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Home My WebLink About206-117• Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O~ ©~ - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III (VIII II III II III ^ Rescan Needed III II~III II II III IN RESCAN DIGITAL DATA OVERSIZED (Scannable) ^ Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Project Proofing II I II IIII II III V III BY: Maria Date:' l © /s/ Scanning Preparation x 30 = + =TOTAL PAGES_~ ry (Count does not include cover sheet)'/~ A BY: _ Maria Date: 1' I''~ f71'~ /s/ Y VI Production Scanning Stage 1 Page Count from Scanned File: ~ ~ (Count does include cover sheet) Page Count Matches Number in Scannin Preparation: YES NO BY: Maria Date:,'~3 ©g /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II III II I I III Rescanned II I II II II I I III V III BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc i ~ ~.~ :,r ~: -~- ', R '_~~ ~~ ~'`~..~ ~ ~ ~ - it ~~ ~~~ 4 .• ~~ ~. ~ ~~ , MICROFILMED ..6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewiCh. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey . 130 West Ir~ternational Airport Road g~~;~~~ ([J~, .~ ~~~~~ Suite C Anchorage, AK 99518 Fa~c (907] 245-8952 1 J Injection Profile 17-May-09 1 J-118 L1 Color Log / EDE 2] ,~-~° ~_`t~ o ~ ~~~ - ,~ ~ ~ Signed : p~ Print Name: 50-029-23337-60 PROACTIVE DIAGN09TIC SERV~CES, INC.: 130 W. (NTERNATIONAL AtRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: 1907)Z45-8951 F~c: (907~245-88952 E-MAIL: ~ `-;: ~';.- , 4lVEBSITE: ~ C:~Documen6 and Settv~gs~Owner~Dasktop\Transrtut_Conow,docx ~. '~ ' i ~ - FRANK H. MURKOWSKI, GOVERNOR ~+ ~-~r~t7~~ OIL ~ V[0-7 333 W. T" AVENUE, SUITE 100 COI~TSERQA'TIO11T COMi-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Dave Wesley ~ FAx (so7) 27sasa2 Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-OlA BP Exploration (Alaska) Inc. Permit No: 206-117 Surface Location: 258' FNL, 1209' FEL, SEC. 11, Tl 1N, R14E, UM Bottomhole Location: 1661' FSL 2091' FEL, SEC. 02, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907-3607 (pager). Si DATED this day of August, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. of STATE OF ALASKA '~~.;-~.loG ALAS AND GAS CONSERVATION COMMIS~d PERMIT TO DRILL 20 AAC 25.005 RE~EI~C~~~/~o~ JUL 3 ~ 2006 Alaska Oil & Gas Cons. Commi ' 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ~ ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is ~p~or: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU WGI-01A ,~Z~ oa 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9210 TVD 8624 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1209' FEL T11N R14E 258' FNL SEC 11 UM 7. Property Designation: ADL 028302 Pool , , . , , , Top of Productive Horizon: 1661' FSL, 2091' FEL, SEC. 02, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Sp ate: Augus 20 006 Total Depth: 1661' FSL, 2091' FEL, SEC. 02, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,400' 4b. Location of Well (State Base Plane Coordinates): Surface: x-684986 y-5972003 Zone-ASP4 10. KB Elevation Plan (Height above GL): 51.1 feet 15. Distance to Nearest Well Within Pool: 711' 16. Deviated Wells: Kickoff Depth: 2800 feet Maximum Hole An le: 35 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC .035) Downhole: 3453 Surface: 90 18. Casin P ram: S ificatio ns To - Settin De th -Bottom Quantit of Ce c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-114" 9-5/8" 47# L-80 TCII 8613' 33' 33' 8646' 8060' 620 sx LiteCrete 784 sx Class 'G' ~ 8-1/2" 7" 26# L-80 BTC-M 714' 8496' 7910' 9210' 8624' Uncemented Slotted Liner 19. PRESE NT VVELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9335 Total Depth TVD (ft): 8643 Plugs (measured): None Effective Depth MD (ft): 9292 Effective Depth TVD (ft): 8610 Junk (measured): None .Casing Length , ize Cement Volume MD p Conductor /Structural 103' 20" 330 sx Arcticset 103' 103' Surface 2731' 13-3/8" 4760 sx Arcticset II 2731' 2731' Intermediate 8314' 9-5/8" 500 sx Class'G' 375 sx Arcticset I 8314' 7822' Production Liner 1315' 7" 355 sx Class'G' 8019' - 9334' 7566' - 8643' Perforation Depth MD (ft): 8695' - 9228' Perforation Depth TVD (ft): 8142' - 8560' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify th t the foregoing is true and correct. Contact Phil Smith, 564-4897 Printed Name ~ve Wesle Title Senior Drilling Engineer Prepared By Name/Number: Si nature ./r`~ Phone 564-5153 Date ~/~/ ~~ Terrie Hubble, 56a-4628 Commission Use Onl Permit To Drill Number: ~ / API Number; 50-029-20369-01-00 Permit pro al See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: Yes ~No Mud Log Req'd:~Yes ~No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~ -2 S ~ ~ ~ ~ ~ to ¢C~ D D t0 I.~C 1 ~~. ~ T ~ CQ.w~ ~P.vt.'~" K,~ Lr, ~ Y`e (,c-t t~-Q ~ . ~ursu~t '[,' Zo i4~-C Zs, 0~5 C(ti~Ltl~ ~,.lt~,-~~ BoP~ ~es~ Jv,a ,,~ ~'s ~r~~~d. APPROVED BY THE COMMISSION Date -~^Q ,COMMISSIONER Form 10-401 Revised 12/2005 vvC~ ~ Submit In Duplicate ~RJGlNA~. • ~ Well Name: WGI-O1A Planned Well Summary Horizontal Well WGI-01A Well Sidetrack Target Zone 1B Type Producer Objective API Number: 50-029-20369-01 Current Status WGI-01 Shut-In and P&A Procedures commencing Estimated Start Date: 20-Aug-2006 Time to Com lete: 18.0 Days Surface Northin Eastin Offsets TRS Location 5,972,003 684,986 258' FNL / 1209' FEL 11 N, 14E, 11 Target Northin Eastin TVDss Offsets TRS Location 5,973,900 684,055 -8,440 3619' FNL / 3188' FWL 11 N, 14E, 2 Bottom Northin Eastin TVDss Offsets TRS Location 5,973,900 684,055 -8,580 3619' FNL / 3188' FWL 11 N, 14E, 2 Planned KOP: 2800'MD / 2755'TVDss Planned TD: 9,210' MD / 8,580' TVDss Ri Nabors 27E CBE: 17.6' RTE: 51.1' Directional -Sperry P02 KOP:~ 2800' MD Maximum Hole An le: ~35° in the 12'/a" intermediate section Close Approach Wells: All wells pass major risk close approach criteria. The closest well is WGI-02 at 110' ctr-ctr 44' allowable deviation at 3100' tanned MD. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 18400' to the PBU property line Nearest Well within Pool: L1-15 is 711' away from planned well WGI-O1A at 9012' planned MD. Ll-~s t~Rr3z pf~ /~/-~S/4- 203 ~io WGI-OlA Permit to Drill Application Page 1 • Formation Markers WGI-OlA (Based on 5OR) • Formation Estimated Formation Tops (TVDss) (TVDbkb) (MDbkb) Estimated Pore Press. ( EMW / Psi) SV4 3275 3320 3327 UG4 4780 4825 4940 UG3 5040 5085 5219 UG1 5500 5545 5712 WS2 6105 6150 6360 WS1 6300 6345 6569 CM3 6555 6600 6842 CM2 6950 6995 7265 CM1 7420 7465 7769 THRZ 7765 7810 8139 BHRZ 7990 8035 8380 LCU 8000 8045 8391 TSGR 8015 8060 8407 TSHA 8055 8100 8450 TSHB 8065 8110 8460 TSHC 8075 8120 8471 TSAD 8080 8125 8476 42S6 8125 8170 8525 TCGL 8200 8245 8605 BCGL 8265 8310 8675 23S6 8320 8365 8734 22TS 8370 8415 8787 21 TS 8395 8440 8814 7.8 / 3383 TZ1 B 8440 8485 8862 TDF 8480 8525 8905 BSAD 8530 8575 8959 /" TD Criteria: Approx. 50 ft TVD below BSAD or sufficient rat hole required to complete lowest Z1 B sand. Final TD will be determined by both the town & wellsite geo. Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 121/a" 9 5/8" 47 L-80 TC-II 6,870 4,760 8,613' 33' / 33' 8,646' / 8,060' 8-1/z" 7" 26# L-80 BTC-M Slotted Slotted 714' 8,496' / 9,210' / 7,910' 8,624' Tubing 7 5/8" 29.7# L-80 Vam 6,890 4,970 8,170' 33' / 33' 8,433' / To HC 7,846' Tubing 7" 26# L-80 TC-II 7,240 5,410 67' 8,433' / 8,500' / 7,846' 7,914' WGI-OlA Permit to Drill Application Page 2 • • Mud Program Hole Section / o eration: Drillin 12-'/a" interval, surface shoe - 8,396 (To HRZ) T e Densit Viscosit PV YP Chlorides API FL H LSND 9.1 - 9.3 45 - 60 15 - 22 25 - 30 <600 6.0 - 8.0 9.0 - 9.5 Hole Section / o eration: Drillin 12-'/a" interval, 8,396 (HRZ)-8,646 (Int TD T e Densi Viscosit PV YP Chlorides API FL H LSND 9.6 '' 45 - 60 18 - 25 25 - 35 <600 < 5.5 9.0 - 9.5 ~'' Hole Section / o eration: Drillin 8-'/z" roduction interval to 9,210' (TD) T e Densit Viscosit PV YP LSRV API FL H Flo-Pro SF g 4 - 8.6 45 - 55 8 - 15 24 - 30 >20,000 7.0 - 9.0 9.0 - 9.5 Logging Program Hole Section: Required Sensors /Service 12'/2" intermediate: Real time MWD Dir/GR/PWD 8'h" roduction: Real time MWD Dir/GR/PWD O en Hole: None Cased Hole: USIT in Intermediate section Cement Program Casin Strin 9 5/8", 47#, L-80, TC-II Intermediate casin Ion strin 2 Sta e Slurry Design Basis: (Stage 1) Tail slurry. 1,000' of 9 5/e" x 12-'/a" annulus with 40% excess, plus ~80' of 9 5/8", 47#, shoe tract. Tail TOC @ 7,650 md. Lead Slurry. 1,650' of 9 5/8" x 12-'/a" annulus with 40% excess. Lead TOC to 6,000' and C sta e tool set 'ust below the UG1. Pre-Flush Sta e 1 : 20 bbls CW 100 S acer Fluid Sta a 1): 100.0 bbls MudPush II at 11.5 pp Slur T e 12.5 Litecr to L d Sl Mix method ~_ Batch"Mix ea urry: (Sta l BHST /BHCT 80° F / 80° F ge ) Thickenin time ~ hrs 100 Bc Slur Volume 129 bbf / 723 cf / 2 sx Litecrete, 12.5 .2 cf/sk Slur T e 15.8 Class ` liner slur with `GASBL additive T il Sl Mix method Batch mix a urry: (Sta e 1 BHST /BHCT 170° F / 130° F g ) Thickenin time 5 hrs Slur Volume 84 bbls / 471 cf / 0 x Class `G', 15.8 .1 cf/sk. Slurry Design Basis: (Stage 2) Tail slurry. 1,000' of 9 5/8' x 12-'/a" a ulus with 40% excess. TOC 5,000 and (just over top UG4). Le s urry. 2,270' of 9 5/8" x 12-~/a" annulus with 40% excess. Lead TOC to ,73 md, 13 3/" surface casin shoe. Pre-Flush Sta e 2 : Is CW 100 S acer Fluid Sta e 2 : 150 bbls MudPus h II at 10.0 pp Slur T e 11.0 Lite Crete slur L d Sl Mix method Batch mix ea urry: St 2 BHST /BHCT 80° F / 80° F ( age ) Thickenin time 4 hrs 27 min Slur Volume 177.0 bbls / 994 cf 29 sx Litecrete, 11.0 ~ .3 cf/sk. Slur T e 15.8 Class `G' xter slur with `GASBLOK' ~ itive T il Sl Mix method Batch mix a urry (sta e 2) BHST /BHCT 80° F / 1.30° F verif BHCT with MWD. Provide to SLB g Thickenin time 5 hrs 14 minute ~ Slur Volume 78 bbls / 438 c / 378 sx Class `G', 15.8 , 1.16 f/sk. WGI-OlA Permit to Drill Application Page Surface and Anti-Collision Issues • Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. WGI-01 is on the end of a well row; WGI-02 is the closest well at 120' center. Close Approach Shut-in Wells: All wells pass major risk close approach criteria. The closest well is WGI-02 at 110' ctr-ctr (44' allowable deviation) at 3100' planned MD. Hydrogen Sulfide WGI is not designated as an H2S site. #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) Date of Well Name H2S Level Reading WGI-02 Gas in'ector - WGI-03 no sam les NGI-06 Gas in'ector - NGI-09 no sam les NA H2S Samples are not taken on WGI Faults The proposed WGI-01A well is located in a localized high and the structural dip is expected to be to the west. No seismically mapped fault crossings are expected in WGI-01 A, however, one fault was crossed in the parent well, WGI-01. Four faults are mapped in the BSAD in the near vicinity of the proposed WGI-01A. The coordinates for these faults will be provided in the directional plan details. The risk of fault- and fracture-associated lost circulation is considered low to medium. Significant losses (>100 barrels) were recorded in a few of the surrounding WGI, NGI, and L1 wells but no losses were observed in the WGI-01 parent well. The majority of the losses in the surrounding wells were observed below the BSAD with a couple observed in Zone 2 (WGI-02 and NGI-07) and one in Zone 1 (WGI-02). However, since no losses were recorded in the parent well, the risk of lost circulation is considered low. WGI-OlA Permit to Drill Application Page 4 • Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 12'/z" intermediate interval into TSAD Maximum antici ated BHP: 3,383 si at 8,440' tvd. Maximum surface ressure: SI (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: 173 bls with 11.0 pp EMW LOT Planned BOPE test ressure: si low / 4,000 si hi h -14 da test c cle Drillin o erations BOPE configuration for 9 5/8" intermediate casing (top to bottom . Annular preventor, 9-g/e"pipe rams, blind/shear rams. Well Interval: 8'/z" injection interval in Ivishak Zones 1, 2, 3 and 4 sands Maximum antici ated BHP: 3,453 psi at 8,624' tvd. Maximum surface pressure: 2,590 pSl (based upon BHP and a full column of gas from TD (~ 0.10 psi/ft) Calculated kick tolerance: I 'Hite with 10.0 pp EMW FIT. Planned BOPE test ressure: 250 ` si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: pp seawater / 7.1 pp Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. ~~ BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular No annular injection in this well. In'ection• Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at Handlin DS-04. Any metal cuttings should be sent to the North Slope Borough. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for disposal. WGI-OlA Permit to Drill Application Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.70 ppg EMW. This pressure is estimated based on offset well pressures. II. Lost Circulation/Breathing A. The risk of fault- and fracture-associated lost circulation is considered low to medium. Significant losses (>100 barrels) were recorded in a few of the surrounding WGI, NGI, and Li wells but no losses were observed in the WGI-01 parent well. The majority of the losses in the surrounding wells were observed below the BSAD with a couple observed in Zone 2 (WGI-02 and NGI-07) and one in Zone 1 (WGI-02). However, since no losses were recorded in the parent well, the risk of lost circulation is considered low. 111. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 173 bbls with 9.6 ppg mud, 11.0 ppg FIT, and an 7.7 ppg pore pressure at the top of the Sag River. This FIT should prove up adequate formation strength for expected ECD's. Kick tolerance drops to 50 bbls at a reservoir pressure of 9.1 ppg. B. Recent sidetrack AGI-07A experienced gas cut mud in the reservoir, although reservoir pressure was predicted at 7.7 ppg. After weighting up to 9.0+ ppg the gas ceased, but minor static losses ensued and did not cease throughout the remainder of the well and completion. Gas-detection/mud logging equipment will be available to aid the mud weight decision process if gas cut mud occurs in this well. C. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 10.0 ppg FIT, and an 8.8 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. D. Integrity Testing Test Point Test Depth Test EMW (lb/gal) t e 9 5/8" 20-ft minimum from the 9-5/8" FTT 11.0 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal with the short, vertical, slotted liner completion. VI. Hydrogen Sulfide A. WGI is not designated as an H2S site since samples are not taken on the pad, however Standard Operating Procedures for H2S precautions should be followed at all times. VII. Faults A. The proposed WGI-O1A well is located in a localized high and the structural dip is expected to be to the west. No seismically mapped fault crossings are expected in WGI-O1A, however, one fault was crossed in the parent well, WGI-01. Four faults are mapped in the BSAD in the near vicinity of the proposed WGI-01 A. The coordinates are provided with the directional plan. Regional Fault #1 is likely the fault that was crossed by the WGI-01 parent well. VIII. Anti-Collision Issues All wells pass major risk close approach criteria. The closest well is WGI-02 at 110' ctr-ctr (44' allowable deviation) at 3100' planned MD. The closest well in the reservoir section is Li-15 at 711' center-center at ±9000' MD. WGI-OlA Permit to Drill Application Page 6 WGI-01 A Drill and Complete Procedure Summary Background: WGI-01 was drilled and completed in August 1979. It was worked over in August 1997 to increase injection by replacing 7" non-coated tubing with 7 5/8" plastic coated tubing. Recent injection capacity is 250 mmscfd at 3600 psi. WGI-01 has several integrity issues. • It has a leak in the 9 5/8" casing at 6430'. This liquid leak rate is --1.5 gpm at 3500 psi. The leak depth was confirmed via Leak-Detect-Log on 2/9/03. It was waivered for the PC leak April 2003. • It has slow Ix0 communication. The OA repressurization rate was within guidelines. It was waivered for Ix0 June 2004 • It also has slow but chronic inner annulus repressurization (Txl communication). The source of the Txl is the SSSV control/balance lines. The solution to date has been to change out the SSSV. The IA repressurization has been manageable with bleeds in accordance with operating policy. In July the IA repressurization rate increased. SSSV change out did not help. By December 2005 the cumulative integrity issues were deemed unmanageable and all waivers were cancelled. The well was shut in and safed out 2/11/05. Pre-Rig Work: 1. Pull Tbg Tail Plug @ 7,814'. 2. Fluid pack the IA and tubing. 3. MIRU service coil and P&A current perforations from 9228' to 8695'. 4. Jet cut 7" tbg C~ 6,500'. 5. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 27E. 2. Circ out freeze protect and install TWC. 3. ND Tree and adapter flange. NU BOP and test to 4,000 psi. 4. Pull TWC. 5. POOH w/ 7-5/B' tbg from pre-rig cut C~ 6,500'. PU 5" DP and stand back. 6. MIRU Schlumberger. Run gauge ring/ JB to 3000'. Run USIT 2900' to surface. 7. Set CIBP C~ 2,900'. Test csg to 4,000 psi. 8. TIH w/ Multi string mechanical cutter. Spot 300' of 18 ppg mud pill on top of CIBP. 9. Make initial cut Cad 2,830'. Circulate through cut. Make second cut if necessary. 10. POOH w/ cutter. Change over to 9-5/a" rams and test BOPE. 11. POOH w/ 9-5/d' casing and make 13-3/e" clean out run. 12. TIH w/ cmt stinger and spot 17.0 ppg kick off plug from 50' below 9 5/8" stub to 100' into 13 3/8" casing. 13. POOH and LD cement stinger. 14. Test the 13 3/8" casing to 4,000 psi for 30 minutes. ~ 15. MU 12-'/a" drilling assembly with Dir/GR/PWD and RIH to TOC. Circulate and dress cement plug down to KOP. Displace over to new LSND mud. 16. Drill new formation to 20' below 13 '/d' shoe and perform LOT. 17. Drill to ± 200' above the HRZ, ensure mud is conditioned and weighted to 9.6 ppg. Ensure pre-reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 18. Drill ahead to target TD at 8,646' MD, (Top set Sag). ~ 19. Circulate and condition hole, POOH to run casing. Perform wiper trip ONLY if hole conditions dictate. CN 20. Run and cmt the 9-5/e" intermediate casing in two stages. Ensure 500 psi compressive on first stage prior to ~ pumping second stage. Displace with seawater during cementing operations. Bump plug and ensure that float ~ holds. Install 9-5/8" casing packoff and test per FMC rep. Freeze protect the 13-9/" x 9-5/8" annulus. ~ WGI-01A Permit to Drill Application Page 7 'r • • 21. MU 8-'/z" drilling assembly with MWD / GR / PWD and TIH to ES cementer. Drill out ES cementer and TIH to float equipment. 22. Test casing to 4,000 psi. Drill out Float equipment and displace to clean Flo-Pro SF. ~ 23. Drill shoe and 20' of new formation. Perform FIT. 24. Drill to Proposed TD (~3 9,210'. Short trip as required; condition hole to RIH w/ 7" slotted liner. POOH. 25. Run 7" 26 ppf slotted liner. There will be 150' of overlap into the 9 5/s" intermediate casing. Set liner top packer. ~'" Release from liner, displace well to filtered seawater and POOH. 26. RU Schlumberger wireline and run USIT from liner top packer to TOC. 27. Run 7-5/d' 26 ppf, VamTop HC completion. Gator Hawk all connections. RILDS. Install TWC and test. 28. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 29. RU LRHOS. Reverse in SW and CI. Pump freeze protect and allow to U-tube. Set packer @ 8,433'. 30. Notify AOGCC for witnessing tubing and annulus to 4,000 psi. 31. Install BPV in tubing hanger. Install a VR plug in the 9 5/8' x 7" annulus valve and secure the well. Ensure that IA/OA are both protected with two barriers. 32. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC. 2. Pull VR plug. WGI-O1A Permit to Drill Application Page 8 TREE = GRAY WELLHEAD = GRAY ACTUA70R = AXELSON KB. ELEV = 49' BF. ELEV = KOP - 3500' Max Angle = 39 @ 9200' Datum MD =_ __ ~ Datum TVD = 8800' SS ~ WGI-01 7" TBG, 29.0#, L-80, 0.0371 bpf, ID = 6.184" ~ 2' 7-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, ID = 6.875" 2182' TOP OF 7" TBG 2182' 7" TBG, 29#, L-80, .0371 bpf, ID = 6.184" 21$7' TOP OF 7-5/8" TBG 2187' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2731' Minimum ID = 4.845" @ 7920' BAKER SHEAROUT SUB 7-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, ID = 6.875" 7801' TOP OF 7" TBG 7801' 7" TBG, 29#, L-80, .0371 bpf, ID = 6.184" 7$23' TOP OF 7" TBG ~-~ 7902' 7" TBG, 29#, N-80, .0371 bpf, ID = 6.184" ~ 7921' TOP OF 7" LNR 8019' elm 9-5/8" CSG, 47#, N-80, ID = 8.681" 8314' PERFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE See Perforation Data on Page 2 PBTD 9292' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 9334' 2182' ~ 7-5/8" X 7" XO 2183' 7" CAM BAL-O SSSV NIP, ID = 5.937" 2187' 7" X 7-5/8" XO 7795' I~ 9-5/8" X 7" BKR SAB PKR 7801' 7-5/8" X 7" XO 7814' 7" HES RN NIP, ID = 5.5" 78~ 7" TUBING TAIL WLEG 71 902' I-19-5/8" X 7" BKR SB-2 PKR i 7920' 7" BKR SHEAROUT SUB (NO TAILPIPE) ID = 4.845" 7910' ELMD TT LOGGED 08/07/79 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTPPLUGPULLED(12/19/05) 08/11/97 LAST WORKOVER 11/03/01 RNITP CORRECTIONS 03!22/03 JM/KAK PULL IBP 12/11/05 ???lTLH SETTTP 12/13/05 RPH/TLH WANER SFTY NOTE DELETED PRUDHOE BAY UNff WELL: WGF01 PERMff No: 1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) ~ WGI-01 ~ PERFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 4 8695-8725 O 08/10/80 3-3/8" 4 8725-8745 O 03/01/87 3-3/8" 4 8745-8785 O 08/10/80 3-3/8" 4 8785-8797 O 03/01/87 3-3l8" 4 8813-8853 O 08/10/80 3-3/8" 4 8853-8907 O 03/01/87 3-3/8" 4 8907-8917 O 08/10/80 3-3/8" 4 8934-8954 O 08/10/80 3-3/8" 4 8954-8983 O 03/01 /87 3-3/8" 4 8983-9003 O 08/10/80 3-3/8" 4 9008-9018 O 03/01/87 3-3/8" 4 9024-9034 O 08/10/80 3-3/8" 4 9040-9048 O 03/01/87 3-3/8" 4 9048-9058 O 08/10/80 3-3/8" 4 9074-9082 O 03/01/87 3-3/8" 4 9082-9102 O 08/10/80 3-3/8" 4 9102-9122 O 03/01/87 3-3/8" 4 9122-9142 O 08/10/80 3-3/8" 4 9143-9151 O 03/01 /87 3-3/8" 4 9156-9162 O 03/01/87 3-3/8" 4 9162-9182 O 08/10/80 3-3/8" 4 9208-9228 O 08/10/80 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED (12/19/05) 08/11/97 LAST WORKOVER 11/03/01 RN/TP CORRECTIONS 03/22/03 JM/KAK PULL IBP 12!11/05 ???/TLH SETTTP 12/13/05 RPH/TLH WA V ER SFTY NOTE DELETED PRUDHOE BAY UNff WELL: WGI-01 PERMff No: '1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18' & FEL 2926.14' FNL BP 5cploration (Alaska) TREE = GRAY WELLHEAD= ~,",_.~„m ACTUATOR= GRAY ,.," AXELSON KB. ELEV = 49' ~ WGI-01A 7" Al INJECTION VALV E SEATED IN CAMCO DB6 NIPPLE (ID = 6") 6920' HES ES CEMENTER 7-5/8" 29.7#, L-80, VAM TOP HC, IPC, 0.04591 bpf, 8433' ID = 6.875" 8433' 7" x 9-5/8" S-3 PKR, ID = 6.05" 8458' HES R Nipple, ID = 5.963" 8479' HES RN Nipple, ID = 5.770" 8496' 7" 26#, L-80, TC-II, IPC, 0.03826 bpf, ID = 6.276" FLEXLOK LINER HANGAR W/ ZXP LINER TOP PKR, 8496' ID = 6.25", 12' TBS w / 7.5" ID 8646' 9-5/8" 47#, N-80, TC-II, 0.07321 bpf, ID = 8.681" 9124' PBTD 9210' 7" SLOTTED LNR, 29#, N-80, BTGM, 0.0371 bpf, ID = 6.184" DATE ~ REV BY~MMEN I/06/O6 STG ORIGINAL COMPL PRUDHOE BAY UNff WELL: WGI-01A PERMfT No: API No: 50-029-20369-01 SEC 11, T11N, R14E, 1795.18' 8~ FEL 2926.14' FNL ~ S err -Sun P Y BP Planning Report Company: BP Amoco Date: 12/19/2005 Lime: 10:13:07 Page: 1 Ficld: Prudhoe Bay (various) Co-ordinate(NE) Refcrence: WeIC WGI-01, True North Site: WGI Vertical (TVD) Reference: 2:01 8!5(1997 17:00 44.5 Well: WGI-01 Section (VS) Reference: Well (O.OON,O.OOE,335.28Azi) Wcllpath: Plan WGI-01A Survey Calculation lytethod: Minimum Curvature Db: Oracle Plan: WGI-01A wp02 Date Composed: 12/14/2005 Version: 9 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay (various) Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: WGI TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5971028.59 ft Latitude: 70 19 32.905 N From: Map Easting: 685599.07 ft Longitude: 148 29 41.399 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.42 deg Well: WGI-01 Slot Name: 01 WGI-01 Well Position: +N/-S 989.24 ft Northing: 5972002.90 ft Latitude: 70 19 42.634 N +E/-W -589.10 ft Easting : 684985.72 ft Longitude: 148 29 58.597 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Holc Size Name ft ft in in 8645.96 8059.50 9.625 12.250 9 5/8" 9210.00 8623.54 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle D ip Direction ft ft deg deg 3323.98 3319.50 SV4 0.00 0.00 5081.67 4824.50 UG4 0.00 0.00 5397.61 5084.50 UG3 0.00 0.00 5956.59 5544.50 UG1 0.00 0.00 6688.51 6149.50 WS2 0.00 0.00 6907.94 6344.50 WS1 0.00 0.00 7179.31 6599.50 CM3 0.00 0.00 7580.87 6994.50 CM2 0.00 0.00 8050.96 7464.50 CM1 0.00 0.00 8395.96 7809.50 THRZ 0.00 0.00 8620.96 8034.50 BHRZ 0.00 0.00 8630.96 8044.50 LCU 0.00 0.00 8645.96 8059.50 TSGR 0.00 0.00 8685.96 8099.50 TSHA 0.00 0.00 8695.96 8109.50 TSHB 0.00 0.00 8705.96 8119.50 TSHC 0.00 0.00 8710.96 8124.50 TSAD 0.00 0.00 8755.96 8169.50 42S6 0.00 0.00 8800.96 8214.50 FAULT* 0.00 0.00 8830.96 8244.50 TCGL 0.00 0.00 8895.96 8309.50 BCGL 0.00 0.00 8950.96 8364.50 23S6 0.00 0.00 9000.96 8414.50 22TS 0.00 0.00 9025.96 8439.50 21TS 0.00 0.00 9070.96 8484.50 TZ16 0.00 0.00 9110.96 8524.50 TDF 0.00 0.00 9160.96 8574.50 BSAD 0.00 0.00 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 12/19/2005 Time: 10:13:07 Page: 2 Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: WGI-01, True North Site: WGI Vertical (TVD)Reference: 2:018!5/199717:0044.5 Welt: WGI-01 Section (VS) Reference: Well (O.OON,O.OOE,335.28Azi) Wellpath: Plan WGI-01A Survey Calculation J~Iethod: Minimum Curvature Db: Oracle Targets Map Map <____ Latitude -> <~ Longitude -> Name Description TVD +Nl-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Uir. ft ft ft ft ft WGI-01AT1 8619.50 1919.59 -883.72 5973900.00 684055.00 70 20 1.512 N 148 30 24.402 W -Circle (Radius: 300) -Plan hit target Plan Section Information MD ft Ind deg Azim deg TVD ft +~/-S ft +E/-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft TFO Target deg 2800.00 0.45 149.96 2799.99 -0.87 2.14 0.00 0.00 0.00 0.00 2850.00 1.13 88.19 2849.98 -1.03 2.73 2.00 1.37 -123.54 -85.00 4019.35 34.62 334.93 3950.28 309.99 -130.69 3.00 2.86 -9.69 -114.75 6551.94 34.62 334.93 6034.44 1613.28 -740.41 0.00 0.00 0.00 0.00 7705.96 0.00 330.00 7119.50 1919.59 -883.72 3.00 -3.00 0.00 180.00 9205.96 0.00 330.00 8619.50 1919.59 -883.72 0.00 0.00 0.00 0.00 WGI-01A T1 9210.46 0.00 330.00 8624.00 1919.59 -883.72 0.00 0.00 0.00 330.00 Survey MD Inc! Azim TVD Sys "1'VD VS N/S E/W DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft ft deg/100ft ft ft 2800.00 0.45 149.96 2799.99 2755.49 -1.69 -0.87 2.14 0.00 5972002.08 684987.88 MWD+IFR+MS 2850.00 1.13 88.19 2849.98 2805.48 -2.08 -1.03 2.73 2.00 5972001.94 684988.48 MWD+IFR+MS 2900.00 1.45 18.44 2899.97 2855.47 -1.81 -0.41 3.43 3.00 5972002.57 684989.16 MWD+IFR+MS 3000.00 4.16 347.72 2999.85 2955.35 2.66 4.33 3.06 3.00 5972007.31 684988.67 MWD+IFR+MS 3100.00 7.10 341.71 3099.36 3054.86 12.34 13.74 0.35 3.00 5972016.65 684985.73 MWD+IFR+MS 3200.00 10.08 339.23 3198.22 3153.72 27.21 27.80 -4.70 3.00 5972030.57 684980.34 MWD+IFR+MS 3300.00 13.07 337.87 3296.18 3251.68 47.24 46.45 -12.06 3.00 5972049.04 684972.52 MWD+IFR+MS 3323.98 13.78 337.63 3319.50 3275.00 52.80 51.60 -14.17 3.00 5972054.14 684970.29 SV4 3400.00 16.06 337.01 3392.96 3348.46 72.36 69.66 -21.72 3.00 5972072.00 684962.29 MWD+IFR+MS 3500.00 19.05 336.42 3488.29 3443.79 102.51 97.36 -33.66 3.00 5972099.39 684949.67 MWD+IFR+MS 3600.00 22.05 335.98 3581.91 3537.41 137.61 129.47 -47.83 3.00 5972131.14 684934.71 MWD+IFR+MS 3700.00 25.05 335.64 3673.58 3629.08 177.55 165.91 -64.21 3.00 5972167.16 684917.44 MWD+IFR+MS 3800.00 28.04 335.37 3763.02 3718.52 222.24 206.57 -82.74 3.00 5972207.35 684897.91 MWD+IFR+MS 3900.00 31.04 335.15 3850.01 3805.51 271.54 251.34 -103.38 3.00 5972251.60 684876.18 MWD+IFR+MS 4000.00 34.04 334.96 3934.30 3889.80 325.32 300.11 -126.07 3.00 5972299.79 684852.30 MWD+IFR+MS 4019.35 34.62 334.93 3950.28 3905.78 336.24 309.99 -130.69 3.00 5972309.56 684847.43 MWD+IFR+MS 4100.00 34.62 334.93 4016.65 3972.15 382.06 351.49 -150.11 0.00 5972350.56 684827.00 MWD+IFR+MS 4200.00 34.62 334.93 4098.95 4054.45 438.87 402.96 -174.18 0.00 5972401.41 684801.67 MWD+IFR+MS 4300.00 34.62 334.93 4181.24 4136.74 495.68 454.42 -198.26 0.00 5972452.26 684776.33 MWD+IFR+MS 4400.00 34.62 334.93 4263.53 4219.03 552.49 505.88 -222.33 0.00 5972503.11 684751.00 MWD+IFR+MS 4500.00 34.62 334.93 4345.83 4301.33 609.31 557.34 -246.41 0.00 5972553.96 684725.66 MWD+IFR+MS 4600.00 34.62 334.93 4428.12 4383.62 666.12 608.80 -270.48 0.00 5972604.81 684700.33 MWD+IFR+MS 4700.00 34.62 334.93 4510.41 4465.91 722.93 660.26 -294.56 0.00 5972655.65 684674.99 MWD+IFR+MS 4800.00 34.62 334.93 4592.71 4548.21 779.75 711.72 -318.63 0.00 5972706.50 684649.66 MWD+IFR+MS 4900.00 34.62 334.93 4675.00 4630.50 836.56 763.18 -342.71 0.00 5972757.35 684624.32 MWD+IFR+MS 5000.00 34.62 334.93 4757.29 4712.79 893.37 814.64 -366.78 0.00 5972808.20 684598.99 MWD+IFR+MS 5081.67 34.62 334.93 4824.50 4780.00 939.77 856.67 -386.44 0.00 5972849.73 684578.30 UG4 5100.00 34.62 334.93 4839.59 4795.09 950.18 866.10 -390.86 0.00 5972859.05 684573.65 MWD+IFR+MS 5200.00 34.62 334.93 4921.88 4877.38 1007.00 917.56 -414.93 0.00 5972909.90 684548.32 MWD+IFR+MS 5300.00 34.62 334.93 5004.17 4959.67 1063.81 969.02 -439.01 0.00 5972960.74 684522.98 MWD+IFR+MS 5397.61 34.62 334.93 5084.50 5040.00 1119.27 1019.25 -462.51 0.00 5973010.38 684498.25 UG3 5400.00 34.62 334.93 5086.47 5041.97 1120.62 1020.48 -463.08 0.00 5973011.59 684497.65 MWD+IFR+MS 5500.00 34.62 334.93 5168.76 5124.26 1177.43 1071.94 -487.16 0.00 5973062.44 684472.31 MWD+IFR+MS 5600.00 34.62 334.93 5251.05 5206.55 1234.25 1123.40 -511.23 0.00 5973113.29 684446.98 MWD+IFR+MS 5700.00 34.62 334.93 5333.35 5288.85 1291.06 1174.86 -535.31 0.00 5973164.14 684421.64 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: 12/19/2005 Time: 10:13:07 Pagc: 3 Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: WGI-01, True North Site: WGI Vertical (TVD) Reference: 2:01 8/5/1997 17:00 44.5 Well: WGI-01 Section (VS) Reference: Well (O.OON,O.OOE,335.28Azi) Wellpath: Plan WGI-01A Survey Calculation Method: Minimum Curvature Db: Oracle Survev R1D Intl Haim I~VD SysTW YS M1/S E/~V DLS MapN MapN: TooVComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 5800. 00 34.62 334.93 5415.64 5371.14 1347.87 1226.33 -559 .38 0.00 5973214 .99 684396.31 MWD+IFR+MS 5900. 00 34.62 334.93 5497.93 5453.43 1404.69 1277.79 -583 .46 0.00 5973265 .83 684370.97 MWD+IFR+MS 5956. 59 34.62 334.93 5544.50 5500.00 1436.83 1306.91 -597 .08 0.00 5973294 .61 684356.63 UG1 6000. 00 34.62 334.93 5580.23 5535.73 1461.50 1329.25 -607 .53 0.00 5973316 .68 684345.64 MWD+IFR+MS 6100. 00 34.62 334.93 5662.52 5618.02 1518.31 1380.71 -631 .61 0.00 5973367 .53 684320.30 MWD+IFR+MS 6200. 00 34.62 334.93 5744.81 5700.31 1575.12 1432.17 -655 .68 0.00 5973418 .38 684294.97 MWD+IFR+MS 6300. 00 34.62 334.93 5827.11 5782.61 1631.94 1483.63 -679 .76 0.00 5973469 .23 684269.63 MWD+IFR+MS 6400. 00 34.62 334.93 5909.40 5864.90 1688.75 1535.09 -703 .83 0.00 5973520 .08 684244.30 MWD+IFR+MS 6500. 00 34.62 334.93 5991.69 5947.19 1745.56 1586.55 -727 .91 0.00 5973570 .92 684218.96 MWD+IFR+MS 6551. 94 34.62 334.93 6034.44 5989.94 1775.07 1613.28 -740 .41 0.00 5973597 .33 684205.80 MWD+IFR+MS 6600. 00 33.18 334.93 6074.32 6029.82 1801.87 1637.56 -751 .77 3.00 5973621 .32 684193.85 MWD+IFR+MS 6688. 51 30.52 334.93 6149.50 6105.00 1848.58 1679.86 -771 .56 3.00 5973663 .12 684173.02 WS2 6700. 00 30.18 334.93 6159.42 6114.92 1854.38 1685.12 -774 .02 3.00 5973668 .32 684170.43 MWD+IFR+MS 6800. 00 27.18 334.93 6247.14 6202.64 1902.37 1725.58 -794 .36 3.00 5973711 .27 684149.03 MWD+IFR+MS 6900. 00 24.18 334.93 6337.25 6292.75 1945.69 1767.83 -812 .72 3.00 5973750 .04 684129.71 MWD+IFR+MS 6907. 94 23.94 334.93 6344.50 6300.00 1948.93 1770.76 -814 .09 3.00 5973752 .94 684128.27 WS1 7000. 00 21.18 334.93 6429.51 6385.01 1984.24 1802.75 -829 .05 3.00 5973784 .55 684112.52 MWD+IFR+MS 7100. 00 18.18 334.93 6523.66 6479.16 2017.91 1833.25 -843 .32 3.00 5973814 .68 684097.51 MWD+IFR+MS 7179. 31 15.80 334.93 6599.50 6555.00 2041.09 1854.23 -853 .14 3.00 5973835 .42 684087.17 CM3 7200. 00 15.18 334.93 6619.44 6574.94 2046.61 1859.24 -855 .48 3.00 5973840 .37 684084.71 MWD+IFR+MS 7300. 00 12.18 334.93 6716.59 6672.09 2070.26 1880.66 -865 .50 3.00 5973861 .53 684074.17 MWD+IFR+MS 7400. 00 9.18 334.93 6814.85 6770.35 2088.78 1897.44 -873 .35 3.00 5973878 .11 684065.90 MWD+IFR+MS 7500. 00 6.18 334.93 6913.94 6869.44 2102.14 1909.54 -879 .01 3.00 5973890 .07 684059.95 MWD+IFR+MS 7580. 87 3.75 334.93 6994.50 6950.00 2109.14 1915.88 -881 .98 3.00 5973896 .33 684056.82 CM2 7600. 00 3.18 334.93 7013.60 6969.10 2110.30 1916.93 -882 .47 3.00 5973897 .37 684056.31 MWD+IFR+MS 7700. 00 0.18 334.93 7113.54 7069.04 2113.23 1919.58 -883 .71 3.00 5973899 .99 684055.00 MWD+IFR+MS 7705. 96 0.00 330.00 7119.50 7075.00 2113.24 1919.59 -883 .72 3.00 5973900 .00 684055.00 MWD+IFR+MS 7800. 00 0.00 330.00 7213.54 7169.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 7900. 00 0.00 330.00 7313.54 7269.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8000. 00 0.00 330.00 7413.54 7369.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8050. 96 0.00 330.00 7464.50 7420.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 CM1 8100. 00 0.00 330.00 7513.54 7469.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8200. 00 0.00 330.00 7613.54 7569.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8300. 00 0.00 330.00 7713.54 7669.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8395. 96 0.00 330.00 7809.50 7765.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 THRZ 8400. 00 0.00 330.00 7813.54 7769.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8500. 00 0.00 330.00 7913.54 7869.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8600. 00 0.00 330.00 8013.54 7969.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8620. 96 0.00 330.00 8034.50 7990.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 BHRZ 8630. 96 0.00 330.00 8044.50 8000.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 LCU 8645. 96 0.00 330.00 8059.50 8015.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 9 5/8" 8685. 96 0.00 330.00 8099.50 8055.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 TSHA 8695. 96 0.00 330.00 8109.50 8065.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 TSHB 8700. 00 0.00 330.00 8113.54 8069.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8705. 96 0.00 330.00 8119.50 8075.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 TSHC 8710. 96 0.00 330.00 8124.50 8080.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 TSAD 8755. 96 0.00 330.00 8169.50 8125.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 42SB 8800. 00 0.00 330.00 8213.54 8169.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8800. 96 0.00 330.00 8214.50 8170.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 FAULT' 8830. 96 0.00 330.00 8244.50 8200.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 TCGL 8895. 96 0.00 330.00 8309.50 8265.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 BCGL 8900. 00 0.00 330.00 8313.54 8269.04 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 MWD+IFR+MS 8950. 96 0.00 330.00 8364.50 8320.00 2113.24 1919.59 -883 .72 0.00 5973900 .00 684055.00 23S6 ' " ~ S err -Sun P Y BP Planning Report Company: BP Amoco Date: 12/19/2005 'l'ime: 10:13:07 t'age: 4 Ficld: Prudhoe Bay (various) Co-ordi nate(NE) Rcfcrcncr. Well: WGI-01, True North Site: WGI Vertical (CVD) Reference: 2:01 8/5/1997 17:00 44.5 Well: WGI-01 Section (VS) Referen ce: Well (O.OON,0. OOE,335.28Azi) Wellpath: Plan WGI-0 1A Survey Calculation Method: Minimum Curv ature Db: Oracle Su rve~ MD Intl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooVComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 9000.00 0.00 330.00. 8413.54 8369.04 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 MWD+IFR+MS 9000.96 0.00 330.00 8414.50 8370.00 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 22TS 9025.96 0.00 330.00 8439.50 8395.00 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 21 TS 9070.96 0.00 330.00 8484.50 8440.00 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 TZ1 B 9100.00 0.00 330.00 8513.54 8469.04 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 MWD+IFR+MS 9110.96 0.00 330.00 8524.50 8480.00 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 TDF 9160.96 0.00 330.00 8574.50 8530.00 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 BSAD 9200.00 0.00 330.00 8613.54 8569.04 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 MWD+IFR+MS 9210.00 0.00 330.00 8623.54 8579.04 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 7" 9210.46 0.00 330.00 8624.00 8579.50 2113.24 1919.59 -883.72 0.00 5973900.00 684055.00 MWD+IFR+MS • Terri Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF Y "Mastercard Check" First National Bank Alaska `" Anchorage, AK 99501 MEMO 1'~~~ • 89-6/1252 292 DATE ~~ ~ I'~~ s I OCR .~ ~:L25200060~:99L46227L55611' 0292 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~.,.. J Development Service Exploratory Stratigraphic Test Yon-Convention Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-Olv`S WHAT ~ (OPTIONS) APPLIES I TEXT FOR APPROVAL LETTER MULTI LATERAL 'The permit is for a new wellbore segment of existing well (If last two digits i API number in are ~ Permit No. . API No. 50- - _ ;` between 60-69) i Production should continue to be reported as a function of the i- original API number stated above. PILOT HOLE ~ In accordance with 20 AAC 25.005(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number ~ (50- - -_) from records, data and logs acquired for well ~ SPACING ~ The permit is approved subject to full com liance with 20 AAC + EXCEPTION p ~ 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH I AI[ dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. i Non-Conventional Please note the following special condition of this permit: ~ Well production or production testing of coal bed methane is not allowed ~ ~ for (name of well] until after (Com~anv Name} has designed and implemented a water well testing program to provide baseline data on water quality and quantity. 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