a cons er ....................................... Is admini trative approval needed S eeeeeeeleeeeeeeeeeeeeeeeeeeeeeeeeee I the 1 number appropriate s ease ....,.,....................,......... Is conduct string provided ' or eeeeelleeeeeeeeeeeeeeeeeeeeee~eeeeee~eee Is enough cement used to circulate on cOnductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons~ ....... ~ ............. Will surface casing protect fresh water zones ...... '.. Wil]..all'casing give adequate safety in collapse, Is this well to be kicked off from an existing wellbore ...; ........ Is old wellb°re abandonment procedure included on 10-403 ............ I deq llb p i p d s a uate we ore se arat on pro ose ............................ Is a diverter system required .................................. Are necessary diagrams of diverter and BOP equipment attached ..... Does the.choke manifold comply w/API RP-53 (Feb.78) ..... , ....... Is the presence f H2S gas probable ' 0 eeeeeleeeeeeeeeeeeeeeeeeeeeeeeeee Additional requirements ............................................. Additional Remarks: Geology: Engin~e~ing: g. LCS WVA ~-- - MTM~ HJH JAL~, rev:.,03/13/85 '%6. O11 .. . INITIAL GEO. UNIT O'N/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. lit"' L'r) U () 0 0 O1 9 O04 014 O02 0 O4 002 0.1,2 ,I~E C 0 D ,m ,,m mlm mlm 065 065 065 065 065 065 065 065 0.65 065 : :t0,9i~ ,~,¢F',t..C = 3."1'"20 fa 65,0 D~' -- 9.,.,~'.' R",~C = ?,,qO0 .., 65'0 1.).~ :I. 6 4 t /1 4 4 4 1, a 4 1, 4, 4 1 6~ 000000000000()0 68 t,)O000000000000 fi8 00000000000000 6B 00000000000000 68 0000000:)000000 68 00000000000000 68 OOO0000000000n 68 OOOO0;)O00000()() 68 00000000000000 68 90000000000000 6~ 00000000000o00 C ,& I, i r) 'C r.'.. 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