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194-020
Pages 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. ~-~0 File Number of Well History File PAGES TO DELETE RESCAN [] 121 Color items- Pages: ~ '~ t I ~-~ t"~¢¢' ~ Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original - Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [3 Logs of vadous kinds [] Other Complete COMMENTS: Scanned by: Beved~Dian~hVincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent ~owell Date: I~_ S Is/ ~,,./(~ FW: NK-I6 (PTD #1940200) IA Re ssurization Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, October 15, 2007 7:52 PM ~/ ~ ~~~~ `~ ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) t, Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; NSU, ADW Well Operations Supervisor Subject: FW: NK-16 (PTD #1940200) IA Repressurization Jim and Tom, /, A recent IA bleed of NK-16 indicates repressurization of 150 psi/day. Our plan forward is to perform an MITlA and apply for an AA if it passes. if the MITIA does not pass. the wel{ will be shut-in and secured. Please call With any questions or concerns. Thank you, Andrea Hughes ~~ NCB' ~. ~ ZOD7 From: NSU, ADW Well Integrity Engineer Sent: Monday, October 08, 2007 4:Z1 PM To: GPB, LPC DS Ops Lead; GPB, GPMA OTL; GPB, Area Mgr North (Gas Plants/GPMA);_.~ossbery, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; 'James Regg'; Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Ramsay, Gavin Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: NK-16 (PTD #1940200) IA Repressurization Hi all, Well NK-16 (PTD #1940200) has been exhibiting IA repressurization. The well will remain on-line while the following diagnostics will be conducted to evaluate the repressurization. The plan for ward is: 1. W: PPPOT-T 2. D: Bleed IAP to 200 psi, monitor for BUR 3. WIE: Consider AOGCC MITIA if IA repressurizes A wellbore schematic and TIO plot have been included for reference. 10/29/2007 • LOOUbUOL t00U8/O6 LOOU6U6 LOOU~/6 t00U6tJ8 t00U£Y8 LOOUtW1 4000 i- 'd00 tooU wt w~F- 0 dSH'dW'd0 000 ~ 000°Z tll -~- 6ql + -z2~-~'~~' ~d 000°£ fold all 9L'NN ooo'b ~ TREE = 4-1;16°' 5fa1 CMI i V`JELLHEAD= 23-518"SItRFMC UN~,'ERSAL ACTUATOR KB. ELEV = i9. a`' BF. ELEV = KOP , ` .~~e,~,. t: Mtax 2ngle~~ . ~ 65 ~ 8802` _..~..~...,.m._ ~....~... Datun7 MD = ~.~_~ ~_,-,~,. 12685' ,._ _~ ~,. datum ND ~ _ , .~, _ 92f7Q' SS 10-3{4" CSG, 45.5#, NT-80, Id = 9.953°' ~--{ 0' GAS LIFT MANDRELS ST Md TVd dEV TYPE VLV LRTCH PORT BATE 2 1 4759 12401 4464 8899 5Q 19 MERLA-TMPdX MERLA-T~:1PC1X BK BK 3-1f2" HES NIPPLE ^ ~, SAFETY NOTES: __.__. J li ., ,~ J 2140' I~ 4-112°' HES X NIP. Id = 3.813„ 12551' 4-1 t2" HES X NIP, Id = 3.813" 12562' ~ 7-5,`8" X 4-112" BAKER SABL PKR Vs{,' ANCHOR LATCH; ID = 4.75Q" 125$6' 4-1{2" HES X NIP. Id = 3.813„ 9259T 4-1t2" HES XN NIP, Id = 3.725" TOP OF 5-'l i2"' LNR ~ 121505' 4-112" TBG, 12.6#, L-80, 12609" Q.0152 bpf, Id = 3.958'. 7-5{8" CSG, 29.7#; I~IT-s5 Hs, ~ 127$1' .0459 bpf, Id = f.875" TOP OF 3-1/2" TBG ~----~ 12902' 3-1,°2" T6G, 9.3#, L-80, .OD87 bpf, id = 2.992" 92915° PERFORATION SUMMARY REF LOG: ATLAS SBL on 05.?10195 ANGLE AT TOP PERF: 23 cz? 12088' Note: Refer to l~aduction dB for historical pert data SIDE SPF INTERVAL Qpn?Sqz BATE 3-3(8" 6 12800-12840 O 05?28/95 3-3; 8" 6 1285©-12893 fl 08I10i95 3-3{8° 6 12912-12917 fl 05%12{95 3-3; 8" 6 12806-12811 O 05.??27!95 PBTd 93079' 5-1{2" LNR; 17#, NT-80, O.Q232 bpf, IC3=4.892" 93160' 12609` °i 4-1(2" TUBING TAIL WLEG 12617' ELMd TUBING TAIL 12~ 902' 1-`~ 5-1/2" X 3-1i2" FB-1 PICR, Id = 3.937" 12912' 3-1l2" HES X NIP, Id = 2.75" 92915' -~-~-112" MULESHfll2~ 12913' ELMd MULE SHOE (05i26i95) BATE REV BY COMMENTS DATE REV BY COfv1(~tENTS 05f16f95 4R4G1NAL CC3MPLE7"tON .r 09? 08{Q6 CS~'PJC TV Dr MQ dATUM C©RRECTIO ~.~~ NIAKIIK UNfC WELL: NK-16 PERMIT No: 94-G22 API No: 50-C29-22447-00 Sec. 36, T12N; R15E, 851.75 FEL 4293.93 FNL BP Exploration {Alaska) ON OR BEFORE c:LORikM~ILM,DOC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:ChairmanDan Seamount p/~ THRU' Blair wondzell ~.,~..~ P.I. Supervisor ~f~;(oO FROM: LOU Grimaldl~ (~ ~'~, DATE: September 25, 2000 SUBJECT: Mechanical Integrity Tests BPX Niakuk NK-10, 16, 23, 38 Prudhoe Bay Unit Petroleum inspector Niakuk Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. '30 Min. WellI NK-10 I~,e,.~.l ~ I~.v.~l ~0~ I~,~,n~l ~:: I ~000 I ~0~0 I ~0~0 Ilntervall 4 ' P.T.D.I 1931840, TYpetestI 'P Testpsi 2254 Casing 2460 2420. 2420 P/F I 13 Notes: Observed )retest conditions for ~hi~y minutes "OK". P.T.D.I 1940220 T~petestI P ITestpsi 2286. C~sing 1100 2490 2460 2440 P/F I ~ Notes: Obse~ed )rete~ conditions for thidy minutes "OK". WellI NK-23 Typ ,nj,I s I Tubingl I I I' I,nte all 4 P.T.D. 1940350 TypetestI P I Test ~si 2102 Casing 1050 2450 2420 2420 P/F I ~ Notes: ~e,! ~-~ I~e,~.l ~ I,.~.~.l **~ I,u~,~,l ~o I ~o~o I ~oo I ~oo I'n~e~'l ~ P.T.D.I 1941700 TypetestI P ]Test psi 2341 Casing 20 2480 2440 2450 PIE ~ Notes: Obse~ed )retest conditions for thi~y minutes "OK". WellI Type Inj. I I T.V.D. Inte~al P.T.D.I Type testI ITest psi~ ITubing ~ot~' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P-- Standard Pressure Test R= Internal RadiOactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) Test's Details I met Joe Anders and the HBR crew on the Niakuk pad. The testing went well with all wells exhibiting competent tubing and casing. Wells # 10, 16 and 38 tubing injection pressures were high enough to exhibit the required minimum of 500 psi differential between tubing and casing. These wells were held and observed at their pretest conmditions for thirty minutes with no change in annulus pressures observed. The wellhouSes and pad were in good condition. Subsidence does not seem to be a issue on this pad. M.I.T.'s PerfOrmed: 4_ Number of Failures: Attachments: Well schematics {4.) Total Time during tests: 4 cc: Joe Anders/Kevin Yea,qer (BPX) MIT report form 5/12/00 L.G. MIT NIAKUK 9-25 LGT.xls 9/26/00 Memorandum To: Well File: qq --- ~~)..~ 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 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 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 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 (wetibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician April 28, 1994 PETROYINA DELAWARE, INCORPORATED P. O. Box 62102 Houston, Texas 77205-2102 14950 Heathrow Forest Pkwy. S. Suite 300 Houston, Texas 77032 (713) 936-6000 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attention: Mr. Bob Crandell Re: BP Exploration (Alaska), Inc. Badami No. 3 Well Gentlemen: Please be advised that Petrofina Delaware, Incorporated ("Petrofina") is a leasehold owner within the drillsite lease ADL#365533. Petrofina is aware of BP's plans to drill the Badami No. 3 Well in conjunction with their requested spacing exception, and has no objection to the drilling of said well nor its location. Respectfully, Thomas M. Wadsworth Attorney-in-Fact JPT:WEF:klt CC: Mr. R. L. Skillern BP Exploration (Alaska), Inc. RECEIVED 1A¥ - 9 1994 Alaska Oil & Gas Cons. Commission Anchorage inspinfo.frm INSPECTION INFORMATION - EXPLORATORY WELLS ~his form is intended to supply some basic well information that will be useful to the inspectors when inspecting diverter and. BOPE systems. Conductor size: Diverter line: size: , configuration: Surface hole size: / 7 ~Q'F-," Surface Casing size: /3F~and weight & grade: Surface casing BOP: size: , Pressures - WP/TP: / Intermediate hole size: , ;~'c Prod casing size: ~_ ~ and weight & grade: &(~ Sr N r-~5~ Prod casing BOP: size: Liner hole size: Liner/casing size: · Pressures - WP/TP: and weight & grade: ~ '80 Hydrogen Sulfide ~asures: ~% Name: ·Date: / ! ALASKA OIL AND GAS / CONSERVATION CO~IMISSION / May 5, 1994 WALTER J. HICKEL, GOVERIVOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Badami #3 BP Exploration (Alaska), Inc. Permit No: 94-20 Sur. Loc. 1355'SNL, 1637'WEL, Sec. 10, T9N, R20E, UM Btmhole Loc. 3759'NSL, 4121'WEL, Sec. 3, T9N, R20E, UM Dear Mr. Clark: 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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 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. April 28, 1994 PE TRO¥1NA DELAWARE, INCORPORATED P. O Box 62102 Houston, Texas 77205.2102 14950 Heathrow Forest Pkwy. S. Su~te 30O Houston, Texas 77032 (713) 936-6000 VIA FAX AND MAIL State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501.3192 Attention: Mr. Bob Crandell Re: BP Exploration (Alaska), Inc. Badami No. 3 Well Gentlemen: Please be advised that Petrofina Delaware, Incorporated ("Petrofina") is a leasehold owner within the drillsite lease ADL#365533. Petrof'ma is aware of BP's plans to drill the Badami No. 3 Well in conjunction with their requested spacing exception, and has no objection to the drilling of said well nor its location. JPT:WEF:klt CC.' Mr. R. L. Skillern BP Exploration (Alaska), Inc. Respectfully, Thomas M. Wadsworth Attorney-in-Fact RECEIVED t994 Alaska Oil & Gas boris. Cornr~i$$~o° Anchora..q~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 1, 1994 Mr. Robert P. Crandall AOGCC 3001 Porcupine Drive, Anchorage, AK 99501-3192 Ref.: Badami #3 Exploration Well Weekly Staus Report Contact Geological Information Contact Dear Mr. Crandall, In reference to your request for a contact person at BP Exploration for the weekly status report and the end-of-well reports as required by 20 AAC 25.070 and 20 ACC 25.071, the following persons will be responsible for Badami #3: Weekly Status Report: Tim Billingsley- Drilling Engr. 564-5405 20 AAC 25.070: Tim Billingsley- Drilling Engr. 564-5405 2O AAC 25.071' Tim Putnam- Petrophysicist 564-4791 As you know, Badami #3 has been postponed and these names that I have provided are subject to change when the well is hopefully drilled next winter. If there any questions, please call me at 564-5405. Sincerely, ' /_' ' z/ /"~"'; ['-'t, ..f/ ., L:/)~' Ti~m Billingsley (_~.-// Drillin~ fin~inoor- ~rudhoo Bay Drillin~ Ar~chorag~; ., FRi i 0: 4~ F~× NO, P, D2 ST ~K/DiV OiL AND GAS DEPT. OF NATURAL RESOURCES DI~$tOH OF OIi. AND 0,48 9075823852 WALTER J. HIC,. . 'L, GOVERNOR P.O, BOX 107034 ANCHORAGE, AI.~KA 99510.7034 DECISION JAN ! S 199 Assignor: Conoco Inc. Attn: Business Development Manager 3201 C, Street, Suite 200 Anchorage, AK 99503*3999 Assignee: BP Exploration (Alaska)Inc. Attn: Land Manager-Alaska P.O, Box 196612 Anchorage, AK 99519-6612 Oil and Gas Lease ADL 365533 _Assignment Appli~_ation Approved Application for approval of assignment of 66.67 percent working interest from Conoco Inc. to BP Exploration (Alaska) Inc. is hereby approved effective December 30, 1993. This assignment is approved as to the working interest only and does not constitute approval or acceptance of any stipulatlon~ or attachments to the a,,s~gnmcnt instrument,. An approved assignment Is enclosed with this clecision. Eason UDIrector Enclosure JE/J$/355533 RECEiV ED ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER,]. HIC, KEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 12,1994 Tim Billingsley, PB Drlg Engr BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Exporatory well Badami #3 Dear Mr Billingsley: This is to review the reporting requirements (20 AAC 25.300) associated with the approval of BP's application for a permit to drill the Badami #3 exploratory oil well. Please designate a BP employee to generate the weekly status report. This report is required from the time the well is spudded until it is suspended or plugged and abandoned; it should be a generalized synopsis of the week's activities. This information is exclusively for the Commission's internal use, and will be kept strictly confidential. It can be phoned or faxed to me or, in my absence, to Blair Wondzell. Following suspension or abandonment of the Badami #3 well, a member of your staff who is familiar with the project will be expected to coordinate the submission to the Commission of reports and materials as required by 20 AAC 25.070 and 20 AAC 25.071. If you have any questions regarding those regulations, please call me at 279-1433. Please advise me in writing of the name(s) of BP contact(s) for this well. This information is required prior to approval of your application for permit to drill. I look forward to working with you and your staff. Yours very truly, / Robert P Crandall Sr Petr Geologist /jo c: well file A:\RPCexpl-rpt BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 7, 1994 Mr. D. W. Johnson AOGCC 3001 Porcupine Drive, Anchorage, AK 99501 Ref.' Badami #3 Exploration Well Dear Sir, Attached is an application for a permit to drill the above referenced well. There is no close approach data included as the nearest well (Badami #1) is some 1.5 miles distant. A review has been performed of seismic data over the location and offset well information, in the search for any shallow gas accumulations. A letter is attached concluding that these surveys do not indicate the presence of a shallow hazard. Included in this application is a request for exemption to hydrogen sulfide requirements. Offset wells indicate no H2S is present in the area and this well will not penetrate the Lisburne formation. This well will utilize a 10,000 psi BOP stack (diagram enclosed). The diverter and mud sytem schematic will be consistent with those on file at AC)GCC for Nabors Rig #22E. If there any questions, please call me at 564-5402. Sincerely Tim Billi ngsle.y/ Drilling Engineer- Prudhoe Bay Drilling STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 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 RKB =35' AMSL feet Wildcat 3. Address 6. Property Designation P. 0. Box 196612. Anch(~rage. Alask~ 9951~-6612 ADL 365533 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 20 AAC 25.025) 1355'SNL, 1637' WEL, SEC. 10, T9N, R20E Badami At top of productive interval 8. Well number Number 2416' SNL, 3688' WEL. SEC. 3, TgN, R20E Badami #3 2S100302630-277 At total depth 9. Approximate spud date Amount 3759' NSL, 4121' WEL, SEC. 3, T9N, R20E 2/1/94 $200,000°00 12. Distance to nearest i13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandmVD) / line prop L377011-1526' feet Nocloseapproach feet 5120 13534'MD/712035°TvD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o3s (e)(2)) Kickoff depth ~5oo feet Maximum hole angle 3o 0 Maximum surface 6153 psig At total depth (TVD) 12035Y7473 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" 1044t ER W Weld 80' 30' 30' 11 O' 11 O' 260 sx Arcticset (Approx.) 17-1/2" 13-3/8" 72# L-80 BTC 5463' 30' 30' 5433' 5035' 3200 sx PF "E"/410 sx "G"/250 sx PF II 12-1/4" 9-5/8" 47# NT95HS NSCC 3720' 30' 30' 3750' 3582' ~'~" 9-5/8" 47# NTaOS NSCC 7469' 3750' 3580' 11219' 10035' 590 sx Class "G" 8-1/2" 7" 29Yt L-80 NSCC 2515' 11019' 9862' 13534' 12035' 500 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 R E C E IV E D ~ Surface Intermediate Production J/~,N ] 0 19~' Liner Perforation depth: measured I.'d~'si:,a Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~l Drilling fluid program/E1 Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify~hat the foregoihg is true and correct to the best of my knowledge 1 Signed ,/"t ~ U--~'7"t~ Title Drilling Engineer Supervisor Date i Commission Use Only Permit Number APl number IApproval date See cover letter /9 ~...;~ 5 O- 0 ~..?J 7_.., ~.~ ~'/--7' / I ~5'"'%' ~ ' ~' ~./z. for other requirements Conditions of approval' Samples required [] Yes [] No Mud Icg required,l~Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey requ~rea J~ Yes [] No Required working pressure for BOPE [] 2M; FI3M; [-15M; I~110M; []15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner ~ne comm,ssion Date Form 10-401 Rev. 12-1-85 Submit in t cate WELL PLAN Well: Badami #3 Sec. 3, T9N, R20E LOCATION: Surface: Target: T.D.: 1355' FNL, 1637' FEL, S10 T9N R20E 2416' FNL, 3688' FEL, S3 T9N R20E 3754' FSL, 4121' FEL, S3 T9N R20E ESTIMATED START: OPR. DAYS TO COMPLETE: ~RACTOR: 1st week of February, 1994 68 (61 days drill, core and log; 7 days testing) Nabors 22E MAX ANGLE/AZIMUTH/KOP/BUILD/MAX DEP' 30°/334°/1500'/2°per100'/5685' Estimated Ground level elevation is 5' AMSL. KB to ground level elevation is 30'. RKB-35' Item TVD(SS) MD(BKB) Pore Pressure. Mud Wt. 20" CONDUCTOR 8 0 11 0 8.5 8.5 BASE PERMAFROST 2000 203 8 9.0 9.2 13-3/8" SHOE 5000 5433 9.0 9.2 9-5/8" SHOE 10000 11219 11.0 11.3 TOP OF TARGET 1 0300 11566 11.3 11.6 TOTAL DEPTH 1 2000 1 3534 1 2.0 12.3 CASING PROGRAM: Hole Csg Wt Grade Conn Length 30" 20" 1 04 # ERW WELD 8 0 1 7-1/2" 1 3-3/8" 72# L-80 BTC 5403 1 2-1/4" 9-5/8" 47# NT95HS ~ 3720 12-1/4" 9-5/8" 47# NTSOS NSCC 7469 8- 1/2" 7" Liner 29# L-80 NSCC 2515 Top 3O 3O 3O 3750 11019 Btm 110 5433 3750 11219 13534 LOC-~ING PROGRAM: Open Hole- 17-1/2" Hole: MWD/LWD- Directional only Open Hole Wireline- 13-3/8" csg pt to surface, RUN #1- DIFL/GR/MAC/TEMP Open Hole- 12-1/4" Hole: ...Open Hole - 8-1/2" Hole: MWD/LWD- GR/RES/DIR +_6500 TVD to Csg Pt. Open Hole Wireline- 12-1/4" TD to surf csg. Run #1- DIFL/SP/GR/MAC/TEMP Run #2- ZDL/CN/GR/TEMP/MINILOG Run #3- RCOR (if oil present) MWD/LWD- GR/RES/DEN/DIR Open Hole Wireline- TD to 9-5/8" csg Run #1- DIFL/SP/GR/MAC/TEMP Run #2- ZDL/CN/Speotral GR/CAL/TEMP/ MINILOG Run #3- FMT/GR Run #4- RCQR Run #5- DIP/CBIL/GR Run #6- SWC PERCUSSION (50 shots) Run #7- CHECK SHOT (VSP MAY BE ADDED) Cased Hole CBT/CET will be run if DST is to be performed PROPOSED DRILLING PROGRAM WELL: Badami #3 (Sec. 3, T9N, R20E) It is proposed to drill Badami #3 as an exploration well from an ice pad using rig Nabors 22E. Access to the site will be via a 32 mile ice road teeing off from the Endicott causeway access road and following the coast to Badami #3. The top of overpressure is expected to occur at 9500' TVD and a top of moderate overpressure is expected at 10,400' TVD. (See attachments) Shallow gas hazards are not expected. (See attachments) Ooerations: Construct ice road and pad at Badami #3 surface location. Set 20" conductor. MIRU Nabors #22E. NU diverter and function test same. Full mudlogging facilities will be on location from spud to TD. Drill 17-1/2" hole with kick-off point @ 1500'. Directionally drill to approx. 5000' TVD (5433' MD). Run wireline logs. Run 13-3/8" surface casing, cement to surface. Install and test blowout prevention equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum anticipated possible bottomhole pressure is 7473 psi at TD. Maximum possible surface pressure is 6153 psi based on a gas column to surface from TD. Formation leak-off tests will be performed 10' below the 13-3/8" shoe and 10' below the 9-5/8" shoe, Drill 12-1/4" hole to appx. 10,000' TVD (11,250' MD). Run wireline logs. Run 9- 5/8" intermediate casing to surface. Cement with Class G cement (covering any hydrocarbon intervals). Directionally drill a 8-1/2" hole to TD @ appx. 12,000' TVD (_+13,500' MD). Conventional coring is possible in this interval. Run wireline logs. A decision to run the 7" liner for a DST will be based on log and core information. If the liner is run, it will be cemented using Class G cement. If no liner is run, the 8-1/2" open hole will be plugged and abandoned in accordance with AOGCC regulations. Any DSTs will be conducted with the rig on location. Fluids and cuttings incidental to the drilling of the well will be hauled to Prudhoe Bay for disposal. The possible exception would be annulus injection of fluids in the 9-5/8" x 13-3/8" annulus during the drilling of the 8-1/2" production hole. RECEIVED The well will be suspended or abandoned with the appropriate plugs and markers according to AOGCC regulations. The rig will be moved from location and the pad cleaned up of any surface debris prior to spring break-up. The nearest offest well is Badami #1 located 1.5 miles to the west of this proposed Badami #3. Hence no close approach data is included in this package. Offset well information indicates no H2S or CO2 gas will be present at Badami #3. The drilling fluid program and surface system will conform to the reguations set forth in 20AAC25.003. RECEIVED , i ,"'~ f'.! 'i 0 ~"-:, o/,,. ?¢ ::.:..',:: (_)ii & Gas Cons. Commission Anchoragr~ MUD PROGRAM: Badami #3 MUD SPECIFICATIONS- SURFACE HOLE Mud Weight: ppg Funnel Viscosity sec/qt YP lbs/1 00ft2 10 sec Gel Ibs/100ft2 10 min Gel Ibs/100ft2 pH APl Fluid loss mi/30 min Solids Surface: 8.5 - 9.3 250-300 30-70 10-30 25-70 8.5-9.5 12-25 < 10% MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to 10,000' TVD: LSND Gel/Water System Mud Weight ppg 9.3-1 0.0 10.0-11.3 Yield Point Ibs/100ft2 6- 1 2 10-15 o 10 sec Gel Ibs/100ft'- 5- 1 5 8-18 10 min Gel Ibs/100ft2 1 0-25 12-28 APl Fluid Loss mi/30 min 8-1 0 5-6 pH -- 8.5-9.5 Casing point: 9.3 60-80 3O 15 - 20 25 - 35 8.5-9.5 8-12 <10 % (From 5000' to 9000'TVD) (From 9000' TVD to casing pt) (From 5000' to 9000'TVD) (From 9000' TVD to casing pt) (From 5000' to 9000'TVD) (From 9000' TVD to casing pt) (From 5000' to 9000'TVD) (From 9000' TVD to casing pt) (From 5000' to 9000'TVD) (From 9000' TVD to casing pt) MUD SPECIFICATIONS-PRODUCTION INTERVAL: Watered back mud system used in intermediate hole. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel Ibs/100ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH 11.3-12.3 8 - 20 5-12 9 - 20 5-6 9.0 - 9.5 Drill out the 9-5/8" casing and dump severely contaminated fluid. Continue drilling with this fluid until core point. At this point, a decision will need to be made on whether or not to displace with a KCI core fluid. Whichever fluid is used while coring will be maintained to TD. Estimated Overbalance in the Production Hole Design Mud Wt. (8-1/2" Hole)' 12.3 ppg. Maximum anticipated formation pressure at 12,000' TD: 7473 psi at 12,000' TVD Overbalance @ TD: 202 psi RECEIVED j/',i'[ 'i 0 Anchora~ Nabors Rig #22E Drilling Fluid System Description Mud Pits and Caoacities Number Volume Active Pits 4 1200 bbls Trip Tank 1 80 bbls Pill Pit 1 20 bbls Mud Fa0ilities ~,ncl Eauipment Shale Shakers: 2 each, Derrick Model 58 screen shale shakers Mud Cleaner: 2 each, Derrick Model L-48-96 dual manifold mud cleaners, each with sixteen 4" desilter cones and two 10" desander cones. Each mud cleaner charged by one Harrisburg Model 250 5"x6" pump rated at 800 gpm at 14 ppg. Centrifuge: One Pioneer Mark I, rated at 100 gpm. Gas Buster: One each, 6' high x 6' wide with one 3" inlet, one 4" gas exit line and one 12" mud exit line. 15 psi rated working pressure. Number of surface guns on pits: 9. One Monarch 73B cellar jet pump, rated at 75 gpm. RECEIVED ~,,~ ,~..~ ~'i~i & (.}',a.~.; Col'is. C31:rii'rlissior~ Anchorag9 13-3/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 13-3/8" CIRC. TEMP 70°F @ 5000' TVD SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: PERMAFROST TYPE E WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gps APPROX #SACKS: 3200 THICKENING TIME: 6:00+ hrs TAIL CEMENT TYPE: CLASS G W/2% CACL2 ADDITIVES: As Required WEIGHT: 15.8 ppg APPROX #SACKS: 410 YIELD: 1.15 ft3/sx THICKENING TIME: 4 hrs MIX WATER: 5.0 gps TOP JOB CEMENT TYPE: PERMAFROST II ADDITIVES: NONE WEIGHT: 15.6 ppg YIELD:0.95 ft3/sx MIX WATER: 3.7 gps APPROX #SACKS: 250 CEMENT VOLUME: 1. Lead slurry from 500' above shoe to surface w/100% excess:. 2. Tail slurry volume 500' above shoe from 5467' to 4967' w/15% excess plus; 80' MD 13-3/8" 72# capacity for float joints for a total of 410 sx. 3. Top job volume,if necessary: 250 sx. ?,~.-..'~a ;',;i & Gas Cons. Commission Anchorag':, 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140° F @ 10,000' TVD SPACER: 50 bbls Arco Preflush, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: Class G w/extenders WEIGHT: 11.5 ppg APPROX #SACKS: 440 YIELD: 1.75 ft3/sx MIX WATER: 12 gps THICKENING TIME: 5:00+ hrs TAIL CEMENT TYPE: CLASS G ADDITIVES: as required WEIGHT: 15.8ppg YIELD: 1.15 ft3/sx MIX WATER: 3.7 gps APPROX #SACKS: 350 THICKENING TIME: 4 hrs CEMENT VOLUME: 1. Lead G neat slurry from _+1000' above shoe to appx 7000' TVD (7800' MD) with no excess. Exact TOC to be determined by top of significant hydrocarbons from logs. 2. Tail G slurry to ___1000' md above shoe with 15% excess. Review caliper Icg for excessive washouts and adjust volumes if neccessary. 3. 80' md 9-5/8", 47# capacity for float joints. 7" PRODUCTION LINER CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 160° F @ 12,000' TVD SPACER: 50 bbls Arco preflush + 1% S-400. CEMENT TYPE: CLASS G ADDITIVES: as required WEIGHT: 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 3.7 gps APPROX #SACKS: 500 THICKENING TIME: 5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/ cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME: . . Open hole +50% excess (adjust if a caliper Icg is run and it indicates severe washouts). 7", 29# casing capacity below landing collar (120'). 150' liner lap 200' of cement on top of the liner in the 9-5/8" casing. Cons. ,. ' I3~S"-' PRESSURE INFORMATION Badami #3 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Badami #3 well. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (SS ft.) (lbs/gall (lbs/gal) lpsi) (psi) 20 80 11.6 8.5 35 39 1 3-3/8 5000 12.8 9.0 2335 2778 9-5/8 10000 14.5 11.0 5708 6153 7 12000 15.2 12.0 7473 Procedure for Calculating Anticpated Surface Pressure rASP/ ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP - (0.11 x D) where' FPP = Formation Pore Pressure at the next casing point ASP Cal<Fvlation~; 1. Drilling below conductor casing (20") ASP = ... [(FG x 0.052) - 0.11]D [(11.6 x 0.052) - 0.11] x 80 39 psi ASP = --. --. FPP - (0.11 x D) 2335 - (0.11 x 5000) 1785 psi ASP Calculations !continued) 2. Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.11]D = [(12.8 x 0.052) - 0.11] x 5000 = 2778 psi ASP= FPP - (0.11 x D) = 5708 - (0.11 x 10,000) = 4608 psi 3. Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.11]D - [(14.5 x 0.052) - 0.11] x 10000 =6440 psi ASP-- FPP - (0.11 x D) = 7473 (0.11 x 12,000) -- 6153 psi Badami #3 Casing Design Specifications SURFACE CASING 13-3/8", 72# L-80 BTC CASING BURST L-80 5380 COLLAPSE PBYS (#) TJYS (#) 2670 1661000 1650000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (12.8 ppg) at the surface casing shoe less gas gradient of .11 psi/ft. LOT (ppg) TVD (FT) SI PRESSURE 12.8 5000 2778 Burst S.F. 1.94 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.3 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.3 5000 2418 Collapse S.F. 1.1 0 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 72 5433 PBYS Tension S.F. 4.95 Mud Wt. 9.3 TJYS 4.92 String Wt. (#) 335584 Badami #3 Casing Design Specifications Intermediate Casing 9-5/8" 47# NT95HS to 3750' MD, NT80S to 11219' MD GRADE BURST COLLAPSE PBYS (#) NT-95HS 81 50 71 50 1311000 NT-80S 6870 4750 1122000 TJYS (#) 1311000 1122000 Burst Pressure Calculation for NT-95HS @ 3750' MD Assume worst case at surface of formation pressure less gas gradientof .11 psi/ft.. Form. Press. Depth TVD SITP 12.0 12000 6168 Burst S.F. 1.32 Burst Pressure Calculation for NT-80S @ 3750' MD (3580' TVD)- 11219' MD Assume worst case at surface of formation pressure less gas gradient. Form. Press. Depth TVD TVD of Top csg MW in annulus SITP SITP @3750' 12.0 12000 3580 11.3 61 68 5774 Burst S.F. 1.87 Collapse Calculation Collapse rating based on casing being evacuated Mud weight behind the casing is 11.3 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) 11.3 10000 0.11 Collapse S.F. 0.99 Collapse press 4776 Full evacuation unrealistic @ this depth Collapse S.F. I .00 For 97% evacuation Tension Calculation for NT-95HS @ surface Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 47 11219 11.3 PBYS TJYS Tension S.F. 3.01 3.01 String Wt. (#) 436241 Tension Calculation for NT-80S from 3750' MD to 11219' MD Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 47 7469 11.3 290426 PBYS TJYS Tension S.F. 3.86 3.86 Badami #3' Casing Design Specifications PRODUCTION LINER 7", 29#, L-80, NSCC Casing GRADE BURST L-80 8160 COLLAPSE PBYS (#) TJYS (#) 7030 676000 718000 Burst Pressure Calculation Kill wt. fluid in annulus with test packer set inside liner and annulus pressure applied to function APR tools in hole Ann. Press. Annulus fluid back up (ppg) Burst Pressure 2500 12.3 11.3 3124 Burst S.F. 2.61 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 12.3 ppg (assume well suspended as future producer) Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) 12.3 12000 0.11 Collapse S.F. I. 11 Collapse Press 6355 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 29 2515 12.3 59226 Tension S.F. PBYS TJYS 11.41 12.12 Badami #3 Request for Exemption to Hydrogen Sulfide Requirements 20 AAC 25.065 (c) BP Exploration (Alaska) Inc. as operator of the Badami #3 well respectfully requests exemption to the hydrogen sulfide requirements as per 20 AAC 25.065 (c). Offset well information indicates there is no hydrogen sulfide gas present in any of the formations which Badami #3 will be penetrating. The Lisburne formation will not be penetrated by the Badami #3 well. Even though no formations which the Badami #3 will penetrate are expected to contain hydrogen sulfide, a mudlogging unit with audible and visible alarms will be on the well and will monitor for hydrogen sulfide- at the shale shakers and at the bell nipple and the Nabors #22E rig will be equipped with six Scott Air-Packs at the rig floor as standard equipment. All personnel on location wilY be trained for emergency procedures in the presence of H2S as standard operating procedures. It is not deemed necessary by BP Exploration, Inc. to develop a further contingency plan. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: cc: From: Subj: Jim Farnsworth - Exploration Mgr. R.L. Skillern - Land Tim Billingsley- Drilling Peter Hanley- Enviromental Well File- Badami #3 Walt Fulroth ¢//-/~' Shallow Gas Survey for Badami #3 wellsite Date: 29-Dec-1993 The Badami #3 well is currently planned to be drilled from a surface location of T09N, R20E, SEC 10, 1355' FNL, and 1637' FEL (Attachment I). Badami #3 drilling will start vertical and build along an azimuth of N26°W to an angle of about 30° at an aPproximate depth of 4500' tvdss (approximately 990 mSec seismic two-way recording time) where 13 3/8" casing will be set. In accordance with Alaska State permitting requirements, the potential for shallow (<2000') gas sources in the vicinity of the proposed well location has been reviewed. Analysis consisted of examination of 3-D seismic data near the well site (see Attachment II) and looking for the the following effects: · anomalous high or low amplitude seismic reflectors · velocity pull downs or time delays along individual seismic reflectors · phase changes along otherwise continuous reflectors Excluding the long-wavelength statics anomaly associated with the thinning permafrost section at the shoreline, none of these effects were observed above 2000' near the proposed location. One minor amplitude increase occurs at about 2650' tvdss, but it is similar to other stratigraphically-related changes within this fluvial section. Existing wells within the area have no substantial gas shows above 2000', but minor gas shows associated with penetration of Iow- grade coal and peat horizons have been encountered in the 2000-4000' range. The nearest offset wells are located 1.5 miles to the southwest (Badami #1) and 2.7 miles east (East Mikkelsen Bay #1). WHF Hardcopy of Shallow Hazard Seismic Traverse __[, BADAMI .fl1 I BADAMI ~¥3! · ~ , ~..~ ..... ,~ . ..... . ~, ~ ..... ....... ~ ;%~- 2000 ~' ~ ~ ,~:.- ~" I-'- - '~, .~.,~ '" ~ ,.3000 . 5000 NW SEIW Else ~w~ SHORELINE SHORELINE ,i Amplitudes Positive Amplitudes GeoQuest SMstems, Inc. - ..... ~ 30-Dec-93 08: 19: 51 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: CC: Jim Farnsworth - Exploration Mgr. Heimer Fucke - Chief Geoscientist R.L. Skillern - Land Tim Billingsley- Drilling Peter Hanley - Enviromental Ed Travis - Exploration Engineer G.J. Pelka- geologist Well File ~ Badami #3 Date: December 29, 1993 From' Walt Fulroth'~/-¢~' Subj: Geophysical Analysis for Overpressure in the Badami #3 area The Badami #3 well is currently planned to be drilled from a surface location of' T9N, R20E, SEC 10, 1355' FNL, and 1637' FEL and be directionaily drilled to a TD bottom-hole location at T9N, R20E, SEC 3, 1593' FNL, and 4088'FEL at about 11,800 ft tvdss (Attachment I). Velocity analyses of 3-D, CDP seismic data in the vicinity of the Badami #3 well location were reviewed in an effort to determine formation pressure profile in the vicinity of the site of operations. This review was in accordance to State of Alaska permitting regulation 25.033, section El. Attachment il plots seismic RMS velocity vs. time in the vicinity of the Badami #3 well path. This plot suggests that the top of potential overpressure should fall between 9500' and 9800 ' tvdss. This is analagous to a similar plot from the Badami #1 (1.5 miles southwest) (Attachment Iil) showing the top of overpressure between 9450' and 9950' tvdss. The mud-weight buildup chart from Badami #1 (Attachment IV) confirms the top overpressure within this range. Results are also in agreement with observations of other wells within the area. Casing design and mud program allow for expected formation pressures. WHF AREA WELLSITES BADAM! #3: RMS VELOCITY VS TIME - CDP 632472 Seismic Time (ins 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 85.00 9O.O0 95.00 - 100.00 O0 (TVDSS) BADAMI #1' RMS VELOCITY VS TIME- CDP 632400 Seismic Time (ms) 1000 1200 1400 1600 1800 2000 2200 2400 2600 .~..~..-~ ......... T__-f~__-l--.._. ,f .... 85.00 90.00 95.00 100.00 :i (TVDSS) 2800 3000 --~-~-~ ..... ......... Badami I Mud Buildup o c) o o [] I I I i'-" , II I 2OOO 40O0 6000 8000 Depth (tvdss) 1OOOO 12000 14000 8OOO 7000 6000 5000 4000 3000 2OOO 1000 BADAMI #3 - PRESSURE VS DEPTH I I TVDSS IMud Weight iPore Pressure 1000 9.01 467 2000 9,0[ 934 -- 3000 9.0 1401 4000 9.0 1668 5000 9.0 2335 6000 9.0 2802 7000 9.2 3342 -- 80001 9.5 3944 9000!' 9.6 4484 95001 10.1 4979 100001 11.0 5708 10500! 11,5 6266 -- 11000 11.7 6679 11500 11.9 7102 12000! 12.0, 7473 ~ r~ I I I TVDSS Mud Weight iPorePressure 1000 9.0 467 2000 9,0 934 300O 9.O 1401 4000 9.0 1868 5000 9.0 2335 6000 9.0 2805 7O00 9.2 3342 8000 9.5 3944 90001 9.6 4484 9500 10.1 4979 100001 11.0 5708 10500 11,5 6266 11000 11.7 6679 11500 11.9 7102 12000! 12.0 7473 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Depth (tvdss) ', 1 BP EXPLORATION (ALASKA) INC. BADAMI AREA WELLSITES AND WATER SOURCES LOCATION MAP DATE: SCALE: SHEET: ~/3/c~3 1'= ! MILE 2' oF PRUDH©? BA YF~/ LEGEND I ~' P~0~OPOSED ICE ROAD ROUTE PROPOSED SEA ICE ROUTE WATER SOURCE PROPOSED WELLSITE EXISTING WELLSITE D(s) A(I)~ ~214) [ALASKA) INC. BADAMI AREA VICINITY MAP PRJ]D-HOE BAY DRI _LZNG G-fq'O'UP ,~- ...... , ...... BABANI #3 (P4) VERTICAL SECTION VIEW ) A i t ', Section at: 334.00 TVD Scale.' i inch = q_500 feet. · ~ ! Oep Scale' ~ inch = :tSO0 feet : i Drawn ' 01/04/94 I ] /nadr i 11 Schlumberger ...... - .......... ~ .......... ~m~.~T-E:~ Marker I~nti~iCa~on MD BKB SECTN ZNCLN } .......... ~ ....... ~ A) KB 0 0 O O, 00 ~ B) KOP BUILD 2.OO/100 ~5OO ~aO O 0.00 ~ C) END OF 2.00 BUIL0 301~ 2gq2 38g 30.2~ ) - .; ' D) f3-3/8' CASING 5433 5035 1608 30.2~ E) 9-5/8" CASING ~12~9 10035 4520 30.2~ F) TARGET t~566 10325 4695 30.2t ~ . ~ _. 6) TD ~3534 12035 5685 30.2~ I ..... . ,., I. · 0 750 1500 2250 3000' :~750 4500 5250 6000 6750 7500 8250 9000 9750 Section Departure m m . n .... I ._ I. ii .. P~U'BHOE -=_-; ;,-;%-- Napker !dentifica(~on HO N/$ A) KB 0 0 B) KOP BUILD 2,00/t00 ~500 0 C) END OF 2.00 BUILD 30'_,t 350 D} 13-3/8' C/~$!NG 5433 2445 ~) ~-~/8" CAStN~ lj2~.~ 4062 F) lAP. GET 1J566 42t9 G) ID 13534 5t09 BAY DRI 1982 2058 24~2 _LING--'~'ROU'P ...... IIlIII III I IIII I ,..] II IlIIIII II .I i BADANI #3 (P4) PLAN VIEW CLOSURE ' 5685 feet at Azimuth 334.00 DECLINATION.' 30.793 E SCALE ' 1 inch = 1000 feet DgANN. ' 0~/04/94 /na~lrY ] ] £chYum/]erger 3500 20o0 2500 2000 ~500 t000 500 0 500 100o ~.500 2000 2500 3000 DS00 · <- WEST ' EAST -> ' .... i .. II I ..... II TOTAL P. 05 01/04/94 10'23 '~§075633754 N.4BOR .4/{ DRILL ~JZ BP DRILLING ANCH ~ 002/002 Rig 22E with 10000# Bop Stack BOTTOM OF DRIP PAN ,.. ... 2 EA 4 1/8 10000# VALVES 4" KILL KILL ~11~,,,-- .=. 2EA 4 1/8 10000# VALVES 4" CHOKE ---, 16'4" 23.8' 18" ITEM APPROVE DATE (1) Fee /~>~-. .~/'.;,.~C~.,-"-~ [ 2 thru (3) Admi n ~___ 1~__~ [9 thru [10 & 13] [14 thru 2 (5) BOPE [23 thru Company ** CHECK LIST FOR NEW WELL PEP. HITS :::: YES 1. Is permit fee attached ............................................... ,~,, 2 Is well to be located in a defined pool · e I e e e e e e e e · · · · · · · · · · · · · · · · · · · · 3. Is well located proper distance from property line ................... q.. Is well located proper distance from other wells ..................... .L 5. Is sufficient undo. dicated acreage available in this pool ............. 6. Is well to be deviated C is wellbore plat included ................... ?~".., 7. I$ operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. I$ a conservation order needed ....................................... 11. Ts administrative approval needed .................................... 12. Is lease n~rnber appropriate .......................................... 13. Does well have a unique name $ nLrnber ................................ lq. Is conductor string provided ......................................... ~- 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement, used to circulate on conductor C surface ............ 17. Will cement tie in surface $ intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. ~- .... 20. Is well to be kicked off from an existing wellbore ................... 21. Im old wellbore abandonment procedure Included on 10-q03 ............. .~ . 22. Is adequate wellbore separation proposed ............................. 23. I$ a diverter system required ........................................ 2q. Is drilling fluid program schematic C list of equipment adequate ..... 25. Are necessary diagrams C descriptions of diverter C BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to /O,d:~psig ..... 27. Does choke manifold comply w/APl RP-53 (Nay 8q) ...................... -- 28. Is presence of H2S gas .probable ...................................... FOR EXPLOP-,ATORY C STP, ATIGRAPHIC WELLS' 2cj.Are data presented on potential overpressure zones ................... /.~ 30.Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc~ are survey results of seabed conditions presented... 32. Name and phone nLrnber of contact to supply weekly progress data ...... 33. Add i t i onal requ~ remen~s .. ,~ ..... /. .................................. /' ? '" , -)':'"' -~ , ):" ~) : '""'?: Lease & Well ~.. ,,:,:,:-~ ~'.'"- NO RENARKS geo.logy · engineering: JDH~e~/~ ' TAB rev 6/93 jo/6.011 INITIAL GEOL j UNIT ON/OFF POOL CLASS STATUS AREAJ ~ SHORE '~' ~ ~ ' t , Additional remarks' UM MERIDIAN' SM o z E WELL TYPE' Exp/Dev Inj Redrill Rev .
