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Home My WebLink About199-002Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J~¢-~(..~ Well History File ldentifier RESCAN Grolor items: ayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA Diskettes, No. [] Other, No/Type TOTAL PAGES: ¢ ? NOTES: ORGANIZED BY: BEVERLY BREN ~HERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) DATE: Logs of various kinds Other ~si ~ Project Proofing PROOFED BY: BEVERLY III I[111111111 II III III IIIIIIIIII III III BRE~SHERYL MARIA LOWELL DATE:¢~ [] Staff Proof By: Date: SCANNED BY; BEVERLY BRE~ SHERYL MARIA LOWELL RESCANNEDBY; BEVERLY BREN VINCENT SHERY~LOWELL General Notes or Comments about this fide: PAGES: Quality Checked (done) RevlNOTScanned,wpd AI,ASI~k OIL A~D GAS CO~SERYATION COMMISSI TONY KNOWLES, GOVERNOR 333 W. 7'm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: September 6, 2001 The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1, 2001. Permit to Drill No.'s- 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 98-223 98-236 98-257 98-261 Sincerely, Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: Prudhoe Bay Unit U-12A Permit # 199-002 February 19, 2001 Re.' Cancelled or Expired Permit Action Prudhoe Bay Unit U-12A XX API# 029-21409-95 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 drill. 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 redrills and or multilaterals 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 drill. The APl 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 APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 14, 1999 James E. Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Rc~ Prudhoc Bay Unit U- 12A BP Exploration (Alaska) Inc. Permit No: 99-02 Sur Loc: 462'NSL, 2275'WEL, Sec. 18, TI 1N, R13E, UM Btmhole Loc. 396'NSL, 1909'WEL, Sec. 7, T11N, R13E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. Thc permit to rcdrill docs 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 arc 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 drilling new hole. Notice mav be given by contacting the Commission pctrolcum field inspector on thc North Slope pager at 659-3607. Robert N. Christcnson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosurcs CC~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation xv/o cncl. STATE OF ALASKA ALAsKA"IDIL AND GAS CONSERVATION CO~t/rl'VllssION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [-I Drill I~Redrill Ilb. Typeofwell r-]Exploratory [--I Stratigraphic Test I~ Development Oil []. Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 75.47' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay PoOl P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028282 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 462' NSL, 2275' WEL, SEC. 18, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 113' NSL, 222' WEL, SEC. 12, T11N, R12E, UM U-12A At total depth 9. Approximate spud date Amount $200,000.00 396' NSL, 1909' WEL, SEC. 7, T11N, R13E, UM 01/19/99 12. Distance to nearest property line113. Distance to nearest'well ....... 1,{'.'"'Number of acres in property 15. Proposed depth (MD and TVD) ADL 028283, 396'I NO Close, Approach 2560 15385' MD / 8585' TVDss 16. To be completed for deviated wells 17. Anticipated pressu~:~ {see 20 AAC 25.035 (e) (2)} KickOff Depth 10725' MD Maximum HoleAn,qle 100° Maximum surface 2510 psig, At total depth (TVD) 8800'/3390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 4835' 10550' 8531' 15385' 8585' 541 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. F,~ ~ L ~ ! ~- Present well condition summary Totaldepth: measured 11.280 feet Plugs(measured) ~/~['~ ~8 true vertical 9141 feet Effective depth: measured 11071 feet Junk (measured) Cement plugged back to 11071~,~aSka 0ii & Gas Cons, true vertical 8995 feet Anch0mge Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2645' 13-3/8" 3719 cu ft Cold Set III & Cold Set II 2674' 2674' Intermediate 10651' 9-5/8" 2286 cuff Class 'G' 10680' 8716' Production Liner 865' 7" 290 cu ft Class 'G' 10415' - 11280' 8524' - 9141' Perforation depth: measured Open: 10720' - 10750', 10884' - 10924' Sqzd: 10716' - 10720', 10750' - 10758', 10883' - 10884', 11002' - 11102' true vertical Open: 8745' - 8766', 8862' - 8891' Sqzd: 8742' - 8745', 8766' - 8772', 8862' - 8862', 8947' - 9017' ..... 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby cert'~ that the~ fore~e~.l...~ and correct to the best of my knowledge]/~//-'0~"~ Signed Jam,~E. Srdith - -- Title Senior Drilling] En~]ineer Date U Commission Use Only Permit Number APl Number ! Appro,v~al Da, t,e~. I See cover letter ? ,~_ ~) ~ 50-029-21409-01 ...... ~, ../,4/~... ~ ~/ for other requirements Conditions of Approval: Samples Required r-lYes []No Mud Log Required []Yes I~No Hydrogen Sulfide Measures l~Yes [] No Directional Survey R, equired ,l~ Yes r-I No Required Working Pressure for BOPE 1-12K; []3K; []4K; 1~SK; [] 10K; [] 15K Other: by order of ORIGINAL SIGNED'By Commissioner the commission Date//'"/'~'''' ~'~ Approved By Rob~_rt _kl Form 10-401 Rev. 12-01-85 Submit In Triplicate har?d s BP Exploration / Arco Alaska Date: January 8, 1998 To: Attn: Alaska Oil & Gas Conservation Commission Mr. Blair Wondzell/Mr. David W. Johnston Reference: Rush Permit From: Robert Kaluza Senior Drilling Operations Engineer Mr. Wondzell and Mr. Johnston: I am requesting a rush permit for the purposes of a pre-spud meeting which will take place on Friday, January 15. The meeting is designed to review the drilling plan and discuss the approved permit with management and drilling personnel. Thank you for accommodating my request. Please contact me if you have questions at 564-5344. Cc: Well Files Alaska hared ervices rilling WELL NAME U-12A DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) r~ DRILLING PERMIT Permit D.,o~ en~ion Prepared: ODE: /(-'~" ' / \ ' Date: Permit Ayplication P.~ viewed: SDE/ES: t/]~ ,~~ Date: ~ Permit ,T A:~,p~ __~ub '' mitted: Date:[/(~/(~ [-'] PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date:~ Pre-Rig Memo Sent to Slope: ODE: Date:~ Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date:~ SUNDRY NOTICE ~i Sundry Documentation Prepared: ODE: Date: D Sundry Application Reviewed: SDE~S: Date: D Sundry Application Submitted: TA: Date:~ NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that ap[fly) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate · APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: ]Well Name: Iu-12A Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: 462' FSL, 2275' FEL, Sec. 18, TI IN, R13E X= 631,718 Y= 5,961,039 Target Start: 113' FSL, 222' FEL, Sec. 12, T11N, R12E X = 628,740 Y = 5,965,918 Z = 8810' TVDss Intermediate 491' FSL, 4716' FEL, Sec. 7, T11N, R13E X = 629,165 Y = 5,966,303 Z = 8,870' TVDss Intermediate 129' FSL, 3646' FEL, Sec. 7, T11N, R13E X = 630,242 Y = 5,965,960 Z = 8,720' TVDss Intermediate 5207' FSL, 2851' FEL, Sec. 18, T11N, R13E X = 631,041 Y = 5,965,773 Z = 8,780' TVDss Target End: 396' FSL, 1909' FEL, Sec. 7, T11N, R13E X = 631,973 Y = 5,966,258 Z = 8,585' TVDss I AFE Number: 14P1076 I Estimated Start Date: ] 1/19/99 I I Rig: I Nabors 9ES IOperating days to complete: 31 I Twss: 18,sss' I I g E: 75.47' Well Design (conventional, slim hole, etc.): Extended Horizontal Sidetrack Objective: Sidetrack out of existing 7" liner into the Sag River formation, directionally drill 6" hole thru (1) long horseshoe ZA target, TD at 15,385' MD. Run, cmt and test 4 1/2" solid liner, complete with 4 ½", L-80 tbg, (7) GLM's and WOA tail assy. Formation Markers Formation Tops MD TVD(ss) TSAG 10,710' 8661' Begin sidetrack 10,725' 8673' Sidetrack from Whipstock out of 7 "liner into Sag River formation. TShublik 10,749' 8,690' TSAD 10,936' 8,795' TZA 10,936' 8,795' Target: Start 11,710' 8,810' TD - Target 2 15,385' 8,585' Undulating thru updip horseshoe target HO/T 8,940' OOWC 9,014' TZ3 9,048' Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 6" 4 1/2" 12.6# L-80 IBT 4,835' 10,575'/8,552' 15,385'/8,585' liner Mod 4 V2" 12.6# L-80 IBT 10,545' 30'/30' 10,575'/8,552' compl. Mod Logging Program: Open Hole Logs: Drilling section: MWD/GR from KOP (10,725') to start target #1. MWD/GR/Res to TD at 15,385' MD. MADD pass as per Geologist request. DPC Platform Express + Sonic will be run after reaching TD. Sample catchers and rig site geologist on site before drill out of window. I Cased Hole Logs None Mud Program: ISpecial design considerations Drill from KOP to TD with MI Flo-Pro Polymer system. [ The formulation of the brine phase will be 6% KCL. I Density LSRV PV Gels Chlorides pH (ppg) (cps) 8.7 55 - 60,000 < 15 10 sec. >18 30,000 9.0-9.5 to to expect to to 8.9 55 - 60,000 8-12 10 min. >20 30,000 9.0-9.5 Record LSRV at 1,2,3 minutes: Make certain they are elevated and flat. Plan to run 3-5 % Lubetex by volume. Start 6", Z4 section at 3 % Sweeps, Liner slugs and CBU sweeps at 150,000 cp w/60-80 rpm & reciprocation the full 90'. Ensure eood stocks of LCM on location. -- Directional: KOP: Maximum Hole Angle: Surface Shut-in 1) 10,725' MD, drill out of 7" liner via whipstock window at 332° azimuth, 44° inclination, build and turn angle to 83° inclination, 28° azimuth to Start target #1 at 11,710' MD, 8,810' TVDss', finish horseshoe turn at 12,714' MD, 8,810'TVDss, 116° azimuth, hold azimuth and undulate thru target, invert tail, final TVDss 8,585' at 15,385 MD, TD. Close Approach Well: Point to point separation 100° undulating thru target #1. No wells will need to be shut-in and de- pressurized before rig move on and off of the well. There are no close approach wells to this wellbore identified by Sperry Sun. Cement Data: Casing/Liner Lead: Tail: Sxs/Wt/Yield Comments Sxs/Wt/Yield P&A of original well 132/15.8/1.15 Class "G", TOC 454' + 10 bbl 10,570', 150' above squeezed top perfs. 4 V2", 12.6#, L-80 liner 541/15.8/1.15 Class "G", 50% excess OH SUMMARY PROCEDURE Pre-Rig Operations: RU CT, spot cement across open perfs + 150' above top perf and 100' below bottom perf (cement top at 10,570', cement bottom at 11,024'); hesitation squeeze 10 bbls into perfs. Open perforations from 10,720' to 10,750' and 10,884' to 10,,924' MD. Cement top MUST NOT be above 10,500' MD (minimum per AOGCC = 10,620' MD or 100' above uppermost squeezed perforation and 11,024' MD, 100' below bottom perforations). After spotting and squeezing cement, pull up to 10,570' (top of cement) circulate out anly excess cement and circulate well to seawater. Note: Minimum ID 2.313" at 10,279' ELM and same ID at 10,429' ELM. 2. RU electric line and make a chemical cut in the middle of the first full joint of 4 ½" tubing above the 2 7/8" tubing patch. Cut 4 ½" tbg at +10,080' MD. Circulate well to seawater through the cut. Freeze protect to + 2,200' MD. Note: use double anchor chemical cutter. 3. Test the 9 5/8" slips type packoff to 3,800 psi and tubing hanger (through test port) to 5000 psi. 4. Set a BPV and test from above to 500 psi in preparation of the rig move. .,.~g Sidetrack Procedure , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. MIRU. ND tree, NU and test BOPE. Cffculate well clean. Pull the 4 ½" tubing completion. Tubing cut at + 10,080' MD. Replace the leaking 9 5/8" packoff if necessary. RIH w! 4 ½" Overshot, retrieve SBR assy.. RIH retrieve K-anchor. RIH w/Packer mill/catch tool, mill packer slips, retrieve 9 5!8" production pkr w/tailpipe. RIH w/cmt drill out assembly, tag cmt top, test 9 5/8" csg to 3,000 psi. Dress cement to + 10,720'. Circ well. POOH RIH w! bottom trip whipstock, orient, set whipstock, mill window out of 7" csg liner. Kick-off and directionally drill 6" hole 'to 15,385' TD. Run DPC log suite at TD. Run and cement 4 ½", L-80 solid production liner. Perforate DPC Run 4 ½", L-80 tubing completion. ND BOPE, NU and test tree. RDMO. 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 and BOPE system schematics on file with AOGCC. Bottom hole pressure is 3,390 psi at 8,800' TVDss (estimated) through target. Maximum shut-in casing pressure is 2,510 psi (assumes 0.1 psi/ft gas gradient to surface). NO ANNULAR INJECTION IN THIS WELL. U-12A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Contacts Name Office Home Pager Bob Kaluza Drilling Eng. 564-5344 563 9059 275-1014 Tony Bunch Drilling Supt. 564-5219 229-0729 275-3703 Bob Metzger Geologist 564 4613 345 2592 223 7187 Daniel Hsi Pad Engr. 564 4513 345 5982 227 0439 Bruce Smith Asset Drilling Eng. 564 5173 345 2948 275 4600 Stuart Montaque Geophysicist 564 4029 561 9500 230 6335 Drilling Discussion Well Objective Well U-12A is the first of two wells that will target the area immediately North of the fault separating U and N pads. The overall extra development of U pad gives 35.31 million STB of incremental reserves, of which 74% is associated with primary plus WF, and 26% is associated with MI. U-12A could receive support from N-08 and two future producers to injector conversions, N-10 and N-03. Using project averages, the potential incremental would then be increased by an additional 0.29 million STB of WF reserves and 1.48 million STB of EOR reserves. The expected initial rate for U-12A is 3,550 BOPD at a 38% WCUT and 1170 GOR. The expected first year average incremental rate is 2770 BOPD at 52% WCUT and 1400 GOR. Drilling Objective The objective is to cut and pull the existing 4 ½" completion tubing/production packefftailpipe, mill a window by Whipstock through the 7" liner at + 10,730' MD, directionally drill an undulating 6" hole through (1) Zone 4 horizontal target;TD _+ 15,385'. Run, cement and test a 4 ½" solid liner (liner top at + 10,575' MD). Perforate as per geologist request. Complete with 4 ½" tubing, (7) GLM's + WOA completion tailpipe assembly. Eight (8) faults are prognosed to be crossed while drilling U-12A. Three (3) of the faults are expected to be minor and possibly not seen. Faults 1 and 5 are parallel to the regional horizontal stress directions, so there is a high possibility that one or both of these faults could be conductive. No large faults are predicted but small faults will occur with the potential for fluid loss. Several small faults (10'-20') have been interpreted, but poor data quality precludes correlation of these faults laterally for any significant mapable extent. The designed well path optimizes structural position and reservoir exposure with undulations that will be geosteered using MWD/GR/Res (real time). The well will be completed as a Zone 4B producer with a 4 ~/-" v2 , L-80, 12.6# tubing, (7) GLM's and WOA tailpipe assy. The GLM's will be run with depths determined after log evaluation. H~S: U-Pad is not an H2S Pad There are no reported incidents of H2S at well U-02. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) · Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; H2S monitors with both audible and visual alarms; Access to 5-minute emergency escape air packs; Personal H2S monitors; Functional wind indicator; Posted evacuation routes (minimum of two); Muster points in designated safe areas;H_a_S; Functional communications between rig camp and rig floor. Fault Evaluation See Hole Problems. The original wellbore, U-12, did not experience lost circulation. Other wells in the immediate vicinity have experienced lost circulation: U-03, U-11, U-13, U-14, H- 10, H-12, and H-32. Casing Shoe Kick Tolerance The smallest kick tolerance for the 9 5/8" casing shoe is calculated as infinite of influx assuming a swabbed gas influx at the Sag River formation along the planned directional path. Based on 8.7 ppg MW (TSAG 9,883' MD & 8,725' TVDss, 7.8 ppg reservoir pore pressure), and min. frac at shoe of 12.0 ppg. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is no well that will need to be shut-in during the rig move on and off of the well. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Sperry Sun directional well plan #2 due to close approach requirements. PORE PRESSURE: The pore pressure in the Sag River (KOP) is expected to be near 7.4 ppg EMW and the Sadlerochit is expected to be near 7.4 ppg. 8.7 - 8.8 ppg mud will be used drilling the Sag River, Shublik and Sadlerochit formations and will provide sufficient overbalance to the reservoir pressure.. HOLE PROBLEMS The well's design cuts (8) faults in the reservoir section, however only (2) of the faults run parallel to the regional horizontal stress that will significantly increase the chance for lost circulation. Be prepared for lost circulation crossing these two faults. The original wellbore, U-12, did not experience lost circulation. Other wells in the intermediate vicinity have experienced minor lost circulation. No large faults are predicted but small faults will occur with the potential for fluid loss. Several small faults (10'-20') have been interpreted, but poor data quality precludes correlation of these faults laterally for any significant mapable extent. No major hole problems are expected. ACTUATOR: AXELSON SSSV LANDING NIPPLE Cemented ~ L-80 BTRS 2,674 (OILS W/RA ~TCH~ 5 3,605 3,583 KOP: 28~ 4 6,293 5,632 MAX ANGLE: 49~ / 3 8,493 7,172 i TUBING ID: 3.958" ~ -- _ - HES PACKER ~BING ID: 2.441" ~ GIW )(4.75'1D) Top Of 7" Dner ~ ~ * (OTIS) (3,725" ID) J 4-1/2' ~G TAIL 10,466 (DOT SOS) ; (ELMD) 10,443 ~E IN LOG: CBL ~28/85 ~ MARKER JOINT 1 o,851 10,716 - 10,720' Sqzd 5/28/92 10,750 - 10,758' Sqzd 5/2~9~ ' ~:: P~ckker Rubber LeE 7/26/89 1 002-11 102 Sqzd 5/2~92 ~':; R 26 and 29 118" Guns ~29/86 DATE REV. BY COMMENTS 813018S D JR Initial Riq Completion PRUDHOE BAY UNIT 5/30/92 PAD Revis~ WELL: U-12 (41-13-11-12) APl NO: 50-029-21409 BP ~ploration (Alaska) GAS LIFT MANDRELS (OTIS W/RA LATCH) N~ MD(BKB) TVDss Dev 5 3,605 3,583 4 6,293 5,632 3 8,493 7,172 2 9,876 8,130 1 10,173 8,349 TREE: CAMERON WELLHEAD: 4' ACTUATOR: AXELSON TUBING iD: 2.441' U-12 Pre- Rig BF~ELEV =48.57 SSSVLANDING NIPPLE (4-I/2 OTIS X)( 3.813' ID) I ','~=J GASUFTMANDRELS (OTISW/RALATCH) MD(BKB) TVDss Day 3,605 3,583 6,293 5,632 8,493 7,172 9,876 8,130 10,173 8,349 SLIDING SLEEVE (OTISXA)(3.813'MIN~ID) I 10,277 HES PACKER PBR, Pi(R, X-NIPPLE,WLEG (HES 'RCP')(2.313 ' MIN. ID) TIW RECEPTACLE (TIW (OTIS) (3.813" ID) (OTIS) (3.725' 2 7/8" REDUCING NIPPLE (El_MD) I~RFORATION SUMMARY REF. LOG: BHCS 8f24/85 TIE IN LOG: CSL 8/28/85 10,716-10,720' 3~3/8' 6 10.720 - 10.750' 10,750 - 10,758 DATE o~s~sqze~ ~qzd 5728/82 Sqzd ~ REV. BY COMMENTS D JR In~ieI Riq C~n'~ptet~on Packker Rubber Left 7f26~9 UR to Rubber ~ 11.090' 5/92 Cement Plugged Back to 11.071'. PRUDHOE BAY UNIT WELL: U-12 (41~13-11-12) APl NO: 50-029-21409 BP Exploration (Alaska) TREE: 4" CIW * 5M - McEvoy ;B. ELEV = 74.72' WELLHEAD: 13 5/8" - 5M - McEvoy __ __ BF, ELEV = 46@7' ACTUATOR: OTIS ~ 'X' NIPPLE O lei I I GAS LIFT MANDRELS 13 3/8" 72# L'80 BTRSt 2,674' ]~,d · ( CAMCO w/ RK LATCH) KOP: 2.800 3 MAX ANGLE: 49q 4 5 6 7 4 1/2", 12~6#/ff, L-80 TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT ~ ~ 4.1/2" X Nipple @ 10,340' MD ~ i ~ 7" Production Packer @ 10,350' MD , I 4.1/2" X Nipple @ 10,375' MD 7" LINER TOP 10,415' ~ .... ~ i I ~ 4-1/2 XN Nipple @ 10,565 MD _ __ C~ _~ 4-1/2 UnerTop @10,575' MD 95/8"47#L-80BTR~C [ 10680' ] MAXANGLE: 100 @ 14.460 MD ' L PERFORATIONREF LOG: SWsSUMMARYBHCS - 11-14-86 ,:!m TD @ 15 385 MD szE SPF NTERVAL OPEN/SQZ'D~ PBGC3 @ 15 305 MD I~ err a 'ons Pugged ~ ~ Cmt Plugoed back fish to 11,071 FlSH(2):26'&29'31,8'gunsiost, I 11,1S0' I PBTD I 11~204 I 7", 47#L~OIJ4S I 11,280' DATE REV. BY COMMENTS PRUDHOE BAY UNIT 9 - 8 - 84 INITIAL COMPLETION 1~99 RMK EHST WELL: U-12A (4t-13-11~12) BP Exploration (Alaska) X D O Proposal Target Summa~ COPY Prolx~l Data for U.12A Wp2 _ ! 8500~ 9000 I, I I I I · 500 0 500 1000 1500 2000 2500 Scale: linch ~- 500fl Vertical Section Section Azimuth: 60,000° (True North) C) , suR~c~bc~,T~o, "I I -~pLOT DATE~'~9'Oct;9~ Proposal Target Su~ . ' 4500 4000 -2500 4930.46 N, 2892.0~ W 5000 - ~4500 - 4000 - 3500-- 4500 -3000 -2500 Scale: linch = 50Oft -2000 Eastings ' ,~ · :,?.o .... .',,:Ioo 4 ~t gO, 8~5"/~'tt TVO : 13'1~ ' U. I2A ~,~P2 TS 8795.47 TVD 4946.12 N, 1389.52 W Start Dir @ 10.00071001t: 13,305,1,5lt MD, : $[at ~ {~ 12.000'/100tt: 10725,001~ MD, 874,8.5,31t T'VD -500 0 510 4745.I4 ff, $95.91 Ti' lO,O00'llOOft: 1, ONtY -- I I I -2000 -1500 Eastings · 1000 .500 0 )..$9lt MO, U95,47tt TVD TVD 886,3,52tt rVC MO, 885,5.47tl TVD 41/2' Liner 15384.5O MD 8660,47 l~O 13.88 N, 328.92 E - 5500 - 5OO0 ' 4500 - 4000 i II 3500 500 Reference is True Noah Prudhoe Bay Unit Measured Depth Incl. 10725.00 44.418 332.420 1074~.18 46.614 ~3~080 10800.00 51,405 840.063 109OO.00 61.330 348.211 10036.08 6~.021 ~50.747 11000.00 71.654 864.596 111OO.00 82.184 0.813 1120O.0O 92.783 6.436 11246.10 97.680 9.639 113O0.00 97.680 9.039 11400.OO 97.530 9.039 1147021 97.680 8.039 115OO.00 95.867 11.419 116OO.00 89.723 19322 . 11700 00 83.585 27.233 11709.60 83.000 28,000 11800.OO! 78.058 ~.877 11818.75 77.057 37.301 11890.49 77.057 37,301 119OO.00 77.057 37-301 11915.10 77.057 37.301 12OO0.00 81.210 46.445 12100.OO 86.502 55.147 12200.00 91.894 64.740 12300.00 97.232 74,392 1230624 97.559 75.000 12400.00 98.168 84.445 12500.00 98.576 94.545 12600.00 88.722 104.659 127OO.OO 98.600 114.774 25 Ootober, 19~8.16:19 Sperry-Sun Dri fl Services 'Proposal Report for U-1~2, Alaska State Plar~ ~nE PBU_WO~ U Pi Sub-Sea Vertical Depth Depth (fl) (fl) Lo,al Coordinates Global Coordinatea Dogleg Vertical Northing$ Eastlng$ Northing$ Ea,tlngs Rate Section (ft) (ft) (fi) (fi) ('/10~) (ft) Comment 8673.06 8746,53 4022.19 N 2863.61 W 8890.00 3765.47 4037.68 N 296123 W 8723.34 8798.81 4078.11 N 2975.79 W 8778.72 8854.19 4153.09 N 2998.15 W 8795.00 6870,47 4164o74 N 8004.01 W 6818.59 8884.06 4243'63 N 3011.38 W 884121 5916.68 4340.79 N 3014.91 W ' 8845,69 8921.06 444031 N $008.59 W' 8841,38 8910,85 ~5.79 N ~02.41 W 8,864.18 8~.~ _~'~"~iLeZ,4 N _~.~ W 6~7~2 ~ ~ ~4~N , 2~W .o3. w ,o2o.87, w ~7.13 89~ ~8~ N 273~19 W M65.~ ~12 51~15 N 2~86 W ~7 595~ ~1~ N 2~.96 W M78,~ 89~A4 6~1 ~ N ~ W 8~0.80 ~ ~.31 N 2~6~0 W 6870.00 894~.47 5307.95 N 2460.33 W 8857.14 5932.61 5,324.50 N 2369.05 W 8842.65 5918.02 5325.38 N 2270.25 W 8827.47 8002.94 5306.91 N 2172.91 W 6812.37 8887.84 5275.60 N 2079.37 W 5965008.79 N 628694.34 E .~46.81 5968024,13 N 628686.44 E 12.0OO 59~,068-32 N 62867126 E 12.000 -543~ 5905138.68 N 628647.51 E 12.000 -~19.93 5985170.43 N 028641,08 E 12.000 -509.18 5965229.10 N 628532*59 E 12.000 -485.12 596532627 N 826827.&6 E 12.OO0 -440,60 6965425,89 N 628632*03 E 12.000 -38536 5965471.46 N 628637,41 E 12.0OO -367.27 5965524.35 N 628644.87 E 5.000 -323.63 5965822.48 N 62865873 E 0.000 -2812'J 5965691,38 N 626868.45 E 0.000 -217,89 5965720,6,8 N 628673,19 E 10.000 -19828 ,596861721 N 628897.96 E 10.000 ,,127,2,8 5965009,46 N 628735.73 E 10.000 -47.88 5953915.OO N 828740.00 E 10.000 -30.33 5965994.50 N 628786.62 E 10.000 39.18 5966OO9A1 N 628796.25 E 10.000 55.97 · 5966066.76 N 628837.63 E 0.000 120.47 5966073.23 N 628843,12 E 0.OO0 129,02 5866087.45 N 5268,53.56 E 0.000 145.29 ,5908146.64 N 626905,63 E 11,000 221.44 5966213,35 N 528980.91 E 11.000 319.30 5968284~ N 629060.43 E 11.000 419.13 5966301.26 N 629159.06 E 11.000 51728 5966303.00 N 629165,00 E 11.000 5232'/ 5966321.15 N 629255.88 E 10.000 610.60 5966323,76 N 529354.74 E 10.000 598.59 5666309.00 N 6294,52,36 E 10.000 772*66 5906277,33 N 629646.87 E 10.OD0 636.50 ,1o KOP: ~ Dir · 12.000'/100ft: 10725,00ft MD, 8748.53ft TVD TSHU TSAD Dh': 11246.10ft MD, 8016.6811 'rvo ,~att DIr · 10.oo0¥100ft: 1147021ft MD, 888~.90ft 'rVD j~o~up.l~! .Q.10,0.~7/J 00~t: .11709.60ft MD, 8885.47ft TVD TaJ'g~C U-1ZA WJ:)Z 11, 6eOlOgIcaJ End Db': 11818.76ft MD, 8904,40ft TVD 46P 8ta~t DIr · 11,000'/loofl: 11918.10tl MD, 8926.65tt'iND rRt e e 1000 '/10 Cofl~nue~ , OrlllQuea Prudhoe Bay Unit Sperry-Sun Or, i/ling Services Proposal Rep /o~f~¢,l~A Wp2 Alaska $t,~te Plane Zon~ 4 PBU_WOA U Pad CD .D ;D Measured Depth ¢1) Azlln. Sub-Sea Vertical Depth Depth (ti) (:t) 12714.11 98.562 116.200 8810.27 8885.74 12800.00 98.562 116.200 0797.48 8872.95 12900.00 98.562 tlG.200 8782.59 8858.06 13000.00 98.562 116.200 8707.71 8843.18 13100.00 98.562 116.200 8752.62 6828.29 13200.00 13300.00 13305.15 13400.00 13472.59 · 98,562 98,562 89.747 63.000 13500.00 83,036 13564,99 83.185 13600.00 83.185 13700,00 8~,185 13600.00 83.185 ~3900,00 14000.00 83,185 14044,61 83,185 14100.00 86.887 14200.00 93.598 143~0.00 100.246 14301.97 100.378 14400.00 100.378 1,1500,00 100.310 1.161~.o0 100.378 Local Coordinrzlcs Global Coordinate~ Dogleg Vertical Northings Eastlngs Northings Eastings Rate Section 52§9,60N 2067,38W 5966271,55N 623558.56 E 10.000 844.40 5732.10N 1991.17W 59(;6235,33 N 629635.42 E O,000 891.65 5188.44 N 1902.44W 5966193,29N 629724.89E 0.000 946,66 5144.78N 1813.72W '5966151.2bN 62981L37E 0.000 1001.67 5101.12N 1724.99W 5966109.10N 620903.85 E 0.000 1056.68 116.200 5'737.93 8813.40 5057.47N 116,200 8723.04 8798,51 5013,61N 116.200 0722.28 ~797,75 5011,56N 1,2,6~5 8715,41 879~8 4~,,.~7N i1o.ooo ,,~a~ 100.~5 ~ 8~0~ 4921.~7N 100~ ~.75 ~ :22 4841.71N 100~&~788.05 ~863.52 4833.~N 104.~1- 8792.84 8868.31 4821.30 N 112,249 87~2,42 8867,89 4789,55N 119,777 8780.35 8855.82 119,928 8780.00 8855.47 4746,11N 4745,14 N 4697.03N 4647.96N 4538.88N 119.928 ~762.34 8837.81 119,928 6744.33 8819.80 119.928 8726,31 8801.18 1636.26W 5966067.00N 829993,33 E 0.000 It11.69 1547.54W 5966024.31N 630082,8nE 0,000 1166.70 1542.96W 5966022.74 N 630087,42 E 0,000 1169.53 1456.34W 5905985.17 N 630174.12 E 10.00'0 1224.49 1389.51W 5965360.00N 630242.00 E 10.000 1269.71 1363~3W 5865951,77N 63026~92E 10,000 1287.69 1301.15W 5965937,31N 630330.78 E 10.000 1334.10 1266.99W 5965931,45N 630365,03 E 0.000 1360.46 1169:42W 596591434 N 630462.91E 0.000 1435.75 1071,85W 5905836.03N 630560.73 E 0.000 1511.03 974.29W 5905881.31N 630056.66 E 0.000 1586.3! 876.72W 5365864.60N 630756.54 E 0.000 1661.60 833.19W 5965857.14 N 630800.21E 0.CtX) 1685.18 779.40W 5~65845.30N 63085L20 E 10.000 1735.67 664.71W 5966815,81N 63094.,%4,!,E 10,000 1801,80 595,59W 5905773.94 N 631039,30 E 10.000 593,91W 5965773,00N 631041,00E 10,000 510,34W 5905726,36N 631125.40 E 0.000 425.09W 5905678.79N 631211.49 E 0.000 3~9.84W 5065631.22 N 631297.53 E 0,0110 Comment End Oir: 12714,11tl MD, 8ti85.74113'VD .l~m,nllnue Dk (} 10 000'll00tl: ~3472.59~ MD, 8735,4711 TV0 gel; U-12A V,'P~ TO, Geolog,cal End Oir: 13564.9911 MO, 8806,6111TVD Sial1 DIr ~ 10.000"/100~: t4044.61fl MO, 8I~63.5211 TVO 1857,26 1858.23 End Dh': 14301,97tt MO~8855.47f1 TV0 Tar[lei: U-12.A Wp2 T4, Gootorj1cal 1906.55 1355.84 2005,13 Con.qnued.,, 290¢~obe~ ~998.16:19 .2. OflllOuc~l Prudhoe B~y Unil Measured Sub. Sea Vertical Depth Incl. Azim. Depth Depth (~) (It) 14700.00 100.378 !19.928 8708.30 8783.77 14~00.00 100.378 119.928 8690.29 8765.78 ;4500.00 100.378 119.928 8612.21 8747.74 15000.00 100.376 118.929 8654.26 8729~3 15100.00 100.373 119.029 8636.25 8711.72 15260.00 100.378 119.929 8618.23 8693.70 .15300.00100.378 119.929 8600.22 ~75.69 15384.50 100.378 119.929 8585.00 86c0.47 LocalCoordinales GIobalCoordlnales Dogleg Vmlicai Northings Ea$lin[.IS Northlngs Eastings Rale . Section (~,~) fit) (t~)' (t~} ('noo~) Comment /3,,:.,,,. .~,Jaska St~.~te P!ane Zor:e -'1, '/%.:,// PBU_WOA U 4549.~1N 254.60W 5965583.64N 631383.68E 0.060 2054.42 4500.73N 169.35W 5965536.07N 631469~8 E 0.000 ZI03.71 4451.66 N 84.10W 5965488.50N 631555.87 E 0.000 2152.99 4402.5~N 1.15E . 59654,10.92N 631641.97E 0.O00 2202.?8 4353.50 N 86.39 E 596,5393.35 N 635728.06 E 0.000 2251.57 4304.43 N 171.6~E 5965345.78N 631814.15E 0.000 2300.~6 4255.35 N 256.89 E 5~6529820N 631~00.25 E 0.000 2350.15 4213.88 N 3~8.92 E 5965258.00N 631~73.00E 0.000 2391.80 4 t/2' Liner Te. rg e l: U- 12^ Wp2 T5 (TO), G eD logic al All data is in feet unless otherwise staled. Direclions and coordinates are relalive to True North. Ve~,ical depths are relative to Well. Northings and Eastings are relative to W/ell. Magnelic Declination at Surface is 0.000° (28-Oct-98) The Dogleg Severity is in Degrees per 100tr. Vertical Section is Irorn We[I and calculated along an Azimu(h ol~ 60.000" (True). Bssed upon Minimum Curvature lype calculalions, at ~ Measured Depth ol 15384.50R., The Boltom Hole Displacement is 4226.7011,, in lhe Direction of 4,463" (True), CohO'hUed.,. ,3., Alaska hared · ervlces rilling WELL NAME U-I2A DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT Permit D ~o~men~n Prepared: ODE: /g._,~-~,. t X. Date: Permit ~plication ~viewed: Permit ~voli~afio~ Sub~tted: TA: ~~~ Date:~/~/~ PRE-RIG WORK Pre-Rig Memo Reviewed: S DE/ES: Date: ~ Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date:~ Pre-Rig Sundry Application Submitted: TA: Date: ~'] SUNDRY NOTICE D Sundry Documentation Prepared: ODE: Date: D Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Naska 011 & (~as Cons. Commission Anchorage I APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDEfES: Date: ~ hared s Shervice ~l~t~A~'~ rilling BP Exploration / Arco Alaska Date: January 8, 1998 To: Attn: Alaska Oil & Gas Conservation Commission Mr. Blair Wondzell/Mr. David W. Johnston Reference: Rush Permit From: Robed Kaluza Senior Drilling Operations Engineer Mr. Wondzell and Mr. Johnston: I am requesting a rush permit for the purposes of a pre-spud meeting which will take place on Friday, January 15. The meeting is designed to review the drilling plan and discuss the approved permit with management and drilling personnel. Thank you for accommodating my request. Please contact me if you have questions at 564-5344. Cc: Well Files D^T': I C. ECKNO. I H 145054 :t " ,/ o~,,/ 'geI 00:t4~0~4I VENDO. ALASKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 110&~8 CK 1 lO&~Bg 100. O0 100. O0 HANDLINO INST' S/H KATHY CAMPOAMOR X5122 THE A~ACHED CHECK IS IN PAYME~ FOR ~"S DE~RIBEO ABOVE. ~ 1 OO_ OO ] OO_ OO BP ~,,.XPLORATION (ALASKA).~ANG, ..~:~=,...! RO.'BOX.196.612 ..i..' :::~..,:- ~:;" .~ AN~'HORAGE;: A~SK~ 99519-6612 '" "F~iRST '~ATI~'SANK ]bF AShE'AND · ..:: . 'i :;A~:*AI~FIIc4ATE;.{~I~ '.:/." '*" CCEVELAND. OHIO .... . :.:,..., .,' .: :. ~ : :~::"56-389. 412 PAY ::0r d ~;i, '!:~::~ iii':3001;!iPORCUP INE:::.!!:DR,' :i;i~/: ::::::.' ::ii? ::? .;~':~;""' ~::" : ' ;~' "::'; DATE ,:, ::: "' ..... AMOUNT ~: .:; ;: .:' '; : /?~':.: N~.,~:y~UD) A~ER 1~ DAYS::./':. :::;.:..'::":'..,:. ;:.:~:~'.~ : I~i .1: i;' j:j::j: '::.~::~ :' ':~.:' :'"." ~..":' ::: ....... ;::7 ..... ' . .::;:.":':' ANCHORAOE AK 9~501-3120 '~ '~ ,' i, h 50 5 h,' ':0 h ~ ilo ::1,8 WELL PERMi+ cHE~KMST COMPANY ,/~,~ '" FIELD & POOL ~'.'~"_,C")./._(;"'~,"~ INIT C~.ASS ~,'~J,,' /-,~_) ? WELL NAME/~"~,.f/~',, ~ PROGRAM: exp dev.~, redrill ~x~ serv wellbore seg .. ann disposal para req __ ADMINISTRATION ENGINI~ERING APPR DATE 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 drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 0. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ........ 2. Permit can be issued without administrative approval ...... 3. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 5000 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... GEOL AREA ... (~?,,--') UNIT# /.,,~T_~,"~:::~ ON/OFF SHORE ~1 N N N N' Y N Comments/Instructions: 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ ~ 31. Data presented on potential overpressure zones ....... Y ,,N/ './' ) 32. Seismic analysis of shallow gas zones ............. Y/N /[ ./, /'~/i APplieR .,DAT, E 33. Seabed condition survey (if off-shore) ............. _ /~ N' '"' ' ,~.~._/~? ,~ 34. Contact name/phone for weekly progress reports[exploratory ~ Y N ANNULAR DISPOSAL35~ With Proper cementing records,~tJ)j~l~nl"~ ....... ~ ~ (A) will contain waste !~ui{able'~receiving zone; ....... Y N APPR DATE (B) will not conta~le?eshwater; or cause drilling waste... Y N to surface'-, "' (C) will~nd~ impair mechanical ih'tegri~ of the well used for disposal; Y N (D) ~¢v~l'[not damage producing formati~'~'~mpair r_~ecovery from a Y N ~ ......... pool; and -----'-~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N .... GEOL_O~GY: E~NGINEERING: Ul'l~Anr)Ul'~; ' coMMIssION: '"" ' RPg'~,, BEW(~ ~'/'(P---/~'~ WM ~'/~., DW~~''~" co,, 0 ,-] dlf:C:tmsofflce~wordiantdiana~checklist