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Home My WebLink About193-122Pages 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. i~'~' / 2~' 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: ianna Vincent Nathan Lowell Date: [] 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 PL A T W E IA L UNDER T H IS M ARK ER C j~O~lVtI)OC Memorandum To: Well File: State of Alaska Re: Oil and Gas Conservation Commission 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 file. 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 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 remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddils 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 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 (wetlbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' ~ Statistical Technician WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY'. (907) 276-7542 September 23, 1993 Terry Jordon, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit C-14A BP Exploration (Alaska) Inc 93-122 335'SNL, 1219'WEL, Sec 19, T11N, R14E, UM 706'NSL, 5248'WEL, Sec 16, T11 N, R14E, UM Dear Mr Jordon: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting to-drilling operations until all other required permitting determinations aro 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 ddlling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the Nodh Slope pager at 659-3607. airman BY ORDER OF THE COMMISSION jo/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 20 AAC 25.0O5 la. Type of work Drill [] RedrillElllb. Type of well. Exploratory[] Stratigraphic Test[-] Development OilE] 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 Exp/oration KBE = 58.38 feet Prudhoe Bay Fie/d/Prudhoe 3. Address !6. Property Designation Bay Poo/ P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28306 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(me 2o AAC 25.o25) 335' SNL, 1219' WEL, SEC. 19, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1022' NSL, 82 7' WEL, SEC. 17, T11 N, R 14E C- 14A (14 - 16-11 - 14) 2S 100302630-2 77 At total depth §. Approximate spud date Amount 706' NSL, 5248' WEL, SEC. 16, T11N, R14E 8/26/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28305-30' feet No close approach feet 2560 12752' MD/8948' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 960o feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) i~00'/43~;0 ps~ 18. Casing program Setting Depth s~ze . Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 8-1/2" 7" 29~ '. L-80 NSCC 2385' 9450, 7301' 11835' 8942' 300 sx Class "G" 6" 4-1/2" 12.6# L-80 NSCT 952' 11800' 8941' 12752' 8886' Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. !'~ ~-~ (': ~i ~ Present well condition summary Total depth: measured 12003 feet Plugs (measured),~,.. .... I,.~"' ~,... (:, ~';~'~:-~;~'~ true vertical BKB 9043 feet ,.~,,, . .' ' ' Effective depth: measured 11879 feet Junk (measured) ,~¢,~' .... true vertical BKB 9043 feet '/~,t~0'h0-r3~ Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 2o"x3o" 12.9 cu yds PF 139' 139' Surface 2671' 13-3/8" 3720 cu ft AS 2700' 2700' I ntermed late 10803' 9-5/8" 1575 cu ft "G" & 10832' 8225' Production 130 cu ft AS Liner 1580' 7" 472 cu ft "G" 10310'-11988' 7883'-8965' Perforation depth: measured 11776'-11786', 11796'-11826', 11826'-11836', 11840'-1i856', 11862'-11866', 11890'-11896' true vertical 8873'-8880', 8888'-8910', 8910'-8918', 8921'-8933', 8937'-8940', 8956'-8962' 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 requirementsl-I 21. I hereby certify that the foreooing is true and correct to the best of my knowledge Signed ~¢'~/¢' .~. ,.~_ Title DrillinEEnEineerSupervisor Date¢"/t- ~¢ / (] Commission Use Only .Permit Number v IAPI number IAppro_yal date .... _ See cover letter ¢,~ -/2.2, 150' O'2-~- ~--4::~ ¢¢/'~"O ( I ~ .--¢;~,_~ ~'~ for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes ,j~ No Directional survey required [] Yes [] No Required working pressure for BOPE 1'-I2M; 1-13M; ~5M; I-]10M; []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 trplicate I Well Name: ]C-14A Redrill Plan Summary I Type of Redrill (producer or injector): I PRODUCER Surface Location: Target Location: 1022 FSL, 827 FEL, S17, Ti iN, R14E, UM Bottom Hole Location: 706 FSL, 5248 FEL, S16, TllN, R14E, UM 4944 FSL, 1220 FEL, S19, TllN, R14E, UM I AFENumber: ! I Estimated Start Date: I 8/26/93 IMD: I12752 I [Rig: [DOYON 16 I I Operating days to complete: 125 ITVD: 18948 I IKBE: 162'48 ! Well Design (conventional, slimhole, etc.): CONVENTIONAL/HORIZONTAL [ Objective: I Access new reserves by redrilling to a new target at the base of the reservoir Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. Special design I A non-damaging Xanvis polymer mud at 8.6-9.0 ppg will be used to drill considerations I the 6" hole interval. Depth Density PV YP INT 10MIN 'FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 ....30 15 30 5 0 8 Directional: IKOP: 19600 I Maximum Hole Angle: [ 90DEG Close Approach Well: NONE The above listed wells will be secured during the close approach. ~ .-.,r ~.,. Redfill Plan Sumaw Page 1 Casin,, bin ram: Hole Siz(~ Cig/ ' Wt/Ft~ Grade Conn Length 'Tdi~ Btm Tb§ O.D. MD/TVD MD/TVD 8.5" 7 CSG 29 L-80 nscc 2385 9450/7301 11835/8942 6" 4.5" CSG] 12.6 L-80 nsct 952 1-1800/8941 12752/8886 12.25 3.5" TBG 9.3 L-80 nsct 11100 SURF 11100/8669 ,, Cement Calculations: I Liner Size: [ 2385' of 7" liner in 8.5" hole I Basis:[ 50¢o open hole ex~ess, 40' shoe)oint, 500' above top oil bearing sand (Sag river) Total Cement Volume: 300 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 -I -a ,I ~. O0 i PRUDHOE BAY DRILLZN6 · ,, , =,,, .... - · 6rear. Land tTieec~iona] flr'ilJin9 [ .. C- 4A PLAN VIE CLOSURE ' 66~! feet at Azimu[h B0.gl DECLINATION.' 30.000 E SCALE · ~ inch = 300 feet DRANN ' 07/22/93 Marker Ident i f ica[ ion I~I) N/S E/N A) TIE-IN 9gOO ]670 4359 · B) END OF 6/100 6tRVE 10333 1704 4730 C) KOP ~ILD 5/100 .1046~ t69B 4753 D~ 8UtLO 3/100 ~8980 t617 4988 E~ BUILD B/lO0 11105 1587 5049 FI END OF B/tOO BUILD 11835 1360 5668 6] TARGEI tl835 1360 5668 HI TL1 f~752 ~044 652B 4350 4500 4550 ,4800 4950 5100 5250 5400 5550 5.,-"00 5850 6000 §tS0 6300 6450 6600 t750 69]0 EAST -> " C f. $., t. £ PRODHOE BAY DRILLING C- 14A VERTICAL SECTION VIEW Sect ion al: ~10.~5 TVD Scale.' ~ inch -- 1200 feet <KB> o Der Scale · ] inch = 1200 feet 600 ]200 '~BO0. u " I ' Drawn ..... : 07/E2/93 I SPear Lane DJ/' ctJona D£J]]jng ] Yarker identif~c~tior, MD BKB SECTN INCLN )0 I Al TIE-IN 9600 7368 3516 5;.07 BI ENO OF 6/I00 CURVE J0333 ?998 3553 10.95 I i C] gOP BUILD 6/~00 ~046J 8124 3877 10.95 I . ~0 ...................., O~ BUILD 3/~00 ~OgBO 8582 4106 42.:0 t E) BUILD 5/I00 Jli05 8672 4~93 45,85 F) END OF 6/~00 BUILD 11835 8942 4852 89.53 ~ ~ G) ~ARGET 1i835 5948 4858 89.63 I ~ H) fO 12752 8945 5769 Bg. 63 ._ ~ I I~ ....... z --' ' ---- , : ~ ! i , ~ ', I i ~ · I I 240C B K 5400 6oo0 65oo 0 600 120( 1800 24003~0,9 u 3.60:} ,4 2uO"' 4800 5400 6000 7-, R". :', ,...,_ uu Section Departure ~'~LDO [cJga ,7.~.~4 91.~ 4:27 PN i~ , o. STATE OF ALASKA ALAS~'".OIL AND GAS CONSERVATION COMMISSI¢~'' -- APPLICA'i ,ON FOR SUNDRY APFr OVALS 1. Type of Request: Alter casing Repair well Plugging x Change approved program Pull tubing __ Variance __ 2. Name of Operator I 5. Type of Well: ~ Development _x BP Exploration I E~xploratory ._ 3. Address I ~Sf~'~tigraphic c~f -=--., "-,"~. t · '- P. O. Box 196612, Anchorage, Alaska 99519-6612 I, ¢¢-.,) ....~ (, Serwce ~-- It". .~ -, '- ,. t,on o, 335'SNL, 1219' WEL, SEC. 19, T11N, R14E At top of productive interval --~ Abandon x Suspend ~ Operation Shutdown__ Re-enter suspended well Time extension 15erforate Stimulate Other x Plugback for redrill 6. Datum elevation (DF or KB) KBE = 62.48 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number C-14(43-17-11-14) 9. Permit number 79-91 APl number 50- 029-20413 1422'NSL, 1009' WEL, SEC. 17, T11N, R14E At effective depth 1382'NSL, 497' WEL, SEC. 17, TllN, R14E At total depth 1376'NSL, 416' WEI.., SEC. 17, T11N, R14E AU G 1 6 199;5 10. Alaska. 0il & Gas Cons. Cornrnissio~ 11. Anchorage Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 12003 feet BKB 9043 feet 11879 feet BKB 9043 feet Size Plugs (measured) Top of cement plug @ 11110' (5/31/91) Junk (measured) Fill @ 11879' (5/89) Cemented Measured depth True vertical depth 110' 20"x30" 12.9 cuyds PF 139' 139' 2671' 13-3/8" 3720 cu ft Arcticset 2700' 2700' 10803' 9-5/8" 15~'5 cu f~ "G"/130 cu f~ AS 10832' 8225' 1580' 7" 472cu ft Class "G" 10310'-11988' 7883'-8965' measured 11776'-11786', 11796'-11826', 11826'-11836', 11840'-11856', 11862'-11866', 11890'-11896' true vertical 8873;8880', 8888;8910',~8910;8918', 8921;8933', 8937;8940', 8956;8962' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 10190' w/4-1/2" 12.6#, L-80 tubing tail to 10388' Packers and sSSV (type and measured depth) 9-5/8" BOTpacker @ 10213,; Otis SSSV landing nipple @ 2003' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 8/2O/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearances-_. Mechanical Integrity Test Subsequent for ~'~q~uir~'~'l Date IApproval No. Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE C-14 SUNDRY PROr'~EDURE OUTLINE , Notify an AOGCC representative of our intent to plugback and sidetrack this well. A cement plug was pumped with coiled tubing 5/29/91. The top of the plug was tagged with slickline 5/31/91 at 11,110 MD, 666' MD above the top perf. The 'well was plugged at that time because there was communication from the tubing to 9 5/8" annulus via a leaking packer. , With an AOGCC representative on location to witness the operation, run in with stickline and confirm that top of cement is at least 100' above the top perforation. 3. Cut 5-1/2" tubing at +/- 9900' MD. 4. Circulate the well over to sea water and freeze protect well with diesel to 2OO0 'MD. 5. Bleed any pressure from the tubing, inner annulus, and outer annulus to zero. e Install a back-pressure valve. Remove the well house and flowlines. Level the pad and dig out the cellar. Prepare the pad for arrival of the rig. .. 7. MIRU rig. Pull BPV. Circulate out freeze protection. Pull 5-1/2" tubing. 8. Set a 9-5/8" bridge plug at 9880 MD. 9. Upon completion of milling a 50' section from the 9-5/8" casing from 9600-9650 MD, a kickoff cement plug will be laid with the base of the cement plug extending 100' md below the section window to 9750 MD. The cement kickoff plug extending 100' MD below the base of the milled section and the bridge plug set approximately 200' below the section will serve as the liner top cement plug. The 9-5/8" casing is cemented or adjacent to an impermeable formation from the liner top to the milled section. This is consistent with the waiver request dated 9/17/92 for the case where the kickoff point is 400' to 2000' from the existing production liner top. A U G 1 6 Alaska 0il & Gas Coils. Conlmissio~ A~]chorage C-14 PROPOSED PLUGBACK Proposed Top of 7" liner @ 9450 MD Window in 9-5/8" @ 9600-9650 MD 18 PPG MUD Cement @ 9650-9750 MD 9-5/8" Bridge plug @ 9880 MD Tubing cut @ 9900 MD Old parfs plugged TOC @ 11,110 MD (tagged 5/91) Top of Fill 11860 MD Original PBTD 11935 MD TD Displacement of 680 ' TD @ 12752 MD Ri C[IVED A U 6 1 6 199,~ Alaska 0il & Gas Colin. 6ommission Anchorage sssv ND,NG N PPLE i (OT,S)(4.562'~D) [ 2003' J FOC-- L~ 13-3/8", 72#/fi, 12700' j~'~ L-80, BTRS KOP: 2800' MAX ANGLE: 58° @ 9400' 5 1/2', 17#/It, L-80, · ..~_... ~ 5 1/2' MERLA PATCH (3.75" ID) 10,059' BTRS/ABMOD TUBING (IPC) .~CROSS TBG PERES TUBING ID: 4.892" ..' ~ 10,068 - 10,072' (32- 1.69" HOLE~ )1 0,090' CAPACITY: .0232 BBI_/FT ~/~ · ..... ~.,-V"..~t. ~ / I~.~..A'-L)~ ,~ c.... OTIS 'XA' (4.562" ID) , ~,..~.....~' c~'-_ '~r'~c' ~ '~ qoo ~ ~ 9-5/8' PACKER i i ( BOT ) (3.813"1D) i , ~ 4 1/2', 12.6#/ft, L-80 TAILPIPE ,110.310'1.-.i ! I 41/2- -x-N,P.LE I In 7' LINER, ~ ~ (OTIS) (3.813' ID) , ; (OTIS) (3.725' ID) 9-5'8', 47#/1t, 0,832'J~ jI ' i~ 4 1/2' TBG TAIL L-80, 9TRS I I ik (BOT WLEG ) (ELMD) ~NOTE: I; 7/8" "XXN" NIPPLE (2.313" IDI .PERFORATION SUMMARY ! REF LOG: SWS - BHCS- 2-10-80 SiZE SPF INTERVAL OPEN/SQZ'D ....... ~ 11,110' TOP OF CMT P LUG ON 5-31-91. 3 1/8" 4 11,776 - 11,786' SQZD/4-2-89 · 4 11,796- 11,826' ' ' · 2 11,826- 11,836' SQZD/5-29-91 ;;; **;;; ~ MARKER JOINT · 2 11,840 - 11,856 .... · 2 11,862 - 11,S66' ' ' 2 11,890 - 11,896' ' ' ' ...... PBTD ] 11 __ClR.~'] ~ ,,,,~,,,,,..,.. 7',29#~, L-80,~TRS {11.988'l-- DATE REV, BY COMMENTS PRUDHOE BAY UNIT 2-16-80 INITIAL COMPLETION WELL: (~-14 (44-17-11-14) 9-7-82 RWO APl NO: 50-029-20413 SEC 19; TN 11N ' RGE 14E 6-30-91 A. TEEL REVISED 8/2/91 REVISED BP Exploration (Alaska) A/aska 0il & Gas Cons. Comrnissiou Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE. 2. [2 thru 8]' ' ' 3. 4. (3) Admin thru lV~3'],~, '- '~" ,¢? [ 10 '" S 13] (4) Casg ~' .~/*''' t I [14 thru 22] (5) BOPE [23 thru 28] · 6. 7. 8. 9. 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES Is permit 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 undo. dicated acreage available in this pool ............. /~ Is well to be deviated & is wellbore plat included ................... ~_ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Lease & Well NO REMARKS Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... ~ . Is lease nLmber appropriate ......... ~_ Does well have a unique name ~ nL~nber Is conductor string provided ......................................... Wil 1 surface casing protect al 1 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 wellbore ....... _~ I s ol d wel 1 bore abandonment procedure i nc 1 uded on i I~-/~ ] ] ] ] ] ] ....... Is adequate wellbore 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 ...................................... ?-- '1]'29 thrTM .~1 ] c7) [32] (8) Addl 29. 30. 31. 32. 33. geology' engineering: DWJ~ MTM RAD_~- 2- o RPg~ BEW~)_~ JD~ TAB ~ 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 nunber of contact to supply weekly progress data ...... Additional requirements Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' MERIDIAN' UM ~ SM WELL TYPE' Exp/CD_~/X~ Inj Redrill 2~ Rev O -T'Z ~O