The URL can be used to link to this page

Home My WebLink About195-209XHVZE 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: a~ev~~/ Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes' Re-Scanned by: Be~edy Dianna Vincent Nathan Lowell Date: Is~ ON OR BEFORE Memorandum State of Alaska Oil and Gas Conservation Commiasion Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well f'de. 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 the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair, unchanged. The APl number and in some instances the well name reflect the number of preexisti~ reddlls 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 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 AP! numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (wellbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX'. (907) 276-7542 December 26, 1995 ~. Ted Stagg, Coiled Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re' Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit G-31A BP Exploration (Alaska), Inc. 95-209 2409'SNL, 2368'WEL, Sec 12, T11N, R13E, UM 2171'SNL, 3435'WEL, Sec 12, TllN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-ddil does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-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 pdor to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W Johnston \ - ~ BY ORDER OF T COMMISSION Ijb/encl ¢: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ALASKA OIL AND GAS COi'qSERVATIOix! COMMISSiGixl PE. RIv'iI'f lO DRILL 20 AAC 25.005 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 65.35 AMSL feet Prudhoe Bay Field/Prudhoe 3. Address 6. Properly Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 28280 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2409' SNL, 2368' WEL, Sec. 12, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2062'SNL, 2473' WEL, Sec. 12, T11N, R13E G-31A 2S100302630-277 At total depth 9. Approximate spud date Amount 2171' SNL, 3435' WEL, Sec. 12, T11N, R13E January 3,1996 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandTVD) property line 28280 @ 3108' feet no close approach feet 2560 9891 'MD (8915'ss) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth s~ feet Maximum hole angle ~o o Maximum surface 2220 pslg At total depth (TVD) 8800~3360 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) ss ss 60 cu. ft. 3.75" 2 7/8" 6.16 L-80 FL4S 2741 7150 7078 9891 8915 60 cu. ft. .. 19. To be completed for Redrill, Re-entry, and Deepen Operations. '..~. Present well condition summary "' Total depth: measured 9274 feet Plugs (measured) true vertical 9084 ss feet Effective depth: measured 9209 feet Junk (measured) true vertical 902655 feet Casing Length Size Cemented Measured depth True Vertical depth Structural ss Conductor 80' 20" 8 cu. yds 110' 45 S u rface 2665' 13 3/8" 3723 cu. ft. 2695' 2630 I nte rm ed iate 7387' 9 5/8" 955 7417' 7347 Production Liner 2141' 7" 625 cu. ft. 9317' 9122 Perforation depth: measured 9076'-9118' sqzd; 9128'-9136' sqzd; 9136'-9150'open true vertical ss 8907'-8944' sqzd; 8953'-8960' sqzd; 8960'-8973' open 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 ~t~oregoing is true and correct to the best of my kn.owledge 2/7/,¢'''¢'''' Signed ' Title Coiled Tubing Drilling Engineer Date / Commission Use Only Permit Number APl number Approva, I dat~) See cover letter ~'.._~'- .2.-~ ,~ 50' 0~-..'°--~-//~'/~'-c::3'/ /~'//Z(¢/~'.~_ 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 DOPE 1-12M; r-13M; i-15M; I-IIOM; F-I15M; J~ ~~' Other: Original Signed By by order of Approved by David W. Johnston Commissioner ~ne comm,ssion Date/~ --orm 10-401 Rev. 12-1-85 Submit in triplicate BPX G-31A Sidetrack Summary of Operations: Well G-31 is currently shut-in due to high TGOR. The well is being sidetracked to achieve lower GOR production. This sidetrack will be conducted in two phases with an operation shut-down between Phase 1 and Phase 2. Phase 1: Cut Window: Planned for Dec. 28-Jan. 1, 1995. - The existing Ivishak perforations will be squeezed. - A whipstock will be set on ELine in Zone 4 at approximately 8651' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" and 10 ft of formation will be drilled. Phase 2: Drill Directional Hole: Planned for Jan. 3-13, 1996. - Directional drilling coil tubing equipment will be dgged up and utilized to ddll the directional hole as per attached plan to planned TD of 9891' MD (8915' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.6 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, FL-4S liner will be run from TD to approx. 7150' MD and cemented with approx. 60 cu. ft. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: See attachments. Phase 1 will utilize "Type B" BOP arrangement (no circulation system, all returns will be sent down flowline). Phase 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. - The completion phase will utilize BOP equipment as shown in the attachment. Directional - See attachements. - Kick Off: 8651' MD (8520' TVD ss) - TD: 9891' MD (8,915' TVD ss) - Magnetic and inclination surveys will be taken every 25 ft. No gyro will be run. Lo~ging - A gamma-ray log will be run over all of the open hole section. A GR/CNL will be run in cased hole prior to perforating. TREE: 4" CIW WELLHEAD: FMC ACTUATOR: AXELSON G-31A Proposed Sidetrack KB. ELEV = 65.35' BF. ELEV = 36.66' FOC -- SSSV LANDING NIPPLE (OTIS)(3.813" ID) 13-3/8", 72#/ft, 12695' I L-80, BTRS KOP: 7000 MAX ANGLE: 27°/9165' 4-1/2", 12.6#/ft, L-80, BTRS TUBING (IPC) TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT NSCC THREAD SFC TO 4563 FT TOP OF 7" EOT I TIEBACK SLEEVE 7176' 9-5/8", 47#/ft, 7' L-8o, BTRS 1741 ! MARKER JOINT 8595' I TOP OF WHIPSTOCK APPROX. 8650' MD/~' PERFORATION SUMMARY REF LOG: GEARHART- BHCS 7-14-86 SIZE SPF INTERVAL OPEN/SQZ'D 3-1/8" 4 9076- 9118' SQUEEZED 3-1/8" 4 9128- 9136' SQUEEZED 3-3/8" 6 9136 - 9150' SQUEEZED I I PBTD [ 9274'/ 7", 26#/,, L-8O IJ4S [ 9317' J /%/%/%/%/%/% /%/%/%/%/%/% /%/%/%/%/%/% /%/%/%/%/%/% '/%/%/%/%/%/%, %%%%%% /%/%/%/%/%/%' '/ .,. / ..' ,,. SLIDING SLEEVE OTIS "XA" (3.813" ID) 7051'1 711 ' I 7129' J TUBING SEAL ASSY. (SBR) 9-5/8" PACKER (TIW) 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 .... X" NIPPLE (OTIS) (3.813" ID) 4-1/2 .... XN" NIPPLE (OTI~S) (3.725" ID) 4-1/2" TBG TAIL (BAKER SOS) (ELMD) 7174' 7214' 7246' 7235' SHUBLIK SADLEROCHIT 3.75" OPEN HOLE TREE: 4" CIW WELLHEAD: FMC ACTUATOR: AXELSON G-31A Proposed Completion KB. ELEV = 65.35' BF. ELEV = 36.66' SSSV LANDING NIPPLE (OTIS)(3.813" ID) FOC -- 13-3/8", 72#/ft, 12695' L-80, BTRS KOP: 7000 MAX ANGLE: 27°/9165' 4-1/2", 12.6#/ft, L-80, BTRS TUBING (IPC) TUBING ID: 3.958" CAPACITY: 0.01522 NSCC THREAD SFC TO 4563 FT TOPOF7" BOT I I TIEBACK SLEEVE 7176' 9-5/8", 47#/ft, 7' L-80, BTRS 1741 Proposed top of liner approx. 7950' MD. MARKER JOINT I 8595' 2 7/8" CEMENTED LINER PERFORATION SUMMARY REF LOG: GEARHART- BHCS 7-14-86 SIZE SPF INTERVAL OPEN/SQZ'D 3-1/8" 4 9076 - 9118' SQUEEZED 3-1/8" 4 9128- 9136' SQUEEZED 3-3/8" 6 9136- 9150' SQUEEZED 2" 4 to be determined PBTD 19274'1 7", 26#/ft, L-80 IJ4S I 9317'1 L SLIDING SLEEVE I OTiS "XA" (3.813" ~D) 7051' TUBING SEAL ASSY. I 7113' (SBR) I 9-5/8"PACKER (TIW) ] 7129'J 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 .... X" NIPPLE (OTIS) (3.813" ID) I 7174' I 4-1/2 .... XN" NIPPLE (OTIS) (3.725" ID) I 7214' I 4-1/2" TBG TAIL I 7246' (BAKER SOS) (ELMD) I 7235'J SHUBLIK SADLEROCHIT G-31 Plan View 1,400 - 1,200 1,000 - 800 - oo O0 oo ~ -1,400 -1,200 -1,000 -800 -600 -400 -200 0 X distance trom Sfc Loc JWellName G-31 J CLOSURE JDistance 1,093 ft J Az 2 81 de~l NEW HOLE Efw (X) N/S (Y'), Kick Off -112 354 Top Sad -436 444 State Plane 657,419 5,969,676 TD -1 ~072 21 5 State Plane 656,783 5,969,447 Surface Loc 657,855 5,969,232 I TSAD1 Step Out 332I TSAD2 Step Out 332 JMD of TSAD1 -> TD 660J Az Ch~l MD (ft) -20.6' 460' -8.0 1 80 3.0 600 Curve 1 Curve 2 Curve 3 Drawn: Plan Name: I 1/29/95 8:37 Case I 845O 8500 855O 8600 8650 8700 8750 88OO 885O 89O0 895O 9OO0 G-31 Vertical Section 200 400 58 deg le @ K.O.= 23 deg Path Distance (Feet) 600 800 1,000 I I I 1,200 1,400 I I .............. TSAD DL 1= 18 de~?2 ........ DL 2-- 20 deg/100 31 p 14P .............................................. 90 de ......... Marker Depths TSAD 31 p 14P IKick Off I Deprtr @ KO 8,500Irt TVD 8,6401ft TVD 8,9051ft TVD 8,925Jft TVD 8,5201ft TVD 8~651 Iff MD 387 ft Predict From Survey #: Length MD KO Pt MD New Hole Total MD TVD TD 30.I 8,651] 1240I 9,8911 8~915] Build Rt de911 O0 MD (ft) 7.5 460 18,0 180 0.0 600 Curve 1 Curve 2 Curve 3 Drawn: I 1/29/95 8:37 lC,oil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams CTDM:2.3.2A I Pump-InI BOP St ack Type A To be used for drilling wit h mud Spacer Spools needed for Hei~lht) I To Choke Manifold I Hydraulic Act uat ed Valve! Manual Valve Mud Cross i _ManUal Valve I Manual Swab I Hydraulic Act uat ed Valve ~~l Exist ing Flowline I IManual Mast er Va I Manual Wing ValveI RECEIVEL OEC 1 8 19~5 Alaska Oil & Gas Cons. Commission Anchorage (if applicable)l (3-i D ',i:2. IOoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I Pump-In SubI BCP Stack Type B To be used when no mud will be circulated Spacer Spools (as needed for Height) I Manual Swab Valve /' Exist ing Flowline I I Hydraulic Act uat ed Valve [Manual Wing Valve Manual Mast er Valve Lift Gas In I I(if applicable)I 2 7/8" LINER DEPLOYING / CEMENTING CONFIGURATION Blind/Shear Pipe Paros S~ip Pams I ANNULAR T.O.T. QUAD 1 3/4" $CHAFFER HYDRIL I'~ 2 7/8" Blind / Shear HYDRIL 2 7/8" Pipe and Slip Mud Cross RECEI'V L Or~C 1 8 1995 Alaska Oil & Gas Cons. G~mmission WELL PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev [] redrll~ serv [] 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 other 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 REMARKS ENGINEERING <~. DA~E 14. Conductor string provided ................ Y 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 ...... ~ N 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..Y N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... 25. N 26. BOPE press rating adequate; test to ~7~ psig.t;/~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... .~ N 29. Is presence of H2S gas probable ............ Y~ N t GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ _ 31. Data presented on potential overpressure zones ..... Y//~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N ' - 34. Contact name/phone for weekly progress reports . . ./< . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: o HOW/ljb - A:\FORMS~cheklist rev 11/95