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Home My WebLink About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y Anne Prysunka at 4:02 pm, Nov 28, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNRX 8VHUV 'DWH RBDMS JSB 113022 WCB 11-26-2024 DSR-11/28/22 $&7,9,7<'$7(6800$5< 7,2 7HPS 6,7%*)/(OLQHUHTXHVW1R$/7%*)/# EHORZVWD62EEOV 69:9669 &09 2,$2$ 27* :(//6+87,121$55,9$/ 35(6685(7(673&(72/3+3 5,+:&+' )1:(,*+7:(,*+7*5&&/ %$,/(5 2$/ 7$**(' $%29(3/8*6(7'(37+# $33($563/8*6+,)7('83 +2/(25+$6),//217232),7 '803('*$/ 33*&(0(17217232)&,%3(6772&# :$,7+56%()25(3233,1*:(// :(///()76+87,1 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8% Cement is shown correctly on the new WBS below. -WCB 7$**(' $%29(3/8*6(7'(37+# $33($563/8*6+,)7('83 +2/(25+$6),//217232),7 '803('*$/ 33*&(0(17217232)&,%3(6772&# RECEIV 2Oc. -OIs-7 Vaal JAN 17 2017 PRINT DISTRIBUTION LIST BAKER HUGHES _ ((�� Please sign and return one copy of this transmittal form to: COMPANY BP Ext;ito 1 Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME 15-12B 900 E.Benson Blvd. /10/201 7 ,, K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE December 26,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares& .bakerhughes com TODAYS DATE January 16,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OFPRINTS #OF I-F IN I S #OF COPIES #OF COPIES #OF COPIES V V V V V V 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. JUN3 0 20 Anchorage,Alaska 99508 SCANNED 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 --* _ ',p"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 3 4 TOTALS FOR ALL PAGES: 0 3 4 0 0 • • Im~~e Project 11Veli F~i~tQry File Gover 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 ar are viewable by direct inspection of the file. ~Ci~- Q ~ ~ Well History File Identifier o~,~,.,~ea~., o..o,aea iuuiuiuimuu ~ae=<a~~e~ea iuiuiiiniiiiuu RES AN 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: Mari Date: ,~ ~ /s/ Project Proofing I II I I'I II III II II II I BY: Maria Date: ~ ,~ ~ © /s/ Scanning Preparation ~ x 30 = + ~C~ =TOTAL PAGES 11 C~ BY M i D t ~ ~ (Count does not include cover sheet) / / ar a : a e: ~ s Production Scanning III 111111 IIIII II III Stage 1 Page Count from Scanned File: ~_ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: / ~$ ~ /s/ 'n /1 r'4 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 ~I II I II II I (III ReScanned BY: Maria Date: !s/ Comments about this file: Quality Checked III II'lll'll II'I II 10!6/2005 Well History File Cover Page.doc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y Samantha Carlisle at 10:27 am, Mar 11, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUN RX 8VHUV 'DWH %R<RUN $&7,9,7<'$7(6800$5< <(//2:-$&.(7(/,1(-2%2%-(&7,9('5,)7:(//$1'$'' 3()25$7,21 0,5808$1'5,+:/,1(*5722/:,7+ '5,)7*81$1'*5 :,7+ 3(5)25$7,21*81/2$'(' 63):,7+*(2'<1$0,&5$=25;'3&+$5*((+ 3(1(75$7,21 3(5)25$7(')520 :,7+ *81663) /2*:$6&255(/$7('72%$.(5+8*+(65(6(592,53(5)250$1&( 021,72531&' '$7(''(& :(//:$6)/2:,1*8321$55,9$/ :(//:$6&/26('8321-2%&203/(7,21$1'23(5$725:$6 127,),('7+$77+(:(//&28/'%(387%$&.21/,1( 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8% STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~C~1VED JUL 1 9 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ~r~~0 Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter uspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 206-0870 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20665-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028309 ~ PBU 15-126 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11500 feet Plugs (measured) 11020' 4/16/09 feet true vertical 8901.75 feet Junk (measured) None feet Effective Depth measured 11412 feet Packer (measured) 8749 true vertical 8903.99 feet (true vertical) 8097 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 SURFACE - 80 SURFACE - 80 1490 470 Surface 2482 13-3/8" 72# L-80 SURFACE - 2482 SURFACE - 2482 4930 2670 Intermediate 5637 9-5/8" 47# L-80 SURFACE - 5637 SURFACE -5410 6870 4760 Production 2501 7" 26# L-80 2979 -5480 2976 - 5268 7240 5410 Liner 3485 7"26# L-80 5471 - 8956 5259 - 8281 7240 5410 Liner 2701 4-1/2" 12.6# L-80 8797 - 11498 8140 - 8902 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8806 _ Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 8749 8097 12. Stimulation or cement squeeze summary: Intervals treated (measured): '.; t ~ "~~`~ ~ ~~ Treatment descriptions including volumes used and final pressur ~, e: ~ .° 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X Well Status after work: Oil r Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 7/16/2010 ~~~~~~ ~~--.mow ~~AG4 ,~~w~ inau~ JUL 2 01010. _= ~-- 7-2l-/o.,u.,~~~~. ~.,~y~~~a~ ~.,~~y 15-12B 206-087 PERF OTTOC:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-12B 12/29/06 PER 9,760. 9,790. 8,891.43 8,894.66 15-12B 12/29/06 PER 11,100. 11,400. 8,912.43 8,904.33 15-126 12/29/06 PER 10,540. 10,570. 8,913.26 8,913.95 15-12B 12/29/06 PER 10,650. 10,960. 8,915.06 8,912.27 15-12B 12/29/06 PER 10,030. 10,140. 8,891.44 8,892.97 15-12B 12/29/06 PER 9,880. 9,910. 8,893.16 8,892.3 15-12B 12/29/06 PER 10,210. 10,480. 8,896.43 8,910.87 15-126 4/16/09 BPS 11,020. 11,400. 8,912.38 8,904.33 15-12B 7/14/10 BPS 9 . R13o ~ 11,100. 8,885.57 8,912.43 15-12B 7/14/10 APF / 9,690. 9,710. 8,875.23 8,880.95 15-12B 7/15/10 APF 9,670. 9,690. 8,868.37 8,875.23 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • 15-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE 'SUMM'ARY 7/13/2010eCTU #9 w/ 1.75" CT (GSO) 4Road unit from K-08. MIRU. MU combo drift/logging BHA 7/14/2010CTU #9 w/ 1.75" CT Scope; (GSO) Continued from WSR 07-13-10. Finish MU drift/logging BHA. RIH w/ 3.7" drift assy w/ GR/CCI tool to 10000'. Log up to ;.9500'. POOH. Data indicates -10' correction. RIH w/ 3.66 HES CIBP. Set @ '.9730 corr. depth. Test plug to 1300 psi and pooh. RIH w/ 20'x 3.375" pert gun ;and perforate 9690-9710'. "*job in progress'`'` 7/15/2010~CTU #9 w/ 1.75" CT (GSO) Continued from 7/14/2010 RIH and perforate 9670- 9690' w/ 3-3/8" gun. FP wellbore w/ 30 bbls McOH. RDMO o omplete FLUIDS PUMPED BBLS 1 DIESEL 1 MEOH 2 Total TREE= ~ ~ d-1/16" FMC WELLHEAD = FMC ACTUATOR = OTIS-LONG KB. ELEV = 62.4' BF. ELEV = NA KOP = 2800' Max Angle = 94° @ 12596' Datum MD = 9565' Datum TV D = 8800' SS ~ 15-12B 20" CONDUCTOR, 94#, H-40, ID = 19.124" i~ $0' 13-3l8" CSG, 72#, L-80 BTC, ID = 12.347" 2484' 9-5/8" X 7" BKR ZXP LTP, ID = 6.290" 2979' 9-518" X 7" BKR FLEX-LOCK 2996' LNR HGR, ID = 6.360" Minimum ID = 3.725" @ 8792' 4-1 /2" HES XN NIPPLE 7" SCAB LNR, 26#, L-80 BTGM, 54$0' .0383 bpf, ID = 6.276" 9-5l8" EZSV WHIPSTOCK (07/29/06} 5637' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3176 3168 16 KBG2 DMY BK O 10/20/09 3 4919 4756 23 KBG2 DMY BK O 10/20/09 2 6331 6008 31 KBG2 DMY BK 0 12/28!06 1 7485 7014 30 KBG2 DMY BK 0 12/28!06 5467' 7" BKR TIEBACK STEM w!NO-GO , ID = 6.180" 5471' 9-5/8" X 7" BKR ZXP LTP, ID = 6.350" 54$9' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.310" MILLOUT WINDOW (15-12B) 5637' - 5654' $~ 4-1/2" HES X NIP, ID = 3.813" $7~~ 7" X 4-112" BKR S-3 PKR, ID = 3.875" 9-518" CSG, 47#, L-80 BTC, ID = 8.681" ~ 8210' 9-5/8" EZSV (07/29/06) 8284' PERFORATION SUMMARY REF LOG: MWD / GR ON 12/22/06 ANGLE AT TOP PERF: 81 ° @ 9760' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 9760 - 9790 O 12/28/06 2-1/2" 6 9880 - 9910 O 12!28(06 2-1/2" 6 10030 - 10140 O 12/28/06 2-112" 6 10210 - 10480 O 12/28/06 2-112" 6 10540 - 10570 O 12/28/06 2-1/2" 6 10650 - 10960 O 12!28/06 2-1/2" 6 11100 - 11400 C 12/28/06 1!2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 8806' 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 8956' 4-112" HES X NIP, ID = 3.813" 8793' I-14-1l2" HES XN NIP, ID = 3.725" $797' 1~ 7" X 5" BKR HRD ZXP LTP I w / 11.8' TIEBK SLV, ID = 4.250" 8$06' 4-1/2" WLEG, ID = 3.958" 8815' 7" X 5" BKR HMC LNR HGR, ID = 4.410" $$22' 5" X 4-1 /2" XO, ID = 3.958" 4-1/2" SC WRP(04/16/09) PBTD --i 11412' 1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 11498' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/17/81 N1 ES ORIGINAL COMPLETION 06/03/09 SRBITLH WRP SET (04!16!09) 08/04/00 N4/3S CTD SIDETRACK 10/24/09 RCT/PJC GLV C/O (10/20/09) 11/18/06 N27E SUSPENDED SDTRCK "B" 12/29/06 N2ES SIDETRACK "B" 01/17/07 SWC/PA GLV C/O 04/15/08 NS/PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 15-12B PERMIT: 2060870 API No: 50-029-20665-01 SEC 22, T11 N, R14E, 2114' FNL & 1474' FWL BP Exploration {Alaska) SAFET'i~~ES: WELL ANGLE> 70° @ 10807'. *** 4-1 /2" CHROME TBG *** 2234' I~4-1/2" HES X NIP, ID = 3.813" i • ~.. ~ ~~- . w-;..:. ~ ~ - '. ~` t,~~ x y A~fi~ , t, ....t MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, as y° ~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, ~ ~' i Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 r)ata• n1/O5/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 - 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-118 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-268 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9!2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-458 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8(2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 ~LL. ~~.T ~~1 ~~f d~° PrtoAcrive D'u-yNOSric SERVICES, INC. • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Production Profile 15 Apr-09 15-12B 2) Signed Print Name: ao~-v~~ `~ ! Jib 1 BL / ESE 50-029-20665-02 _~ ~j~'I'~ ~ ~ ~ f `~ Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL -1 ~ , ,.,5 ,"~ li;~° 7 ~~ r ~~ wEasITE A '.~~ r .~~ _ C,'~,Docurnents and Settings\Diane Williams\DeslQop\Transmit_SP.docr RE: LINDER EVALUATION: 15~B (PTD #2060870) Sustained Casing:ssure due to... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] '~ ~~-~~ ~-I~~~~ Sent: Tuesday, October 20, 2009 1:38 PM To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Holt, Ryan P (ASRC) Subject: RE: UNDER EVALUATION: 15-12B (PTD #2060870) Sustained Casing Pressure due to TxIA Communication AI I, ~ Well 15-126 (PTD #2060870) passed an MITIA after the gas lift valves were dummied off. The well has been reclassified as Operable and may be placed on production when convenient for operation. Please be careful when BOL as the IA is fluid packed. Thank you, Torin ~ `~ ~J~~ ~~~~~~~~~:~ ~'~i'~~,i ~ ~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, October il, 2009 7:58 PM % To: NSU, ADW Well Integrity Engineer; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; SchwarYz, Guy (DOA) <guy.schwar~@alaska.gov>; GPB, Area Mgr Centrel (GCl/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Sala, Jaycen (CH2MHill); GPB, Gas Lift Engr Subject: UNDER EVALUATION: 15-126 (PTD #2060870) Sustained Casing Pressure due to TxIA Communication All, Well 15-12B (PTD #2060870) has confirmed sustained casing pressure due to TxIA communication. On 10/09/09 the wellhead pressures were tubing/IA/OA equal to 1535/2150/20. The well has been reclassified as Under Evaluation. The plan forward is: 1. Slickline: Dummy off gas lift valves 2. F: MIT-IA to 3000 psi A TIO plot and wellbore schematic have been included for reference. « File: 15-12B TIO Plot.doc» « File: 15-12B.pdf» .-~ Please let us know if you have any questions. Thank you, Torin Roschinger (alt. Anna Dube) 11 /6/2009 RE: IJNDER EVALUATION: 1~B (PTD #2060870) Sustained Casing: ssure due to... Page 2 of 2 Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 11 /6/2009 PBU 15-12B PTD 206-087 10/20/2009 TIO Pressures ~,ooo 3,OOD 2,~J00 1.000 ~- Tbg f IA -~- OA OOA ~ OOOA On 07111I~J9 07f18J09 07/25109 ~8!D1/09 O~IL~~l09 08I15f09 08122I09 08/29/09 09I05l09 09/12I09 D9I19109 09l26/09 10/03J09 10l10I09 ~ ~ TREE= 4-1/16" FMC WEl LHEAD = FMC ACTUATOR = OTlS-LONG KB. ELEV = BF. ElEV = .., ~ 62.4' ~..~.__ ~,, ~,NA KOP = _ 2800' Max Angle = 94° @ 12596' Datum MD = 9565' Datum ND = 8800' SS 2Q° CONDUCTOR, 94#, H-4d, ID = 19.124" ~-~ $0` 13-3/8" CSG, 72#, L-80 BTC, ID = 12.3~t7" 24$4' 9-518" X 7" BKR ZXP L7P, fD = 6.290" 2979~ 9-5/$" X 7" BKR FLEX-LOCK 2996' LNR HGR, ID = 6.360" Minimum ID = 3.725" @ 8792' 4-1/2" HES XN NIPPLE 7" SCAB LNR, 26#, L-8d BTGM, 5480' .0383 bpf, ID = 6.276" 9-5/8" EZSV WHIPSTOCK (d7/29106} 5637' GAS LIFT MANDRE~S ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3176 3188 16 KBG2 DOME BK 16 01/15/07 3 4919 4756 23 KBG2 SO BK 20 01/15/07 2 6331 6008 31 KBG2 DMY BK 0 12/28/06 ~ 7486 7014 30 KBG2 DMY BK 0 12/28/06 5~.~7' 7" BKR TIEBACK STEM w/ NO-GO , ID = 6.180" $1~7'~~ 9-5/8" X 7" BKR ZXP LTP, ID = 6.350" 54$9~ 9-5t8" X 7" BKR HMC ~NR HGR, ID = 6.310" MILLOUT WINDOW (15-126) 5637' - 565A' \ ~$7~~$' ~ 4-1/2" HES X NIP, ID = 3.813" 7" X 4-1/2" BKR S-3 PKR, ID = 3.$75" 9-5l8" CSG, 47#, L-80 BTC, ID = 8,681" ~~ ~L 1~e ~_ 9-5l8" EZSV (Q7/29106) $2$4~ PERFC}RATION SUMMARY REF LdG: MWD / GR ON 12122/06 ANGIE A7 TOP PERF: 81 °@ 9760' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 2-1/2" 6 9760 - 9790 O 12I28/06 2-1/2" 6 9880 - 9910 O 12i2810fi 2-1l2" 6 10030 - 10140 O 12/28/06 2-1/2" 6 10210 - 10480 O 12/28/06 2-1/2" 6 1D540- 10570 O 12/28/06 2-1/2" 6 10650 - 10960 O 12128I06 2-1l2" 6 1110Q - 114Q0 G 12/28/06 4-1/2" TBG, 12.6#, 13CR-8d VAM TOP, .0152 bpf, ID = 3.958" -i 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 4-1i2" HES X NIP, ID = 3.813" 87J~" e--~4-1/2" HES XN NIP, ID = 3.726" $7~7' ~ 7" X 5" BKR HRD ZXP LTP i w/ 11.8' TIEBK SLV, ID = 4.25Q" I 8806~ 4-1i2" WLEG, ID = 3.958" 8815' 7" X 5" BKR HMC LNR HGR, ID = 4.410" $$22~ 5" X 4-1/2" XO, ID = 3.958" 11020' (--~4-1/2" SC WRP(04/16/09} i~ _~- 4-1(2" LNR, 12.6#, ~-80 IBT M, .0152 bpf, ID = 3.958" DATE REV BY COMtNENTS dATE REV BY COMMENTS 12/i7/81 N1ES QRIGINALCOMPLEf10N 06l03l09 SRB/TLH WRPSEf'(04/16/09} OSi04/00 N4l3S C7D SIDETRACK 11/18/06 N27E SUSPENDELt SpTRCK "B" 12/29t06 N2ES 31DETRACK "6" 01(17/07 SWC/PA GLV C/O 04(15I08 NStPJC DRLG DRAFT CORREGTIONS PRUDHOE BAY UNIT WELI.: 15-12B PERMIT: 2060874 API No: 50-029-20665-01 SEC 22, T11 N, R14E, 2114' FNL & 1474' FWL BP Explaration {Alaska) 1~~~~~ 41(~?" CHROME BG L ANC~E > 70° @ 10807'. *** 2~3q.' ~-j 4-1 /2" HES X NIP, ID = 3.813" 12/08!08 ~C~~~mb~h~~l' NO. 4995 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Bette 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wall _Ini. ft ~ ,,.. n......a....:__ R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-028 4994 MEM PROD PROFILE - 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT [ 11/04/08 1 1 12-17 4994 PRODUCTION LOG Q C~/ 11/04/08 1 1 P2-41 4994 PRODUCTION LOG 11/07/08 1 1 1••29/M-25 4994 PRODUCTION LOG (p .- 11/04/08 1 1 NIPC-05A 4994 MEM LDL .~ 11/15/08 1 1 L-114A 4994 USIT ~- ~- (( `j` 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ [ ~} 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~- - 12/02/08 1 1 15-128 4994 MEM PROD PROFILE ~p ^ ~ 11/27/08 1 1 4-40/P-43 4994 MEM LDL (~j - '~' `Y ' 11/26!08 1 1 N-146 4994 MCNL --~~~ ~ 09/20/08 1 1 01-21A 4994 MCNL Og/2g/Og 1 1 E-29A 4994 MCNL - 09/01/08 1 1 PI FASF Ar`KNAWI FIInC oe rnoT av e~r_w uw~r_ nun ocTUnwuw, i. r..,.- nn,.,.. .-..... ~,. BP Exploration (Alaska) Inc. Petrotechnic:al Data Center LR2-1 900 E. Benson Bfvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: ~~ LJ -y e ~~ '- DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2060870 Well Name/No. PRUDHOE BAY UNIT 15-12B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20665-02-00 MD 11500 TVD 8902 Completion Date 12/27/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, PWD, DEN, NEU (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 5627 8999 Open 10/19/2006 PB 1 D D Asc Directional Survey 8910 11500 Open 1/28/2007 ED D Asc Directional Survey 5627 8999 Open 1/28/2007 PB 1 ~t LIS Verification 5453 11498 Open 5/7/2008 LIS Veri, GR, RPX, FET, RPM, RPS, RPD, ROP, FCNT, NCNT, NPHI, RHOB, DRHO ED C Lis 16221 Induction/Resistivity 5453 11498 Open 5/7/2008 LIS Veri, GR, RPX, FET, RPM, RPS, RPD, ROP, FCNT, NCNT, NPHI, "~ RHOB, DRHO D C 16963 Induction/Resistivity 0 0 Open 9/30/2008 PDF, EMF and CGM graphics for EWR MD and ND logs g Induction/Resistivity 25 Col 5632 11500 Open 9/30!2008 MD ROP, DGR, EWR, CTN, ALD r/Log Induction/Resistivity 25 Col 7-V 9 5405 8901 Open 9/30/2008 TVD DGR, EWR, CTN, ALD ' Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2060870 Well. Name/No. PRUDHOE BAY UNIT 15-126 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20665-02-00 MD 11500 TVD 8902 Completion Date 12/27/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ,~ Daily History Received? 'wG N Chips Received? YT1V- Formation Tops Q N Analysis Y-1-N.. Received? Comments: Compliance Reviewed By: _.._______.______._~________ Date: ' ~~ ~~ ~J /y.»~ ~ « WELL LOG TRANSMITTAL To: State of Alaska September 17, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-12B AK-MW-4730559 15-12B 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20665-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20665-02 ° Digital Log Images: 1 CD Rom 50-029-20665-02 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signed: 2v~~$~ ~ 0~9 ~3 n~ • A WELL LOG TRANSMITTAL To: State of Alaska Apri123, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1S-12B AK-MW-4730SS9 1 LDWG formatted CD rom with verification listing. API#: SO-029-20665-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99S 18 "~ = -- ,~, ~ ; ;N ~_. ~,, ~~ ~v ~ .. Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: (i. ao~-~~~ '~~~~21 15-12A (200-061) and 15-12B (206-087) ..- • Subject: 15-12A (200-061) and 15-12B (206-087) From: Thomas Maunder <tom maun er ciadmm.state.ak.us> Date: Thu, O1 Feb 2007 09:19:51 -0900 To: Sondra Stc~~rman ~~Ste«maSD~~~~BP.com=~~. Tcrric Hubble °~hubbletl«i.:bp.com~= Ladies, I am reviewing the 407 for 15-12B. Lots of work to get what looks like a really nice well. Would you please get with whoever does the drawings. According to the work summaries, the drawing sections below the EZSV/whipstock are not correct. I am not sure that there is much benefit to be realized by redoing the drawings since that section of the wellbore has been effectively plugged, but an EZSV was set at -8254' with 15 bbls of cement spotted on top. Then the EZSV/whipstock. was installed at -5637'. The drawing submitted with the 15-12A 407 for abandonment does have both EZSVs listed, but no depth are entered. Thanks much for passing this on. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 2/1/2007 9:21 AM 3e~ STATE OF ALASKA ~ ~,, ALASKA IL AND GAS CONSERVATION COMM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~ ~ ~ 2Q07 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC2s.~os zoAAC2s.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other '~ 1 b. Well Class: r~ ~~fft'0 p ry ® Develop x lorato ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. -1~tL91'Z006'/~?0? ,r~ 12. Permit to Drill Number 206-087 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded "~ /~ ~,~A ,.?~s~-~'rl 13. API Number 50-029-20665-02-00 / 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached '1 12/22/2006 14. Well Name and Number: PBU 15-12B ~ 2113 FNL, 3803 FEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 4571' FNL, 1895' FEL, SEC. 22, T11 N, R14E, UM 8. KB Elevation (ft): 62.40 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 601' FNL, 639' FEL, SEC. 27, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11412 ~+ 8904 Ft Pool ,~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 677429 y- 5959402 Zone- ASP4 10. Total Depth (MD+TVD) 11500 - + 8902 Ft 16. Property Designation: ADL 028309 TPI: x- 679402 y- 5956992 Zone- ASP4 Total Depth: x- 680691 y- 5955712 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: s.//iV OsJ .5'6 ~7 MWD, DIR, GR, RES, PWD, DEN, NEU o?--/'O~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2482' Surface 2482' 17-1/2" 2500 sx Fondu 400 sx PF 'C' 9-5/8" 47# L-80 Surface 5637' Surface 410' 12-1/4" 250 sx lass 'G' 7" 26# L-80 2979' 5480' 2976' 5268' 8-1/2" 372 sx Class 'G' 7" 26# L-80 5471' 8956' 5259' 8281' 8-1/2" 223 sx Lite Crete 169 sx Class 'G' 4-1/2" 12.6# L-80 8797' 114 8140' 902' 6-1/ " 347 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TualNC RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 6 SPF~ 4-1/2", 12.6#, 13CR80 8806' 8749' MD TVD MD TVD 9760' - 1140' 8$91 ~ - $904' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protected with 150 Bbls Diesel 26. PRODUCTION TEST Date First Production: January 16, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 1/17/2007 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 578 GAS-MCF 1768 WATER-BBL 0 CHOKE SIZE 78 GAS-OIL RATIO 3057 Flow Tubing Press. 827 Casing Pressure 1150 CALCULATED 24-HOUR RATE• OIL-BBL 3469 GAS-MCF 10607 WATER-BBL 0 OIL GRAVITY-API (CORK) 27• CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separ Submit core chips; if none, state "none". . ~~. ~E EI ~ 200 None - ~te.sheet„if.n essary}. ~r°'~' ~~°0~ ~~ 06 ~`-`-`-^~ ~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~ ~~ V 28. GEOt.OGIC MARKE 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Sag River 8957' 8282' None Shublik A 9000' 8320' Shublik B 9022' 8340' Shublik C 9043' 8359' Top of Sadlerochit 9075' 8388' 42SB 9210' 8512' TCGL 9237 8537 BCGL 9316' 8610' 23SB 9376' 8665' 22TS 9446' 8726' 21 TS 9490' 8762' TZ1 B 9583' 8826' TDF 9682' 8873' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr tewma Title Technical Assistant Date -~ ~- ~~ PBU 15-12B 206-087 Prepared ByName/Number.~ Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Ron Phillips, 564-5913 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. IreM 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 Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE= 4-1/16" CM! WELLHEAD = 13-5/8" FMC ACTUATOR = AXELSON KB. ELEV = 60' BF. ELEV = NIA KOP= 5,700'MD Max Angle = 92.44 Datum MD = N/A Datum TV D = 8800' SS 15-1?~ SAFETY NOTES: W ELL >90° @ 9824' and $6° to 92° through to TD of 11500' MD 1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS +D DEV TYPE VLV LATCH ~ PORT DATE 68 16 KBG-2 DOME BK 16 01/15/07 56 23 KBG-2 SO BK 20 01115(07 08 31 KBG-2 DMY BK 0 12!28/06 14 31 KBG-2 Dtv1Y BK 0 12(28/06 7" Liner Hanger 9-5/8" Whipstock, millout w indow -3/8" CSG, 72#, L-80, ID = 12.347" Scab LNR HGR Minimum ID = 3.725" @ 8793' 4.5" HES XN Nipple 9Cr 7700' Top of Cerr~nt 7.33 BBL ~ ZS~1 ~(ob ~~~~~~ ~`i5 @~C-~tO~ 0 ~ ttU-l`~-- ~, :rte ~i~0 CIJ~ ~LT~ ~lCC[- ~~as _~~a~ ~~ S~ M_d`tG~T `I . ~~~ ~~ 8728' 4-1/2" HES X NIPPLE; ID=3.812" 8749' 7" X 4-112" BAKER S-3 PERM PKR; ID=3.88" $772' 4-1/2" HES X NIPPLE; ID=3.812" 8793' 4-112" HES XN NIPPLE; ID=3.725" 8804' 4-1/2" TBG, 12.6#, 13CR-80 / WLEG 8787' 4- 112" LNR HGR/LTP w / 11' Tieback Sleeve 8954' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 0.32 6 9760' - 9790' Opn 12/28106 0.32 6 9880' - 9910' Opn 12!28/06 0.32 6 10030' - 10140' Opn 12/28/06 0.32 6 10210' - 10480' Opn 12/28!06 0.32 6 10540' - 10570' Opn 12!28106 0,32 6 10650' - 10960' Opn 12/28/06 0.32 6 11100' - 11400' Opn 12/28/06 4-1/2" CSG, 12.6#, L-80, .0152bpf, ID =3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05!81 ORIGINAL COMPLETION 05!10/06 RLP 15-12B (wp04) Side track 08/04100 CTD SIDETRACK 05/17!06 RLP 15-12B (w p05} Side track 08/29101 CWKAK CORRECTIONS 11/21!06 RLP 15-12B Updated casing depths 09/11/03 CMOlTLP DATUM MD/TVD CORRECTIONS 12/29/06 MGS/JGR ST Producer/Nishak 06!12/04 RWL/KA GLV C!O 01/15!07 SWC/PAG GLV C/O 07/27/04 BJMcN/K FISH PRUDHOE BAY UNIT WELL: 15-126 PERMff": API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) r"t ~~ BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours ~ Task { Code ~ NPT Phase Description of Operations 7/15/2006 20:00 - 00:00 4.00 RIGD P PRE Rig released from 15-36B at 20:00 hrs. Pull out al! modules and place for rig up. P/U matting boards and herculite. No pressure on tubing, upper, and lower annulus. 7/16/2006 00:00 - 06:00 6.00 RIGD P PRE Pull sub base off of 15-36B, pick up herculite and rig mats, move wheels in on sub base, stage sub base at 15-12B. 06:00 - 09:30 3.50 RIGU P PRE Set rig mats and lay herculite for sub base on 15-126. r~- 09:30 - 20:00 10.50 RIGU P PRE Spot the sub base over~l2~ set rig mats and spot pipe sheds, set rig mats and lay herculite for pits and motor complex, set complexes in place. Set rig mats and set pump complex in place. 20:00 - 00:00 4.00 RIGU P PRE Berm rig, hook up power lines, switch to rig power, hook up all lines at interconnects, skirt around tree, hook up skate rail. 7/17/2006 00:00 - 02:00 2.00 RIGU P PRE Finish berming rig complexes, level all stairs on outside of rig, cut off excess herculite. Rig accepted at 02:00 hrs. 02:00 - 08:30 6.50 W HSUR P DECOMP Take on 9.8 ppg brine to mud pits, while checking for leaks found the pump suction in between the mud pits and mud pumps were leaking. A total of 5 gallons of 9.8 PPG brine leaked into the contaiment. We called #5700 and reported it, then sucked it up with a vac truck and put it back in the pits. PJSM, install spacer spool on tree in order to have clearance to pull TWC with lubricator and be able to close the master valve. Set circulating manifold in cellar and connect lines to pump through IA and OA while taking returns through the choke line and gas buster. 08:30 - 09:30 1.00 WHSUR P DECOMP Hold pre job and pre spud safety meeting with WSL. 09:30 - 11:00 1.50 W HSUR P DECOMP Veco rigged up scaffolding in cellar to access wellhead. 11:00 - 12:00 1.00 WHSUR P DECOMP Purge lines with fresh water and check for leaks. 12:00 - 13:00 1.00 WHSUR P DECOMP Held decompletion safety meeting with WSL. 13:00 - 15:00 2.00 WHSUR P DECOMP Test HP mud lines to 3,500 psi with fresh water, shut down and replace bad o-ring in mud line. 15:00 - 16:00 1.00 WHSUR P DECOMP Service rig. 16:00 - 17:30 1.50 WHSUR P DECOMP Rig up DSM lubricator, 0 pressure on all annulus valves, pull BPV, 157 psi on lubricator, bleed off same (All gas), rig down lubricator. Rig up circulating manifold to tubing. 17:30 - 21:00 3.50 W HSUR P DECOMP Bleed tubing pressure through choke line and gas buster (gas only), flow check, tubing pressure=0 psi. Pump 38 bbls 9.8 ppg brine down 3-1/2" X 5-1/2" annulus, displacing the 19 bbls of diesel out of the 3-1/2" tubing back through the gas buster at 2 bpm @ 350 psi. Pump 93 bbls 9.8 ppg brine down the tubing taking returns out the annulus displacing 26 bbls of diesel out of the annulus at 2 bpm @ 400 psi. Monitor well 15 minutes. Pump 1 drum Safe Surf O down the tubing chasing it with 200 bbls of 110 degrees of heated 9.8 ppg brine, well clean. Monitor well 15 minutes. 21:00 - 22:00 1.00 WHSUR P DECOMP FMC set TWC, tested TWC from below, tested to 800 psi before pumping away, rig down circulating manifold. 22:00 - 00:00 2.00 W HSUR P DECOMP Nipple down master valve off tree, hanger threads were damaged with the starting thread being smashed. Dressed hanger thread with a chisel and pinged the lip back with a ball peen hammer. Screwed the 3-1/2" NSCT x 3-1/2" XO in 7.75 turns with chain tongs. Threads OK. 7/18/2006 00:00 - 01:00 1.00 WHSUR P DECOMP As we were unable to test below TWC to 1,000 psi:, tested against top of TWC to 4,500 psi to verify we could test after l,~~ Printed: 1/29/2007 9:39:59 AM U BP EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours I Task Code ~ NPT Phase Description of Operations _-_ _- 7/18/2006 00:00 - 01:00 1.00 W HSUR P 01:00 - 07:00 6.00 BOPSU P 07:00 - 12:00 I 5.001 BOPSUp P 12:00 - 13:00 1.00 BOPSU~ P 13:00 - 18:30 5.50 BOPSU P 18:30 - 21:00 I 2.501 BOPSUR P 21:00-21:30 I 0.501 WHSURIP 21:30 - 23:00 I 1.501 PULL I P 23:00 - 00:00 ~ 1.00 ~ PULL ~ P DECOMP nippling up. DECOMP Nipple up BOPE. Break 7-1/16" spacer spool off of master valve, install on top of 3-1/2" tubing hanger, install 7-1/16" x 13-5/8" DSA spool. Break spacer spool off of stack below mud cross, remove BOP bolts from spacer spool. Lower set of variables were removed from the BOP stack so it would fit in the cellar on top of the tall wellhead. Set and secure BOP's. DECOMP Continue to nipple up BOPE. Install the following: - Riser - Turn buckles - Choke and Kill lines - Drain lines - Test joint DECOMP Rig up BOP test equipment. DECOMP Pressure test BOPE to 250 psi low, 4000 psi high for 5 minutes. - WSL Bill Decker and ToolPusher Dave Hanson to witness. - AOGCC Chuck Shieve waived witness. - No failed tests. DECOMP PJSM, Prep to pull hanger: - Rig down test pump. - Install elevators. - Apply steam to lock down screws /tubing hanger. - Pick up tubing handling equipment. - Service rig - Rig up Hot Oil truck to OOA DECOMP PJSM was held and the pump-in test of the OOA (9-5/8" x 13-3/8" annulus) was conducted. - Pressure test to lines to 300 psi low, 3500 psi high. - Starting IAP 0 psi, OAP 20 psi, OOAPP 20 psi - Pump diesel down OOA at 0.5 bpm as per the following schedule. TIME BPM BBLS PSI 1 min 0.5 0.7 100 1 min 0.5 1.0 300 1 min 0.5 1.6 900 1 min 0.5 2.0 1500 1 min 0.5 2.4 2000 1 min 0.5 2.8 2500 1 min 0.5 3.0 2700 - A total of 3 bbls were pumped to a final pressure of 2700 psi. -The pressure was monitored for 5 minutes with minimal bleedoff (suspect bleedoff through the pump). - Final pressures after Hot oil was rigged down and OOAP pressure bled down: IAP 0 psi, OAP 20 psi, OOAP 34 psi. DECOMP -PJSM. Rig up lubricator. -Pull TWC. Monitor well. Well on a vacuum. IAP 0 psi. - Rig down lubricator. - Pick up landing joint. 8-3/4 turns to screw into hanger - Back out lock down screws. - Pull hanger to the floor with 112k up weight (bouyed wt estimated at 110k). No evidence of fill or partial cut. DECOMP -Establish returns pumping at 3.5 bpm. Printed: 1/29/2007 9:39:59 AM • BP EXPLORATION Operations Summary Report Page 3 of 19 Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E From - To Hours Task i Code NPT Phase Description of Operations Date I -- ~~ - --- - - - _ _ _ _ _ - - --__ 7/18/2006 23:00 - 00:00 1.00 PULL P DECOMP -Caught returns at 26 bbls, 1300 psi. - Send 20 bbls contaminated fluid to cuttings box. - Close system and pump 1 drum of Safe Surf-O. - Circulate at 3.5 bpm, 1000 psi. - Losing fluid, decrease pump to 2.5 bpm, 655 psi. 7/19/2006 00:00 - 01:30 1.50 PULL P DECOMP Continue circulating across the top to verify loss rate at -30 bph static. 01:30 - 02:30 1.00 PULL P DECOMP PJSM. Rig up equipment for pulling tubing. 02:30 - 03:30 1.00 PULL P DECOMP UD hanger and Pull 6 joints of 3-1/2" 9.3 ppg L-80 tubing. 0 losses ~ this time. 03:30 - 05:30 2.00 PULL N RREP DECOMP Replace brake pad on drawworks. - Secure well with TIW valve MU to top drive. - Fluid loss has diminished, No losses at 05:00 hrs. 05:30 - 22:00 16.50 PULL P DECOMP Pull 254 joints of 3-1/2" 9.3 ppg L-80 tubing. Cut joint 15.27' 22:00 - 22:30 0.50 PULL P DECOMP R/D tubing handling equip. 22:30 - 23:00 0.50 DHB P DECOMP Clean floor ands service TD 23:00 - 00:00 1.00 DHB P DECOMP R/U to run 3 1/2" DC's **Clean up oil under Pipe skate, (hyd. fluid contain in barrier) 7/20/2006 00:00 - 01:30 1.50 DHB N RREP DECOMP Repair loose hose on pipe skate and cleanup Hyd. fluid 01:30 - 05:30 4.00 DHB P DECOMP PJSM & P/U 16 Jts 3 1/2" DCs and HES Storm Packer RIH w/ 3 1/2" Tbg and set packer ~ 89'. Release from packer. POH w/ Tbg & setting tool. 05:30 - 06:30 1.00 DHB P DECOMP - RU & test storm packer to 3100 psi for 5 mins. - Bleed off and Monitor well for 30 mins. No flow. 06:30 - 07:30 1.00 DHB P DECOMP Install FMC BPV. 07:30 - 10:00 2.50 DHB P DECOMP - P/U DSM Lubricator. - Test BPV with 1500 psi. Good test. - Bleed off pressure above BPV. - Monitor pressure with gauge. No pressure leaking by BPV. - Pressure up above BPV to 1000 psi. -Open BPV poppit, observe increase in lubricator pressure, indicating BPV held from below. 10:00 - 18:00 8.00 BOPSU P DECOMP N/D BOPE's, Choke & Kill Lines. Remove tubing spool. Make up single gate pipe ram to BOP stack. 18:00 - 19:00 1.00 BOPSU P DECOMP Clean ACME threads of 5-1/2" tubing hanger. Install FMC Blank Plug - 6 3/4 LH turns. 19:00 - 21:00 2.00 BOPSU P DECOMP Work on lock down screws on 5 1/2" x 9 5/8 spool. Unable to work 12 lockdown screws. Charge void with penetrrating oil ~ 1500 psi and let soak. 21:00 - 00:00 3.00 BOPSU P DECOMP N/U BOPs, choke and kill lines 7/21/2006 00:00 - 04:00 4.00 BOPSU P DECOMP Continue NU BOPE, choke line, Kill line, drilling nipple & flowline. 04:00 - 10:30 6.50 BOPSU P DECOMP *Test Annular to 250 psi low / 3500 psi high -Good test *Repair small leak found in flange between lower pipe rams and drilling spool *Test Upper Pipe rams to 250 psi low / 4000 psi high -Good test *Atempt to test Lower Pipe rams -unable to get 250 low test - tested high to 4000 ppsi -OK Printed: 1/29/2007 9:39:59 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-126 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT 7/21/2006 04:00-10:30 ~ 6.50 BOPSUF-P 10:30 - 12:00 1.50 DHB P 12:00 - 13:00 1.00 DHB P 13:00 - 14:00 1.00 DHB P 14:00 - 17:00 3.00 DHB P 17:00 - 19:00 2.00 PULL P 19:00 - 21:00 I 2.001 PULL I P 21:00 - 00:00 I 3.001 PULL I P 7/22/2006 00:00 - 02:00 2.00 I PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 05:00 2.00 PULL P 05:00 - 10:00 I 5.001 PULL I P 10:00 - 10:30 I 0.501 PULL I P 10:30 - 19:30 I 9.001 PULL I P Start: 7/15/2006 Rig Release: 8/18/2006 Rig Number: 27E Page 4 of 19 Spud Date: 7/31 /2006 End: 8/18/2006 Phase ' Description of Operations DECOMP *Test blinds and lower rams to 250 low and 4000 high -Good test Re attempt to get low test on lower rams .leaking past 5 1/2" tubing hanger into annulus. Spoke with John Crisp, AOGCC and explained anomalus situation. John gave permiission to proceed. We will re-test annular and rams w/ test plug after getting tubing out of well. DECOMP R/U and pull blanking plug in 5 1/2" hanger DECOMP R/U lubricator, Pull BPV, UD lubricator DECOMP Rig up power tongs and handling equip. Run into hole with 1 stand of 3 1/2" tubing DECOMP *Screw into storm packer *Make up top drive and check for pressure - no pressure *Release packer *Ud 3 1/2" tubing DECOMP Clear floor and rig up to pull 5 1/2" hanger and tubing DECOMP *M/U landing joint and top drive *Pulled on 5 1/2" to 210k, pulled free and broke back to 185k PUW *Pulled hanger to floor DECOMP *Lower hanger below annular and close Bag *Pump through choke and gas buster to pit ~ 4 bbl/min / 130 psi *40 bbl +/- of diesel containment mud *circ. surface to surface through choke *Shut down and open bag, well static *circ. ~ 15 bbl/ min / 530 psi DECOMP *Finish Full circ. ~ 15 bbl/min / 530 psi *Slowed pumps 03800 strokes to 10 bbls/min -due to minor gas on bottoms up *finish full Ciro. *Monitor well, well dropping in annulus / 10- psi on tubing *Circ.full circulation ~ 15 bbl/min 530 psi *Monitor well, well static DECOMP UD 5 1/2" landing joint DECOMP *Clear floor of extra equip. * Change bails, *R/U Camco control line spooler DECOMP PJSM, UD 51 jts. of 17# 5 1/2" casing & Spoof SSSV control line *2 bands and 27 clamps on control line DECOMP *Rig SSSV control line spooler UD SSSV DECOMP PJSM, UD 131 joints of 17# 5 1/2 casing *Perf hole in Joint # 75 19:30 - 20:30 1.00 PULL P DECOMP Service Drawworks and Top Drive 20:30 - 21:00 0.50 PULL N RREP DECOMP Repair split ring on Top Drive compensator 21:00 - 23:00 2.00 PULL P DECOMP *Continue UD 7 joints of casing, 3 1/2" tubing stub in Joint # 190 *M/U joint #189 and lower to floor *R/U and circ 5 1/2" casing volume Printed: 1/29/2007 9:39:59 AM • • BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To ~ Hours ' ' Task ~ Code' NPT Phase Description of Operations - - 7/22/2006 21:00 - 23:00 -_ - 2.00 PULL _- P DECOMP - -_- PJSM 23:00 - 00:00 1.00 PULL P DECOMP *UD joint # 189 *Fish Slick line junk, Qunk 4" long wedged between 5 1/2" casing and 3 1/2" tubing 3 1/2" tubing stub) *Prepare floor for wireline operations 7/23/2006 00:00 - 01:00 1.00 PULL P DECOMP PJSM Spot truck and prep tools for run 01:00 - 02:00 1.00 PULL P DECOMP PJSM, R/U SWS RU to SWS pump in sub circulating line and pressure gauge to monitor well after perforating 3 1/2" tubing 02:00 - 02:30 0.50 PULL P DECOMP RIH w/SWS tubing punch and CCL * Correlated collars and place tubing punch below 3 1/2" x 5 1/2" packer *Perf. tubing @ 428-430' Monitor tubing for pressure, No Presure Circulated 2X Casing volume Check for pressure, Well static 02:30 - 03:30 1.00 PULL P DECOMP Laydown tubing punch and Rig Up tubing cutting tool 03:30 - 04:30 1.00 PULL P DECOMP RIH w/SWS Jet cutter, CCL * Correlated collars and place SCP jet Cutter above 3 1/2" x 5 1/2" packer *Shoot off 3 1/2" tubing ~ 419', (3 1/2" pup joint above packer) *Circ. Casing volume 10 min. and check well, well static 04:30 - 05:00 0.50 PULL P DECOMP Rig down SWS and clear floor. Prep floor to pull 3 1/2" tubing 05:00 - 05:30 0.50 PULL P DECOMP PJSM with BOT fishing hand and rig crew R/U false table and power tongs Spear 3 1/2" tubing 05:30 - 09:00 3.50 PULL P DECOMP Pull 12 jts.of 3 1/2" tubing out of 5 1/2" casing, 1 gas lift mandrel, and 1 short shot joint 09:00 - 09:30 0.50 PULL P DECOMP Rig down BOT false table and fishing equip. 09:30- 11:30 2.00 PULL P DECOMP Lay down 10 joints of 5 1/2" 17# L-80 casing *UD seal assembly & joint with 3 1/2" packer and 3 1/2 cut jt. *200 total joints retrieved, 11:30 - 12:00 0.50 PULL P DECOMP Rig down floor of tubular handling equip. 12:00 - 13:30 1.50 BOPSU P DECOMP PJSM, Flush stack with wash tool 13:30 - 16:00 2.50 BOPSU P DECOMP PJSm, R/U to test and set test joint 16:00 - 17:30 1.50 BOPSU P DECOMP PJSM, test ROPE to 250 low / 4000 high Printed: 1/29/2007 9:39:59 AM • • BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: 1 Common Well Name: 1 Event Name: Contractor Name: Rig Name: Date From - To 5-12 5-12B REENTE NABOBS NABOBS Hours R+COM ALASK 27E Task PLET A DRI Code E LLING NPT ! Spud Date: 7/31/2006 Start: 7/15/2006 End: 8/18/2006 I Rig Release: 8/18/2006 Rig Number; 27E ~ Phase Description of Operations - - 7/23/2006 16:00 - 17:30 1.50 BOPSU P DECOMP *witness of test waived by John Crisp (AOGCC) 17:30 - 18:00 0.50 BOPSU N SFAL DECOMP Repair leak on choke hose 18:00 - 22:00 4.00 BOPSU P DECOMP Test BOPE *Test Annular to 250 / 3500 psi, *Test upper and lower set of pipe rams to 250 / 4000 psi * Choke manifold 250 / 4000 psi *IBOP and surface safety valves to 250 / 4000 psi All test held 5 min. / no failed tests John crisp, AOGCC, waived witness of test. Test witnessed by Dave Newlon, BP WSL and Dave Richards, NAD Tourpusher. 22:00 - 00:00 2.00 BOPSU P DECOMP Pull test plug and X/O's *Test Floor Safety vavle Install wear bushing 7/24/2006 00:00 - 01:30 1.50 BOPSU P DECOMP Finish setting Wear bushing, Clear floor of test equipment Blow down choke manifold and top drive Rig rig tongs and Iron Roughneck for P/U BHA and DP Pick up XO's, Scraper and mills from outside Strap BHA and measure all ID/ OD's 01:30 - 03:00 1.50 CLEAN P DECOMP PJSM M/U 9 5/8" casing scraper assembly Taper guide mill, watermelon mill, 9 5/8' casing scraper, XO's 03:00 - 16:00 13.00 CLEAN P DECOMP P/U 4' DP ,single in to 8188' 16:00 - 16:30 0.50 CLEAN P DECOMP Precautionary Wash 3 jts 8188' -_> 8287' staging up to 5 bbl/min C~1 400psi 16:30 - 18:30 2.00 CLEAN P DECOMP Stage pumps up to 14 bbl/min, ~ 2460 psi, Pump 30 bbl Hi-vis sweep w/super sweep and chase w Safe Surf O Pump ~ 18 bbl/min / 3000 psi S/S 1.5 x 18:30 - 19:00 0.50 CLEAN P DECOMP Monitor well, Well static loss ~ 11 bbl/hr 19:00 - 20:00 1.00 CLEAN P DECOMP Monitor well, Well static loss @ 11 bbl/hr 20:00 - 22:00 2.00 CLEAN P DECOMP PJSM, Hang blocks and curt drilling line Inspected and adjust drawwork brakes 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM and POOH from 8287 =. 4454' 7/25/2006 00:00 - 02:00 2.00 CLEAN P DECOMP POOH => 2377' Hole not taking proper fill, stop and Monitor Hole, losing slightly 02:00 - 03:00 1.00 CLEAN P DECOMP Circulate bottoms up to clear BHA of any possible restrictions Stage pumps up slowly to 15 bbl/min ~ 1100 psi well taking fluid slight) Monitor well, static losses .8 bbl/min but slowed to static after a few minutes. Losses leveled off C~3 4 - 6 bbls / hr. 03:00 - 05:00 2.00 CLEAN P DECOMP POOH and UD Scraper BHA 05:00 - 06:00 1.00 EVAL P DECOMP R/U to SWS wireline 06:00 - 12:00 6.00 EVAL P DECOMP PJSM, Run USIT logs on E-Line, Circ. across top to trip tank to monitor well Losses @ 7 bbl / hr 12:00 - 16:00 4.00 EVAL P DECOMP PJSM with SWS crew Load firing head and EZSV, RIH to 8284' wireline depth Set EZSV @ 8287' MD (3' below wireline depth) 16:00 - 17:00 1.00 EVAL P DECOMP PJSM, Rig Down Wireline and clear floor 17:00 - 20:30 3.50 CASE P DECOMP PJSM, w/ Rig crew and HES Tool hand, Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To !, Hours Task 'Code NPT Phase Description of Operations - - ---- ~ 17:00 - 20:30 ~ 3.50' - -- - - _ - - __ 7/25/2006 1 ~ CASE P DECOMP RIH => 3200' 20:30 - 21:30 I 1.001 CASE I P 21:30 - 22:00 ~ 0.50 ~ CASE ~ P 22:00 - 23:00 I 1.001 CASE I P 23:00 - 00:00 I 1.001 CASE I P 7/26/2006 00:00 - 00:30 0.50 CASE P 00:30 - 01:30 1.00 CASE P 01:30 - 02:00 0.50 CASE P 02:00 - 02:30 0.50 CASE P 02:30 - 04:00 I 1.501 CASE I P 04:00 - 04:30 0.50 CASE P 04:30 - 08:00 3.50 PULL P 08:00 - 08:30 0.50 ZONISO P 08:30 - 10:00 1.50 ZONISO X 10:00 - 11:00 1.00 ZONISO P 11:00 - 12:00 1.00 ZONISO X Set RTTS (20k set down ) DECOMP R/U to test from 3200' to surface, Pressured up to 3500 psi and shut in Monitor for 30 min. ,Good test DECOMP Test below RTTS 1 bbl /min pressure stabilized C~ 480 psi, Stop pumping / 2 bbls total pump Pressure bled to zero in 5 minutes DECOMP RIH => 5290' D-1 BOP drill DECOMP Set RTTS ~ 5290' Test below 1 bbl/min ~ 500 psi, Bled down to zero pressure in 5 minutes Pressure up from 5290 => surface, good test, Held 3500' psi for 10 min. DECOMP RIH 11 stands from 5290 => 6326' DECOMP Test below, good test for 30 min. @ 3500 psi Pressure up between 6326' and EZSV C~3 8287' Leak between 5290 => 6326' DECOMP POH 5 stands => 5855' DECOMP Test below RTTS C~? 5855' Leak off @ 1 bbl /min @ 500 psi Leak 5855' _> 6326' DECOMP RIH 1 stand to 5957' and test below, GOOD test Pull up 60' to 5894' test below RTTS, GOOD test Pulled up to 5865 to test above leak, found leak still above 5865' Pulled up to previous depth of 5855' Test 5855' _> surface, Good test for 30 min @ 3500 psi Leak is 5855 => 5865' DECOMP ~ Release RTTS, Monitor well, well losing 4 bbl/hr static DECOMP POH w/RTTS tool and Laydown DECOMP PJSM, R/U to run EZSV on SWS wireline DECOMP Consult with Anchorage rig team on options to remediate casing leak Heated brine in 2 pits (started 09:45 hrs) DECOMP M/U EZSV on SWS wireline and run into to hole DECOMP New plan forward from town, Cement abandoment plug on top of EZSV at 8287' Printetl: 1/29/2007 9:39:59 AM BP EXPLORATION Operations Summary Report Page 8 of 19 Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours Task Code ~ NPT i Phase Description of Operations 7/26/2006 11:00 - 12:00 1.00 ZONISO X DECOMP Aborted run and POH with EZSV & R/D SWS wireline 12:00 - 14:00 2.00 PXA X DECOMP Mobilize 3 1/2" tubing work string Perform rig maintenance and service Top Drive 14:00 - 17;30 3.50 ZONISO P DECOMP PJSM, R/U tubing handling equip. P/U 10 jts of 3 1/2" NSCT tubing 17:30 - 20;00 2.50 ZONISO P DECOMP RIH with tubing stinger, Tag EZSV ~ 8291' 20:00 - 21:30 1.50 ZONISO P DECOMP Set Back 1 stand and space out to place mule shoe ~ 8282' R/U cement hose and valves on to 4" DP 21:30 - 22:30 1.00 ZONISO P DECOMP Stage up pumps to 8 bbl/min (1250 psi) Monitor loss, 4 bbl /hr static and 10 bbl/hr whilst pumping 22:30 - 23:15 0.75 ZONISO N WAIT DECOMP Waited on heated water truck, unable to get designated truck due to .high activity, Continue to Circ. whilst waiting 23:15 - 00:00 0.75 ZONISO P DECOMP PJSM with cementing crew and rig crew @ Pre-tour meeting 7/27/2006 00:00 - 00:45 0.75 ZONISO P DECOMP Flush lines and pressure test cement lines to 4000 psi Pump 15 barrels of water spacer ahead Pump 15 bbls of 15.81bs/gal. class G cement Chase lines with 2.8 bbls. of water to flush lines 00:45 - 01:15 0.50 ZONISO P DECOMP Line up to rig pumps ,displaced cement with 78 bbl of 9.8 brine ~ 7.5 bbl/min slowed rig pumps to 4 bbl/min for last 10 bbl CIP ~ 01:05 hrs 01:15 - 01:30 0.25 ZONISO P DECOMP POH 600' to 7679 01:30 - 02:15 0.75 ZONISO P DECOMP Circulate pipe clean Q 15 bbl/min & 2400 psi Total of 6000 pump strokes No indication of cement or contaminated returns 02:15 - 05:00 2.75 ZONISO P DECOMP Monitor well - .5 bbls lost POH with 3 1/2" cement stinger => 2500'md 05:00 - 08:30 3.50 WHSUR P DECOMP Circulate 120 degree brine ~ 2500' MD Circ. @ 2-3 bbls /min after displacing annulus volume 08:30 - 10:00 1.50 ZONISO P DECOMP POH to 3 1/2" Tubing work string 10:00 - 11:30 1.50 ZONISO P DECOMP Lay down 3 1/2" work string /cement stinger 11:30 - 14:00 2.50 EVAL P DECOMP Rig up SWS a-line Run #1- 8.5" gauge ring /Junk basket to 5770' (junk basket had 1 small rock) 14:00 - 16:30 2.50 EVAL P DECOMP Run #2 - 9 5/8" EZSV plug, RIH & set ~ 5662' a-line MD Setting tool and CCL 16:30 - 17:15 0.75 ZONISO P DECOMP Test EZSV 3500 psi f/30 minutes (90 psi drop over thirty minutes) 17:15 - 18:00 0.75 EVAL P DECOMP R/D SWS and ready floor to P/U DP 18:00 - 22:30 4.50 DHB P DECOMP PJSM, P/U 92 jts of 4" HT DP, 22:30 - 23:00 0.50 ZONISO P DECOMP Service rig, Top Drive and Drawworks 23:00 - 23:30 0.50 DHB P DECOMP P/U 10 jts of 4" HT DP, Total of 102 joints of DP 40k string wt. "ALL DP for drilling picked up" Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date !From - To ~ Hours Task Code I NPT Phase Description of Operations f 7/27/2006 123:30 - 00:00 ~ 0.50 DHB ~ P ~ DECOMP P/U storm packer 7/28/2006 100:00 - 01:00 I 1.001 DHB I P 01:00 - 01:30 0.50 DHB P 01:30 - 02:30 1.00 DHB P 02:30 - 03:00 0.50 BOPSUFj P 03:00 - 05:00 2.00 BOPSU P 05:00 - 07:30 ~ 2.50 ~ W HSUR ~ P 07:30 - 09:30 I 2.001 WHSUR I P 09:30 - 10:00 0.50 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 16:30 5.50 BOPSU P 16:30 - 17:00 0.50 BOPSU P 17:00 - 18:00 I 1.001 BOPSUR P 18:00 - 19:00 I 1.001 BOPSUR P 19:00 - 21:30 I 2.501 DHB I P Change elevators and XO's to Storm Packer DECOMP Pick up X/O's, 2 JTS of DP and make up Storm Packer Kelly up to top Drive DECOMP Set Storm packer @ 35' MD, 40k hanging UD 2 joints of DP DECOMP PJSM with rig crews and HES Tool hand on testing storm packer *Test between Blind Rams and Storm packer to 3500 psi Chart test for 30 min. During Pressure test duration, conducted pre-job meeting on Tubing spool change out. Attendees: FMC wellhead tech, rig crews, tour pusher and BP WSL DECOMP Blow out Choke lines, Kill Lines, Drain stack 'Pull Wear bushing DECOMP De-energized BOPE & accumulator, Pull wear bushing, Pull drip pan cover, Pull drilling nipple, Latch onto BOP stack with bridge Cranes, release turn buckles DECOMP Lift BOP stack with tubing spool attached. Remove Spool and pack off Install VR plug and remove Lower OA valve DECOMP PJSM, Install new Lower OA valve Install 9 5/8" pack off Install New tubing Spool Test lower OA valve to 5000 psi. Held Remove VR plug with lubricator Torque bolts on Tubing spool DECOMP Test 9-5/8" pack off and casing head flange to 5000 psi, for 20 mim. Good test DECOMP Install secondary annulus valve, DECOMP Set stack, N/U drilling nipple and flowline, Hook up turn buckle , install drip pan covers, drain lines and secure cellar DECOMP Set Test plug and seat Fill stack,choke and kill lines Check for leaks DECOMP Body test Stack and flanges from Blind rams to test plug Tested to 250 psi low for 5 mins. / 4000 psi high for 5 mins. Good Test Witness of test Waived by John Crisp AOGCC Witness by Dave Newlon (WSL) and Rick Brumley (tourpusher) DECOMP Pull test plug and set wear bushing DECOMP ~ P/U strom packer running tool, XO's, 1 x Dp& pup jt. Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date -- Name: 1 ell Name: 1 e: Name: From - To 5-12 5-12B REENTE NABOB NABOB Hours R+COM S ALASK S 27E Task _ PLET A DRI Code _ i E LLING NPT ~ _ I Start I Rig Rig Phase __ Spud Date: 7/31/2006 : 7/15/2006 End: 8/18/2006 Release: 8/18/2006 Number: 27E Description of Operations -- __ 7/28/2006 19:00 - 21:30 - 2.50 DHB P DECOMP - RIH and tag storm packer , 22 turns to right to screw and release tool POH with Storm Packer and lay down 21:30 - 22:00 0.50 DHB P DECOMP Clear floor of extra handling equip. and subs 22:00 - 00:00 2.00 DHB P DECOMP POH w/34 stands of 4" HT DP used for weight below storm packer 7/29/2006 00:00 - 00:30 0.50 STWHIP P WEXIT PJSM, Clear Floor P/U drill collar handling subs, Slips and Elevators 00:30 - 03:30 3.00 STWHIP P WEXIT M/U 9 steel 6 1/4" DC's and stand back in derrick (pipe skate operating slowly picking up DC's ) 03:30 - 04:30 1.00 STWHIP P WEXIT P/U BOT whipstock and M/U mills and 1 jt. of HWDP 04:30 - 06:30 2.00 STWHIP P WEXIT M/U Halliburton MWD and plug-in 'Comm issue with download, total time 1 hr. 06:30 - 07:00 0.50 STWHIP P WEXIT Orient Mwd & whipstock, P/U whipstock and attach to starting mill 07:00 - 08:00 1.00 STWHIP P WEXIT RIH with 3 stands of DC's 08:00 - 10:00 2.00 STWHIP P WEXIT RIH P/U 21 jts of 5" HWDP 1x1 10:00 - 10:30 0.50 STWHIP P WEXIT Shallow Hole Pulse test of MWD, Tested O.K. 10:30 - 12:30 2.00 STWHIP P WEXIT RIH Q 120'/min to 3576' 12:30 - 13:00 0.50 STWHIP P WEXIT Break circ. 110 stks / 1350 psi Pump 50 bbls total 13:00 - 14:00 1.00 STWHIP P WEXIT RIH @ 120'/min to 5621' 14:00-15:00 1.00 STWHIP P WEXIT Break circulation 110 stkd / 1000 psi PUW - 160 /SOW - 150 Orient Whipstock to 45 deg Right of Highside 15:00 - 15:30 0.50 STWHIP P WEXIT Tag top of EZSV Q 5659' Set down 20k and trip anchor, Pull 10k over PUW, anchor secured, Slack off and shear lug with 35k TOW =5637 /BOW=5654 15:30 - 16:30 1.00 STWHIP P WEXIT Displace to 9.0 ppg LSND milling fluid Pump 30 bbl. spacer and 460 bbl of milling fluid 16:30 - 17:00 0.50 STWHIP P WEXIT Establish parameters f/window milling operation 110 stks / 1200 psi ! Obtain SPR's 17:00 - 23:30 6.50 STWHIP P WEXIT Mill window from 5637 to 5654', pumped 150 visc sweep, drill new formation to 5 66, PUW=165k, SOW=135k, RW=155k, 100 rpm's, 460 gpm at ~'Z, ' 1250 psi, 5k WOB, 25% increase in cuttings when sweep ~C~~ 'a.. ~O returned. TOW - 5637' /BOW - 5654' 23:30 - 00:00 0.50 STWHIP P WEXIT Ream back through window without obstructions Dry run through window, no obstructions Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date i From - To Hours I Task ~ Code j NPT ~ Phase ' Description of Operations 7/29/2006 ~ 23:30 - 00:00 0.50 ~ STW HIP ~ P ~ WEXIT 7/30/2006 100:00 - 01:00 ( 1.00 I STWHIPI P 01:00 - 02:00 ~ 1.00 STWHIPI P 02:00 - 03:00 I 1.001 STWHIPI P 03:00 - 04:30 I 1.501 STWHIPI P 04:30 - 07:00 I 2.501 STWHIPI P 07:00 - 07:30 0.50 STWHIP P 07:30 - 09:00 1.50 STWHIP P 09:00 - 10:00 1.00 STWHIP P 10:00 - 11:00 1.00 STWHIP P 11:00-12:30 1.50 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00 - 14:00 1.00 STWHIP P 14:00 - 14:30 0.50 STWHIP P 14:30 - 16:30 2.00 STWHIP P 16:30 - 17:00 0.50 STWHIP P 17:00 - 18:00 1.00 STWHIP P 18:00 - 19:00 1.00 STWHIP P 19:00 - 20:00 1.00 STWHIP P 20:00 - 20:30 0.50 STWHIP P 20:30 - 22:00 1.50 STWHIP P 22:00 - 22:30 0.50 STWHIP P 22:30 - 23:00 I 0.501 DRILL I P Pump 30 bbl super sweep and circ hole clean C~ 460 gpm and 85 rpm WEXIT Circulated & condition mud f/FIT 9.2 in/out (15% increased above normal when super sweep returned) Monitor well, static after 30 min PJSM on FIT WEXIT Attempt to Perform FIT to 12.1 EMW (820 psi) Hole Depth 5666' MD / 5436' TVD Unable to get 12.1 FIT, Pressure up to 600 psi, equates to 11.3 ppg EMW WEXIT MWD /Mad pass log f/ 5627 - 5527' to tie-in geological logs no rotation , 110 stroke /min , 460 gpm/ 1200 psi Running speed @ 300'/hr WEXIT Monitor well, static no loss, no gain Clean out suction on Mud Pumps, Suction screens 60% blinded with super sweep Pump dry job WEXIT POH w/ window milling assembly WEXIT Change Elevators and stand back 5" HWDP WEXIT L/D 9 - 6 1/4" steel DC's WEXIT Service Rig and Top Drive WEXIT L/D Bumper Jars, XO's, and Mills Top Mill full gauge WEXIT Download MW D data, Lay down tools and clear floor WEXIT Pull wear bushing WEXIT P/U wash tool to flush stack, Wash and Rotate through stack and Mud cross UD wash tool WEXIT Set wear bushing and lock down WEXIT Pick BHA and ready floor for picking up BHA M/U BHA / M/U Halliburton Mud motor and re-set bend from 1.5 => 1.22 AKO WEXIT Plug into MWD and program tool WEXIT P/U flex DC's and RIH w/HWDP => 810'md WEXIT Shallow hole test MWD, Tested O.K. 460 gpm = 890 psi WEXIT RIH to 3664, hole fill showing slight loss, slowed running speed showed correct displacement WEXIT Break circ. /fill DP 460 gpm = 1280psi WEXIT RIH => 5617, NO Loss ~ slower tripping speed WEXIT Estabilish parameters and set depth Orient to 45 right of high side @ 340 gpm 1000 psi slide through window, No pump or rotation, Clean window, no issues getting through - Tag ~ 5658' PUW - 145k ,SOW 135k INT1 Ream under gauge hole from 5658 - 5666', Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 15-i2 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours ~ Task ~ Code NPT Phase !I Description of Operations 7/30/2006 22:30 - 23:00 0.50 ~ DRILL P ~ INT1 No rotation, 420 gpm / 1300 psi 23:00 - 00:00 1.001 DRILL P 7/31/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 01:00 0.50 DRILL P 01:00 - 01:30 0.501 DRILL P 01:30 - 03:00 I 1.501 DRILL I P 03:00 - 03:30 I 0.50 f DRILL I P 03:30 - 12:00 I 8.501 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 8/1/2006 100:00 - 15:00 I 15.001 DRILL I P 15:00 - 00:00 I 9.001 DRILL I P 8/2/2006 100:00 - 07:30 I 7.501 DRILL I P 07:30 - 10:00 I 2.501 DRILL I P 10:00 - 11:00 I 1.001 DRILL I P Drill oriented from 5666 - 5686' 420 gpm / 1300 psi / 4-6k WOB INT1 Pull back up into casing above window and circulate hole clean INTi Circ. hole clean. / 9.2 ppg mud wt. in and out INT1 Monitor well, Static PJSM with WSL, Tour pusher and rig crew INT1 Attempt to Perform FIT to 12.1 EMW (820 psi) Hole Depth 5637' MD / 5410' TVD Unable to get 12.1 FIT INT1 Circulate and condition mud. Consult with Anchorage rig team on Drilling plan forward Verify precautions on drilling with 11.3 EMW FIT INTi Establish clean hole ECD's C~3 420 gpm /zero rotation/ 9.2 ppg mw ECD = 9.57 EMW INT1 Directional drill from 5686 - 6311'. PUW 155k, DW 140k, RW 145k,460 gpm @ 1700 psi, WOB 5-10k, TO on 4k, TO off 3k, RPM's 100, MW 9.2 ppg in/out. /ECD ceiling of 10.1 ppg Calculated ECD = 9.5 / PWD ECD 9.7 INT1 Directional drill from 6311- 7314'. PUW 165k, DW 155k, RW 155k, 500 gpm C~ 1975 psi off, 2300 psi on WOB 5-16k, TO on 5k, TO off 4k, RPM's 100, MW 9.1 ppg in/out. /ECD ceiling of 10.1 ppg Calculated ECD = 9.54 / PW D ECD 9.8 INT1 Directional drill from 7,314'- 8,194'. UW 175k, DW 160k, RW 165k, 500 gpm ~ 2,600 psi off, 2,900 psi on WOB 5-16k, TO on 4k, TO off 3.5k, RPM's 100, MW 9.2 ppg in/out. Calc ECD = 9.6 /ACT ECD = 10.0 INT1 Directional drill from 8,194' to 8,631'. (Raise mud wt to 10.5 ppg with 14.0 ppg spike fluid at 450 gpm.) UW 180k, DW 165k, RW 172k, 500 gpm C~ 2,800 psi off, 3,125 psi on WOB 5-16k, TO on 4k, TO off 3.5k, RPM's i00, MW 10.6 ppg in/out. Calc ECD = 10.8 /ACT ECD = 11.04 INT1 Directional drill from 8,631' to 8,957'. UW 200k, DW 162k, RW 172k, 500 gpm @ 2,800 psi off, 3,125 psi on WOB 5-16k, TO on 4k, TO off 3k, RPM's 100, MW 10.6 ppg in/out. Calc ECD = 10.8 /ACT ECD = 11.17 {At 8,700' we saw an increase in flow. We monitored the well 15 minutes, no flow. Mud was gas cut from 10.6 ppg to 9.6 ppg, no gain in pits. Assume a gas bubble from the Put River formation.) Pumped sweep at 05:30, YP 45, 10% cuttings increase. INT1 Circulate sample up for geology to verify 7" drilling liner TD. 420 gpm @ 2,330 psi, 80 rpm's, 3k torq, UW 200k, DW 162k, RW 172k, MW 10.5 ppg in/out. INTi Monitor well, empty trip tank. Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date i From - To Hours Task i Code'; NPT Phase Description of Operations 8/2/2006 111:00 - 16:00 I 5.001 DRILL I P I I INT1 16:00 - 17:30 1.50 DRILL P INT1 17:30 - 18:30 1.00 DRILL P INT1 18:30 - 22:00 3.50 DRILL P INT1 22:00 - 22:30 0.50 DRILL P INT1 22:30 - 00:00 1.50 DRILL P INT7 8/3/2006 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P ~ ~ INT1 01:30 - 06:00 I 4.501 DRILL I P I I INT1 06:00 - 06:30 0.50 DRILL P INT1 06:30 - 07:30 1.00 DRILL N RREP INT1 07:30 - 09:30 2.00 DRILL P INT1 09:30 - 10:30 1.00 DRILL P INT1 10:30 - 14:00 3.50 DRILL P INT1 14:00 - 15:30 1.50 CASE P LNR1 15:30 - 16:30 1.00 CASE P LNR1 16:30 - 17:00 0.50 CASE N MISC LNR1 17:00 - 00:00 7.00 CASE P LNR1 8/4/2006 ~ 00:00 - 02:30 2.50 ~ CASE I P LNR1 02:30 - 03:30 ( 1.001 CASE I P I I LNR1 03:30 - 05:30 2.00 CASE P LNR1 05:30 - 07:00 1.50 CASE P LNR1 07:00 - 10:00 3.00 CASE P LNR1 10:00 - 11:00 1.00 CASE P LNR1 11:00 - 12:30 1.50 CASE P LNR1 12:30 - 13:30 1.00 CASE P LNR1 13:30 - 14:00 0.50 CEMT P LNR1 POH to 6,400' with no problems. From 6,400' to 5,992 we had to backream and pump out of the hole due to pulling tight. Continue POH from 5,992' to the window with no problems. UW 160k, DW 140k, 375 gpm at 1,750 psi, ECD 11.1 ppg. Cut and slip drilling line. Rig service. TIH at 2 minutes/stand to 8,957'. No drag seen, hole in good shape. Stage pumps up from 200 gpm to 500 gpm in 50 gpm increments every 5 minutes. Pump High visc sweep with 45 YP, circulate and condition mud. 10% increase in cuttings. UW 200k, DW 165k, RW 172k, 490 gpm C~? 2,750 psi, CECD 10.83, AECD 11.18. Circulate and condition mud. Circulated a total of 4 bottoms up. UW 200k, DW 165k, RW 172k, 490 gpm ~ 2,750 psi, CECD 10.83, AECD 11.11, MW 10:5 ppg in/out. Monitor well 10 minutes, drop rabbit with 100' tail, POH to window with no problems, monitor well 10 minutes at window, POH to 5" HWDP. Monitor well 10 minutes, hold PJSM for laying down bha. Repair pipe skate. Lay down XO, 14 jts HWDP, jar, 6 jts HWDP, and 3 NMDC's. Download MWD data. Lay down MWD, stab, float sub, mud motor, and bit. Clear and clean rig floor. Hold PJSM and rig up to run 7" drilling liner. Service rig while replacing flow line air boot. Finish replacing air boot in flow line. Pick up and Bakerloc shoe track, fill pipe, pick up 40', come down and check float equipment, OK. Run in hole with 7" drilling liner filling every joint while running in hole and topping off every 10 jts. Run in hole with 7" drilling liner filling every joint while running in hole and topping off every 10 jts. Make up Baker HMC liner hanger, Baker ZXP liner top packer, and inspect same. Make up 4.5" IF p x 4" HT40 b and 5' 4" HT40 pup, and 1 stand 4" dp. Stage pump up at 2 bpm, 260 psi, 3 bpm, 270 psi, 4 bpm, 290 psi, 5 bpm 300 psi. Circulate 145 bbls, tubing volume is 133 bbls. No losses. UW 125k, DW 120k. TIH to window with 7" drilling liner at 3 minutes per stand. No losses. Stage up from 2 bpm @ 290 psi, to 5 bpm ~ 420 psi, circulate 1 bottoms up at window. RIH to 8,935' @ 2 minutes a stand, pump 98 strokes every 5 stands. P/U a single jt 4" dp and rig up cement head. RIH to 8,957', P/U to 8,956' and park it. Stage pumps up from 2 bpm at 5 minute intervals 1 bbl at a time to 5 bpm C~ 830 psi. UW 200k, DW 145k. Hold PJSM, test cement lines to 4,000 psi. Pump 30 bbls 10.8 ppg mud push, pump 90 bbls 11 ppg lite lead at 4 bpm, pump 35 bbls 15.8 class G tail cement at 4.5 Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: 1 5-12 Common W ell Name: 1 5-12B Spud Date: 7/31/2006 Event Nam e: REENTE R+COM PLET E Start : 7/15/2006 End: 8/18/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 8/18/2006 Rig Name: NABOB S 27E Rig Number: 27E Date From - To Hours Task ; Code ~~ NPT Phase Description of Operations 8/4/2006 13:30 - 14:00 0.50 CEMT P LNR1 bpm, kick out plug with 5 bbls water. 14:00 - 15:30 1.50 CEMT P LNR1 Switch to rig pump, displace cement with mud at 5 bpm at 230 psi. At 350 strokes reduce rate to 3 bpm at 94 psi, caught cement at 500 strokes, 350 psi.At 517 strokes dart latched into plug & sheared at 900 psi. Bumped the plug at 1802 strokes, pressured up to 3,500 psi, slacked off 65k & check hanger, hanger set, bled pressure and checked floats, OK. Cement in place at 15:30, no losses. 15:30 - 17:00 1.50 CASE P LNR1 Rotated 20 turns to the right, release from hanger, 2.5k torq. Pressured up to 1,000 psi picked up to clear seals, pumped 420 gpm ~ 2,000 psi to circulate cement out of the hole.After circ 30 bbls reduced rate to 2 bpm @350 psi, p/u and expose dogs, slack off 44k, set packer, repeat 1X. PU & SO rotating ~ 20 RPM's and set 50k, Increase pump rate to 500 gpm 2,600 psi. Diverted 40 bbls cement and 172 bbls contaminated mud to cuttings tank. 17:00 - 18:00 1.00 CASE P LNRi Pull 1 stand, lay down cement head. 18:00 - 19:00 1.00 CASE P LNR1 Test liner lap to 500 psi for 10 minutes, pump dry job. 19:00 - 21:30 2.50 CASE P LNR1 POH with 4" dp and running tool. 21:30 - 22:00 0.50 CASE P LNR1 Lay down packer running tool. 22:00 - 23:30 1.50 CASE P LNR1 Rig up to run 7" scab liner. 23:30 - 00:00 0.50 CASE P LNR1 Service the rig. 8/5/2006 00:00 - 07:00 7.00 CASE P LNR1 Hold PJSM, pick up and run 7" scab liner, Bakerlok first two joints from the float collar to the Baker insert landing collar, fill on the run. 07:00 - 08:00 1.00 CASE P LNR1 P/U hanger and liner top packer, inspect same. Liner with 1 stand 4" dp was 109k UW, 100k DW. 08:00 - 09:00 1.00 CASE P LNR1 Rig down casing equipment, clear rig floor. 09:00 - 10:00 1.00 CASE N RREP LNR1 Remove and repair cement line. 10:00 - 14:30 4.50 CASE P LNR1 TIH with 7" scab liner on 4" dp. 14:30 - 15:30 1.00 CASE P LNR1 Make up cement head, screw into head and torq with top drive. 15:30 - 16:30 1.00 CASE P LNR1 Circulate bottoms up at 5 bpm, 620 psi. UW 145k, DW 140k. 16:30 - 17:30 1.00 CEMT P LNR1 Slack off and tag tie back stem to the no go, pressure up to 500 psi, pick up 7.81' to expose circ ports and establish circulation at 5 bpm, 650 psi. Switch to Dowell, pump 5 bbls water, test lines to 4,500 psi, pump 27 bbls 12 ppg mud push at 3.5 bpm, 630 psi, pump 78.4 bbls 15.8 ppg class "G" cement at 4 bpm, 700 psi. 17:30 - 18:00 0.50 CEMT P LNR1 Switch to rig mud pumps, displace cement at 5 bpm, caught cement at 76 strokes. At 200 strokes away reduced pump rate to 3 bpm, 350 psi, latched dart into plug at 252 strokes, 875 psi. Raised pump rate to 5 bpm for 1,000 strokes, reduced rate to 3 bpm, 1,140 psi. At 1,150 strokes reduced rate to 2 bpm, 1,110 psi, bumped the plug at 1,170 strokes ~ 1,200 psi. Cement in place at 18:00 hrs. Bleed off pressure. No losses. 18:00 - 19:00 1.00 CASE P LNR1 Slack off, tag no go, pick up 1 foot, UW 150k. Pressure up to 3,200 psi to set hanger, pressured up to 3,700 psi setting the liner top packer, bleed off pressure, rotate 20 turns to the right to release the running tool. Pressure up to 1,000 psi, pick up 8' to clear pack off sub from packer, pump 500 gpm @ 1,800 psi to clear cement from liner top. At 300 strkes reduced rate to 2 bpm, pick up and clear dogs, UW 90k, slack off all the weight on the dogs, DW 50k, pick up, and repeat. Rotate with all the Printed: 1/29/2007 9:39:59 AM • BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date j l From - To --- - - Hours _- Task Code' - NPT Phase __ l 8/5/2006 18:00 - 19:00 1.00 CASE P LNR1 19:00 - 21:30 2.50 CASE P LNR1 21:30 - 22:30 1.00 BOPSU P LNR1 22:30 - 00:00 1.50 BOPSU P LNR1 8/6/2006 00:00 - 05:00 5.00 BOPSU P LNR1 05:00 - 06:00 1.00 BOPSUFt P LNR1 06:00 - 06:30 0.50 BOPSU P LNR1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 09:00 2.00 DRILL P PROD1 09:00 - 10:00 1.00 DRILL P PROD1 10:00 - 11:00 1.00 DRILL P PROD1 11:00 - 12:30 1.50 DRILL P PROD1 12:30 - 15:00 2.50 DRILL P PROD1 15:00 - 15:30 0:50 DRILL P PROD1 15:30 - 16:30 1.00 CASE P PROD1 16:30 - 19:00 2.50 DRILL P PROD1 19:00 - 20:00 1.00 DRILL N WAIT PROD1 20:00 - 21:30 1.50 DRILL N WAIT PROD1 21:30 - 22:30 i.00 DRILL N WAIT PROD1 22:30 - 23:30 1.00 DRILL N WAIT PROD1 23:30 - 00:00 0.50 DRILL N WAIT PROD1 8/7/2006 00:00 - 00:30 0.50 DRILL N WAIT PROD1 00:30 - 01:30 1.00 DRILL N WAIT PROD1 01:30 - 08:00 6.50 DRILL N WAIT PROD1 08:00 - 09:00 1.00 DRILL N WAIT PROD1 09:00 - 00:00 15.00 DRILL N WAIT PROD1 8/8/2006 100:00 - 17:00 I 17.001 DRILL I N I WAIT I PRODi 17:00 - 19:00 2.00 DRILL N WAIT PROD1 Description of Operations weight slacked off to verify packer is set, pick up and circulate bottoms up at 500 gpm, 1,700 psi. 17 bbls straight cement back. Lay down cement head, POH with running tool, lay down same. Pull wear ring, pick up Johnny Whacker and flush stack. Rig up to test BOPE. Test choke manifold valves, dart valve, TIW valve, upper and lower IBOP valves on the top drive, upper and lower variable rams, blind rams, manual and HCR choke and kill line valves 250 psi low, 4,000 psi high for 5 minutes each. Test Hydrit to 250 low and 3,500 psi high for 5 minutes each. Test the accumulater, 21 seconds to 200 psi build up, lminute 51 seconds to build to 3,000 psi. 8 bottles with 2,300 psi. Witness of test waived by AOGC Chuck Sheeve, test witnessed by WSL Charlie Noakes and TP Rick Brumley. Pull test plug, rig down test equipment. Blow down choke manifold. Install wear bushing, RILDS Service rig. Pick up bit, mud motor, float sub, MWD tools. Initialize MWD tools. Pick up 3 nmdc's, drilling jar, circ sub, and xo. Change out saver sub on top drive. RIH, tag up at 5,337'. Circulate and condition mud. Test scab liner lap and scab liner to 3,500 psi for 10 minutes. OK Drill cement from 5,337 to 5,370'. ~©~~'+Q ~~`~ ~~ ~ Received orders from town to suspend operations and secure well. Circulated sweep around, tested 7" scab liner to 3,500 psi for 5 minutes to verify the integrity of the scab liner hadn't been compromised by drilling cement. Drop bar to open circ sub, pump dry job, POH to bha. Lay down jar, stand 3 nmdc's back in derrick. Down load MWD tool. Lay down MWD tool. Lay down float sub, mud motor and bit. RIH with mule shoe and 10 stands of 4" dp. Wait on orders from town. Circulate bottoms up every 6 hours. Mud Temp 64 degrees. Cleaning rig. RIH with mule shoe to 2,448'. Wait on orders from town. Circulate bottoms up every 6 hours. Mud Temp 62 degrees. Work on camera's for pump room and derrick. Replace #1 cylinder liner and swab in mud pump #2, replace all seats and valves in #2 mud pump. Cleaning inside wind walls on derrick. Wait on orders from town. Circulate bottoms up every 6 hours. Mud Temp 58 degrees. Cleaning inside wind walls on derrick, primer inside of pipe shed,Repair steam and air leaks through out rig, install camera in derrick,repair pump suctions in between complexes, label subs on rig floor. Ready rig floor to POH, circulate mud in hole at 50 spm, 190 psi, MW 10.5 ppg in/out. ~ "~ "~ Printed: 1/29/2007 9:39:59 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 5-12 5-12B REENTE NABOBS NABOB Hours ' RfCOM ALASK S 27E i Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 7/31/2006 : 7/15/2006 End: 8/18/2006 Release: 8/18/2006 Number: 27E Description of Operations 8/8/2006 19:00 - 20:00 1.00 DRILL N WAIT PROD1 POH with kill string. 20:00 - 20:30 0.50 DRILL N WAIT PRODi Service rig. 20:30 - 21:30 1.00 DRILL N RREP PROD1 Replace cement line stand pipe. 21:30 - 22:30 i.00 DRILL N RREP PROD1 Repair pipe skate, loose electrical wire. 22:30 - 00:00 1.50 DRILL N WAIT PROD1 Pick up bit, mud motor, float sub, MWD tools, initialize MWD. tools. 8/9/2006 00:00 - 01:00 1.00 DRILL N WAIT PROD1 RIH with 3 NMDC's, pick up jar and XO. 01:00 - 04:00 3.00 DRILL N WAIT PROD1 RIH to 5,300', fill pipe at 2,500'. 04:00 - 08:00 4.00 DRILL P PROD1 RIH to 5,337', tagged up stacking 15k, pick up to 5,300', ream down, tag up at 5,314'. Took 30 minutes to get by suspected _ wiper dart. Tag up on cement at 5,365', drill cement to 5,404', - tag up on Insert landing collar in 7" scab liner.. Drill LC and cement stringers to 5,800'. UW 120k, DW 110k, TO on 3k, TO off 2k, 245 gpm at 2,000 psi, 50 rpm's. 08:00 - 09:30 1.50 DRILL P PROD1 RIH to 8,868', tag up on LC in 7" drilling liner. 09:30 - 10:00 0.50 DRILL P PROD1 Circulate 1,100 strokes at 250 gpm @ 2,000 psi for casing test. 10:00 - 10:30 0.50 CASE P PROD1 Test 7" drilling liner to 3,500 psi for 30 minutes, OK. (During test orders from town came to POH, L/D bha, RIH w/kill string to 2,448.) 10:30 - 15:00 4.50 DRILL N WAIT PROD1 Open circ sub, pump dry job, POH to bha. 15:00 - 16:00 1.00 DRILL N WAIT PROD1 Lay down xo, jar, stand back 3 NMDC's in derrick. 16:00 - 16:30 0.50 DRILL N WAIT PROD1 Download MWD tools. 16:30 - 17:00 0.50 DRILL N WAIT PROD1 Lay down MWD tools, float sub, mud motor, and bit. 17:00 - 18:30 1.50 DRILL N WAIT PROD1 TIH with mule shoe and 26 stands 4" dp to 2,453'. 18:30 - 00:00 5.50 DRILL N WAIT PROD1 Waiting on orders from town. Cleaning inside derrick wind walls, painting inside pipe shed, change oil in rig motors. 8/10/2006 00:00 - 12:00 12.00 DRILL N WAIT PROD1 Waiting on orders from town. Circulate bottoms up 35 spm at 140 psi. Mud temp at flowline is 63 degrees. Cleaning inside derrick wind walls, painting inside pipe shed, painting in mud pits, Change oil in #3 motor, repair #2 mud pump suction line. 12:00 - 00:00 12.00 DRILL N WAIT PROD1 Waiting on orders from town. Circulate bottoms up 35 spm at 140 psi. Mud temp at flowline is 61 degrees. Cleaning inside derrick wind walls, painting inside pipe shed, cleaning in mud pits, repair hoses on EZ Torq, fix belting skirt around bottom of pipeshed, drain casing tong reservior to make repairs on tank, R & R gun line in pill pit. 8/11/2006 00:00 - 08:30 8.50 DRILL N WAIT PROD1 Waiting on orders from town. Circulate bottoms up 25 spm at 110 psi. Mud temp at flowline is 61 degrees. Cleaning inside derrick wind walls, cleaning in mud pits, install rubber skirting around bottom of pipeshed, prep pump room floor for paint. 08:30 - 10:30 2.00 DRILL N WAIT PROD1 Cut and slip drilling line. 10:30 - 13:00 2.50 DRILL N WAIT PROD1 Waiting on orders from town. Cleaning inside derrick wind walls, cleaning in mud pits, install rubber skirting around bottom of pipeshed, prep pump room floor for paint. 13:00 - 14:00 1.00 DRILL N WAIT PROD1 Mix and pump slug. MW 10.5 ppg in/out. 14:00 - 14:30 0.50 DRILL N WAIT PROD1 Pre Spud safety meeting to refocus hands to tasks ahead of us. 14:30 - 16:00 1.50 DRILL N WAIT PROD1 POH with kill string, lay down mule shoe. 16:00 - 17:00 1.00 DRILL N WAIT PRODi Make up bit, mud motor, float sub, MWD tools. 17:00 - 18:00 1.00 DRILL N WAIT PROD1 Initialize MWD tools. 18:00 - 19:00 1.00 DRILL N WAIT PROD1 RIH with 3 nmdc's, pick up jar, circ sub, xo, and 1 stand of dp, shallow pulse test MW D tools. 19:00 - 22:30 3.50 DRILL N WAIT PROD1 RIH to 8,868', fill pipe every 30 stands. Printed: 1/29/2007 9:39:59 AM • BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date ~ From - To Hours ~ Task ~ Code ! NPT Phase Description of Operations 8/11/2006 22:30 - 23:00 0.50 DRILL N WAIT PROD1 Install blower hose on top drive. 23:00 - 00:00 1.00 DRILL P PROD1 Drill landing collar, drill cement from 8,870' to 8,877'. UW 165k, 8/12/2006 100:00 - 00:30 I 0.501 DRILL I P I I PROD1 00:30 - 01:00 I 0.501 DRILL I P I I PROD1 01:00 - 02:30 I 1.501 DRILL I P I I PROD1 02:30 - 03:30 I 1.001 DRILL I P I I PROD1 03:30 -.04:00 I 0.501 DRILL I P I I PRODi 04:00 - 07:30 I 3.501 LCR I N I DPRB I PROD1 07:30 - 08:00 0.50 LCR N DPRB PROD1 08:00 - 12:00 4.00 LCR N DPRB PROD1 12:00 - 14:00 ~ 2.00 ~ LCR ~ N ~ DPRB ~ PROD1 14:00 - 18:00 4.00 LCR N DPRB PROD1 18:00 - 19:30 1.50 LCR N DPRB PROD1 19:30 - 20:00 I 0.501 LCR I N I DPRB I PROD1 20:00 - 00:00 I 4.001 LCR I N I DPRB I PROD1 8/13/2006 00:00 - 00:30 0.50 LCR N DPRB PROD1 00:30 - 01:00 0.50 LCR N DPRB PROD1 01:00 - 02:00 I 1.001 LCR I N I DPRB I PROD1 02:00 - 03:00 I 1.001 LCR I N I DPRB I PROD1 DW 155k, RW 160k, 40 rpm's at 3k TO, 5.8 bpm @ 2,700 psi, MW 10.5 ppg in/out. Drill cement from 8,877' to 8,911', drill tloat collar, drill cement from 8,912' to 8,949'.. UW 165k, DW 155k, RW 160k, 40 rpm's at 3k TO, 5.8 bpm ~ 2,700 psi, MW 10.5 ppg in/out. While circulating cement out hold Pre Spud Safety Meeting with rig crew to refocus hands on tasks ahead of us. Displace old mud out of hole with a 30 bbl viscous pill, 100 bbls of water, 400 bbls of 8.5 ppg Flo Pro mud. Flush both mud pumps and auxiliary lines while displacing with water. UW 165k, DW 155k, RW 160k, 40 rpm's at 3k TO, 6 bpm ~ 2,400 psi, MW 8.5 ppg in/out. Wash out possum belly, under shale shakers, and mud troughs. Take SPR. #1 at 30 spm=675 psi, @ 40 spm=900 psi. Pump #2 at 30 spm=675, @ 40 spm=890 psi. Drill cement from 8,949' to 8,956', drill float shoe, drill new formation from 8,957' to 8,977'. Stand back 1 stand to be able to circulate and reciprocate. UW 165k, DW 155k, RW 160k, 45 rpm's at 2k TO, 6.5 bpm ~ 1,670 psi, MW 8.5 ppg inlout. Attempt to circulate bottoms up at 6.5 bpm, lost 26 bbls in 15 minutes, reduce pump rate to 5 bpm, still losing. Line up trip tank, circulate over top of hole and monitor well. Static losses 20 bbls an hour. Drill from 8,977' to 8,999'. Hole taking fluid. 40 rpm's with 2k Tq, 3 bpm ~ 660 psi, WOB 10k, UW 177k, DW 145k, RW 160k. Pump loss circulation material down drill string while pumping across the top of the hole with the hole fill pump to keep the hole full. Well taking 180 bbls an hour. Pump down hole until the LCM clears the dp, monitor the well. Hook up 2 portable pumps sucking water from the re „serve pit to the #2 '~ pit, Pump 8.5 bpm through the kill line to keep the hole full with minimal returns. Loss rate 450+ bbls/hr. Decision made to set EZSV at 8,850', 20' above the scab liner landing collar. We will circulate 8.5 bpm through the kill line to keep hole full until EZSV is set and tested. POH with drilling assembly to bha. Lay down xo, jar, 3 nmdc's, mwd tools in one piece, float sub and mud motor in one piece, and the bit. Hold PJSM, pick up xo and ported sub, make a dummy run through the stack, OK. Make up EZSV onto ported sub. TIH with EZSV at 1 minute/stand while keeping hole full. Losing 500 bbls/hr. --' TIH to 8,785' with EZSV. RIH to 8,855', pull up to 8,850', UW i80k, DW 150k. Rotate 38 turns to the right to set top slips, pull up to 200k to inflate packer, pull up to 220k to shear off EZSV and set bottom slips. Slack off to 130k to verify EZSV is set. Hold PJSM, pressure up to 3,500 psi for 30 minutes to test EZSV, OK. Recorded on chart. Bleed off pressure. Displace water in hole with seawater, pumped 30 bbl viscous Printed: 1/29/2007 9:39:59 AM r1 U BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 7/15/2006 End: 8/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/18/2006 Rig Name: NABOBS 27E Rig Number: 27E Date ' From - To Hours ~ Task Code 8/13/2006 02:00 - 03:00 1.00 LCR N 03:00 - 08:00 5.00 LCR N 08:00 - 08:30 0.50 LCR P 08:30 - 21:00 12.50 BOPSU N 21:00 - 22:30 1.50 BUNCO 22:30 - 00:00 1.50 BUNCO 8/14/2006 00:00 - 03:30 3.50 BUNCO 03:30 - 05:00 1.50 BUNCO 05:00 - 06:00 1.00 BUNCO 06:00 - 07:00 1.00 BUNCO 07:00 - 10:00 3.00 BUNCO 10:00 - 13:00 3.00 BOPSU N 13:00 - 13:30 0.50 WHSUR N 13:30-14:30 1.00 WHSUR N 14:30 - 15:00 0.50 WHSUR N 15:00 - 16:00 1.00 WHSUR N 16:00 - 17:00 1.00 WHSUR N 17:00 - 20:00 3.00 WHSUR N 20:00 - 23:00 3.00 WHSUR N 23:00 - 00:00 1.00 WHSUR N 8/15/2006 00:00 - 00:00 24.00 CONS N 8/16/2006 00:00 - 00:00 24.00 CONS N 8/17/2006 00:00 - 00:00 24.00 CONS N NPT Phase ~ Description of Operations DPRB PROD1 pill, chased with 410 bbls of seawater behind 1 drum of SAFE O Surf. Spotted 2 drums of corrosion inhibitor in annulus. Pumped job at 10 bpm at 1,600 psi. UW 180k, DW 150k. DPRB PROD1 PJSM, POH laying down 4" dp 1 x 1, lay down EZSV running tool. PROD1 CanRig Rep tested Top Drive, OK. DPRB PROD1 RIH w/ stands from derrick. Complete POH LD 4" DP. B/O UD EZSV running tool. Pull wear bushing. DPRB RUNCMP Rig up casing equipment to run 2,900' of 4-1/2" tubing kill string. DPRB RUNCMP Run 4-1/2" tubing kill string. DPRB RUNCMP Run 4-1/2" tubing kill string to 2,930'. UW 78k, DW 78k, tubing weight 28k. DPRB RUNCMP Make up 4-1/2" tbg hanger, install TWC, land tubing hanger 28.3' from rotary table, RILDS, FMC torq to specs. DPRB RUNCMP Test hanger and TWC above to 3,500 psi for 5 minutes, test same from below to 3,500 psi for 5 minutes. DPRB RUNCMP Break and lay down xo's and landing jt. DPRB RUNCMP Clean mud out of drip pans below rig floor with super sucker. DPRB RUNCMP Nipple down BOPE. DPRB RUNCMP Clean and dress 4-1/2" tubing hanger. DPRB RUNCMP Nipple up tree consisting of a master and swab valve with a tree cap, needle valve, and gauge. DPRB RUNCMP Test tree and adapter to 5,000 ps. DPRB RUNCMP Rig up testing manifold to the IA and tubing side of the tree. DPRB RUNCMP Rig up DSM lubricator and pull TWC. DPRB RUNCMP Evacuate rig and muster all personnel in mechanics shop due to a Halon release in a manifold building on DS 15 until location cleared to go back to work. DPRB RUNCMP Hold PJSM, test all lines and manifold to 3,000 psi, freeze protect 4-1/2" x 9-5/8" annulus by pumping 150 bbls of diesel down IA at 5 bpm @ 500 psi. Open tubing to IA and U tube diesel, install BPV with DSM lubricator, test BPV to 1,000 psi from below, bleed off pressure, suck lines dry, rig down DSM and Little Red. DPRB RUNCMP Remove secondary annulus valves and install blinds with gauges. WAIT POST Perform rig maintenance. Waiting for pre-rig work on 15-39 . Srcape and prep inside derrick wind walls for paint, clean in cellar area. PM rig mud pumps, PM valves in mud pits Install emergency stop on pipe skate Install Bridle line roller on ODS WAIT POST Perform rig maintenance. Waiting for pre-rig work on 15-39 . Scrape and prep inside derrick wind walls for paint, clean in cellar area. Install new Bridle Line roller PM valves in Mud Pits WAIT POST Perform rig maintenance. Waiting for pre-rig work on 15-39 . Scrape and prep inside derrick wind walls for paint, paint pipe shed Install new Bridle Line roller Install new sensor in Mud Pits Printed: 1/29/2007 9:39:59 AM Printed: 1/29/2007 9:39:59 AM • BP EXPLORATION Page 1 of 10 Operations Summary .Report Legal Well Name: 15-12 Common Well Name: 15-12B Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date ~ From - Tc ; Hours ~ Task Code NPT 12/9/2006 09:00 - 12:00 3.00 MOB P 12:00 - 15:00 3.00 MOB P 15:00 - 20:00 5.00 MOB N WAIT 20:00 - 22:00 2.00 MOB P 22:00 - 00:00 2.00 MOB P 12/10/2006 00:00 - 03:30 3.50 MOB P 03:30 - 06:00 2.50 MOB P 06:00 - 14:00 I 8.001 RIGU I P 14:00 - 14:30 0.50 BOPSUF{ P 14:30 - 15:30 1.00 BOPSU P 15:30 - 17:00 I 1.501 BOPSUFI P 17:00 - 19:00 I 2.00 I BOPSUR P 19:00 - 20:30 ~ 1.50 ~ BOPSUFt P 20:30 - 23:00 2.50 BOPSU P 23:00 - 00:00 1.00 BOPSU P 12/11/2006 100:00 - 06:00 6.001 BOPSUp P 06:00 - 06:30 0.50 PULL P 06:30 - 07:30 1.00 PULL P 07:30 - 09:30 2.00 PULL P 09:30 - 12:00 I 2.501 PULL I P 12:00 - 13:00 1.00 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 18:30 4.00 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 00:00 3.50 CLEAN P 12/12/2006 00:00 - 05:00 5.00 CLEAN P 05:00 - 06:00 I 1.001 CLEAN I P 06:00 - 09:30 I 3.501 DRILL I P Spud Date: 7/31 /2006 Start: 12/10/2006 End: I Rig Release: Rig Number: 2ES Phase Description of Operations PRE Rig down floor,bridle up,tie back lines PRE Remove cuttings tank and all berms. Rig out to move. PRE Wait on security,Remove and repair steam table. Install winch. PRE Move Plts to DS15. PRE Move Rig to DS15. PRE Move sub from DSO6 to DS15. PRE Lay rig malts-spread herculite-spot sub on well 12B. Close cellar doors. PRE Spot shop,camp, mud pits and support buildings. Raise derrick and rig up rig floor. Spot and berm cuttings tank. Bridel down and berm rig. Put walkways in place and take on seawater into mud pits. DECOMP Pre-Spud meeting. Rig accept 12/10/2006 G 14:00 DECOMP Pull BPV with lubricator. Tubing pressure C~? 0 psi,annulus pressure @ 0 psi. DECOMP Rig up circulating lines to tree. Test lines and circulate out 150 bbl. diesel, 10 BPM @ 800 psi. Shut down and verify well is dead. DECOMP Install TWC,test from above and below to 1000 psi. Blow down and rig down circulating lines. DECOMP PJSM. Nipple down tree.RKB to LD 23.65'. Check hanger threads, TC11 - 7.5 turns. DECOMP Nipple up BOP,install flow riser. Fill stack and check for leaks. DECOMP Test BOP's to 250 psi low and 4000 psi high. Test witness waived by AOGCC rep Chuck Shieve. Test witnessed by BP rep. Blair Neufeld (WSL). DECOMP Test BOP's to 250 psi low and 4000 psi high. Test witness waived by AOGCC rep Chuck Shieve. Test witnessed by BP rep. Blair Neufeld (WSL).Blow down surface equipment. DECOMP Rig up 4 1/2" tubing equipment. Bleed OA to 0 psi. DECOMP Rig up DSM lubricator,pull TWC. Rig down lubricator. DECOMP Make up landing joint,back out lock down screws. Pull hanger to floor,55k up weight. Lay down landing joint and hanger,change out elevators. DECOMP Lay down 4 1/2" L-80 work string from 2900',70 joints + wireline entry guide. Rig down handling euipment. DECOMP PJSM. Clean and clear floor,hang tongs. DECOMP Make up 4" test joint and test annular to 250 psi low, 3500 psi high. Test upper and lower pipe rams to 250 psi low and 4000 psi high. DECOMP Install wear ring, ID 9". DECOMP Strap drill pipe and BHA components. DECOMP Make up 6 1/8" bit to BHA and run in to 752'. DECOMP Run in hole with 4" drill pipe from pipe shed from 752' to 3865'. DECOMP Pick up drill pipe from pipe shed from 3865' to 8800'. Rack back 10 stands and pick up 30 singles from pipe shed.lnstall blower hose. DECOMP Break circulation,get slow pump rates. PJSM prior to drill out of EZSV. Rig up sencondary kill line to annulus. Up wt. 170k, down wt. 140k,rotating wt. 155k. 80 RPM torque off bottom 400 and on bottom 600k.270 GPM ~ 1000 psi. PROD1 Tag EZSV @ 8842'.Drill EZSV to 8845',losses @ 10 BPH. Pump 50 bbl LCM pill at 80 ppb MI seal Magna Fiber, Mix 11, Printed: 1/2/2007 12:56:33 PM • 6P EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date ~~ From - To Hours ~~ Task ~ Code NPT __' 12/12/2006 ~ 06:00 - 09:30 ~ 3.50 ~ DRILL ~ P 09:30 - 11:00 I 1.501 DRILL I P Spud Date: 7/31/2006 Start: 12/10/2006 End: Rig Release: Rig Number: 2ES Phase PRODi PROD1 11:00 - 12:00 I 1.001 DRILL I P 12:00 - 13:00 1.00 DRILL P 13:00 - 14:30 1.50 DRILL P 14:30 - 15:30 I 1.001 DRILL I P 15:30 - 17:00 I 1.501 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 22:00 2.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 12/13/2006 00:00 - 05:00 5.00 DRILL P PROD1 05:00 - 09:00 4.00 DRILL P PROD1 09:00 - 11:00 2.00 DRILL P PROD1 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 13:00 ( 0.501 DRILL P PRODi 13:00 - 16:00 3.00 DRILL P PROD1 16:00 - 18:30 2.50 DRILL P PROD1 18:30 - 21:30 3.00 DRILL P PROD1 21:30 - 23:30 I 2.001 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 12/14/2006 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 04:00 I 1.501 DRILL I P I I PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 06:30 1.50 DRILL P PROD1 06:30 - 10:00 3.50 DRILL P PROD1 Description of Operations Safecarb 250 and 40. Losses stop when pill out the bit. Drill remainder of plug and push plug down to 8992'. Drill remainder of EZSV and new hole from 8992' to 9010'. 110 SPM 031000 psi. 75 RPM,torque off bottom 4k torque on bottom 6k. Losses start slowley and work back up to 110 BPH. Monitor well, static losses 110 BPH. Spot 50 bbl LCM pill at 80 ppb on bottom (same formulation as previous), monitor well. Static losses 6 BPH. POOH trom 9010' to 8940',monitor well - losses ~ 6 BPH. Close Hydril,attempt to squeeze 25 bbl. Pump down back side at 10 SPM @ 450 psi.Pumped 100 strokes,shut down and attempt to pump through drill pipe. Plugged off, worked pipe,unable to clear obstruction. POOH from 8940' to 8789'. Drop circulating sub ball and wait 10 minutes, pressure up to 2500 psi then 3000 psi, did not open. Bleed off pressure and wait 10 minutes for ball to land on seat, pressure up to 2500 psi,circ. subs opens. Circulate 82 and 102 SPM with no loses. Bring pump up to 122 SPM then 134 SPM with no losses. Pump 20 bbl. dry job and POOH from 8789' to 752'. Stand back BHA and clean plugged bit,bit sub and drill collar. Make up new bit, stabilizer and BHA to 281'. Run in hole with HWDP. Drop ball to close circulating sub. Run in hole with 4" drill pipe to 8795'. Install blower hose,wash to bottom with minor losses due to LCM running over shakers. Drill 6 1/8" hole from 9010' to 9088',60 to 80 BPH losses while drilling. Up wt. 185k, down wt. 135k,rotating wt. 160k. 80 RPM,torque off bottom 6k and on bottom 7k. WOB 10k,270 GPM @ 990 psi. Circulate 20 bbl LCM pill at 30 ppb around at 270 GPM @ 1100 psi,slow to 150 GPM as pill passes through open hole. Losses 50 BPH. Spot 20 bbl. LCM pill on bottom and POOH from 9088' to 8420'. Pump LCM pi11,350 GPM ~ 1560 psi,no losses. Squeeze LCM @ 8 SPM,300 psi. Attempted to raise to 450 psi,pressure bled off. Total strokes pumped 30. Bleed annulus and drill pipe to 0 psi,open bag. Circulate at 400 GPM with no losses. Pump dry job and POOH from 8327' to 758'. Lay down BHA,clear floor. Make up 6 1/8" bit and directional drilling BHA to 377'. Test MWD with 270 GPM @ 1340 psi. Run in hole picking up 4" drill pipe from pipe shed from 377' to 2618'. Run in hole from 2618' to 3177'. Run in hole from 3177' to 8320' filling pipe every 3000' and testing MWD. Cut and slip line,service crown, and draworks. Inspect brakes and traction motor brushes. Service top drive. Run in hole, wash to bottom from 8850'. MAD Pass log with MW D from 9088' to 8878' @ 90 FPH. Pumping at 210 GPM C~3 1150 psi losses to 85 BPH. Run in Printed: 1/2/2007 12:56:33 PM • BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 12/10/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase 12/14/2006 06:30 - 10:00 3.50 DRILL P PROD1 10:00 - 12:00 2.00 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 13:00 0.50 DRILL P PRODi 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 15:00 I 0.501 DRILL I P I I PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:00 I 0.501 DRILL I P I I PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 19:00 1.00 DRILL P PROD1 19:00 - 22:00 3.00 DRILL P PROD1 22:00 - 00:00 I 2.001 DRILL I P I I PROD1 12/15/2006 100:00 - 01:00 I 1.001 DRILL I P I I PRODi 01:00 - 07:00 I 6.001 LCR I N I DPRB I PROD1 07:00 - 07:15 I 0.251 LCR I N I DPRB I PROD1 07:15 - 08:30 ~ 1.25 ~ LCR ~ N ~ DPRB ~ PROD1 08:30 - 09:00 0.50 LCR N DPRB PRODi 09:00 - 10:00 1.00 LCR N DPRB PROD1 10:00 - 10:45 0.75 LCR N DPRB PROD1 10:45 - 11:45 1.00 LCR N DPRB PROD1 Description of Operations hole from 8878' to 9088',static losses 85 BPH. Circulate @ 165 BPM,720 psi,rotate and reciprocate. POOH from 9088' to 8950', circulate at 125 BPM C~? 470 psi while waiting on mud products (Form-A-Squeeze). Losses at 60 BPH. '~ Run in hole from 8878' to 9088'. Pump down 25 bb1,80 ppb Form-A-Squeeze pill. POOH from 9088' to 8315'. Shut Hydril, pump down drill pipe and annulus,25 SPM ~ 200-300 psi. Pumped total of 18 bbl. Formation bled to 0 psi. Circulate over the top of the hole ,monitor losses. Losses at 55 BPH. Run in hole from 8315' to 9065'. Drop circulating sub 1.76" opening ball and pressure up to 2500 psi to open. Drop circulating sub 1.69" shut off ball to shut flow off through BHA. Pump 25 bbl, 40 ppb LCM pill with Seal mix 11,S-250 and S-40. POOH from 9065' to 8131',tight off bottom,pulled 70k over. Drop circulating sub closing ball,pressure up to 3500 psi to close tool. Establish circulation through BHA. Pump dry job,monitor weII,POOH from 8131' to 377'. Hole took correct displacement (no losses). Stand back HWDP,jars, and non magnetic drill collars. Pump 20 bbl. clean water to flush MWD and motor. Download and laydown MWD. Break off bit and lay down mud motor. Make up Halliburton EZSV and run in hole to 8907' MD - 50' above 7" shoe. Set Howco EZSV at 8907' with 35 turns to right. Verify set and unsting to set collets on retainer. Sting back in - OK. Establish injection rate up to 4 bpm at 1200 psi. Shut pump down and pressure drops to zero within a minute. PJSM for cement squeeze. Batch mix squeeze slurry. Pump 5 bbls freshwater. Test lines to 4000 psi. Pump 10 bbls freshwater followed by 97 bbls (320 sx) Class G slurry with 8% gel and 1.5 ppb CemNET - 4 bpm w/zero surface pressure. Start displacing cement with seawater at 4 bpm - zero W HP. Continue displacing with seawater. 46 bbls cement to formation -start seeing surface pressure. SD displacement for 5 min. At 61 bbls cmt to formation - 1300 psi surface pressure. SD for 10 min. Back on at 2 bpm. Catch fluid after 11 bbls pumped. 2 bpm at 1130 psi. 81 bbls cmt to formation - 1100 psi surface pressure. SD for 20 min. Back on at 1.5 bpm. Caught fluid at 91 bbls cement to formation. Continue building squeeze pressure up to 1600 psi then dropping to 1000 psi after overdisplacing retainer by 4.8 bbls. CIP at 11:45 hrs. Printed: 1/2/2007 12:56:33 PM • BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 12/10/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To ~ Hours ~ Task Code ~ NPT ~ Phase 12/15/2006 11:45- 13:00 ( 1.251 LCR N DPRB PROD1 13:00 - 18:00 I 5.001 LCR I N I DPRB I PROD1 18:00 - 19:30 1.501 LCR N DPRB ~ PROD1 19:30 - 21:00 1.50 LCR N DPRB PROD1 21:00 - 00:00 3.00 LCR P PROD1 12/16/2006 00:00 - 02:30 2.50 LCR P PROD1 02:30 - 03:00 0.50 LCR P PROD1 03:00 - 05:00 2.00 LCR N DPRB PROD1 05:00 - 08:00 3.00 LCR N DPRB PROD1 08:00 - 09:00 I 1.001 LCR I N I DPRB I PROD1 09:00 - 12:00 ~ 3.00 ~ LCR ~ N ~ DPRB ~ PROD1 12:00 - 13:30 I 1.501 LCR I N I DPRB I PROD1 13:30 - 15:00 1.50 LCR N DPRB PROD1 15:00 - 18:30 3.50 LCR N DPRB PROD1 18:30 - 19:30 1.00 LCR N DPRB PROD1 19:30 - 23:00 3.50 LCR P PROD1 23:00 - 00:00 1.00 LCR P PROD1 12/17/2006 00:00 - 03:00 3.00 LCR P PROD1 03:00 - 12:00 I 9.001 DRILL I P I I PROD1 Description of Operations Pick up and unsting from retainer. Check for losses - OK, static. CBU at 425 gpm. Saw slight pH increase on bottoms up but. no visible cement. Pump dry job,blow down cement line, and top drive. POOH from 8910',lay down running tool,clear floor. Change out handling equipment. Make up clean out BHA to 391',change out handling equipment. Run in hole from 391' to 4312' -secure well. Safety stand-down with Mike Schultz. Safety stand-down with Mike Schultz. Open kill line and check well. Open TIW and rams. Fill pipe and blow down top drive. Run in hole from 4311'. Install blower hose and wash down last stand. Drill EZ drill plug from 8908'. Up wt. 175k,down wt. 145k,rotating wt. 160k. 210 GPM C~3 540 psi. 8.6 ppg seawater. Flow increase of 14% and pit gain of 6 bbl. Pick up and shut in well. Shut in drill pipe pressure 40 psi Shut in casing pressure 10 psi.,increasing to 50 psi. in 15 minutes. Open choke and break circulation ~ 30 SPM 160 psi-DP. Bring choke to full open and bleed casing down to 0 psi. Monitor returns through poor boy until flow stops (10 minutes). Open up well and monitor,dead. Continue drilling on plug and wash plug down to 8970'. Drill on plug at 8970' with no gains or losses. Up wt. 172k, down wt.145k,rotating wt. 158k. WOB 15k, 85 RPM,ott bottom torque 4k on bottom torque 6-7k. 215 GPM C~3 550. psi. Drill and wash cement from 8970' to 9088' with losses at 18 BPH. Up wt. 172k, down wt.145k,rotating wt. 158k. WOB 15k, 85 RPM,off bottom torque 4k, on bottom torque 6-7k. 215 GPM @ 550 psi. 8.6 ppg seawater. Circulate bottoms up at 270 GPM @ 820 psi,losses at 18 BPH. Monitor well,static losses at 18 BPH. Pump dry job,blow down top drive. POOH from 9088' to 391',change out handling equipment. POOH with BHA,Iay down drill collars,clear floor. Make up BHA to 402',orient,upload MWD,and surface test with 250 GPM @ 1430 psi. PJSM Install radioactive sources. Change out handling equipment. Run in hole from 402' to 2737'. Run in hole from 2737' to 9088'. Fill pipe every 30 stands and test MWD. Install blower hose and wash last 10' before tagging up at 9088',no fill or tight spots in the open hole section. Trip losses 20 BPH for a total of 31 bbl. Drill 6 1/8" hole as per directional plan. Up wt. 186k,down wt. 129k,rotating wt. 155k. 60 RPM,5-14k WOB,torque off bottom 6-7k, on bottom 7-9k. Printed: 1/2/2007 72:56:33 PM • BP EXPLORATION Page 5 of 10 Operations Summary- Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 12/10/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task I Code , NPT ~ Phase Description of Operations 12/17/2006 03:00 - 12:00 9.00 DRILL P PROD1 250 GPM C~ 1800 psi off bottom, and 1900 psi on bottom. 8.5 ppg seawater in and out. Start displacement to Flo-Pro mud at 9131' @ 04:30. Losses with Flo-pro initially slow to less than 10 BPH then increase to where losses are 80 BPH while drilling. Mud wt in and out 8. ppg. 12:00 - 19:00 7.00 DRILL P PROD1 Drill 6 1/8" hole from 9331' to 9438'. Geology adjusted TVD for landing point i 5' lower necessitating dropping angle to avoid landing horizontal long in vertical section. Up wt 165k,down wt. 145k, rotating wt. 160k. WOB 12k,RPM 80,off bottom torque 3k, on bottom torque 4k. 250 GPM @ 1500 psi off bottom, 1625 on bottom. Mud wt. in and out 8.4 ppg. Pressure fluctuations of 200 to 300 psi causing some difficulty determining weight transfer to bit. Surface systems all checked but unable to resolve. Possibly due to constant additions of new mud to make up for losses. At 19:00 Geology moves target up 55' TVD, making it necessary to stop drilling to determine if current assembly can achieve the new well path. 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 21:00 1.00 DRILL P PROD1 21:00 - 00:00 3.00 DRILL P PROD1 12/18/2006 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 02:00 1.00 DRILL X DPRB PROD1 02:00 - 06:00 4.00 DRILL X DPRB PROD1 06:00 - 10:00 4.00 DRILL X DPRB PROD1 10:00 - 12:30 2.50 DRILL X DPRB PROD1 Circulate bottoms up to discuss changes to target. 250 GPM ~ 1400 psi rotate and reciprocate. Perform MAD pass with MW D from 9110' to 9015' at 300 FPH. Target ends up moving up 45' which means some further hole can be drilled to determine assembly build rate with full slides. Estimated dogleg required 15.5-16 degrees/100'. Drill 6 1/8" hole from 9439' to 9453'. Up wt 165k,down wt. 145k, rotating wt. 160k. WOB 12k,RPM 80,off bottom torque 3k, on bottom torque 4k. 250 GPM C~ 1500 psi off bottom, 1625 on bottom. Mud wt. in and out 8.4 ppg. Drill 6 1/8" hole from 9453' to 9465'. Up wt 165k,down wt. 145k, rotating wt. 160k. WOB 12k,RPM 80,off bottom torque 3k, on bottom torque 4k. 250 GPM @ 1580 psi off bottom, 1650 on bottom. Mud wt. in and out 8.4 ppg. Survey shows dogleg of 12.6/100', which is insufficient to continue, require 15.5-16/100' now that target has been moved up. Circulate bottoms up, 250 GPM ~ 1550 psi. POOH to casing shoe, 20k max pull, worked through,no overpull. Pump dry job, remove blower hose. POOH to BHA at 402' last 15 stands pulled wet. Losses while pulling out 15 BPH, total of 57 bbl over displacement Rack back HWDP and jars,lay down circulation sub. PJSM, on handling radioactive sources and laying down BHA. Stand back collars, remove sources and download MWD. Lay down motor and bit. Make up bit and motor to MWD, measure offset. Shallow pulse test MWD then load sources.Run in collars,HWDP and jars to Printed: 1/2/2007 12:56:33 PM • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 12/10/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To 1 Hours .Task Code i~ NPT Phase 12/18/2006 10:00 - 12:30 2.50 DRILL X DPRB PROD1 12:30 - 16:00 3.50 DRILL X DPRB PRODi 16:00 - 17:00 1.00 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 18:30 0.50 DRILL X DPRB PROD1 18:30 - 00:00 I 5.501 DRILL I P I I PROD1 12/19/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL l P ~ ~ PROD1 12:00 - 23:00 I 11.001 DRILL I P I I PROD1 23:00 - 00:00 I 1.001 DRILL I P I I PROD1 12/20/2006 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 01:30 - 04:30 ~ 3.001 DRILL I P PROD1 04:30 - 11:00 I 6.501 DRILL I P I I PROD1 11:00 - 15:00 I 4.001 DRILL I P I I PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 Description of Operations 403'. Change out handling equipment. Run in hole from 403' to 8900',fill pipe and test MWD every 3000'. Cut and slip drilling line. Service Top drive. Run in hole 8900' to 9371' -Wash down from 9371' to 9466'. Hole takes 163 bbls over displacement when running in hole. Drill 6 1/8" hole from 9465' to 9539'. Up wt 170k,down wt. 145k, rotating wt. 160k. WOB 10k, RPM 60, off bottom torque 4k, on bottom torque 5k. 250 GPM @1480 psi off bottom, 1640 psi on bottom. Mud wt in and out 8.4 ppg. Once back on bottom at bottoms up there was more than normal trip gas taking 45 minutes to circulate out. Drill 6 1 /8" hole from 9539' to 9657'. Up wt 170k,down wt. 145k, rotating wt. 160k. WOB 10k, RPM 60, off bottom torque 4k, on bottom torque 5k, 250 GPM C~ 1480 psi off bottom, 1640 on bottom. Mud wt. in and out 8.4 ppg. Losses while drilling at 26 BPH. Cuttings started out fine silUsand and are currently coarse and larger in size. Drilling in zone 1 B. BHA is currently building at the required build rates. SPR's both pumps, 30/580, 45/720 at 9570'/0100 hours. Drill ahead to 9840' MD, 8895' TVD. Finished build section. Up weight 170k, down 145k, RT 160k at 15 rpm. WOB 14k. Pump at 250 gpm wtih 1720 psi off bottom, 1820 psi on bottom. Torque 4-5k on and off bottom. SPR's both pumps, 30/660, 45/800 at 9746'/1600 hours. Losses at 50 bph. Circulate for 15 minutes and set up for MAD pass: ~~ MAD Pass from 9840' to 9600' with tool face at 20 R. Pass at 300 fph. MAD Pass from 9600' to 9300' at 300 fph. Pump at 250 gpm with 1780 psi, oriented to 20 deg right. POOH to 8900 into 7" shoe. Pump dry job. Remove blower hose. Install air slips. Blow down top drive. POOH to BHA. Losses during trip at 8 bph. Change out handling equipment. Stand back jars and HWDP. Pull nuke sources. Flush and download MWD. Pick up and change out TM HOC and probe. Upload MWD. Change out elevators. Pick up and make up DP and XO. Stand back MWD tools. Break out and service float. Change out elevators. Break and lay down bit and motor. Pull stripping rubbers. Make up new bit and motor. Break motor and adjust bend. Change out elevators and run in MWD tools. Bring up and scribe offset. Pulse test MWD. Blow down top drive. Lay down XO and DP pup. Change out elevators. PJSM. Load sources. Make up flex collars, HWDP, jars and circulating sub to 394'. Run in hole to 8895'. Fill pipe and test MWD every 3000'. Install blower hose. Service top drive. RIH to 9840'. Wash down from 9737'. Obtain parameters and MAD Pass last 10'. SPR's both pumps, 30/600, 45/710 at 9840'/1615 hours. Printed: 1/2/2007 12:56:33 PM BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: 15-12 Common Well Name: 15-12B Spud Date: 7/31/2006 Event Name: REENTER+COMPLETE Start: 12/10/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task ~ Code NPT j Phase Description of Operations 12/20/2006 16:30 - 00:00 7.50 DRILL P PROD1 Drill ahead to 9944' MD, 8891' TVD. Up weight 170k, down 140k, RT 160k. WOB 5-10k. Torque 5k off bottom, 5.5k on bottom at 40 rpm. Pump at 280 gpm with 1740 psi off bottom, 1940 psi on bottom. Mud weight in and out 8.4 ppg. 12/21/2006 00:00 - 12:00 12.00 DRILL P PROD1 Drill ahead to 10504' MD. Up weight 170k, down 135k, RT 155k. Torque 5-6k on bottom, 5k off bottom at 80 rpm. WOB 8k. Pump at 280 gpm with 1800 psi off bottom, 2050 psi on bottom. SPR's both pumps at 10018', 0130 hrs, 30/650, 45/770. Dynamic losses 40-50 BPH 12:00 - 00:00 12.00 DRILL P PROD1 Drill ahead to 10909' MD, 8912' ND. Up weight 170k, down 135k, RT 155k. WOB 6k. Torque 5k off bottom, 6k on bottom at 80 rpm. Pump at 285 gpm with 1840 psi off bottom, 2100 psi on bottom. SPR's both pumps at 10577', 1500 hrs, 30/680, 45/790. Dynamic losses 40-50 BPH. 24 hr losses of 1175 bbls of Flo-Pro 12/22/2006 00:00 - 01:00 1.00 DRILL P PROD1 Drill ahead to 10954' MD. 01:00 - 01:30 0.50 DRILL N RREP PROD1 Trouble shoot top drive. Service top drive. Unable to rotate. Repaired electrical and able to rotate. 01:30 - 12:00 10.50 DRILL P PROD1 Drill ahead to 11326' MD. Up weight 170k, down 130k, RT 155k. Torque on bottom 7k, off bottom 5k at 80 rpm. Pump at 285 gpm with 1870 psi off bottom, 2160 psi on bottom. WOB 5-8k. SPR's both pumps at 11047', 0500 hrs, 30/690, 45/800. 12:00 - 15:00 3.00 DRILL P PROD1 Drill ahead to TD of 11500' MD, 8901' TVD. Up weight 170k, down 140k, RT 155k. Torque 7k on bottom, 6k off bottom at 80 rpm. Pump at 285 gpm with 1860 psi off bottom, 2100 psi on bottom. SPR's both pumps at 11500', 1500 hrs, 30/730, 45/830. Mud weight in and out 8.4 ppg. 15:00 - 17:30 2.50 DRILL P PROD1 Pump sweep and circulate 2 times BU. Rotate and reciprocate. 17:30 - 00:00 6.50 DRILL P PROD1 Log MAD Pass from 11500' to 9600' at 480 fph while pumping 285 gpm and rotating at 60 rpm. Slow to 15 rpm from 10000' through doglegs to 9600'. No problems encountered. Total losses for day 884 bbls. 12/23/2006 00:00 - 01:30 1.50 DRILL P PROD1 POOH from 9600' to 8895' inside 7" shoe. 01:30 - 03:00 1.50 DRILL P PROD1 Monitor well. Service rig and top drive. Grease back up wrench gripper. 03:00 - 04:30 1.50 DRILL P PROD1 RIH to 11500', no problems. 04:30 - 07:30 3.00 DRILL P PROD1 Circulate sweep and 2 times BU. Trip gas back on BU. Circulate until clean. Shut down pump and monitor well. 07:30 - 09:30 2.00 DRILL P PROD1 POOH to 8895'. Up weight 185k, down 140k. 09:30 - 11:00 1.50 DRILL P PRODi Monitor well at shoe. Drop ball and open circulating sub. After sub opened pump at 500 gpm with 1380 psi. Pump hi-vis sweep surface to surface and BU until clean. Increase in cuttings on return of sweep. Shale back with sweep. 11:00 - 15:00 4.00 DRILL P PROD1 Drop rabbit and pump dry job. Remove blower hose and monitor well. POOH to 394'. 15:00 - 20:30 5.50 DRILL P PROD1 PJSM. Lay down BHA. PJSM. Unload nukes and send off floor. Flush BHA with fresh water. Download MW D. Pull probe. Break and lay down BHA. Clear and clean tloor. 20:30 - 21:30 1.00 CASE P RUNPRD PJSM. Rig to run liner. 21:30 - 00:00 2.50 CASE P RUNPRD PJSM. Make up shoe track. Check floats. Pick up and run 4.5" 12.6#, L-80 IBT-M liner to 1254'. Losses for time period 271 bbls. 12/24/2006 00:00 - 03:30 3.50 CASE P RUNPRD RIH with 4.5" 12.6#, L-80 IBT-M liner. Losses minimal while Printed: 1/2/2007 12:56:33 PM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date j Name: 1 ell Name: 1 e: Name: From - To ~ 5-12 5-12B REENTE NABOB NABOB Hours ! '~ R+COM S ALASK S 2ES Task ~ -1 PLET A DRI Code -- E LLING i NPT ~ Start I Rig Rig Phase Spud Date: 7/31/2006 : 12/10/2006 End: Release: Number: 2ES Description of Operations 12/24/2006 00:00 - 03:30 3.50 CASE P RUNPRD running liner in hole. Run 64 joints 4.5" liner, liner hanger and liner top packer. Make up liner to mark on pipe with average torque 3800. Run in with 1 stand of DP. Up and down weight 60k with pipe full. 03:30 - 04:00 0.50 CASE P RUNPRD Stage pumps up to 250 gpm with 185 psi. Circulate 1-1/2 times liner volume. 04:00 - 10:00 6.00 CASE P RUNPRD Run liner in hole on 4" DP at 75 fpm. Slow down going through 7" liner top at 2982'. Slow to 60 fph and RIH to 8949'. Pump DP and liner volume at 7" shoe. Stage up pump to 207 gpm with 715 psi. Up weight 150k, down 140k. Shut down pump and blow down top drive. 10:00 - 12:00 2.00 CASE P RUNPRD RIH to 11468'. Make up cement head on single. RIH to 11500', tag bottom at 11500'. Pull up to free weight. Establish circulation at 83 gpm with 750 psi. Up weight 175k, down 130k. 12:00 - 15:00 3.00 CEMT P RUNPRD Circulate and condition mud for cement job. Stage up pumps over 20 minutes to 210 gpm with 1075 psi. PJSM. Start batch up of cement. 15:00 - 16:30 1.50 CEMT P RUNPRD Pump 5 bbls water, pressure test lines to 4500 psi. Pump 32 bbls 10.5 ppg Mud Push II spacer. Follow with 72 bbls Class G 15.8 ppg cement. Wash through 'T' with Perf Pill. Release DP wiper dart. Pump 40 bbls Perf Pill and displace with 86.6 bbls of 8.4 ppg FloPro mud using SCH pump truck. Observe latch up and bump blug with 126.6 bbls away and 1918 psi. CIP at 1606 hrs. Set liner hanger with 3800 psi. Set weight and confirm. Bleed off and check floats - OK. Rotate off of hanger. Swap over to rig pumps. Put 1000 psi on string and unsting. Pump cement off of liner top with 500 gpm. Slow pumps and set down, shear packer. Pick up rotate down and confirm. 16:30 - 19:00 2.50 CEMT P RUNPRD Pick up and circulate out cement at 550 gpm with 2440 psi. Approximately 20 bbls cement returns to surface. Shut down, rig down cement hea and 2 singles. Make up top drive and circulate bottoms up until clean at 470 gpm with 1150 psi while reciprocating full stand. 19:00 - 20:30 1.50 CEMT P RUNPRD Displace well to clean seawater at 500 gpm with 1150 psi. Shut down and clean shakers and trough. 20:30 - 23:30 3.00 CEMT P RUNPRD POOH from 8799' to 2475'. 23:30 - 00:00 0.50 CEMT P RUNPRD PJSM. Slip and cut 75' of drilling line. Total losses for time period 235 bbls. 12/25/2006 00:00 - 02:00 2.00 CEMT P RUNPRD PJSM. Finish slip and cut 76' drilling line. Inspect braking system and linkage. Service Elmago Spline. Check traction motor brushes and draworks chains. Change out absorb under draworks. Load test. 02:00 - 02:30 0.50 CEMT P RUNPRD Service top drive. 02:30 - 05:00 2.50 CEMT P RUNPRD PJSM. POOH and lay down 4" DP. 05:00 - 06:30 1.50 CEMT P RUNPRD POOH and lay down liner running tool. Recovered 100% of tool. Clear and clean floor. 06:30 - 09:00 2.50 BOPSU P RUNPRD Thaw slop line from cellar and change check valve on slop line. Drain stack. 09:00 - 13:30 4.50 BOPSU P OTHCMP Pull wear bushing. Install test plug. Rig up to test BOPE. Fill stack and choke. Test ROPE to 250 psi low, 3500 psi high. Test witness waived by Winton Aubert with AOGCC. 13:30 - 15:00 1.50 BOPSU N RREP OTHCMP Repair pop off, pressure relief valve on test pump. 15:00 - 18:00 3.00 BOPSU P OTHCMP First 5 tests redone to 4000 psi high. Low already tested. Finish Printed: 1/2/2007 12:56:33 PM • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: ~, From - To ~ 5-12 5-12B REENTE NABOB NABOB Hours R+COM S ALASK S 2ES ~ Task ~ i PLET A DRI i Code E LLING i NPT ~ Start I Rig Rig Phase ' Spud Date: 7/31/2006 : 12/10/2006 End: Release: Number: 2ES Description of Operations 12/25/2006 15:00 - 18:00 3.00 BOPSU P _ - OTHCMP _ -- _-- testing BOPE. Blow down and line up equipment. Pull test plug. Install wear ring. Lay down test joint. 18:00 - 20:30 2.50 PERFO P OTHCMP Secure well. Shut down for safety Christmas dinner. 20:30 - 21:30 1.00 PERFO P OTHCMP Test casing to 3500 psi. Hold for 30 minutes and chart. Bleed and blow down. 21:30 - 00:00 2.50 PERFO P OTHCMP PJSM. Pick up and rig up gun and PAC equipment. Run 2-1/2" guns to 955'. Running 1080' of loaded guns, 574' of blanks and a total run of 1674'. Running 1020' of 2-7/8" PAC DP. 12/26/2006 00:00 - 02:00 2.00 PERFUB P OTHCMP RIH with 2-1/2" pert guns from 955' to 1674'. 02:00 - 04:45 2.75 PERFUB P OTHCMP Change out handling equipment. Pick up 2-7/8 PAC DP and RIH to 269T. 04:45 - 10:30 5.75 PERFUB P OTHCMP Change out handling equipment. PJSM. RIH with perfs on 4" DP. RIH to 11389'. Up weight 175k, down 140k. 10:30 - 13:00 2.50 PERFUB P OTHCMP Pick up single. Tag bottom at 11408'. Pull up and space out pert guns. Bottom shot at 11400', top shot at 9760'. PJSM with SCH. Break circulation. Make dummy run. Engage firing sequence as directed by SCH. Good indication guns fired. Monitor well. Lossing fluid at 4 bph static. POOH above pert/ interval to 9618'. Monitor well. Pump dry job. 13:00 - 23:00 10.00 PERFUB P OTHCMP PJSM. POOH laying down DP to 2697'. Run in 20 stands from derrick and lay down. 23:00 - 00:00 1.00 PERFUB P OTHCMP PJSM. Change out handling equipment. Rig up power tongs and backups to lay down 2-7/8" PAC DP. Static losses slowed to 1 bph. Total seawater losses for time period 15 bbls. 12/27/2006 00:00 - 02:30 2.50 PERFUB P OTHCMP POOH and tay down 2-7/8" PAC drill pipe from 2697' to 1674'. 02:30 - 09:30 7.00 PERFUB P OTHCMP Change out handling equipment for Perf Guns. PJSM with SCH. POOH laying down 2-1/2" pert guns and assembly from (~ 1674'. Losses holding at <1 bph while pulling guns. Perf r intervals from 9760' to 9790', 9880' to 9910', 10030' to 10140' 10210' to 10480', 10540' to 10570', 10650' to 10960' and 11100' to 11400'. All guns fired. Rig down handling equipment. Clear and clean floor. 09:30 - 16:00 6.50 BUNCO RUNCMP Drain stack. Pull wear bushing. Change out bales on topdrive. Remove saver sub. PJSM. Install saver sub and adjust. PJSM. Rig up floor; torque-turn power tongs, computer, stabbing board, compensator and handling equipment. 16:00 - 00:00 8.00 BUNCO RUNCMP PJSM. Make up packer, tailpipe assembly. Bakerlok all connections below packer. Run 90 joints 4.5" 12.6#,13Cr-80 VamTop tubing. Total losses for time period 5 bbls seawater. 12/28/2006 00:00 - 11:00 11.00 BUNCO RUNCMP PJSM. Run 4.5" 12.6#, 13Cr-80 VamTop completion. Pulled one joint for bad collar. Tag bottom at 8808'. Torque-turn connections. Pick up and space out. Use 2 pups, 9.89' and 9.83'. Up weight 125 down 105k. Make up torque 4400#. 11:00 - 12:30 1.50 BUNCO RUNCMP Change out elevators. Remove compensator. Make up hanger and landing joint. RIH and land hanger, tail at 8805.80'. Run in lock down screws as per FMC rep. Pull landing joint. 12:30 - 16:00 3.50 BUNCO RUNCMP PJSM. Rig up circulating lines to tubing annulus. Pump 134 bbls clean seawater followed by 110 bbls seawater/corrosion inhibitor. Displace with 160 bbls clean seawater at 126 gpm with 200 psi. 16:00 - 18:00 2.00 BUNCO RUNCMP PJSM. Install landing joint. Drop ball and rod. Pull, break and lay down landing joint. Line up and pressure up tubing to 4000 psi. Hold and chart for 30 minutes. Bleed tubing down to 1500 Printed: 1/2/2007 12:56:33 PM BP EXPLORATION Operations Summary Report Legal Well Name: 15-12 Common Well Name: 15-12B Event Name: REENTER+COMPLETE Start: 12/10/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date i From - To ~ Hours Task Code' NPT i 12/28/2006 116:00 - 18:00 I 2.00 18:00 - 19:00 I 1.00 19:00 - 22:00 3.00 BOPSU P 22:00 - 00:00 2.00 BOPSU P 12/29/2006 00:00 - 03:00 3.00 WHSUR P 03:00 - 04:30 1.50 WHSUR P 04:30 - 05:00 0.50 WHSUR P 05:00 - 09:30 4.50 WHSUR P 09:30 - 12:00 I 2.501 WHSUR I P 12:00-14:30 ~ 2.50WHSURP Page 10 of 10 Spud Date: 7/31 /2006 End: Phase Description of Operations RUNCMP psi. Line up on annulus and test packer to 3500 psi for 30 minutes and chart. Bleed off tubing side and observe DCK valve shear at 600 psi. Bleed both sides to zero. Break circulation and pump both ways. Confirm circulation - OK. RUNCMP PJSM. Install TWC. Dry rod by FMC. Confirm turns and travel distance to 1-11/16". Test from top and bottom to 1000 psi for 10 minutes each. Blow down kill line and cellar circulating lines. RUNCMP PJSM. Pull mouse hole. Nipple down and stand back BOP stack. RUNCMP Prep hanger neck. PJSM. Install adapter flange. Bring tree into cellar. RUNCMP Nipple up tree and adapter flange. Blow down mud lines. RUNCMP Test void to 5000 psi for 15 minutes as per FMC rep. Fill tree with diesel, test tree to 5000 psi for 10 minutes and record on chart. RUNCMP Rig up DSM lubricator. Pull TWC. Rig down lubricator. RUNCMP Rig up LRS for freeze protect, Test lines to 2500 psi. Reverse circulate 150 bbls diesel at 126 gpm with 1050 psi to freeze protect the tubing and annulus to 2200'. Shut in. Install guage. Blow down circulating line to cuttings tank. Open up well and U-tube diesel from annulus to tubing. RUNCMP Suck back tree. Rig down circulating lines from top of tree. Rig up DSM lubricator. Install BPV and test from below to 1000 psi. Rig down and lay down DSM lubricator. RUNCMP PJSM. Remove secondary annulus valve and install tree cap, flanges and guage manifolds. Close all valves and secure well. Cleanout cellar, suck out and blow down pits. Blow down pits steam. Release rig at 1430 hrs. Printed: 1/2/2007 12:56:33 PM Printed: 1/2/2007 12:56:27 PM Halliburton Company Survey Report Company: BP Amoco Date: 1/8/2007 Time: 16:38:57 Page: 1 I Field: Prudhoe Bay Site: PB DS 15 Co-ordinate(NE1 Reference: Well: 15-12, Ttue North Vertical (TVD) Reference: 15-12B: ~a 0.0 (15-12 B:) 58.0 Well: 15-12 Section (VS) Reference: Well (O.OON,O.OOE,1 39.87Azi) Wellpath: 15-12B Survey Calculation Method: Minimum Curvature Db: Oracle -- Field: Prudhoe Bay --- --- North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 15-12 Slot Name: 15-12 Well Position: +N/-S 537.85 ft Northing: 5959401.88 ft Latitude: 70 17 40.525 N +E/-W 1145.01 ft Easting : 677428.99 ft Longitude: 148 33 47.842 W Position Uncertainty: 0.00 ft Wellpath: 15-12B Drilled From: 15-12BPB1 500292066502 Tie-on Depth: 8910.90 ft Current Datum: 15-12 B: @ 0.0 (15- 12 B:) Height 58.03 ft Above System Datum: Mean Sea Level Magnetic Data: 1 2/12/2006 Declination: 24.18 deg Field Strength: 57659 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28. 50 0.00 0.00 139.87 Survey Program for Definitive Wellpath Date: 1/8/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 98.03 5623.06 15-12 GYRODATA (98.03-7692.66) GYD-CT-CMS Gyrodata cont.casing m/s 5632.63 8910.90 15-12BP61 II FR+MS+SAG (5632.63 MWD+IFR+MS MWD +IFR + Multi Station 9010.50 11462.99 15-12B IIFR+ MS+Sag (9010.50-11 MWD+IFR+MS MWD +IFR + Multi Station Survey ', MD Incl Azim TVD __ Sys TVll -- N/S F/W - - MapN A~IapE Tool -- ft deg - deg ft ft ft ft ft ft _ --- 28.50 0.00 0.00 28.50 -29.53 0.00 0.00 5959401.88 677428.99 TIE LINE 98.03 0.12 105.30 98.03 40.00 -0.02 0.07 5959401.86 677429.06 GYD-CT-CMS 198.03 0.25 210.60 198.03 140.00 -0.23 0.06 5959401.65 677429.06 GYD-CT-CMS 298.03 0.35 219.90 298.03 240.00 -0.66 -0.25 5959401.22 677428.76 GYD-CT-CMS 398.03 0.45 227.30 398.03 340.00 -1.16 -0.73 5959400.71 677428.29 GYD-CT-CMS 498.03 0.50 227.81 498.02 439.99 -1.72 -1.34 5959400.13 677427.69 GYD-CT-CMS 598.03 0.54 228.19 598.02 539.99 -2.32 -2.02 5959399.51 677427.03 GYD-CT-CMS 698.03 0.46 236.31 698.01 639.98 -2.86 -2.70 5959398.96 677426.36 GYD-CT-CMS 798.03 0.37 244.57 798.01 739.98 -3.22 -3.33 5959398.58 677425.74 GYD-CT-CMS 898.03 0.30 271.94 898.01 839.98 -3.35 -3.88 5959398.44 677425.19 GYD-CT-CMS 998.03 0.23 299.68 998.01 939.98 -3.24 -4.32 5959398.54 677424.75 GYD-CT-CMS 1098.03 0.25 162.99 1098.01 1039.98 -3.35 -4.43 5959398.42 677424.64 GYD-CT-CMS 1198.03 0.28 23.03 1198.01 1139.98 -3.34 -4.27 5959398.44 677424.80 GYD-CT-CMS 1298.03 0.31 33.76 1298.01 1239.98 -2.89 -4.02 5959398.90 677425.04 GYD-CT-CMS 1398.03 0.33 47.49 1398.01 1339.98 -2.47 -3.66 5959399.33 677425.39 GYD-CT-CMS 1498.03 0.28 52.73 1498.00 1439.97 -2.12 -3.25 5959399.68 677425.79 GYD-CT-CMS 1598.03 0.23 57.80 1598.00 1539.97 -1.87 -2.89 5959399.94 677426.15 GYD-CT-CMS 1698.03 0.17 109.77 1698.00 1639.97 -1.81 -2.58 5959400.01 677426.45 GYD-CT-CMS 1798.03 0.12 162.68 1798.00 1739.97 -1.96 -2.41 5959399.86 677426.63 GYD-CT-CMS 1898.03 0.26 148.21 1898.00 1839.97 -2.26 -2.26 5959399.57 677426.79 GYD-CT-CMS 1998.03 0.42 132.40 1998.00 1939.97 -2.70 -1.87 5959399.14 677427.19 GYD-CT-CMS 2098.03 0.72 133.13 2097.99 2039.96 -3.37 -1.14 5959398.48 677427.93 GYD-CT-CMS 2198.03 0.72 133.91 2197.99 2139.96 -4.24 -0.23 5959397.64 677428.86 GYD-CT-CMS 2298.03 0.57 148.83 2297.98 2239.95 -5.10 0.48 5959396.79 677429.59 GYD-CT-CMS 2398.03 0.33 159.77 2397.98 2339.95 -5.80 0.84 5959396.11 677429.97 GYD-CT-CMS 2498.03 0.40 65.92 2497.98 2439.95 -5.92 1.26 5959395.99 677430.39 GYD-CT-CMS 2598.03 1.48 107.84 2597.96 2539.93 -6.18 2.81 5959395.77 677431.94 GYD-CT-CMS 2698.03 3.75 128.62 2697.85 2639.82 -8.61 6.59 5959393.43 677435.78 GYD-CT-CMS Halliburton Company Survey Report Company: BP AmoCO --- - Datr. _ _ 1/8/2007 -- Time: 16:38:57 Page: 2 Field: Pru dhoe Bay Co-ordinatelNE)Re ference: Well: 15-12, True North Site: PB DS 15 Vertica l (TVDI Refe rence: 15-12B: Qa 0.0 (15-12 B:) 58.0 Well: 15- 12 Section (VS) Reference: Well (O.OON,O.OOE,139.87Azi) VVellpath: 15- 12B Survey Calcu-atim~ I<Iethod: Minimum Curvatu re Db: Oracle Sur~ev MD Intl Azim TVD Sys'fVD N/S E/W MapN DIapF Tool ', ft deg deg ft ft ft ft ft ft 2798.03 6.48 126.56 2797.45 2739.42 -14.02 13.68 5959388.19 677443.00 GYD-CT-CMS 2898.03 8.95 122.38 2896.53 2838.50 -21.54 24.78 5959380.93 677454.27 GYD-CT-CMS 2998.03 11.08 125.49 2995.00 2936.97 -31.29 39.18 5959371.53 677468.89 GYD-CT-CMS 3098.03 14.08 126.24 3092.59 3034.56 -44.06 56.82 5959359.17 677486.83 GYD-CT-CMS 3123.03 14.84 125.60 3116.80 3058.77 -47.72 61.87 5959355.63 677491.97 GYD-CT-CMS 3148.03 15.46 125.76 3140.93 3082.90 -51.53 67.18 5959351.95 677497.36 GYD-CT-CMS 3173.03 16.17 125.39 3164.99 3106.96 -55.50 72.72 5959348.12 677503.00 GYD-CT-CMS 3198.03 17.53 125.64 3188.91 3130.88 -59.71 78.62 5959344.05 677508.99 GYD-CT-CMS 3223.03 19.19 126.17 3212.64 3154.61 -64.33 85.00 5959339.58 677515.48 GYD-CT-CMS 3248.03 19.78 126.30 3236.21 3178.18 -69.26 91.72 5959334.81 677522.32 GYD-CT-CMS 3273.03 20.41 126.28 3259.68 3201.65 -74.34 98.65 5959329.89 677529.36 GYD-CT-CMS 3298.03 21.01 126.35 3283.07 3225.04 -79.58 105.77 5959324.83 677536.60 GYD-CT-CMS 3323.03 21.53 126.47 3306.37 3248.34 -84.96 113.07 5959319.62 677544.02 GYD-CT-CMS 3348.03 21.98 126.73 3329.58 3271.55 -90.48 120.51 5959314.27 677551.59 GYD-CT-CMS 3373.03 22.43 126.90 3352.73 3294.70 -96.15 128.07 5959308.79 677559.29 GYD-CT-CMS 3398.03 22.92 127.10 3375.80 3317.77 -101.95 135.77 5959303.17 677567.12 GYD-CT-CMS 3423.03 23.61 127.41 3398.77 3340.74 -107.92 143.63 5959297.38 677575.11 GYD-CT-CMS 3448.03 24.25 127.62 3421.62 3363.59 -114.10 151.67 5959291.40 677583.30 GYD-CT-CMS 3473.03 24.78 128.05 3444.36 3386.33 -120.46 159.86 5959285.23 677591.64 GYD-CT-CMS 3498.03 25.15 128.45 3467.03 3409.00 -127.00 168.15 5959278.90 677600.08 GYD-CT-CMS 3523.03 25.42 128.79 3489.63 3431.60 -133.66 176.49 5959272.43 677608.57 GYD-CT-CMS 3548.03 25.65 129.01 3512.19 3454.16 -140.43 184.88 5959265.87 677617.12 GYD-CT-CMS 3573.03 25.78 129.10 3534.71 3476.68 -147.26 193.30 5959259.23 677625.70 GYD-CT-CMS 3598.03 25.76 129.34 3557.23 3499.20 -154.13 201.72 5959252.56 677634.28 GYD-CT-CMS 3623.03 25.80 129.59 3579.74 3521,71 -161.05 210.12 5959245.85 677642.83 GYD-CT-CMS 3648.03 25.86 129.56 3602.24 3544.21 -167.98 218.51 5959239.11 677651.39 GYD-CT-CMS 3673.03 25.90 129.77 3624.73 3566.70 -174.95 226.91 5959232.35 677659.95 GYD-CT-CMS 3698.03 25.90 129.87 3647.22 3589.19 -181.94 235.30 5959225.55 677668.50 GYD-CT-CMS 3723.03 25.89 129.83 3669.71 3611,68 -188.94 243.68 5959218.76 677677.05 GYD-CT-CMS 3748.03 25.97 129.99 3692.20 3634.17 -195.95 252.07 5959211.94 677685.59 GYD-CT-CMS 3773.03 26.02 130.02 3714.67 3656.64 -203.00 260.46 5959205.10 677694.15 GYD-CT-CMS 3798.03 25.99 130.04 3737.14 3679.11 -210.05 268.85 5959198.25 677702.71 GYD-CT-CMS 3823.03 25.83 130.18 3759.62 3701.59 -217.08 277.21 5959191.41 677711.23 GYD-CT-CMS 3848.03 25.85 130.21 3782.12 3724.09 -224.12 285.53 5959184.58 677719.71 GYD-CT-CMS 3873.03 25.73 130.37 3804.63 3746.60 -231.15 293.83 5959177.74 677728.17 GYD-CT-CMS 3898.03 25.70 130.33 3827.16 3769.13 -238.17 302.09 5959170.92 677736.60 GYD-CT-CMS 3923.03 25.61 130.35 3849.69 3791.66 -245.18 310.34 5959164.11 677745.01 GYD-CT-CMS 3948.03 25.49 130.43 3872.25 3814.22 -252.17 318.56 5959157.32 677753.39 GYD-CT-CMS 3973.03 25.52 130.49 3894.81 3836.78 -259.15 326.75 5959150.53 677761.74 GYD-CT-CMS 3998.03 25.50 130.51 3917.37 3859.34 -266.15 334.93 5959143.73 677770.09 GYD-CT-CMS 4023.03 25.52 130.66 3939.94 3881.91 -273.15 343.11 5959136.92 677778.43 GYD-CT-CMS 4048.03 25.57 130.67 3962.49 3904.46 -280.17 351.29 5959130.09 677786.77 GYD-CT-CMS 4073.03 25.52 130.70 3985.05 3927.02 -287.20 359.46 5959123.26 677795.11 GYD-CT-CMS 4098.03 25.26 130.90 4007.63 3949.60 -294.21 367.58 5959116.45 677803.39 GYD-CT-CMS 4123.03 25.24 130.83 4030.25 3972.22 -301.18 375.64 5959109.67 677811.61 GYD-CT-CMS 4148.03 25.23 130.97 4052.86 3994.83 -308.16 383.70 5959102.88 677819.83 GYD-CT-CMS 4173.03 25.23 130.97 4075.48 4017.45 -315.15 391.74 5959096.09 677828.04 GYD-CT-CMS 4198.03 25.21 130.94 4098.09 4040.06 -322.13 399.79 5959089.30 677836.25 GYD-CT-CMS 4223.03 25.16 130.93 4120.72 4062.69 -329.10 407.83 5959082.52 677844.44 GYD-CT-CMS 4248.03 25.08 130.89 4143.35 4085.32 -336.05 415.85 5959075.76 677852.63 GYD-CT-CMS 4273.03 24.99 131.01 4166.00 4107.97 -342.99 423.84 5959069.02 677860.78 GYD-CT-CMS 4298.03 24.96 130.95 4188.66 4130.63 -349.91 431.81 5959062.28 677868.91 GYD-CT-CMS Halliburton Com any P Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-12 Wellpath: 15-128 Survey ~IVID Incl ft deg zim deg VT) ft ys TVD ft Date: 1/8/2007 Time: 16:38:57 Page: 3 Co-ordinate(NE) Reference: Well: 15-12, True North Vertical (TVDI Reference: 15-12B: Qa 0.0 (15-12 B:) 58.0 Section (VS) Reference: Well (O.OON,O.OOE,139.87Azi) ~~ Survey Calculation Method: Minimum Curvature llb: Oracle N/S E/W MapN biapE Tool ft ft ft ft 4323.03 24.91 130.89 4211.33 4153.30 -356.81 439.77 5959055.57 677877.03 GYD-CT-CMS 4348.03 24.84 131.08 4234.02 4175.99 -363.71 447.71 5959048.86 677885.13 GYD-CT-CMS 4373.03 24.75 131.32 4256.71 4198.68 -370.61 455.60 5959042.15 677893.18 GYD-CT-CMS 4398.03 24.73 131.36 4279.42 4221.39 -377.53 463.45 5959035.42 677901.19 GYD-CT-CMS 4423.03 24.70 131.32 4302.13 4244.10 -384.43 471.30 5959028.71 677909.20 GYD-CT-CMS 4448.03 24.67 131.50 4324.84 4266.81 -391.34 479.13 5959021.99 677917.19 GYD-CT-CMS 4473.03 24.56 131.46 4347.57 4289.54 -398.23 486.93 5959015.28 677925.15 GYD-CT-CMS 4498.03 24.42 131.43 4370.32 4312.29 -405.09 494.70 5959008.60 677933.08 GYD-CT-CMS 4523.03 24.23 131.60 4393.10 4335.07 -411.92 502.41 5959001.96 677940.95 GYD-CT-CMS 4548.03 24.12 131.87 4415.91 4357.88 -418.73 510.05 5958995.33 677948.75 GYD-CT-CMS 4573.03 24.11 131.87 4438.73 4380.70 -425.55 517.66 5958988.69 677956.51 GYD-CT-CMS 4598.03 24.14 132.01 4461.54 4403.51 -432.38 525.26 5958982.05 677964.27 GYD-CT-CMS 4623.03 24.03 132.26 4484.37 4426.34 -439.22 532.82 5958975.38 677972.00 GYD-CT-CMS 4648.03 23.95 132.31 4507.21 4449.18 -446.06 540.34 5958968.72 677979.68 GYD-CT-CMS 4673.03 23.68 132.60 4530.08 4472.05 -452.88 547.79 5958962.09 677987.28 GYD-CT-CMS 4698.03 23.71 132.74 4552.97 4494.94 -459.69 555.18 5958955.46 677994.83 GYD-CT-CMS 4723.03 23.72 132.81 4575.86 4517.83 -466.51 562.56 5958948.80 678002.37 GYD-CT-CMS 4748.03 23.72 132.96 4598.75 4540.72 -473.36 569.93 5958942.14 678009.90 GYD-CT-CMS 4773.03 23.46 133.12 4621.66 4563.63 -480.19 577.24 5958935.48 678017.37 GYD-CT-CMS 4798.03 23.39 133.34 4644.60 4586.57 -486.99 584.48 5958928.85 678024.77 GYD-CT-CMS 4823.03 23.41 133.40 4667.54 4609.51 -493.81 591.70 5958922.20 678032.14 GYD-CT-CMS 4848.03 23.46 133.39 4690.48 4632.45 -500.64 598.92 5958915.55 678039.53 GYD-CT-CMS 4873.03 23.45 133.67 4713.41 4655.38 -507.50 606.14 5958908.87 678046.90 GYD-CT-CMS 4898.03 23.41 133.97 4736.35 4678.32 -514.38 613.31 5958902.15 678054.23 GYD-CT-CMS 4923.03 23.48 134.03 4759.29 4701.26 -521.29 620.47 5958895.42 678061.55 GYD-CT-CMS 4948.03 23.58 134.03 4782.21 4724.18 -528.23 627.64 5958888.65 678068.88 GYD-CT-CMS 4973.03 23.74 134.19 4805.11 4747.08 -535.21 634.84 5958881.84 678076.25 GYD-CT-CMS 4998.03 23.83 134.13 4827.99 4769.96 -542.23 642.08 5958874.99 678083.65 GYD-CT-CMS 5023.03 23.94 134.31 4850.84 4792.81 -549.29 649.33 5958868.10 678091.07 GYD-CT-CMS 5048.03 23.79 134.81 4873.71 4815.68 -556.39 656.54 5958861.18 678098.44 GYD-CT-CMS 5073.03 23.84 134.95 4896.58 4838.55 -563.51 663.69 5958854.23 678105.76 GYD-CT-CMS 5098.03 23.99 135.12 4919.43 4861.40 -570.68 670.85 5958847.23 678113.08 GYD-CT-CMS 5123.03 24.12 135.12 4942.26 4884.23 -577.90 678.04 5958840.18 678120.44 GYD-CT-CMS 5148.03 24.21 135.23 4965.07 4907.04 -585.16 685.26 5958833.09 678127.83 GYD-CT-CMS 5173.03 24.21 135.42 4987.87 4929.84 -592.45 692.47 5958825.98 678135.20 GYD-CT-CMS 5198.03 24.18 135.65 5010.68 4952.65 -599.77 699.64 5958818.84 678142.55 GYD-CT-CMS 5223.03 24.28 135.75 5033.47 4975.44 -607.11 706.81 5958811.66 678149.89 GYD-CT-CMS 5248.03 24.45 135.87 5056.25 4998.22 -614.50 714.00 5958804.44 678157.25 GYD-CT-CMS 5273.03 24.66 135.89 5078.99 5020.96 -621.96 721.23 5958797.16 678164.65 GYD-CT-CMS 5298,03 24.78 135.98 5101.69 5043.66 -629.47 728.50 5958789.82 678172.10 GYD-CT-CMS 5323.03 24.55 136.40 5124.41 5066.38 -637.00 735.72 5958782.46 678179.50 GYD-CT-CMS 5348.03 24.69 136.34 5147.14 5089.11 -644.54 742.91 5958775.10 678186.86 GYD-CT-CMS 5373.03 24.47 136.54 5169.88 5111.85 -652.08 750.08 5958767.73 678194.20 GYD-CT-CMS 5398.03 24.39 136.76 5192.64 5134.61 -659.60 757.17 5958760.38 678201.47 GYD-CT-CMS 5423.03 24.45 136.78 5215.40 5157.37 -667.13 764.25 5958753.02 678208.73 GYD-CT-CMS 5448.03 24.62 136.78 5238.14 5180.11 -674.69 771.36 5958745.63 678216.01 GYD-CT-CMS 5473.03 24.79 136.90 5260.85 5202.82 -682.31 778.51 5958738.18 678223.34 GYD-CT-CMS 5498.03 24.92 136.89 5283.54 5225.51 -689.98 785.69 5958730.68 678230.70 GYD-CT-CMS 5523.03 25.10 136.98 5306.20 5248.17 -697.71 792.91 5958723.13 678238.09 GYD-CT-CMS 5548.03 25.17 137.16 5328.83 5270.80 -705.48 800.14 5958715.53 678245.51 GYD-CT-CMS 5573.03 25.10 137.30 5351.46 5293.43 -713.28 807.35 5958707.91 678252.90 GYD-CT-CMS 5598.03 25.20 137.31 5374.09 5316.06 -721.09 814.56 5958700.27 678260.29 GYD-CT-CMS 5623.03 25.28 137.37 5396.70 5338.67 -728.92 821.78 5958692.60 678267.69 GYD-CT-CMS Halliburton Company Survey Report Company: BP AmoCO Field: Prudhoe Bay Site: PB DS 15 ~y'ell: 15-12 Wellpath: 15-12B Survev MD Incl ft deg zim deg VD ft ys TVD ft Date: 1/8/2007 Time: 16:38:57 Page: 4 Co-ordinate(NEI Reference: Well: 15-12, True North Vertical (TVD) RePere~nce: 15-12B: @ 0.0 (15-12 B:) 58.0 Section (VS) Reference: Well (O.OON,O.OOE,139.87Azi) Survey Calculation Method: Minimum Curvature llb: Oracle N/S E/W MapN MapE Tool ft ft ft ft J 5632.63 25.28 _ 137.39 _ 5405.38 5347.35 _ -731.94 _ 824.56 5958689.65 678270.54 MWD+IFR+MS 5665.00 27.17 138.86 5434.42 5376.39 -742.60 834.10 5958679.23 678280.33 MWD+IFR+MS 5759.08 30.16 141.18 5516.96 5458.93 -777.19 863.05 5958645.32 678310.09 MWD+IFR+MS 5850.28 29.58 138.13 5596.05 5538.02 -811.81 892.44 5958611.42 678340.29 MWD+IFR+MS 5945.38 31.19 148.04 5678.14 5620.11 -850.21 921.16 5958573.71 678369.90 MWD+IFR+MS 6039.85 31.60 150.35 5758.78 5700.75 -892.47 946.36 5958532.05 678396.09 MWD+IFR+MS 6134.27 31.84 151.02 5839.10 5781.07 -935.76 970.66 5958489.35 678421.40 MWD+IFR+MS 6228.24 30.66 147.60 5919.44 5861.41 -977.68 995.51 5958448.04 678447.24 MWD+IFR+MS 6322.85 30.56 148.00 6000.87 5942.84 -1018.44 1021.18 5958407.89 678473.86 MWD+IFR+MS 6416.11 30.33 147.09 6081.27 6023.24 -1058.32 1046.54 5958368.63 678500.15 MWD+IFR+MS 6510.41 29.47 148.53 6163.02 6104.99 -1098.09 1071.59 5958329.46 678526.13 MWD+IFR+MS 6607.10 29.53 148.55 6247.17 6189.14 -1138.70 1096.44 5958289.45 678551.93 MWD+IFR+MS 6699.29 29.41 148.10 6327.43 6269.40 -1177.30 1120.25 5958251.42 678576.65 MWD+IFR+MS 6793.47 28.98 147.90 6409.65 6351.62 -1216.26 1144.59 5958213.05 678601.90 MWD+IFR+MS 6888.22 27.95 147.99 6492.94 6434.91 -1254.54 1168.56 5958175.36 678626.76 MWD+IFR+MS 6981.94 29.52 149.20 6575.12 6517.09 -1292.99 1192.03 5958137.47 678651.13 MWD+IFR+MS 7078.10 28.86 149.35 6659.07 6601.04 -1333.31 1215.99 5958097.73 678676.03 MWD+IFR+MS 7173.65 27.69 148.62 6743.22 6685.19 -1372.10 1239.31 5958059.50 678700.26 MWD+IFR+MS 7268.52 29.16 149.25 6826.65 6768.62 -1410.79 1262.60 5958021.38 678724.46 MWD+IFR+MS 7363.46 31.02 149.10 6908.79 6850.76 -1451.66 1286.99 5957981.10 678749.81 MWD+IFR+MS 7456.95 30.46 148.35 6989.14 6931.11 -1492.50 1311.80 5957940.86 678775.57 MWD+IFR+MS 7550.63 29.59 148.00 7070.25 7012.22 -1532.33 1336.52 5957901.62 678801.22 MWD+IFR+MS 7644.37 29.75 146.91 7151.70 7093.67 -1571.44 1361.48 5957863.11 678827.09 MWD+IFR+MS 7737.58 29.15 147.22 7232.87 7174.84 -1609.90 1386.40 5957825.25 678852.91 MWD+IFR+MS 7831.85 29.73 146.13 7314.96 7256.93 -1648.62 1411.85 5957787.15 678879.27 MWD+IFR+MS 7926.44 28.92 145.84 7397.43 7339.40 -1687.02 1437.77 5957749.38 678906.08 MWD+IFR+MS 8019.44 30.17 151.12 7478.35 7420.32 -1726.10 1461.69 5957710.88 678930.92 MWD+tFR+MS 8113.78 28.92 151.08 7560.42 7502.39 -1766.82 1484.17 5957670.70 678954.35 MWD+IFR+MS 8205.77 29.36 151.58 7640.77 7582.74 -1806.12 1505.66 5957631.92 678976.76 MWD+IFR+MS 8297.90 29.89 150.84 7720.86 7662.83 -1846.03 1527.59 5957592.54 678999.63 MWD+IFR+MS 8397.81 35.12 148.25 7805.09 7747.06 -1892.25 1554.86 5957546.98 679027.99 MWD+IFR+MS 8489.36 35.85 143.85 7879.65 7821.62 -1936.29 1584.54 5957503.65 679058.69 MWD+IFR+MS 8584.65 34.78 143.84 7957.40 7899.37 -1980.77 1617.04 5957459.96 679092.23 MWD+IFR+MS 8679.73 31.43 143.42 8037.04 7979.01 -2022.58 1647.82 5957418.89 679123.99 MWD+IFR+MS 8773.63 28.10 143.88 8118.54 8060.51 -2060.12 1675.46 5957382.02 679152.50 MWD+IFR+MS 8866.37 27.28 143.33 8200.66 $142.63 -2094.81 1701.02 5957347.94 679178.88 MWD+IFR+MS 8910.90 26.85 143.66 8240.31 8182.28 -2111.09 1713.08 5957331.95 679191.31 MWD+IFR+MS 9010.50 26.69 144.15 8329.23 8271.20 -2147.34 1739.51 5957296.33 679218.58 MWD+IFR+MS 9043.64 26.29 144.21 8358.89 8300.86 -2159.33 1748.16 5957284.56 679227.52 MWD+IFR+MS 9136.53 22.02 152.26 8443.65 8385.62 -2191.45 1768.31 5957252.92 679248.42 MWD+IFR+MS 9228.75 21.39 150.54 8529.34 8471.31 -2221.39 1784.62 5957223.37 679265.44 MWD+IFR+MS 9324.15 24.30 156.83 8617.26 8559.23 -2254.60 1800.91 5957190.56 679282.50 MWD+IFR+MS 9356.54 24.66 157.48 8646.74 8588.71 -2266.97 1806.12 5957178.32 679288.00 MWD+IFR+MS 9388.64 26.40 156.42 8675.70 8617.67 -2279.70 1811.54 5957165.73 679293.72 MWD+IFR+MS 9418.31 30.18 154.90 8701.82 8643.79 -2292.50 1817.35 5957153.06 679299.82 MWD+IFR+MS 9449.87 32.32 154.10 8728.80 8670.77 -2307.28 7824.40 5957138.46 679307.22 MWD+IFR+MS 9480.72 36.19 154.45 8754.30 8696.27 -2322.92 1831.93 5957123.00 679315.12 MWD+IFR+MS 9510.79 41.92 152.17 8777.64 8719.61 -2339.82 1840.46 5957106.30 679324.04 MWD+IFR+MS 9542.73 47.70 151.46 8800.29 8742.26 -2359.65 1851.09 5957086.73 679335.14 MWD+IFR+MS 9574.04 52.78 150.76 8820.31 8762.28 -2380.72 1862.72 5957065.95 679347.26 MWD+IFR+MS 9603.97 57.09 148.23 8837.50 8779.47 -2401.81 1875.16 5957045.16 679360.20 MWD+IFR+MS 9635.33 62.23 145.39 8853.34 8795.31 -2424.44 1889.98 5957022.89 679375.55 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 1/8/2007 Timc: 16:38:57 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-12, True North Site: PB DS 15 L'erticat (TVDj Reference: f 5-126: ~a 0.0 (15-12 B:) 58.0 Weil: 15-12 Section (VS) Reference: Well (O.OON,O.OOE,139.87Azi) Wdlpath: 15-126 Survey Calculation Method: Minimum Curvature Db: Oracle Survey NiD Ind Azim TVll Sys TVD N/S FJW NIapN b4xpE Tool ft deg deg ft ft ft ft ft ft 9667.39 67.66 141.45 8866.91 8808.88 -2447.73 1907.30 5957000.01 679393.41 MWD+IFR+MS 9698.40 73.28 140.17 8877.28 8819.25 -2470.37 1925.76 5956977.81 679412.40 MWD+IFR+MS 9729.79 77.24 138.42 8885.26 8827.23 -2493.38 1945.56 5956955.28 679432.74 MWD+IFR+MS 9761.14 81.18 137.14 8891.13 8833.10 -2516.18 1966.25 5956932.98 679453.96 MWD+IFR+MS 9792.06 87.09 135.93 8894.29 8836.26 -2538.49 1987.40 5956911.17 679475.63 MWD+IFR+MS 9823.96 91.94 134.57 8894.56 8836.53 -2561.13 2009.85 5956889.06 679498.61 MWD+IFR+MS 9854.59 91.90 135.10 8893.53 8835.50 -2582.72 2031.56 5956868.00 679520.82 MWD+IFR+MS 9885.27 91.96 135.01 8892.50 8834.47 -2604.42 2053.22 5956846.82 679542.98 MWD+IFR+MS 9918.17 90.91 134.56 8891.68 8833.65 -2627.59 2076.56 5956824.21 679566.86 MWD+IFR+MS 9949.36 90.23 135.95 8891.37 8833.34 -2649.74 2098.52 5956802.58 679589.33 MWD+IFR+MS 9979.35 90.59 136.24 8891.15 8833.12 -2671.35 2119.32 5956781.47 679610.63 MWD+IFR+MS 10031.90 89.80 135.99 8890.97 8832.94 -2709.22 2155.74 5956744.47 679647.94 MWD+IFR+MS 10072.33 90.05 136.72 8891.02 8832.99 -2738.48 2183.65 5956715.88 679676.53 MWD+IFR+MS 10124.71 88.01 136.79 8891.91 8833.88 -2776.63 2219.53 5956678.60 679713.30 MWD+IFR+MS 10165.63 87.08 137.38 8893.66 8835.63 -2806.57 2247.36 5956649.32 679741.83 MWD+IFR+MS 10212.36 87.02 136.76 8896.07 8838.04 -2840.74 2279.15 5956615.92 679774.41 MWD+IFR+MS 10258.89 86.95 135.77 8898.52 8840.49 -2874.31 2311.27 5956583.11 679807.31 MWD+IFR+MS 10312.51 86.83 135.08 8901.43 8843.40 -2912.45 2348.85 5956545.87 679845.78 MWD+IFR+MS 10351.56 86.90 135.81 8903.56 8845.53 -2940.23 2376.20 5956518.75 679873.78 MWD+IFR+MS 10444.55 86.96 136.33 8908.54 8850.51 -3007.11 2440.63 5956453.42 679939.76 MWD+IFR+MS 10490.09 87.08 135.86 8910.91 8852.88 -3039.87 2472.16 5956421.40 679972.06 MWD+IFR+MS 10538.25 88.56 135.42 8912.74 8854.71 -3074.28 2505.81 5956387.80 680006.51 MWD+IFR+MS 10587.41 88.93 135.12 8913.82 8855.79 -3109.19 2540.40 5956353.72 680041.91 MWD+IFR+MS 10631.10 89.42 135.74 8914.45 8856.42 -3140.32 2571.06 5956323.33 680073.29 MWD+IFR+MS 10680.48 90.35 136.80 8914.55 8856.52 -3176.00 2605.19 5956288.47 680108.25 MWD+IFR+MS 10726.52 90.41 136.49 8914.24 8856.21 -3209.47 2636.80 5956255.75 680140.64 MWD+IFR+MS 10775.67 90.60 136.65 8913.81 8855.78 -3245.16 2670.58 5956220.87 680175.26 MWD+IFR+MS 10820.19 90.66 136.28 8913.32 8855.29 -3277.44 2701.25 5956189.33 680206.67 MWD+IFR+MS 10869.83 90.66 135.67 8912.75 8854.72 -3313.13 2735.74 5956154.46 680242.00 MWD+IFR+MS 10914.63 90.67 135.78 8912.23 8854.20 -3345.20 2767.02 5956123.14 680274.02 MWD+IFR+MS 10962.67 90.42 135.37 8911.77 8853.74 -3379.51 2800.64 5956089.64 680308.44 MWD+IFR+MS 11008.09 89.49 135.09 8911.80 8853.77 -3411.75 2832.63 5956058.16 680341.18 MWD+IFR+MS 11058.37 89.86 135.80 8912.09 8854.06 -3447.58 2867.90 5956023.17 680377.29 MWD+IFR+MS 11101.66 90.54 136.37 8911.94 8853.91 -3478.77 2897.93 5955992.71 680408.04 MWD+IFR+MS 11150.91 90.60 135.51 8911.45 8853.42 -3514.16 2932.18 5955958.14 680443.11 MWD+IFR+MS 11194.30 91.27 135.98 8910.74 8852.71 -3545.23 2962.45 5955927.79 680474.11 MWD+IFR+MS 11244.48 92.44 135.80 8909.12 8851.09 -3581.24 2997.36 5955892.62 680509.85 MWD+IFR+MS 11287.36 92.21 135.92 8907.38 8849.35 -3611.99 3027.20 5955862.59 680540.41 MWD+IFR+MS 11332.75 91.71 136.39 8905.82 8847.79 -3644.70 3058.62 5955830.62 680572.59 MWD+IFR+MS 11382.35 91.66 136.13 8904.37 8846.34 -3680.52 3092.90 5955795.63 680607.70 MWD+IFR+MS 11427.53 91.65 136.36 8903.06 8845.03 -3713.14 3124.13 5955763.75 680639.70 MWD+IFR+MS 11462.99 91.34 136.40 8902.14 8844.11 -3738.80 3148.59 5955738.68 680664.75 MWD+IFR+MS 11500.00 91.34 136.40 8901.27 8843.24 -3765.60 3174.10 5955712.49 680690.89 PROJECTED to TD Halliburton Company Survey Report Company: BPAmOCO ___ Date: 1/9/2007 _- - Time: 15:43:16 __ Page: 1 Field: Prudhoe Bay Co-ordinatelNE) Reference: Well: 15-12, True N orth Site: PB DS 15 Vertical (TVD) Kefer ence: 15-12BPB1: 62.4 Well: 15-12 Section (VS) Reference: Well (O.OON,O.OOE,1 40.98Azi) Wellpath: 15-12BPB1 Survey Calculation Method: Minimum Curvature llb: Oracle 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: bggm2006 Well: 15-12 Slot Name: 15-12 Well Position: +N/-S 537.85 ft Northing: 5959401.88 ft Latitude: 70 17 40.525 N +E/-W 1145.01 ft Easting : 677428.99 ft Longitude: 148 33 47.842 W Position Uncertainty: 0.00 ft Wellpath: 15-12BPB1 Drilled From: 15-12 500292066570 Tie-on Depth: 5627.43 ft Current Datum: 15-12 BPB1: Height 62.40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/21/2006 Declination: 24.36 deg Field Strength: 57651 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32 .87 0.00 0.00 140.98 Survey Program for DeTinitive Wellpath Date: 9/22/2006 Validated: Yes Version: 15 Actual From To Survey Toolcode Tool Name ft ft 102.40 5627.43 15-12 GYRODATA (102. 40-7697.03 GYD-CT-CMS Gyrodata cont.casing m/s 5637.00 8915.27 15-126PB1 IIFR+MS+SAG (5637.00 MWD+IFR+MS MWD +IFR + Multi Station Survey hiD Incl Azim TVD Sys'I'VD N/S FJV1' A1apN MapE Tool ft deg deg ft ft ft ft ft ft 32.87 0.00 0.00 32.87 -29.53 0.00 0.00 5959401.88 677428.99 TIE LINE 102.40 0.12 105.30 102.40 40.00 -0.02 0.07 5959401.86 677429.06 GYD-CT-CMS 202.40 0.25 210.60 202.40 140.00 -0.23 0.06 5959401.65 677429.06 GYD-CT-CMS 302.40 0.35 219.90 302.40 240.00 -0.66 -0.25 5959401.22 677428.76 GYD-CT-CMS 402.40 0.45 227.30 402.40 340.00 -1.16 -0.73 5959400.71 677428.29 GYD-CT-CMS 502.40 0.50 227.81 502.39 439.99 -1.72 -1.34 5959400.13 677427.69 GYD-CT-CMS 602.40 0.54 228.19 602.39 539.99 -2.32 -2.02 5959399.51 677427.03 GYD-CT-CMS 702.40 0.46 236.31 702.38 639.98 -2.86 -2.70 5959398.96 677426.36 GYD-CT-CMS 802.40 0.37 244.57 802.38 739.98 -3.22 -3.33 5959398.58 677425.74 GYD-CT-CMS 902.40 0.30 271.94 902.38 839.98 -3.35 -3.88 5959398.44 677425.19 GYD-CT-CMS 1002.40 0.23 299.68 1002.38 939.98 -3.24 -4.32 5959398.54 677424.75 GYD-CT-CMS 1102.40 0.25 162.99 1102.38 1039.98 -3.35 -4.43 5959398.42 677424.64 GYD-CT-CMS 1202.40 0.28 23.03 1202.38 1139.98 -3.34 -4.27 5959398.44 677424.80 GYD-CT-CMS 1302.40 0.31 33.76 1302.38 1239.98 -2.89 -4.02 5959398.90 677425.04 GYD-CT-CMS 1402.40 0.33 47.49 1402.38 1339.98 -2.47 -3.66 5959399.33 677425.39 GYD-CT-CMS 1502.40 0.28 52.73 1502.37 1439.97 -2.12 -3.25 5959399.68 677425.79 GYD-CT-CMS 1602.40 0.23 57.80 1602.37 1539.97 -1.87 -2.89 5959399.94 677426.15 GYD-CT-CMS 1702.40 0.17 109.77 1702.37 1639.97 -1.81 -2.58 5959400.01 677426.45 GYD-CT-CMS 1802.40 0.12 162.68 1802.37 1739.97 -1.96 -2.41 5959399.86 677426.63 GYD-CT-CMS 1902.40 0.26 148.21 1902.37 1839.97 -2.26 -2.26 5959399.57 677426.79 GYD-CT-CMS 2002.40 0.42 132.40 2002.37 1939.97 -2.70 -1.87 5959399.14 677427.19 GYD-CT-CMS 2102.40 0.72 133.13 2102.36 2039.96 -3.37 -1.14 5959398.48 677427.93 GYD-CT-CMS 2202.40 0.72 133.91 2202.36 2139.96 -4.24 -0.23 5959397.64 677428.86 GYD-CT-CMS 2302.40 0.57 148.83 2302.35 2239.95 -5.10 0.48 5959396.79 677429.59 GYD-CT-CMS 2402.40 0.33 159.77 2402.35 2339.95 -5.80 0.84 5959396.11 677429.97 GYD-CT-CMS 2502.40 0.40 65.92 2502.35 2439.95 -5.92 1.26 5959395.99 677430.39 GYD-CT-CMS 2602.40 1.48 107.84 2602.33 2539.93 -6.18 2.81 5959395.77 677431.94 GYD-CT-CMS 2702.40 3.75 128.62 2702.22 2639.82 -8.61 6.59 5959393.43 677435.78 GYD-CT-CMS 2802.40 6.48 126.56 2801.82 2739.42 -14.02 13.68 5959388.19 677443.00 GYD-CT-CMS Halliburton Company Survey Report '~ Company: BP Amoco Field: Prudhoe Bay I Site: PB DS 15 ~'~i Well: 15-12 '~Wellpath: 15-12BPB1 Survey IV1D lncl ft deg cim deg VD ft ys TVD ft Date: 1/9/2007 Time: 15:43:16 Page: 2 Co-ordinatetNE) Reference: Well: 15-12, True North Vertical (TVD) Reference: 15-12BPB1: 62.4 Section (VS) Reference: Well (O.OON,O.OOE,140.98Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S F./VV IVIapN MapF, 1'001 ft ft ft ft 2902.40 8.95 122.38 2900.90 2838.50 -21.54 24.78 5959380.93 677454.27 GYD-CT-CMS 3002.40 11.08 125.49 2999.37 2936.97 -31.29 39.18 5959371.53 677468.89 GYD-CT-CMS 3102.40 14.08 126.24 3096.96 3034.56 -44.06 56.82 5959359.17 677486.83 GYD-CT-CMS 3127.40 14.84 125.60 3121.17 3058.77 -47.72 61.87 5959355.63 677491.97 GYD-CT-CMS 3152.40 15.46 125.76 3145.30 3082.90 -51.53 67.18 5959351.95 677497.36 GYD-CT-CMS 3177.40 16.17 125.39 3169.36 3106.96 -55.50 72.72 5959348.12 677503.00 GYD-CT-CMS 3202.40 17.53 125.64 3193.28 3130.88 -59.71 78.62 5959344.05 677508.99 GYD-CT-CMS 3227.40 19.19 126.17 3217.01 3154.61 -64.33 85.00 5959339.58 677515.48 GYD-CT-CMS 3252.40 19.78 126.30 3240.58 3178.18 -69.26 91.72 5959334.81 677522.32 GYD-CT-CMS 3277.40 20.41 126.28 3264.05 3201.65 -74.34 98.65 5959329.89 677529.36 GYD-CT-CMS 3302.40 21.01 126.35 3287.44 3225.04 -79.58 105.77 5959324.83 677536.60 GYD-CT-CMS 3327.40 21.53 126.47 3310.74 3248.34 -84.96 113.07 5959319.62 677544.02 GYD-CT-CMS 3352.40 21.98 126.73 3333.95 3271.55 -90.48 120.51 5959314.27 677551.59 GYD-CT-CMS 3377.40 22.43 126.90 3357.10 3294.70 -96.15 128.07 5959308.79 677559.29 GYD-CT-CMS 3402.40 22.92 127.10 3380.17 3317.77 -101.95 135.77 5959303.17 677567.12 GYD-CT-CMS 3427.40 23.61 127.41 3403.14 3340.74 -107.92 143.63 5959297.38 677575.11 GYD-CT-CMS 3452.40 24.25 127.62 3425.99 3363.59 -114.10 151.67 5959291.40 677583.30 GYD-CT-CMS 3477.40 24.78 128.05 3448.73 3386.33 -120.46 159.86 5959285.23 677591.64 GYD-CT-CMS 3502.40 25.15 128.45 3471.40 3409.00 -127.00 168.15 5959278.90 677600.08 GYD-CT-CMS 3527.40 25.42 128.79 3494.00 3431.60 -133.66 176.49 5959272.43 677608.57 GYD-CT-CMS 3552.40 25.65 129.01 3516.56 3454.16 -140.43 184.88 5959265.87 677617.12 GYD-CT-CMS 3577.40 25.78 129.10 3539.08 3476.68 -147.26 193.30 5959259.23 677625.70 GYD-CT-CMS 3602.40 25.76 129.34 3561.60 3499.20 -154.13 201.72 5959252.56 677634.28 GYD-CT-CMS 3627.40 25.80 129.59 3584.11 3521.71 -161.05 210.12 5959245.85 677642.83 GYD-CT-CMS 3652.40 25.86 129.56 3606.61 3544.21 -167.98 218.51 5959239.11 677651.39 GYD-CT-CMS 3677.40 25.90 129.77 3629.10 3566.70 -174.95 226.91 5959232.35 677659.95 GYD-CT-CMS 3702.40 25.90 129.87 3651.59 3589.19 -181.94 235.30 5959225.55 677668.50 GYD-CT-CMS 3727.40 25.89 129.83 3674.08 3611.68 -188.94 243.68 5959218.76 677677.05 GYD-CT-CMS 3752.40 25.97 129.99 3696.57 3634.17 -195.95 252.07 5959211.94 677685.59 GYD-CT-CMS 3777.40 26.02 130.02 3719.04 3656.64 -203.00 260.46 5959205.10 677694.15 GYD-CT-CMS 3802.40 25.99 130.04 3741.51 3679.11 -210.05 268.85 5959198.25 677702.71 GYD-CT-CMS 3827.40 25.83 130.18 3763.99 3701.59 -217.08 277.21 5959191.41 677711.23 GYD-CT-CMS 3852.40 25.85 130.21 3786.49 3724.09 -224.12 285.53 5959184.58 677719.71 GYD-CT-CMS 3877.40 25.73 130.37 3809.00 3746.60 -231.15 293.83 5959177.74 677728.17 GYD-CT-CMS 3902.40 25.70 130.33 3831.53 3769.13 -238.17 302.09 5959170.92 677736.60 GYD-CT-CMS 3927.40 25.61 130.35 3854.06 3791.66 -245.18 310.34 5959164.11 677745.01 GYD-CT-CMS 3952.40 25.49 130.43 3876.62 3814.22 -252.17 318.56 5959157.32 677753.39 GYD-CT-CMS 3977.40 25.52 130.49 3899.18 3836.78 -259.15 326.75 5959150.53 677761.74 GYD-CT-CMS 4002.40 25.50 130.51 3921.74 3859.34 -266.15 334.93 5959143.73 677770.09 GYD-CT-CMS 4027.40 25.52 130.66 3944.31 3881.91 -273.15 343.11 5959136.92 677778.43 GYD-CT-CMS 4052.40 25.57 130.67 3966.86 3904.46 -280.17 351.29 5959130.09 677786.77 GYD-CT-CMS 4077.40 25.52 130.70 3989.42 3927.02 -287.20 359.46 5959123.26 677795.11 GYD-CT-CMS 4102.40 25.26 130.90 4012.00 3949.60 -294.21 367.58 5959116.45 677803.39 GYD-CT-CMS 4127.40 25.24 130.83 4034.62 3972.22 -301.18 375.64 5959109.67 677811.61 GYD-CT-CMS 4152.40 25.23 130.97 4057.23 3994.83 -308.16 383.70 5959102.88 677819.83 GYD-CT-CMS 4177.40 25.23 130.97 4079.85 4017.45 -315.15 391.74 5959096.09 677828.04 GYD-CT-CMS 4202.40 25.21 130.94 4102.46 4040.06 -322.13 399.79 5959089.30 677836.25 GYD-CT-CMS 4227.40 25.16 130.93 4125.09 4062.69 -329.10 407.83 5959082.52 677844.44 GYD-CT-CMS 4252.40 25.08 130.89 4147.72 4085.32 -336.05 415.85 5959075.76 677852.63 GYD-CT-CMS 4277.40 24.99 131.01 4170.37 4107.97 -342.99 423.84 5959069.02 677860.78 GYD-CT-CMS 4302.40 24.96 130.95 4193.03 4130.63 -349.91 431.81 5959062.28 677868.91 GYD-CT-CMS 4327.40 24.91 130.89 4215.70 4153.30 -356.81 439.77 5959055.57 677877.03 GYD-CT-CMS Halliburton Company Survey Report Company: BP AmOCO Field: Prudhoe Bay Site: PB DS 15 Well: 15-12 Wcllpath: 15-12BPB1 Survey __ Mll Incl ', ft deg im deg _ TVD ft s "fVll ft Date: 1/9/2007 Timc: 15:43:16 Yaffe: 3 Co-ordinate(NE) Reference: Well: 15-12, True North Vertical (TVD) Reference: 15-12BPB1: 62.4 Section (VS) Reference: Well (O.OON,O.OOE,140.98Azi) Survey Calculation Yiethod: Minimum Curvature Db: OraCle -__ __ N/S >//V1' MapN MapF. Tool ft ft ft ft 4352.40 24.84 131.08 4238.39 4175.99 -363.71 447.71 5959048.86 677885.13 GYD-CT-CMS 4377.40 24.75 131.32 4261.08 4198.68 -370.61 455.60 5959042.15 677893.18 GYD-CT-CMS 4402.40 24.73 131.36 4283.79 4221.39 -377.53 463.45 5959035.42 677901.19 GYD-CT-CMS 4427.40 24.70 131.32 4306.50 4244.10 -384.43 471.30 5959028.71 677909.20 GYD-CT-CMS 4452.40 24.67 131.50 4329.21 4266.81 -391.34 479.13 5959021.99 677917.19 GYD-CT-CMS 4477.40 24.56 131.46 4351.94 4289.54 -398.23 486.93 5959015.28 677925.15 GYD-CT-CMS 4502.40 24.42 131.43 4374.69 4312.29 -405.09 494.70 5959008.60 677933.08 GYD-CT-CMS 4527.40 24.23 131.60 4397.47 4335.07 -411.92 502.41 5959001.96 677940.95 GYD-CT-CMS 4552.40 24.12 131.87 4420.28 4357.88 -418.73 510.05 5958995.33 677948.75 GYD-CT-CMS 4577.40 24.11 131.87 4443.10 4380.70 -425.55 517.66 5958988.69 677956.51 GYD-CT-CMS 4602.40 24.14 132.01 4465.91 4403.51 -432.38 525.26 5958982.05 677964.27 GYD-CT-CMS 4627.40 24.03 132.26 4488.74 4426.34 -439.22 532.82 5958975.38 677972.00 GYD-CT-CMS 4652.40 23.95 132.31 4511.58 4449.18 -446.06 540.34 5958968.72 677979.68 GYD-CT-CMS 4677.40 23.68 132.60 4534.45 4472.05 -452.88 547.79 5958962.09 677987.28 GYD-CT-CMS 4702.40 23.71 132.74 4557.34 4494.94 -459.69 555.18 5958955.46 677994.83 GYD-CT-CMS 4727.40 23.72 132.81 4580.23 4517.83 -466.51 562.56 5958948.80 678002.37 GYD-CT-CMS 4752.40 23.72 132.96 4603.12 4540.72 -473.36 569.93 5958942.14 678009.90 GYD-CT-CMS 4777.40 23.46 133.12 4626.03 4563.63 -480.19 577.24 5958935.48 678017.37 GYD-CT-CMS 4802.40 23.39 133.34 4648.97 4586.57 -486.99 584.48 5958928.85 678024.77 GYD-CT-CMS 4827.40 23.41 133.40 4671.91 4609.51 -493.81 591.70 5958922.20 678032.14 GYD-CT-CMS 4852.40 23.46 133.39 4694.85 4632.45 -500.64 598.92 5958915.55 678039.53 GYD-CT-CMS 4877.40 23.45 133.67 4717.78 4655.38 -507.50 606.14 5958908.87 678046.90 GYD-CT-CMS 4902.40 23.41 133.97 4740.72 4678.32 -514.38 613.31 5958902.15 678054.23 GYD-CT-CMS 4927.40 23.48 134.03 4763.66 4701.26 -521.29 620.47 5958895.42 678061.55 GYD-CT-CMS 4952.40 23.58 134.03 4786.58 4724.18 -528.23 627.64 5958888.65 678068.88 GYD-CT-CMS 4977.40 23.74 134.19 4809.48 4747.08 -535.21 634.84 5958881.84 678076.25 GYD-CT-CMS 5002.40 23.83 134.13 4832.36 4769.96 -542.23 642.08 5958874.99 678083.65 GYD-CT-CMS 5027.40 23.94 134.31 4855.21 4792.81 -549.29 649.33 5958868.10 678091.07 GYD-CT-CMS 5052.40 23.79 134.81 4878.08 4815.68 -556.39 656.54 5958861.18 678098.44 GYD-CT-CMS 5077.40 23.84 134.95 4900.95 4838.55 -563.51 663.69 5958854.23 678105.76 GYD-CT-CMS 5102.40 23.99 135.12 4923.80 4861.40 -570.68 670.85 5958847.23 678113.08 GYD-CT-CMS 5127.40 24.12 135.12 4946.63 4884.23 -577.90 678.04 5958840.18 678120.44 GYD-CT-CMS 5152.40 24.21 135.23 4969.44 4907.04 -585.16 685.26 5958833.09 678127.83 GYD-CT-CMS 5177.40 24.21 135.42 4992.24 4929.84 -592.45 692.47 5958825.98 678135.20 GYD-CT-CMS 5202.40 24.18 135.65 5015.05 4952.65 -599.77 699.64 5958818.84 678142.55 GYD-CT-CMS 5227.40 24.28 135.75 5037.84 4975.44 -607.11 706.81 5958811.66 678149.89 GYD-CT-CMS 5252.40 24.45 135.87 5060.62 4998.22 -614.50 714.00 5958804.44 678157.25 GYD-CT-CMS 5277.40 24.66 135.89 5083.36 5020.96 -621.96 721.23 5958797.16 678164.65 GYD-CT-CMS 5302.40 24.78 135.98 5106.06 5043.66 -629.47 728.50 5958789.82 678172.10 GYD-CT-CMS 5327.40 24.55 136.40 5128.78 5066.38 -637.00 735.72 5958782.46 678179.50 GYD-CT-CMS 5352.40 24.69 136.34 5151.51 5089.11 -644.54 742.91 5958775.10 678186.86 GYD-CT-CMS 5377.40 24.47 136.54 5174.25 5111.85 -652.08 750.08 5958767.73 678194.20 GYD-CT-CMS 5402.40 24.39 136.76 5197.01 5134.61 -659.60 757.17 5958760.38 678201.47 GYD-CT-CMS 5427.40 24.45 136.78 5219.77 5157.37 -667.13 764.25 5958753.02 678208.73 GYD-CT-CMS 5452.40 24.62 136.78 5242.51 5180.11 -674.69 771.36 5958745.63 678216.01 GYD-CT-CMS 5477.40 24.79 136.90 5265.22 5202.82 -682.31 778.51 5958738.18 678223.34 GYD-CT-CMS 5502.40 24.92 136.89 5287.91 5225.51 -689.98 785.69 5958730.68 678230.70 GYD-CT-CMS 5527.40 25.10 136.98 5310.57 5248.17 -697.71 792.91 5958723.13 678238.09 GYD-CT-CMS 5552.40 25.17 137.16 5333.20 5270.80 -705.48 800.14 5958715.53 678245.51 GYD-CT-CMS 5577.40 25.10 137.30 5355.83 5293.43 -713.28 807.35 5958707.91 678252.90 GYD-CT-CMS 5602.40 25.20 137.31 5378.46 5316.06 -721.09 814.56 5958700.27 678260.29 GYD-CT-CMS 5627.40 25.28 137.37 5401.07 5338.67 -728.92 821.78 5958692.60 678267.69 GYD-CT-CMS 5637.00 25.28 137.39 5409.75 5347.35 -731.94 824.56 5958689.65 678270.54 MWD+IFR+MS Halliburton Company Survey Report ~~~ Company: BP AmoCO Date: 1/9/2007 Time: 15:43:16 Page: 4 Field: Pru dhoe Bay Co-ord inate(NE) Re ference: W ell: 15-12, True North Site: PB DS 15 Vertica l (TVD) Reference: 15 -12BPB1: 62.4 y~'ell: 15- 12 Section (VS) Reference: W eli (O.OON,O.OOE,140.9$Azi) j yVcllpath: 15- 12BPB1 Survey Calculation Method: Mi nimum Curvatu re Db: Oracle Survey A4D - Incl -__ -- Azim TVD _ ._-- Sys'fVD N/S -_ _ __ E/W _ 113apN -- NiapE _ _ _ _.- l Tool ft deg deg ft ft ft ft ft ft I 5669.37 27.17 138.86 5438.79 5376.39 -742.60 834.10 5958679.23 678280.33 MWD+IFR+MS 5763.45 30.16 141.18 5521.33 5458.93 -777.19 863.05 5958645.32 678310.09 MWD+IFR+MS 5854.65 29.58 138.13 5600.42 5538.02 -811.81 892.44 5958611.42 678340.29 MWD+IFR+MS 5949.75 31.19 148.04 5682.51 5620.11 -850.21 921.16 5958573.71 678369.90 MWD+IFR+MS 6044.22 31.60 150.35 5763.15 5700.75 -892.47 946.36 5958532.05 678396.09 MWD+IFR+MS 6138.64 31.84 151.02 5843.47 5781.07 -935.76 970.66 5958489.35 678421.40 MWD+IFR+MS 6232.61 30.66 147.60 5923.81 5861.41 -977.68 995.51 5958448.04 678447.24 MWD+IFR+MS 6327.22 30.56 148.00 6005.24 5942.84 -1018.44 1021.18 5958407.89 678473.86 MWD+IFR+MS 6420.48 30.33 147.09 6085.64 6023.24 -1058.32 1046.54 5958368.63 678500.15 MWD+IFR+MS 6514.78 29.47 148.53 6167.39 6104.99 -1098.09 1071.59 5958329.46 678526.13 MWD+IFR+MS 6611.47 29.53 148.55 6251.54 6189.14 -1138.70 1096.44 5958289.45 678551.93 MWD+IFR+MS 6703.66 29.41 148.10 6331.80 6269.40 -1177.30 1120.25 5958251.42 678576.65 MWD+IFR+MS 6797.84 28.98 147.90 6414.02 6351.62 -1216.26 1144.59 5958213.05 678601.90 MWD+IFR+MS 6892.59 27.95 147.99 6497.31 6434.91 -1254.54 1168.56 5958175.36 678626.76 MWD+IFR+MS 6986.31 29.52 149.20 6579.49 6517.09 -1292.99 1192.03 5958137.47 678651.13 MWD+IFR+MS 7082.47 28.86 149.35 6663.44 6601.04 -1333.31 1215.99 5958097.73 678676.03 MWD+IFR+MS 7178.02 27.69 148.62 6747.59 6685.19 -1372.10 1239.31 5958059.50 678700.26 MWD+IFR+MS 7272.89 29:16 149.25 6831.02 6768.62 -1410.79 1262.60 5958021.38 678724.46 MWD+IFR+MS 7367.83 31.02 149.10 6913.16 6850.76 -1451.66 1286.99 5957981.10 678749.81 MWD+IFR+MS 7461.32 30.46 148.35 6993.51 6931.11 -1492.50 1311.80 5957940.86 678775.57 MWD+IFR+MS 7555.00 29.59 148.00 7074.62 7012.22 -1532.33 1336.52 5957901.62 678801.22 MWD+IFR+MS 7648.74 29.75 146.91 7156.07 7093.67 -1571.44 1361.48 5957863.11 678827.09 MWD+IFR+MS 7741.95 29.15 147.22 7237.24 7174.84 -1609.90 1386.40 5957825.25 678852.91 MWD+IFR+MS 7836.22 29.73 146.13 7319.33 7256.93 -1648.62 1411.85 5957787.15 678879.27 MWD+IFR+MS 7930.81 28.92 145.84 7401.80 7339.40 -1687.02 1437.77 5957749.38 678906.08 MWD+IFR+MS 8023.81 30.17 151.12 7482.72 7420.32 -1726.10 1461.69 5957710.88 678930.92 MWD+IFR+MS 8118.15 28.92 151.08 7564.79 7502.39 -1766.82 1484.17 5957670.70 678954.35 MWD+IFR+MS 8210.14 29.36 151.58 7645.14 7582.74 -1806.12 1505.66 5957631.92 678976.76 MWD+IFR+MS 8302.27 29.89 150.84 7725.23 7662.83 -1846.03 1527.59 5957592.54 678999.63 MWD+IFR+MS 8402.18 35.12 148.25 7809.46 7747.06 -1892.25 1554.86 5957546.98 679027.99 MWD+IFR+MS 8493.73 35.85 143.85 7884.02 7821.62 -1936.29 1584.54 5957503.65 679058.69 MWD+IFR+MS 8589.02 34.78 143.84 7961.77 7899.37 -1980.77 1617.04 5957459.96 679092.23 MWD+IFR+MS 8684.10 31.43 143.42 8041.41 7979.01 -2022.58 1647.82 5957418.89 679123.99 MWD+IFR+MS 8778.00 28.10 143.88 8122.91 8060.51 -2060.12 1675.46 5957382.02 679152.50 MWD+IFR+MS 8870.74 27.28 143.33 8205.03 8142.63 -2094.81 1701.02 5957347.94 679178.88 MWD+IFR+MS 8915.27 26.85 143.66 8244.68 8182.28 -2111.09 1713.08 5957331.95 679191.31 MWD+IFR+MS 8999.00 26.85 143.66 8319.38 8256.98 -2141.56 1735.49 5957302.02 679214.43 PROJECTED to TD • • 10-Jan-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-12B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,910.90' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 11,500.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ A ~ ~ , . Date ~•g Jn~.~.0~1"~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~u~e- b ~7 • • 10-Jan-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-12B PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,627.43' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 8,999.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~.1b-u2~7 r ~, ~J ALASKA OIL A11TD GAS C011TSERQATI011T CODIIrIISSIOI~T Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSK/, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-12B Sundry Number: 306-350 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. y~ DATED this- day of October, 2006 Encl. ~incerely_ -z ~~ STATE OF ALASKA ~'D~'a~~~a ~~ ~,.~ ~ ~ ~00~ ALA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVAL ~~ ~:<.,- ~~~ G~~ Cons. Commission 20 AAC 25.280 ~tlltgora~o 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Re-Start O erations after shutdown 2. Operator Name: 4. Current Well Class: ~ 5. Permit T~Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-087 / 306-279 3. Address: ^ Stratigraphic ^ Service 6. API Number: r P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20665-02-00 7, If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 15-12B / Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028309 62.4' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8999 8316 8850 8183 8850 None asin Len th Size MD TVD Burst Colla se Structural ondu r 80' 20" 80' 80' 1490 470 Surface 2482' 13-3/8" 248 ' 2482' 4930 2670 Intermediate 8697' 9-5/8" 7 ' - 8697' 5164' - 8261' 6870 4760 Producti n Liner 5975' 7" 2982' - 8957' 2979' - 8278' 7240 5410 Perforation Depth MD ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~ None None / Kill String: 4-1/2", 12.6# L-80 2930' Packers and SSSV Type: None Packers and SSSV MD (ft): None ~ 13. Attachments: 14. Well Class after proposed work: ~' ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Octob 26, 06 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: D ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name -Fto t#~ aeh~ (-2~ ~~,~,~5 Title Senior Drilling Engineer Prepared By Name/Number: Signature ~ Phone 564-b-1~53'~le ~ Date /J Z~ ~~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness ,/ ^ Plug Integrity L~J BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ .e s t- ~ 4 l? L` ~- d L~-v D d !D L.(. ~~~, C3~~ ~ ~ 2~~6 Subsequent Form Required: ~~ ~ APPROVED BY ~' ~~ A roved B COMMI - IONER THE COMMISSION Date / Form 10-403 Revised 06/2006 Submit In Duplicate GRIGIN L -=-~ ~' ~~ To: Winton Aubert - AOGCC Date: From: Ron Phillips - BPXA GPB Rotary Drilling October 19, 2006 Subject: 15-126 Application for Sundry Approval - To resume drilling operations Reference: API # 50-029-20665-01 Approval is requested to resume drilling and completing 15-12B. History: When we drilled out the 7" drilling liner shoe track and 20 feet of new formation we started taking losses (104 bbls/hr). We think we hit the small fault that was supposed to be above the drilling liner shoe and behind cement. We decided to drill another 20 feet with LCM, but losses went to 500 bbls/hr. D tttalt the activity on the slope (lack of vac trucks due to the shut in of GPB), we elected to temporarily spend~~this well by setting an EZSV in the 7" drilling liner as deep as possible (8,850'). The EZSV was t ,_ d~t`o~ 3,500psi for 30 minutes, and charted. We displaced to seawater above the EZSV. We ran 2,930' of 4 1/2" kill string and freeze protected the well with diesel. We installed a BPV to finish securing the well. We moved off of 15-126 on August 18, 2006. Plan forward: Pull the 4'/z" kill string, drill up the EZSV with a used 6 1/8" tri-cone bit, then drill 200' of new formation to get us past the fault, which is nearly parallel to the well bore. While drilling we plan on taking 500 bbl/hr losses and static 20bb1/hr. At this point we will pump and/or squeeze 150 bbls of 13.8 cement, bentonite, Cem-Net mixture in to the open hole and fracture. The bentonite will make the cement lighter and easier to drill up without kicking the bit off the cement plug. The Cem-Net is a cement LCM that we hope will plug up the fracture. If this works we plan to drill ahead as previously permitted for. If this does not work we plan to drill ahead with sea-water. Ron Phillips Operations Drilling Engineer 564-5913 15-126 Application for Sundry TREE = 5-1 /8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = BF. ELEV = KOP= 7,700'MD Max Angle = Datum MD = Datum TV D = 15-12B~rrent Status • 2482' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2930' 4-1/2", 12.6#, L-80, IBT-M tbg kill string 2982' 7" Scab LNR HGR 5370' 7" Liner Hanger 5659' 9-5/8" Whipstock, millout w indow 5659' 9-5/8" ¢SV 8087' Top of Cement 15 BBL 8287' 9-5/8" ¢SV 8290' 5-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" 8290' 3-1/2" TBG, 9.3#, L-80, .0087bpf, ID = 2.992" 8850' 7" ¢SV 8957' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8999' 6.125" New Formation into fault w ith 500 bbVhrlosses FISH ORIGINAL COMPLETION CTD SIDETRACK GO ATE REV BY COMMEMS PRUDHOE BAY UNfT 0/06 RLP 15-126 (w p04) Side track WELL: 15-126 7/06 RLP 15-12B (w p05) Side track PERMfT: 4/06 RLP 15-12B Updated casing depths API No: 50-029-20665-02 4/06 RLP Temporary secure & RDMO SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) TREE = 5-1 /8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = BF. ELEV = KOP= 7,700'MD Max Angle = Datum MD = Datum TV D = 1/2" HES X NIP, b = 2.813"~ -3/8" CSG, 72#, L-80, ID = 12.347" Scab LNR HGR 7" Liner Hanger 9-5/8" Whipstock, millout w indow 7700' Top of Cement 7.33 BBL 7800' 9-5/8" ¢SV 7825' 5-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" 7850' 3-1/2" TBG, 9.3#, L-80, .0087bpf, ID = 2.992" 8729' 4-1/2" HES X NIPPLE; ID=3.812" 8750' 7" X 4-1/2" BAKER S-3 PERM PKR; ID=3.88" 8774' 4-1/2" HES X NIPPLE; ID=3.812" 8795' 4-1/2" HES XN NIPPLE; ID=3.725" 8807' 4-1/2" TBG, 12.6#, 13CR-80 / WLEG 8807• 4- 1/2" LNR HGR/LTPw/ 10' Tieback Sleeve 8957' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8697' 9-5/8" CSG, 47#, L-80, ID=8.681" 11536' 4-1/2" CSG, 12.6#, L-80, .0152bpf, ID =3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/81 ORIGINAL COMPLETION 05/10/06 RLP 15-12B (wp04) Side track 08/04/00 CTD SIDETRACK 05/17/06 RLP 15-12B (w p05) Side track 08/29/01 CH/KAK CORRECTIONS 06/14/06 RLP 15-12B Updated casing depths 09/11/03 CMO/TLP DATUM MD/TVD CORRECTIONS 06/12!04 RWUKA GLV GO 07/27/04 BJMcNIK FISH PRUDHOE BAY UNIT WELL: 15-126 PERMfr: API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) 15-12B~oposed Completion u • 05-Oct-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-12B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,627.43' MD Window /Kickoff Survey: 5,637.00' MD (if applicable) Projected Survey: 8,999.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 i/J / ~ ~, / , , Date ~ v ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~ ~ z ALA.$SA Oii. A1~TD GAS COI~TSERQATI011T COMhII5SIOIQ Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 i FRANK H. MURKOWSKI, GOVERNOR ~' 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RP• Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-12B Sundry :`?~ ember: 306-279 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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}. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~~ay of August, 2006 Encl. • ~~~6~" . ~ ~ ~~~ ~ z ~ ~~G ~I~~1r~~' STATE OF ALASKA ~ g,zz-fl,~ ~ ~ f ALA OIL AND GAS CONSERVATION COM SION RECEIVED AUG 1 2006 . APPLICATION FOR SUNDRY APPROVAL 5 ` 20 AAC 25.280 / 'en 1. Type of Request: ^ Abandon ^ Suspend ®Operation Shutdown ^ Perforate ^ Time ExtensionAncher~ga ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To ill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-087 3. Address: ^ Stratigraphic ^ Service 6. API Number. ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20665-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 15-12B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028309 62.4';' Prudhoe Bay Field / Prudhoe Bay Pool t2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8999 8316 8850 8183 8850 None Casin Len th Size MD TVD Burst Colla se Structural Conductor 80' 20" 80' 80' 1490 470 Surf ce 2482' 13-3/ " 2482' 2482' 4930 2670 Intermediate 8697' 9-5/8" 5370' - 8697' 5164' - 8261' 6870 4760 Producti n Liner 5975' 7" 2982' - 8957' 2979' - 8278' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Kill String: 4-1/2", 12.6# L-80 2930' f Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: % ® Description Summary of Proposal ^ B P Sketch ~' ^ Exploratory ®Development ^ Service ' ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Aug t 9, 006 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: te: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name D ve Wesley Title Senior Drilling Engineer _ Prepared By Name/Number: Signature '' ~~ ~~/ Phone 564-5153 Date ~~~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~ YD ~ 4.0 ~ /e~ wt,b~ed ~O 1~3L~/ ~ a~iiCt--~'o~-t35 , (~ APPROVED BY Q A roved B COMMISSIONER THE COMMISSION Date p Form 10-403 Revised 06/2006 `,~ ~ ~irubmit I'n Duplicate O R I G " ~ s ~F~ ~U~ ~ ~ z~o~ ~ HL n • by C'~7FernPmv~oeavr To: Winton Aubert - AOGCC Date: August 21, 2006 From: Ron Phillips - BPXA GPB Rotary Drilling Subject: 15-126 Application for Sundry Approval - To temporary secure well and move off Reference: API # 50-029-20665-01 Approval is requested to temporary secure 15-12B and move off. When we drilled out the 7" drilling liner shoe track and 20 feet of new formation we started taking losses (104 bbls/hr). We think we hit the small fault that was supposed to be above the drilling liner shoe and behind cement. We decided to drill another 20 feet with LCM, but losses went to 500 bbls/hr. Due to all the activity on the slope (lack of vac trucks due to the shut in of GPB), we elected to temporarily suspend this well by setting an EZSV in the 7" drilling liner as deep as possible (8,850'). This has been done. The EZSV has been tested to 3,500psi for 30 / minutes, end charted. We displaced to seawater above the bridge plug. We ran 2,930' of 4 1/2" kill string and free rotected the well. We installed a BPV to finish securing the well. We moved off of 15-126 on August 18,~L006. i Ron Phillips Operations Drilling Engineer 564-5913 15-126 Application for Sundry t TIDE = 5-1 /8" FMC WELLHEAD = FMC ACTUATOR ~ AXELSON KB. ELEV = BF. EL,EV =' KOP = 7,700'MD Max Angle = Datum MD = Datum TV D = 15-12 d j~'~~ s~~-~o w ~- I~.lG/Ir- 2482' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2930' 4-1/2", 12.6#, L-80, IBT-M tbg kill string 2982' 7" Scab LNR HGR 5370' 7" Liner Hanger 5637-5654 9-5/8" Whipstock, rmllout w indow 5659' 9-5/8" ¢SV 8087' Top of Cement 15 BBL 8287' 9-5/8" EZSV 8290' 5-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" 8290' 3-1/2" TBG, 9.3#, L-80, .0087bpf, ID = 2.992" 8850' 7" EZSV 8957' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8999' 6.125" New Formation into fault w ith 500 bbl/hr losses DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/81 ORIGINAL COMPLETION 05/10/06 RLP 15-126 (w p04) Side track 08/04/00 CTD SIDETRACK 05/17/06 RLP 15-126 (w p05) Side track 08/29/01 CH/KAK CORRECTIONS 06/14/06 RLP 15-126 Updated casing depths 09/11/03 CMO/TLP DATUM MD/TVD CORRECTIONS 08/14/06 RLP Temporary secure & RDMO 06/12/04 RWL/KA GLV C/O 07/27/04 BJMcN/K FISH PRUDHOE BAY UNIT WELL: 15-12B PERMff: API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP F~cploration (Alaska) = l { ~t ~ ~ i I { ~~ COI~SERQA ~ ~ q ~, ~~~ a ~~~ ~i ~ ' ~ '®i a i ~ ~ ~' If ~'"'~ ~ ~ ; ~'^'~ ~± a j ~ ~ ~'~ ! FRANK H. MURKOWSKl, GOVERNOR ~~" i Al/t~7~ O1i/ tusi/ t7[47 ~ 333 W. 7TM AVENUE, SUITE 100 j=O" CO~~IISS"'IO~ ?` ANCHORAGE, ALASKA 99501-3539 y PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 1966.12 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-12B BP Exploration (Alaska) Inc. Permit No: 206-087 Surface Location: 2113' FNL, 3803' FEL, SEC. 22, T 11 N, R 14E, UM Bottomhole Location: 593' FNL, 640' FEL, SEC. 27, T11N, R14E, UM Dear Mr. Wesley: 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 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) 659-3607 (pager). Sincerely, Dan T. Seamount Commissioner DATED this2~ day of June, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~I ~ ~ B.fvB STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMIV~ON PERMIT TO DRILL 20 AAC 25.005 E~~t~9`L ~~`'°~ JUN 2 0 2006 Alaska Dil & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class D Exploratory ^ Development Gas D Service ^ Multiple Zone D Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pr ^ 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: y~ PBU 15-12B G~,I~-{zogG 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11536 TVD 8933 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: UM 22 T11N R14E 2113' FNL 3803' FEL SEC 7. Property Designation: ADL 028309 Pool , , , , , . Top of Productive Horizon: 4762' FNL, 1687' FEL, SEC. 22, T11N, R14E, UM 8. Land Use Permit: 13. Approximate ate: ly 10, 006 Total Depth: 593' FNL, 640' FEL, SEC. 27, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to rest Property: 30,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-677429 y-5959402 Zone-ASP4 10. KB Elevation Plan (Height above GL): 63 feet 15. Distance to Nearest Well Within Pool: 291' 16. Deviated Wells: Kickoff Depth: 7700 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4100 Surface: 3434 18. Gasin .Pro ram: S ecifications Top - Settin Depth -Bottom Quantity of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 1353' 7550' 7167' 8903' 8273' 277 sx Class 'G' i t ~'" 7" 26# L-80 BTC-M 4568' 2982' 2979' 7550' 7167' Scab Liner 639 sx Class 'G' ~ 6-1/8" 4-1 /2" 12.6# L-80 IBT-M 2776' 8760' 8166' 11536' 8933' 337 sx Class 'G' 19. PRESENT WELL'GONDITION SUMMARY (Ta be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10730 Total Depth TVD (ft): 8855 Plugs (measured): None Effective Depth MD (ft): 10696 Effective Depth TVD (ft) 8852 Junk (measured): 8268 Casing Length Size Cement Vohame MD TVD Conductor /Structural 80' 20" 300 sx Permafrost 80' 80' Surface 2482' 13-3/8" 2500 sx Fondu, 400 sx Permafrost 'C' 2482' 2482' Intermediate 8697' 9-5/8" 250 sx Class 'C' 8697' 8261' Production Liner 734' 7" 300 sx Class 'C' 8367' - 9101' 7944' - 8652' Liner 2447' 2-7/8" 108 sx LARC 8283' - 10730' 7863' - 8855' Perforation Depth MD (ft): 9400' - 10680' Perforation Depth TVD (ft): 8851' - 8851' 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 Ron Phillips, 564-5913 Printed Name D e Wesley Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5153 Date fv /~/d ~ Terrie Hubble, 564-4628 Commission Use,Only Permit To Drill Number: API Number: Permit Approval 50- 029-20665-02-00 Date: See cover letter for other requirements 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: -^JYes ~No Mud Log Req'd: ^ Yes ~~`No ' .e Cp ~` ~ O C~ E "~O ~-C700 ~ S ( HZSLMeasures: /^~q Yes r ^~(No Directional Survey Req'd: Yes ^ No O~u Vr: aV4~ 1 O O ~' s ~ ~' 1 C,l, J Q.~ [ pi hti. (C° ~Y •L^AA.t4! l'QS~ ~lroC2~l~e C[YL c~y~yv ved . APPROVED BY THE COMMISSIO p~ ,COMMISSIONER F9ffn 10 Revised 12[2005 ~ ~ Submit In uupucate • • Well Name: 15-12B Drill and Complete Plan Summary Well Horizontal Target Ivishak Zone Well 15-12B Sidetrack Type producer Objective 1 A AFE Number: PBD4P2532 Surface Northin Eastin Offsets TRS Location 5,959,402 677,429 3,166' FSL / 3,806'FEL 11 N, 14E, 22 API Number: 50-029-20665-02 Target Locations Northin Eastin Offsets TRS T1 5,956,805 679,615 517 FSL / 1,687 FEL 11 N, 14E, 22 T2 5,956,370 680,050 72' FSL / 1,263' FEL 11 N, 14E, 22 T3 5,955,720 680,690 4,687' FSL / 640' FEL 11 N, 14E, 27 Bottom Northin Eastin Offsets TRS Location 5,955,720 680,690 4,687' FSL / 640' FEL 11 N, 14E, 27 Planned KOP: 7,700 MD / 7,309' TVD Planned TD: 11,536 MD / 8,933' TVD Ri Nabors 27E GL: 29.5' RTE: 63.0' Directional Program s A roved Well Ian: Wp05 Exit oint: 7,700' MD / 7,309' TVD Maximum Hole Inclination: -90.2° in the tanned horizontal roduction section. Proximity Issues: All wells should pass Major Risk anti-collision survey (after re-gyroing 15-38 and 15-12A . Survey Program: Standard MWD/IIFR/MS. Nearest Well within pool: Well 15-38 (currently on production), 291' away at the closest point 8,934' TVD. Nearest Pro ert Line 30,000' 15-12B Permit to Drill Page 1 • • Logging Program Hole Section: Required Sensors /Service 8 1/2 intermediate: MWD Dir/GR/Res/PWD (real time Res. only last 500' to locate intermediate TD). 6 1/8" production build: MWD Dir/GR 6 1/8" production horizontal: MWD Dir/GR/Den/Neu (run Den/Neu memory mode to mad pass back up to 50' above TCGL rior to drillin horizontal section and run Den/Neu real time to drill horz. section . Cased Hole: None Planned O en Hole: None lanned Mud Program Mill window in the 9 5/8" casino to sertian TD T e Densi PV YP API FL HTHP H LSND 0.8 15-22 20-25 4.0-6.0 <10.0 9.0 -10.0 Hole Section / o eration: Drillin 6 1 /8" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.5 >20,000 8 - 12 22-28 6-8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade ~ Connection '` Length Top and / tvd Bottom and / tvd 8 1/2" 7" drill liner 26.0# L-80 BTC-M 1,353' 7,550' / 7,167' 8,903' / 8,273' 8 1/2" 7" scab liner 26.0# L-80 BTC-M 4,568' 2,982' / 2,979' 7,550' / 7,167' 6 1/8" 4 ~/z" rod liner 12.6# L-80 IBT-M 2,776' 8,760' / 8,166' 11,536' / 8,933' Tubin 4 ~/z" 12.6# 13CR-80 Vam To 8,740 Surface 8,760' / 8,166' Cementing Program Casin Strin 7", 26#, L-80, BTC-M Drillin Liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 86' of 7", 26# shoe track, 1,210' of 7" X 8-1/2" annulus with 40% excess, 150 of 7 X 9-5/8 ,47# liner lap and 200 of 4 DP X 9-5/8 ,47# annulus. Pre-Flush None lanned Fl id S /V l S acer 30 bbls MudPUSH at 12.0 u s equence o ume: Lead Slur None lanned Tail Slur 57 bbl / 321 ft3 / 77 sk Class `G', 15.8 .1 ft3/sk. ~/ ~! 15-12B Permit to Drill Page 2 • • Casin Strin 7", 26#, L-80, BTC-M Scab Liner Z ~ 2 Slurry Design Basis: Lead slurry: None planned. Tail slurry: 86' of 7",26# shoe track, 4,568' of 7" X 9 5/8", 47#, with 0% excess and 200' of 4" DP X 9-5/8", 47# annulus. Pre-Flush None tanned Fl id / V S l • S acer 30 bbls MudPUSH at 12.0 u s equence o ume ' Lead Slur None tanned Tail Slur 132 bbl / 741 ft3 / 39 s' Class `G', 15.8 .1 ft3/sk.. ,, ;~'" Casin Strin 4-1/2", 12.6#, L-80, IBT-M Production Liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 86' of 4-1/2", 12.6# shoe track, 2,626' of 4-1/2" X 6-1/8" annulus with 40% excess, 150' of 4-1/2" X 7" liner la and 200' of 4" DP X 7" annulus. Pre-Flush 20 bbls CW 100 at 8.32 Fl id /V S l S acer 40 bbls MudPUSH at 10.0 ume: u s equence o Lead Slur None tanned Tail Slur 70.3 bbl / 394.7 ft3 / 37 k Class `G', 15.8 .17 f 3f/sk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" EZSV EZSV to RTTS 30 min recorded 3,500 si surface Shallowest 9-5/8" casing leak known cretaceous leaks RTTS to surface 30 min recorded 3,500 psi surface 9 5/8" casin window 20' new formation be and FIT 11.6 EMW 7" scab liner Float a ui ment to surface 5-10 min recorded 3,500 si surface 7" drillin liner Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1 /2" intermediate interval Maximum antici ated BHP: 4,100 si at 8043 TVD (based on offset wellbore pressures) Maximum surface ressure: 3,434 SI (based upon BHP and a full column of gas from TD C~1 0.10 psi/ff) Calculated kick tolerance:. Infinite with 10 EMW FIT Planned BOPE test 250 psi low / ,000;psi high - 7 day test cycle prior to picking up whipstock ressure: assembl arz_]dda test c cle after ickin u whi stock assembl . BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams while drilling liner. running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This configuration provides two sets of em to able rams, rather than one. 15-126 Permit to Drill Page 3 • Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,345 psi at 8,933' TVD (based on offset wellbore pressures) Maximum surface ressure: 2,451 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.5 pp EMW FIT. Planned ROPE test ressure: 250 si low / si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.4 p seawater / 6.8 p Diesel ¢• 0 00 f' ii. W Glt" 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 sealing equipment for other than well control or equivalent ` ,, purposes, except when the routine use of BOP sealing equipment may have compromised their ._/ye`-- 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. DISpOSc'~I Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 15-12B Permit to Drill Page 4 • • Geologic Prognosis TD Criteria: Reach planned TD unless drilling conditions deteriorate. Final TD to be determined by both Rigsite and Town geologist. Note: End of Geopolygon is hardline to avoid crossin NW-SE Fault near tanned TD. Formation tops and estimated pore pressures Estimated Formation To s Estimated Formation To s Uncertain Hydroca rbon Bearin Estimated Pore Press. Pore Press. Formation TVDss MD +/- eet Yes/No Psi EMW CM3 6270 CM2 6680 KOP 7242 7700 20 CM 1 7415 7886 20 THRZ 7740 8282 20 BHRZ 7935 8540 20 LCU 7970 8586 20 TJB 8005 8632 20 4100 9.9 TJA 8105 8764 20 Fault 8111 8775 10-20' throw & +/- 200' MD TSGR 8210 8903 20 TSHA 8255 8962 20 TSHB 8265 8976 20 TSHC 8285 9002 20 TSAD 8310 9035 20 Yes 45SB 8330 9061 20 Yes 44SB 8355 9094 20 Yes 42SB 8405 9160 20 Yes TCGL 8465 9240 20 Yes BCGL 8540 9339 20 Yes 23SB 8600 9418 20 Yes 22TS 8665 9504 20 Yes 21TS 8720 9582 20 Yes TZ1B 8785 9694 20 Yes TDF 8830 9799 20 Yes 3300 7.2 BSAD 8870 10251 20 (b 15-126 Permit to Drill Page 5 • • Operations Summary Pre-Riq Operations: 1. RU E-Line w/ Gyro and run surveys on both the 15-12 and 15-38 well bores. RD E-Line. 2. RU SL and drift the 3'h" tubing to 7,900' MD. This will confirm the tubing is clear to the required cut depth of 7,850' MD. RD SL. 3. RU E-Line w/ RST to locate fill behind 3-1/2" tubing. 4. RIH with the appropriate jet cutter and cut the 3-1/2" tubing at 7,850' MD. RD E-Line. 5. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 6. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 27E. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC and test to 1000psi. 3. Nipple down tree. Nipple up and test ROPE to 250 psi low and 4,000psi high (due to a 3,434 psi maximum surface pressure based upon BHP and a full column of gas from TD). Pull TWC. 4. Pull 3'h" tubing from the cut at 7,850' MD. 5. RU SL and drift the 5'/z" tubing to 7,840' MD. This will confirm the tubing is clear to the required cut depth of 7,825' MD. RD SL. 6. RU E-Line and RIH w/ Free Point Indicator Tools. Verify tubing is free to 7,825' MD. 7. RIH with the appropriate jet cutter and cut the 5-1/2" tubing at 7,825' MD. RD E-Line. 8. Pull 5'h" tubing from the cut at 7,825' MD. 9. RU E-line. M/U gauge ring junk basket / CCL / GR. RIH and tag tubing stump. POOH. 10. RIH with HES EZSV on E-line. Set EZSV at 7,800' MD. RD E-Line. 11. RIH w/open ended drill pipe and tag EZSV. RU Cement Unit. Pick up off bottom and place a 7.3 BBL cement cap (100ft) on top of EZSV. POOH. RD Cement Unit. 12. RU RTTS (1500psi compressive strength needed before testing) to test EZSV /cement plug to 3500psi for 30 minutes. 13. Using RTTS find shallowest depth of 9-5/8" casing leak. Once shallowest leak is found in 9-5/8" casing, verify by performing a 30minute test to 3500 psi. POOH w/ RTTS. 14. PU and RIH with mill assembly to dress up cement plug (using the CCL/GR Log run prior to setting EZSV) to determine required depth to land the whip stock, to prevent milling on a casing collar. 15. ND the BOP and pull the existing tubing spool with the 9-5/8" pack off. The lower LDS are not functional, so the tubing spool and pack off will need to be replaced. Test the seals and pack off. 16. NU and test the BOP. Note: all operations before this point are on a 7day BOP test cycle until the whipstock is picked up. Once the whipstock is picked up the 14 day test cycle starts and continues until `~. the rig moves off. ~' 17. PU and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as '~ required by directional a .Shear off of whip stock at 7700. 18. Displace the well to 1 .8 g LSND based milling fluid. Completely displace the well prior to beginning milling ope a ions. 19. Mill a 20' window in 9-5/8" casing at ± 7,700' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 20. Pull up into 9 5/8" casing and conduct an FIT. (Notify ODE if 11.6 ppg FIT is not obtained). POOH. f ~ 21. MU 8'/i" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8'h" intermediate section. d., 22. Continue drilling ahead in the 8'/z" hole section to the top of the Sag River, per directional plan. Circulate well clean, short trip to window. POOH. ~ 23. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. / -,.. `" 15-12B Permit to Drill ~- Page 6 • • 24. Run and cement 7" scab liner from intermediate drilling liner top up to 500' from surface casing 0 shoe. Assuming there are no shallow 9-5/8" leaks above this depth. 25. M/U 6-%8" tri-cone bit Dir/GR assembly. 26. RIH to the 7" scab liner shoe track, test scab liner to 3500 psi for 5-10 minutes, drill out cement / ~ float equipment. 27. RIH to the 7" liner shoe track, test drilling liner to 3500 psi for 30 minutes. / 28. Drill out 7" drilling liner shoetrack. 29. Displace the well over to Flo-Pro drilling fluid prior to drilling 20' of new formation. 30. Pull up into the shoe and conduct a FIT. (Notify ODE if 10.0 ppg FIT is not obtained). Drill ahead ./ through Zone 2, completing build section. POOH. 31. M/U 6-%8" PDC drilling assembly with Dir/GR/Res/Den/ Neu. RIH. Tag bottom and mad pass (den/Neu in record mode only) up to 50' above TCGL. 32. Drill ahead to TD (Den/ Neu in real time mode for drilling). Fault just beyond TD! This fault is 200' away and has not been crossed before. 33. Circulate well bore clean, short trip to shoe, circulate. POOH. 34. Run and cement 4%2", 12.6#, L-80, IBT-M solid production liner. POOH. '~ 35. Test 4-1 /2" production liner to 3,500 psi for 30 minutes. 36. RIH with drill pipe conveyed pert guns. Perf intervals to be determined from LWD logs. Plan to `- perforate overbalance. Perforate. POOH, LD DP and pert guns. 37. R/U and run a 4~h", 12.6#, 13CR-80 tubing completion, stinging into the 4'/z" liner tie back sleeve. 38. Reverse circulate seawater and corrosion inhibitor. Drop the ball and rod, set the packer. 39. Individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. Pressure up on annulus to shear the DCR valve. Confirm two-way circulation. 40. Set a TWC and test to 1000 psi. 41. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. ,,~ 42. Pull TWC. Reverse in sufficient diesel to freeze protect to 2200 ft TVD. U-tube. 43. Install BPV and test. Secure well. RDMO. Post-Rig Operations: 1. MI / RU slick line. Pu!! the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. 15-126 Permit to Drill Page 7 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control • The Ivishak in this fault block is expected to be under-pressured at 7.20 ppg EMW. This pressure is estimated based on offset well pressures. II. Lost Circulation/Breathing • Risk due to lost circulation is rated to be low to moderate. If it occurs, follow the LCM decision tree. • DS15 has somewhat of a history of lost circulation events while drilling in the reservoir section and normally occur when crossing faults. There is only one expected fault crossings identified for this directional trajectory with no losses anticipated. Care should be taken while looking for the top of the Sag River, the parent well 15-12 took an 847 bbl loss while casing and cementing in the Sag River and 15-38 took a 120 bbl loss in the Sag River. In the reservoir section 15-12 also took a 96 bbl loss in zone 1 and 15-38 took a 150 bbl loss in zone 4. In general, most of the losses in the area around 15-12B occurred east of the graben where 15-12B is placed. • The geo-polygon hardline fault at TD is -200' away and has not been crossed before. III. Kick Tolerance/Integrity Testing • The Kick Tolerance for the intermediate hole section is i inite~vith 10.8 ppg mud, 11.6 ppg FIT, and an 10.2 ppg pore pressure at the 9 5/8" window. This FIT s t~prove up adequate formation strength for expected ECD's. Kick tolerance drops to 25 bbls with an 10.6 ppg FIT. Notify the ODE and Drilling Manger if a 11.6 ppg FIT is not achieved at the window. -- • The Kick Tolerance for the production hole section is ' fi ' e with 8.5 ppg mud, 10.0 ppg FIT, and an 8.4 ppg pore pressure at the 7" shoe. This FIT should p , up adequate formation strength for expected ECD's. IV. Stuck Pipe • We do not expect stuck pipe. • There could be slight differential sticking issues within the 7.2 ppg EMW reservoir and 8.5 ppg mud. Centralizers will be run to mitigate. V. Hydrogen Sulfide • DS15 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are in the 20 PPM range based on the last samples taken in 2005/2006. • Max H2S reading on DS 15 is~3 pm for 15-48 on 03/23/1996. VI. Faults • We expect to cross one small fault with the proposed 15-12B wellbore. It is anticipated that the fault will be crossed at 8,775 ft. MD. This fault has a throw of 20-30 ft. down to the E. It has been crossed previously by the 15-38 well with no losses. We should cross this fault in the Kingak 100' above our 7" casing set point at the top of the Sag River. • The geo-polygon hardline fault at TD is 200' away and has not been crossed before. This fault has a throw of 30-50 ft. down to the W-SW. VII. Anti-Collision Issues • All wells will pass major risk close approach criteria after re-gyroing 15-12A and 15-38A. The closest well is 15-38 at 289' ctr-ctr (214' allowable deviation) at 11,028 planned MD. CONSULT THE DS 15 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION • • Variance Request ,~..--- Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. 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. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be fiunction pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore.:.for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPS requirements in {e) of this section i# the variance provides at least an equally effective means of well control; TREE= 5-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV.- BF. ELEV..- KOP = 7,700'MD x Angle = Datum MD = Datum TV D = 1 /2" HES X NIP, ID = 2.813" -3/8" CSG, 72#, L-8Q ID = 12.347" _ Scab LNR HGR 7" Liner Hanger ] 9-5/8" Whipstock, millout w indow ~ 7700' Top of Cement 7.33 BBL 7800' 9-5/8" EZSV 7825' S-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" _------- 7850' 3-1/2" TBG, 9.3#, L-80, .0087bpf, ID = 2.992" 8675' 4-1/2" HES X NIPPLE; ID=3.812" 8696' 7" X 4-1/2" BAKER S-3 PERM PKR; ID=3.88" 8720' 4-1/2" HES X NIPPLE; ID=3.812" 8741' 4-1/2" HES XN NIPPLE; ID=3.725" 8753' 4-1/2" TBG, 12.6#, 13CR-80 / WLEG 8753' 4- 1/2" LNR HGR/LTPw/ 10' Tieback Sleeve 8903' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8697' 9-5/8" CSG, 47#, L-80, ID=8.681" 11536' 4-1/2" CSG, 12.6#, L-80, .0152bpf, ID =3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/81 ORIGINAL COMPLETION 05/10/06 RLP 15-126 (wp04) Side track 08/04/00 CTD SIDETRACK 05/17/06 RLP 15-126 (w p05) Side track 08/29/01 CWKAK CORRECTIONS 06/14/06 RLP 15-126 Updated casing depths 09/11/03 CMO/TLP DATUM MD/TVD CORRECTIONS 06/12/04 RWUKA GLV GO 07/27/04 BJMcWK FISH PRUDHOE BAY UNIT WELL: 15-12B PERMIT: API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) 15-12B ~oposed Completion Dp ('UMI',Wti ULI VLS 6P \ %1'YL%LNl11NkU%AL111UN lu.rtJu IN II%( N IIl trc: 151_' Irtr.~N,urh 111%\I'1'P%t%~%:\M IkYlh hm UePI I S '.w I'I I~„~I Plan I5.1'_B xp115115-I?: PI I$-1261 ('natal 6} Troy Jaknhuaky 6uknllku.bp Bllle: h: 13: 21x1fi ('akulunun Nltlxul. hlnmam lun'anuc I:mu Syvnu: ISCKS,\ \utx 1((\111%t 115 )531333 hv„nl\SI %.frtwi Sb,- (II ININ I II~.I 51 (.tut .ure~IkPlh %ckrelwv: 11 5-±4 %lea "NI ~ IIStS J IL: In~L I. 1'14 „Jw5\'I %INn Ih%~h1S L'he~k<a: Dele-. -- \anMnh.ul:l~e~Cylilx4rN.rctli . . . l'aleularl.m MrYlxwl: Minnnwn ('lur:muc NI~.LL Ut~I.\ILS I~rtur Surrac<: I:Itipiul ~ ('a.nig N anling Al alxul: Nulin naxJ Nance ~N-S 1:-N' Nunhmg I~::uul} Lanuuk Lw,ginxle SIW IS-I? 53]x5 IIJS III 5454/111 Xx 6771_'%.w "III'17'JILS_'$N IJ%'ll'J7.xJ2N' NSA . I ~ ' ~ TARGET DETAILS - - - ~ I ~; I 1 I I ~ - Nanlc TVD +N/-S +E/-W Northing Fasting Shapc I ~ { ------ --- -- - ~ 15-126 I X93 LU1 -2647.93 2124 24 5956riU5.U0 G79GISAU Point r U. '. ~ IS-I'_B Fauh l ri93 103 -1755.87 1753.17 5957Griri.00 G79223A0 Polygon I . 15-I2B Fauh 2 ri93 103 2911 23 2132.9ri 5x565411.011 6796311.011 Polygal 35110 ~ 1 ! ~ .12,(1. , _ V 15-12B Fault 3 893 LU3 -21 19x7 211116.66 59573311.00 G794ri5.0(1 Polygon I 1 ~ _ _ _ 15-136 Fauh 5 893 107 -2584.311 2000.90 595G8ri1L00 680096.00 Polygon 4000 - ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ 15-128 Fault 7 893 101 '816.19 3276bG 5956664.00 GSU77 LOU Polygat ~ ~ '' _ -_- - 15-I2BFault6 8')3103 3899.74 3496.16 5955586.110 681111(,.00 Polygal ~ ~ ~ ~ ~ I IS-128 Fault4 893 101 -186(1.28 2192.85 5957594.0(1 679665.00 Polygon ' _ _ 4500 ~ I 15_126 T3 8933.03 -3758.08 3173.39 595572(100 Gri0(90.0(1 Point ! I, ' U-12B T2 8936.03 -3093.1 I 2548.87 5956370.00 6ri11U5U.U0 Point 711( ~ IS-11( 5-12APB11 I ~ ~, SECTION DETAILS 5511(1 _ _ _ ~ Scc MD Inc Azi TVD +N/-S +E/_W DLcg TFacc VScc Targcl I - U ~ I ~ I 77011.(10 19.50 1311.110 7308.51 -12x7.5x 1393.96 OAU U.UII 1890.75 ~- 0 U '. . - - 2 772UA11 21.59 139.36 7327.24 -13112.78 1398.68 X12.0(1 311111 1897.76 . - - I ~ ~ 3 8243.26 40.79 156.27 7773.58 -1534.ri8 153165 4.UU 32.1? 21611.88 ' I KSUU' ! I - 4 9491.63 40.79 ISG.27 8718.78 -22ri1.3v 1859.88 U.UU UAU 2943.01 ~ 9 G 1 I TI 5 11((1(18._3 89.53 136.35 8931113 _647.93 _1_4._4 IO.l1U _5.74 3. - 5 2B . .. I Ij(15-,12 ~ ) ~ ~ ~ 9 615 8931.03 -2647.99 2124.30 IO.UU -136.35 3393.70 I OU118 3_ 8 .53 13 .- 6 ~ 00 l1AU 39x144 96 -31181 67 0 35 8935 27 2537 7 106(17 17 89 53 136 -140 ' I ~ . . . . . . . 8 10623.48 9UA11 136.80 891603 -311x1.11 2548.87 4.00 43.65 4007.71 IS-12BT2 ~ 5 12~ Fault 1 I 9 10628.20 90.19 136.80 8936.112 -11196.55 2552.1 I 4.011 0.110 4012.43 Stan Dit 4/1011 :772 733724?Vp ~ ~ ' MD ( U' ' I f IU 11535.74 90.19 136.80 8933.113 -3758A8 3173.39 0.110 l1AU 4918.70 IS-12BT3 , 2~SpU \ 5 l2B Fault3 . I - ,EgdDir 21243 (~'MD,777353'TV¢.. ~ - . 1 -? _ - ~ { . ~ ~-- 1... KI 15-1~6 Fault i - _ 1 _ ~ , - I ~ ;,,~ r ,.. - - - + _1101 , 1 L ~~ 5~' o _ . - - t ~ , S`arl Dir 10, I (IU' 9891 G3 MD, 8718 7tS'TV ~ I -r - __ 1 1 1 - --_ - ~ S- 1 - 2 f~a t -- - - _ --- -- - - - CASING DETAILS . 1 ~' 1 ' ~ ' ~ ' ~ ~ ! i No. TVD MD Nmnc Sizc n ; v . 100(1!(.3.. Mti, 893 d UJ I T ~ ~ I ~ -2811 I '~. ~ ~ _ _ I ri271A1 8902.91 U ' { i ~ f I I ~ I : ~ r - ~ - - - .OU 41/2" 45(1 8x33111 11535 l1 - - - - - t FURMATIONTUPUETAILS 1 , t _ _'_ ; - . - - - '. ~ IS-12BFaul12~ i '~. -_-. ---- - - -- ~ 1 - - ~ ~~ ' -- -_ . I No. TVDPmh MDPaU) Formation - - - - - - - I _ - _ I 747ri.(13 78ri5.75 CMI S 4'100' GU6117 1TMD Di - 8935 %'TVD F - - _ ; - %- ~ I 2 7803.113 ri2R2.IG THRZ . . ta •: 1 r . - 3 7998.03 8539.70 BHRL -350 4 8033.113 8585.93 LCU . ' - -! ~ _ T 5 8068.03 8632.15 TJB - -;--- --- o ~I •End Dir .'106_8._ i D; 8936.0_' TVD ~ ~ S- ~ - ~ ~ ~ ~ ~ 6 8168.03 876423 TJA - - - , I + ~ 7 ri273A3 rivU2.91 TSGR -I ; _. t ---- - -- - I 8 8318.03 8962.34 TSHA ' - . :.. 9 8328.03 8975.55 TSHB _ - Ill 8348.113 91101.96 "fSHC otal Dcpt6 : 11534.74' M 933.03 TVD. r - - { II 8373.(13 9(114Ari TSAD _ , - ~ - -12B FnuIL ~ - 12 8393.03 91161.411 455B - - - Pl 15 t 2B - - 13 8418.03 9094.41 44S8 . , - an ~ ~ 14 8468.113 9160.45 4256 ' -420( ; t : . - , ,_ . - - ~ ' ~. 15 8528.113 9239.70 TC GL 1 _ - -_ , 15-126 p05 4.1 .~„ . ~ I6 8603.113 9338.75 BCGL 17 8663.113 x418.110 23S8 15-12 T3 18 ri72ri.113 9503.95 22TS 19 8783.113 9582.45 21TS 20 riri4ri.(13 9694.01 TZIB U 7 UU 14 (10 21 UU 28 (1(1 35011 42110 49W 21 8893.03 9798.69 TDF 3'_ 8933.03 1025107 BSAU Wcsq-I,Eaul~l [70 01i,'in] u u u 3 Q _ N Z U 9 ~ o a _ _ _ s .o'o.o 3 rn aaa - 2 < n - eL 7 _ J^~ _ .: ~^. - '~ ~ J v, r. 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M F zl z 6 z -N ~rI [n!i~J 005] 41daQ ~emu~p any `~ z n 0 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 6/13/2006 Time: 1$:16:26 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-12, True North Site: PB DS 15 Vertical (TVD) Reference: 33.5 + 29.53 63.0 Well: 15-12: Section (VS) Reference: Well (O:OON,O.OOE,139.82Azi) Wellpath: Plan 15-12B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 15-12B wp05 Date Composed: 2/16/2006 Version: 26 Principal: Yes Tied-to: From: Definitive Path 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: bggm2005 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-12 Slot Name: 15-12 Well Position: +N/-S 537.85 ft Northing: 5959401.88 ft Latitude: 70 17 40.525 N +E/-W 1145.01 ft Easting : 677428.99 ft Longitude: 148 33 47.842 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 8902.91 8273.03 7.000 8.500 7" 11535.00 8933.03 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 7885.75 7478.03 CM1 0.00 0.00 8282.16 7803.03 THRZ 0.00 0.00 8539.70 7998.03 BHRZ 0.00 0.00 8585.93 8033.03 LCU 0.00 0.00 8632.15 8068.03 TJB 0.00 0.00 8764.23 8168.03 TJA 0.00 0.00 8902.91 8273.03 TSGR 0.00 0.00 8962.34 8318.03 TSHA 0.00 0.00 8975.55 8328.03 TSHB 0.00 0.00 9001.96 8348.03 TSHC 0.00 0.00 9034.98 8373.03 TSAD 0.00 0.00 9061.40 8393.03 45S6 0.00 0.00 9094.41 8418.03 44S6 0.00 0.00 9160.45 8468.03 42S6 0.00 0.00 9239.70 8528.03 TCGL 0.00 0.00 9338.75 8603.03 BCGL 0.00 0.00 9418.00 8663.03 23S6 0.00 0.00 9503.95 8728.03 22TS 0.00 0.00 9582.45 8783.03 21 TS 0.00 0.00 9694.01 8848.03 TZ1 B 0.00 0.00 9798.69 8893.03 TDF 0.00 0.00 10251.07 8933.03 BSAD 0.00 0.00 Targets Map Map w Latitude ---> <, Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 15-126 T1 8931.03 -2647.93 2124.24 5956805.00 679615.00 70 17 14.480 N 148 32 45.952 W 15-12B Fault 1 8931.03 -1755.87 1753.17 5957688.00 679223.00 70 17 23.254 N 148 32 56.757 W -Polygon 1 8931.03 -1755.87 1753.17 5957688.00 679223.00 70 17 23.254 N 148 32 56.757 W S err -Sun P Y BP Planning Report Company:. BP Amoco Date: 6!13/2006 Time: 16:16:26 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL 1 5-12, True North Site: PB DS 15 Vertical (TVD) Reference: 33.5 + 29.53 63.0 Well: 45-12 Section (VS) Referen ce: Well (O.OON,O.OOE,139. 82Azi) Wellpaffi: .Plan 15-12B Survey Calculation Method: M inimum Curvature Db: . Oracle Targets Map Map <--- - Latitude ---> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min. Sec Deg Mi n Sec Dip. Dir. ft ft ft ft ft -Polygon 2 8931.03 -3572.87 2023.37 5955878.00 679536.00 70 17 5.384 N 148 32 48.898 W 15-126 Fault 2 8931.03 -2913.23 2132.98 5956540.00 679630.00 70 17 11.871 N 148 32 45.699 W -Polygon 1 8931.03 -2913.23 2132.98 5956540.00 679630.00 70 17 11.871 N 148 32 45.699 W -Polygon 2 8931.03 -3651.13 2160.57 5955803.00 679675.00 70 17 4.614 N 148 32 44.902 W -Polygon 3 8931.03 -4230.72 2176.89 5955224.00 679705.00 70 16 58.913 N 148 32 44.431 W -Polygon 4 8931.03 -3651.13 2160.57 5955803.00 679675.00 70 17 4.614 N 148 32 44.902 W 15-126 Fault 3 8931.03 -2119.97 2006.66 5957330.00 679485.00 70 17 19.673 N 148 32 49.373 W -Polygon 1 8931.03 -2119.97 2006.66 5957330.00 679485.00 70 17 19.673 N 148 32 49.373 W -Polygon 2 8931.03 -2660.47 2273.99 5956796.00 679765.00 70 17 14.356 N 148 32 41.589 W 15-12B Fault 5 8931.03 -2584.30 2606.90 5956880.00 680096.00 70 17 15.104 N 148 32 31.889 W -Polygon 1 8931.03 -2584.30 2606.90 5956880.00 680096.00 70 17 15.104 N 148 32 31.889 W -Polygon 2 8931.03 -2781.69 2705.28 5956685.00 680199.00 70 17 13.163 N 148 32 29.025 W -Polygon 3 8931.03 -3475.72 3247.08 5956004.00 680757.00 70 17 6.335 N 148 32 13.248 W -Polygon 4 8931.03 -2781.69 2705.28 5956685.00 680199.00 70 17 13.163 N 148 32 29.025 W 15-12B Fault 7 8931.03 -2816.19 3276.66 5956664.00 680771.00 70 17 12.821 N 148 32 12.378 W -Polygon 1 8931.03 -2816.19 3276.66 5956664.00 680771.00 70 17 12.821 N 148 32 12.378 W -Polygon 2 8931.03 -3684.60 3620.28 5955804.00 681135.00 70 17 4.279 N 148 32 2.379 W -Polygon 3 8931.03 -3968.99 3632.57 5955520.00 681154.00 70 17 1.482 N 148 32 2.025 W -Polygon 4 8931.03 -3684.60 3620.28 5955804.00 681135.00 70 17 4.279 N 148 32 2.379 W 15-12B Poly 8931.03 -3080.53 2355.10 5956378.00 679856.00 70 17 10.225 N 148 32 39.230 W -Polygon 1 8931.03 -3080.53 2355.10 5956378.00 679856.00 70 17 10.225 N 148 32 39.230 W -Polygon 2 8931.03 -3949.11 3171.88 5955529.00 680693.00 70 17 1.680 N 148 32 15.445 W -Polygon 3 8931.03 -3789.36 3396.73 5955694.00 680914.00 70 17 3.250 N 148 32 8.893 W -Polygon 4 8931.03 -2693.76 2243.20 5956762.00 679735.00 70 17 14.029 N 148 32 42.486 W -Polygon 5 8931.03 -2447.20 2053.95 5957004.00 679540.00 70 17 16.454 N 148 32 47.998 W -Polygon 6 8931.03 -2511.97 1958.39 5956937.00 679446.00 70 17 15.818 N 148 32 50.783 W 15-12B Fault 6 8931.03 -3899.74 3496.16 5955586.00 681016.00 70 17 2.164 N 148 32 5.998 W -Polygon 1 8931.03 -3899.74 3496.16 5955586.00 681016.00 70 17 2.164 N 148 32 5.998 W -Polygon 2 8931.03 -4555.14 3799.79 5954938.00 681335.00 70 16 55.716 N 148 31 57.163 W 15-126 Fault 4 8931.03 -1860.28 2192.85 5957594.00 679665.00 70 17 22.226 N 148 32 43.946 W -Polygon 1 8931.03 -1860.28 2192.85 5957594.00 679665.00 70 17 22.226 N 148 32 43.946 W -Polygon 2 8931.03 -2858.47 2525.40 5956604.00 680021.00 70 17 12.408 N 148 32 34.266 W 15-12B T3 8933.03 -3758.08 3173.39 5955720.00 680690.00 70 17 3.558 N 148 32 15.398 W 15-126 T2 8936.03 -3093.11 2548.87 5956370.00 680050.00 70 17 10.101 N 148 32 33.584 W Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 7700.00 19.50 136.00 7308.51 -1297.59 1 393.96 0.00 0. 00 0.00 0.00 7720.00 21.59 139.36 7327.24 -1302.78 1 398.68 12.00 10. 46 16.80 31.00 8243.26 40.79 156.27 7773.58 -1534.88 1 531.65 4.00 3. 67 3.23 32.12 9491.63 40.79 156.27 8718.78 -2281.39 1 859.88 0.00 0. 00 0.00 0.00 10008.23 89.53 136.35 8931.03 -2647.93 2124.24 10.00 9. 44 -3.85 -25.74 15-126 T1 10008.32 89.53 136.35 8931.03 -2647.99 2124.30 10.00 -7. 24 -6.90 -136.35 10607.17 89.53 136.35 8935.96 -3081.27 2537.67 0.00 0. 00 0.00 0.00 10623.48 90.00 136.80 8936.03 -3093.11 2548.87 4.00 2. 89 2.76 43.65 15-128 T2 10628.20 90.19 136.80 8936.02 -3096.55 2552.11 4.00 4. 00 0.00 0.00 11535.74 90.19 136.80 8933.03 -3758.08 3173.39 0.00 0. 00 0.00 0.00 15-128 T3 • S er -Sun P rY BP Planning Report Company: BP Amoco Date: 6/13/2006 Time: 16:16:26 Pager 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-12, True North Site: PB DS 15 Vertical (TVD) Reference: 33.5 + 29;53.63.0 Well: 15-12 Section (VS) Reference: Well (O.OON,O.OOE,139.82Azi) , Wellpath: Plan 15-126 Survey Calculation Method: Minimum Curvature 1)b: Oracle MD ft Ir-cl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/R' ft DLS deg/100ft MapN ft MapE ft TooUCo 7700.00 19.50 136.00 7308.51 7245.48 1890.75 -1297.59 1393.96 0.00 5958137.64 678853.10 Start Dir 1 7720.00 21.59 139.36 7327.24 7264.21 1897.76 -1302.78 1398.68 12.00 5958132.56 678857.94 Start Dir 4/ 7800.00 24.36 143.49 7400.89 7337.86 1928.95 -1327.22 1418.08 4.00 5958108.59 678877.91 MWD+IFR 7885.75 27.42 147.02 7478.03 7415.00 1966.20 -1358.00 1439.36 4.00 5958078.32 678899.91 CM1 7900.00 27.94 147.54 7490.65 7427.62 1972.76 -1363.57 1442.94 4.00 5958072.83 678903.62 MWD+IFR 8000.00 31.61 150.72 7577.44 7514.41 2021.74 -1406.22 1468.34 4.00 5958030.80 678930.02 MWD+IFR 8100.00 35.35 153.30 7660.83 7597.80 2075.63 -1454.95 1494.17 4.00 5957982.70 678956.99 MWD+IFR 8200.00 39.14 155.44 7740.42 7677.39 2134.18 -1509.52 1520.29 4.00 5957928.76 678984.39 MWD+IFR 8243.26 40.79 156.27 7773.58 7710.55 2160.88 -1534.88 1531.65 4.00 5957903.68 678996.35 End Dir 8282.16 40.79 156.27 7803.03 7740.00 2185.25 -1558.14 1541.88 0.00 5957880.67 679007.12 THRZ 8300.00 40.79 156.27 7816.54 7753.51 2196.43 -1568.81 1546.57 0.00 5957870.12 679012.06 MWD+IFR 8400.00 40.79 156.27 7892.25 7829.22 2259.08 -1628.61 1572.86 0.00 5957810.96 679039.76 MWD+IFR 8500.00 40.79 156.27 7967.97 7904.94 2321.74 -1688.41 1599.16 0.00 5957751.80 679067.45 MWD+IFR 8539.70 40.79 156.27 7998.03 7935.00 2346.61 -1712.15 1609.60 0.00 5957728.31 679078.45 BHRZ 8585.93 40.79 156.27 8033.03 7970.00 2375.57 -1739.79 1621.75 0.00 5957700.97 679091.25 LCU 8600.00 40.79 156.27 8043.68 7980.65 2384.39 -1748.21 1625.45 0.00 5957692.64 679095.15 MWD+IFR 8632.15 40.79 156.27 8068.03 8005.00 2404.53 -1767.43 1633.90 0.00 5957673.62 679104.05 TJB 8700.00 40.79 156.27 8119.40 8056.37 2447.04 -1808.01 1651.74 0.00 5957633.48 679122.84 MWD+IFR 8764.23 40.79 156.27 8168.03 8105.00 2487.28 -1846.41 1668.63 0.00 5957595.49 679140.63 TJA 8800.00 40.79 156.27 8195.11 8132.08 2509.69 -1867.80 1678.04 0.00 5957574.33 679150.54 MWD+IFR 8900.00 40.79 156.27 8270.83 8207.80 2572.35 -1927.60 1704.33 0.00 5957515.17 679178.23 MWD+IFR 8902.91 40.79 156.27 8273.03 8210.00 2574.17 -1929.34 1705.09 0.00 5957513.45 679179.04 7" 8962.34 40.79 156.27 8318.03 8255.00 2611.40 -1964.88 1720.72 0.00 5957478.29 679195.50 TSHA 8975.55 40.79 156.27 8328.03 8265.00 2619.68 -1972.78 1724.19 0.00 5957470.47 679199.16 TSHB 9000.00 40.79 156.27 8346.54 8283.51 2635.00 -1987.40 1730.62 0.00 5957456.01 679205.93 MWD+IFR 9001.96 40.79 156.27 8348.03 8285.00 2636.23 -1988.58 1731.14 0.00 5957454.85 679206.47 TSHC 9034.98 40.79 156.27 8373.03 8310.00 2656.91 -2008.32 1739.82 0.00 5957435.31 679215.62 TSAD 9061.40 40.79 156.27 8393.03 8330.00 2673.46 -2024.12 1746.76 0.00 5957419.69 679222.93 45SB 9094.41 40.79 156.27 8418.03 8355.00 2694.15 -2043.86 1755.45 0.00 5957400.16 679232.08 44SB 9100.00 40.79 156.27 8422.26 8359.23 2697.65 -2047.20 1756.91 0.00 5957396.85 679233.62 MWD+IFR 9160.45 40.79 156.27 8468.03 8405.00 2735.53 -2083.35 1772.81 0.00 5957361.09 679250.37 42SB 9200.00 40.79 156.27 8497.97 8434.94 2760.30 -2107.00 1783.21 0.00 5957337.69 679261.32 MWD+IFR 9239.70 40.79 156.27 8528.03 8465.00 2785.17 -2130.74 1793.64 0.00 5957314.21 679272.31 TCGL 9300.00 40.79 156.27 8573.69 8510.66 2822.96 -2166.80 1809.50 0.00 5957278.54 679289.02 MWD+IFR 9338.75 40.79 156.27 8603.03 8540.00 2847.23 -2189.97 1819.69 0.00 5957255.61 679299.75 BCGL 9400.00 40.79 156.27 8649.40 8586.37 2885.61 -2226.60 1835.79 0.00 5957219.38 679316.71 MWD+IFR 9418.00 40.79 156.27 8663.03 8600.00 2896.88 -2237.36 1840.53 0.00 5957208.73 679321.70 23SB 9491.63 40.79 156.27 8718.78 8655.75 2943.01 -2281.39 1859.88 0.00 5957165.17 679342.09 Start Dir 1 9500.00 41.54 155.72 8725.08 8662.05 2948.31 -2286.43 1862.13 10.00 5957160.19 679344.45 MWD+IFR 9503.95 41.90 155.46 8728.03 8665.00 2950.84 -2288.82 1863.21 10.00 5957157.83 679345.59 22TS 9582.45 49.10 151.06 8783.03 8720.00 3005.26 -2338.70 1888.49 10.00 5957108.55 679372.04 21TS 9600.00 50.73 150.21 8794.33 8731.30 3018.45 -2350.41 1895.08 10.00 5957097.01 679378.90 MWD+IFR 9694.01 59.55 146.23 8848.03 8785.00 3094.68 -2415.82 1935.77 10.00 5957032.59 679421.12 TZ1 B 9700.00 60.11 146.00 8851.04 8788.01 3099.83 -2420.12 1938.66 10.00 5957028.35 679424.11 MWD+IFR 9798.69 69.48 142.57 8893.03 8830.00 3188.74 -2492.46 1990.79 10.00 5956957.26 679477.93 TDF 9800.00 69.61 142.53 8893.49 8830.46 3189.97 -2493.44 1991.54 10.00 5956956.31 679478.70 MWD+IFR 9900.00 79.16 139.46 8920.38 8857.35 3286.13 -2568.14 2052.12 10.00 5956883.06 679541.03 MWD+IFR 10000.00 88.74 136.59 8930.91 8867.88 3385.40 -2641.96 2118.57 10.00 5956810.83 679609.19 MWD+IFR 10008.23 89.53 136.35 8931.03 8868.00 3393.62 -2647.93 2124.24 10.00 5956805.00 679615.00 15-126 T1 10008.32 89.53 136.35 8931.03 8868.00 3393.70 -2647.99 2124.30 10.00 5956804.94 679615.06 End Dir : 1 10100.00 89.53 136.35 8931.79 8868.76 3485.21 -2714.33 2187.58 0.00 5956740.12 679679.89 MWD+IFR 10200.00 89.53 136.35 8932.61 8869.58 3585.02 -2786.68 2256.61 0.00 5956669.43 679750.60 MWD+IFR 10251.07 89.53 136.35 8933.03 8870.00 3636.00 -2823.63 2291.86 0.00 5956633.32 679786.71 BSAD • S er -Sun P rY BP Planning Report Company: BP Amoco Date: 6/13/2006 Time: 16:T6:26 . Page: 4 .Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-12, True North. Site: PB DS 15 Vertical (TVD) Reference: 33. 5 + 29.53 63.0 Well: 15- 12 Section (VS) Reference: Well (O.OON,O.OOE,139.82Azi) Wellpath: Plan 15-12B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inch Azim TVD Sys TVI) VS N!S FJW DLS M$pN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 10300 .00 89.53 136. 35 8933.43 8870.40 3684 .84 -2859.03 2325.63 0.00 5956598.73 679821.31 MWD+IFR 10400. 00 89.53 136. 35 8934.26 8871. 23 3784 .65 -2931.38 2394.66 0.00 5956528.03 679892.02 MWD+IFR 10500. 00 89.53 136. 35 8935.08 8872. 05 3884 .46 -3003.73 2463.69 0.00 5956457.34 679962.73 MWD+IFR 10600. 00 89.53 136. 35 8935.90 8872. 87 3984 .28 -3076.08 2532.72 0.00 5956386.64 680033.44 MWD+IFR 10607. 17 89.53 136. 35 8935.96 8872. 93 3991 .44 -3081.27 2537.67 0.00 5956381.57 680038.52 Start Dir 4/ 10623. 48 90.00 136. 80 8936.03 8873. 00 4007 .71 -3093.11 2548.87 4.00 5956370.00 680050.00 15-12B T2 10628. 20 90.19 136. 80 8936.02 8872. 99 4012 .43 -3096.55 2552.11 4.00 5956366.63 680053.31 End Dir : 1 10700. 00 90.19 136. 80 8935.79 8872. 76 4084 .13 -3148.89 2601.26 0.00 5956315.47 680103.69 MWD+IFR 10800. 00 90.19 136. 80 8935.46 8872. 43 4183 .99 -3221.78 2669.72 0.00 5956244,22 680173.84 MWD+IFR 10900. 00 90.19 136. 80 8935.13 8872. 10 4283 .85 -3294.67 2738.18 0.00 5956172.97 680244.00 MWD+IFR 11000. 00 90.19 136. 80 8934.80 8871. 77 4383 .71 -3367.57 2806.64 0.00 5956101,72 680314.15 MWD+IFR 11100. 00 90.19 136. 80 8934.47 8871. 44 4483 .57 -3440.46 2875.09 0.00 5956030.47 680384.31 MWD+IFR 11200. 00 90.19 136. 80 8934.14 8871. 11 4583 .43 -3513.35 2943.55 0.00 5955959,21 680454.46 MWD+IFR 11300. 00 90.19 136. 80 8933.81 8870. 78 4683 .29 -3586.24 3012.01 0.00 5955887.96 680524.62 MWD+IFR 11400. 00 90.19 136. 80 8933.48 8870. 45 4783 .15 -3659.14 3080.47 0.00 5955816.71 680594.77 MWD+IFR 11500. 00 90.19 136. 80 8933.15 8870. 12 4883 .01 -3732.03 3148.93 0.00 5955745.46 680664.93 MWD+IFR 11535. 00 90.19 136. 80 8933.03 8870. 00 4917 .96 -3757.54 3172.89 0.00 5955720.52 680689.48 41/2" 11535. 74 90.19 136. 80 8933.03 8870. 00 4918. 70 -3758.08 3173.39 0.00 5955720.00 680690.00 15-12B T3 vent • Terri Hubble BP Exploration AK Inc. PO Box 196.612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF • "Mastercard Check" 89-6/1252 280 DATE ~~ >~ $ I~~.G° First NTational Bank Alaska - , Anchorage, AK 99501 ~~~~~ MEMO ~.c-- ~: L 25 200060:99 L46 2 2 7 155611` 0 280 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~J~ (~ f s-/Z,~_ PTD# _ ~ p~~~ G~Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the 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 compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent 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 All 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. ,Company Name must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl ist m_.._ , ~.._ -_ -__.. ~~._ WtLL PEr~"AIT CHECKLIST yield & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 - -- ,,Well Name: PRUD_H_OE BAY UNIT 15-12B__ Program DEV ___ _ Well bore seg PTD#:2060870 Company BP EXPLORATION (ALASKA) INC ______ _ Initial CiasslType -m-_ - ~. _.~. ~ ~ - _ ____ _DEV / 1-O1i GeoArea 890 Unit 11650__. __ OnlOff Shore On Annular Disposal _ _ - PT ~- ~ Administration 1 . . -~ ___~_ Pe[mit_fee attached, Yes '12 Lease number appropriate- Yes 3 Unique well name and number .Yes I~4 Well located m adefined pool Yes 5 Well)ocated proper distance_from drilling unit boundary, Yes ~,6 Well located properdistance-fromotherwells- Yes I~7 Sufficient acreage available in drilling unit Yes _ ~8 If deviated, is_vuellbore plat included Yes i9 Operator only affected party- - Yes 110 Operator has approprate_bond in force - - - Yes 11 1 Permit_can be issued wdhout conservation order, No_ 12 Pe[mit.can be issued wlthoui administrative_approval Yes Appr Date ', ;13 Can permit be approved before 1~-daywait Yes _ _ RPC 6!2112006 ',14 Well located within area an_d strata authorized by Injection Orde[# (put.1O# in_comments).(i=4r_ fJA i15 All wells within 114_mile area of review identified (For se(uice w_el_I only) NA . 16 Pre-produced injector; duration of pre p[oduction less thaq 3 months, (for service well only) N_A_ ~~17 Nonconven gas conforms to A$31.05,030Q.1.A),(j,2.A-p) NA __- ---18 --- Conductor string-provided - Engineering i~19 Surface casing protects all known_l1SDWs . - fJA_ 1,20 CMT vol adequate_to circulate on conductor & surf-a9 fJA- 21 CMT vol adequate_to tie-in long string to_surf csg. - NA ~!i22 CMT will cover-all knownproductive horizons. _ _ _ _ _ _ _ Yes _ _ - - ..Adequate excess, _ 123 Casing designs adequate for C, T B &_ permafrost, Yes 124 Adequate tankage or reserve pit . Yes Nabors 27E, L25 If a re-drill, has. a_ 10-403 for abandonment been approved Yes 612212006.- X26. Adequate wellbore separation proposed _ _ Yes x;27 If_diverter required, does it meet regulations. - NA- Sidetrack. ~I28 Drilling fluid-program schematic & equip list-adequate, Yes Max. MW.10,8_ppg._ Appr Date ~i29 BOPEs, do they meet regulation _ - - - - - - . - - - - - - Yes - WGA 6123/2006 !30 BOPE.press rating appropriate; test to (put psig in comments)- . - - - - - - Yes Test to 400Qpsi. MSP 3434 psi., 31 Choke manifold c4mpliesw/APl_RP-53 (May84)_ _ _ _ _ _ _ - - _ _ Yes 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ ~33 Is presence of H2Sg~s ptobable No Not an H2$ pad. I34 Mechanical condition of wells within AOR verfied (For-service well only) NA --- -- ',35 Permitcan be issued wlo hydrogen_sulfide measures _ _ _ _ _ _ _ _ __ _ _ _ No_ _ .... _ _ ------- Geology X36 i Data presented on potential ove-rpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ I 37 Seismic analysis.of shallow gas zones... - - NA- - - _ - - - Appr Date 38 Seabed condition survey_(ifoff-shore) NA_ _ - - . - _ _ RPC 6121/2006 x,39 Contact namelphone for weekly-progress reports-[rrxploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ _ _ _ Geologic Engineering Public Commissioner: Date: Co missioner.. Date Commissioner Date C~~- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Penrritting Process but is part of the history file. To improve the readability of the Well History file: and to simplify Tending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 15-12b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 16 13:30:00 2008 Reel Header Service name .............LISTPE Date . ...................08/04/16 Ori in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/04/16 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Library. Scientific Technical services Physical EOF comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: 15-12B API NUMBER: 500292066502 OPERATOR: BP Exploration (Alaska) Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-APR-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 5 JOB NUMBER: Mw0004730559 Mw0004730559 Mw0004730559 LOGGING ENGINEER: B. TRANI B. TRANI N. WHITE OPERATOR WITNESS: C. CLEMENS C. CLEMENS B. DECKER MWD RUN 6 MWD RUN 7 MWD RUN 8 JOB NUMBER: Mw0004730559 Mw0004730559 Mw0004730559 LOGGING ENGINEER: M. BUCKLEY M. LEAFSTEDT M. LEAFSTEDT OPERATOR WITNESS: D. MASKELL D. MASKELL D. MASKELL MAD RUN 8 MWD RUN 9 MAD RUN 9 JOB NUMBER: Mw0004730559 Mw0004730559 Mw0004730559 LOGGING ENGINEER: M. LEAFSTEDT M. LEAFSTEDT M. LEAFSTEDT OPERATOR WITNESS: D. MASKELL D. MASKEL D. MASKEL SURFACE LOCATION SECTION: 22 Page 1 ~ • 15-12b.tapx TOWNSHIP: 11N RANGE: 14E FNL: 2114 FSL: FEL: FWL: 1474 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 58.03 GROUND LEVEL: 29.53 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 5637.0 2ND STRING 6.125 7.000 8957.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-5 WERE DRILLED BY NABORS 27E; MWD RUNS 6-9 WERE DRILLED BY NABORS 2ES. 4. THIS WELLBORE EXITS 15-12 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 5637'MD/5410'TVD. 5. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. UPHOLE MAD TIE-IN SGRC DATA ACQUIRED AFTER REACHING TD FOR RUN 1 WERE MERGED WITH RUN 1 MWD DATA. 6. MWD RUNS 2-9 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 1 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 5-8 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 7-9 ALSO INCLUDED COMPENSATED THERMAL NEUTRON(CTN) AND AZIMUTHAL LITHO-DENSITY (ALD). MAD PASS DATA ACQUIRED AFTER RUNS 8 AND 9 WERE MERGED, AND ARE PRESENTED SEPARATELY. NO PROGRESS WAS MADE, NO DATA WERE ACQUIRED ON RUNS 3 AND 4. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN IN 15-12 ON 11/1/1981. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 11/28/07, QUOTING AUTHORIZATION Page 2 15-12b.tapx OF ROGER FURLEY. MAD DATA WERE CORRECTED (SHIFTED) TO MWD DATA. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. THESE SHIFTED MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-9 REPRESENT WELL 15-12B WITH API# 50-029-20665-02. THIS WELL REACHED A TOTAL DEPTH OF 11500'MD/8901'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED-HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4-8.5 PPG MUD SALINITY: 3500-4800 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLiB.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 3 15-12b.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5453.0 11441.5 RPX 5604.5 11448.5 FET 5604.5 11448.5 RPM 5604.5 11448.5 RPS 5604.5 11448.5 RPD 5604.5 11448.5 ROP 5632.5 11498.5 FCNT 8921.0 11413.0 NCNT 8921.0 11413.0 NPHI 8921.0 11413.0 RHOB 8933.5 11428.5 DRHO 8933.5 11428.5 PEF 8933.5 11428.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 5455.5 5450.5 5461.0 5456.5 5474.0 5470.0 5482.0 5478.0 5485.5 5481.5 5491.0 5487.5 5496.0 5491.0 5499.0 5495.5 5505.5 5500.5 5508.5 5503.5 5521.0 5516.0 5524.0 5520.0 5527.0 5525.0 5532.5 5530.0 5537.5 5534.0 5545.5 5543.0 5550.0 5547.0 5552.5 5550.0 5555.0 5552.5 5574.5 5572.0 5593.5 5592.5 5600.5 5601.5 5609.0 5611.5 5615.0 5618.0 5622.0 5628.5 5632.5 5639.0 5640.0 5646.5 5645.5 5652.5 11496.5 11503.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 5446.0 5666.0 MwD 2 5666.0 8957.0 MwD 5 8957.0 8999.0 MwD 6 8999.0 9088.0 MwD 7 9088.0 9469.5 MwD 8 9469.5 9843.5 MwD 9 9843.5 11503.5 Page 4 15-12b.tapx REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 5453 11498.5 8475.75 12092 5453 11498.5 FCNT MWD CP30 112.33 2920 706.455 4985 8921 11413 NCNT MWD CP30 14216.8 50245.6 30324.3 4985 8921 11413 RHOB MWD G/CC 0.031 3.278 2.38421 4991 8933.5 11428.5 DRHO MWD G/CC -3.793 0.82 0.0394548 4991 8933.5 11428.5 RPD MWD OHMM 0.08 2000 96.05 11689 5604.5 11448.5 RPM MWD OHMM 0.2 2000 68.1597 11689 5604.5 11448.5 RPS MWD OHMM 0.22 1754.75 36.5526 11689 5604.5 11448.5 RPX MWD OHMM 0.12 1810.49 30.6976 11689 5604.5 11448.5 FET MWD HR 0.2 3216.17 34.5019 11689 5604.5 11448.5 GR MWD API 17.16 508.61 90.172 11963 5453 11441.5 PEF MWD B/E 0.64 14.43 2.35129 4991 8933.5 11428.5 ROP MWD FPH 0.02 2334.54 107.785 11733 5632.5 11498.5 NPHI MwD PU-S 6.33 65.89 23.2524 4985 8921 11413 First Reading For Entire File..........5453 Last Reading For Entire File...........11498 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Page 5 15-12b.tapx Physical EOF File Header Service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 9274.0 11409.5 FCNT 9274.0 11409.5 NCNT 9274.0 11409.5 RHOB 9288.5 11426.5 PEF 9288.5 11426.5 DRHO 9288.5 11426.5 GR 9301.5 11440.5 RPX 9310.0 11447.5 RPS 9310.0 11447.5 RPD 9310.0 11447.5 FET 9310.0 11447.5 RPM 9310.0 11447.5 RAT 9365.5 11495.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN N0. MAD PASS NO. MERGE TOP MERGE BASE MwD 8 1 9279.0 9843.5 MwD 9 1 9549.5 11503.5 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FONT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 Page 6 15-12b.tapx RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 9274 11495 10384.5 4443 9274 11495 FONT MAD CP30 286.33 2322.89 671.29 4272 9274 11409.5 NCNT MAD CP30 20745 44643.7 30676.8 4272 9274 11409.5 RHOB MAD G/CC 2.068 2.923 2.41478 4277 9288.5 11426.5 DRHO MAD G/CC -0.196 0.818 0.0443149 4277 9288.5 11426.5 RPD MAD OHMM 8.22 2000 126.956 4276 9310 11447.5 RPM MAD OHMM 7.85 1906.37 85.1288 4276 9310 11447.5 RPS MAD OHMM 8.22 1595.65 61.7206 4276 9310 11447.5 RPX MAD OHMM 7.25 267.47 54.8611 4276 9310 11447.5 FET MAD HR 3.4 95.86 36.8959 4276 9310 11447.5 GR MAD API 15.83 206.73 72.8847 4279 9301.5 11440.5 PEF MAD B/E 0.92 7.32 2.31552 4277 9288.5 11426.5 RAT MAD FPH 0.33 1870.05 411.502 4260 9365.5 11495 NPHI MAD PU-S 7.95 34.81 23.5729 4272 9274 11409.5 First Reading For Entire File..........9274 Last Reading For Entire File...........11495 File Trailer Service name... .......STSLIB.002 Service sub Level~Name... version Number.. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. Page 7 15-12b.tapx BI T RUN NUMBER: 1 DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5446.0 5611.5 RoP 5637.0 5666.0 LOG HEADER DATA DATE LOGGED: 29-~uL-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5666.0 TOP LOG INTERVAL (FT): 5637.0 BOTTOM LOG INTERVAL (FT): 5666.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 26.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 5637.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 80.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 106.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logyin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 8 15-12b.tapx Max frames per record ..... ........undefine d Absent value ... ...................-999 Depth Units. . . .. .. ..... Datum Specifica tion Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5446 5666 5556 441 5446 5666 GR MWDO10 API 31.91 78.07 47.2791 315 5446 5611.5 ROP MWDO10 FPH 0.03 12.6 5.70932 59 5637 5666 First Reading For Entire File..........5446 Last Reading For Entire File...........5666 File Trailer service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5604.0 8902.5 RPM 5604.0 8902.5 RPD 5604.0 8902.5 RPS 5604.0 8902.5 RPx 5604.0 8902.5 GR 5612.0 8910.0 ROP 5666.5 8957.0 Page 9 r ~ 15-12b.tapx LOG HEADER DATA DATE LOGGED: 02-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8957.0 TOP LOG INTERVAL (FT): 5666.0 BOTTOM LOG INTERVAL (FT): 8957.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.9 MAXIMUM ANGLE: 35.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 5637.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Polymer 10.00 46.0 9.0 12500 3.0 .305 64.0 .140 145.0 .275 64.0 .205 64.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 10 15-12b.tapx RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5604 8957 7280.5 6707 5604 8957 RPD MWD020 OHMM 0.08 2000 11.2666 6598 5604 8902.5 RPM MWD020 OHMM 0.2 1553.88 3.16141 6598 5604 8902.5 RPS MWD020 OHMM 0.22 1754.75 3.66975 6598 5604 8902.5 RPX MWD020 OHMM 0.12 1810.49 3.64345 6598 5604 8902.5 FET MWD020 HR 0.2 37.36 1.52495 6598 5604 8902.5 GR MWD020 API 22.58 396.51 113.157 6597 5612 8910 ROP MWD020 FPH 1.13 336.98 128.689 6582 5666.5 8957 First Reading For Entire File..........5604 Last Reading For Entire File...........8957 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPx 8903.0 RPS 8903.0 FET 8903.0 RPD 8903.0 RPM 8903.0 STOP DEPTH 8946.0 8946.0 8946.0 8946.0 8946.0 Page 11 f • 15-12b.tapx GR 8910.5 8939.0 ROP 8957.5 8999.0 LOG HEADER DATA DATE LOGGED: 12-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8999,0 TOP LOG INTERVAL (FT): 8957.0 BOTTOM LOG INTERVAL (FT): 8999.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1 wR4 Electromag Resis. 4 130908 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8957.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Page 12 Polymer 8.50 26.0 .0 0 .0 .000 .0 .000 98.6 .000 .0 .000 .0 15-12b.tapx Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8903 8999 8951 193 8903 8999 RPD MWD050 OHMM 1.55 2000 1154.45 87 8903 8946 RPM MWD050 OHMM 5.56 2000 1620.84 87 8903 8946 RPS MWD050 OHMM 1.87 7.46 3.97667 87 8903 8946 RPX MWD050 OHMM 1.49 3.46 2.31828 87 8903 8946 FET MwD050 HR 236.66 240.36 238.62 87 8903 8946 GR MWD050 API 65.44 92.48 77.7569 58 8910.5 8939 ROP MWD050 FPH 4.57 2334.54 222.251 84 8957.5 8999 First Reading For Entire File..........8903 Last Reading For Entire File...........8999 File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8939.5 9025.0 RPS 8946.5 9031.0 Page 13 15-12b.tapx RPx 8946.5 9031.0 RPD 8946.5 9031.0 FET 8946.5 9031.0 RPM 8946.5 9031.0 RoP 8999.5 9088.0 LOG HEADER DATA DATE LOGGED: 14-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9088.0 TOP LOG INTERVAL (FT): 8999.0 BOTTOM LOG INTERVAL (FT): 9088.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.7 MAXIMUM ANGLE: 26.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8957.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 47.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 10.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT); .000 .O MUD AT MAX CIRCULATING TER MPERATURE: .000 141.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 14 15-12b.tapx Absent value .... ..................-999 Depth Units. .. .. .. ..... Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8939.5 9088 9013.75 298 8939.5 9088 RPD MWD060 OHMM 0.54 1779.08 90.825 170 8946.5 9031 RPM MWD060 OHMM 1.2 2000 70.9565 170 8946.5 9031 RPS MWD060 OHMM 0.31 1467.2 21.1145 170 8946.5 9031 RPX MWD060 OHMM 0.27 662.82 10.0218 170 8946.5 9031 FET MWD060 HR 0.33 3216.17 2057.75 170 8946.5 9031 GR MWD060 API 49.02 381.44 104.522 172 8939.5 9025 ROP MWD060 FPH 12 259 90.9766 178 8999.5 9088 First Reading For Entire File..........8939 Last Reading For Entire File...........9088 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File type. ............Lo Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY Page 15 • VENDOR TOOL CODE START DEPTH FCNT 8926.0 NPHI 8926.0 NCNT 8926.0 DRHO 8938.5 PEF 8938.5 RHOB 8938.5 GR 9025.5 RPx 9031.5 RPM 9031.5 RPD 9031.5 RPS 9031.5 FET 9031.5 $OP 9088.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD 15-12b.tapx STOP DEPTH 9375.5 9375.5 9375.5 9391.0 9391.0 9391.0 9403.5 9411.0 9411.0 9411.0 9411.0 9411.0 9469.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 16 18-DEC-06 Insite 74.09 Memory 9466.0 9088.0 9466.0 21.4 30.2 TOOL NUMBER 153879 1844674407370955 48783 183652 6.125 8957.0 Polymer 8.40 60.0 8.7 3500 .0 .910 69.0 .640 100.4 .760 69.0 .710 69.0 15-12b.tapx REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD070 CP30 4 1 68 4 2 NCNT MWD070 CP30 4 1 68 8 3 RHOB MWD070 G/CC 4 1 68 12 4 DRHO MWD070 G/CC 4 1 68 16 5 RPD MWD070 OHMM 4 1 68 20 6 RPM MWD070 OHMM 4 1 68 24 7 RPS MWD070 OHMM 4 1 68 28 8 RPX MWD070 OHMM 4 1 68 32 9 FET MWD070 HR 4 1 68 36 10 GR MWD070 API 4 1 68 40 11 PEF MWD070 B/E 4 1 68 44 12 ROP MWD070 FPH 4 1 68 48 13 NPHI MWD070 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8926 9469.5 9197.75 1088 8926 9469.5 FONT MWD070 CP30 112.33 2920 898.175 900 8926 9375.5 NCNT MWD070 CP30 14216.8 50245.6 29860.4 900 8926 9375.5 RH08 MWD070 G/cc 0.031 3.278 2.27121 906 8938.5 9391 DRHO MWD070 G/CC -3.793 0.82 -0.0260188 906 8938.5 9391 RPD MWD070 OHMM 0.38 2000 358.311 760 9031.5 9411 RPM MWD070 OHMM 0.51 2000 218.663 760 9031.5 9411 RPS MWD070 OHMM 0.39 1204.7 92.3347 760 9031.5 9411 RPX MWD070 OHMM 0.37 330.09 43.5115 760 9031.5 9411 FET MWD070 HR 1.08 70.31 13.4794 760 9031.5 9411 GR MWD070 API 17.38 508.61 52.827 757 9025.5 9403.5 PEF MWD070 B/E 0.64 14.43 2.62395 906 8938.5 9391 ROP MWD070 FPH 0.07 244 42.119 763 9088.5 9469.5 NPHI MWD070 Pu-s 6.33 65.89 22.1697 900 8926 9375.5 First Reading For Entire File..........8926 Last Reading For Entire File...........9469 File Trailer Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Page 17 15-12b.tapx Physical EOF File Header service name... .......STSLI6.008 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9376.0 9749.0 NPHI 9376.0 9749.0 FCNT 9376.0 9749.0 DRHO 9391.5 9764.5 PEF 9391.5 9764.5 RHOB 9391.5 9764.5 GR 9404.0 9777.5 RPD 9411.5 9784.5 RPM 9411.5 9784.5 RPX 9411.5 9784.5 FET 9411.5 9784.5 RPS 9411.5 9784.5 OP 9470.0 9843.5 $ LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9840.0 TOP LOG INTERVAL (FT): 9466.0 BOTTOM LOG INTERVAL (FT): 9840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 87.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 48783 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 Page 18 15-12b.tapx DRILLER'S CASING DEPTH (FT): 8957.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 53.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 4400 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .500 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .340 104.0 MUD FILTRATE AT MT: .600 69.0 MUD CAKE AT MT: .760 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MwD080 CP30 4 1 68 4 2 NCNT MwD080 cP30 4 1 68 8 3 RHOB MWD080 G/CC 4 1 68 12 4 DRHO MWD080 G/CC 4 1 68 16 5 RPD MwD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MwD080 OHMM 4 1 68 32 9 FET MWD080 HR 4 1 68 36 10 GR MWD080 API 4 1 68 40 11 PEF MwD080 B/E 4 1 68 44 12 RoP MwD080 FPH 4 1 68 48 13 NPHI MwD080 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9376 9843.5 9609.75 936 9376 9843.5 FONT MWD080 CP30 351.91 946.11 607.548 747 9376 9749 NCNT MWD080 CP30 19685.1 36052.1 28394.9 747 9376 9749 RHOB MWD080 G/CC 2.064 2.937 2.32789 747 9391.5 9764.5 DRHO MWD080 G/CC -0.131 0.694 0.022344 747 9391.5 9764.5 Page 19 15-12b.tapx RPD MWD080 OHMM 7.47 2000 357.425 747 9411.5 9784.5 RPM MWD080 OHMM 6.9 2000 194.745 747 9411.5 9784.5 RPS MWD080 OHMM 7.03 244.37 79.6736 747 9411.5 9784.5 RPX MWD080 OHMM 6.66 108.95 47.9119 747 9411.5 9784.5 FET MwD080 HR 2.36 28.62 7.60357 747 9411.5 9784.5 GR MWD080 API 17.16 147.88 48.6193 748 9404 9777.5 PEF MwD080 B/E 1.03 8.41 2.04526 747 9391.5 9764.5 ROP MWD080 FPH 0.02 219.98 27.3442 748 9470 9843.5 NPHI MWD080 Pu-s 18.23 30.66 23.7367 747 9376 9749 First Reading For Entire File..........9376 Last Reading For Entire File...........9843.5 File Trailer Service name... .......STSLI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Ty ~e ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9749.5 11418.0 NPHI 9749.5 11418.0 FCNT 9749.5 11418.0 PEF 9765.0 11433.5 DRHO 9765.0 11433.5 RHOB 9765.0 11433.5 GR 9778.0 11446.5 RPD 9785.0 11453.5 RPS 9785.0 11453.5 FET 9785.0 11453.5 RPM 9785.0 11453.5 RPx 9785.0 11453.5 RoP 9844.0 11503.5 S LOG HEADER DATA Page 20 i 15-12b.tapx DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum Specification Block sub-type...0 23-DEC-06 Insite 74.09 Memory 11500.0 9840.0 11500.0 86.8 92.4 TOOL NUMBER 153879 1844674407370955 48783 183652 6.125 8957.0 Polymer 8.40 54.0 9.0 3900 9.3 1.000 69.0 .570 125.6 .960 69.0 1.110 69.0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 21 • 15-12b.tapx FCNT MWD090 CP30 4 1 68 4 2 NCNT MwD090 cP30 4 1 68 8 3 RHO6 MWD090 G/CC 4 1 68 12 4 DRHO MWD090 G/CC 4 1 68 16 5 RPD MwD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MWD090 OHMM 4 1 68 28 8 RPX MWD090 OHMM 4 1 68 32 9 FET MWD090 HR 4 1 68 36 10 GR MWD090 API 4 1 68 40 11 PEF MWD090 B/E 4 1 68 44 12 RoP MWD090 FPH 4 1 68 48 13 NPHI MWD090 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9749.5 11503.5 10626.5 3509 9749.5 11503.5 FONT MWD090 CP30 290.99 1363.33 676.897 3338 9749.5 11418 NCNT MWD090 CP30 17912.4 40570.6 30881.2 3338 9749.5 11418 RHOB MWD090 G/CC 2.116 2.916 2.42748 3338 9765 11433.5 DRHO MWD090 G/CC -O.l 0.584 0.0610548 3338 9765 11433.5 RPD MWD090 OHMM 24.46 2000 118.267 3338 9785 11453.5 RPM MWD090 OHMM 17.82 1821.79 93.2097 3338 9785 11453.5 RPS MWD090 OHMM 15.75 1595.65 80.717 3338 9785 11453.5 RPX MWD090 OHMM 13.09 321.73 79.0975 3338 9785 11453.5 FET MWD090 HR 0.31 23.57 2.12419 3338 9785 11453.5 GR MwD090 API 21.08 187.47 65.7108 3338 9778 11446.5 PEF MwD090 B/E 1.02 6.04 2.34576 3338 9765 11433.5 ROP MWD090 FPH 0.11 414.39 99.347 3320 9844 11503.5 NPHI MwD090 PU-S 14.61 34.43 23.436 3338 9749.5 11418 First Reading For Entire File..........9749.5 Last Reading For Entire File...........11503.5 File Trailer Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Ty e ................LO Next File Name...........STSLIB.010 Physical EOF File Header service name... .......STSLIB.O10 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.009 comment Record FILE HEADER FILE NUMBER: 10 Page 22 i RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 8 MAD PASS NUMBER: 1 FILE SUMMARY r 15-12b.tapx for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 9279.0 9750.0 NPHI 9279.0 9750.0 NCNT 9279.0 9750.0 RHOB 9293.5 9766.0 DRHO 9293.5 9766.0 PEF 9293.5 9766.0 GR 9306.5 9779.0 RPS 9315.0 9549.0 FET 9315.0 9549.0 RPX 9315.0 9549.0 RPM 9315.0 9549.0 RPD 9315.0 9549.0 RAT 9370.5 9842.5 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9843.5 TOP LOG INTERVAL (FT): 9279.0 BOTTOM LOG INTERVAL (FT): 9843.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 87.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 48783 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8957.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 53.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 4400 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .500 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .340 104.0 MUD FILTRATE AT MT: .600 69.0 MUD CAKE AT MT: .760 69.0 NEUTRON TOOL Page 23 • 15-12b.tapx MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging DireCtion .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MAD081 CP30 4 1 68 4 2 NCNT MAD081 CP30 4 1 68 8 3 RHOB MAD081 G/CC 4 1 68 12 4 DRHO MAD081 G/CC 4 1 68 16 5 RPD MAD081 OHMM 4 1 68 20 6 RPM MAD081 OHMM 4 1 68 24 7 RPS MAD081 OHMM 4 1 68 28 8 RPx MAD081 OHMM 4 1 68 32 9 FET MAD081 HR 4 1 68 36 10 GR MAD081 API 4 1 68 40 11 PEF MAD081 B/E 4 1 68 44 12 RAT MAD081 FPH 4 1 68 48 13 NPHI MAD081 PU-5 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9279 9842.5 9560.75 1128 9279 9842.5 FCNT MAD081 CP30 364.02 2322.89 705.612 943 9279 9750 NCNT MAD081 CP30 22265.1 44643.7 29990.4 943 9279 9750 RHOB MAD081 G/CC 2.068 2.911 2.31595 946 9293.5 9766 DRHO MAD081 G/CC -0.196 0.368 0.0284979 946 9293.5 9766 RPD MAD081 OHMM 8.22 2000 321.308 469 9315 9549 RPM MAD081 OHMM 7.85 1906.37 139.7 469 9315 9549 RPS MAD081 OHMM 8.22 238.49 57.8331 469 9315 9549 RPx MAD081 OHMM 7.25 94.45 35.4057 469 9315 9549 FET MAD081 HR 23.72 62.81 47.1997 469 9315 9549 GR MAD081 API 15.83 186.17 52.4442 946 9306.5 9779 PEF MAD081 B/E 0.97 7.32 1.98476 946 9293.5 9766 RAT MAD081 FPH 1 878 269.569 945 9370.5 9842.5 NPHI MAD081 PU-S 7.95 32.85 22.7459 943 9279 9750 First Reading For Entire File..........9279 Last Reading For Entire File...........9842 File Trailer Page 24 • 15-12b.tapx Service name... .......STSLIB.O10 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.011 Physical EOF File Header Service name... .......STSLIB.O11 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 9 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9549.5 11452.5 FET 9549.5 11452.5 RPX 9549.5 11452.5 RPS 9549.5 11452.5 RPM 9549.5 11452.5 NPHI 9750.5 11414.5 FCNT 9750.5 11414.5 NCNT 9750.5 11414.5 PEF 9766.5 11431.5 RHOB 9766.5 11431.5 DRHO 9766.5 11431.5 GR 9779.5 11445.5 RAT 9843.0 11502.5 LOG HEADER DATA DATE LOGGED: 23-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11503.5 TOP LOG INTERVAL (FT): 9549.5 BOTTOM LOG INTERVAL (FT): 11503.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 25 • 15-12b.tapx DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EwR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • 153879 1844674407370955 48783 183652 6.125 8957.0 Polymer 8.40 54.0 9.0 3900 9.3 1.000 69.0 .570 125.6 .960 69.0 1.110 69.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD091 CP30 4 1 68 4 2 NCNT MAD091 CP30 4 1 68 8 3 RHOB MAD091 G/CC 4 1 68 12 4 DRHO MAD091 G/CC 4 1 68 16 5 RPD MAD091 OHMM 4 1 68 20 6 RPM MAD091 OHMM 4 1 68 24 7 RPS MAD091 OHMM 4 1 68 28 8 RPX MAD091 OHMM 4 1 68 32 9 FET MAD091 HR 4 1 68 36 10 GR MAD091 API 4 1 68 40 11 PEF MAD091 B/E 4 1 68 44 12 RAT MAD091 FPH 4 1 68 48 13 NPHI MAD091 PU-S 4 1 68 52 14 Page 26 • 15-12b.tapx First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9549.5 11502.5 10526 3907 9549.5 11502.5 FONT MAD091 CP30 286.33 1242.18 661.568 3329 9750.5 11414.5 NCNT MAD091 CP30 20745 39052.5 30871.2 3329 9750.5 11414.5 RHOB MAD091 G/CC 2.145 2.923 2.44285 3331 9766.5 11431.5 DRHO MAD091 G/CC -0.12 0.818 0.048807 3331 9766.5 11431.5 RPD MAD091 OHMM 8.57 1307.18 103.013 3807 9549.5 11452.5 RPM MAD091 OHMM 8.46 1821.79 78.4059 3807 9549.5 11452.5 RPS MAD091 OHMM 8.4 1595.65 62.1996 3807 9549.5 11452.5 RPX MAD091 OHMM 7.39 267.47 57.2579 3807 9549.5 11452.5 FET MAD091 HR 3.4 95.86 35.6265 3807 9549.5 11452.5 GR MAD091 API 21.63 206.73 78.6863 3333 9779.5 11445.5 PEF MAD091 B/E 0.92 7.26 2.40946 3331 9766.5 11431.5 RAT MAD091 FPH 0.33 1870.05 451.608 3320 9843 11502.5 NPHI MAD091 PU-S 15.36 34.81 23.8071 3329 9750.5 11414.5 First Reading For Entire File..........9549.5 Last Reading For Entire File...........11502.5 File Trailer Service name... .......STSLIB.O11 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/16 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.012 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/16 Origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/04/16 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF scientific Technical services Scientific Technical Services Physical EOF Page 27 End Of LIS File 15-12b.tapx Page 28 •