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Home My WebLink About195-040XHVZE 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 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 v TO RE-SCAN Is~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si Memorandum State of Alaska Oil and Gas Conservation Commissi~ Re: Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo wffi remain at the front of the subject well ~e. 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 ddii. 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 preexisting, reddlls and or multilaterais 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 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 numbering 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. Statistical Technician WELL R-23Ll(41-33-12-13) PERMIT #95-40 Please cancel drilling permit for R-23L1. Prep. work for the well determined the robing is in a helix that precludes deployment of coil tubing drilling BHA. Sincerely yours ~; ~. Coil Tubing Engineer RECEIVED APR 2,5 1995 Alaska 0il & Gas Cons. Commission Anchorage ~ CONSERVATION COM~HSSION U ALASI~& OIL AND GAS / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 31, 1995 Brock Williams Coil Tubing Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit R-23 L1 BP Exploration (Alaska), Inc. Permit No. 95-40 Sur. Loc. 168'NSL, 2266'WEL, Sec. 32, T12N, R13E, UM Btmnhole Loc. 983'SNL, l196'WEL, Sec. 33, T12N, R13E, UM Dear Mr. Williams: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. The permit is for a new segment from existing well R-23, permit No. 83-137, API No. 50-029-21013-00. 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 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 C 'AND GAS CONSERVATION COIV, SSION PERMIT TO DRILL 20 AAC 25.005 ,ype of work Drill [] RedrillE]Ilb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE 75.11 f e et Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorac~e. Alaska 99519-6612 ADL 028278 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s,,e 20 mc 25.025) 168' NSL, 2266' WEL, SEC. 32, T12N, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well number Number 1245'SNL, 1355' WEL, SEC. 33, T12N, R13, UPM R-23 L1(41-33-12-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 983' SNL, 1196' WEL, SEC. 33, T12N R13E $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 28277 @ 1196' feet No close approach feet 2560 12207MD/8871 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) KiCkott depth feet Maximum hole angle o Maximum surface 3330 pslg 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 TVD (include stage data) 3. 75 None L ! ¥ 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~' [-'' Present well condition summary Total depth: measured 12265' feet Plugs (measured) ~'~ [ ~' true vertical 9190' feet ~,S~a, IJ[[ & Gas Coils. Effective depth: measured 12091' feet Junk (measured) _Allchora,_ ~' true vertical 9093' feet Casing Length Size Cemented Measured depth True Vertical depth Structural -- Conductor 110' 20 x 30" 8 cu yd 145' 145' Surface 3041' 13 3/8" 4200 cuft 3076' 2725' Intermediate 11607' 9 5/8" 2466 cu fl 11642' 8798' Production Liner 878 7 248 cuft 11379'- 12257' 8618'- 9185' Perforation depth: measured 11658'-11750'(Sag R.), 11817'-11862', 11877'-11922'(Ivishak) true vertical 8735'-8760'(Sag R), 8837'-8904'(two Ivishak intervals) 20. 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 certify th.at the,~fo.reg0,ing is true and correct to the best of my knowledge /__ Signed ~, ,,~/~~ Title Coil Tubin~l En~lineer Date~,/~ Commission Use Only Permit Number ~Ri.-~N~er~'~,¢''~'-- "¢¢¢,'~',¢'' IApproval date ISee cover letter ~',d'"-' ¢~ 15o-~?-.2../~d/..~-~O I ~//:~l//c/Z;'- Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud log ~equired []Yes ~1~ No Hydrogen sulfide measures [] Yes ~i~ No D~rectional survey required [] Yes [] No Required working pressure for BOPE F'I2M; I-]3M; F'15M; I-I10M; I-I15M; ~l.~,.r-o~ c7' Other: (Jriglrl~l $igneo ldy by order of Approved by David W, Johnston Commissioner me comm,ssion Date,~.3t,~, Form 10-401 Rev. 12-1-85 Submit ir cate BPX R-23 Sidetrack Summary of Operations: R-23 currently is a Iow productivity producer. This operation is being undertaken to supplement the existing production and develop new technology. All operations will be conducted thru-tubing with the tree in place. This sidetrack will be conducted in two phases with an operation shut-down of 4-6 weeks in between Phase 1 and Phase 2. Phase 1- Cut Window: Planned for April 1 thru April 6 - The existing perforations will not be isolated to preserve the existing production. - A whipstock will be set on ELine at the top of the Sag at 11 653' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" and 10 ft of formation will be drilled. - Coil unit will then be rigged down and 4-6 weeks will elapse before resumption of operations Phase 2: Drill Directional Hole: Planned for May 8 thru May 18 - Directional drilling'coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TD of 12,207' MD (8,871' TVD). - No casing will be run in the hole. Mud Program: - Phase 1: Seawater - Phase 2: Xanvis (8.6 - 9.0 ppg) or Seawater (8.6 ppg) Casing Program: - No casing will be run. This will' be left as an open hole completion. Well Control - See attachments. - Phase 1 will utilize "Type B" BOP arrangement (no circulation system, all returns will be sent down flowline). - ~e 2 will utilize "Type A" BOP arrangement. - Both BOP arrangements allow for tree to remain in place and for the BHA to be fully lubricated above the swab valve. - Lubricator/pack off is pressure tested on each trip. Directional - See attachements. - Kick Off: 11,563' MD (8,760' TVD) - TD: 12,207' MD (8,871' TVD) - Magnetic and inclination surveys will be taken every 25 ft. No gyro will be run. Logging - A gamma-ray log will be run over all of the open hole section. bit & 6as G0r~s. 60mmissi0~ Anch0ra *' ., Condition I TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS 13 3/8", 72#/ft, ' '12994'1 L-80, BTRS IKOP: 3000' MAXANGLE: 52° @ 12,150' 4 1/2", 12.6#/ft, L-80, BTRS TUBING (IPC) TUBING ID: 3.958" CAPACITY: .01522 BBL/FT TOP OF I 11.379' I~ 7" LINER 95/8", 47#/~,111,642' I L-80, BTRS ~ PERFORATION SUMMARY REF LOG: SWS - BHCS - 11-27-84 ~'IZE SPF INTERVAL OPEN/SQZ'r , ,, 3 3/8" 6 11,658 - 11,750' OPEN/I-29-88 31/8'! 4 11,817-11,857' OPEN/6-15-88 " 4 11,857 - 11,862' OPEN/7-7-88 4 11,877 - 11,922 ..... PBTD ~ 7" , 26 #/ft, L-80, IJ4S ~ R-23 KB. ELEV = 75.11" BF. ELEV = 40.11' SSSV LANDING NIPPLE I 2273' I (OTIS) (3.813" ID) GAS LIFT MANDRELS (OTIS wi RA LATCH~ N;{MDIBKB, TVDss 4026' 3327' r6508' 5111' 8384' 6428' 8979' 6855' ii 9598' 7313' 10,160' 7716' 10,670' 8057' 10,974' 8263' 111127' 8368' 41/2" SLIDING SLEEVE J J (OTIS"XA") (3.813" ID) 11,242' BOT PaR Jl 1,303' J 9 5/8" PACKER ",o, 111,327'l 1/2 ", 12.6 #/ft, L-80 TAILPIPE 1/2 X"NIPPLE .... J J (o-ns) ( 3.813" ~D) 1 1,369' 4 1/2 .... XN"NIPPLE ~ (OTIS) (3.725" ID) 4 1/2" TBG TAIL J I 1,434' J (DOT SOS) (ELMD) J 11,442'J RECEIVED MAR 22 1995 Oil & Gas Cons. Commission Anchora ~ .,sed Sidetrack I TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS CMT'd 133/8". ?2#/r~, ,12994'1 L-80, BTRS KOP: 3000' MAXANGLE: 520 @ 12,150' 4 1/2", 12.6#/ft, L-80, BTRS TUBING (IPC) TUBING ID: 3.958" CAPACITY: .01522 BBL/FT TOP OF 7" LINER 95/8", 47#m, 111,642' I L-80, BTRS ~ R-23 KB. ELEV: 75.11" BF. ELEV = 40.11' SSSVLANDING NIPPLE I 227~' I (OTIS) (3.813" ID) GAS LIFT MANDRELS ¢OTIS W/ RA _ATCH~ N-" J MD(BKB) TVDss 9 I 4026' 3327' 8 I 6508' 5111' 7 J 8384' 6428' 6 I 8979' 6855' 5 J 9598' 7313' 4 I 10,160' 7716' 3 I 10,670' 8057' 2 I 10,974' 8263' 1 ] 111127' 8368' 41/2" SLIDING SLEEVEI I (OTIS "XA") (3.813" ID) 1 1,242' I11 ~303' I 9 5/8" PACKER I ( BOT )("ID) 11,327' 4 1/2" 12.6 #/ft, L-80 TAILPIPE 4 1/2 X"NIPPLE .... I I (OTIS) ( 3.813" ID) 1 1,369' 4 1/2 .... XN"NIPPLE ~ (OTIS) (3.725" ID) 4 1/2" TBG TAIL I I 1,434' I (BOT SOS) (ELMD) 111,442'1 Set Whipstock at 11,653' PERFORATION SUMMARY REF LOG: SWS - BHCS - 11-27-84 SIZE SPF INTERVAL OPEN/SQZ'[ ,, 3 3/8'!6 11,658 - 11,750' OPEN/I-29-88 3 1/8' 4 11,817- 11,857' OPEN/6-15-88 " 4 11,857 - 11,862' OPEN/7-7-88 " 4 11,877 - 11,922 ..... PBTD ~ , -, 7", 26 #/ft, L-80, IJ4S ~ Sad ler och i ti?~iiiiiii~Liiii RECEIVED MAR 22 1995 ~i. ask~ Oil & Gas Cons. Commission Anchora R-23 Ft North Of Sfc Location Plan View 5,000 -- 4,800 - - 4,600 - - 4,400 -- New Hole 4,200 -- 4,000 - - 3,800 3,600 3,400 - 3,200 3,000 5,000 5,200 5,400 5,600 5,800 6,000 6,200 6,400 6,600 6,800 7,000 Ft East Of Sfc Location Name R-23 I CLOSURE Distance 7,564 ft I Az 5 6 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 5,9391 3,847 Top Sad 6,107 3,981 State Plane 642,782 5,980,655 TD 6~260 4~246 State Plane 642~935 5,9807920 Surface Loc 636,675 5,976,674 ITSAD Step Out 10 8I MD of TSAD -> TD 3071 Az Chg MD {ft) -15.~ 3~)(~ 3.0 252 1.0 2 Curve 1 Curve 2 Curve 3 Drawn: 3/1 9/95 17'02 8700 880O 8900 9O0O R-23 6800 7000 7200 Vertical Section Departure (Feet) 7400 7600 7800 8000 8200 8400 Hole Angle @ K.O.= 47 deg ~ DL 1= 20.5 Incl Crv1= 89 deg ................ T_SH_U__ _. DL 2= 3.0 deg/lO0 Incl Crv 2= 89 deg -~TSAD Target Depth Original Hole Marker Depths TSGR TSHU TSAD Target Kick Off Deprtr @KO 8,7501ft TVD I 8,7921ft TVD ! 8,8641ft TVD I 8,874lft TVD I8,7601ft TVD 11~653Jft MD 7~09,1 f t IMD KO Pt MD New Hole Total MD , TVD TD 11,653I 554I 12~207I 8~8711 Build Rt de(jI1 O0 MD (ft) ~14.0 366 0.0 252 0.0 2 Curve 1 Curve 2 Curve 3 Drawn: 3/1 9/95 17:02 2.3.2B ICoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I Pump-In SubI BOP Stack Type B To be used when no mud will be circulated Spacer Spools needed for Height) Manual Swab Valve ~ Existing Flowline ] I Hydraulic Actuated Valve I Manual Wing Manual Master Valve RECEIVED MAR 2 2 1995 Ai~ska Oil & Gas Cons. Commission Anchora '~ ILift Gas In (if applicable) 2.~.2A ICoil Tubing BOPE I I Pump-In SubI Blind/Shear Blind/Shear Pipe Rams Slip Rams BOP Stack Type A To be used for drilling with mud Spacer Spools (as needed for Height) I To Choke Manifold I Hydraulic Actuated ValveI Manual ValveI I Manual Swab Valve/ Mud Cross IManual ValveI ---'--~1 Existing Flowline I I Hydraulic Actuated Valve Manual I.Manual Master Valve RECEIVED MAR 2.2 !995 Ai~sk~ Oil & Gas Cons. Commission Anchor~. ~ ILift Gas In I (if applicable)I Site Plan SEAWATER GREEN (DIVERT)TANK (with Type 'A' BOP) .......... :i:!:i:!:i:!:i:!:!:i:i:!:! i:i:i:~:!:!:~:i:i:~:i:i:!: :::::::::::::::::::::::: ~ W,ELLS SHOWN w~,,.o~s~~~ ~i~ ~',~ ;~ ~ l~iil ×. ~/ · WELL (SafedOut) 50 CENTERS ON / ~XXX xxxxx~x~e~ GENERATOR CAMCO "CHO~ %~ ~o ~ MANIFOLD ~ ~TRUOK GENERATOF~ [ LAB e · ANK FARM "" · eI~IaCHARGE PUMP %APPROX 120' + · CLASS I, DIV I* SOZ MANIFOLD CLASS I, DIV IY · POWE _Dk-'q MAN MI VAN 3 PAC FT ~t scs e EMERGENCY ESCAPE PACKS s SCO-I-r Al R PACKS PLANT ·1~.,, 0 PRESSURIZED N2 BOTTLES o OTHER FIRE HAZARDS - PAINT, LUBRICANTS, RAGS, CHEMICALS .... x HALON DUMP/STORAGE GENERATOI~[~ SPEED E EYE WASH STATION · FUEL STORAGE ~" SOHIO TRAILER · H2S SENSORS OR WARNING LIGHTS ~ DIRECTIONAL DRILLERS · H2S/LEL SENSORS OR WARNING LIGHTS ~ :~ r'1'l = GLYCOL STORAGE _,o ~ · ESD ~= _.., ~ 1.2.23v5 + FIRE EXTINGUISHERS ~ FLUID FL~,' SCHEMATIC (with Type 'A' BOP) Seaw~ ier MeOH Green Tank (Dived) Charge Pump Dead Crude (vac trucks) TankFarm CleanFl~pro I I I ,,' i-~harge ! ~'''~'L~.~.mps / % Cosasco Valve Choke Manifold icro motion ~dll Cuttings~ MI Van 3 Squeeze Manifold CTU BJ Pumper Normal flow Gas Divert Fluid transfer from tank farm/upright tanks to BJ/MI Manually operated valve RECEIVED ~VAI-'{ 2. 2 1995 ~.~ka Oil & Gas Co~$. Commission Anchor~,, WELL PERMIT CHECKLIST PROGRAM: exp [] dev [] redrll [] serv [] i 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. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR GEOLOGY APPR 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 18. C~ will cover all kno. productive horizons ...... 19. Casing designs adequate for C, T, B & pe~afrost .... 20. Adequate tankage or rese~e pit ............. 21. If a re-drill, has a 10-403 for abnd~nt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid progr~ schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ psig.~' 27. Choke manifold complies w/~I ~-53 (May 84) ....... 28. Work will occur without operation shutdo~ ....... 29. Is presence of E2s gas probable ............ 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y//~ 32. Seismic analysis 9f shallow gas zones .......... V N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: COM~SSION: Dw~ -- Comments/Instructions: CD I.-I HOW/lo - A:gCORMS%cheklist rev 03/94