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Home My WebLink About186-153Image. Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J Well History File Identifier Organization (done) ~Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. r~ Maps: [] Grayscale items: [] Poor Quality Originals: Other: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ~;~ NOTES: ,. ORGANIZED BY: ~REN VINCENT SHERYL MARIA LOWELL __ Project Proofing [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES: ~)~ (at the time of scanning) SCANNED BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE: ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARia LOWELL DATE: /si General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Memorandum To' Well File: State of Alaska Re: Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE' Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' ~ Statistical Technician August 15, 1986 M~r. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Te!ecopy: (907) 276-7542 Re: Lisburne LG!- 16 A/{CO Alaska, Inc. Permit No. 86-153 Sur. Loc. 953'-Fr~, 1716'FEL, Sec. 1, TllN, R14E, Bt~hole Loc. 2!22'FSL, 739'FEL, Sec. 25, T12N, R14E, I/M. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other 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. !~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below, the shoe of the conductor pipe. C. V. Chatterto~ Chairman o f Alaska Oil and Gas Conservation Con~nission BY ORDER OF THE COCa, fISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl Mr. Doug L. Lowery STATE OF ALASKA ALASK/, .)IL AND GAS CONSERVATION ~-._ MMISSION PERMIT TO DRILL 20 AAC 25.005 GAS INJECTOR i la. Type of work Drill ,~. Redri,l []1 lb. Type of well. Exploratory ~ Stratigraphic Test L~ Development Oil Re-Entry ~ Deepen~1 Service .~ Developement Gas ~ Single Zone F~ Multiple Zone LC 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 52', PAD 13' feet Prudhoe Bay Field 3. Address 6. Property Designation Li sburne 0i 1 Pool P.0, Box 100360 Anchorage, AK 99510 ADL 28301 ALK 2312 , 4. Location of well at surface 7. Unit or property Name 111 Type Bond/see 20AAC 25.025) 953'FNL, 1716'FEL, Sec.1, TllN, R14E, _'M Lisburne Statewide At top of productive interval ~ Target ~d 8. Well nu,mber Number 1600'FSL, 800'FEL, 5ec.25, T12N, Rt.~E, UM LGI-16 #8088-26-27 At total depth 9. Approximate spud date Amount 2122'FSL, 739'FEL, Sec.25, T12N, R14E, UM 08/15/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth~MDandTVm property line 1 3,148 ' MD 0' ~ 3864'TVD feet 120' from LGI-12¢ fse-be~tface 2560 (8854'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2000 feet Maximum hole angle 560 Maximum surface 3440 psig At total depth (TVD) 4490 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 9!.5# H-~.O We!d ~! ';O' 40' 121' !2!' 2000~ 17-1/9_"!3-~/8" ~R ~ ~-~ RTl' ~a 39' ~9' !!q' 119' 1960 ~.~- AS !!! 17-1/?'~!1_"%-_'% /R'' 72_0~ I -RI') RT£ ~%f')1 11c)~ 119' 447¢)' 4f)l")O' ¢;tOn _~, £1~.~ 12-1/4"9-5/8" 47.0# L-80 BTC 12422! 38, 38, 12460 8472, 670 s xC l a s s C&300s xA$ ~A~ 8-1/2" 7" 29.0# L-80 BTC 888'~ 12260 83,6 '1314 ' 8854' 240sx65%ClassG/35%POZ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Intermediate :':!.:.i._i..i :'i ~,~ ?, i_,.'-'? r~ ¢..~ .-,- .,_ Production Liner Alaska 0il & ~;~..~;~,,'"'~s. C0r¢,rnissio~ Perforation depth: measured ,~ ..... 3, true vertical 20. 'Attachments Filing fee ~ Property Plat ~ BOP Sketch ~ Diverter Sketch ~, Drilling program ~ Drilling fluid program~Timevs depth plot % Refraction analysis ~ Seabed report ~ 20AAC25.050 requirements 21. I hereby certify that the forgoing is true and correct to the best of my knowledge Signed ~//?. ~~// TitleRegi°nal Drilling Engineer .Date ~/ Comr~ission Use Only ( FPG ) PD/PD303 Permit Numl~se~°- 153 I50-09-2]-643 I 08/15/86 I for other requirements APl numbe~ Approval date See cover letter Conditions of approval Samples required Yes ~'~._No Mud log required /. Yes ~ No Hydrogen sulfide me_.~3~,ures ~ Yes__kC No Directional,survey required .~,._Yes © No Required workin.g,¢Tess,bre fd¢ B~;;k~5 ./~,2~; ~ 3,~; ~ 5M; ~ 10M; ~ 15M Other: ( /?// ~~--~~"~/~///" byorderof Approved by ~ ,-~/~. k ~,/,,..~/,.../,.._ Commissioner the commission Date sue / ~ triplicate IRNNULIqR .PREVENTOR PIPE BLIND SPOOL PIPE ARMS 10. 11. 12. 13. 13-S/8" ~OP STACK DIAGRAM Acc~ulator ~paci:7 Test ~ck ~d fill ac~la:or rese~oir to p~r level ~th ~lic fluid. ~s~e t~ ac~lator p~ssure is 3000 psi with 1500 psi ~t~ of the re~la:or. Obse~e t~, t~n close all ~ts s~t~ly ~ record t~ t~ ~ pressure re~g after all ~:s a~ closed wi~ ~rg~g ~ off. ~o~ on ~ re~. ~e acceptable lower is 45 seco~ clos~g t~ ~ 1200 psi re~g press~. 1S-5/8" ~P Stack Test 1. Fin BoP stack and .manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug sea.~ing depth. R~n test plug on drill pipe and seat in wellhead. R~n in lock down screws. 3. Close armm~ar preventer and upstream valves. 4. Functionally test chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a ~ of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 mim~es. Blee~ pressure to zero. 7. Open armular preventer ami close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Blee~ pressure to zero. 8. Close valves directly upstream of chokes an~ open chokes.. Increase pressure to 5000 psi an~ hold £or at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 .min- utes. Test reamining untested mani£old valves (if anT) with 5000 psi upstream of valve ami zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe ram~. Sack off running joint and pull ou: o£ hole. Close blimi rams ar~ test to 5000 psi for at least 3 minutes. Bleed pressure o££ all equipment. Open blind rams. Make sure mani£old an~ lines are full of non- freezing liquid ami all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks ar~ inside BoP to 5000 psi with [oomey p~p. Check operation of Degasser. Record test information on blowout preventer test form. Sign an~ send to Drilling Supervisor. Perform complete BOFE test once a week and func- tionally operate BOPE daily. 14. 15. 16. 17. 18. Revised 2/21184 LGI-16 lOOO 2000 300O F-.-. ~,000 '-" 5000 n,- 6000 8000 9OOO 10000 0 1000 2000 3000 4000 SO00 6000 7000 8000 9000 I0000 ARC ::) AL ,SKA, INC. I(OP TVI~ · ~f3tlO ;.ICALE ,'-/o ,,,,,.= I. ooo ~T 2.b - - 2000 7.5 SHL: 963IFNL 1716' FElL 12.5 SEC 1 ~r11N R14E UM 17.5 TARGET: I~or..h' ~-~L. 222) .~FC. ~).R rl~N R14F II1~! 3000 B7.5 4-2.5 47.5 ',,Z' 52.5 EOC TVD -J 3905 MD = 4248 DE'-' 1017 13-3/G' SGRFACE T', ....... MD -- 442;. .... 11C, 0 ,~oo0 5000 ~ N 06 DEG 4~) MINE 7886 FT(TO TARGET) n,-' ~VERAGE AI~ GLE 56 DEG 12 M IN r,~ ooo (-10 TVI'3 = 7(")O~ MI) = ~R17 OFF = Rtl45 ~ 7000 K-6 'I'VD = 7402 MD = 105 i6 DEP '"- 6243 LCU FVD .- 799:: MD -- 115!)7 DEP -- 7' 24 ,,,,. 8000 SA[)LEROCHIT TVD = 799 Z MD = 115 ;}7 DEP = 7124 ~ AVIK TVD = 8392 Mr' = 12316 D ~P = 7722 9-5/8' C/~ SING TVD = 8472 MD == 12460 D ~P "' 7842 -. TOP LIS BURNE TV[) -- 8502 N D = 12514 )EP == 788~ T,~IPIGET TVI) = 8502 ~t D = 12514 DEP = 788~1 %AIAE/"~/'~ "~ '~'Vr'~ ~ a lq"] AJl'~ ~ l~'~QO I~D ~ O~'Tq 9000 TD-7' C~kSl~"l~b['N [ 596 = ~11'~, ~ib = i3148 OEP'-, g4Tl~Z' .......................... ' .................... ,~ ............................................ 10000 1000 2000 3000 s~000 5000 6000 7000 8000 9000 10000 VERTIORL SECTION ~ - W OOOROINB~£S o -3000 -2000 - 1000 0 i000 2000 3000 4000 , , , , , , , , , , , , , i i , i , , , , , , , i , , , i , i , , i , , ' ' ' ' ' ' ' ' ' ' ' ' ' ' I I i I i i i i i & i .,-., c~ ~1-11' fl i~' :NI 1718' FF! "" SEC TI'IN R14E UM TARGE ': IO::~'~=~t.- SEC 5 TI2N R14E UM co - 1 ARGET 1 VD -' 8502' 1 ~D -- 12514' o . C EP -- 7888' E 916 I : . .; . ' ,,: ,;:~ ;-/) -3000 -2000 -1000 0 1000 2000 3000 ~000 ~ - ~ COOROINflT~S -200 co o o ED O I C~ -100 E - N COORDINB?ES 1 O0 200 300 ~00 500 I I I I I I I I I I I I I I I I I I I I I I LGI-I LGI-/ ~689 / ~3 l 520 / ~i23~ ~157 / 35,~8 8 / 3~ 3998 ~3 /3998 L~i_iO X 3385 3918 ~ / 331'~ 38',58 / 3661 8 ~602 /23~8 f305 . ~273~,,636 ~ 3561 : ;' ' 500 600 -200 -100 0 100 200 300 i' ~] "-' ...... E - N COORDINRTES 600 ~i389 55 769 -3000 g - ~1 COORDINPITES -2000 - lO00 0 lO00 2000 3000 4000 0 0 O~ 0 o ~-~ z ?256 8 0 ~59 I [ i , , 6725 , , , , -3000 -2000 -i000 0 1000 2000 3000 '~000 g - N OOORDINFtTES LG1-16 DR I Lt I NG PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annul ar di verter wi 11 be installed-per the attached schematic. This is a variance from 20 AAC 25.035. 2. MIRU Rowan 41. Install 10" diverter lines and function test. 3. Drill 17-1/2" hole to 2000'MD(2OOO'TVD). Build 2-1/2° per 100' to 56°12' oriented N6°40'E to 4420'MD(4000'TVD). 4. Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. Do top job if cement does not surface. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi, annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform leakoff test. 6. Hold angle and drill 12-1/4" hole to 12,460'MD(8472'TVD). 7. Set 9-5/8" casing and cement. Test casing to 3000 psi. 8. Drill 10' of new formation and perform leakoff test to 12.5 ppg EMW. 9. Drill 8-1/2" hole to approximately 13,148'MD(8854'TVD). 10. Run open hole logs. 11. Run and cement 7" liner. 12. Clean out cement and change mud out to brine with 400' diesel cap. 13. Secure well and release rig. 14. Run cased hole logs. 15. MIRU completion rig. 16. Run 5-1/2" 17.0#, L-80, AB-MOD tubing string wi th packer and subsurface safety equipment. Set packer above top of liner. 17. NU tree and test to 5000 psi. 18. Secure well and release completion rig. 19. Perforate and stimulate well. NOTE: a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi ~ 8952'TVD, less an oil column to the GOC ~ 8652', less a gas column to the surface. d. The existing wells within 200' of the proposed well are: LGI-12: 120' at the surface LGi-IO: 142' at 1500'TVD There are no closer approaches at any point in the well. PD/PD303a:tw Density Depth (TVD) #/gal LG1-16 MUD PROGRAM Plas Yield Visc. Point Initial IOM FL % % (CP) #/100 ft2 Gel Gel CC/30M Oil Solids 40-60 20+ 40+ 20+ 0 8-10 Surf 8.8 Funnel to to 100- 13-3/8" 9.7 300 Csg Poi nt 13-3/8" Csg Shoe 8.3 Minimum 6 2 5 25 0 3 to to Possible to to to to to to K-lO 9.4 20 10 30 10 2 ? pH and Type of Mud Spud Mud Low Solids Non-dispersed K-lO 9.2 10 4 4 8 8 2 4 to to to to to to to to to 9-5/8"Csg. Pt. 10.2 20 10 8 20 4 5 15 9-5/8" Csg. Shoe 9.2 4 6 2 8 10 2 4 to to to to to to to to to TD 9.6 10 10 8 20 4 8 8 NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. pH 9-10 Low Sol i ds/Low Li me Non-di spe r sed Low Sol ids/ Non-Dispersed Salt 15,000 - 30,000 ppm EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Desilter PD/PD303b:tw ROWAN MUD SYSTEM mixing pit ~1-1 4_% bbls mixing pit #2-1 45 bb Is pill pit 60 bbls I pit ~4 115bbls pit =3 suction 115 bbls pit ~5 trip tank 145 bbls injection pit 145 bbls pit ~6 -90 bbls pit~7- 90 bbls pit ~8 40 bbls Brandt Double-Decker Shale Shakers-(3) Demco Desander with 3-12" diam. cones Demco Desi!ter with 14-6" diam. cones Dri lco Degasser Pioneer Centrifuge Main Pumps: ~'qational 12-P- 160., (2) Gasbuster well well- AR 0 ALASKA INC. RO AN 41 DIVERTER I Fillup line 10" ball RiSer Flowline vlv I Conductor 'Only aUtomatica-lly when ~ ~ ~c~.~,~~:o~._ divertercloses. Then~~c, ~cl~' other will remain closed_____. ..... and be used only in case of emergency,,This is a variance.from 20 AAC 2~035 .P~="~TOR PIPE I~J. IN$ PIPE: RI:Il'IS 10. 11. 12. 13. 14. 15. 17. 18. 13-S/8" aDP ~rACK D:LA. GRA~ ~_ ~c~oT:~;) Amctmulator Capacit7 Test 1. ~ck ~d fill ac~lator rese~oir to p~r level ~th ~lic fluid. 2. ~s~e ~ ac~ator p~s~re is 3000 psi with 1500 psi ~~ of t~ re~lator. ~. Obse~e t~, t~n close all ~s s~t~ly ~ record :~ :~ ~ pressure r~~g after all ~ts ~ closed wi~ ~rg~ ~ off. 4. ~o~ on ~ re~. ~e acceptable lower is ~5 sec~ clos~g t~ ~ 1200 psi press~. 15-5/8" ~P St~k Tes~ 1. Fill ~P s:a~ ~ ~fold ~:h a ~-fr~z~g 2. ~ck ~ all ~ld ~ screws are ~ly retracted. ~rk ~g jolt ~h p~te~ plug sea:~g ~h. ~ :es: plug on drill pi~ ~ seat ~ ~1~. ~ ~ lo~ ~ s~ews. ~. Close ~~ p~venter ~ ~stre~ valves. · 5. -In e~ of ~ ~ll~g :es~, first ~ld a 250 psi 1~ p~s~e res: for a ~ of 5 ~es, test at :~ M~ ~es~. 6. I~e p~ss~ :o 5000 psi ~ ~ld for a ~ of 5 =es. BI~ ~ess~ :o ze~. 7. ~n ~ar ~e~er ~ close t~ set of pi~ r~. I~e~e pr~e to 5000 psi ~ ~ld for le~: ~ ~es. BI~ ~es~e to zero. 8. ~ose valves ~re~ly ~s:~ of ~s ~ o~n ~s.. I=e~e ~s~e ~o 5000 psi ~ ~ld for a: le~: 5 ~es. Bled press=e to ze~. 9. ~n top set of pi~ ~ :~n clo~ ~t:~ set of pi~ r~. I~e p~s~e to 5000 psi ~1~ ~t:~ se: of pi~ r~ ~ ~ld f~ at le~: u~es. Test ~~g ~test~ ~fold valves (if ~) with 5000 psi ~:re~ of valve ~ ze~ press~e ~re~. BI~ ~es~e ~o zero. ~n ~t:~ ~t of pi~ r~. ~ off ~g jolt ~~1o~ of ~le. Close bl~ r~ ~ test to 5000 psi for at le~: 5 ~tes. Bled ~ess~ off all ~~t. ~n bl~ ~e s~e ~old ~ l~s =e ~1 of ~.- ~z~g li~d ~ all v~ves are set ~ ~ill~g ~siti~. Test s:~i~ valves ~o 5000 psi. Test ~lly c~ ~ ~i~ ~P :o 5000 psi ~y ~. ~ ~rati~ of ~g~ser. ~cord :es: ~~tion ~ bl~ p~en:er tes: fo~. Si~ ~ se~ to ~ll~g ~~sor. :io~ly o~rate ~ ~ily. Revised 2121/84 LQI-16 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 I0000 0 20' CONDL CTOR TVD ---- 12~' ARC 3 AL ,SKA, INC. 2000 ~.b KoP TVD. ~0tlo ~CALI~ .wo,~- tooo ~ 200o 7.5 SHL: 963/FNL 1716' F~L 12.5 SEC 1 ~11N R14E UM 17.5 TARGET: I~o~' 22.'.~ 3000 RFC 9R rlgN R~4F I~ 3000 ~7.5 ~.5 47.5 ~ ~ 52.5 EOC TVD- 3905 MD -4248 DE,~1017 - ' 4000 "~ 442C ~nr~c u VI U ucr ~~ ~000 ~ 5000 ~ N 06 DEG 4~) MINE ~ ~ 7886 FT(TO TARGET) ~VERAGE A~IGLE ~6 DEG 12 M~N ooo ooo ~z. (-10 TVD = 7002 MD = RR17 DFr = Rf145 ~ 7000 7000 ~ ~r~ "~. ' ~:.:.,:~ K-5 ] VD ~ 7402 MD = 105:16 DEP ~ 6243 -,:. ............ 8000 ~ 8000 -~ ,';;, .~L,.-~ SAI )LEROCHIT TVD -- 799 Z MD = 11597 DEP = 7124 "~ :; ~ .....' ........ i AVIK TVD = 8392 ME = 12316 D ~P = 7722 cc~ '~'~:'~ 9-5/8' C~ SING TVD ~- 8472 MD -- 12460 OEP -- 7842 c=' ,~ .......... TOP LIS aURNE TV[) ~ 8502 b D = 12514 3EP ?: T ~flGET TVI) = 8502 ~ D = 12514 DEP = 788( ~. 9000 W~.HOO ~ ~vn - 8 ~27 MD -- ,~n~o nc~ . o~ 9000 :..~ TD-7' C, kSING POIN -- 81154 MD = 3148 DEP ~oooo .................... . ...... , ............................. ........... , .......................... [oooo o ~ 00o 2000 3000 ~ooo 5000 6000 7000 8000 9000 ~ 00o0 VER~[CRL 5ECT]0N E - N COOROINBTF. S o -3000 -2000 - 1000 0 1000 2000 3000 4000 I I SEC Tl'NR14EUM SEC 5 TI2N R14E UM ~ 1 VD -- 860~ ,, ~ C EP -- 788e' E 916 II 3473 , r..,j® [.-, z I -3000 -2000 -tO00 0 tO00 2000 3000 4000 E - N COOROINRTES E - N COOROINBTES -200 - 1 O0 0 1 O0 200 300 '~00 500 600 ~ I I I I I ! I I I I I I I I [ I I I I I I I I i I I I i ,' / ~689 ,"] /3~'3 /3998 ~3d8 3058 02 -,, 36 M~273/~ /2,9~ /356t 2877 t 3~37 ~ 3234 . 4:389 2 z 769 I I -200 -too 0 'too 200 300 ~0~::~ E - 1,4 COORO I NFITES !~':{ % ~' ' ~'-"' ?/ 600 -3000 z8 0 0 -2000 -1000 E - N COOROINRTES 0 lO00 2000 3000 4000 -3000 -2000 - 1000 0 1000 28 3000 dO00 E - N COOROINRTES 7256 ~59 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - LG! Pad (Wells 2, 4, 6, 8, 10, 12, 14, 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 GRU13/L91 Enclosure If ARCO Alaske, inc. is a Subsidiery o! AtlanticRichlieidCompan¥ I II I I I I I I el ,, i., ~ " (~1. . ~'- _~. I . / d ~ . _ DS L~ ~ I I I · ' (Vl~l.l~ ~P) ARCO LISBURNE FACILIRES ~JECT FL4N[ ~IT ~ · ~ ~ (~,~,z.sil.) ~.W SEC. I~TIIN, RI4E~U~.~AK I ~= 4 ,L__JI ~ ~ 2 · ,,: ~ ~ ~ _ , I.$TATE P~N~ COORDINATES aRE /I ~ALL GEt,lC ~SIT~S ARE // ~SED ON NAD 1927. // // 3.~FSETS TO SECTION LINES A~ C~- // /, PUTED B~ED ~ ~OTRACTED VALUES OF THE / SECTION CORKER POSITIONS. 4. PLANT CO~DI~TES CED 4~T-17212~ SHT ~1~ REV. I. _., I I i a I I B N I LOCATION N $[CTIOfl STATE PLkN[ COORDINATES GEODETIC ~SITION A/9 PLANT COORDINATES , 2 . ~J6~ ~632~ 5976~.53 6~7~4,64 70-~v~.6~- 148-~i3~.8~3, ~.OL 6487,58 4 ~3~ 1644 5~63S5,~ 6~21,13 70-~24.~ ~48'~v37.~74w 8~.09 6487.58 6 I247 16~ 597~L3~9 6~7~.4~ 70'~'24.~9" 1~37.53~ ~.01 6487.33 6 1188 1668 597~1,~ 6~,~ 70'~ '25 ,418" 148'~'37,~8" 8~0,07 6487,50 10 1129 16~ 5976~30,3S 6~,60 70'~25,~" 148'~'~8.228" ~,01 6487,52 ~2' ~070 ~692 5g76~,~ 6~67,07 70'~,S75" Z48'~'38,5~" ~,07 64~.S0 14 10~Z 1704 597~,~ 6~53,57 70-~27,~5~ Z48*~38.g31" ~40,~ 6487.48 ~6 ~3 1716 59767~,TZ 6~40,08 70'~,730, Z48'~3g,282" ~,0~ 6487,49 P CEiV D A~as~a Oil & b~s Ou,;s. bu;:::~tssion I I I I II I I II I II I I I I I II ~~p AS-~l~ WELL LOCATION i HEREEY :ERTiF7 THAT lA. "ROPEPLY '-~~'~k4.ll- LG I PAD LAND SURVEYING iN THE STATE OF ~ *~4~ ~ %*~ r ~ ' '~' SURVEYED FOR: ALASKA AND THAT THiS PLAT RE-~"'~~-- '/~~j- '"",~T ~~ ARCO PRESENTS A LOCATION SURVEY ~DE ~=~~~:~~,'/ I~~11~ '- " f. ~ . ~~St~s ~.~ ~ D~TE: I /24/86 SCALE: 1"=400' BY UE OR UNDER My SUPERVISION, "~.' m 6919~ ~ ''" ;' sHEET:' OF. imm, AND THAT ALL DIMENSIONS AND ~l~. e~ _/~-:~ MS J GS · assoo, ' ' ' OTHER DETAILS ARE CORPECT. ......... m LIST FOR Wm,T, PERMITS ITMM AP~ROVE DATE (1) Fee' ~/~x__-. 7 '~'&g 1. ( 8) ' ~ 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. (3) Adnd_n (g thru 13) (10 and 13) f (4) Casg ~.~.~. (14 thru 22) (23 thru 28) Is the permit fee attached ....... ....................... ............ 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 ................ Is operator the only affected p~.~rty ............... , ................. Can permit be.approved before~ifteen-day wait ...................... Does operator have a bond ~,/force ............ ' ..................... Is a conservation order needed ,. ..................................... Is administrative approv~ n.e.eded ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string Provided ........................................ Will surface casing protect fresh water zones .......... ............. Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings .,.. Will cement' cover all.known'productive horizons .. ~ ........ ~ ......... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable .............................. ,.. (6) OTHER (~hrh 31) (6) Add: Geo logy: Eng ~e~er ing: rev: 07/18/86 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirements ............................................. z~ POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE