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Home My WebLink About195-061Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~--0 ~ / File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] .Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 M E p I ATE IA L U T H IS M A R K W N U I:: I~ E R C:LO~M.DOC ' Memorandum State of Alaska Oil and Gas Conservation Commi~ Cancelled or Expired Permit Action EXAMPLE: Point McIn~re P2-36AXX API# 029-22801-95 Re: This memo will remain at the front of the subject well rde. Our adopted conventions for assigning AP! numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the treatment of these kinds of applications for permit to ddil. 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 remair unchanged. The AP! number and in some instances the well name reflect the number of preexistinl redfiils and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit witi'. an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddii. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9.~ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbenng methods descnbed 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 ~ALASKA~ _~heared rvices riltlng BP Exploration/Arco To: Alaska Oil & Gas Conservation Commission Date: December 21, 1995 From: Terrie Hubble Technical Assistant Subject: Permit #95-61, 18-10AL1 The attempt to drill this multilateral was unsuccessful.. Please cancel the Permit To Drill for this well. The APl Number is 50-029-20818-60, approved on 05/17/95. Thank you. /tlh RECEIV ? DEC 2 2 1995 A.la.ska Oil & G>&s Anchorage BP EXPLORATION ARCO Alaska, Inc. To' Mr. Bob Crandall AOGCC - - RECEIVED Date' June 5, 1995 From: Terry Jordar~ JUN - 5 1995 Naska Oil & Gas Cons. Commission Anchors,i? Subject: DS 18-10A Program & Directional Revisions Following your recent telephone discussions with Gregg Walz, attached are the Applications for Sundry Approvals, the revised directional plans and a revised program summary for DS 18-10A and its well segment DS 18-10AL1. These changes are due to the fact that the original lower target sand of the multi-lateral has been proven to be heavy oil/tar from drill pipe conveyed logs. Because of this, the new multi-lateral directional plan will be a "Y" into the same Zone 1 target. Both legs of the "Y" multi-lateral will be approximately 1000' md and will be approximately 1300' apart at the tip of the "Y". Please see the attached directional plan for more details. If there are any questions or concerns about these revisions, please call Dan Stoltz at 564-4922. Drilling Engineering Supervisor Enclosures CC: Dan Stoltz Dave Nims MB 12-1 Well File MB 12-1 Gregg Walz MB 12-1 Co-Operators, Prudhoe Bay Unit BP Exploration (Alaska), Inc. Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing __ Variance __ Perforate Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4909' NSL, 372' WEL, SEC. 24, T11N, R14E At top of productive interval 5. Type of Well: Development x Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) 45.03 7. Unit or Property name Prudhoe Bay Unit At effective depth 10. 4606' NSL, 1475' WEL, SEC. 14, T11N, R14E (Proposed new location) At total depth 11. 38' NSL, 2123' WEL, SEC. 11, T11N, R14E (Proposed new location) 8. Well number DS 18-10AL1 9. Permit number 95-67 APl number 50- 029-20818-60 Well Segment Field/Pool Prudhoe Bay Field/Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth RECEIVED dUN - 5 1995 Alaska 0il & Gas Cons. Commission Anchors :' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 6/10/95 16. If proposal was verbally approved Name of approver Mr. B. Crandall 6/5/95 Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby ce,,~at the~ and correct to the best of my knowledge. Signed .,~/?,,/'~~(..J Title Drilling Engineer Supervisor ' - co ,ss,oN ON.Y Date Conditions of approval: Notify Commission so representative may witness I Approval Noo...~._ Plug integrity__ BOP Test ~ Location clearance __ I Mechanical Integrity Test Sl&J:)..s_.ec_[U_eln~C:)_rL-rj.r_e6j.~ired 10- ~O "'L'Approved Copy -- urigmai o~giiuu [~y Returned o. ,. avid W. Johnston ~Z"~'/'.~ - Approved by order of the Commission t.,ommiss~oner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE o . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. SU,..,~IARY PROGRAM REVISION W, WELL: DS 18-10A & DS 18-10AL1 RIH and spot 275 sx Class "G" cement plug from 12,932' (TD) to 12,250" md. RIH with rotary assembly and dress off the 17 ppg kick off plug to 12,473' md. CBU. POH. MU steerable BHA w/ 1.75° bent housing motor and 8-1/2" bit. RIH. Directionally drill as per attached plan to 8-1/2" TD at 12,950' md. Circulate hole clean. Shod trip as needed. POH. PU 8-1/2" hole opener and ream to bottom as needed. Circulate hole clean. POH. Run 7" drilling liner with Sperry Sun 7" "LTBS" window to 12,950' md / 8,737' tvd. The "LTBS" window to be at 12,795' md. Cement liner in place with 370 sx Class "G" cement. Unsting from liner top at minimal distance and circulate the long way. POH. RIH w/hydraulic packer setting tool and set liner top packer. POH. Rig up to pull 7" internal sleeve out of "LTBS". RIH with 6" directional assembly. Test casing to 3500 psi for 30 minutes. Directionally drill 6" hole to TD at 13,972' md as per the directional plan. RIH with 6" hole opener if needed. Run 4-1/2" slotted liner from 12,900' to 13,972' md. Install retrievable whipstock into the "LTBS" window. POH. RIH with 4-3/4" directional assembly. Directionally drill 4-3/4" hole to TD at 13,773' md as per the DS 18-10AL1 directional plan. Run 3-1/2" slotted liner from 12,795' to 13,773' md. Retrieve the retrievable whipstock. POH. RIH with 2-1/16" work string into the 4-1/2" slotted liner and circulate the well to sea water. Run the 4-1/2", L-80 completion string with a 3-1/2" straddle assembly. Set packers and test tubing to 2000 psi. ND BOPS and NU tree. Test tree to 5000 psi, test tubing x casing annulus to 3500 psi. REC£1VED Shear RP valve in upper GLM and freeze protect, Set BPV and release rig, JUN --5 1995 Oil & Ga.~ Con~, Commission Ancl~or,-."" Alaska District ' - ........................... Anchorage, AK..99.518 .. (907}- 349- 45.t-1 - - -Fa-x...-~49-.2487 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... Field ........ : PRI/DHOE BAY DS18 -. Computation.,: M~NtMUM--~VA~E ....................................................................................................................... -..:--~B-Te~evat~lonr:-.45-.03..ft ......... · . Prepared ..... : 06/02/95 Section at...: 313.43 Magnetic Dcln .' 29.438 E .. Scale Factor.: 0.. 99. 9~.4.16.0 · Convergence..: '+1.45931665 ANADRILL AKA-DPC APPROVED Units. ....... : FEET .,.S..~r.f.a.ce L~...: 70. 2993.5425 N ......... Surface Long.: 148.44999719 W ' " LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 4909 FSL 372 FEL S24 T11N R14R UM 691373.25 5961488.32 Tie-in/KOP..,: 4606 FSL 1475 ~EL S14 TllN R14E UM 684865.23 5966303.60 BHL .... ' ...... : 38 FSL 2123 FEL Sll T11N R14E UM 684200.00 5967000.00 JUN 0 2 1995 STATION I DENTI F ICAT I ON TIE-I~ END 18/100 CRV TD BOTTOH TARGET PROPOSED W~LL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPT~ ANGLE AZIMUTH BKB S[~B-S DIST 12795 91.00 353.00 8739 8694 8059 12800 91.00 352.19 8739 869% 8063 12900 91.00 334.19 8738 8693 8~49 13000 91.00 316.18. 8736 8691. 8243 13015 91.00 313.43 8736 8691 8262 13015 91.00 313.43 8736 8691 8262 . . 13773 91.00 313.43 8722 8677 9020 8743 8698 INI IIAL _6'g'~, ~_Z_~ RELATIVE-COORDINATES FROM-THE-WELLHEAD 4979.77 N 6383.65 W 4984.2~ N 6384.24 W 5079.56 N 6413.04 W 5161.~1.N 6469.89 W 5172.09 N 6%80.74 W STATE-PLANE Y 684865.23 5966303.60 684864.53 5966308.06 684833'. 32 5966402.61 684774.41 5966482.88 68~763'i.28 5966493.38 TOOL DL/ FACE 100 (TIE 90L 17.98 90h 18,00 90L 18.00 18.00 ..... REC'E 5172.09 N 6480.74 W 684763(, 28 5966493.38 18,00 5692,92 N 7030.97 W 6842001~00 5967000 00 0'.00 - ,: 'IVIED ................................. "" .-_'__:'- ;.-_.. ..... :_l::.'.' .... .._L~-:: ....... -. =.::..-' ..... =_.='.-:_._:-_. ....... _'_, ....... ..: .... -:__.- .... : .................. ~..-..-.-... -.. -'...- · -. ....... -'..._':,:.:. . Alaska 0il & Gas Cong. CommJssJ0R " ....... ~,ncho, .m- . ITl z G') Z ITl ITl (A~adril (c) 95 1810AP82 [tl.52 2:18 FM t} ii ii An~dnj J J SchIumbong~r I iiiii i ii SHARED SERVICES DR];L NS iiii i ii i i i ,, C] TO 13773 5693' 703t I iii I I CLOSURE ' 9047 feet at Azimuth 309.00 ,. ....., .~oo rOECL]NAT~0N,' 29. a38 E ~ ~S~A~E..... ..... :---t--~.n~h .... -2004-e e t- ................................................................... i, .......................................................... ~ ...................... DRAUN '06/02/95 .. I -59o~ ........... A ~ADEI[L ........... AK,~-DpC ..................... , ..... ~ ~l~f~ I~ e...... ................................. j ....... ?1 ,, ~ JJN 0 ~ 1995 '" ...... .................. ~ , ' , ,, 5600 ; ..................................... ~~ I ~ . ~ ' - ~ ....... 54~ : J ECI:IVED i ~ / · ' -~5300 " ~ / ~ ;dUN i. ~ i I ...... , i ~ A!~ )J~ & ~ r... ~ ........ 5200 , - ~ociors .. , . ~ . :. .... , ~, , I ~ : ~ ':: ,~ I ~ : X t ~.- '-- ~ ~ ................................................ 4900 .... .. .~ . .,, .... ~ ............ .~ .... ~.. , . . ' .,. .~ .' " -~ ~~" - , .......~ ' ........ '. ' I: ' "" 4800"" ' " I 7200 7t~ 7000 6900 6800 6700 ~ 6500 6400 6300 6~00 6J00 6000 5900 ~00 5700 ~5600 5500 5400 .... <- NEST ~adrL]! [cl~ 1.q10~82 B1.52 2:22 PH l) .... ITl Z Z ITl ITl .... SHARED A] TTE-[N .t27. 95' BI END ia/i'll0 CR'¥' ' 130i5 C) ID' 13773 sE~ .... VICES DRILLING BKB SECTH [NCL'N 6739 8059 . 9!.00 8735 8262 9t.00 8722 9020' '9t,00 " ! ,4nadr)]] Schlumberger ,, _ DSIB-~OAL./(P8-2) VERTICAL SECTION .VIEW i Section at: 3J3 43 .. i ..... Oep--Sc-ale-..-:---t---tach .... 200-feet.- - ~ . ~T"~ ~ ~K' '~IK' . ..... .? ........ -. ............ , . ..I ........... ANACR!LL AKA-DI ~C J I ...... I .................... ~ ~LL - ~ 18-1~A IP~N ~-21: LE~T ~TE~k ' I : FROM TO ~ MD MD ACTION )~ ' ' ~95' ~30~6' TIE-IN TURN.~3"i~90' JUN 0 ~ 19, I5 : "o~. INC g~.00', F~ AZ 3~3.00"T0 AZ 313,43',. ! I 13e~5' ~773' DRIkk TANGENT 8ECTIO~ TO TD, i : "· ' '~_~ ' z ~ ~. HOLD INC 9tOO', ON'~ 3~3A3", I · ' FRM 87~6' ~D TO 672~ ~D ~ ........... ~-- ~ ~ ~ .... ~ ..... '-- =" ~>~ ~ ::;.~: :z: .... i ; .......... ~ ..... ..... ~ i ! ' :--==, · - ~ .... i. . i .., ~ ., , · . ' ] ...... "' i ' ; jtj~ -5~9~5 ~ ~ ~c~or~?' ! ' '' ! .............. · -.:' "-.'-.-.' ........... .... i'--' ':-- ' ' - .-- 7600 7700 7800 7900 8000 BI00 8200 8300 8400 8500 8600 8700 eD00 5900 9000 9100 9200 9300 9400 ....... section Departure (An~dr~l) 0:J93 1810AP82 81.52 ?. 19 PN 11 :3) Z ITl Z m ITl TONY KNOWI. E$, GOVF. I~NOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 16, 1995 ' ~ , Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 : Anchorage, AK 99519-6612 ; Re= Prudhoe Bay Unit 18-10All ARCO Alaska, Inc. Permit No. 95-61 Sur. Loc. 4909'NSL, 372'WEL, Sec. 24, TllN, R14E, UM Btmnhole Loc. 5208'NSL, 2071'WEL, Sec. 14, TllN, R14E, UM Dear Mr. Jordan= Enclosed is the approved application for permit to drill the above referenced well. ~ The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This permit is for a new segment from existing well DS 18-10A Permit No. 95-60, API NO. 50-029-20818-01. Production should continue to be reported as a function of the original well identifier. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at · David W. ~ohnston ~ ~ B~ ORDER OF ISSION dlf/Enclosures i CC g Department of Fish & G~me, Habitat Section w/o encl. - Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 Type of work Drill [] Redrill E'lllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF11 Service [] Development Gas [] Single Zone [] Multiple Zone [] I 2. Name of Operator 5. Datum Elevation (DF or KB) i10. Field and Pool ARCO Alaska, Inc. KBE = 45.93' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 28307 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 4909' NSL, 372' WEL, SEC. 24, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4286'NSL, 1418' WEL, SEC. 14, T11N, R14E 18-10AL1 U-630610 At total depth 9. Approximate spud date Amount 5208' NSL, 2071' WEL, SEC. 14, T11N, R14E 5/20/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28302-72' feet No close approach feet 2560 13619' MD/8706' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~24o5, feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD -I-VD (include stage data) 4-3/4" 3-1/2" 9.3# L-80 NSCT 1214' 12405' 8699' 13619' 8706' Uncemented slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~'" Present well condition summary ~,~ .--/ir Total depth: measured 12250 feet Plugs (measured) true vertical 8854 feet Effective depth' measured 12205 feet Junk (measured) j~,~¥,~ 0~% .~.j~Ch0t'a' '~'Cas Cons. Co~m~$~'ton true vertical 8818 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 79' 20" 1975 # Polesett 79' 79' Surface 2534' 13-3/8" 2120 sx Fondu & 2534' 2452' Intermediate 400 sx "C" Production 11423' 9-5/8" 500 sx "G'Y51 bbls "C" 11423' 8166' L i n e r 1124' 7" 350 sx Class "G" 11126'- 12250' 7948'-8808' Perforation depth: measured 12020'-12035', 12072'-12082', 12090'-12110', 12135'-12145' true vertical 8624'-8636', 8666'-8673', 8680'-8696', 8716'-8724' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 121._ I hereby certify that t,he~ foregoing is true and correct to the best of my knowledge /)~igned "~'~.~ "../' ~~ Title Drillin~l En~lineer Supervisor Date ~- ( I Commission Use Only Permit Number -'~;z.~,~Ni~r~/"~.,,r,...¢~,,.,,.¢'.,,¢ Approval date See cover letter ~',.~.--~',,,, 150- O 2,~-. ~--O~'/~-~c3 I ~-///~7//'~t5-- for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes ~ No Hydrogen sulfide measures Yil Yes [] No Directional survey requirecl 'J~ Yes [] No Required working pressure for BOPE CI2M; 1-13M; 'I~5M; I-I10M; r-115M; Other: Original Sign~(::l ~y by order of//' Approved by David W. Johnstor, Commissioner me commission Pate~%"/~-~/c?,~ Form 10-401 Rev. 12-1-85 Submit in plicate I Well Name: IDS 18-10AL Redrill Plan Summary Type of Redrill (producer or injector): I Producer Surface Location: 4909 FSL, 372 FEL, S24, T1 IN, R14E UM Target Location: 4286 FSL, 1418 FEL, S14, T11N, R14E UM Bottom Hole Location: 5208 FSL, 2071 FEL, S14 TI IN, R14E, UM I AFENumber: 14J0297 I ]Rig: I Nabors2ES I I Estimated Start Date: I May 20, 95 I I Operating days to complete: I 25 I [MD: [ 13619 ] [TVD: 18706 I [KBE: 145.93 I I Well Design (conventional, slimhole, etc.): I multilateral extension I Objective: I The objective of the proposed plan is to install a multilateral extension to I I I DS18-10a. I Mud Program: A 10.0 - 10.20 ppg Biozan polymer/KC1 water based mud will be used. Special design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (g/FY) GEL GEL cc/30min (%) (%) Horiz. 9.0 10 50 23 29 7-8 0 2 Directional: IKOP: I 12405' MD I Maximum Hole Angle: 190° at the window Close Approach Well: I NONE Casing/Tubing Program: MAY -" 4 ]995 Oil & Gas Cons. Commission Anchora. Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 4-3/4" 3.5" Slotted L-80 NSCT 1214 12405/8699 13619/8706 No cement is required. Cement Calculations: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and mud fluid system schematics on file with AOGCC. Hazards and Contingency Plans: Lost circulation is not expected but it is possible. The well trajectory is carefully planned to avoid major faults that would cause massive losses.. However, lost circulation material and procedures will be reviewed prior to drilling this well. SUMMARY PROCEDURE: DS18-10a Drill and Complete Rig-Work: 1. 2. , RECEIVED MAY - 4 1995 ~iaska 0il & Gas Cons. Commission Move in drilti.ng rig. _ ,qnch0ra. ~ Pull BPV. Circ~te diesel freeze protection cap~"~well and recover for future use. Monito~nd insure well is dead and~ble. Install an FMC BPV an"d,.test same, vis~afinulus, to 1000 psi. Remove the production tree. Inspect h4.nning t~ds on the tubing hanger for type and condition. (Th rea~l /8" LH Acme). DS18-10a Drill and Complete Rig-Work: 1. Move in drilling rig. 2. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Monitor and insure well is dead and stable. . Install an FMC BPV and test same, via annulus, to 1000 psi. Remove the production tree. Inspect running threads on the tubing hanger for type and condition. (Threads should be 6-1/8" LH Acme). . NU BOPE. Test below the blind rams to 1000 psi to insure base flange seal. Pull the BPV, install an FMC tree test plug, and perform a State BOPE test. Remove the tree test plug. . , Pull and lay down the 4-1/2" tubing from the cut to surface. Inspect for NORM prior to removing the tubing from location. P/U a Millmaster 7200-2 section mill and RIH. Cut a 50' section from approximately 10805 - 10855'. POOH. 9-5/8" casing and cementing summaries are attached. , RIH with mule shoe on 4.5" DP and spot a balanced cement kick-off plug (180 cubic feet minimum) through the muleshoe from 100' below the base of the section to ,-, 200' above the top of the section. 8. Change out 9-5/8" pack-off. ! Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Prior to kickoff circulate hole clean so that it is free of cement. Kickoff and directionally drill to the target at 8685 TVDss and 90° using GR / MWD only. Notify the Lisburne DS supervisor to shut-in L2-25 while drilling between the depths of 11154-12477. This well presents a close approach, and should be shut-in while DS18-10a is in proximity. DP convey GR / NEU / Sonic formation evaluation logs from the top of the Put River sand to TD. 10. Run a 7" 29 # L-80 liner assembly to bottom in the 8-1/2" hole and space the Baker rotating liner hanger (L-80) and top isolation packer (L-80) about 150' up inside the 9-5/8" casing. Refer to Standard recommended practices for liner running procedure. Include in the liner the Sperry-Sun LTBS precut window and space out same so that the window is within the multilateral extension target sand (position of LTBS precut window is prognosed to be 12405' MD/~3~., EIVED MAY - 4 1995 Oil & Gas Cons° Commission Anchora -~ 11. 12. 13. 14. 15. 16. 17. 18. 19. TVD SS.) RIH to bottom with the liner. The orientation of the window will not be checked prior to cementing. Insure that Baker has available a wiper plug suitable for cementing through the protective sleeve across the Sperry LTBS collar. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. Set liner hanger / packer with 4200 psi. Reverse out clean. Re-test BOP's as needed. MU spear, muleshoe, and MWD tool and RIH. Engage spear/muleshoe to align BHA w/the LTBS collar; MWD toolface will reflect the orientation of the LTBS. PU and shear out the protective sleeve from across the LTBS collar, POH. Make any required adjustments to the directional plan based on the orientation of the precut window. Should the orientation of the window be unsuitable, the lateral extension will not be drilled. Run in with 6'_' steerable drilling assembly with GR / MWD on 4-1/2" x 3-1/2" drillpipe. Test casing to 3500 psi for 15 min. before drilling out float shoe and 10' of new hole. Displace well with non-damaging (FIo-Pro) drilling fluid. Drill approximately 989 of 6" hole to TD as per on site Geologist. Short trip and condition the hole (to run a slotted liner) with the drilling assembly used to TD the well. Should any hole problems occur during the short trip, POH and PU a 6" hole-opener assembly to finish conditioning the hole. Install a 4-1/2" NT-80S slotted liner with 4-1/2" X 7" TIW SS packer. Refer to the attached procedure for slotted liner installation. It is not necessary to PU the 2-1/16" circulation string at this time, Space out the packer to be set from 50-100' of the 7" liner shoe. The packer should not be set above the LTBS precut window, POH. If the L1 leg of the well is not drilled, proceed to step 25 of the L1 drilling procedure. RECEIVED MAY - 4 1995 AJ~ska 0il & Gas Cons. Commission ~,nchora ~ DS18-10AL1 Drilling Procedure 19. PU the Sperry-Sun LTBS whipstock assembly on DP and RIH. Engage whipstock into the LTBS profile as per the Sperry-Sun service engineer on location. Detailed procedures and equipment description and function are attached. Release the running tool and POH. 20. RIH with 4-3/4" steerable drilling assembly with GR / MWD on 4-1/2" x 3-1/2" x 2-7/8" drillpipe. Orient to align the toolface to the whipstock (based on SS gyro result) and kick-off (sliding) against the whipstock. Slide continuously for a minimum of 20' to insure that sufficient displacement from the 7" casing is obtained (1-2'). After 20' of sliding, toolface can be adjusted to align the well to target as required. Drill approximately 1214' of 4-3/4" hole to TD as per onsite geologist. 21. Short trip and condition the hole (for running a 3-1/2" slotted liner) with the drilling assembly used to TD the well. Should any hole problems occur during the short trip, POH and PU a 4-3/4" hole- opener assembly to finish conditioning the hole. Insure that Tool Service has a 4-3/4" hole opener available should one be required. POH. 22. Install a 3-1/2" slotted liner using the Sperry-Sun LTBS hanger assembly. It will not be necessary to displace the drilling fluid from the 4-3/4" hole section. 23. MU the Sperry whipstock retrieving tool and retrieve the whipstock. POH. 24. MU 2-1/16" circulation string (with polished nipple and swab cups) on 3-1/2" x 4-1/2" DP and RIH. Engage polished nipple into pack-off bushing and circulate until sea water returns are obtained at surface. Recover the Flopro for re-use. Unsting from the pack-off bushing and CBU. Spot 1 liner volume of sea water treated w/4 ppb lithium hypo chlorite breaker, POH and position polished nipple just above the TIW SS packer. Continue displacing well to sea water until returns meet 100 mg/I clarity standard. POH and LDDP. 25. 26. Run the 4-1/2" L-80 straddle completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Set packer and test tubing to 4000 psi f/30 min. and test annulus to 2000 psi prior to ND. Install a BPV. Remove BOP's. RECEIVED 0il & Gas Cons. Commission Anchora ~ 27. 28. 29. 30. 31. Install and test the production tree to 2000 psi (against the RHC plug set in tailpipe XN nipple) f/10 min. Pull the BPV and install the tree test plug and test the tree to 5000 psi. Remove the tree test plug. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production ~AAY - 4 1995 Gas Cons. Commission Anchora ~ SHARED SERVICES DRILLINO' i i .BKB .SE[:!N .]t~C!N 8699 7376 BO.OO 8706 7459 90.00 8706 7459 ~.O0 _ _ i _ mil /fnad/"~ ]_l Schlumberger DStD-tOAL~ (PO6) ....... VERTICAL SECTION VIEW D) TO 1~19 870r, 65~9 ~.eO Section at: 324 69 5000 5~.~3 550~ 5750 6000 62_50 6500 B750 ?001} 7250 7500 7750 BO08 8;]50 8500 8750 9000 9250 9500 · section Departure pnodrill Icig3 tSlO~l~O2 01.52 .rt 07 ~,K 2) I i i i - i i~i iiii! i ~ SHAREiD 'SERVICES ..... DRILiLING .... i i ill ..... llllll i ...... iii . 'os 8 ( 6) ~ ~,o ~,~ ~,~, ' ,, A] TiS-IN BUILD :S/~00~ ~405 45B~ 6278 ~ PLAN. VIEW ..... j ' D} TO ~ :38:9 55B~ 6979 6LOSUREI' - Bg3? feet at Az~u[h 308_65 DECLINATION.' 2g 477 E ' I I FEAS~BILI~'P~N hUN :~ i ', EXEC:UTION ,,~o---i, ................ -,, .... ,.': ~, CU~N' ~ ~, ~ ~' ......... i-" ..... ' ! i I s~so .............. ~ ........ ~. ~ ................... ! ..... ~ , r I ' ' , , :.__ ,, 5ooo-- -" I i .......~ ~ ~ ~. ' ..... , i 4750- ' ; ................. ' ~ ...................... ~500 . . - .... . , i : ; : , 4~so , ~ ......... ~ ~ ...... . i ~ ........................... ~ · ~ i N ~ ! '~. ! ~ . ~ % * ~ ........ 4000-- i i ~ ; : ': : '. '' I ~ x~ I ' ' : 3750~ ........... F; ................. i ~ ~ - ,, · ' I : ~ . ~' ..1 ,' A~as~ & 6asCoas. Co mission: ,,,,,~ 3000 ~ ~7~0 - [~ .... ~ ~ -.- ~ ....~ ~ .... ~ .... ; ..... J ........ '~ : ,, ~oo I " I ~ I I i~ , -'- ~00~ 7750 7500' 7~50 7~00 6753' 8500 6250 5~00 5750 j 5503 5250. 5000 4750 4500 ~. ~ , <- WEST :;VELL PERMIT CHECKLIST COM~m~ ~f~__ ~ ~NI~ CLASS /9._.~. /-~.'/ ,,~,~, ,~'~ ,~_,6'~: /~-/~d~ P~o~: e~p [] ~ev [] redrn [] se=,, [] ~r ~.oL ~.~ ??C~ ~=# //~,__¢,-, o~o~ s,,o~ ~,0 ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permitcan be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ................ i§. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor a surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all know1% productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ ._~_~ .... 26. BOPE press rating adequate; test to ~~ psig.~-- 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/) Data presented on potential overpressure zones. .... Y N/ 31. Seismic analysis 9f shall°w gas z°nes .......... y/ /.,~j; ~. 32. . . 33. Seabed condition survey (if off-shore) ......... y N 34. Contact name/phone for weekly progress reports .... /Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB -C~:~-; c) HOW/~o - A:%FORMStcheklist rev 03/94