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Home My WebLink About193-176· · XHVZE Pages NOT Scanned in this Well History File 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. File Number of Well HiStory File PAGES TO DELETE RESCAN Complete 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 · n Other COMMENTS: Scanned by~"~lDiann~ ~ncent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 M p L A T E T H I= IA L U N D IS M ARK I~ ~ W C:LORI~ILM.DOC Memorandum To: Well File: State of Alaska Oil and Gas Conservation Commission AU.,1 Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well f'de. 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 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 remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddils and or muitilaterais 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 ddil. The AP! 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 AP! numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR .,,.. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 7-27A ARCO Alaska, Inc. Permit No. 93-176 Sur. Loc. 952'SNL, 497'EWL, Sec. 34, TllN, R14E, UM Btmnhole Loc. 3684'NSL, 693'WEL, Sec. 28, TllN, R14E, UM Dear Mr. Jordan: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated November 30, 1993 are in effect for this revision. David W. Jo~ston ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc ° Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl printed on recycled pal:mr STATE Of ALASKA '~'"~ ALASKA~OlL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill EIIlb. Type of well. Exploratoryl-! Stratigraphic Test [] Development Oil [] Re-Entry [] Deepeni-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 56' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28309 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 Mc 25.o2s) 952' SNL, 497' EWL, SEC. 34, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2744' NSL, 365' WEL, SEC. 28, T11N, R14E 7-27A U-630610 At total depth 9. Approximate spud date Amount 3684' NSL, 693' WEL, SEC. 28, T11N, R14E 9/1/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVO) property line ADL 28306-1596' feet No close approach feet 2560 11207' MD/9016' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ^^c 25.o35 (e)(2)) Kickoff depth 88oo feet Maximum hole angle 9o o =Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole ' .Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8.1/2" '7" 29# ¥T-80S NSCC 980' 8650' 7900' 9630' 8710' 8-1/2" 7" 29# 13CR NSCC 580' 9630' 8710' 10210' 9016' 350 sx Class "G" 6" 4-1/2" 12.6~ 13CR NSCT 1027' 10180' 9016' 11207' 9016' 19. To be completed for Redrill, Re-entry, and Deepen Operations. R ~' ~ ~ ~V ~ I~) Present well condition summary Total depth: measured 10145 feet Plugs (measured) AU(~ '~ ~- 't994 true vertical 9133 feet Effective depth' measured 10095 feet Junk (measured) ~ D[[ & Gas Cons. Commission --~, _Anchorage true vertical 9091 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 2892 # Poleset 110' 110' Surface 3924' 13-3/8" 3200 sx CS III & 3981' 3896' Intermediate 600 sx "G" Production 9336' 9-5/8" 875 sx Class "G" 9393' 8497' Liner ~ 1053' 5-1/2" 475 sx Class "G" 10140' 9129' Perforation depth: measured None true vertical None 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements I-! 21. I hereby cert. ify tha. t,,the foj'egoing is true and correct to the best of my knowledge Signed ..~(.~/ /.~~¢.- Title Drilling Enginoer Supervisor Date ~-,t.-0~l ( ] Commission Use Only Permit Number "-/ IAPI number _ / _ IApproval date ISee cover letter ~,~ .-//7~' 150- c~2.-.?--.~--~ 7~-~'~/'-~3~/ I ~",_~)-,. ~.,.,~' Ifor other requirements Conditions of approval Samples required [] Yes 'j~ No Mud ICg reqdi-red [] Yes [~ No Hydrogen sulfide measures [] Yes 1~ No Directional survey requ~reo j~ Yes [] NO Required working pressure for BOPE 1-12M; 1-13M; 13~.5M; []1OM; []15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner [ne comm,ssion_ .Da!e.g,.//,'"?/?' ~ Form 10-401 Rev. 12-1-85 Submit in triplicate BP EXPLORATION ARCO Alaska, Inc. To: David W. Johnston, Chairman Date' 8/10/94 AOGCC 3001 Porcupine Dr. Anchorage, Ak. 99501-3192 Dear Commissioner Johnston: Enclosed is a revised permit for DS 7-27A changing the bottom hole location. The original permit (93-176) was approved on November 30, 1993. Res. pectfully, ,~ ~arl~n Sloa~ i'Well Name: IDS 7-27A Redrill Plan Summary I Type of Redrill (producer or injector): I PRODUCER I ISurface Location: Target Location: Bottom Hole Location: 4327 FSL 4783 FEL S34 TllN R14E 2744 FSL 365 FEL S28 TllN R14E 3684 FSL 693 FEL S28 TllN R14E I AFE Number: 1 4J0227 I I Estimated Start Date: I 9/1/94 IMD: Ill,207' I I Well Design (conventional, slimhole, etc.): I Rig: INABORS 2ES I Operating days to complete: 1 32 I TVD: 1901~' ~l II~E: I ~' I Conventional, horizontal Objective: The objective of the 7-27i redrill is to convert the well from a mid-field waterflood injector to a producer by drilling a horizontal hole near the current BHL The proposed redrill BHL will be 1247' northwest of the original BHL, outside of the estimated sea water injection flood front. The horizontal section will run for 1000' through the expected light oil column. Mud Program: A 9.8 -10.4 ppg Biozan,,polymer/KC1 water based mud will be used. I Special design 1 6 ' horiZontal hole in Sadlerochit Zone 1 will use a 9.0 - 9.2 ppg ZanvisI considerations I polymer system after running and cementing the 7" liner at the target. Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) 7980' 9.8 10 15 5 10 10 0 5 to to to to to to to to to 9016' 10.4 18 30 15 30 5 0 8 '9016' 9.0 8 45 18 22 6 0 0 tO tO tO tO tO tO tO tO tO 9016' 9.2 10 55 24 28 7 0 2.5 Oil & Gas Cons. Gommisa~on Redrill Plan Summary Page 1 Directional: I KOP: ! 8800' MD I Maximum HOle Angle: 90° Close Approach Well: ~NONE The above listed wells will be secured during the close approach. Casin /Tubin~ ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# NT-80S nscc 980' 8650'/7900' 9630'/8710' 8.5" 7" 29# NT80 13cr nscc 580' 9630'/8710' 10210'/9016' 6" 4.5" Slot 12.6g 13CR nsct 1027' 10180'/9016' 11207'/9016' Tubin~ 4.5" 12.6g . NT-80 nsct 9650' 0/0' 9650'/8720' Tubin[[ 4.5" 12.6g 13CR nsct 238' 9650'/8720' 9888'/8911' Cement Calculations: I Liner Size: 17'' 29#/ft I Basis:[ 50qo open hole ex':ess, 80' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 350 sxs of Class G Blend @ 1.18 ft3/sx 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, BOPE and mud fluid system schematics on file with AOGCC. Redrill Plan Summary Page 2 Because of the special circumstances we will have to rig down the tree and rig up the BOP in one of the following ways: ao Bleed down all the pressure from the tubing and annuli side. Observe well for 10 minutes. If the pressure does not built up install BPV. R/D Tree and R/U BOP Stack. THIS WILL REQUIRE A WRITTEN APPROVAL FROM THE DRILLING SUPERINTENDENT AS IT IS IN VIOLATION OF THE PBD POLICY. b. R/D Tree above the Master valve. Install a x/o addapter ( 7-1/16" x 13-5/8" and R/U BOP Stack. We will most likely have to omit one set of rams due to the height. After fishing operations are completed and well secured, we will then R/D master valve and R/U complete BOP Stack prior to proceeding with the sidetrack. Redrill Plan Summary Page 3 SUMMARY PROCEDURE: 11a. 20. 21. 22. 23. 24. 1. Pre-rig work: The coiled tubing fish running the length of the production tubing prevents wirelining for pre-rig work. The work will be limited to setting a BPV, removing the wellhouse and flowline, and testing the intermediate casing pack-off to 5000 psi. 2. Move in workover rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. 3. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. 4. Install a BPV and test tree plug. Rremove the production tree. 5. Install BOP's and test to 5000 psi. Remove the test plug and BPV. 6. Pull and lay down the 7"x §-1/2" tubing with coiled tubing fish. 7. Set a 9-5/8"drillable bridge plug/cement retainer at about .~_{~)_0.~I~. 8. Replace the 9-5/8" casing pack-off if needed. 9 Spot a 18 ppg pill on bottom and cut a 50' section in the 9-5/8" casing. 10. Spot a balanced cement kick-off plug (165 cubic feet minimum) through open-ended drillpipe from 100' below the base of the section to 200' above the top of the section. 11. Run in with an {~-1/2" steerable drilling assembly with GR / Directional and dress the cement to 5' below the section top. Kickoff and drill to the target at 8970'ss as per the directional plan. Run MWD Density/Neutron/Resistivity if it doesn't interfere with directional work. Drillpipe-convey GR-Density-Neutron E-line logs through the reservoir section if not obtained with MWD. 12. Run 8-1/2" BHA without MWD forwiper tdp to condition the hole for the liner. 13. Run a 7" 29 # 13-Cr x L-80 liner assembly to bottom in the 8-1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. 14. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the shoe volume, lap volume and 150' excess on top of the liner with drillpipe in the hole. 15. Clean-out liner and float equipment and 5' of new hole. 16. Change mud to MI "FIo-Pro" Xanvis system. 17. Drill 1000' of 6" hole with GR / Directional to TD at 8953' TVDss. CBU. 18. Make a conditioning trip with a 6" hole-opener for the open hole section with a 7" casing scraper spaced to clean the liner. 19. Install a 4-1/2" L-80 slotted liner with 7" TIW packer / hanger. Run in on 4-1/2" x 3-1/2" drillpipe with a 2-1/16" wash string inside the slotted liner. Space packer / hanger to be set within 100' of the 7" liner shoe. Please see attached well plan addendum and slotted liner running procedure for further details. Position packer 100' above the 7" liner shoe and circulate. Set the packer and test the setting. Release from the packer / hanger and displace the drilling fluid with filtered seawater but no corrosion inhibitor. Spot the breaker inside the slotted liner. Pull the wash string up just above the hanger and circulate well clean with filtered and inhibited seawater. Pull out of the hole and lay down the wash string. Retest 9-5/8" wellhead packoff and replace as needed. Rig up wireline and perforate ___10' of Zone 2 sand. Run the 4-1/2" L-80 x 13-Cr straddle tailpipe assembly, with 9-5/8" packer on drillpipe. Locate the top of the liner such that the blast rings are position across the perforated interval. Set and test the packer. POOH and LD DP. Redrill Plan Summary Page 4 25. 26. 27. 28. 29. 30. 31. Pull wear ring. Run 4-1/2" L-80 tubing, space out the tubing into seal assembly, attach the tubing hanger, and land the tubing. Pressure test the tubing and annulus as per standard procedure. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. 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 Redrill Plan Summary Page 5 .... pRUBFi0E"BAy .... D'RTLL'T"NG GROUp I IIII I II IIIII I II III I I I I iii II1! III II I iii i I Marker Identification MD BKB SECTN INCLN A} TIE-IN 8800 7980 2923 29.08 8) ENO 6/t00 CURVE 8866 8038 2955 28~84 C) BUILD 12/lO0 9701 8769 3358 28.84 D) ....... TARGET ....... 10211 90~6 3776 90.00 E) END t2/J00 BUILD ~021~ 9016 3776 90.00 F) TD lJ207 9016 4773 90.00 i Anadri'll Schlumberger DS 07-27A (P7) VERTICAL SECTION VIEW Section at: 340.68 TVD Scale.' 1 inch = 400 feet Dep Sca]e.' 1 inch : 400.feet Drawn ..... ' 08/02/94 1_ i i i AnaOrill (c)g3 07~7Ap7 B'I.§2 5:25 Pt4 1) 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 Section Departure PRUDHOE BAY Marker Identification MD N/S E/W A) TIE-IN 8800 2891 590 A B) END 6/100 CURVE 8866 2922 599 C) BUILD 12/100 9701 3302 731 DJ ....... TARGET ....... 10211 3697 870 E) END 12/100 BUILD 10211 3697 870 F) TD 11207 4637 1199 DRTLLTNG DS GROUP 07-27A (P7) PLAN VIEW CLOSURE ..... : 4790 feet at Azimuth 345.50 DECLINATION.: 29.960 E SCALE ....... : 1 inch : 800 feet' DRAWN ....... : 08/02/94 AnadrY]] Sch2umberger 2800 2400 2000 1600 1200 800 400 0 400 BO0 1200 1600 2000 2400 2800 <- WEST · EAST -> (AnaOril] (c)g3 0727AP7 B1.52 6:13 PN I) ALASKA OIL AND GAS CONSERVATION COMMISSION November 30, 1993 'WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Russ Strickland Drilling Engineer .Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 7-27A ARCO Alaska, Inc. Permit No: 93-176 Sur. Loc. 952'SNL, 497'EWL, Sec. 34, TllN, R14E, UM Btmhole Loc. 3542'NSL, 752'WEL, Sec. 28, TllN, R14E, UM Dear Mr. Strickland: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redril1 does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) 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 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~"~! ALASKA 0IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ia. Type of work Drill [] Redrill ClJlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenDI Service I-i Development Gas [] Single Zone I-! Multiple Zone 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. KBE = 56' feet Prudhoe Bay Field/Prudhoe 3. Address 6, Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 2850~ 4. Location of well at surface 7. Unit or property Name I11. TYpe Bond(-e 20 AAC 25.025) 952' SNL, 497' EWL, SEC. 34, T11N, R14E pru. dhoe Bay Unit At top of productive interval 8. Well number Number 2578' NSL, 485' WEL, SEC. 28, T11N, R14E 7-27A U-630610 At total depth !9. Approximate spud date Amount 3542' NSL, 752' WEL, SEC. 28, T11N, R14E 12/4/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28306-1736' feet No close approach feet 2560 11252' MD~9009' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 Mc 2s.o35 Kickoff depth 9~ feet Maximum hole angle85so' o Maximum sudace 3330 psig At total depth (TVD) ~00'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" 7" 29# VT-80S NSCC 1100' 8400' 7575' 9500' 8653' 8-1/2" 7" 29~ 13CR NSCC 752' 9500' 8653' 10252' 9026' 350 sx Class "G" 6" 4-1/2" 12.6# VT80-S NSCT 1102' 10150' 9023' 11252' 9009' 19. To be completed for Redrili, Re-entry, and Deepen Operations. Present well condition summary NOV -9 199;5 Total depth: measured 10145 feet Plugs (measured) true vertical 9133 feet N~$ka 0il & Gas Cons. C0mmissio~ Effective depth: measured 10095 feet Junk (measured) Altchorage true vertical 9091 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 2892 # Poleset 110' 110' Surface 3924' 13-3/8" 3200 sx CS III & 3981' 3896' Intermediate 600 sx "G" ProduCtion 9336' 9-5/8" 875 sx Class "G". 9393' 8497' Liner 1053' 5-1/2" 475 sx Class "G" 10140' 9129' Perforation depth: measured None true vertical None ~)0. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth 'plot [] Refraction analysis[] Seabed report• 20 AAC 25.050 requirements[] 21. I hereby ~ify that~true and Correct to the best of my knowledge Signed Title DrillingEngineerSupervisor Commission Use Only Number IAPI number IApproval date ISee cover letter PermiT~-/'7~~'' J50-0~ ~'- ~_./,~.5z'5~'-<3 / ] ///_-~,..~_.~ Jfor other requirements Conditions of approval Samples required [] Yes ~ No Mud log required [] Yes .IR No Hydrogen sulfide measures [] Yes I~ No Directional survey requ~re~ E'! Yes [] No Required working pressure for BOPE CI2M; CI3M; J;~I.5M; I'-I10M; ["!15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner [ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate I WellName: IDS 7-27A Redrill Plan Summary i Type of Redrili (producer or injector):" I PRODUCER I Surface Location: fTarget Location: Bottom Hole LOcatiofi: 4327 FSL 4783 FEL S34 T1 IN R14E 2578 FSL 485 FEL S28 TllN R14E 3542 FSL 752 FEL S28 TllN R14E lAFE Number: I 4J0227 I IRig,i I NABORS 2ES [Estimated's'~art Date: ] 12/4/93 ] Opei-afing days to complete: ,! 32 IMD: 111,252' I I TVD: 1'9009' fikG'I [KBE: 156' Will Design (conventional, slimhole, etc.): ObjeCtiVe'i Conventional, horizontal The objective of the 7-27i redrili is to COnvert the well from a mid-field waterflood injector to a producer by drilling a horizontal hole near the current BHL. The proposed reddll BHL will be 375' northwest of the original BHL, outside of the estimated sea water injection flood front. The horizontal section will run for 1000' and cut up throUgh 20' TVD of the e..,xpected light oil column... . ........ Mud Program: A 9.8 -10.4. pp~ Biozan po!¥me.r/KC1 water based mud will be Used. I Special design ' ' ' ' ' considerations I .0-the7" liner9'i'2at the'i~Pgtarget.Zanvis · ... "' Depth Density 'PV YP INT '10MIN FL" OIL soLIDS (TVD) (PPG) (CP) (#/FT) --GEL ..... GEL...cc/30min (%)..~ (%) 7763' ..9.8 10 15 5 10 10" 0 5 to to to to to to t° to to 9026' 10.4 18' 30 15 ' 30' 5 '" 0 "8 · 90~6" '9.0 8 '-'45 18 22 6 0 .... 0 tO tO tO tO tO tO tO tO tO 9009' 9.2 10 55 24 28 7 0 2.5 RECEIVED NOV - 9 199;) Oil & Gas Cons. ~mml~sion Anchorage Redrill Plan Summary Page 1 'Directional: ~ I'''g°~': I ~as0' MD, 7763' TVD-bkb Maximum Hole Angle: 1 91 o Close. Approach Well: I NON The above listed wells will be secured during the Close approach. Casin/Tubin: '___ ram: Hole Size Csg/ Wt/Ft Grade Corm Length Top Btm Tb§ O.D. MD/TVD MD/TVD 8.'5" 7" 29# NT-80S nscc 1100' 8400'/7575' 9500'8653' 8.5" 7" 29# NT80 13ct nscc 752' 9500'/8653' 10252'/90~6' 6" 4.5" slot 12.6g NT-80S nsct 1102' 1015079023' 11252'/9009' ..... Tubin[~ ..... 4.5" 12.6g NT,80 nsct 9600' 0/0' 9600'/8747' ..Tubin~ 3.5" 9.2# NT-80 - -- ' nset ........... 550' - ~ -.9600'/87'47' 10150'/90.23' ~ . Cement Calculations: ' I Liher Size: ] 7" 29#/ft Basis:[ 50qo open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above line~' with DP.. Total Cement Volume: ' 350 sxs of Class G Blend @ 1.18 ft3/sx Well Control: ..... ' . Well control equipment consisting of 5 .000~... Psi W~.Pi' pipe rams, blind rams~' and annular preventer will be installed and is capable of handling'maximum'potential surface pressures. Diverter, BOPE and mud fluid system schematiCS'on file with AOGCC. · Redrill Plan Summary RECEIVED NOV - 9 199) Alaska Oil & Gas Cons. Commission Anchorage .. . Page 2 SUMMARY PROCEDURE: · · . 4. 5. 6. 7. 8. 9 10. 11. 11a. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Pre-rig work: The coiled tubing fish running the length of the production tubing prevents wirelining for pre-rig work. The work will be limited to setting a BPV, removing the wellhouse and flowline, and testing the intermediate casing pack-off to 5000 psi. Move in workover rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and test tree plug. Rremove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 7"x 5-1/2" tubing with coiled tubing fish. Set a 9~5/8"drillable bridge plug/cement retainer at about 8800' MD. Replace the 9-5/8" casing pack-off if needed. Spot a 18 ppg pill on bottom and cut a 50' section in the 9-5/8" casing. Spot a balanced cement kick-off plug (165 cubic feet minimum) through open-ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly with GR / Directional and dress the cement to 5' below the section top. Kickoff and drill to the target at 8970'ss as per the directional plan. Run MWD Density/Neutron/Resistivity if it doesn't interfere with directional work. Drillpipe-convey GR-Density-Neutron E-line logs through the reservoir section if not obtained with MWD. Run 8-1/2" BHA without MWD for Wiper tdp'to condition the hole for the liner. Run a 7" 29 # 13-Cr x L-80 liner assembly to bottom in the 8'1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the shoe volume, lap volume and 150' excess on top of the liner with drillpipe in the hole. Clean-out liner and float equipment and 5' of new hole. Change mud to MI "FIo-Pro" Xanvis sYstem. Drill 1000' of 6" hole with GR / Directional to TD at 8953' TVDss. CBU. Make a conditioning trip with a 6', hole-0Pener for the open hole section with a 7" casing scraper spaced to clean the liner. Install a 4.-1/2" L-80 slotted liner'.'With 7', TIW.packer / hanger. RUn in on 4-1/2" x 3-1/2" drillpipe with a 2-1/16" wash string inSide'the slotted liner. Space packer/ hanger to be set within 100' of the' 7" liner shOe. Please see attached well plan addendum and slotted liner runnii~g Procedure for further details. Position packer 100' above the 71' liner s.hoe and circulate. Set the packer and test the setting. Release fr°mthe packer / hanger and displace' the drilling fluid with filtered seawater but no corrosion inhibitor.. Spot the breaker inside the slotted liner. , . Pull the wash string up just above the.hanger,and circulate.well clean with filtered and inhibited seawater.- Pull out of the hole and lay down the wash string. . ; ... Retest 9-5/8" wellhead packoff and replace as needed. Rig up wireline and perforate _+10' of Zone 2 sand. Run the 3-1/2" L-80 x 13-Cr straddle tailpipe assembly, with 9-5/8" packer on drillpipe. Locate the top of the liner suchthat the blast dngs are position across the perforated interval. Set and test the packer.. POOH and LD DP. RECEIVED · NOV - 9 199,) Page 3 Redrill Plan Summary Alaska. Oil & ~am Cons. COmml~slo. 25. 26. 27. 28. 29. 30. 31. Pull wear ring. Run 4-1/2" L-80 tubing', space out the tubing into seal assembly, attach the tubing-hanger, and land the tubing. Pressure test the tubing and annulus as per standard procedure. Install a BPV and test plug.- Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. 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 RECEIVED NOV - 9 199,,t Alaska Oil & Gas Cons. Commission Anchorage Redrill Plan Summary Page 4 PRUDHOE BA - ! ...... i1 i _ ii i · · ii t,t~rker l~nlif icalion MO A) TIE-IN / KOP 6/i00 6550 B) END OF 6/100 CURYE#I 8874 C) SI&Rf i4/iO0 CURY[¥8 9567 DJ BUILD 5/100 t0032 £J Ekt} OF §/lO0 BUILD 10252 FJ IARGET 10252 G] lO 1~252 ¥ BKB SERfN [~CLN 7763 2620 29.90 8059 2944 18.67 6716 3123 18.67 9009 3449 80.00 9026 3667 90.97 9026 ~667 90.97 9009 4667 90.97 'bR-Zi'_'LI'N0 ii i $ch],umberger Anadr i ] ] , i i i ii , i ii l ii iiinl .! DS 07-27A (P4) VERIlCAL SECTION VIEW _ :Section at: 344.43 TYD Scale · t inch: 300 feet Dep Scale · ] inch: 300 teet Drawn 11/03193 "' J ·2 'i ................ ~ k-- .......... r ~ r'l-g~lrYEn- ')¢i6' ~ ........ : i\, i ~ ..-....°".~_:_. ..... ....................... % .. ~ e,-.,.,~ ' ~* ~1~ ..... · .... ~ ~ ......................... _._~__~.: ........ :, .......... . . J.~. ~. . -=~-~-~,'~.q' ,~,]~.--'" ' . . ' -' ' - ' ~ .... . i .................. , ' '~ ', , I ...... ' .......................... ?~r ~' -~3 ..................... ¥ '~ ...... ~ .......... , .... ! · · '- .... , !~! ,,, ........ ! ..................... i'~,.~ ar~.¢~- ~c ...... , .......... X ........ ~7 ............. . . ,_ . :~[~.~~,:: ::::::; ~ ======================== . · "~,~/~,,,~r'.. ~' : -9,~.. - ................. ' '-"~ ...... ~ ''"~ E 2400 2550 2700 2850 3000 3t50 33~0 3450 3600 3750 3900 4050 4200 .4350 4500 4650 4800 4950 5100 Sect ion, Departure ............... ,1 (cl~ 0;/2;01)4 8t.5~ iQ-40 PRUDHOE BAY DRILLING :CLOSURE ' 4667 feet at Azimuth 34~.36 E) END 0F 5/i00 BUiLB ~0~5~ ~531 990 F) TARGET ~0252 3531 990 ~DECLINATION.' 29.960 E 6) ID ~1852 4495 1258 SCALE... - 1 inch = 300 feet iDRAWN ' ~ 1/03/93 .... ,m m m i m m m ~chYumberger ~nadrJ 2] 'm m m I m 4500 ...... ~- , . 3750 .... ~ , ~ ~ ~-~ ~oo-- , I ......... ~ .... ~ .. ~ ..... ~50 ..... t , ' ....... : 3300 ....... ; ~, ................... RE(EIV[ = , ~ NOV , ~ 3000-- ~ .................. ~ ~m,~- . , ~50 ..... ~. ', .... ,~ ,, ', 2700---- ": .... I '" ~ "' ; "%'-' : ..... ' , ~o ....... I I I~ , . , ~ , ,,, _ ~950 ~800 ~50 1500 1350 i200 ]050 900 750 600 ~50 300 ~50 0 <- WEST' EAST TOTAL P.O? STATE OF ALASKA AI~, OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X~ Suspend Operation Shutdown, Re-enter suspended well. Alter casing Repair well .... Plugging X Time extension Stimulate" ~ ,, Change approved program,,, Pull tubing " Variance ...... Perforate Other X Plugback for redrlll 2. Name of Operator ARCO Alaska, inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development. Exploratory .., Stratigraphic .,, Service. X 4. Location of well at surface 952' SNL, 497' EWL, SEC. 34, T11N, R14E At top of productive interval 2231' NSL, 94' WEL, SEC. 28, T11N, R 14E At effective depth At total depth 2623' NSL, 35' EWL, SEC. 28, T11N, R14E 12. Present well condition summary Total depth: measured true vertical R I'3 ECEIVED Alaska I& ~s."CO'mmisslon AncEErage 10145 feet 9133 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 57' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well 'number 7-27 '"9. Permit number 87-82 10. APl number 50- 029-21744 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured 10095 feet Junk (measured) true vertical 9091 feet Casing Length Size Cemented Structural Conductor. 110' 20" 2892 # Poleset Surf ace 3924' 13-3/8" 3200 sx cs Ily6OO sx Intermediate Production 9336' 9-5/8" 875 sx Class "G" Liner 1053' 5-1/2" 475 sx Class "G" Perforation depth: measured None true vertical None Measured depth True vertical depth 110' 3981' 110' 3896' 9393' 10140' 8497' 9129' Tubing (size, grade, and measured depth) 7", 26#, PCT@ 2234'MD;5-1/2", 17#, L-80, PCT @ 9057'MD Packers and SSSV (type and measured depth) Baker FB-1 @ 9067' MD;7" Camco Bal-O SSSV nipple @ 2217' MD 13. Attachments Description summary of proposal x Detailed operations program .... BOP sketch, ,, 14. Estimated date for commencing operation 11/15/93 16. ff proposal was verbally approved 15. Status of well classification as: Name of approver Date approved 17. I hereby certify that the fo~Eeg~-~u~j~nd correct to the best of my knowledge. Signed ~"~'~~ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Mechanical Integrity Test. , Subsequent form required 10- Orlglnal S~igned By Approved by order of the Commission David W. johnston Oil Gas Service Water Iniector Suspended. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST O UNIT# PROGRAM: exp [] dev [] redrll ~ serv [] oN/oFF 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 fromdrlg 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. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... N N N N N N N N N N N N BNGINEERING APPR 14. Conductor string provided ................ Y ] N 15. Surface casing protects all known USDWs ......... Y~ N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . Y N 18. CMT will cover all known productive horizons ...... .Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... Y~~N~~J~~ 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate . 25. BOPEs adequate .................. ; :~ N 26. BOPE press rating adequate; test to ,~--~ s~g N 27. Choke manifold complies w/API ~-53 ~May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. 31. 32. 33. 34. GEOLOG][: / Permit can be issued w/o hydrogen sulfide measures .... Y Data presented on poten~ial overpressure zones ..... Y /~ ~ / Seismic analysis .of shallow gas zones .......... Y/ N Seabed condition survey (if off-shore) ........ /Y N Contact name/phone for weekly progress reports . . . /. Y N [exploratory on1¥] ENGINEERING: COMMISSION: Co~ents/In~tr~ct/one: HOW/jo - A:~FORMS~cheldist rev 03/94 ** CHECK LIST FOR NEW WELL PERMITS ** I TEN APPROVE DATE ( 1 ) Fee /~/P(____ ///~,/~ (2) 'Loc I¢~0¢__ ,, [2 thru 8] (3) Admin ~ //"/~/~%]/f/~~,,, 13 [~.0 S 13] (4) Casg ~ /)"/r~ [14 thru 22]~ (5) BOPE [23 thru Company /~f'"(_.. 42 Lease & Well YES NO REMARKS . 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is pemit 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 & is well bore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... , ...... Is administrative approval needed .................................... Is lease ncmber appropriate .......................................... Does well have a unique name & nc~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wel lbore ................... Is old wellbore abandonment procedure included on Is adequate wel lb ore separation proposed .......... Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~'-~ .ps ig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas .probable ...................................... (6) Other ~(_ ~ ['29 thru 31] (7) Contact AC/°< [32] (8) Addl 29. 30. 31. 32. 33. rev 6/93 jo/6.011 FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA t~ SHORE Additional remarks' MERIDIAN' SM WELL TYPE' Exp/J~/~ Redri 11 7, Inj Rev