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Home My WebLink About208-132Image Project 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. ~~~ - ~~ ~, Well History File Identifier Or anizin (done) 9 g ^ Two-sided III II'III II III II I II ^ Rescan Needed III (VIII II II III III RES N 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~ Pro "ect Proofing J II I II II II I I III V III BY: Maria Date: ~s~ Scanning Preparation x 30 = BY: Maria Date: Production Scanning + =TOTAL PAGES_~~ (Count does not include cover sheet /s/ Stage 1 Page Count from Scanned File: (count does include co er sheet) hes Number in Scannin Pre aration: ~ YES NO Page Count Matc 9 pp~ BY: Maria Date: ~ ~ rV ~s~ 7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s ~~ i ii ^i ~~ i i~ u i i ~i Scanning is complete at this point unless rescanning is required. Rescanned III IIIIIIIIIII VIII BY: Maria Date: ~s/ Comments about this file: Quality Checked III II'III III (I~I III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/24/2010 Permit to Drill 2081320 Well Name/No. PRUDHOE BAY UNIT 18-14BL1 Operator BP EXPLORATION (ALASI(a INC API No. 50-029-21614-60-00 MD 12960 ND 8767 Completion Date 10/9/2008 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Well Cores/Samples Information: Interval Name Start Stop (data taken from Logs Portion of Master Well Data Maint log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ..~-F~' Daily History Received? ~- Chips Received? Y-/-Pd Formation Tops ~ N Analysis X~td Received? Comments: 'P ~ ~ ~~ - 1`'I 13 L,1 ~1.~ ~° 1) ~.~~) ~. c.s ~eev. ~~ vv,i ~,,sP+-w~i u~ ~- bw,,.~.t ~.-a:~ . ~'~ni we,~llva v^. s ~~ w.z~ 'h~~~~L~ N~,..a.,M.~ ~~u 1~~~~c.- ~~~~-lsl-~)~ Y~'~u~8.-1~~~,1 `~~~ {~~.. Y'~5~•18-I~cc_ ~_~`~~ •* Compliance Reviewed By: . 4~ Date: __ ~-t ~ t+~.•~ Z-l1 ~O P°'~ ~ . STATE dF ALASKA l ~~~~ ALASKA~L AND GAS CONSERVATION CQM~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG AdEnlnistrative Abandon -See Attached Note 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ SuspeRCted 20AAC 25.105 zoAAC zs.» o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: , ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/9/2008 12. Permit to Drill Number 208-132' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/28/2008 13. API Number 50-029-21614-80-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/3/2008 14. Well Name and Number: PBU 18-14BL1 ' 4351 FSL, 4609 FEL, SEC. 19, T11 N, R15E, UM Top of Productive Horizon: 884' FSL, 3644' FEL, SEC. 19, T11 N, R15E, UM 8. KB (ft above MSL): 46.4 R Ground (ft MSL): 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 214' FSL, 2503' FEL, SEC. 19, T11 N, R15E, UM 9. Plug Back Depth (MD+TVD) 12867' 8759' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 692104 y- 5960948 Zone- ASP4 10. Total Depth (MD+TVD) 12960' 8767' 16. Property Designation: ADL 028321-~ TPI: x- 693171 y_ 5957508 Zone- ASP4 Total Depth: x- 694332 - 5956867 Zone- ASP4 11. SSSV Depth (MD+TVD) 2213' 2213' 17. Land Use Permit: y 18. Directional Survey ^ Yes ®No ni 'n orm i 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.). 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, MCNL 22. CASING, LINER AND CEMENTING RECORD CASING- SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 6" -4 11 rf 1 4" 1 I ~~ ~ ~ 4 " 1 ! 17 / 4" 1 x' x' _/„ " 4 12 74' 7 ' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; p 3-1/2", 9.3#, 13Cr80 / 9Cr 9118' 9062' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect w/ Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR IZATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ® No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None /DD Form 10-407 Re, ise !0~2/20[0~7 CONTINUED ON REVERSE SI °' ' ~. ~a 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested . Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kicked off in Zone 1A None (From 18-146) Zone 1A /TDF 10448' 8729' Formation at Total Depth (Name): Zone 1 A /TDF 10448' 8729' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoi g is true a n correct to the best of my knowledge. I ~~J~ Signed Terrie Hubble Title Drilling Technologist Date PBU 18-146L1 208-132 Prepa-ed By NamelNumber. Terris Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing fnterval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 RevisedA2/2007 Submit Original Only 18-14BL1 -change of completion ~ Page 1 of 2 Hubble, Terrie L From: Maunder, Thomas E (DOA) [tom maunder@alaska.gov] Sent: Monday, October 06, 2008 10:09 AM To: Hubble, Terrie L Subject: DS 18-14BL1 (208-132) Terrie, We have received the sundry to abandon 18-146 and the PTD for 18-14C. After much discussion over here, it will also be necessary to submit a 407 abandoning 18-14BL1. All that is needed is the orm wit a copy o t is message an s or you a en ion o is ma er. a wi put a t e proper paperwor in p ace. a or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Friday, October 03, 2008 2:38 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Tom, I put the following statement in the sundry regarding the reserves in the drainage area as I though it addressed the reserve accessibility issue. The low remaining reserves in 18-146 would be accessible with a future side track from 18-14C, 18-036, or 18-24B. Here is a little more information on the parent well. 18-14B has little remaining value to the field and would not sustain production on its own. The sidetrack was first planned with a solid cemented liner. 18-148 is a horizontal well low in Z1 A and has low perm. The team decided to take the risk and plan a slotted liner completion. The intention (hope) was to use the flow from 18-146L1 to pull a little more liquid from 18-14B before it was plugged. If/when the 18-14B well goes to excessively high GOR it would be plugged. The prize was to save ~$700k in completion costs and attempt to keep 18- 146 online. When another wellbore becomes available the 18-14B drainage area will be evaluated for redevelopment. Regards, sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, October 03, 2008 12:34 PM To: Maunder, Thomas E (DOA); McLaughlin, Sean M Cc: McMullen, John C; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Sean, I am reviewing the permit application for DS 18-14C. I have included copies of our messages that describe why the changes were necessary. One item still missing is highlighted in our message of yesterday (below). I would appreciate a statement addressing the now not accessible reserves. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 10/30/2008 18-14BL1 -change of completion ~ Page 2 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, October 02, 2008 11:34 AM To: 'McLaughlin, Sean M' Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Sean, Thanks for the information. You are correct that this newly drilled well segment will become 18-14C. I have spoken to my colleagues and unfortunately it will be necessary to submit a new permit application. This is necessary due to the data system we employ. It is not possible to just "over write" information. It will also be necessary to submit a 407 abandoning the lost portion of 18-14B. It is not necessary to halt operations. The new application should be submitted as soon as possible. Please include a discussion of what has happened to require the new permit. There should also be a discussion regarding the reserves that will no longer be accessible due to the plugging of 18-146. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Thursday, October 02, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor Subject: 18-14BL1 -change of completion plan Tom, Nordic 1 is currently drilling 18-14BL1. This lateral was planned to be completed with a slotted liner. Unfortunately last night the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent well bore. Our planned 18-14BL1 would then become 18-14C. Would this require a change to the current permit (208-132) or a new permit? Regards, Sean «18-14BL1.jpg» «18-14C.jpg» Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 10/30/2008 vr~LHrHL~ = rn ACTUATOR = BAKER :B. ELEV = 47. 3F. ELEV = SOP = 45C Aax Angle = 97 @ 1221 )alum MD = 91 )alum TVD = 8800' f DRLG DRAFT 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~-j 3452' TOP OF 5-1/2"" SCAB LNER ~~ 3530' Minimum ID = 2.750" @ 9086' 3-112" HES X NIPPLE 1 /2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" I~ $509' 1 V -14 C I ~L'~y'~i ON DIAGRAM. 3A1 /2" CHROME TBG. 2213 -{ 3-1/2" CAMCO TRM-4E TRSSSV, ID = 2.812" ® I LOCKED OPEN (02/28/08) GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LTCH PORT GATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/( 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/( 1 8322 7510 39 KBG2-9 DMY INT 0 03/11IC 3530 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1 /2" BKR ZXP LTP, ID = 4.910" 3$43' 7-5/8" X 5-1 /2" FLIX LOCK HGR, ID = 4.820 8509 BKR C-2 TIEBACK SLV, ID =? 8517' 7-518" X 5-112" BKR H PKR, ID = 4.812" 8522 5-1/2" HMC LNR HGR, ID = 4.938" 7-518" CSG, 29.7#, L-80, ~ = 6.875" 8700' PERFORATION SUM~AARY REF LOG: MCNL Log CCL/GR/CNL O6-OCT-08 A NGLE A T TOP PERF: 89 ~ 10860' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 1.56" 6 10860-10890 O 10/07!08 1.56" 6 10920.10990 O 10/07/08 1.56" 6 10080-11130 O 10/07/08 1.56" 6 11280-12080 O 10/07/08 1.56" 6 12470.12490 O 10!07/08 1.56" 6 12530-12610 O 10!07/08 1.56" 6 12700-12859 O 10/07/08 3-1 (2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" ~-I] 9118' ~~ TOP OF EZSV $596' 10590 Liner Top Packer Note: LTP did NOT set i-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ID= 4.767" ~ 10312 ~ 3-1/2" LNR, 9.2#, L-80 IBT M, .0087 bpf, ID = 2.992" ~ ~ PBTD ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11/08186 ORIGINAL COMPLETION 09/24/04 KDCrTLH TRSSSV CORRECTION 02/25/95 RIG SIDETRACK (18-14Aj 06/24/07 KSB/PJC GLV CIO 04101/95 CTD (2-7/8" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS 03113/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWC/PJC TRSSSV LOCKED OPEN (02/28/( 03/16/04 JBM/KAK GLV C/O 05/30/08 DAV/PJC TRSSV CORRECTION (02/21108 09/1R/04 GJB/TLP GLV C/O 1n/os/na Nordir. 1 CTD Sidetrack f18-14(1 9041 I--13-112" HES XNIP, O = 2.813" 9062' --15-1 /2" X 3-112" BKR S-3 PERM PKR, ID = 2.770" ~3-1/2" HES X NIP, ~ = 2.813" ~ 9106 J-~3-1/2" HES XN N~, ID = 2.750" I 9118 3-112" WLEG, ID = 2.992" 9413 5-1/2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' 5-112" X 3-1 /2" BKR ZXP LTP, ID = 3.410" MLLOUT WINDOW (18-146) 9568' - 9581' I t 10593 2 3!8" TOP OF LINER DepbVment Sleeve 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 12904 TD 12867 PBTD 10710' TOP31/2" WHIPSTOCK PRUDHOE BAY INVfT WELL: 18-14( PERMtT No: F2081320 API No: 50-029-21614-U3 8) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL l3P Exploration fAlaskal 18-14BL1 -change of completion plan Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 02, 2008 11:34 AM To: 'McLaughlin, Sean M' Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor; Davies, Stephen F {DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-146L1 -change of completion plan Sean, Thanks for the information. You are correct that this newly drilled well segment will become 18-14C. I have spoken to my colleagues and unfortunately it will be necessary to submit a new permit application. This is necessary due to the data system we employ. It is not possible to just "over write" information. It will also be necessary to submit a 407 abandoning the lost portion of 18-146. It is not necessary to halt operations. The new application should be submitted as soon as possible. Please include a discussion of what has happened to require the new permit. There should also be a discussion regarding the reserves that will no longer be accessible due to the plugging of 18-14B. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.Mclaughlin@bp.com] Sent: Thursday, October 02, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; NSU, ADW Drlg Nordic i Supervisor Subject: 18-14BL1 -change of completion plan Tom, Nordic 1 is currently drilling 18-14BL1. This lateral was planned to be completed with a slotted liner. Unfortunately last night the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent wetl bore. Our planned 1$-146L1 would then become 18-14C. Would this require a change to the current permit (208-132) or a new permit? Regards, Sean «18-14BL1.jpg» «18-14C.jpg>' Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 10/3/2008 TR EE - 7-1116' F AIG WELLHEAD- FLAG ACTUATOR - 9AKER C I4! . EL B1 - 17.7' 6F.ELEt~- I~ F - ___ _.. ISUQ Ill~c A Y g1e - 91 ~ 11865 Daum IIID- 9159' Daum 1V D - SSm' SS IivP OF 5-11Z" 51='AB LNER I ~~ ~, ~ L ~ ~ETY NOTES: ORIGINAL5IVELLBORE NOT PrOpOSBd CTD Sidetracl; SHOV~NONDl4GRAM. a-1~" cHROMETBG. X13' 3-1r2'CAll1C0 TRIIE~ETRSSS~l,ID-212 LOCKEDOP B+I (4Z ~!8 ~q 8 ) GAS LFTlaP,NDRELS (din irniu rri ID = 2.750" 90136' 3-112" HES ~ NIPPLE LNR, 15.6N, L~ BTC, ? dpr, D - t9S0' 8505 715 CSG, 29.7iP, LSO, ID- 6.875 $?IXI' P ERFO RATD N SUTA~.IR RY Rff LOG: SPERRY~UN I1wIUD1GRON 03AtA1 ANGLEATTOPPERF: 88~ 1088Q Nab : R~ei~e r b PradY ctG r D A ib r 1lstarka Ipe rt data SSE SPF INTERVAL Op1+S~ DATE 2' 6 10880- 11610 O 03AIAi 2' 6 11860- 12190 O 03AIA1 TBG,9,3ip, 1S~R, X087 6p1,ID-2.99d' 81 ~~ •112' LNR,17i7, NT~O NSCC,.0232 Dpf.ID- 1367' 10312' 3-i f2 LNR,92M, L~ BT M, ID87 Gpt, ID- 2992' 122691 ST SID T~! D DEV TYPE V L51 LlC H PD RT DATE 3 320 3210 1 KBG2~ DRAY NT 0 06121rQ7 2 5751 9606 ~ KBG2~9 DIaY NT 0 09P18r01 1 8322 7910 39 141G2~ DLfY NT 0 0311tA1 ' B W3 LNR 11EB AG KSL11, ID - 5.750' X 5-112' B kR 2}CP LTP, D - t9 ~~~vc,n•CIPfIfYf`If4Y:R n- ~SOg e143 C-2 TIEaAC~csL~r.lo-? $517' 7~1$ ?C 5-112' B 143 H P W3, D -1,812' r ' 5-1!'2 HLAG LNR HGR, ID- 1.938' ~' 3-112 H E5 ~ NIP, D - 2 X813' 8062' 6-11I X 3-112' 9 W3 S~ PERIU P W3, D -. ' 3-112 H~ X NIP, D -2813' ~~[~ 3-112' HES~N NP,ID-2.750' 811$' 3-112 W LBG, ID- 2.992 9tL13' S-112' 8148 LNR TOP Tl®AC1{ ID- 1.2a' ~1~' 5-112 ~ 3-112' B 143 23CP LTP, D - 3.110' IIILLOUTWNDOW [18-146)966$'-9581' 'II~IJ HIOP 3 i:'2' U1~HIP'TOCk. •11~~1~ 2 3.1; lD P O F LINER LNR, 1.777,L-5i].STL,01]0.~876PF, D-1.9aS H 1~8 F 12201' ~ DATE R BJ B Y CO ~IIIfENT'S QATE REV BY COMMENTS 11~M8186 ORIGINAL cOM PLEI'IDN 09V21J01 KDCJTLH TR9S;V CO RR~TDN 4~f~5~93 RIG S IOETRAOK (18-ibA] 0512il07 14SB1PJC GLV CA Od~i1193 OS 118 ~p d 04VrK4 K GTD(9.7r8" SLTOLNR) RIG S ICETRACK (18 -1dA) 06125/07 03A8108 ?1PJC SWCIIUC TBG1LNRCORR~'fONS TR~V LOC 14~ O PEN ~2f281L 03116A ~ J 8 M1KA G L51 CA 05130~D6 DAVIPJG TR5~U OD RRBCTD N X2121 A8~ 04118x0 ~ GJ91R P G LL' CA PRUDHDEBAY UNIT W a L: 18-1 IB PERM1TNa: ~03063J A P I Na: 50-029-21614.02 S~ 19,T11 N, R15~ 1350' FSL & 1613' FEL 6R Bplara~an (AIaY haJ TREE- 7-1f16' FI.IG UUELLHEAD- ACTLW.lOR- FIaG ~ BAICERC KB. EL Bif - t7.7' v_ k0 P - t500` Illl~c Angle- 9th 11855 oai~m IUD- 9159' Dablm lV D - ~ SSm`'SS ~t -~I ~' ~ L'1 Propused CTD Sid~traGk 2213' 3-1f2' Cp,1.lOD TRAA-tETRSSSil, ID- 212' LO~KEDOP Bil (4Z ~8 ~ 8 J GAS LFTIAP,NDRELS ST ND TVD DBd TYPE ~1LV LICH PORT DATE 3 3210 31210 1 I~G2~9 DMY NT o or~12t,~r 2 5751 5605 ~ kHG2~9 D~fY NT 0 09P18At 1 8322 7510 ~ I~G2~9 DRAY 11T D 03f11At P OF 5-112" SGAB LNER ~~ ~~]' Nin imiu m ID = 2.7a~0" 90816' 3-"1!~"HES }~ NIPPLE SCAB LNR, 15 Sap, L~0 ATG, ? bpt, D - 1950' $509' 7 5~ G;9G, 29.7ip, Lam, ID- 6.875' 8700r P ERFO R4TD N SUMAW, RY REF LOG: SPERRY~UN I.UUDFGRON g3A1A1 ANGLEATTOPPERF: 88 ~ 1088Q Nate : Rene r b Prods Ctb ~ D 91b r i fabarka Ipe rf daia Se E S PF INTERJA L Op 1,6~ a4TE 2' 6 10880- 11610 O 03AiAt 2' 6 11860- 12190 0 03AtAt ,9.3N, 1S {R, D057 bpf,ID-2.992' 9118' 5-1fI LNR,17fp, NT-80 NSGC, .023? bpf, ID- 1.767' 10312' 3-iFI LNR,92M, L-ID BT-IA, IDSt bpT, ID-2992' 1769' ' B Wi LNR TI®A4C KSLV, ID - 5.758 ~JS X 5-1 f2' 8 Wi 2~€P LTP, D - t9 ~ sr v ~i n• FI F§f I f1P'If Fr: R n - $SQ~ AI4i G-2 TIEBAGKSL1t, ID-? 8517' 715 ?C 5-1 f2' B 191 H P 141, D - 1,812' ~' ~ 5-if2 HI.IC LNR HGR, ID- 1.9138' 1' ~3-1f2' Ham' X NIP, D -2$13' ' S-1 fI 7C 3-1 F1' 9141 S~ PER~1 PMQi, D -. ' 3-1f2' H E' X NIP, D- 2 X813' 9108 3-1 f2' HESXN NP,ID-2.750' 911$' 3-if2' INLBG, ID- 2.992' 9413' S-if2' A KR L NR l0 P TI®AG I{ ID- t.2t' `~~ 8419' S-if2' 7C 3-1 fl' B IQ~ ZXP LTP, D - 3.t 1D' IaL LO UT W NDODU (18-14BJ 9668' -9581' 10'rr5 HlOP 3 i,`~ UUHIP~Gk: •ifl~ft~ 23,f-' IOPOF LINER ~2 LNR, 1.7~, L-t`Q ST'L, 0J1~8T B P F, D-1.~5' F 12201' I G4TE R E+1 A Y GO ~INENTS DATE RE'J BY GO LI~IENiS PRU DHD E BAY U NR 11 Iq8 IB 9 ORIG INA L COM RL ETIdN 09V2 1101 ICDGITLH TRSS65! GO RR H:TD N W B. L: 1 F~1 tB 02 ~3 fr 3 RIG S IOETRACK (18 -ibA ~ 06121107 14SB1PJG G LV GA PERAIR Na: X030530 4~141fJ3 4S ~iS ~p b Da51rKA K CTD(2~18" SLTDL NR~ RIGS 10ETRACK (18 -idlk) 062Sf07 03A&DS ?f PJG SUUCING T9G f LNR CO RR~'TONS TR9!~SV LOG I~ O PEN ~2128f0 6~ APINa: 50-029-2161 t-02 S~ 19 , T11 N, R15 ~ 1350' PSL & 1613' F EL 03f16~0 t J B AKA G LV GA OS~4l1~06 Q41t1PJC TRSGif CO RRBGTD N X2,21 ~ 09f18At GJBfRP GLV GA EF Etplarailan [Als~ha) SARAH PAL/N, GOVERNOR CUZ~SER~~'IO)~ ~ ~~+ It7u04~ 333 W. 7th AVENUE, SUITE 100 -7 AiitAii l.~•••~~•~~~u11~~•iiiiii----777 ~l~ ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-14BL1 BP Exploration Alaska Inc. Permit No: 208-132 Surface Location: 4351' FSL, 4609' FEL, SEC. 19, T 11 N, R 15E, UM Bottomhole Location: 200' FSL, 2239' FEL, SEC. 19, T11N, R15E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development 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 iri 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) 659-3607 (pager). cerely, 'el T. Seamount, Jr. -~...~ Chair DATED this `5 day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ti ~ ~• STATE OF ALASKA v .~ ALASKr, IL AND GAS CONSERVATION COMMI N < <! `' s ~-,, . PERMIT TO DRILL ~ ~~`' 20 AAC 25.005 ~~17r"" t ~ ~~= '`~ ` " 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 rhell isproposed for: ^ 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 18-146L1 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13100' TVD 8723'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028321 Pool FEL, SEC. 19, T11 N, R15E, UM 4351 FSL, 4609 Top of Productive Horizon: 3644' FEL, SEC. 19, T11N, R15E, UM 884' FSL 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2008 , Total Depth: 200' FSL, 2239' FEL, SEC. 19, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-692104 y-5960948 Zone-ASP4 10. KB Elevation (Height above GL): 46.4 feet 15. Distance to Nearest Well Within Pool: 400' 16. Deviated Wells: Kickoff Depth: 10700 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3324 Surface: 2444 18. Casin Pro ram: S e ificatio n To - Se in D th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 2390' 10710' 8698'ss 13100' 8723'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12270 Total Depth TVD (ft): 8746 Plugs (measured): None Effective Depth MD (ft): 12201 Effective Depth TVD (ft): 8748 Junk (measured): None asing Length ize ement Volume MD D Conductor /Structural 115' 16" 1540 # Poleset 115' 115' Surface 3452' 10-3/4" 2200 sx Coldset III 400 sx CS II 3452' 3452' Intermediate 8700' 7-5/8" 300 sx Class'G' 8700' 7806' Production Liner 6038' 5-1/2" 131 sx Class 'G' 286 sx'G' 226 sx'G' 3530' - 9568' 3530' - 8443' Liner 2856' 3-1/2" 220 sx Class 'G' 9413' - 12269' 8338' - 8746' Perforation Depth MD (ft): 10880' - 12190' Perforation Depth TVD (ft): 8750' - 8748' 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 that the foregoing is true and correct. Contact Sean Mctaughlin, 564-4387 Printed Name can McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature '~ Phone s6~ -L~3 S7 Date 17 OE Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: API Number: 50-029-21614-60-00 Permit Approval See cover letter for Date: • / ~ 'CU other re uirements Conditions of Approvah tf box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~,^.f 3~~®~S` ~~~~ ~ Samples Req'd: ^ Yes IJ No Mud Log Req'd: Yes 1t0 No v ~ HZS Measures: ~,es ^ No Directional Survey Req'd: Yes ^ No Other: S ~ ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ j ~~ ~ ~ auoma in uupncai~ t-; "u 3 by BPXA Prudhoe Bay DS 18-14B~1 CTD Sidetrack August 12, 2008 CTD Sidetrack Summary Pre-Rig Work: 1. MIT-IA 2. Run caliper as deep as possible 3. Dummy whipstock drift to 10800'. 4. Bleed. production flow lines and GL lines down to zero and blind flange. 5. Set BPV 6. PT MV, SV, WV. 7. Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on November 01, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. Pull BPV. 3. Set 3-1 /2" retrievable whipstock with top at 10700'. 4. Mill 2.75" window through 3'/z" liner. 5. Drill turn section with 2.70" x 3.0" bicenter bit to 11630'. 6. Drill lateral section to 13,100'. 7. Run slotted 2-3/8" L-80 liner string (include CNL log). 8. Pull 3-1/2" whipstock 9. FP well to 2000' with diesel. 10. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 11. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.0" (bi-center bits used) Casing Program: fully cemented liner • 2-3/8", Slotted L-80 4.70# STL 10,710' - 13,100' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90 deg at 11,020'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 25,000 ft. • Distance to nearest well within pool - 400 ft. (18-24AL2) Anti-Collision • 18-03A ctr-ctr distance 119'; The well is P&A'd Logging • MW D directional, Gamma Ray, Resistivity will be run over all of the open hole section. • Cased hole MCNL will be run. Hazards • The maximum recorded H2S level on DS 18 was 20 ppm on well 18-146. • No planned fault crossings Reservoir Pressure • The reservoir pressure on 15-18 is expected to be 3,324 psi at 8,800' TVDSS. (7.3 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,444 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble F = 7-1 /16" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = 94 @ 11865' i Datum MD = 9159' Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" TOP OF 5-1/2"" SCAB LNER ~ 3530' Minimum ID = 2.750" @ 9086' 3-1/2" HES X NIPPLE 5-1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD / GR ON 03/01!04 ANGLE AT TOP PERF: 88 @ 10880' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10880 - 11610 O 03/04/04 2" 6 11860 - 12190 O 03/04!04 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" ~ 9118' TOP OF EZSV 9596' ~ ~ 5-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ID = 4.767" i ~ ~ ~ ~ ~ ~ ~ ~ r 3-1/2" LNR 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" 12269' PBTD I I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/08/88 ORIGINAL COMPLETION 09/24/04 KDGTLH TRSSSV CORRECTION WELL: 18-146 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSB/PJC GLV GO PERMIT No: `2030630 04/01/95 CTD (2-7/8" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS API No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02!28/0 8) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL 03/16/04 JBM/KAK GLV GO 05!30/08 DAV/PJC TRSSV CORRECTION(02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) 18-14B ~ ~'~~ ~ ~M TB~ 2213' 3-1/2" CAMCO TRM-4ETRSSSV, ID = 2.812" ® LOCKED OPEN (02/28/08) GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/07 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/04 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/04 3530' - -~ 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1/2" BKR ZXP LTP, ID = 4.910" 3543' 7-518" X 5-112" FLIX LOCK HGR, ID = 4.820 8509' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-1/2" BKR H PKR ID = 4.812" 8522' 5-1/2" HMC LNR HGR ID = 4.938" 9041' H 3-1 /2" HES X NIP, ID = 2.813" 9062' ~ 5-1/2" X 3-1/2" BKR S-3 P~2N1 PKR, ID = 2.770" 9086' I--I3-1/2" HES X NIP, ID = 2.813" 9106' H 3-1 /2" HES XN NIP, ID = 2.750" 9118' 3-1 /2" WLEG, ID = 2.992" 9413' 5-1 /2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' 5-1/2" X 3-1/2" BKR ZXP LTP, ID = 3.410" MILLOUT WINDOW (18-146) 9568' - 9581' I TREE = 7-1116" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = 94 @ 11865' Datum MD = 9159' Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/07 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/04 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/04 TOP OF 5-1/2"" SCAB LNER 3530' 3530' 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1 /2" BKR ZXP LTP, ID = 4.910" $543' 7-5/8" X 5-1/2" FLEX LOCK HGR, ID = 4.820 Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE $50J' BKR G2 TIEBACK SLV, ID =? ID = 4.950" 8509' 8517' 7-5/8" X 5-1/2" BKR H PKR, ID = 4.812" 8522' 5-1/2" HMC LNR HGR ID = 4.938" 7-5/8" CSG, 29.7#, L-80, ID = 6.875" PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD! GR ON 03/01/04 ANGLE AT TOP PERF: 88 @ 10880' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10880 - 11610 O 03!04/04 2" 6 11860 - 12190 O 03!04/04 3-1 /2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" TOP OFQSV 9596' ~ •' Y .' 5-1 /2" LNR 17#, NT-80 NSCC, .0232 bpf, ~ = 4.767" 10312' 3-1 /2" LNR, 9.2/r:, L-80 ~T-M, .0087 bpf, iD = 2.992^ 12269' 3-1/2" HES X NIP, ID = 2.813" 15-1/2" X 3-1/2" BKR S-3 PERM PKR, ID = 2.770" I 13-1/2" HES X NIP, ID = 2.813" I 9106' -18.1/2" HES XN Nom, ~= 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413' S-1l2" BKR LNR TOP TIEBACK, ~ = 4.24" 9419' 8-1/2" X 3-1 /2" BKR ZXP LTP, ID = 3.410" M~LOIfT WINDOW (18-146) 9568' -9581' 10700' ~ TOP 3 1 /2" WHIPSTOCK 10710' 2 3/8" TOP OF LINER LNR, 4.7#, L-80 STL, 0.003876PF, ID=1.995" I~ 13100' 12201' I-I ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/08/86 ORIGINAL COMPLETION 09/24/04 KDC/TLH TRSSSV CORRECTION WELL: 18-146 02/25/95 RIG SIDETRACK (18-14Aj 06!24/07 KSB/PJC GLV C/0 PERMff No: ~`L030630 04/01/95 CTD (2-718" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS API No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02/28/0 8) SEC 19, T11 N, R15E, 4350' FSL 8 4613' FEL 03/16/04 JBM/KAK GLV GO 05/30/08 DAVlPJC TRSSV CORRECTION (02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) ~ 18 -14 B L 1 S NOTES: ORIGINAL W ELLBORE NOT Proposed CTD Sidetrack ON DIAGRAM. 3-1/2" CHROME TBG. 2213' ~3-1/2" CAMCO TRM-4ETRSSSV, ID = 2.812" LOCKED OPEN (02/28/08) GAS LIFT MANDRELS I 9118' I by ~' BP Alaska Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 8/4!2008 Time: 15:21:55 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: 18-14, True North Site: PB DS 18 Vertical (TVD) Reference: 18-146: 46.4 Well: 18-14 Section~VS)Reference: Well (O.OON,O.OOE,140.OOAzi) Wellpath: Plan 3, 18-14BL1 Survey Calculation Method: Minimum Curvature Db: Oracle i Field: Prudhoe Bay North Slope UNITED STATES 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: bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-14 Slot Name: 14 18-14 Well Position: +N/-S 1720.96 ft Northing: 5960947.74 ft Latitude: 70 17 52.178 N +E/-W 560.77 ft Easting : 692100.14 ft Longitude: 148 26 39.208 W Position Uncertainty:. 0.00 ft Wellpath: Plan 3, 18-14BL1 Drilled From: 18-146 500292161460 Tie-on Depth: 10693.19 ft Current Datum: 18-146: Height 46.40 ft Above System Datum: Mean Sea Level Magnetic Data: 8/4/2008 Declination: 23.23 deg Field Strength: 57687 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 140.00 Plan: Plan 3 Date Composed: 8/4/2008 copy Sean's Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- La titude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Mi n Sec Dip. Dir. n ft ft ft n 18-14BL1 Polygon 46.40 3750.48 207.08 5957204.00 692403.00 70 17 15.292 N 148 26 33.175 W -Polygon 1 46.40 -3750.48 207.08 5957204.00 692403.00 70 17 15.292 N 148 26 33.175 W -Polygon 2 46.40 -3873.59 640.10 5957092.00 692839.00 70 17 14.081 N 148 26 20.559 W -Polygon 3 46.40 -4045.38 1137.90 5956933.00 693341.00 70 17 12.391 N 148 26 6.056 W -Polygon 4 46.40 -4365.12 2531.26 5956649.00 694742.00 70 17 9.243 N 148 25 25.465 W -Polygon 5 46.40 -4024.23 2619.01 5956992.00 694821.00 70 17 12.595 N 148 25 22.905 W -Polygon 6 46.40 -3630.78 1472.62 5957356.00 693665.00 70 17 16.468 N 148 25 56.302 W -Polygon 7 46.40 -3207.02 393.04 5957752.00 692575.00 70 17 20.637 N 148 26 27.756 W 18-14BL1 Target 1 8753.40 -3794.07 699.15 5957173.00 692896.00 70 17 14.863 N 148 26 18.838 W 18-146L1 Target 2 8763.40 -4015.04 1789.92 5956980.00 693992.00 70 17 12.688 N 148 25 47.060 W 18-14BL1 Target 3 8769.40 -4147.55 2394.77 5956863.00 694600.00 70 17 11.383 N 148 25 29.439 W Annotation - -- - ,- nID Tvn - n n 10693.19 8743.77 TIP 10700.00 8744.04 KOP 10720.00 8744.81 End of 9 deg / 100 ft DLS 11020.00 8751.80 4 11330.00 8753.41 End of 31.5 deg / 100 ft DLS 11630.00 8756.75 6 11980.00 8760.20 7 12240.00 8762.18 8 by ~ BP Alaska Baker Hu hes INTEQ Planiun Re ort g g P INTEQ Company: BP Amoco Date: 8/4/2008 Time: 15 :21:55 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-14, T rue North Site: PB DS 18 Vertical ('I'VD) Reference: 18-14 6: 46.4 Well: 1 8-14 Section (VS) Reference: Well ( O.OON,O. OOE,140.OOAzi) Wellpath: Plan 3, 18-146L1 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 12470.00 8763.69 9 12770.00 8766.19 10 13100.00 8769.25 TD Plan Section Information MD Incl - Azim __- -- TVD - - - +N/-S - +E/-W DLS Build Turn TFO _ Target ___ _ T__l ft deg deg ft ft ft deg/100ft deg/100ft deg/i00ft deg 10693.19 87.72 281.61 8743.77 -3437.14 740.02 0.00 0.00 0.00 0.00 10700.00 87.79 281.68 8744.04 -3435.77 733.36 1.45 1.03 1.03 44.98 10720.00 87.79 279.88 8744.81 -3432.03 713.73 9.00 0.01 -9.01 270.00 11020.00 90.17 185.38 8751.80 -3594.20 501.56 31.50 0.79 -31.50 270.00 11330.00 89.38 87.73 8753.41 -3793.01 689.84 31.50 -0.26 -31.50 269.40 11630.00 89.38 123.74 8756.75 -3873.03 973.85 12.00 0.00 12.00 90.20 11980.00 89.54 81.73 8760.20 -3948.46 1307.63 12.00 0.05 -12.00 270.00 12240.00 89.61 112.93 8762.18 -3981.24 1562.33 12.00 0.03 12.00 90.00 12470.00 89.65 85.33 8763.69 -4017.40 1787.21 12.00 0.02 -12.00 270.00 12770.00 89.42 121.33 8766.19 -4085.46 2074.34 12.00 -0.08 12.00 90.50 13100.00 89.56 81.73 8769.25 -4150.13 2391.26 12.00 0.04 -12.00 270.00 Survey MD Incl Azim SS TVD N!S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100 ft ft deg 10693.19 87.72 281.61 8697.37 -3437.14 740.02 5957530.84 692927.73 0.00 3108.68 0.00 MW D 10700.00 87.79 281.68 8697.64 -3435.77 733.36 5957532.04 692921.04 1.45 3103.35 44.98 MW D 10720.00 87.79 279.88 8698.41 -3432.03 713.73 5957535.27 692901.32 9.00 3087.86 270.00 MW D 10730.00 87.79 276.73 8698.79 -3430.59 703.84 5957536.46 692891.40 31.50 3080.40 270.00 MW D 10740.00 87.80 273.57 8699.18 -3429.69 693.89 5957537.10 692881.43 31.50 3073.32 270.12 MW D 10750.00 87.82 270.42 8699.56 -3429.34 683.90 5957537.20 692871.44 31.50 3066.63 270.24 MW D 10760.00 87.84 267.27 8699.94 -3429.54 673.91 5957536.74 692861.46 31.50 3060.37 270.36 MW D 10770.00 87.87 264.12 8700.31 -3430.30 663.95 5957535.74 692851.52 31.50 3054.54 270.48 MW D 10780.00 87.91 260.97 8700.68 -3431.59 654.04 5957534.19 692841.64 31.50 3049.16 270.60 MW D 10790.00 87.95 257.81 8701.04 -3433.43 644.22 5957532.10 692831.87 31.50 3044.26 270.72 MW D 10800.00 88.00 254.66 8701.39 -3435.81 634.52 5957529.47 692822.23 31.50 3039.84 270.83 MW D 10810.00 88.06 251.51 8701.74 -3438.72 624.96 5957526.32 692812.75 31.50 3035.92 270.94 MW D 10820.00 88.12 248.36 8702.07 -3442.14 615.57 5957522.65 692803.46 31.50 3032.52 271.05 MW D 10830.00 88.18 245.21 8702.39 -3446.08 606.38 5957518.48 692794.37 31.50 3029.63 271.15 MW D 10840.00 88.25 242.06 8702.70 -3450.52 597.43 5957513.82 692785.54 31.50 3027.27 271.26 MW D 10850.00 88.33 238.91 8703.00 -3455.45 588.73 5957508.67 692776.97 31.50 3025.46 271.35 MW D 10860.00 88.41 235.76 8703.29 -3460.84 580.32 5957503.06 692768.70 31.50 3024.18 271.45 MW D 10870.00 88.50 232.61 8703.56 -3466.69 572.21 5957497.01 692760.74 31.50 3023.45 271.54 MW D 10880.00 88.59 229.46 8703.81 -3472.98 564.44 5957490.53 692753.14 31.50 3023.27 271.62 MW D 10890.00 88.69 226.31 8704.05 -3479.68 557.03 5957483.64 692745.90 31.50 3023.64 271.70 MW D 10900.00 88.79 223.16 8704.27 -3486.78 549.99 5957476.36 692739.05 31.50 3024.56 271.78 MW D 10910.00 88.89 220.01 8704.47 -3494.26 543.36 5957468.71 692732.60 31.50 3026.02 271.85 MW D 10920.00 89.00 216.86 8704.65 -3502.09 537.14 5957460.73 692726.59 31.50 3028.03 271.91 MW D 10930.00 89.11 213.71 8704.82 -3510.25 531.37 5957452.42 692721.03 31.50 3030.56 271.97 MW D 10940.00 89.22 210.56 8704.97 -3518.72 526.05 5957443.82 692715.93 31.50 3033.63 272.02 MW D 10950.00 89.33 207.42 8705.09 -3527.46 521.20 5957434.96 692711.31 31.50- 3037.22 272.07 MW D 10960.00 89.45 204.27 8705.20 -3536.46 516.85 5957425.85 692707.18 31.50 3041.31 272.11 MW D 10970.00 89.57 201.12 8705.28 -3545.68 512.99 5957416.53 692703.56 31.50 3045.89 272.14 MW D 10980.00 89.69 197.97 8705.35 -3555.11 509.64 5957407.03 692700.46 31.50 3050.96 272.17 MW D 10990.00 89.81 194.83 8705.39 -3564.70 506.82 5957397.37 692697.88 31.50 3056.49 272.19 MW D 11000.00 89.93 191.68 8705.41 -3574.43 504.53 5957387.58 692695.84 31.50 3062.48 272.20 MW D 11010.00 90.05 188.53 8705.42 -3584.27 502.77 5957377.70 692694.34 31.50 3068.89 272.21 MW D 11020.00 90.17 185.38 8705.40 -3594.20 501.56 5957367.74 692693.38 31.50 3075.71 272.21 MW D 11030.00 90.14 182.23 8705.37 -3604.18 500.90 5957357.75 692692.97 31.50 3082.93 269.40 MW D by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company BP Amoco Date: 8/4/2008 Time. 15:21:55 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Refereuce: Well: 18-14, True North ~ Site: PB DS 18 Vertical (TVD) Reference: 18-146: 46.4 i 'i Well: 18- 14 Section (VS) Reference: Well (O.OON,O.OOE,140.OOAzi) Wellpath: Pla n 3, 18-14 6L1 Survey Calculation Method: Minimum Curvatu re Db: Or acle Survev ` MD Incl Azim -- SS TVD _ _ N/S - ENV MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg(t00ft ft deg 11040.00 90.11 179.08 8705.35 -3614.17 500.78 5957347.76 692693.11 31.50 3090.52 269.39 MW D 11050.00 90.07 175.93 8705.33 -3624.16 501.22 5957337.78 692693.80 31.50 3098.45 269.38 MW D 11060.00 90.04 172.78 8705.32 -3634.11 502.20 5957327.86 692695.04 31.50 3106.70 269.38 MW D 11070.00 90.00 169.63 8705.32 -3643.99 503.73 5957318.02 692696.82 31.50 3115.25 269.38 MW D 11080.00 89.97 166.48 8705.32 -3653.78 505.80 5957308.30 692699.14 31.50 3124.08 269.38 MW D 11090.00 89.94 163.33 8705.33 -3663.43 508.40 5957298.71 692701.99 31.50 3133.15 269.38 MW D 11100.00 89.90 160.18 8705.34 -3672.93 511.53 5957289.30 692705.36 31.50 3142.43 269.38 MW 0 11110.00 89.87 157.03 8705.36 -3682.24 515.18 5957280.09 692709.24 31.50 3151.91 269.38 MW D 11120.00 89.83 153.88 8705.39 -3691.33 519.33 5957271.10 692713.63 31.50 3161.55 269.39 MW D 11130.00 89.80 150.73 8705.42 -3700.19 523.98 5957262.37 692718.50 31.50 3171.31 269.40 MW D 11140.00 89.77 147.58 8705.46 -3708.77 529.11 5957253.92 692723.84 31.50 3181.19 269.41 MW D 11150.00 89.74 144.43 8705.50 -3717.06 534.70 5957245.78 692729.64 31.50 3191.13 269.42 MW D 11160.00 89.71 141.28 8705.55 -3725.03 540.73 5957237.96 692735.88 31.50 3201.12 269.43 MW D 11170.00 89.68 138.13 8705.60 -3732.66 547.20 5957230.51 692742.54 31.50 3211.11 269.45 MW D 11180.00 89.65 134.98 8705.66 -3739.92 554.07 5957223.42 692749.59 31.50 3221.09 269.47 MW D 11190.00 89.62 131.83 8705.73 -3746.79 561.34 5957216.74 692757.03 31.50 3231.03 269.48 MW D 11200.00 89.59 128.68 8705.80 -3753.25 568.97 5957210.48 692764.82 31.50 3240.88 269.50 MW D 11210.00 89.57 125.53 8705.87 -3759.28 576.94 5957204.65 692772.95 31.50 3250.63 269.53 MW D 11220.00 89.54 122.38 8705.95 -3764.87 585.23 5957199.28 692781.38 31.50 3260.24 269.55 MW D 11230.00 89.52 119.23 8706.03 -3769.99 593.82 5957194.38 692790.09 31.50 3269.68 269.57 MW D 11240.00 89.50 116.08 8706.11 -3774.63 602.68 5957189.97 692799.07 31.50 3278.93 269.60 MW D 11250.00 89.48 112.93 8706.20 -3778.78 611.77 5957186.05 692808.27 31.50 3287.95 269.63 MW D 11260.00 89.46 109.78 8706.29 -3782.42 621.09 5957182.65 692817.67 31.50 3296.73 269.65 MW D 11270.00 89.45 106.63 8706.39 -3785.54 630.58 5957179.77 692827.24 31.50 3305.23 269.68 MW D 11280.00 89.43 103.48 8706.49 -3788.14 640.24 5957177.42 692836.96 31.50 3313.42 269.71 MW D 11290.00 89.42 100.33 8706.59 -3790.21 650.02 5957175.61 692846.79 31.50 3321.29 269.74 MW D 11300.00 89.41 97.18 8706.69 -3791.73 659.90 5957174.34 692856.71 31.50 3328.81 269.78 MW D 11310.00 89.40 94.03 8706.80 -3792.70 669.85 5957173.62 692866.68 31.50 3335.95 269.81 MW D 11320.00 89.39 90.88 8706.90 -3793.13 679.84 5957173.44 692876.67 31.50 3342.70 269.84 MW D 11330.00 89.38 87.73 8707.01 -3793.01 689.84 5957173.82 692886.67 31.50 3349.04 269.87 MW D 11350.00 89.37 90.13 8707.23 -3792.64 709.83 5957174.70 692906.64 12.00 3361.60 90.20 MW D 11375.00 89.37 93.13 8707.50 -3793.35 734.82 5957174.63 692931.64 12.00 3378.21 90.17 MW D 11400.00 89.36 96.13 8707.78 -3795.37 759.73 5957173.25 692956.59 12.00 3395.77 90.14 MW D 11425.00 89.35 99.13 8708.06 -3798.69 784.51 5957170.56 692981.44 12.00 3414.24 90.11 MW D 11450.00 89.35 102.13 8708.34 -3803.31 809.07 5957166.58 693006.12 12.00 3433.56 90.07 MW D 11475.00 89.35 105.13 8708.63 -3809.20 833.36 5957161.31 693030.55 12.00 3453.69 90.04 MW D 11500.00 89.35 108.13 8708.91 -3816.35 857.31 5957154.77 693054.67 12.00 3474.57 90.01 MW D 11525.00 89.35 111.13 8709.19 -3824.75 880.86 5957146.98 693078.42 12.00 3496.13 89.97 MW D 11550.00 89.36 114.14 8709.47 -3834.37 903.93 5957137.95 693101.73 12.00 3518.33 89.94 MW D 11575.00 89.36 117.14 8709.75 -3845.19 926.46 5957127.71 693124.53 12.00 3541.10 89.90 MW D 11600.00 89.37 120.14 8710.03 -3857.16 948.40 5957116.30 693146.77 12.00 3564.38 89.87 MW D 11625.00 89.38 123.14 8710.30 -3870.28 969.68 5957103.74 693168.37 12.00 3588.10 89.84 MW D 11630.00 89.38 123.74 8710.35 -3873.03 973.85 5957101.09 693172.61 12.00 3592.89 89.81 MW D 11650.00 89.38 121.34 8710.57 -3883.79 990.71 5957090.77 693189.74 12.00 3611.97 270.00 MW D 11675.00 89.39 118.34 8710.84 -3896.22 1012.39 5957078.90 693211.73 12.00 3635.43 270.03 MW D 11700.00 89.39 115.34 8711.10 -3907.50 1034.70 5957068.19 693234.32 12.00 3658.41 270.06 MW D 11725.00 89.39 112.33 8711.37 -3917.61 1057.56 5957058.67 693257.43 12.00 3680.85 270.09 MW D 11750.00 89.40 109.33 8711.63 -3926.50 1080.92 5957050.38 693281.01 12.00 3702.67 270.12 MW D 11775.00 89.41 106.33 8711.89 -3934.15 1104.72 5957043.34 693304.99 12.00 3723.83 270.15 MW D 11800.00 89.42 103.33 8712.15 -3940.55 1128.88 5957037.56 693329.31 12.00 3744.27 270.18 MW D 11825.00 89.43 100.33 8712.40 -3945.68 1153.35 5957033.06 693353.90 12.00 3763.92 270.22 MW D 11850.00 89.45 97.33 8712.64 -3949.52 1178.05 5957029.86 693378.68 12.00 3782.74 270.25 MW D by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco - --- - Date: __ 8/4/2008 Time: 15:21:55 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-14, True North Site: PB DS 18 Vertical (TVD) Reference: 18-14B: 46.4 Well: 18- 14 Section (VS) Reference: Well (O.OON,O.OOE,140.OOAzi) Wellpath: Plan 3, 18-14 BL1 Survey Calculation Method: Minimum Curvatu re Db: Oracle Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11875.00 89.46 94.33 8712.88 -3952.06 1202.91 5957027.95 693403.61 12.00 3800.67 270.27 MW D 11900.00 89.48 91.33 8713.11 -3953.29 1227.88 5957027.35 693428.59 12.00 3817.66 270.30 MW D 11925.00 89.50 88.33 8713.33 -3953.22 1252.87 5957028.07 693453.58 12.00 3833.67 270.33 MW D 11950.00 89.52 85.33 8713.55 -3951.84 1277.83 5957030.08 693478.49 12.00 3848.66 270.36 MW D 11975.00 89.54 82.33 8713.76 -3949.15 1302.68 5957033.40 693503.26 12.00 3862.58 270.38 MW D 11980.00 89.54 81.73 8713.80 -3948.46 1307.63 5957034.22 693508.20 12.00 3865.23 270.41 MW D 12000.00 89.54 84.13 8713.96 -3946.00 1327.48 5957037.19 693527.97 12.00 3876.10 90.00 MW D 12025.00 89.54 87.13 8714.16 -3944.10 1352.40 5957039.73 693552.84 12.00 3890.66 89.98 MW D 12050.00 89.55 90.13 8714.35 -3943.50 1377.39 5957040.96 693577.80 12.00 3906.27 89.96 MW D 12075.00 89.55 93.13 8714.55 -3944.22 1402.38 5957040.89 693602.80 12.00 3922.88 89.93 MW D 12100.00 89.56 96.13 8714.75 -3946.24 1427.29 5957039.51 693627.75 12.00 3940.44 89.91 MW D 12125.00 89.56 99.13 8714.94 -3949.56 1452.07 5957036.82 693652.60 12.00 3958.91 89.89 MW D 12150.00 89.57 102.13 8715.13 -3954.17 1476.64 5957032.84 693677.28 12.00 3978.23 89.86 MW D 12175.00 89.58 105.13 8715.31 -3960.06 1500.93 5957027.57 693701.71 12.00 3998.36 89.84 MW D 12200.00 89.59 108.13 8715.50 -3967.22 1524.88 5957021.03 693725.84 12.00 4019.24 89.82 MW D 12225.00 89.60 111.13 8715.67 -3975.62 1548.42 5957013.23 693749.58 12.00 4040.81 89.80 MW D 12240.00 89.61 112.93 8715.78 -3981.24 1562.33 5957007.96 693763.63 12.00 4054.05 89.77 MW D 12250.00 89.61 111.73 8715.84 -3985.04 1571.57 5957004.40 693772.97 12.00 4062.91 270.00 MW D 12275.00 89.61 108.73 8716.02 -3993.69 1595.03 5956996.36 693796.64 12.00 4084.61 270.01 MW D 12300.00 89.61 105.73 8716.19 -4001.10 1618.90 5956989.56 693820.69 12.00 4105.63 270.03 MW D 12325.00 89.61 102.73 8716.35 -4007.24 1643.13 5956984.04 693845.07 12.00 4125.91 270.05 MW D 12350.00 89.62 99.73 8716.52 -4012.11 1667.65 5956979.80 693869.70 12.00 4145.40 270.07 MW D 12375.00 89.62 96.73 8716.69 -4015.69 1692.39 5956976.85 693894.52 12.00 4164.04 270.09 MW D 12400.00 89.63 93.73 8716.85 -4017.97 1717.28 5956975.21 693919.46 12.00 4181.79 270.11 MW D 12425.00 89.64 90.73 8717.01 -4018.95 1742.26 5956974.87 693944.45 12.00 4198.59 270.13 MW D 12450.00 89.64 87.73 8717.17 -4018.61 1767.25 5956975.85 693969.43 12.00 4214.40 270.15 MW D 12470.00 89.65 85.33 8717.29 -4017.40 1787.21 5956977.56 693989.35 12.00 4226.31 270.17 MW D 12475.00 89.65 85.93 8717.32 -4017.02 1792.20 5956978.07 693994.33 12.00 4229.22 90.50 MW D 12500.00 89.62 88.93 8717.48 -4015.90 1817.17 5956979.83 694019.26 12.00 4244.42 90.50 MW D 12525.00 89.60 91.93 8717.65 -4016.09 1842.17 5956980.28 694044.25 12.00 4260.63 90.48 MW D 12550.00 89.57 94.93 8717.83 -4017.59 1867.12 5956979.42 694069.23 12.00 4277.81 90.46 MW D 12575.00 89.55 97.93 8718.02 -4020.39 1891.96 5956977.26 694094.13 12.00 4295.93 90.44 MW D 12600.00 89.53 100.93 8718.22 -4024.49 1916.62 5956973.79 694118.89 12.00 4314.91 90.41 MW D 12625.00 89.51 103.93 8718.43 -4029.87 1941.03 5956969.03 694143.42 12.00 4334.73 90.39 MW D 12650.00 89.49 106.93 8718.65 -4036.52 1965.12 5956963.00 694167.68 12.00 4355.31 90.36 MW D 12675.00 89.48 109.93 8718.88 -4044.43 1988.83 5956955.70 694191.59 12.00 4376.61 90.34 MW D 12700.00 89.46 112.93 8719.11 -4053.56 2012.10 5956947.17 694215.08 12.00 4398.56 90.31 MW D 12725.00 89.45 115.93 8719.35 -4063.90 2034.86 5956937.41 694238.09 12.00 4421.11 90.28 MW D 12750.00 89.43 118.93 8719.59 -4075.42 2057.04 5956926.47 694260.56 12.00 4444.19 90.25 MW D 12770.00 89.42 121.33 8719.79 -4085.46 2074.34 5956916.88 694278.11 12.00 4463.00 90.22 MW D 12775.00 89.42 120.73 8719.84 -4088.04 2078.62 5956914.41 694282.46 12.00 4467.73 270.00 MW D 12800.00 89.43 117.73 8720.09 -4100.24 2100.43 5956902.76 694304.57 12.00 4491.10 270.01 MW D 12825.00 89.43 114.73 8720.34 -4111.29 2122.86 5956892.29 694327.27 12.00 4513.98 270.04 MW D 12850.00 89.43 111.73 8720.59 -4121.15 2145.82 5956883.02 694350.48 12.00 4536.30 270.07 MW D 12875.00 89.44 108.73 8720.84 -4129.80 2169.28 5956874.98 694374.14 12.00 4557.99 270.10 MW D 12900.00 89.45 105.73 8721.08 -4137.20 2193.15 5956868.19 694398.20 12.00 4579.01 270.13 MW D 12925.00 89.45 102.73 8721.32 -4143.35 2217.38 5956862.66 694422.57 12.00 4599.29 270.15 MW D 12950.00 89.47 99.73 8721.55 -4148.22 2241.90 5956858.42 694447.21 12.00 4618.78 270.18 MW D 12975.00 89.48 96.73 8721.79 -4151.80 2266.64 5956855.48 694472.03 12.00 4637.43 270.21 MW D 13000.00 89.49 93.73 8722.01 -4154.08 2291.53 5956853.83 694496.97 12.00 4655.17 270.24 MW D 13025.00 89.50 90.73 8722.23 -4155.05 2316.51 5956853.50 694521.96 12.00 4671.98 270.27 MW D 13050.00 89.52 87.73 8722.44 -4154.72 2341.50 5956854.47 694546.93 12.00 4687.79 270.29 MW D 13075.00 89.54 84.73 8722.65 -4153.08 2366.44 5956856.75 694571.83 12.00 4702.56 270.32 MW D by ~ BP Alaska Baker Hughes INTEQ Plannin Report g INTEQ Company: BP Amoco Bate: 8/4/2008 Time: 15:21:55 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-14, True North Site: PB DS 18 Vertical (TVD) Reference: 18-14B: 46.4 Well: 18-14 Section (VS) Reference: Well (O.OON,O.OOE,140.OOAzi) i f Wellpath: Plan 3, 18-14BL1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Atim SS TVD N/S FJW MapN MapE DLS VS TFO Tool ft deg deg ft - - ft ft ft ft dey/100ft ft deg - -- - 13100.00 89.56 81.73 8722.85 -- -4150.13 2391.26 5956860.33 694596.56 12.00 4716.26 270.34 MW D LEGEND •• ~ira..,n., ~.,e+re/+ BP Alaska I/,~ ,e-,41,8,4) N~"za ~w prd~om 18-14118-idA) ,8-,6118-14APB1) " .LL .. s w~ by ,e-,dhe-,dfi, ~Rro,~e~ r•u<I~~ram Plan 3,18-14BLi ` Plan 3 ~oq~a/m.oo° LPI, ,NNLI P, ',~r3,4,.w INTEQ a~~m E",a~~e~~m~u,aa~ ~ ~mr•+ al.: _ .w ~~ ..~. D ~. 3..4. e I I I I` ~ _,. _` , ,Tr I I _ REFERENCE NFORMAT ON I i , ( t T~ } 1 ~ i { eeoro rare N/El Reference we cemre ,e tl, True NOrlll ieao- I~ ~-{-~} ~ 1-{ 1 - I{ I{;-/ ~ }~t1 + I I it - j. ea (~vol Relereza svarem: Mean sea,e. . ~ 1 i-i-r _, a ~ ~ ~" - ~ ~1_i.. .f t _ _ J ~ - #- j { - VSector(VSIRelerence5o tJ (D.CON OOOEI :- ~ * ' s„ree oeo zmo- - Mee m Rclerunre ~e rae f_. _ I I_ r -- t r , f~ i I 1 ~ r r' I - I c.+wmoaManee " maa~w~e - _~ r :- -~. ~. I ~~ 11 __ {i +.~ ~~.T - I_ F t + r FF ; { a+ ... 18-14 18-748 ~ : ' .. ~Y i - \ ' 1 1. i 1 i -F ~1 ~ -~t as N •M n,Pn End o18 / 100 TI DL I ~ tit' r h t ~ ~ ~ ± ._}y »a, a~ I ~~_ I- _ t T ... v i iiaaaa~~ ~' twn m.a .°aar'~'» ~ _ _ .. te-t4 lens J{ _ F _I I anu, saala -'°° T »war ,emu, m,w ma ia"i, ~ w1~ ~ iu i o xinn~ u l a amrlTn ~aa+, 1a4, „s war »1»rr rua n.n ,Taa, M,n1a n»s lar craw ,»w KOP - _.1 I 4 . I / TIP I . i- i t ~-f I I ~[. -~ `r ' ,- I 1 , C ! b .. _ ~__ - __ annoTaTron, or A +_: 1..- { _ C r r 1 hr { y a, rr, aP ,r.,.r... Nr~,a Pena„" ~ , - ~ - I - - 4 i_f r? I 1 1 .,»....,~mnou re,.a~, .o r~1.m <lu.w :ae..,, vNN S. # - I _ i'60 ~ 18-14 18-1/APB1 ~~ ~ ~ ~ -~ nazaa t11,nm To ~ - End 0107.8 dp / 700 K OL ~ I I ~ iiiniaimram io Z _a / / - _I ... « I },~- ~ 1 / / ~~ Plan 7 18-14BL1 ''""~~ I I I I 1 I ~ ~ I a :. .ice I I 8 / I me 1 o q I ~'~ 18-14BL1 Pol on I ~__ / t P ,+m- ~. ~L~ ~ ~ ""' ~ I I ~:.: i ~ ~ fit I i : - ta-uau T.r .e ] ~ to I r+ . ~ r ~ [ J I 4-L~ r ~ - tt }tr I I . r 1 y r~~ i i i -.~ 1 I ~- ~~ ~ ~ 1 ae, ~ t --i t fi- I 1 + ! r- •- r-~ t '. 1- }Y ~ ~~ 1en4ne-T4Al - -.- - 1 l r 1~ r _ i t ~ ~ ~ 7 I I 4 +} ~ ,_j I 18.74BL1 Tarsal I 1 4 1 I nmoi \\ ..-~ -._ ~ F i L l 1 I-~i. il~ _~ r ~. ~ I L.I ~, I I+1 t ,.{_ r .{ +r i { ~ : ~ ~ ~;~_- - I N I IZ + I ' r~ { I r 1 1 ~ i { . { .._ I l { ( ~* ~ te-ueu rar .e ,~ ~ I,; 1a1. t~11E ~/ L; `~ F a I I ,* rrm" `,~ "rte " ;.m , ~" ` ~a~a rma , `r ' I i it i 1 i s \ r ,~ e I I w ~ , -, :~ ,TTY ~ ~ __ ~ . :. , ~~r~~*-rr-r~r I - r ~ rr -rl N l 1 [ r*~ , ICI-~, F, ~,-,-},- ~ ,-,-, ~~+~-r+-r~r.~, zroaT.,.,_ mo aw I at E at t 100ft/in we - a ] } \\ ~ I a~ }+- + _ }: I L __ l ., LI i I I .: I _ .I_,_ !,-I -Y- Ir ~ I r ~. +I~ D + ' ~ I ~~ ~ a aCa - ~_ r rt ~ _ ~_ 1 I + - .- ~ '' ~ I - i t 4k ~- ...~.' . Ff ~+t I I -_ i ~ ~ ~- i i III.. ~l'. fi ~ , Y t ( 1 I 111111 II II I 1111111 ;- I ~ ~ I r , ~1 r , ena aaawlloon DU :. ... I. .. r1- ~ f tLk { I: n \ I TI ~ ~ 1414 161 ~{~ ! I \ I ~ I f+ ~ Plan ], 1anOBL1 II \ \ ^a \09 10 I II 1&t9 t&116 _ II \ _ \~ /\\ 1 to-14BL1 Ta at 1 j I I I i- I __ .. ~.. .... ~ I 1 1B-19BL1 TarY.131 ~- ~ 1 i I '• 1&14BL1 Tar9.1 ] I i. Q End 0/]1.56 I100»DL 1{1 ~ : emo 18-14 1•-19 ~ T,. r ` t.-.~Y I~ 1 +-it ~!-I~~_r-lil~{~~I~.i II III ~IiH{+~-it~ ~?~~# Imo.... ~:.. «se r r ,-, , r , . , I , . , . , a~ . , , .. I r, (~~ ~ . , ~ uoT ~-~~T I ~ . «:a mor .. ~~ . ~, r.-,.,~ ~ ";m I,o,, wo ,,,m ~e mm , W a,m um a,m a~» use „W a.m ~m ~ ~ a,m .,+., .,m <,m ~T .am .rm Vertical Section a! 740.110' [SOWIn] m • u by ~ BP Alaska Anticollis><on Re ort P ^ iNTEQ -- Company: BP Amoco --- - Date: 8/4/2008 Time: 15:36:52 Page: 1 Fietd: Prudhoe Bay Reference Site: PB DS 18 Co-ordinate(NE) Reference: Well: 18-1 4, True North Reference Well: 18-14 Vertical (T VD) Reference: 18-14B: 46.4 Reference Weilpath: Plan 3, 18-14BL1 Db: OraCle ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are eadls in this fldttllcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCW SA Ellipse Depth Range: 10693.19 to 13100.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1507.15 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/4/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 96.40 8698.70 Schlumberger GCT Muftishot (96 GCT-MS Schlumberger GCT multishot 8698.70 9546.70 MWD -Standard (8703.70-10848. MWD MWD -Standard 9568.00 10693.19 18-14B IIFR (9568.00-12234.51) MWD+IFR+MS MWD +IFR + Multi Station 10693.19 13100.00 Planned: Plan 3 V1 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 13100.00 8769.25 2.375 3.000 23/8" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site WeII Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft 18-14,PIan 3, 18-146L1 12875.00 12875.00 0.00 166.62 -166.62 FAIL: Major Risk Lis DS 02 L2-03A L2-03A V6 10700.00 10275.00 872.34 118.08 754.26 Pass: Major Risk Lis DS 02 L2-03 L2-03 V1 10716.62 10950.00 527.61 162.86 364.74 Pass: Major Risk PB DS 05 05-16 05-16A V1 Out of range PB DS 05 05-16 OS-166 V3 13004.49 13125.00 838.73 234.04 604.69 Pass: Major Risk PB DS 05 05-28 05-286 V11 Out of range PB DS 18 18-01 18-01 Vi 11750.00 9900.00 1219.17 459.51 759.66 Pass: Major Risk PB DS 18 18-01 18-01A V1 11750.00 9900.00 1219.17 459.51 759.66 Pass: Major Risk PB DS 18 18-03 18-03A V1 11657.90 11650.00 119.21 254.68 -135.47 FAIL: Major Risk PB DS 18 18-03 18-03B V2 11190.00 11100.00 641.17 247.28 393.89 Pass: Major Risk PB DS 18 18-11 18-11 DPN V3 Out of range PB DS 18 18-14 18-14 V5 Out of range PB DS 18 18-14 18-14A V4 12287.05 10850.00 4.50 187:99 -183.50 FAIL: Major Risk PB DS 18 18-14 18-14APB1 V4 12379.03 10825.00 66.08 147.97 -81.89 FAIL: Major Risk PB DS 18 18-14 18-14B V6 10724.97 10725.00 0.59 139.95 -139.36 FAIL: Major Risk PB DS 18 18-22 18-22 Vi 13061.92 11225.00 44.22 215.54 -171.33 FAIL: Major Risk PB DS 18 18-22 18-22A V1 12710.53 10625.00 978.19 272.05 706.14 Pass: Major Risk PB DS 18 18-24 18-24AL2 V1 10780.00 10489.00 689.86 133.50 556.36 Pass: Major Risk PB DS 18 18-30 18-30 Vi Out of range Site: Well: Rule Assigned: Major Risk Wellpath: 18-14,PIan 3, 18-146L1,PIan 3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axds Ctr-Ctr No-Go Allowable j MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft 10693.19 8743.77 10693.19 8743.77 19.71 0.00 281.61 0.00 3.000 0.00 92.17 -92.17 FAIL 10700.00 8744.04 10700.00 8744.04 19.71 0.06 281.68 0.00 3.000 0.00 92.21 -92.21 FAIL 10725.00 8745.00 10725.00 8745.00 19.31 0.51 278.30 0.00 3.000 0.00 91.27 -91.27 FAIL 10750.00 8745.96 10750.00 8745.96 18.54 1.03 270.42 0.00 3.000 0.00 89.23 -89.23 FAIL 10775.00 8746.89 10775.00 8746.89 18.02 1.54 262.54 0.00 3.000 0.00 87.96 -87.96 FAIL 10800.00 8747.79 10800.00 8747.79 17.77 2.02 254.66 0.00 3.000 0.00 87.48 -87.48 FAIL 10825.00 8748.63 10825.00 8748.63 17.81 2.45 246.78 0.00 3.000 0.00 87.87 -87.87 FAIL 10850.00 8749.40 10850.00 8749.40 18.11 2.84 238.91 0.00 3.000 0.00 89.05 -89.05 FAIL 10875.00 8750.08 10875.00 8750.08 18.68 3.16 231.03 0.00 3.000 0.00 91.03 -91.03 FAIL 10900.00 8750.67 10900.00 8750.67 19.46 3.42 223.16 0.00 3.000 0.00 93.67 -93.67 FAIL 10925.00 8751.14 10925.00 8751.14 20.43 3.60 215.29 0.00 3.000 0.00 96.83 -96.83 FAIL 10950.00 8751.49 10950.00 8751.49 21.47 3.72 207.42 0.00 3.000 0.00 100.25 -100.25 FAIL 10975.00 8751.72 10975.00 8751.72 22.52 3.77 199.55 0.00 3.000 0.00 103.67 -103.67 FAIL rements are i N !n of bag BAG Dowell Ibttm of bag Blind/Shears TOTs of pipes 2" combi pipe/slips Mud Cross I I Mud Cross of flow cross of rams 2 3/8" x 3 1/2" VBR's TOTs of Dios/slios 2" combi pipe/slips b Valve Flow Tee Alaska Department of Natural,~esources Land Administration System Page 1 of~2' I „' ;.~°,,,r,~ .~-~~ ..~, ~. ..-~`:.~ rya; ~~cor;~er`s Search Sfate Cabins ~I~t~a~ S~DUt'€es Alaska DNR Case Summar~- File Type ADL....._ ....' File Number: 1 28321 ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~' Yes ~" No New Search LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract File: AUL 28321 ~`'~^~~ Search for Status Plat Updates Customer: 000107377 BP EXPLORATION (ALASKA} INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 7~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Primary Responsibility; DOG DIV OIL AND GAS. Last Transaction Date: 12/04/2006 Case Subtype : N5 NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 1lc~ridic~n: U ~o~i~nship: U I IN R~nl~c: 0l ~E Sectiu~~ ~ i? Section .-1ci•~~s: 6d(} search Plats ~Vc~ri~licnt.~ l_I Townsl~ij~: O11N Rcan,~e: 01 ~E S"ec~iun: 18 S~etiun . (crc~~~: ti99 1 /rridr~~n: t_! Towns}ui,: OllN Rc~ft~e: U i5E .S'c~clruir.~ 19 .ti'e~e~lrun :lc~~~c~~~: ('i01 Meridian: L! I~~~rm~hii~: 01 l V K~r~t~c~: O l >E .~~~~clinn: 20 .ti'ectinn -1crc~s: 6~0 Le~;xl Descrilrtion OS-28-196.5 * * * SALE NOTICE LEGAL DESCRIPTION C14-1 ~ 1 Tl l N, RI ~E, UM I7, I8, 19, 20 2480.00 Last updated on 08/1412008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28321 &... 8/14/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~,~'L~ /~ /'~,d°Lf PTD# o?OSr/3o?~? Developmen~t~ Service Exploratory Stratigraphic Test Non-Conventional WeII FIELD: ~•C'6/~.~oE' LSAy POOL: ~.eyo,~OE' ~qy. ~`~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /°Sd1.~g ~ ~ `~ ~ ~ , (If last two digits in API number permit No.o?o30630, AP[ No. 50-p~9_~?/6/~-- ~ ~ ; are between 60.69) Production should continue to be reported as a function of the original API number stated above. PLOT HOLE In accordance with 20 AAC 25.005(fj, alt 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 togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Alf 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 throw tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~liane is not allowed for (name of weU) until after (Corauanv Narae) has designed and implemented a water well testing program to provide baseline data on water Quality and quantity. ~Corapanv Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/I I/2008 1fI~LL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 Well Name: PRUDHOE BAY UNIT 18.146L1 Program DEV Weil bore seg ^ PTD#:2081320 Company BP EXPLORAT-ON (~l(A) INC Initial Classffype DEV / PEND GeoArea 890 Unit 11650 OnlOfl Shore _ n~ Annular Disposal ^ Administration 1 Perrnitfeeattaehed___-_________-__________- -__-___-_NA_- ________-_____-_____-__-_---__-_---_ -- ---------------------------- 2 Lease number appropriate- - - - - - - - - - - - - - - - -Yes - - - - - - - - - 3 Uniquewell_nameandnumber----------- ----- ----- - -Yes- - -- - - ---- ---- - ----- ---- ------------------- - -------- 4 1Nelllocatedtn-a_definedpool-___-_____--.__--_._______ _________ Yes- __.__PrudhoeBayFiekllPrudhceBayOilPOCI.____,__________-__,-------._--_ ---------- 5 WelUocatedpropardistanceftomdrihingunit_boundery--------------- -__.___Yes- _----__-.--_-----__--_---_-_. -------------------------------------------- 6 WeIIIQCakedproperdistanCefromotherwelis__-________________ _________Yes_ ____-__--____--_____. ------------------------------- ----------- ----- 7 SuffioiQntacreageavailablein_driklinqunJt_____-_____----------- ---- ----Yes- ------2560 acres.--___.-------------------_.--_-- ------------------------- 8 if deviated,is_wrellbQrepiat-included-------------------------- ------ --Yes- ---------------------.------------____-- 9 Ope(atoroniyafkectedPa~------------- -- ------ --- -.Yes- -- --- -- -- - - ---------- ------ -- -- --------- - ------ 10 Operakorbas_approprjatebandinforoe___----________________ _________Yes. -_-.-_BlanketBond#61Q4153.______.___________,._---_--_- 11 PetmitcanbQissuedwjthQUtGOnseruationorder------------------- ---------Yes- -------------------.._------------..------------------------------------ Appr Date 12 Pem]itcanbeissuedwithoutadminist[ative_approval--------------- ---------Yes-- ----------------.---------------------------_.---------_---- ---------- ACS 611412008 13 CanpermJtbsapprovedbefora15-da~y_wait---------------------- ---------Yes- --------------.---'_---------------------------------------------------, 14 Well located within area andsirataautborkzedby-Injection Order#(putl9#in_comments)(For- NA-- -_---_._________________________________-_________--__--__--__-________ 15 -AhwelJs_wiihin114_mikearea_ofreviswidentified(Fo[gervicewellonly)------ ---------tyA-- -----------.---------------------------------- --- -- -- -- -- - ----- 16 Pte-producedinjeaor, duration of preDroduotionkessthan3months-(Forservicewelionly)--_NA___ ____________________________________-____-_--__--_ --------------------- 97 Nonconven_ gas.ccnforms icAS31,05.03QQ•t,A)~4.2.A-D1- - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorstring_plQVided-____.-._-.-_._____------ ----------NA_.- -.--Conduclorset_inDS1l3.14(185-119).-------------------.-------------------- -- 19 Sud>rcecagingprotectgall_knownUSDWs---------------------- -------- NA--- -----NoaQulferS,AIQ4S,_Conolusion_5.--------_.-----------,--------------------- 20 CMTvoiadequatetopirc~alekeonconduotor&surf-csg______________ _.______ NA___ __.__SurfaeeGasingse<in!)S1@-14.___-_--_________.--_---_-----_._ _ _ __ _ 21 :CMTvoiadequatetotie-knlQngskringtosurf~g------------------- ----------NA--- -----Producti4n.casingget inD$18-14,---------------------------------------- ---- 22 CMTwillcoveraltJcnownproduCtivebQrizons_...-._------------- ----------No_.- _---Slotkedlinercomplekionplanned,_---_-.-___________.--______-__-_____________ 23 Casing desgns adequate for C,_T, B 8 permaf[ost- - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ . _ _ Original w@II-met design specification&. - NA for slotted liner._ _ - _ _ _ - _ - - _ _ _ - - _ _ - - _ - - - - _ - _ 24 Adequate tankage_or resetvepit - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - -Yes - . - _ - - -Rig equipped with sleet pits, Nolese[ve pit planned._ All waste to approved disposalwell(s). - - - . - - - - - . 25 ifare-dril~has-a10-403JorabandortmenklteenaRRreved------------- --------- NA--- -----Thissegmentisalateral.------------,--------------------- - -- --- ---- 26 Adequate_wellkore separationproposed- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - - P[oximktY analysis performed_ tJearest segment is retainedpodion of 18.146 and_paths diverge.- .. - _ - - - _ - _ 27 If_divederrequkred,doesJtmeetreg~tlations---------------------- ----------tyA--- -----BQPStackwillalreadY-be in place,---------------------------- - --- -- -- - Appr Date 28 Drilling tluidRrogram schQmattc-& equip ilstadequate- - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - -Maximum expected formation pressu[e 7,3-EMW._ Planned MW 6.6-ppg•- - . _ _ _ _ _ _ _ - .. - _ - - - _ - - - _ _ - TEM 8115!2008 29 BOPES,doiheYmeetregulation- ------ -- - - - - _ - - --Yes-- -- - --- - -- -- -- ---- --- - _--- --- - 30 BOPS-press rating appropriate; test to_{put psig kn c9mments)- - - - - - - - - - - - - - - - - - - -Yes - _ - _ _ - - MASP calculated at 2444 psi, 3500_psi_BOP testplanned, _ _ _ _ - _ _ - - _ ---------------------- 31 ChokemanlfoklcornplieswlAPl_RP-53(MaY84)------------------- -------Yes-- ---------- 32 Work will occur wr<houi operation sbutdow_n- - - - - - - - - - - - - -Yes - - - - - - - - - ... - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ko_ - _ _ _ - _ _ MinorH2S_is repgrted at QS 18. -Mud-should preclude H2S on rig._ Rig has &ensora and alarms. - - . _ - _ - - . 34 -MechanicafconditionofwallswtthinAORyenfied(FOrservicaweilonhl)-_-- -._---_--NA-- ------------------------___________________ --------------------------- Geology 35 Pemlit can be issued wlo hydrogen sulfide measures - - - - - - - - - - - - - - - - - _ _ - - No_ _ _ _ _ _ _ _ Max H2S- level on_ DS 18=24ppm-on_well 18-148, _ _ _ _ _ _ _ _ _ _ - _ _ - - - - - - - . - - - - - - - _ _ _ _ - 36 Daka-presented on potential ofrerpressurezones---.__-_-------- ----------NA_ ____.-------__.__--__________,-__________-----_-------_-- _ Appr Date 37 Seismicanarysisofshallowgas_zones------- --- ---- - - ---- NA-- ____ --- - - ----- - -- - ACS 811412008 38 Seabed condition sunrey_(i(cff-shore)------------------------- --------- P1A_- --- ---- - -- - --- - --- - - -------------------.------------------------ -- -- ------------------ 39 Contact namelphone for weQkly_prcgress reports (exploratory onlyj _ , - - _ _ _ . _ _ _ _ _ _ _ _ Yes - - _ - - _ Sean Mct.aughlin_- 5G4-4387, - - . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - - - _ - - _ - - - - _ _ _ - Geologic Engineering Commissioner. pate Date: Commissioner: C inner Date 1~ ~r/~_OV