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Home My WebLink About195-104XHVZE 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. /¢~E/-/~/--// F ileNumberof 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 Dian~than Lowell Isl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl THE MATERIAL UNDER THIS cOVER HAS BEEN MICRO-FILMED ON :OR BEFORE JANUARY 03 2001 E PL M ATE IA L U N D E R T H IS M A R K E R C:LO~M.DOc Memorandum To' State of Alaska Re: Oil and Gas Conservation Co~ 1 t q' Cancelled or Expired Permit Action EXAMPLE' Point Mclntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning AP! numDers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies 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 APl number and in some instances the well name reflect the number of preexistin~ reddils and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit witl'. an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddil. The APl 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 AP! numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (wellbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' r Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 24, 1995 Terry Jordan, Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit G-20 BP Exploration (Alaska), Inc. Permit No 95-104 Surf Loc 2809'SNL, 2912'EWL, Sec. 12, T11 N, R13E, UM Btmhole Loc 1580'SNL, 2172, EWL, Sec. 13, T11 N, R13E, 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative Of the Commission may witness the test. Notice may be · field inspector 659-3607. ~D.av!d W. Johnston \ ~--' -'~ Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratory[~ Stratigraphic Test[] Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration 70.35 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2809' SNL, 2912' EWL, SEC 12, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1321'SNL, 3013' EWL, SEC 13, T11N, R13E G-20 (22-13-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 1580' SNL, 2172' EWL, SEC 13, T11N, R13E 07/25/95 $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 028280 1580 feet No Close Approach feet 2560 11206' MD/9005' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2~oo feet Maximum hole angle 9o o Maximum sudace 2620 psig At total depth (TVD) 8800'/3500 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 75' 35' 35' 11 O' 11 O' 13-1/2" 10-3/4" 45.5# NT8OLHE Butt 3474' 34' 34' 3508' 3370' 1650 SX CS III 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 10292' 33' 33' 10325' 9005' 517 sx Class 'G' 6-3/4" 5-1/2" 12.6# L-80 NSCT 1031' 10175' 9005' 11206' 9005' 100 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ProductionLiner ~}'~ 07 Perforation depth: measured AI~,~}~, 0[[ & Gas Cons, C0mm[ss[0P. true vertical 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[] 21. I hereby certify that ,the~ foregoing is true and correct to the best of my knowledge Signed /'~(,~,,, / ~ - I Title Drilling Engineer Supervisor Date //.,/~,~ .... ~' ~.,) Commission Use Only ~ermit Number APl number Approval date See cover letter ?~--/'~ ~/ 50-c:~--~'-'- 2_.- 2.- ~'7~4' "]//'2..~r / ?~"" for other requirements Conditions of approval Samples required [] Yes J~ No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M; []3M; 1~SM; CIIOM; I-I15M; Other: Approved by Original Signed By Commissioner by ordercomm~ssionOf n,~,,;~ ~,M lr~hn~tnn me Date .~,/-,//z.. Form 10-401 Rev. 12-1-8~ Submit in icate Logging Program: Open Hole Logs: 13 1/2" Hole MWD Directional 9 7/8" Hole MWD Directional/Neutron 6 3/4" Hole LWD/GR/Res Mud Properties Surface Mud Properties: I SPUD Mud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 +/- 300 40 - 60 30 - 60 50 - 80 9 - 10 15 - 25 to to to to to to to 9.5 100 - 200 25 - 50 15 - 25 25 - 40 9 - 10 15 - 25 Intermediate Mud Properties: I LSND WBM Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0-9.2 35-40 8- 12 3- 6 8- 10 9- 10 8- 12 to to to to to to to 10.0 - 10.2 45 - 50 10 - 15 6 - 8 10 - 15 9 - 10 <15 HPHT Production Mud Properties: [ Flo-Pro Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 45 5 10 9- 10 5 to to to to to to to 9.2 60 50 15 30 9 - 10 7 Directional: 12100' IMaximum Hole Angle: Close Approach Well: 90 degrees None The above listed wells will be secured during the close approach. 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 drilling fluid system schematics on file with AOGCC. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: SxsfW~ield Comments 10-3/4" 1275/12.2/1.92 375/15.8/1.15 COLDSET III 7-5/8" none 684/15.7/1.17 Class "G" 5 1/2" none 100/15.7/1.17 Class "G" Well Plan Summary PROPOSED DRILLING AND COMPLETION PROGRAM WELL G-20 [12 - 11- 131 PBU 1. MIRU. NU diverter and function test same. 2. Drill 13-1/2" hole. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to surface. . Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 3500 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 2620 psi based on a gas column to surface from 8800' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. . Test 10-3/4" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. o Directionally drill 9-7/8" hole to 10,325'MD. Run a 7-5/8", 29.7#, NT-95 NSCC casing string and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. Bump the plug and test casing to 3500 psi. o Drill out the 7 5/8" casing with a 6 3/4" bit and a mud weight of .5 ppg over what the expected formation pressure is. Drill to 11206' MDTD. Run in with 5 1/2" 17.0#, L-80, NSCC production liner and cement in place. Perforate with 3 3/8" guns. .-. . Run 7-5/8" production packer on the 4-1/2", 12.6#, L-80 NSCT tubing, such that the tubing tail is above the Sag River. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2200' TVDBKB. Set and test packer. 8. The well will be perforated after the rig_.h95.~een released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size: 4-1/2", 12.6 #, L-80 tubing with 2 GLM's. RECEIVED ., dUI_ 0 7 1995 Alaska Oil & Gas Cons. Commission Well Plan Summary Anticipated Bottom Hole Pressure Maximum Anticipated Surface Pressure Planned Completion Fluid 3500 psi @ 8800' TVDSS 2620 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. No potential hazardous levels of H2S are anticipated in this well. d. Drilling hazards: .~- G-31 .~previous well on "G" pad experienced experienced some shallow gas a~+6900'i~TVD with a pore pressure of 10.7 ppg. The expected pore pressure on this well is 10.2 pPg, At 4375 TVD there is the possibilty of drilling into coal where torque may become high and chances for stuck pipe exist. Well Plan Summary 3846 HALLIBURTON DRILLIM6 __ , ,, 3157 1030 P. 2/4 @ 8.00/~00 ¢¢ [Well Nhme: [G:20PBU ~ '~ Well Plan Summary I Xy~e o~ Whll ~roO,u,c.,er or !n~eetor?..' I Producer '.'.' ' ! Surface Location:' t" 2809' FNL 2912' FWL See 12 T1 iN'R13E uM Target-Location: '--] 1321' FN'L 30iY FWL gee 13 'TllN R13E UM aott~m tt0i~ L0cafioni 1580' FNL 2172' FWL gee 13 Tli'~ R13E. UM- ' i AF~ Nura~r.. I TBA ' I lRig: _._ I Estimaf,ed_Start Date: [.9/,7/95 --1 rOperatlng days to comp.!ete: 1 30 11205' ' i I TVD: 19ooy ' I Well-Design .(co_nventio ,hal, slimhole~ et~,): . ] Slimh01eHorizbhtal Formation Markers: ,i [ RT-GL [ 34.'85~- I KBE: _{ 70.35' · For-mati6n TOps "' MD TVD (BK.B) ' ' ' Base Permafrost --- 2000,, .... 2000, ...... ~;V3 ' 3518' 3370' " Surface cas.inS ~aoint 3~60' TVD ',U~nu ~n~,~A4o60' ., 43~o' ' , _ ' _. I.CU 82~-0' 7575' TopSa$ Rive3 9267' 8355' ' ' ' Top. Shublik-" 9313' .... 8390, .... Top Sa. dleroChfi 9439' -- 8468~ ...... GOC 9939' 8835' ' ' ' --. Target' , 10-326' 90~5' ' ' Total DoI~th . 11,206' 9005' .... . . ~..asmg/· umng.rro,~am: H01e Sizecsg/ . Wt/Ft Grade corm 'Length Top " Btm . .,Tbg O.D. MD~ MO/TVO .-30" ..20" -91.5# H-,lO" Weld 75' 35'/35" i10'/i10' 13 1/2" 10 3/4"--- 45~3~NTg0LI'tE; Butt 3474' '34/34" 3508733~0' 9 7/8~ " 0'~/8" 29.7# NT95HS -N$C¢ .... 11173' 3Y/3Y '10325'/9005' 6 3/4" = '"'" ' , , ' , , a ,/~' -17,0~ L-80 N~CC 103i' '- 10175/9005 112067900.5' I iiii · 4 1/2'" 12,6g L-80_ . NSCT i'0O00" 27727' '100000'i8930' I ii iii i i i , I I --, i i i _ i ii Well Plan Summary · f\.q:tt:':. [' :' ~hared Services Drilling 20" DIVERTER SCHEMATIC NABORS 28 E II FILL UP LINE HYDRIL "MSP" 20" 2000 PS1 DIVERTER ._ FLOWLINE I · '- NINGVALVE CONDUCTOR Divertor Line is 70' in length (:1: 50' from the substructure wall.~) RI C£1Vr D ,It ll_ 'il 1995 Alaska 0il & Gas Cons. Commission _,..L. PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ON/OFF SNORE (~ ADMINISTRATION 1. Permit fee attached ................... N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from ~ther wells...... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor strin9 provided ............... ~ N 15. Surface casing protects all known USDWs ........ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in lon9 strin9 to surf csg . . . Y 18. CMT will cover all known productive horizons ...... C~ N 19. Casin9 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. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it,adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... O N 26. BOPE press rating adequate; test to ~Od~ psig.~, 27. Choke manifold complies w/API RP-53 (M~y 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports . . . ~ Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: ODE ~ RAD '~ ., Comments/Instructions: ~O Z HOW/jo - A:~FORMS~cheklist rev 03/94