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Home My WebLink About204-051 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 W- - 0 S 1 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 R~AN \zf' Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. d... o Other, NolType: o Poor Quality Originals: o Other: NOTES: Date ~, q I () ft, BY: ~ Project Proofing BY: c: Maria~ Date 10 /} I () fn ~ x30= CfO + Date: to I q I 0 0 Scanning Preparation BY: ~ Production Scanning Stage 1 ql (Count does include cover sheet) VYES Page Count from Scanned File: BY: Page Count Matches Number in Scanning Preparation: S Date: (pI q 10 fo If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VV\r 151 1/11111111111111111 151 n1P = TOTAL PAGES ()J 0 (Count does not include cover shelt) "I\!\ f Isl \ I \ 11/1111111111111111 NO 151 tv1 P YES NO 151 111111111111111111I 11111111111111 11111 151 Quality Checked 11111111111I 111111I 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 `j ' E: ' ' 914t "t4?4&t‘ 4°6' ;,, Cl i% Mr. Tom Maunder "It Alaska Oil and Gas Conservation Commission " 4 e,, 333 West 7 Avenue. Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 q 04- 0'C 1 Dear Mr. Maunder, 0 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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 -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 ' 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 • STATE OF ALASKA ALASKA IDAND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver 0 Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate p Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ . 204 -0510 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 22011 -03 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028308 ' t PBU 02 -29C 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11411 feet Plugs (measured) None feet true vertical 8856.3 feet ti (reasured) None feet Effective Depth measured 11380 feet 1 ` Packer (measured) 4097, 8386 8476 8636 feet true vertical 8852.75 feet (true vertical) 3856, 7707 7793 7947 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 91.5# H -40 31 - 112 31 - 112 1490 470 Surface 74' 13 -3/8" 68# K -55 30 - 104 30 - 104 3450 1950 Surface 3819' 13- 3/8 "68# L -80 104 - 3923 104 - 3703 4930 2270 Production 9070' 9 -5/8" 47# L -80 29 - 9099 29 - 8401 6870 4760 Liner 572' 7" 29# L -80 8683 - 9255 7993 - 8554 8160 7020 Liner 2724' 2 -3/8" 4.6# L -80 8687 - 11411 7997 - 8856 Scab Liner 4495' 7" 26# L -80 4097 - 8592 3856 - 7904 Perforation depth: Measured depth: SEE ATTACHED - _ - - - True Vertical depth: _ _ - - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 29 - 3011 29 - 2900 3 -1/2" 9.2# 13CR80 3011 - 8454 2900 - 7772 3 -1/2" 9.3# L -80 8454 - 8740 7772 - 8049 Packers and SSSV (type, measured and true vertical depth) 7" BKR ZXP LTP 4097 3856 4 -1/2" BKR S -3 PKR 8386 7707 4 -1/2" BKR S -3 PKR �,IV 7947 3 -1/2" BKR MOD D PKR ? EC 12. Stimulation or cement squeeze summary: n AUG 2 3 1 011 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: & Gsa tat' Nncfiera9$ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 472 32,484 28 878 Subsequent to operation: 373 26,598 29 882 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil • Ei Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ 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 Joe Lastufka Printed Na.- oe Lastu iii Title Petrotechnical Data Technologist Signat lioni Phone 564 -4091 Date 8/23/2011 -- . , mrp *s"aT n. • Sdbmit Original Only -- SDMS AUG 2 4 20 �� f.wy-« if 02 -29C 204 -051 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02 -29C 5/3/04 PER 10,670. 11,100. 8,873.3 8,849. 02 -29C 8/30/04 BPS 8,685. 11,100. 7,994.68 8,849. 02 -29C 10/4/04 BPP 8,685. 11,100. 7,994.68 8,849. 02 -29C 7/2/05 RPF 10,780. 10,880. 8,861.35 8,857.63 02 -29C 7/4/05 APF 11,140. 11,210. 8,848.48 8,849.03 02 -29C 8/8/05 APF 9,970. 10,000. 8,916.04 8,910.5 02 -29C 8/9/05 APF 9,910. 9,970. 8,921.02 8,916.04 02 -29C 7/29/11 APF d' 9,735. 9,755. 8,906.01 8,909.44 02 -29C 7/29/11 APF V 9,770. 9,795. 8,911.63 8,913.94 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED 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 • • • 02 -29C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/28/2011; CTU #8, 1.5" coil, Job Scope: Tie -in log, drift and add pert. :MIRU CTU #8. Perform weekly BOP test. Load well with 5 bbls meth, 110 bbls KCL, '5 bbls meth. RIH w/ 1.69" ctc,dfcv,blank sub, 1.56 crossover, 1.75" KJ, 1 11/16" memory CCL, GR, 1.7" crossover, 1.68" crossover, 1.75" stinger and nozzle (oal= 17.33') * *job continued on WSR 07- 29 -11 ** 7/29/2011 Continued from WSR 07- 28 -11. CTU 8 w/ 1.5" CT. Scope; Addperfs ;Continue RIH w/ 1.69" ctc,dfcv,blank sub, 1.56 crossover, 1.75" KJ, 1 11/16" memory ICCL, GR, 1.7" crossover, 1.68" crossover, 1.75" stinger and nozzle (oal= 17.33'), Stop © 10050'. Log 40 fpm.. flag pipe © 9900' and cont log 40 fpm up to 8000'. pooh. Good data. M/U 25' of 1.56" perf guns. RIH. Correct to flag. Perforate 9770 - 9795' with 6 spf. POH. All shots fired. RIH with 20' pert gun. Correct depth at flag. Perforate 9735 - 9755' with 6 spf. POH. All shots fired, recovered ball. ** *job complete * ** 1 1 + FLUIDS PUMPED BBLS 10 50/50 METH 110 1 %KCL 120 TOTAL TREE= . CIW GEN 4 WELLHEAD = CIW • 02-29C , SAFETY Ne: 3-1/2" CHROMETBG*** I ACTUATOR = AXELSON KB. ELEV = 62' i BF. ELEV = 120" CONDUCTOR H ? El i... 1 I •1 '• .• KOP = — 9'00' • • U 13-3/8" CSG, --I 104' • .• ,, 2120' H4-1/2" HES X NIP, ID = 3.813" 1 Max Angle = 102 @ 9982' • .• .4 Datum MD = 9621 68#, K-55, • , • • A , • 3014' I-14-1/2" X 3-1/2" X0, ID = 2.992" •,..■ .• Datum W = 8800' SS ID = 12.415" • .• • ; GAS LIFT MANDRELS .• l!''.: • .1 .. 4-1/2" TBG, 12.6#, L-80, BTC, IPC, — 3014' ST MD ]VD DEV TYPE VLV LATCH PORT DATE .0152 bpf, ID = 3.958" 1 3405 3249 27 MMG DOME RK 16 06/26/07 2 _ 6226 5757 25 MMG SO RK 20 06/26/07 113-3/8 CSG, 68#, L-80, 0= 12.415" H 3923' 11 ■ : ,1 • 8364' —13-1/2" HES X NIP (9CR), ID = 2.813" I 9-5/8" X 7" BKR ZXP LTP, ID = 6.28" H 4097' : 1 4 1 ■ 1 A 8386' 1-17" x 4-1/2" BKR (9CR) S-3 PKR, ID = 3.89" I Minimum ID = 1.92" @ 8693' * 0 i:4;.; TOP OF 2-3/8" LINER . N . F 84m3. --I 3-1/2" FES X NIP (9CR), ID= 2.813" I ' • 3-1/2" TBG, 12.6#, 13CR-80, VAMP TOP 8454' . 1 1 , • . . P., .0152 bpf, ID = 3.958" W 8464' . 1 - 17" x 3-1/2" UNIQUE OVERSHOT I : ■■•• 13-1/2" TUBING STUB (06/08/07) I — 8456' 7 ,, V, 8476' — 17" x 4-1/2" BKR S-3 PKR, ID = 3.88" , •;•,- kV 1# : • • ■ • 8534' — 13-1/2" X NIP, ID = 2.813" 1 17" SCAB LNR, 26#, L-80, ID = 6.276" H 8546' *4 44, 17" x 4-1/2" X0, ID = 3.94" H 854T %• **I Vrf +0 8545' I - 13-1/2" MULESHOE, ID = 2.992" I .• 10 S.' 4+4 13-1/2" TUBING STUB (05/31/07) I 8592' 1■4 8592' I - 17" x 3-1/2" UNIQUE OVERSHOT 1 V kV XIII, of,:rei 8634' —13-1/2" BKR LOC SEAL ASSY, ID = 3.00" I mil 8636' H9-5/8" X3-112" BKR MOD D PKR, D = 4.75" I 8655' 1-13-1/2" BKR MILLOUT EXT, ID = 6.00" 1 9-5/8" x 7" TIEBACK RECEPTABLE --I 8683' I w / HYDRO HGR, ID = ?? L 8687' 1-12-5/8" BKR DEPLOY SLV, ID = 2.250" I 1 8693' I - 12-5/8" X 2-3/8" X0, ID = 1.920" 1 ill 1 8727' H3-1/2" OTIS XN NIP, MILLED ID = 2.80" 3-1/2" TBG, 9.3#, L-80, EUE-8RD, 8740' 1 .0087 bpf, ID = 2.992" II I 8739' H3-1/2" BKR SHEAR OUT SUB I Behind I 19-5/8" CSG, 47#, L-80, BTC-M, ID = 8.681" I 9099' I 8740' 1-13-1/2" WLEG, ID = 3.00" CT LNR 1 8719' H ELMD TT LOGGED 04/26/90 I ,• •• •• .•, 14., 9075' 1-1TOP OF CEMENT 1 17" LNR, 29#, L-80, BTC, .0371 bpf, D = 6.184" H — 9791 1---- ' ■• •• ■ • • PERFORATION SUMMARY I 7" MILLOUT WINDOW (02-29C) 9251' - 9255' REF LOG: SWS MCNL / GR / CCL ON 05/03/04 ANGLE AT TOP PERF: 91 @ 9910' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 9735 -9755 0 07/29/11 V I 1.56" 6 9770 - 9795 0 07/29/11 V I 1.56" 6 9910 - 10000 0 08/09/05 1.56" 6 10670 - 11100 0 05/03/04 1.56" 6 10780 - 10880 0 07/04/05 1.56" 6 11140 - 11210 0 07/04/05 I 1 I 1 1 1 1 1 11380' I-1 PBTD 1 12-3/8" LNR, 4.6#, L-80, .0036 bpf, ID = 1.92" H 11411' I !..t. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/29/90 N2ES ORIG COMPLETION (02-29A) 07/17/10 CRH/PJC FINAL DRLG CORRECTIONS WELL: 02-29C 10/07/03 NORDIC2 ABORTED (02.29B) CTD 07/29/11 RMH/PJC ADPERFS PERMIT No: r 2040510 05/04/04 NORDICI CTD SIDETRACK (02-29C) API No: 50-029-22011-03 06/10/07 N4ES RWO SEC 36, T1 1N, R14E, 161.22' FEL & 5259' FNL 06/26/07 BSEJTLH GLV C/O 12/15/09 SV DRLG DRAFT BP Exploration (Alaska) • • »,.., ;~~ ,~ ~k ~~ ~C ~.s ~.. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~ . STATE OF ALASKA _ ?-/5~~ RECEIVED ALASKA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS JUL 1 2 2007 í\ 1..,,1.. n: () ro. n n. 1. Operations Performed: -...- -.. UU.. VV.h.. ,",UI II Anc'mraij{f o Abandon ~ Repair Well o Plug Perforations o Stimulate ORe-Enter Suspen e ell ~ter CaSing~~ ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 204-051 - 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22011-03-00 " 7. KB Elevation (ft): 63' 9. Well Name and Number: / PBU 02-29C - 8. Property Designation: 10. Field / Pool(s): ADL 028308 - Prudhoe Bay Field / Prudhoe Bay Pool - 11. Present well condition summary Total depth: measured 11411 . feet true vertical 8856 . feet Plugs (measured) None Effective depth: measured 11380 feet Junk (measured) None true vertical 8853 / feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 3923' 13-3/8" 3923' 3704' 4930 2270 Intermediate 9099' 9-5/8" 9099' 8401' 6870 4760 Production Liner 1108' 7" 8683' - 9251' 7993' - 8550' 8160 7020 Liner 2729' 2-3/8" 8682' - 11411' 7992' - 8856' 11200 11780 Scab Liner 4495' 7" x 4-1/2" 4097' - 8592' 3856' - 7904' Perforation Depth MD (ft): 9910' -11210' SCANNED JUL 1 8 2007 Perforation Depth TVD (ft): 8921' - 8849' 4-1/2", 12.6# x 3-1/2",9.2# 13Cr80 Surface - 8464'; Tubing Size (size, grade, and measured depth): p. ~-1/?" ç¡ ~# 1-80 Ae::no:¡' _ A7 An' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker Perm. packer; 7" x 4-112" 'S-3' Perm. 8386'; packer; 9-5/8" x 3-1/2" Baker '0' packer 8476'; 8636' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl JUL 1 7 2DD7 Treatment description including volumes used and final pressure: Cut and pulled tubing from -8603'. Run 7" Scab Liner and cement with 130 Bbls Class 'G' (730 cu ft /629 sx). Run new Chrome tubinQ, discovered leak, pull tubinQ. Find leak, repair/replace and run new Chrome tubing. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development o Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 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: Contact Aras Worthington, 564-4102 307-108 Printed Name T,errie Hubble Title Technical Assistant Signature ~ ~ k\,~ Date ôì/(Z!o7 Prepared By Name/Number: Phone 564-4628 Terrie Hubble, 564-4628 . . ission Form 10-404 Revised 04/2006 ORIGINAL ~ ~ --0/ ~ Submit Onglnal Only h~ \'b\~ q(t{ð? '0''>(l,- 4 \ 1\ Digital Wellfile . . Page 1 of 2 Well: 02-29A Well Events for SurfaceWell - 02-29A Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> 02 -> 02-29A Date Range: 09/Apr/2007 to 25/May/2007 Data Source(s): AWGRS Events Source AwGRS AwGRS AWGFis Well 02-29C 02-29C 02-29C OS/25/2007 OS/24/2007 OS/23/2007 Description PULL TWC, BOP TEST PULL BPV /RIG MOVED ON T/I/O= 350/300/140 Circ - out, Bullhead IA (Pre RWO) Pumped 5 bbl meth spear and 280 bbls 9.8# NaCl Brine down tubing, thru open pocket (sta 4 @ 6803') taking returns up IA to flowline. Pumped a 3bbl diesel cap on tubing. Pumped 451 bbls of 9.8# NaCl Brine down IA - Bullheading thru a PC leak, followed by 11 bbls diesel freeze protect. Monitored pressures and bled to zero. Freeze protect flowline with 5 bbls meth and 10 bbls diesel. Final WHP= O/vac/vac. AWGRS 02-29C OS/23/2007 ***CONTINUED FROM WSR 5/22/07*** SET 4.5 HOLD OPEN SLEEVE @ 2215' SLM, (15' OAL, 3.83 NOGO, 2.992 ID) BLEED CONTROL LINE DOWN TO 0 PSI. ***LEFT WELL S/I*** AWGRS 02-29C OS/23/2007 T/I/O = O/Vac/O. Temp = S/I. Bleed WHPs to 0 psi, Assist Cameron (PPPOT-T & IC). AL spool dropped, 2" integrals installed on IA and OA casing valves. Circ-Out complete, Cameron on site, pressures do not necessitate a bleed. AWGRS 02-29C OS/23/2007 T/I/O=O/O/O. PPPOT-T (PASS), PPPOT-IC (PASS). Pre-rig. PPPOT-T: Stung into test port with high pressure bleeder tool (0 psi). No off side port to pump through test void. Pressured test void to 5000 psi for 30 min test, lost 100 psi in first 15 min, lost 50 psi in second 15 min (PASS). Functioned all LDS, all moved freely, no sign of bent or broken pins. PPPOT-IC: Stung into test port with high pressure bleeder tool (0 psi). Pressured void to 3500 psi for 30 min test, pressure held. Functioned all LDS, all moved freely, no sign of bent or broken pins. AWGRS 02-29C OS/23/2007 SET BPV /PRE RIG AWGRS 02-29C OS/22/2007 ***CONTINUED FROM WSR 5/21/07*** PULLED HOLD OPEN SLEEVE @ 2215'SLM. SET 3 1/2" SLIP STOP CATCHER @ 6900' SLM PULLED DGLV FROM STA#4 @ 6779' SLM (LEFT POCKET OPEN). PULLED 3.5 SLIP STOP CATCHER @ 6900' SLM ***CONTINUED ON WSR 5/23/07*** AWGRS 02-29C OS/21/2007 ***WELL S/I ON ARRIVAL *** (Pre RWO) RUNNING IN HOLE TO PULL HOLD OPEN SLEEVE IN PROGRESS ***CONTINUE ON WSR 5/22/07*** AWGRS 02-29C OS/21/2007 T/I/O = 750/140/140 Circ-Out (RWO Prep) ***Unable to complete job due to tubing pressuring up*** Pumped 3 bbls of neat methanol into flow line to check flow path. Pumped 27 bbls of neat methanol into tubing at 0.5 BPM and 1500 psi, tried to increase the rate but the tubing would pressure up. No sign of TxIA communication pumping from tubing. RU to IA and pump 6 bbls of neat methanol and 20 bbls of diesel @ 4.5 BPM. Good TxIA communication pumping from IA. RU to tubing and was able to pump only 1 bbl of diesel, tubing pressure increased from 800 psi to 3500 psi. Freeze protect the flow line with 10 bbls of diesel. RDMO Final WHP's = 700/120/120 AWGRS 02-29C OS/20/2007 *** JOB CONTINUED FROM 05-19-07 WSR *** (pre rwo) SET HOLD OPEN SLEEVE IN TRSSSV @ 2216' SLM OAL=15' MIN. ID=2.992" NO-GO=3.830" BLED CONTROL LINE TO 0 PSI *** LEFT WELL SHUT IN *** AWç:,RS 02-29C 05/19/2007 *** WELL SHUT IN ON ARRIVAL *** (rwo / set ho sleeve) DRIFTED TO SSSV W/ 3.845" NO- GO, SD @ 2216' SLM ATTEMPTED TO SET HOLD OPEN SLEEVE, SD @ TUBING HANGER UNABLE TO WORK PAST *** JOB CONTINUED ON 05-20-07 WSR *** AWGRS 02-29C 05/18/2007 *** WELL SI ON ARRIVAL, INITIAL T/I/O = 800/100/150 *** J T CUT 3-1 2" TUBING @ 8610~' USED 2.5" SUPER JET CUTTER W/ 2 GEMCOS ABOVE CUTTER. NO RES RICTIO DID NOT TAG TD. WELL LEFT SHUT IN POST JOB. FINAL T/I/O = 800/100/200 ***JOB COMPLETE*** 8WGRS 02-29C 05/18/2007 T/I/O = 790/110/100. SI. AL spool disconnected,OA with integral. TBG & IA FL (pre-RIG). TBG FL @ Surface, IA FL near surface, OA FL @ Surface. AWGFi..5. 02-29C 05/17/2007 T/I/0=800/100/0 temp=SI MiT OA to 2000 psi (PASSED) (Pre-RWO) First test - MiT OA pressured up to 2000 psi with 4.6 bbls crude. OA lost 60 psi in first 15 minutes and 40 psi in second 15 minutes. For a total of 100 psi in 30 minutes. Second test - MiT OA pressured up to 2000 psi with .2 bbls crude. OA lost 0 psi in first 15 minutes and 0 psi in second 15 minutes. For a total of 0 psi in 30 minutes. Bled pressure down. FWHP's=800/100/0 AWGRS 02-29C 04/17/2007 ***CONTINUED FROM 4-16-07***** FIELD TEST EMIT (ELECTRO-MAGNETIC IMAGING TOOL) & PMIT (PRODUCTION MULTI-FINGER IMAGING TOOL) CASING EVALUATION. LOGGED FROM 8620' TO SURFACE. WELL LEFT SI WITH DSO. GOING TO SEND EMIT DATA FOR PROCESSING. PRE BLEED T/I/O, PPPOT'S, LDS *****J06 COMPLETE***** Date http://digitalwellfile.bpweb.bp .comIW ellEvents/Home/Default.aspx 7/12/2007 Digital Wellfile AWGRS 02-29C 04/16/2007 AWGRS 02-29C 04/16/2007 AWGJZS 02-29C 04/15/2007 AWGRS 02-29C 04/10/2007 . Page 2 of 2 . FIELD TEST EMIT & PMIT CASING EVALUATION. CONTINUED ON 4-17-07 WSR. ****JOB IN PROGRESS**** """JOB CON'T'TNUED FROf'1 15-APRn.-2007**'" LOG EI\1IT, Pfv1IT 1\1ULTI FINGER CALIPER LOG, P¡YllT TOOL CAUSED TELEf'1ETRY FAILURE n.50'¡ UNABLE TO FIX. RD, TO SHOP TO REPAIR TOOL *""'JOB INCOfvlPLETE*'*" ***WELL SHUT-IN ON ARRIVAL *** RIG UP E-LINE EQUIPMENT TO RUN EMIT, PM IT - MULTI FINGER CALIPER LOG. ***JOB CONTINUED ON 16-APRIL-2007*** *** CONT FROM 04-09-7 WSR *** (pre rwo) TAGGED TOP OF SLUGGITS AT 8632'SLM W/2.70" DRIFT. NOTE: 4-1/2" WRP SET BELOW SLUGGITS AT 8644'SLM. *** WELL LEFT SI *** AWGRS 02-29C 04/09/2007 *** WELL SI ON ARRIVAL *** (pre rwo) RAN FLAPPER CHECKER TO 2211' SLM. FUNCTION TEST TRSV, GOOD TEST. NOTE: NO-GO TO FLAPPER ON 4 1/2" AVA TRSV IS 144". TAGGED TOP OF WRP AT 8644'SLM. DUMP BAIL 60# OF SLUGGITS ON WRP. RIH W/2.70" CENT, S.BLR TO TAG TOP OF SLUGGITS. ***CONT JOB ON 04-09-2007 WSR*** http://digitalwellfile.bpweb.bp .com/W ellEvents/Home/Default. aspx 7/1212007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 5/22/2007 21 :00 - 00:00 3.00 RIGD P PRE PJSM. Rig down, lower derrick & layover. Disconnect rig modules & make ready for move. 5/23/2007 00:00 - 06:00 6.00 MOB P PRE PJSM. Move rig from MP F-34 to 02-29, 50 mile move. 06:00 - 00:00 18.00 MOB P PRE PJSM. Continue moving to DS 02. At Milne 1 Spine junction @ 09:30 hrs. At Kuparuk River Bridge @ 16:00 hrs. 5/24/2007 00:00 - 03:00 3.00 MOB P PRE Continue to move rig to Drill Site #2. 03:00 - 06:00 3.00 MOB N WAIT PRE Rig on location, flowline in the process of being removed. Wait on flowline removeall site prep. 06:00 - 15:00 9.00 MOB N WAIT PRE Continue to wait on flow line removal, well prep. 15:00 - 18:00 3.00 RIGU P PRE PJSM. Move on & rig up on 02-29. Raise & scope up derrick, connect rig components. Accepted rig @ 18:00 hrs 5/24/2007. 18:00 - 19:00 1.00 RIGU P PRE Held PJSM. Filled fluid pits with 9.8 ppg brine. 19:00 - 19:30 0.50 WHSUR P DECOMP RU lubricator, pulled BPV, RD lubricator. 19:30 - 21 :30 2.00 KILL P DECOMP Tested choke and kill lines to 3500 psi. Circulated out freeze protect fluid and killed well by pumping down the lA, then down the tubing. Pumped a total of 225 bbls @ 3 bpm. 21 :30 - 22:00 0.50 KILL P DECOMP Monitored well. Tubing and annulus pressures 0 psi. 22:00 - 23:00 1.00 DHB P DECOMP Installed TWC. Tested TWC to 1000 psi from below and to 3500 psi from above. 23:00 - 00:00 1.00 WHSUR P DECOMP RD kill, choke, cement and mud lines. 5/25/2007 00:00 - 02:30 2.50 WHSUR P DECOMP Bled tubing hanger void. ND tree and adapter flange. 02:30 - 06:00 3.50 BOPSU P DECOMP Inspected and confirmed tubing hanger threads. NU BOPE. 06:00 - 13:00 7.00 BOPSU P DECOMP PJSM. Rig up to test BOPE. Test all BOPE components, 250/ 3500 psi, OK. Witnessing of test waived by AOGCC State Rep Bob Noble. Test witnessed by Nabors tool pusher & BP Well Site Leader as well as Nabors driller and roughneck running test pump. Tested kelly and kelly valves, drawdown test on accumulator. No failures. Rig down test equipment, pull two way check valve. 13:00 - 14:30 1.50 PULL P DECOMP PJSM. P/U landing jt, M/U to hanger, BOLDs. 14:30 - 15:30 1.00 PULL P DECOMP PJSM. P/U hanger (2-3'). Bring on pump @ 6 bpm / 400 psi, 29 bbls to fill hole & get returns. Pull hanger to floor, 99K max pull, up weight 92K, no real bobbles or indications of being stuck at all. Break out & UD hanger, rig up Schlumberger spooling unit. 15:30 - 18:00 2.50 PULL P DECOMP PJSM. M/U headpin & circulate well @ 6 bpm 1 400 psi, notice some gas & fluid lightened up a bit wI 425 bbls away. WI 650 bbls pumped, gas is all but gone & getting 9.7 ppg brine back. Shut down & monitor well. 18:00 - 18:30 0.50 PULL P DECOMP Performed pre-tour rig checks. Fluid level stable. 18:30 - 00:00 5.50 PULL P DECOMP POH and LD tubing, spooling control line and chem injection line. Recovered one control line clamp per joint. Recovered 75 jts 4-1/2" tubing, 20 jts 3-1/2" tubing, one SSSV plus accesssories @ 00:00 hrs. Maintaining stable fluid level by overdisplacing with 9.8 ppg brine. Fluid losses approx 5 - 6 bbls/hr. 5/26/2007 00:00 - 06:00 6.00 PULL P DECOMP Continued POH and LD tubing, spooling chem injection line. Recovered one control line clamp per joint. Recovered 159 total jts tubing plus accessories @ 05:00 hrs. Well continuing to take approx 5 - 6 bbls/hr. 06:00 - 06:30 0.50 PULL P DECOMP Service rig, check PVT system, Crown 0 Matic, Derrick inspection, OK. 06:30 - 14:00 7.50 PULL P DECOMP PJSM. Continue to POOH w/3 1/2" completion string & control Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 5/26/2007 06:30 - 14:00 7.50 PULL P DECOMP line & chemical injection line. Recovered 174 jts of 31/2" tbg & cut off jt, 13.80'. Jet cut looked good. Also recovered (8) GLMs, 129 clamps, & (16) stainless steel bands. 46 1/2 clamps & (1) stainless bands left in the hole. 14:00 - 15:30 1.50 PULL P DECOMP Clear I clean rig floor, prep to run reverse circulating junk basket. 15:30 - 17:30 2.00 FISH N DPRB DECOMP PJSM. Pick up reverse circulating BHA (BHA #1). 17:30 - 18:00 0.50 FISH N DPRB DECOMP Performed pre-tour checks. 18:00 - 00:00 6.00 FISH N DPRB DECOMP PU 3-1/2" DP, RIH with RCJB ass'y (BHA #1). 5/27/2007 00:00 - 00:30 0.50 FISH N DPRB DECOMP Continued PU, RIH with BHA #1 on 3-1/2" DP. Tagged fill @ 8413' DPM. 00:30 - 02:00 1.50 FISH N DPRB DECOMP MU kelly. Rotated and washed to 8465'. 02:00 - 03:30 1.50 FISH N DPRB DECOMP CBU to balance well fluid. 03:30 - 05:00 1.50 FISH N DPRB DECOMP Continued rotating and washing to 8560'. 05:00 - 06:30 1.50 FISH N DPRB DECOMP Circulated to clear wellbore of solids, 5 bpm 11900 psi. 06:30 - 07:00 0.50 FISH N DPRB DECOMP PJSM. Check PVTs, derrick inspection, OK. Mix pump 20 bbls weighted dry job. 07:00 - 10:30 3.50 FISH N DPRB DECOMP PJSM. Break off headpin, check Crown 0 Matic, OK. POOH w/3 1/2" DP & RCJB assembly. 10:30 - 13:30 3.00 FISH N DPRB DECOMP PJSM. Stand back drill collars, clean off string magnet, break down RCJB, (shoe was plugged off wI clampage), clean junk subs. Send for new set of fingers for RCJB. M/U RCJB assembly & drill collars, (same configuration as first run). Pulled finger assembly, looked OK, re installed. 13:30 - 16:30 3.00 FISH N DPRB DECOMP PJSM. RIH wI 2nd RCJB run. 16:30 - 17:30 1.00 FISH N DPRB DECOMP PJSM. In hole w/ 88 stands & (2) singles. Kelly up. Establish parameters. Up wt = 139K, down wt = 11 OK. Dry tag 20' in on kelly @ 8575'. Pick up, break off kelly, drop 1" ball, kelly up & bring on pump @ 5 bpm 11000 psi, observe ball go on seat & pump pressure increase to 2400 psi. Slack off, take a little weight @ 8575', wash on down without rotating to 8585'. Pick up, engage rotary table, free spin torque = 3000 ft/lbs. Rotate @ 40 RPM & run down to 31' in on kelly & rotate for 30 minutes, stalling out seversal times w/1 0,000 ft/lbs of torque. Call 'er good. 17:30 - 20:00 2.50 FISH N DPRB DECOMP PJSM. Pump 20 bbls hi vis sweep @ 5 bpm 12375 psi. 20:00 - 00:00 4.00 FISH N DPRB DECOMP Stood back kelly, PU 1 jt. POH with BHA #2. 5/28/2007 00:00 - 02:00 2.00 FISH N DPRB DECOMP Stood back DC. Broke out BHA #2. Recovered approx 50 Ib metal debris from RCJB and boot baskets. MU BHA #3, identical to BHAs 1 and 2. 02:00 - 05:00 3.00 FISH N DPRB DECOMP RIH with BHA #3. 05:00 - 06:00 1.00 FISH N DPRB DECOMP Slipped and cut drill line. 06:00 - 06:30 0.50 FISH N DPRB DECOMP Check PVT system, derrick inspection, crown 0 matic, OK. 06:30 - 07:30 1.00 N DPRB DECOMP PJSM. Continue in hole wI RCJB run #3. Dry tag @ 8588', hard. 07:30 - 09:00 1.50 FISH N DPRB DECOMP PJSM. Pick up kelly wI 88 stands & (2) singles. Drop 1" ball. Establish parameters. 139K up wt, 11 OK down wt. Bring on pump, wI ball on seat pump pressure @ 3150 psi /5 bpm. 3000 ft/lbs or 160 amps off bottom torque. 45 RPM. Wash I rotate down, tag @ 8586'. Wash I mill w/5 - 10K WOB to 8591'. Put up to 15K WOB, no further progress. 09:00 - 12:30 3.50 FISH N DPRB DECOMP PJSM. POOH wI 3 1/2" DP & RCJB run #3. 12:30 - 14:30 2.00 FISH N DPRB DECOMP PJSM. Stand back collars, break down I clean out RCJB, Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/22/2007 6/11/2007 Spud Date: 2/26/1990 End: 6/5/2007 5/28/2007 12:30 - 14:30 2.00 FISH N DPRB DECOMP recovered approximately 30# of clampage. M/U RCJB run #4. 14:30 - 18:00 3.50 FISH N DPRB DECOMP PJSM. RIH w/ RCJB run #4 to 8587'. PU kelly. 18:00 - 20:00 2.00 FISH N DPRB DECOMP PJSM. Dropped 1" ball, established parameters: PU 140k Ib, SO 110k Ib,Rot 125k lb. Tagged @ 8590' DPM. Rotated 45 rpm with 150 amps (3200 Ib-ft), pumping 5 bpm @ 2400 psi. Washed to 8594' DPM, made no further progress. Fin CBU. 20:00 - 23:00 3.00 FISH N DPRB DECOMP Stood back kelly. POH with BHA #4. 23:00 - 00:00 1.00 FISH N DPRB DECOMP Stood back DC. Broke out BHA #4. Cleaned baskets and string magnet of metal debris. No clamps recovered. 5/29/2007 00:00 - 00:30 0.50 FISH N DPRB DECOMP MU BHA #5. 00:30 - 04:30 4.00 FISH N DPRB DECOMP RIH with BHA #5. Dropped ball, PU kelly, lined up to circ. 04:30 - 07:00 2.50 FISH N DPRB DECOMP Pumped ball to seat. Established parameters: PU 140k Ib, SO 110k Ib, Rot 125k Ib, 40 rpm, 150 amps, 5 bpm, 2400 psi. Tagged @ 8594'. Rotated with 15k WOB. 07:00 - 11 :00 4.00 FISH N DPRB DECOMP PJSM. POOH w/ 3 1/2" DP & RCJB run #5. 11 :00 - 11 :30 0.50 FISH N DPRB DECOMP PJSM. Stand back collars, break down I inspect BHA. No debris in RCJB. Groove found up inside RCJB on face of jet sub, 4" OD .. .. could be made by tubing stub jet cut end. Opt to run dress off assembly. 11 :30 - 14:00 2.50 FISH N DPRB DECOMP Wait on tubing dress-off tools to arrive. 14:00 - 15:00 1.00 FISH N DPRB DECOMP PUMU BHA #6 - 8-1/2" Dress-Off Shoe and 4-3/4" Pilot Mill wlWP extensions, boot baskets, Jars, BS and DC's. 15:00 - 18:00 3.00 FISH N DPRB DECOMP RIH w/BHA #6. Held PJSM and crew change, performed pre-tour checks. 18:00 - 19:00 1.00 FISH N DPRB DECOMP Continued RIH with BHA #6. Tagged @ 8591'. LD one jt, MU kelly. 19:00 - 21 :00 2.00 FISH N DPRB DECOMP Established milling parameters: PU 145k Ib, SO 116k Ib, Rot 130k Ib, 45 rpm @ 3000 Ib-ft, 3 bpm @ 500 psi, WOB 5k lb. Made two passes to 8596' while rotating, made one pass to 8596' without rotation. Made DP connection. Continued rotating to 8603' with 45 rpm @ 5000 Ib-ft, 4 bpm @ 900 psi, WOB 8k lb. Made additional pass to 8603' without rotation. 21 :00 - 23:00 2.00 FISH N DPRB DECOMP Circulated 20 bbl Hi-Vis sweep @ 5 bpm. 23:00 - 00:00 1.00 FISH N DPRB DECOMP POH with BHA #6. 5/30/2007 00:00 - 02:30 2.50 FISH N DPRB DECOMP Continued POH with BHA #6. 02:30 - 04:00 1.50 FISH N DPRB DECOMP Stood back DC. Broke out BHA #6. Cleared string magnet and junk baskets. Recovered -2.5 gal metal cuttings. Had clear indication of 3-1/2" OD groove in dress off mill. 04:00 - 06:00 2.00 FISH P DECOMP Pre-Tour safety meeting. Cleared rig floor. MU BHA #7 which includes 9-5/8" casing scraper. 06:00 - 08: 15 2.25 FISH P DECOMP RIH w/BHA #7 to 4650'. 08:15 - 09:15 1.00 FISH P DECOMP Reverse circulate hi-vis sweep surface to surface @ 5.0-BPM @ -800-psi. 09:15 - 11 :45 2.50 FISH P DECOMP POH w/BHA #7. Boot baskets came back clean. 11 :45 - 13:00 1.25 FISH P DECOMP BO/LD BHA #7 and 6 x 6-1/2" Drill Collars. 13:00 - 13:15 0.25 DHB P TIEB1 PJSM - PUMU RTTS packer and RIH. 13:15 - 16:15 3.00 DHB P TIEB1 PUMU Halco 9-5/8" RTTS packer. RIH w/same and set @ 4498'. 16:15 - 17:00 0.75 DHB P TIEB1 PIT 9-5/8" casing from 4498' to surface @ 3500-psi for 30 charted minutes. Good test. Bleed off pressure. 17:00 - 18:00 1.00 DHB P TIEB1 Release 9-5/8" RTTS packer. POH with same. 18:00 - 19:30 1.50 DHB P TIEB1 Held crew change and PJSM. Performed pre-tour checks. Continued POH with 9-5/8" RTTS. Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/22/2007 6/11/2007 Spud Date: 2/26/1990 End: 6/5/2007 5/31/2007 00:00 - 00:30 0.50 BOPSU TIEB1 00:30 - 02:00 1.50 CASE TIEB1 02:00 - 02:30 0.50 CASE TIEB1 02:30 - 03:30 1.00 CASE TIEB1 03:30 - 06:00 2.50 CASE P TIEB1 06:00 - 12:00 6.00 CASE P TIEB1 12:00 - 14:30 2.50 BOPSU P TIEB1 14:30 - 17:00 2.50 BOPSU P TIEB1 17:00 - 18:00 1.00 BOPSU TIEB1 18:00 - 19:00 1.00 CASE P TIEB1 19:00 - 20:00 1.00 CASE P TIEB1 20:00 - 23:00 3.00 CASE P TIEB1 23:00 - 00:00 1.00 CASE P TIEB1 6/1/2007 00:00 - 00:30 0.50 CASE P TIEB1 00:30 - 06:00 5.50 CASE P TIEB1 06:00 - 06:30 0.50 CASE P TIEB1 06:30 - 07:00 0.50 CASE P TIEB1 07:00 - 10:00 3.00 CASE P TIEB1 LD RTTS. Cleared rig floor. Drained stack, installed test plug. Installed 7" casing rams, MU test joint. RU, tested 7" rams 250 psi low /3500 psi high. Pulled and LD test plug. RU to run 7" 26#, L-80 BTC-M liner. PJSM on liner running procedure. PUMU 4-1/2" x 7" tailpipe assembly with Unique overshot. Dumped 2 x 50# bags 20/40 river sand on top of ball seat sub. BakerLok'd all connections. PU and RIH with 7", 26 #/ft, L-80 BTC-M liner. MU connections to mark, using Best-O-Life 2000 dope on connections, filling liner each 5 jts. 24 jts. RIH @ 0600-hrs. 54 jts. RIH @ 0730-hrs. 106 jts. RIH @ 1200-hrs. Make up 3-1/2" x 7" XO BxP to top of casing jt. PUMU 9-5/8" Halco RTTS packer wlstorm valve. Set packer @ 10' below wellhead. PIT packer to 1000-psi. PU and set test plug in tubing spool. Open IA valve and PIT test plug to 3500-psi. Made 24-hr. notification to AOGCC @ 1500-hrs. of impending weekly BOPE test. PJSM - Swap pipe rams. Change pipe rams from 7" fixed rams to 3-1/2" x 6" VBR's. PIT door seals and pipe rams to 3500-psi. Pull and lay down test plug. POH UD RTTS packer and storm valve. PUMU liner hanger and liner top packer. RU head pin, circulated 2 bpm @ 150 psi. RD liner handling equipment. Cleared rig floor. Continued RIH with scab liner assembly on 3-1/2" DP. Tagged 3-1/2" tubing stub @ 8592'. Established parameters: PUW 180k Ib, SOW 125k lb. Set overshot down on tubing stub. Made three unsuccessful attempts to work OS onto stub. PU, carefully rotated string one revolution to left at surface, worked pipe, had 3/4 rotation returned, net 1/4 rev down hole. Engaged tubing stub with OS, sheared pins with 5k Ib indicated, swallowed stub additional 7'. PU and worked OS freely over stub. LD 1 jt. PU pup jt and cementing head with wiper dart loaded. RU to circulate. PU neutral wt plus 2'. Circ 120 deg 9.8 ppg brine to warm well bore. Brine temp in = 100-F, brine temp out = 83-F @ 0600-hrs. PJSM - All crew. Rig up for cement job and high pressure pumping. Hook up SLB cementers to Baker cement head. Prime up pumps, load lines and PIT same to 800-psi Lo, 4500-psi Hi. Verified integrity of seawater supply for displacement to SLB cementers. Pump 130-Bbls. 15.8#/gal. Class "G" cement @ 4-5 BPM @ 300-90 psi. followed by 194-Bbls. of 9.8# brine to displace and bump plug. With 23-Bbls. of displacement away, slowed pump rate to 3.0-BPM to allow DP dart to latch up 7" liner wiper plug. Did not observe any pressure increase when DP dart engaged Printed: 6/1112007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 6/1/2007 07:00 - 10:00 3.00 CASE P TIEB1 wiper plug. At 46.0-Bbls. displacement away, increased rate to 5.0-BPM. With 189.0-Bbls. displacement away, slowed pump rate to 2.6 BPM and bumped plug with 2390-psi at 194-Bbls. displacement. Max. pressure during treatment - 1758-psi. Increased DP pressure to 3030-psi to set liner hanger. Applied 25K# downweight on liner hanger and increased DP pressure to 3859-psi to set liner top packer. Increased DP pressure momentarily to 4500-psi per Baker rep. Bled DP pressure to O-psi. Disconnect cementing line from Baker cement head and blew lines down with air. Set DP in rotary slips and BO/LD cementing head. PUMU TIW valve w/headpin and rig circulating line. Applied 7 rounds of right hand torque to disengage packer setting tool. Picked up DP 6' to disengage setting tool seals from liner top seal bore and start reverse circ. out cement. Reversed out -10-Bbls. diluted cement and continued reversing until returns cleaned up. SID pump BO/LD TIW valve/headpin, 10' DP pup and 1 jt. DP. Rig up floor to POH. 10:00 - 11 :30 1.50 CASE P TIEB1 POH w/DP and liner running tools. 11 :30 - 12:30 1.00 CASE P TIEB1 Clean and clear rig floor. 12:30 - 13:00 0.50 CASE P TIEB1 PJSM - All cew. Picking up BHA and RIH w/DP. 13:00 - 14:30 1.50 CASE N WAIT TIEB1 Wait on 6-1/8" bit to arrive. 14:30 - 15:15 0.75 CASE P TIEB1 PUMU BHA #8 - shoe track cleanout assembly. 15:15 - 16:30 1.25 CASE P TIEB1 RIH w/BHA #8 to 3900'. Cement compressive strength = 350-psi @ 1530-hrs. 16:30 - 19:00 2.50 CASE P TIEB1 PUMU 9-5/8" Halco RTTS packer w/storm valve. Cement compressive strength = 500-psi @ 1630-hrs. Successfully PIT 7" liner/9-5/8" casing to 3500-psi for 30 minutes prior to setting RTTS packer. Set RTTS 10' below wellhead. Tested RTTS to 1000 psi for 10 minutes. 19:00 - 21 :00 2.00 BOPSU P TIEB1 ND BOPE and tubing spool. 21 :00 - 23:30 2.50 WHSUR P TIEB1 Held tour change and PJSM. Performed pre-tour checks. Replaced casing spool packoff and S-seals on casing hanger neck. 23:30 - 00:00 0.50 WHSUR P TIEB1 NU new tubing spool. 6/2/2007 00:00 - 01 :30 1.50 WHSUR P TIEB1 Continued NU new tubing spool. Tested casing hanger flange and packoff seals to 5000 psi for 30 minutes. 01 :30 - 03:00 1.50 BOPSU TIEB1 NU BOPE. 03:00 - 04:30 1.50 BOPSU TIEB1 Held PJSM. Installed test plug, RU test equipment. 04:30 - 12:30 8.00 BOPSU TIEB1 Tested all BOPE components to 250 psi low 13500 psi high per AOGCC and BP requirements. BOPE test witness waived by C. Scheve @ 19:30 hrs, 6/1/2007. 12:30 - 14:00 1.50 BOPSU TIEB1 PJSM - POH w/RTTS packer. POH UD 9-5/8" Halco RTTS packer w/storm valve. 14:00 - 16:00 2.00 DRILL P TIEB1 RIH w/DP to 7" liner top @ 4104". Ease BHA through liner top with no resistance noted and continue RIH to tag cement @ 8401'. PUW = 145K, SOW = 98K. 16:00 - 00:00 8.00 DRILL P TIEB1 Kelly up and establish drilling parameters - PUW = 145K, SOW = 102K, Rot 120K, pump rate = 4-BPM @ 830-PSI, RPM = 60. 10K WOB. Drill out cement to 8548'. 6/3/2007 00:00 - 03:00 3.00 DRILL P TIEB1 Continued rotating at 8548' DPM. Made no further progress. Dynamatic malfunctioning. Troubleshoot and attempt to repair same. Printed: 6/1112007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 6/3/2007 03:00 - 05:00 2.00 DRILL P TIEB1 Circulated 30-bbl Hi-Vis sweep around. Had cement and small amount of metal shavings in returns. 05:00 - 06:00 1.00 DRILL P TIEB1 Stood back kelly. LD 2 singles. POH with drilling ass'y. 06:00 - 06:30 0.50 DRILL P TIEB1 Pre-tour safety meeting and rig maintenance. 06:30 - 09:45 3.25 DRILL P TIEB1 POH w/BHA #8 standing DP in derrick. 09:45 - 12:30 2.75 DRILL P TIEB1 Slip and cut drilling line w/-800' DP and BHA in hole. 12:30 - 13:30 1.00 DRILL P TIEB1 POH w/BHA #8 standing DP in derrick. 13:30 - 14:30 1.00 DRILL P TIEB1 BO/LD BHA #8. PUMU BHA #9. 14:30 - 15:30 1.00 DRILL P TIEB1 Repair Dynamatic 15:30 - 19:00 3.50 DRILL P TIEB1 RIH w/DP from derrick and BHA #9. Performed pre-tour checks @ 18:00 hrs. MU kelly, established circulation. Tagged @ 8546'. 19:00 - 20:00 1.00 DRILL P TIEB1 Established parameters: PU 157k Ib, SO 97k Ib, Rot 123k Ib, 1000 psi @ 4 bpm, 5k Ib-ft @ 48 rpm. Milled cement and ball seat to 8574' DPM. 20:00 - 21 :30 1.50 DRILL P TIEB1 CBU with large amount of cement in returns. 21 :30 - 22:30 1.00 DRILL P TIEB1 Made connection, milled and washed to 8590' DPM. 22:30 - 00:00 1.50 DRILL P TIEB1 Stood back kelly, PU single. RU to circ on bottom. Circ long way one DP volume 4 bpm @ 1100 psi. Lined up to reverse. Rev circ 5 bpm @ 1800 psi. Pump pressure began increasing after about 2 DP volumes pumped. DP packed off while reversing. 6/4/2007 00:00 - 03:00 3.00 DRILL P TIEB1 Pressured up to 3200 psi with no returns. PU, LD 2 jts, pulled mill into 7". Lined up to pump long way. Reciprocated pipe vigorously to dislodge obstruction. Regained circulation the long way 3 bpm @ 1000 psi and 4 bpm @ 1350 psi. Pumped sweep around. Increased long way circ rate to 5-1/2 bpm @ 2050 psi. 03:00 - 08:30 5.50 DRILL P TIEB1 Continued washing down while reversing, to 8579'. Varied circ rate from 3 bpm to 5 bpm. Began packing off, circ pressure increased from 1200 psi to 2600 psi. Had quarter coin-sized pieces of cement, metal, and rubber in returns. LD 2 jts to pull into 7". Alternated pumping long way and reverse. Continued difficulties with cleaning out inside 3-1/2" liner section. 08:30 - 12:15 3.75 DRILL P TIEB1 POH w/BHA #9 standing DP in derrick. 12:15 - 12:45 0.50 DRILL P TIEB1 BO/LD 3-5/8" junk mill and 7" casing scraper. Cleaned out boot baskets. Recovered -1.5 gallons cement and metal cuttings. 12:45 - 13:30 0.75 DRILL P TIEB1 PUMU BHA #10. 13:30 - 16:30 3.00 DRILL P TIEB1 RIH w/BHA #10. 16:30 - 19:30 3.00 DRILL P TIEB1 Hook up circulating hose commence reverse circulating @ 4.0-BPM @ 950-psi and enter top of 4-1/2" liner @ 8554'. Wash down to 8572'. CBU. Make connection. Resume reverse circulating. Washed to 8590', reverse circulated. Observed diminishing amount of cement in returns, until clean. 19:30 - 00:00 4.50 DRILL P TIEB1 POH, laying down 3-1/2" DP and BHA #10 in prep for completion. 6/5/2007 00:00 - 02:00 2.00 DRILL P TIEB1 Continued POH, LD DP and BHA #10. 02:00 - 02:30 0.50 DRILL P TIEB1 Held PJSM. 02:30 - 04:30 2.00 DRILL P TIEB1 LD drill collars and BHA #10. Cleared junk baskets and rig floor. 04:30 - 05:30 1.00 DRILL P TIEB1 Pulled wear bushing. RD DP handling equipment. RU to run completion. Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 6/6/2007 00:00 - 01 :00 1.00 RUNCO RUNCMP 01 :00 - 02:00 1.00 RUNCO RUNCMP 02:00 - 03:00 1.00 RUNCO RUNCMP 03:00 - 05:30 2.50 RUNCO RUNCMP 05:30 - 06:00 0.50 RUNCO RUNCMP 06:00 - 06:30 0.50 RUNCO RUNCMP 06:30 - 09:15 2.75 RUNCO RUNCMP 09:15 - 10:00 0.75 RUNCMP 10:00 - 11 :30 1.50 DFAL RUNCMP 11 :30 - 11 :45 0.25 DFAL RUNCMP 11 :45 - 14:00 2.25 DFAL RUNCMP 14:00 - 18:00 4.00 DFAL RUNCMP 18:00 - 19:30 DFAL RUNCMP 19:30 - 20:30 1.00 DFAL RUNCMP 20:30 - 22:30 2.00 DFAL RUNCMP 22:30 - 00:00 1.50 DFAL RUNCMP 6m2007 00:00 - 01 :00 1.00 DFAL RUNCMP Pre-tour safety meeting wldaylight crew. Run 3 1/2" 9.2#, 13Cr80/4-1/2" 12.6# 13Cr80 Vam Top Tubing, compensating and torque turning each connection to 2900/4440 Nibs. respectively, using Jet Lube Seal Guard thread compound, running GLMs and other jewelry at depths specified in program. Hole stable and not losing any fluid to formation. 80 jts. 3-1/2" RIH @ 1400-hrs. 235 jts in @ 2400 hrs. UD jt # 227 & replaced wI jt# 253. (Bad pin) Con't to RIH w/3 1/2" & 41/2" 13Cr Vam Top completion. torque turn all connections, 3 1/2" wI 2900 ft-Ibs & 4 1/2" wI 4440 ft-Ibs. used Jet Lube Seal Guard. Ran 242 jts. P/U jt # 251 & tagged up @ 29' in. P/U 2' & perform space out. UD jt # 251. P/U & M/U landing jt into hanger. Land completion. RILDS. P/U Wt = 92K, S/O Wt = 70K. R/U lines & reverse circulate 140 bbls of 120 degree seawater down annulus. Follow wI 290 bbls of 120 degree inhibited seawater. Pumped 3 BPM @ 400 psi. Bleed off DP pressure. Open blind rams. PU jt. of 3-1/2" DP and stab intyo top of tubing hanger. Drop balllrod & allow to fall. LD jt. of 3-1/2" DP. Rig up lines and sensators to set and test packer, IA and tubing. Close blind rams and pressure up tubing to 3500-psi with IA open to atmosphere. Tubing leaking off and fluid flowing a trickle from IA. Tubing pressure bled off 315-psi in 17 minutes. Inspected all fittings and connections on surface and found no visible leaks. Bled off pressure and re-pressured tubing to 3640-psi and pressure bled off 1400-psi in 30-minutes. Bled tubing to 1500-psi and pressured up IA to 3592-psi. Pressure bled off in IA to 3059-pdi in 30-minutes and tubing pressure increased to 2200-psi. Bled off IA pressure to 2200-psi and opened manifold to pressure up both IA and tubing together to 3651-psi. Pressure tested good w/50-psi bleed off over 30-minutes. Bled off tubing and IA to O-psi. Collaborated wltown engineer Dave Reem for plan forward. PU 7" lubricator extension, set in hole and close annular preventer around lubricator extension. Close blind rams. Waiting on slickline unit to arrive on DS. PJSM - All crew. Rigging up slickline. Rig up slickline with line wiper to top of 7" lubricator extension. Open blind rams and RIH to set 3-1/2" slip stop wlcatcher sub @ 3510' WLM. POH, change tool string and RIH w/dummy valve and set same. POH wltool string. Pressure up on tubing & attempt to test. Pressure leaked off 575 psi in 30 min. Re-pressured & leaked off 350 psi in 15 min. Tested IA & Tbg together, pressure held @ 3500 psi. RIH wI W/L & pulled catcher sub. Re-pin catcher sub & re-spot S/L unit. RIH & set Catcher sub @ 6381' SLD. POOH. RIH & pull Dummy valve in Lower GLM @ 6217' SLD. POOH. RIH & set Dummy in GLM @ 6217' SLD. POOH. Printed: 6/11/2007 11: 19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 Pressure up on tubing & attempt to test to 3500 psi. Pressure bled off 300 psi in 15 min. Re-pressure & lost 300 psi in 15 min. Notify engineer of results. Plan to Pull balllrod & RHC sleeve. 02:00 - 03:00 1.00 DFAL RUNCMP RIH & pull catcher sub. POOH. 03:00 - 04:00 1.00 DFAL RUNCMP RIH & pull rod / ball. POOH. 04:00 - 06:00 2.00 DFAL RUNCMP RIH & pull RHC sleeve. 06:00 - 08:30 2.50 DFAL RUNCMP RIH wl"XX" plug and set in "X" nipple @ 8534' WLM to isolate tubing for PIT. 08:30 - 09:30 1.00 DFAL RUNCMP PIT tubing to 3650-psi. Leaked off to 3050-psi in 15 minutes and measured leak rate @ 7.5-gallons per hour. 09:30 - 10:00 0.50 DFAL RUNCMP Collaborate with RWO engineer to formulate plan forward. 10:00 - 11 :00 1.00 DFAL RUNCMP Dry rod set TWC in tubing hanger. PIT TWC and hanger seals to 41 OO-psi. Good test. PUMU lubricator, pull TWC and lay down lubricator. 11 :00 - 12:30 1.50 DFAL RUNCMP Nipple down flow nipple and flange up shooting flange to top of annular preventer. 12:30 - 14:00 1.50 DFAL RUNCMP PUMU wireline riser and makeup to top of shooting flange. PU wireline stuffing box and Techwelllogging tools. PIT wireline stuffing box to 3500-psi. Rigged up test pump to BOPE test spool. 14:00 - 15:30 DFAL RUNCMP RIH wlTechwelllogging tool string and tag top of "XX" plug @ 8534' WLM. Pressure up tubing to 3500-psi and o-ring in wireline stuffing box assembly started leaking. 15:30 - 16:30 1.00 DFAL RUNCMP POH wllogging tools to replace leaking o-ring. Replaced leaking o-ring and PIT wireline stuffing box to 3000-psi. 16:30 - 18:00 1.50 DFAL RUNCMP RIH wlTechwell sonic logging tools and tag "XX" plug @ 8534' WLM. 18:00 - 23:30 5.50 DFAL RUNCMP Run Techwell Leak Detection Log from 8481 to surface. Held 3500 psi on tubing while logging. Located leak in tubing @ 5062 WLD. (Jt # 108). 23:30 - 00:00 0.50 DFAL RUNCMP RIH wI slickline toll to pull equalizing prong. 6/8/2007 00:00 - 00:30 0.50 DFAL RUNCMP Pull Equalizing prong. POOH. 00:30 - 02:00 1.50 DFAL RUNCMP RIH & pull "XX" plug. POOH. 02:00 - 03:00 1.00 DFAL RUNCMP RID Slickline equip. 03:00 - 06:30 3.50 DFAL RUNCMP Spot in E-line truck & RlU to cut tubing. 06:30 - 07:00 0.50 DFAL RUNCMP PJSM - All crew: Chemical cut tubing. 07:00 - 08:30 1.50 DFAL RUNCMP Rig up E-line equipment with chemical cutter tool string. 08:30 - 11 :00 2.50 DFAL RUNCMP RIH w/chemical cutter and log completion jewelry to locate cutter head @ 8456' ELM. Detonate cutter @ 8456'. POH wltool string. Close blind rams. 11 :00 - 12:00 1.00 DFAL RUNCMP Clear rig floor of all rig personnel. SWS personnel BO/LD chemical cutter tool string. 12:00 - 12:30 0.50 DFAL RUNCMP Pumped 10-Bbls. @ 3.0-BPM @ 250-psi down tubing taking returns from IA to rig pits to gain clear indication of free communication between tubing and IA. 12:30 - 13:00 0.50 DFAL RUNCMP Finish rigging down SWS E-line eqpt. RDMO SWS. 13:00 - 14:00 1.00 DFAL RUNCMP ND shooting flange. NU flow riser. 14:00 - 14:30 0.50 N DFAL DECOMP PUMU 3-1/2" DP landing jt. and screw into tubing hanger. BOLDS. Unland tubing hanger and hoist to rig floor. PUW = 92K. 14:30 - 16:30 2.00 PULL N DFAL DECOMP Rig up compensator, double stack hydraulic tongs and 4-1/2" elevators and prepare to POH w/completion. Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 POH w/4-1/2" x 3-1/2" completion laying pipe down through piep shed 1 x1. Unique Machine inspector cleaning and inspecting every connection in pipe shed. Pulled & UD 15 jts. Crew change. Check PVT alarms & inspect derrick. Con't to POOH & UD 41/2" x 31/2" completion. UD 70 jts of 4 1/2" tubing. Replaced 2jts, galled pin & box. Change out handling tools for 3 1/2" tubing. Con't to POOH & UD completion. Pulled & UD 30 jts 3 1/2" tubing. Con't to POOH & UD 3 1/2" tubing to Jt # 108. ¿ Jt # 108 not made up properly. Had threads exposed. RlU cutting tools. Cut off bottom 4' of pin end of jt #108 & cut off top 4' of box end of Jt #107. Set aside for inspection. See photos. Notified AOGCC - Jeff Jones - of weekly BOPE test. Con't to POOH & UD 3 1/2" tubing. Recovered 70 jts. of 4-1/2" 12.6# 13CR-80 Tubing and 172 jts. of 3-1/2" 9.2#, 13CR-80 Tubing 1 x 10' 3-1/2" 9.2#, 13CR-80 Tubing Pup, 1 x 3-1/2" Halco 9Cr "X" Nipple and 1 x cut 3-1/2" 9.2#, 13CR-80 Tubing Pup. Cut Tubing Pup is 5.53' long, leaving a 4.20' 3-1/2" stub. DFAL DECOMP PUMU test jts. and prepare for weekly BOPE test. Test BOPE per AOGCC/BP requirements: 250-psi Lo, 3500-psi Hi. AOGCC - John Crisp witnessed BOPE test. Air over hydraulic pump on Koomey failed. Electric over hydraulic pump on Koomey fully operational. Permission granted by John Crisp to run completion while repairing Koomey unit. DFAL RUNCMP Rig up floor with torque turn and air compensator equipment. DFAL RUNCMP PJSM - All crew: Running chrome tubing. DFAL RUNCMP PUMU Unique Machine OIS, HES "X" Nipple assy., Baker S-3 7" x 4-1/2" packer, HES "X" nipple assy. and RIH on 3-1/2" Tubing. Torque turning all connections to 2900-Wlbs. optimum torque and using compensator and single joint elevators to pick up Tubing. Crew change. Check PVT alarms. Inspect derrick. Con't to RIH. Had bad 10' 3 1/2" pup from below X Nipple. UD same. W/O new pup, M/U & con't to RIH wi completion. Con't to RIH w/ completion. Torque turn all connections to 2900 ft-Ibs. Used Jet Lube Seal Guard thread compound. RIH wI 75 jts. Con't to RIH wi new completion. Torque turn all connections to 2900 ft-Ibs. Used Jet Lube Seal Guard thread compound. Had 1 bad jt, # 116, Replaced & Con't in hole. Ran 169 jts of 3 1/2" 9.2#, 13 Cr80 Vam Top tubing. DFAL RUNCMP M/U 3 1/2" x 41/2" X-over. Con't to RIH w/4 1/2" 12.6#, 13Cr80, Vam Top tubing. Torque turn all connections to 4440 ft-Ibs. used Jet Lube Seal Guard thread compound. Jt. #206 makeup rejected due to galling. Replaced with new jt. of same length. Also replaced collar on mill end of jt. #205. Jt. #240 makeup rejected due to galling. Replaced wlnew jt. of same length. Establish spaceout parameters - PUW = 89K, SOW = 70K. DFAL RUNCMP PUMU spaceout jt. and tag top of 3-1/2" stub @ 8460.20'. Swallow stub and tag shear pins @ 8461.90' w/10K downweight. Tag top of tubing collar on bottom of tubing stub 6/8/2007 16:30 - 18:00 1.50 PULL N DFAL DECOMP 18:00 - 18:30 0.50 PULL N DFAL DECOMP 18:30 - 21 :00 2.50 PULL N DFAL DECOMP 21 :00 - 21 :30 0.50 PULL N DFAL DECOMP 21 :30 - 00:00 2.50 PULL N DFAL DECOMP 6/9/2007 00:00 - 01 :30 1.50 PULL N DFAL DECOMP 01 :30 - 02:00 0.50 PULL N DFAL DECOMP 01 :30 - 08:30 7.00 PULL N DFAL DECOMP 08:30 - 14:30 6.00 BOPSU N 14:30 - 16:00 16:00 - 16:30 16:30 - 18:00 1.50 0.50 1.50 18:00 - 18:30 0.50 RUNCO DFAL RUNCMP 18:30 - 20:00 1.50 RUNCO DFAL RUNCMP 20:00 - 00:00 4.00 DFAL RUNCMP 6/10/2007 00:00 - 05:00 DFAL RUNCMP 05:00 - 12:30 7.50 RUNCO 12:30 - 14:00 1.50 RUNCO Printed: 6/11/2007 11:19:01 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/22/2007 Rig Release: 6/11/2007 Rig Number: Spud Date: 2/26/1990 End: 6/5/2007 14:00 - 16:00 2.00 WHSUR N @ 8464.70' wino-go on bottom of Unique O/S. Picked up to neutral weight plus additional 2' to spaceout for landing tubing hanger. Calculated spaceout length wlBaker Packer serviceman. Layed down spaceout it. and it. #240 and it. #239. Replaced it. #239 with shorter it. RIH wlnew it. #239, 3.84' pup and it. #240. PUMU 3-1/2" DP landing it. w/TIW valve & headpin and circulating hose madeup to tubing hanger per Cameron wellhead tech. Circulate @ 3.0-BPM @ 130-psi while easing down to top of tubing stub. Pressure increased to 150-psi when Unique O/S started swallowing stub. Landed tubing hanger an additional 1.5' in hole after pressure increase noted indicating 1.5' of swallow with overshot. DFAL RUNCMP POH UD 3-1/2" DP landing it. Pump out BOP stack. Cameron wellhead technician remove one lockdown screw and observe tubing hanger landed correctly in tubing spool. RILDS. Close blind rams. Rig down torque turn equipment and tubing handling tools. Reverse circulate 140-Bbls. 140F seawater and 290-Bbls. 140F seawater w/EC1124A corrosion inhibitor @ 3.0-BPM @ 320-psi. taking returns to rig pits. Crew Change. Check PVT alarms. Inspect derrick. Con't to displace well. Drain Stack. P/U landing it & align wI hanger. Drop Rod/Bal1. Allow to fall. UD landing jt. Pressure up on tubing to 3500 psi & set S-3 Packer. Hold pressure for 30 min & test tubing string. Test good. Bled off tbg pressure to 1500 psi & SI. Pressure up on Tubing annulus to 3500 psi & test for 30 min. Tested Good. Bleed off tubing pressure to 750 psi & DCR-SV sheared & Tbg/ Ann equalized. Pumped thru tubing 3 BPM 300 psi & pump thru annulus 3 BPM @ 260 psi. Charted entire testing operation. P/U T-bar & install TWC in hanger. Pressure up & test from above wI 3500 psi, Ok. Pressure up from below TWC & test to 1000 psi for 10 min. Tested Ok. Charted same. Hold PJSM. Drain stack. NID BOPE. N/U adapter flange & tree. Con't to N/U tree. Pressure test tubing hanger void to 5000 psi, Ok. fill tree & pressure test to 5000 psi, Ok. P/U lubricator & pull TWC. UD lubricator & TWC. Hold PJSM wi All hands. R/U Hot Oilers. Pressure test lines to 3500 psi. Pump 140 bbls of diesel down annulus to freeze protect well. Pump 2 BPM @ 350 psi. R/U lines & allow Tbg I Ann to U-tube diesel freeze protect. P/U T-bar & set BPV. Pressure test BPV from bottom to 1000 psi for 10 min. Test Ok. charted same. Secure well & cellar. RELEASE RIG @ 0600 hrs. 16:00 - 18:00 2.00 RUNCO DFAL RUNCMP 18:00 - 18:30 0.50 RUNCO DFAL RUNCMP 18:30 - 19:00 0.50 RUNCO DFAL RUNCMP 19:00 - 20:30 1.50 RUNCO RUNCMP 20:30 - 21 :00 RUNCMP 21 :00 - 23:00 2.00 BOPSU P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP 6/11/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP 00:30 - 01 :30 1.00 WHSUR P RUNCMP 01 :30 - 02:00 0.50 WHSUR P RUNCMP 02:00 - 03:30 1.50 WHSUR P RUNCMP 03:30 - 04:30 1.00 WHSUR P RUNCMP 04:30 - 05:00 0.50 WHSUR P RUNCMP 05:00 - 06:00 1.00 WHSUR P RUNCMP 06:00 - 0.00 WHSUR P RUNCMP Printed: 6/11/2007 11:19:01 AM TREE = OlIN GEN 4 CWIJ 13-3/S"CSG,68#,K-55, tD=012.41S"H 104' 14-1/2" TBG, 12,6#, 13Cr. VAM TOP, ID =3,958" H 3012' 3923' Baker ZXP PKR wI 02 Profile I 4097' 7" SCAB LNR 26#, l-80, STCM tD = 6.276'1 I 8592' Minimum ID = 1.92" @ 8693' TOP OF 2-3/8" LINER ~8G, 9.3#, L-80, ,0067 bpf, ID'" 2.992" I -4100' PERFORA TION SUI\IINlð. RY REF lOG: SWS MCNL / GR 1 CCl ON 05/0.3/04 ANGLE A T TOP PERF: 90.· @ 9910.' Production DS fOf IN1'ERVA L Opn/Sqz 9910. - 1000.0 0 10670.-1110.0. 0 10760. - 10880 0 11140.-11210. 0 SIZE 1.56" SPF 6 6 6 6 08/09/05 0.5/03/04 0.7/04/0.5 07/04/05 1.56" 9791' 10486' 02-29C SA~T£:S: 06/22/03 - 9-618- CSG LEAK LOl. 01i3~A DWNSQZ. 02.29B NOT SHOWN (P & A). 02/15/06 IBP RUBBER LEFT IN HOLE - Q83TH UNKNOWN 4 112" HES X NIP, ID=3.813" GAS LIFT MANDRELS TYPE VLV LATCH IV'iI'v1G DOME RK IV'iI'v1G SO RK DATE 0.6/26/0.7 3 1/2" HES X NIP, ID= 2.813" SKR 7" )( 4 112" S3 PERM PKR, ID = 3.88" 8719' H ELMD TT lOGGED 0.4/26190.1 I MlLLOUTWlNOOW 9251' - 9255' REV BY COIV'il'v1ENTS JOMlPA G RKED VLV LATOH BROKE OFF M H Nabors 4ESRWO PRUDHOE BAY UNff WELL: 0.2-290 PERMIT No: "2040510 API No: 50-0.29-220.11-0.3 T11 N, 161.22' FEL .& 5259' BP Exploration {Alaska) ell Job# Loa Description Date BL Color CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 1 L3-30 11637115 PRODUCTION PROFILE 03/19/07 1 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 I ~ ~... 11686732 PRODUCTION PROFILE 04/08/07 1 L,...:J"" 02-29C N/A EMIT & CALIPER IMAGE 04/17/07 1 DS 02-36 11637141 MULTI-FINGER CALIPE 03/14/07 1 F-16A N/A SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20/07 1 A-30A 11628762 MEM CBL 03/13/07 1 03-36A 11637326 USIT (CORROSION) 04/12/07 1 03-36A 11637326 USIT (CEMENT) 04/12/07 1 DS 17-05 11594492 USIT 04/24/07 1 DS 03-01 11630462 USIT 03/11/07 1 Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth W 05/15/07 NO. 4024 9c"K/- 05- ( Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. SCANNED MAY 1 7 2007 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth --- t1/\'{ 1 6 zu07 Received by: \~ . . WELL LOG TRANSMITTAL RECEIVED ¡¡\lie 9 ¿UOt) !\Jaska Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5] 6) 7) D.S. 02 - 29C 21..Jul-06 Leak Detect - WLD --,,-.- . b'CANNED AUG 3 0 2.006 (\ oL C LI c'i~ -h jA Q,. (.]A 0. LLI A h 'þ'1,/\. Signed: Print Name: Date: -'8./ (yJt. / O~ t I PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-18952 E-MAIL: PDSANCHORAGE(!ì>MEMORYLOG.COM £)(:::/-1- os- f .,t 140"&"6 WEBSITE: WWW.MEMORYLOG.COM 0:\00 ]OSANC-2006\Z _ W ord\Dis1ribution\TnmsmittaJ_ Sheets\Tnmsmit_ Original.doc t1J~ ~c.o DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040510 Well Name/No. PRUDHOE BAY UNIT 02-29C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22011-03-00 MD 11411 TVD 8856 Completion Date 5/4/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ ~ DATA INFORMATION Types Electric or Other Logs Run: MWD / GR / ROP / TVDSS, MGR / CCL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D Asc Directional Survey 6/9/2004 IIFR PB1 ~ Directional Survey 6/9/2004 IIFR PB1 ~D Asc Directional Survey 0 0 6/9/2004 IIFR Directional Survey 0 0 6/9/2004 IIFR .>P C Tf ~731 Neutron 8568 11374 Case 9/22/2004 COMPENSATED NEUTRON LOG/MEMORY ~731 GRlCCUCNL 4 D Tf Neutron Blu 8568 11374 Case 9/22/2004 COMPENSATED NEUTRON LOG/MEMORY GRlCCUCNL ~D ~768 Gamma Ray 9011 11378 9/14/2004 GRlROP pt 12768 LIS Verification 9011 11378 9/14/2004 GRlROP ~~ V11772 Gamma Ray 9011 1 0844 9/14/2004 GRlROP, PB1 . 12772 LIS Verification 9011 1 0844 9/14/2004 GRlROP, PB1 ~ ~mple 5 Blu 8750 9235 12/23/2004 DOWNHOLE SAMPLE LOG/PBMS-A, PGMC-A, OILPHASE SAMPLE TOOL .~C Lis /1'3600 Gamma Ray 9175 11411 Open 2/22/2006 ROP NGP plus Graphics / PB 1 9075-10872 ROP NGP plus Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040510 Well Name/No. PRUDHOE BAY UNIT 02-29C Operator BP EXPLORATION (ALASKA) INC MD 11411 Completion Date 5/4/2004 Current Status 1-01L Completion Status 1-01L TVD 8856 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ I IIJ Daily History Received? 0N ThIN Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: API No. 50-029-22011-03-00 UIC N ~~~ ~ ~ . . Well 02-29C (PTD 2040510) Reclassified from Waiver to Trouble . e . #t~ ~\~\D~ Hello all. Well 02-29C (PTD 2040510) has been reclassified from Waiver to Trouble. It has a production casing leak. During waiver compliance testing, the MIT-T failed against a L TTP with a leak rate of 0.6 GPM @ 2500 psi. Lead Operator: would you please ask the OS Operator to remove any waiver related signage? The PE is evaluating setting another TTP, repeating the MIT-T and conducting an LDL if necessary. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com 1 of! 3/8/2006 1 :52 PM . . WELL LOG TRANSMITTAL ~ 04 - 051 I 3I.ÞOO February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-29C + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-29C + PBl: LAS Data & Digital Log hnages: 50-029-22011-03, 70 1 CD Rom ~-º-~(ì :11 ~ :;!DLP . STATE OF ALASKA Al,A Oil AND GAS CONSERVATION COM.ION . . REPORT OF SUNDRY WELL OPERATIONS AUG 1 8 2005 .t~18 I'"~ , N D Stimulate D ." .;'> ,;¡¡; (jft1~ GJs D WaiverD Time Extensio'lGJt~,\ [2] Re-enter Suspended Weil 'OJi(,¡¡;;ge 5. Permit to Drill Number: 204-0510 o 6. API Number: 50-029-22011-03-00 9. Well Name and Number: J 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (fI): 3. Address: 63 KB 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Total Depth measured 11411 true vertical 8856.3 Effective Depth measured 11380 true vertical 8852.75 Casing Conductor Surface Production Liner Liner Length 81 3893 8970 568 2724 Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# L-80 7" 29# L-80 2-3/8" 4.6# L-80 Perforation depth: Measured depth: 9910 - 10000 True Vertical depth: 8921.02 - 8910.5 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 2740 2769 x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 24753 99 0 26052 93 0 15. Well Class after proposed work: ExpIaatay ce.elcp I at PJ 16. Well Status after proposed work: 01 PJ <?as 0 VVA.G Plug Perforations Perforate New Pool Perforate 4. Current Well Class: C5e1cprert PJ Stlëll:igcØic 0 feet feet feet feet MD 31 - 112 30 - 3923 29 - 8999 8683 - 9251 8687 - 11411 10670 - 11100 8873.3 - 8849 4-1/2" 12.6# 3-1/2" 9.3# 9-5/8" DV Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal P'oled N,me Sh"~a;", Voslel '. J Signa~ß' ~ Form 10-404 Revised 04/2004 ExpIaatay Sa\Åce 02-29C 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) None 8661 TVD 31 - 112 30 - 3703.49 29 - 8303.28 7992.73 - 8549.93 7996.6 - 8856.3 Collapse 470 2270 4760 7020 11780 Burst 1490 4930 6870 8160 11200 11140 -11210 8848.48 - 8849.03 L-80 L-80 29 - 3011 3011 - 8740 8636 RBDMS BFL AUG 1 9 2005 Tubing pressure 210 235 Sa\Åce o GlI\U WI\U w::EPL ISundry Number or N/A if C.O. Exempt: LN/A Title Data Mgmt Engr O D." . P~cyre.16N4f, 27\ L "~\' I lJ ! . \1 " i I Date 8/16/2005 Submit Original Only Jo . 02-29C . DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/1/2005 Mem 10g/Adperf. CTU #9 wi 1.5" CT. MIRU. Perform weekly BOP test. MU and RIH with PDS CCL/GR logging tools. Bull head 2% X-SLK wi lubtex into liner ahead of coil. Formation tight. Establish injectivity of only .14bpm at 987 psi WHP. Attempt to RIH to 11,250'. Set down at 10,975' ctm. ***Continued on 7/2/05 WSR*** 7/2/2005 Mem 10g/Adperf. CTU #9 wi 1.5" CT. ***Continued from 7/1/05 WSR*** Set down on obstruction with PDS GR/CCL logging tools at 10974' ctm. Sat down at same spot several times. Log interval 10960' to 10350'. Flag pipe at 10850'. POOH. Good data. Tie into SWS MEM GR/CCL/CNL Dated 5-3-2004. Make -4' depth correction. MU and RIH with 4 - 25' x 1.56" HSD 1606-PJ 6spf TCP guns. Shoot interval 1 0780' to 10,880'. Injectivity after perforating was 1 bpm at 1870 psi WHP. ***Continued on 7/3/05 WSR*** 7/3/2005 Milll Adperf. CTU #9 wi 1.5" CT. ***Continued from 7/2/05 WSR*** POOH after 4th gun run. All shots fired. Cut 300' pipe off. Weld on connector. MU and RIH with jars, motor and 1.8" 00 tapered mill. Tag at 10972' ctm. Mill to 11260' with 1 % KCL/Lub T ex no obstructions - no motor work - Dry run to clean out depth 11260' with no problem. POH. MU/RIH with PDS GR/CCL tool to 11243' ctm. Log interval 11243' to 11100'. Flag at 11100'. Good data tie into same log. Make -4' correction. MU and RIH gun # 5. Correct at flag and shoot interval 11185' - 11210'. ***Continued on 7/4/05 WSR*** 7/4/2005 Adperf/N2 Lift. CTU #9 wi 1.5" CT. ***Continued from 7/3/05 WSR*** MU and RIH gun # 6. Correct at flag and shoot interval 11,160' - 11,185' MU and RIH gun # 7. Correct at flag and shoot interval 11,140' - 11,160' POH with gun # 7 - all shots fired- MU JSN BHA. Service tree valves. RU N2 pumpers- RIH start lifting at 1500' - work down to 8000' md - recovered 385 bbls in - 12 hrs. Returns are foamy emulsified crude. Needs gas assist to flow. Continue to lift. ***Continued on 7/5/05 WSR*** 8/8/2005 MIRU CTU #5. MU MHA wi PDS memory logging tools. RIH. Log from 10,200' to 9,400'. Paint flag at 10,030.3'. POOH. Correct flag to MCNL log dated 5/3/04 (-3.5' correction to log). RIH wi gun #1: 30' x 1.56" PJ, 6 SPF, 60 Phase. Correct to top shot depth and perforate 9970-10000'. POOH. **** Job in progress.*** 8/9/2005 ***** Job continued from 8/8/05 WSR:***** At surface wi gun #1 (all shots fired). RIH wi gun #2: 30' x 1.56",PJ, 6 SPF, 60 Phase. Perforate 9940-9970' (NOTE: between 9970'-9960' only 14 of 61 shots fired across the 10' interval, average 1 shot 1ft). RIH wi gun #3: 30' x 1.56",PJ, 6 SPF, 60 Phase. Perforate 9910' - 9940' (all shots fired). POOH. MU BHA wi 2" BON. RIH. Start N2 lift operations. Work down and lift from 8200'. Flowback -400 bbls (four tubing volumes) with last sample being 100% oil. Flowback stable to surface tanks at 180 psi, 59 deg, 960 BPD rate. Leave well flowing to facility, routed around separator for lowest common line pressure possible (170 psi). *** Job complete*** FLUIDS PUMPED BBLS 5 Diesel 10 Methanol 352 2% KCL 246 2% X-SLK wi 2% Lubtex 12.4 TOTAL Schlumberger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~/. ~ -¡- L5-05 'a~A5'Y L3-02 ,¡¡ 'L3-02 Nf;(j.l\- L5-05 ~~IØ- DS 06-23B )P v- ;'ð 02-06A \'\~. '(tj.¡:t Z-39 rf>'JPv W-17 '). ....~02-29C ~~~ X-04 'P'r" .elf. W-31 \;;~~ Well . Job# 10662986 10679068 10900108 10674383 10715411 10621750 10900123 10889187 10889185 10919925 10877807 12/20/04 NO. 3287 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 01/28/04 1 1 1~7'D"'1 04/03/04 1 1 I~G-:JJ 10/29/04 1 1 I gr., -IS' 10/05/03 1 1 f '87-()(ðj 06/15/04 1 1 20'(. fR7 12/01/03 1 19'~/3í' 11/27/04 1 2 t9() - Ze'i! 11/08/04 1 I 'il8'-ø?r 11/07/04 1 2.oI/-Þ51 12/15/04 1 17 <¡-19ft 't 12/15/04 1 ,,'jf:?/:)"cf RST -SIGMA RST -SIGMA RST -SIGMA RST -SIGMA MCNL SCMT PROD PROF W/DEFT TEMPERATURE PROFILE DOWN HOLE SAMPLE LOG PROD PROF W/DEFT PROD PROF W/DEFT/GHOST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage 99503-2 ATTN· eth ~vþ~ . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin DCll.!Jðh 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs 02-29C PB 1, 1 LDWG fonnatted Disc with verification listing. A I Â 11)....... API#: 50-029-22011-70 11 . :<0 f -06- J September 13, 2004 AK-MW-3030695 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: /f-}rI BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~ RECEIVED SEP .\ '/2004 J.\J8sKa Oil & GaaCoJ}$.Commilsion Anó\t~ß . À.tJf-tJ5i . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: itob~u Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Septernber13,2004 RE: MWD Formation Evaluation Logs 02-29C, AK-MW-3030695 1 LDWG formatted Disc with verification listing. ~ API#: 50-029-22011-03 ::[1 ),.11. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Ia/-ff ~r! RECEIVED SEP "ì ... 2DOLJ i11éJSKa Oil & Gas Cons. Camm_ AnoooJage ALASKAtL AND ~~~T~g~S~L:~~ON COMJSION RE WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD I GR / ROP / TVDSS, MGR / CCL / CNL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE BoTTOM Top SIZE Surface 112' Surface 112' 30" Surface 3923' Surface 3704' 17-1/2" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 887' SNL, 1740' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 89' NSL, 4808' EWL, SEC. 25, T11 N, R14E, UM Total Depth: 1782' NSL, 4697' EWL, SEC. 25, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688489 y- 5950336 Zone- ASP4 TPI: x- 691531 y- 5951389 Zone- ASP4 Total Depth: x- 691377 y- 5953079 Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. WT. 91.5# 68# H-40 L-80 20" 13-3/8" 9-5/8" 47# L-80 Surface 9099' 7" 29# L-80 8683' 9251' 2-3/8" 4.6# L-80 8682' 11411' 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 1.56" Gun Diameter, 6 spf MD TVD MD TVD 10670' - 11100' 8873' - 8849' 26. Date First Production: May 8, 2004 Date of Test Hours Tested PRODUCTION FOR 5/11/2004 4.1 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 322 250 24-HoUR RATE OIL-BsL 2,752 One Other 5. Date Camp., Susp., or Aband. 5/4/2004 6. Date Spudded 4/20/2004 7. Date TD. Reached 4/30/2004 8. KB Elevation (ft): 63' 9. Plug Back Depth (MD+ TVD) 11380 + 8853 10. Total Depth (MD+TVD) 11411 + 8856 11. Depth where SSSV set 2239' MD 19. Water depth, if offshore NIA MSL Surface 7993' 7992' 24. 8401' 12-1/4" 8550' 8-1/2" 8856' 3" ~....) ~ JUN 08'2.004 iI'"""... ~.~: b-~ SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.3#, L-80 t\.laska 1b. Well IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-051 13. API Number 50-029-22011-03-00 14. Well Name and Number: 02-29C 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028308 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 2150# Poleset 2000 sx CS III, 600 sx Class 'G' Top Job: 250 sx CS II 450 sx Class 'G' 250 sx Class 'G' 77 sx Class 'G' DEPTH SET (MD) 3011' 3011' - 8740' PACKER SET (MD) 8636' 25. ORIGINAL CONTINUED ON REVERSE SIDE DEPTH INTERVAL (MD) 2000' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH GAs-McF 4,109 GAs-McF 24,050 W A TER-BsL 16 WATER-BsL 93 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL 470 CHOKE SIZE I GAS-OIL RATIO 85 8740 OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r .~rë¡t:j'i¡:. .! 5/"'¡~fl : V I>;IED I Form 10-407 Révišed"12/2003 None ð¡:;;l. ·~·PI JJ~Qß G (g} 28. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary~ If no tests were conducted, state "None". Zone 3 9304' 8599' None Zone 2C 9374' 8666' Zone 2B 9469' 8753' 24N 9482' 8764' 24P 9494' 8774' Zone 2A 9572' 8833' Zone 1 B 9653' 8880' 14N 9708' 8900' R~' <, JUN 082004 Alaska Qì! 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~lIø" 1'- all/2. T'tl T h· IAs t t D t 0'-..07 /Y f Terrie Hubble /Øv~ ~ Ie ec mea sisan ae I...Q "v, 02-29C 204-051 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Thomas McCarty, 564-4378 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/18/2004 02:30 - 04:30 2.00 MOB P PRE Rig released from 07-25A @ 02:30Hrs on 4/18/2004. Prep to move rig off well. Roll up tarps & warm-up moving system. Meanwhile rig move to DS# 07-25A is going to be derrick up as CPS contractors have finished burrying power lines along the rig move route. 04:30 - 08:00 3.50 MOB P PRE PJSM. Jack-up rig & pull rig off well. NU & P/test 07-25A tree cap. Move rig to down pad. 08:00 - 09:00 1.00 MOB P PRE PJSM. Secure BOP. P/U mats & secure pad. Conduct post-operations pad inspection. 09:00 - 09:30 0.50 MOB P PRE PJSM. Move rig to pad entrance. 09:30 - 12:30 3.00 MOB N WAIT PRE Standby W.O. BP security & tool services personnel due to two other ongoing rig moves. 12:30 - 13:00 0.50 MOB P PRE Held pre-move safety meeting with crew, security & tool services. 13:00 - 16:30 3.50 MOB P PRE Move rig from DS#07 to DS#02. 16:30 - 17:00 0.50 MOB P PRE Arrive @ DS#02 & align rig in front of 02-29. Install dikes around tree. DSM install tree platform. Conduct pre-operations pad inspection. 17:00 - 17:15 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 17:15 - 17:30 0.25 MOB P PRE Back rig over well & set down. 17:30 - 18:00 0.50 RIGU P PRE ACCEPT RIG AT 17:30 HRS ON 04/18/04. Grease Xmas tree valves. 18:00 - 18:30 0.50 RIGU P PRE PJSM with night crew. 18:30 - 20:00 1.50 BOPSUF P PRE ND tree cap. NU BOP. While NU BOP, swap CT reel. 20:00 - 00:00 4.00 BOPSUF P PRE Test BOPE. Witness of test waived by Chuck Sheve. Accept rig at 20:30 to 4/18/04. Rig accept time adjusted for RU injector and stabbing coil. While testing BOPE, weld nubbin on CT. MU hard line. and inner reel valve. 4/19/2004 00:00 - 02:00 2.00 BOPSUF P PRE Continue testing BOPE. 02:00 - 03:45 1.75 RIGU P PRE RU injector. RU goose neck. MU internal CTC. PullCT across roof. Stab pipe in injector. 03:45 - 04:20 0.58 RIGU P PRE Weld on CTC. 04:20 - 06:00 1.67 RIGU P PRE MU dart catcher. Pump 3 bbls. PT hard line against inner reel valve. Launch dart & pump 33bbls. CT pressure up due to several ice plugs in CT. Also observe ice plugs in hardline & valve to tiger tank. 06:00 - 08:00 2.00 RIGU N SFAL PRE Break hardline to tiger tank & trouble shoot ice plugs. Thaw out ice plugs. M/U hardline, fluid pack with MeOH & P/test to 3500psi. 08:00 - 08: 15 0.25 RIGU P PRE Open up well & record 37psi WHP. Bleed off trapped gas & WHP drop to Opsi. 08:15 - 09:30 1.25 RIGU N SFAL PRE M/U & RIH nozzle stinger BHA# 1 to 500'. Pressure up to 4000psi & blowout ice plug with 4.7bbls. 09:30 - 10:15 0.75 RIGU N SFAL PRE POOH to surface. 10:15-10:30 0.25 RIGU P PRE Reverse PfTest inner reel valve to 3500psi - OK. 10:30 - 11 :30 1.00 RIGU P PRE Install dart catcher. Load wiper dart. Launch & chase with 2% KCL. Dart hit @ 36.4bbls. 11 :30 - 11 :45 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & milling BHA M/U procedures. 11 :45 - 13:15 1.50 STWHIP P WEXIT M/U & lock tite cement milling BHA #2 with new 2.74" D331 mill, 2-3/8" WF 1.75deg ABH motor, Sperry GR-DIR MWD & orienter & WF MHA (OAL = 59.69'). Scribe tools. M/U injector. Printed: 5/10/2004 9:22:09 AM - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/19/2004 13:15 - 15:00 1.75 STWHIP P WEXIT RIH cement milling BHA #2. SHT orienter & MWD - OK. Continue RIH to 9015' taking FP well returns to the tiger tank. 15:00 - 15:40 0.67 STWHIP P WEXIT Log down GR & tie-into TSAD @ 9022' - subtract 2' from CTD. 15:40 - 15:45 0.08 STWHIP P WEXIT RIH & tag TOC @ 9171'. 15:45 - 15:55 0.17 STWHIP P WEXIT Orient TF to 170R. Establish freespin @ 1.7bpm/2950psi. P/U wt = 30k, S/O wt = 14k. PVT = 278bbls. lAP = 4psi, OAP = 95psi. 15:55 -16:10 0.25 STWHIP P WEXIT Resume pilot hole milling operations. Mill LS pilot hole to 9180' with 170R TF, 1.7/1.7bpm, 2950/3450psi, 2-3k WOB & 70fph ave inconsistent ROP. 16:10 -17:20 1.17 STWHIP P WEXIT Mill cement to 9235' with 165R TF, 1.7/1.7bpm, 2950/3400psi, 3-4k WOB & 55fph ave consistent ROP. 17:20 - 17:25 0.08 STWHIP P WEXIT Continue milling LS pilot hole to 9242' with 178L TF, 1.7/1.7bpm, 2950/3400psi, 2-3k WOB & 40fph ave consistent ROP. 17:25 - 17:40 0.25 STWHIP P WEXIT Orient TF to 1 OL for HS cement ramp. 17:40 - 18:15 0.58 STWHIP P WEXIT Mill 8' cement ramp from 9242' to 9249.5' with 5-10L TF, 1.7/1.7bpm, 2950/3050psi, 2k WOB & 25fph ave consistent ROP. 18:15 - 19:50 1.58 STWHIP P WEXIT POOH. Paint 9,000' EOP flag. 19:50 - 20:45 0.92 STWHIP P WEXIT LD motor and mill. Mill gaged 2.74". MU Weatherford 2.5 deg bent housing motor w/2.74" Hughes 1 step diamond window mill. Check orienter. Change out pulser. Scibe MWD/motor. MU injector. 20:45 - 21 :00 0.25 STWHIP P WEXIT Change packoff. 21 :00 - 22:50 1.83 STWHIP P WEXIT RIH to 9,000' EOP flag. Correct depth -9.2'. 22:50 - 23:25 0.58 STWHIP P WEXIT Log GR tie in, +3' correction. 23:25 - 00:00 0.58 STWHIP P WEXIT Orient 10L. RIH. Tag at top of cement, 9,174'. Attempt to work through. Orient to 136R. Tag. Bleed off pressure on choke. Set down and pop through. RIH w/o pumping. RIH to just above ramp. 4/20/2004 00:00 - 00:15 0.25 STWHIP P WEXIT Orient to 10L. RIH and tag w/o pump at 9,248'. PU to 9,238'. Bring up pump to 1.4 bpm. Got a click. RIH and zero WOB. Tag at 9,251.7'. Flag pipe. PU to 9,251'. Pump at 1.8 bpm, Start time milling schedule. 00:15 - 06:30 6.25 STWHIP P WEXIT Mill window following time milling schedule. Mill to 9,253.7'. Observe pressure drop from 3400psi to 3080psi & TF rolling right from 10L to 13R. Continue time-milling to 9,254'. 06:30 - 07:15 0.75 STWHIP P WEXIT Time-mill from 9254' to 9254.7' with 13-35R TF, 1.7/3150psi, 1k WOB & 1fph ave ROP. TF still rolling right. 07:15 - 07:20 0.08 STWHIP P WEXIT P/U with 10k O/pull. PUH to 9180' & establish freespin @ 1.7bpm/3080psi. Observe TF roll to 21 L. P/U wt = 30k, S/O wt = 12k. 07:20 - 07:30 0.17 STWHIP P WEXIT Eased back in hole & see motor work @ 9254.2'. Bleed down OAP from 800psi to 270psi. 07:30 - 08:20 0.83 STWHIP P WEXIT Continue time-milling from 9254.2' to 9255' with 13-18R TF, 1.7/3120psi, 1k WOB & 1fph ave ROP. Seems like we're out. 08:20 - 08:55 0.58 STWHIP P WEXIT Start milling formation by wt. Mill to 9260' with 13R TF, 1.7/1.7bpm, 3100/3130psi, 3k WOB & 5fph ave ROP. P/U with 2k O/pull. Ease back to 9257'. 08:55 - 09:55 1.00 STWHIP P WEXIT Mill formation to 9265' with 13-25R TF, 1.7/1.7bpm, 3100/3420psi, 1-2k WOB & 1 Of ph ave HOP. Seeing 14degs inclination @ 9248'. Tentative depths are: TOCPilot = 9171', Printed: 5/10/2004 9:22:09 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/20/2004 08:55 - 09:55 1.00 STWHIP P WEXIT TOCRamp = 9242', TOW = 9250' & BOW = 9255'. 09:55 - 10:00 0.08 STWHIP P WEXIT PUH to 9015' for GR tie-in. 10:00 - 1 0: 1 0 0.17 STWHIP P WEXIT Log down GR & tie-into TSAD @ 9022' - add l' to CTD. 10:10 - 11 :45 1.58 STWHIP P WEXIT Paint EOP flag @ 9000' & POOH window milling BHA. 11 :45 - 13:10 1.42 STWHIP P WEXIT LD motor and mill. Change out MWD. PU 2.74" diamond crayola mill, 1.75 degree BH motor. 13:10 - 15:15 2.08 STWHIP P WEXIT RIH. Correct depth to flag, -8'. Tie in w/ GR, -1'. 15:15 - 17:10 1.92 STWHIP P WEXIT Orient to 14R. Ream window. Stall at 9247.4'. Ream down between 3R and 8R w/ TF rolling to 25R. Weight dropped off at 9252.2. RIH and tag at 9262.5'. Back ream window at 14R at 1.5 fpm to 9240'. Pump 30 bbl high visco pill. RIH and tag. Orient to 45R. Back ream window to 9245' and PU to 9240'. Slow pump to minimum rate and drift window smoothly. Tag bottom and orient to 45L. Back ream window. Slow pump to minimum rate and drift smoothly. Shut down pump and pull through the window. Run back through the window w/o a bobble. 17:10 - 17:30 0.33 STWHIP P WEXIT Start pumping new flo pro. Displace well bore. 17:30 - 19:15 1.75 STWHIP P WEXIT POOH. 19:15 - 20:00 0.75 DRILL P PROD1 LD dressing mill (in gauge) and MU 1.7 Xtreme. 20:00 - 21 :50 1.83 DRILL P PROD1 RIH to 9035 21 :50 - 22:55 1.08 DRILL P PROD1 Tie - in (correction -2') 22:55 - 23:05 0.17 DRILL P PROD1 RIH tag at 9267' 23:05 - 23:20 0.25 DRILL P PROD1 Directionally drill at 1.8/1.8 bpm at 3370 psi. FS = 3000 psi, ROP 50 fph, TF 75 L. Drill to 9279. 23:20 - 23:40 0.33 DRILL P PROD1 Orient to 40L 23:40 - 00:00 0.33 DRILL P PROD1 Directionally drill at 1.8/1.8 bpm at 3160 psi. FS = 3000 psi, ROP 29 fph, TF 105 L. Drill to 9300'. 4/21/2004 00:00 - 04:40 4.67 DRILL P PROD1 Directionally drill 1.8/1.8 bpm @ 3350 psi.3000 psi FS, Up weight 32K, SO weight 16K, 2K WOB, ROP 10 fph,drill to 9335. Tool face irradic most likely formation change top of zone 3. ROP slowing. 04:40 - 06:00 1.33 DRILL P PROD1 POH. 06:00 - 06:20 0.33 DRILL P PROD1 Change out bit. Bit graded 4-2-BT-T-X-NA-RO-PR. 06:20 - 08:10 1.83 DRILL P PROD1 RIH. Tag bottom at 9,343'. Correct depth to 9,336'. 08:10 - 10:00 1.83 DRILL P PROD1 Orient to 90L. Drill from 9,336' to 9,347'. Orienter is not working. Tag bottom. Pull into 7" and cycle orienter, no clicks. 10:00 - 11 :30 1.50 DRILL N DFAL PROD1 POOH to change orienter. 11:30 -12:10 0.67 DRILL N DFAL PROD1 Change out orienter. Check and change bit. 12:10 - 13:50 1.67 DRILL N DFAL PROD1 RIH to 900'. SHT orienter and MWD, ok. RIH and tag bottom. Correct depth to 9347'. 13:50 - 14:00 0.17 DRILL N DFAL PROD1 Orient to 70L. 14:00 - 18:20 4.33 DRILL P PROD1 Drill from 9347' to 9392' at 1.7/1.73,100/3,350 psi, TF 60L to 80L. Slow ROP in zone 3. ROP increased at 9,370'. 18:20 - 20:15 1.92 DRILL P PROD1 Drill from 9392 to 9411' at 1.8 /1.8 bpm @3360 psi. 3100 psi = FS. 20: 15 - 20:50 0.58 DRILL P PROD1 Orient 90L 20:50 - 23:20 2.50 DRILL P PROD1 Directionally drill 1.8/1.8 bpm @ 3460 psi., FS= 3160 psi., UP WT 32K, DN WT 13K, WOB 2K, ROP 12, Based on cuttings and comparison to last sidetrack should have higher ROP. Decided to look at bit. 23:20 - 00:00 0.67 DRILL _P PROD1 POH Printed: 5/10/2004 9:22:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/22/2004 00:00 - 01 :00 1.00 DRILL P PROD1 POH 01 :00 - 01 :30 0.50 DRILL P PROD1 Bit graded 3-2-BT-N-X-I-WT-PR. PU new DS100 01 :30 - 03:00 1.50 DRILL P PROD1 RIH to 9035. 03:00 - 03:30 0.50 DRILL P PROD1 Tie in correct -6' 03:30 - 04:00 0.50 DRILL P PROD1 RIH 04:00 - 04: 15 0.25 DRILL P PROD1 Orient 70L 04:15 - 08:15 4.00 DRILL P PROD1 RIH tag at 9451. Directionally drill 1.8/1.8 bpm @ 3540 psi, 3200 psi FS, Up wt 32K, DN WT 13K, WOB 2K, ROP 20 fph. 08: 15 - 08:30 0.25 DRILL P PROD1 Wiper trip to window. 08:30 - 08:45 0.25 DRILL P PROD1 Drill to 9,621'. 08:45 - 09:05 0.33 DRILL P PROD1 Orient to 30R. 09:05 - 10:30 1.42 DRILL P PROD1 Drill to 9,715' at 1.8/1.83,728/4,200 psi at 30R, 80 - 100 fph. 10:30 - 10:40 0.17 DRILL P PROD1 Pull up hole 100' for a short wiper trip. Start increasing Klagard content from 8 ppb to 12 ppb. 10:40 - 11 :00 0.33 DRILL P PROD1 Drill to 9,731'. ROP slowed. Getting into 14N shale. PU and overpulled 30K. 11 :00 - 11: 15 0.25 DRILL P PROD1 Orient to 60R. 11:15-14:20 3.08 DRILL P PROD1 Drill to 9,825'. 14:20 - 16:15 1.92 DRILL P PROD1 POOH for lateral BHA pumping at 1.8 bpm. Pull into tubing tail. Wash back down to 9,170', top of the pilot hole, to clean the 7" casing. POOH pumping at 1.8 bpm. 16:15 -16:30 0.25 DRILL P PROD1 PJSM for changing BHA. 16:30 - 18:30 2.00 DRILL P PROD1 LD MHA. Change out MWD pulser and probe. Change out motor and bit. Bit graded 3-3-BT-A-X-NA-NO-BHA. MU new Hughes DOSTRWD324 to new motor. Scribe motor to MWD. 18:30 - 20:10 1.67 DRILL P PROD1 RIH to 9035. 20: 1 0 - 20:30 0.33 DRILL P PROD1 Tie - in. ( NO Correction required) 20:30 - 21 :00 0.50 DRILL P PROD1 RIH . Tag at 9828.5' Clean trip. 21:00-21:10 0.17 DRILL P PROD1 Orient 90R 21 :10 - 23:15 2.08 DRILL P PROD1 Directionally drill 1.7/1.7 bpm @ 3600 psi, FS = 3280 psi. .7K WOB, 70-100 ROP. TF 90R 23:15 - 00:00 0.75 DRILL P PROD1 Wiper to window. No Problems. 4/23/2004 00:00 - 03:00 3.00 DRILL P PROD1 Directionally drill 1.6/1.55 bpm @ 3800 psi, FS = 3450 psi. 2K WOB, 70-100 ROP. Ratty drill from 10000'. Identified as lower 14P.ROP 20 fph. Sample at 10100 showed 10% shale claystome previous sample all sand. Gamma has spiked to 130 API. Seeing some spurt losses. Averaging 4 bph. 03:00 - 04:30 1.50 DRILL P PROD1 Wiper to tail pipe. No overpulls. Clean trip. Tag top of cement 9175. Went thru window and ramp at min rate. No problems. 04:30 - 06:30 2.00 DRILL P PROD1 Directionally drill 1.6/1.6 bpm @ 3640 psi, FS = 3450 psi. 2K WOB,<10 ROP. -6k surface wt. 06:30 - 11 :45 5.25 DRILL P PROD1 Pit volume = 167 bbls. IA=6, OA=172. Drill ahead at 1.6/1.4 3,300/3,750 psi. Slow drilling in shale. Start new mud down hole at 10,160'. Drill to 10,193'. 11 :45 - 12:30 0.75 DRILL N PROD1 Attempt to orient, not getting clicks. Pull up hole and try to orient, no go. Tag bottom and bleed off pressure. PU and attempt to orient. 12:30 - 14:35 2.08 DRILL N PROD1 POOH to change orienter. Pull into tubing tail. Wash back down to the top of the pilot hole to clean the 7" casing. POOH pumping at 1.8 bpm. Monitor shaker at bottoms up. No increase in cuttings observed. Continue to monitor shaker while POOH. Pull to 50' pumping at 1.8 bprn. RIH at 100 fpm pumping 1.8 bpm to 500'. Slight increase in cuttings over Printed: 5/10/2004 9:22:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/23/2004 12:30 - 14:35 2.08 DRILL N PROD1 shaker. POOH pumping at 1.8 bpm. Only slight increasing in cuttings 14:35 - 15:25 0.83 DRILL N PROD1 Change orienter. Check bit. 0-1-CT-G-X-NA-NO-DTF. 15:25 - 17:05 1.67 DRILL N PROD1 RIH. 17:05 - 17:30 0.42 DRILL N PROD1 Tie in from 9,035' to 9,060' logging down. -6' correction. 17:30 - 17:45 0.25 DRILL N PROD1 RIH Tag TD. 17:45 - 18:50 1.08 DRILL P PROD1 Work shales 10050 -10170 18:50 - 23:00 4.17 DRILL P PROD1 Directionally drill 1.8/1.8 bpm @ 3640 psi, FS = 3450 psi. UP WT 32K, DN WT 13K, ,<20fph ROP. -3k surface wt. Drilling ratty in and out of hi gamma shale. Drill at 23L TF. Turn TF highside. 97 inclination at bit.Not seeing mirror image of gamma pattern. Maybe unidentified fault. 23:00 - 23:45 0.75 DRILL P PROD1 Directionally drill 1.8/1.8 bpm @ 3700 psi, FS = 3450 psi. UP WT 32K, DN WT 13K, ,70+fph ROP. WOB 5K wt Roll TF to 120 L continue to drill to cross identified fault per plan. Drill to 10350'. 23:45 - 00:00 0.25 DRILL P PROD1 Wiper to window. 4/24/2004 00:00 - 01 :25 1.42 DRILL P PROD1 Wiper to window. Seen over pulls in the shale 10,300 -10,100 while back reaming out of hole. Trip back to bottom clean. 01 :25 - 05:40 4.25 DRILL P PROD1 Directionally drill 1.8/1.8 @ 3560 psi, 3200 psi SF, WOB 3K, ROP 100+ Up Wt 29K, DN WT 12K. Drill to 10400. Formation kicked us up 4'. Drill to 10502'. 05:40 - 08:00 2.33 DRILL P PROD1 Wiper trip to tubing tail. RIH. Work through tight shale section from 9,480' to 9,495'. RIH. 08:00 - 10:35 2.58 DRILL P PROD1 Drill at 1.6/1.6 3,200/3,500 psi. WOB 4K, TF 162R. Drill to 10,650' . 10:35 - 12:30 1.92 DRILL P PROD1 Wiper trip to window. Tie in wi GR logging down. +6' correction. RIH. 12:30 - 17:45 5.25 DRILL P PROD1 Drill to 10,765' geo steering. Losing fluid at 3 bph. Drilling with -6,000 injector weight in shales. 17:45 - 18:00 0.25 DRILL P PROD1 Short 200' wiper trip to wipe shales. 18:00 - 23:00 5.00 DRILL P PROD1 Drill at 1.6/1.63,200/3,450 psi. Pump 20 bbls high lubricant sweep to aid drilling in shale. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper to window. 4/25/2004 00:00 - 00:50 0.83 DRILL P PROD1 Wiper to window. Set downs at 10230,10423,10440, 00:50 - 06:00 5.17 DRILL P PROD1 Directionally drill 1.6/1.6 bpm @ 3440 psi -3K surface wt. ROP 20 fph. Pull up hole for a short wiper trip. 06:00 - 07:50 1.83 DRILL P PROD1 Drill to 10,872' making little progress. Stacking weight and not drilling off. 07:50 - 09:30 1.67 DRILL P PROD1 Wiper trip to window. Overpulls at 10,430', and 10,255' - 10,185'. RIH. Set down at 10,200',10,450'. and 10,600'. 09:30 - 11 :50 2.33 DRILL C PROD1 POOH for OH sidetrack BHA. Pressure fluctuating while POOH. May have a washout. 11 :50 - 13:30 1.67 DRILL C PROD1 Pull BHA and inspect for washout. Found Baker disconnect O-ring washed out and leaking mud. LD motor and bit. Bit 0-1-CT-G-X-NA-NO-BHA. MU OH sidetrack BHA. MU injector to riser. 13:30 - 14:20 0.83 DRILL C PROD1 Replace traction cylinder on injector. 14:20 - 16:00 1.67 DRILL C PROD1 RIH. 16:00 - 16:15 0.25 DRILL C PROD1 Tie in logging down. -4' correction. 16:15 - 17:00 0.75 DRILL C PROD1 RIH through pilot hole oriented 140 R, no pump, w/o problem. Tag up at 9,256', bottom of window. PU to 9,170' and attempt Printed: 5/10/2004 9:22:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/25/2004 16:15 - 17:00 0.75 DRILL C PROD1 to orient. Orienter not working. 17:00 - 17:15 0.25 DRILL X DFAL PROD1 POOH to change orienter. CT pin holed at reel w/ 8,845' bit depth. Line up to fill across the well head. Hold 100 psi back pressure with choke. 17:15 - 19:15 2.00 DRILL X RREP PROD1 POOH. 19:15 -19:30 0.25 DRILL X RREP PROD1 LD BHA 19:30 . 19:45 0.25 DRILL X RREP PROD1 PJSM 19:45 - 20:00 0.25 DRILL X RREP PROD1 N2 blow down. 20:00 - 00:00 4.00 DRILL X RREP PROD1 Cut coil connector off. Dress end of coil and install grapple. Pull coil back to reel and secure. 4/26/2004 00:00 - 09:00 9.00 DRILL X RREP PROD1 Wait on arrival of Peak crane to swap reels. The operators are limited out on hours. 09:00 - 11 :00 2.00 DRILL X RREP PROD1 PJSM for lifting reel. Review lift plan and procedure for swapping reels. Swap reels. 11 :00 - 12:30 1.50 DRILL X RREP PROD1 MU hardline inside reel. Install internal CTC. Pull coil across roof. Stab pipe. 12:30 - 14:00 1.50 DRILL X RREP PROD1 Change packoff brass and element. 14:00 - 15:10 1.17 DRILL X RREP PROD1 Weld on CTC. 15:10 -15:50 0.67 DRILL X RREP PROD1 Pump dart. 15:50 - 16:40 0.83 STKOH X RREP PROD1 MU OH sidetrack BHA w/2.73" R60ST, 1.9 deg. bent housing motor. 16:40 - 18:30 1.83 STKOH X RREP PROD1 RIH to 990'. SHT MWD and orienter. RIH. Tag up on GLM at 5,670'. RIH to 9035'. 18:30 - 18:55 0.42 STKOH X RREP PROD1 Tie -in correction -8.5'. 18:55 - 19:30 0.58 STKOH C PROD1 RIH to 9850 and survey. 19:00 - 22:50 3.83 STKOH C PROD1 Start open hole side track 9820 - 9850. RIH orient. 165L. Make scribe run to 9850. Drill trough 1.7/1.7 bpm 3130 psi and 30 fph. Trough to 9841 seeing motor work. Increased ROP. Sidtracking. Progressive rolling TF clock wise. Drilling at 1.7 I 1.7 bpm 3400 psi, FS = 3000 psi. WOB 2K, ROP 90, Drill to 9932' EOB. (Calling KO point 9840'.) 22:50 - 23:30 0.67 STKOH C PROD1 Back ream @ 1.1 BPM 3400 psi @ 3fpm TF 133 L from 9869 to 9800. RIH wo pumps 144L and dry tag 9932'. No Problems thru open hole sidetrack. 23:30 - 00:00 0.50 STKOH C PROD1 POH. 4/27/2004 00:00-01:15 1.25 STKOH C PROD1 POH 01 :15 - 02:00 0.75 STKOH C PROD1 PU lateral BHA. R60 bit pulled had one cutter missing two chipped. 02:00 - 04:00 2.00 STKOH C PROD1 RIH to 9035. 04:00 - 04:15 0.25 STKOH C PROD1 Tie-in correction -1'. 04:15 - 04:40 0.42 STKOH C PROD1 RIH tag at 9933' 04:40 - 06:00 1.33 DRILL C PROD1 Orient 60R.Directionally drill 1.7/1.7 bpm 3770 psi, FS 3280 psi, 2-3K WOB, ROP 20. Drill to 9,975'. 06:00 - 07:00 1.00 DRILL C PROD1 Pull into casing. Tighten hard line inside reel. 07:00 - 07:30 0.50 DRILL C PROD1 Orient to 170R. 07:30 - 09:10 1.67 DRILL C PROD1 Drill at 1.7/1.73,200/3,370 psi, 160R TF. Orient 80R and drill to 10078' at 90 fph. 09:10 - 09:50 0.67 DRILL C PROD1 Tighten hardline. 09:50 - 10:05 0.25 DRILL C PROD1 Orient to 112R. 10:05 - 11 :00 0.92 DRILL C PROD1 Drill at 1.7/1.73.300/3,600 psi, 160-173R TF, 90 fph ROP. Drill to 10,150'. 11 :00 - 12:00 1.00 DRILL C PROD1 Wiper trip to 9035'. Tie in logging down. -1 .5' correction. 12:00 - 12:25 0.42 DRILL C PROD1 RIH. Printed: 5/10/2004 9:22:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/27/2004 12:25 - 15:40 3.25 DRILL C PROD1 DirectionallydriIl1.7/1.7bpm @ 3620 psi, FS=331 0 psi, UP WT 30K, DN WT 12K, 2-3K WOB, 60 ROP. 15:40 - 17:10 1.50 DRILL C PROD1 Wiper to tailpipe. Clean trip. 17:10 - 20:00 2.83 DRILL C PROD1 Directionally drill 1.6/1.6 bpm @3486 psi, 3200 psi FS, Up WT 30K, DN WT 12k, WOB 3K, ROP 40. 20:00 - 20:30 0.50 DRILL C PROD1 Orient TF to 130L 20:30 - 21 :30 1.00 DRILL C PROD1 Drilling Lateral in Z1, 1.65 bpm, 3300 - 4000 psi, 135L, 96 deg incl, Drilled to 10,450 ft. 21 :30 - 23:00 1.50 DRILL C PROD1 Wiper trip to window. Clean trip. 23:00 - 23:45 0.75 DRILL C PROD1 Circulate well to new FloPro. Send old FloPro system to MI for reconditioning. 23:45 - 00:00 0.25 DRILL X DFAL PROD1 Unable to get pulses from tool. No MWD data prior to fluid swap and no change with new FloPro in hole. POH to check Sperry tools and BHA. 4/28/2004 00:00 - 02:30 2.50 DRILL X DFAL PROD1 POH for failed Sperry MWD. intermitent pulses. 02:30 - 02:45 0.25 DRILL X DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA change out. 02:45 - 03:45 1.00 DRILL X DFAL PROD1 c/o Sperry MWD tools (Sonde and Pulser replaced), check & rerun orienter, check bit [0,1,1] and motor. PIT weld on CTC. 03:45 - 04:30 0.75 DRILL X DFAL PROD1 RIH with BHA #14, 1.1 deg motor and HC Bi-center bit. BHA = 59.19 ft. SHT Sperry tools. OK. Tested orienter, No clicks. POH. 04:30 - 04:50 0.33 DRILL X DFAL PROD1 C/O Sperry Orienter. 04:50 - 06: 15 1.42 DRILL X DFAL PROD1 RIH with BHA #15, 1.1 deg motor and HC Bi-center bit. BHA = 59.19 ft. SHT Sperry tools. OK. Test Orienter OK. RIH. 06:15 - 06:30 0.25 DRILL X DFAL PROD1 Unable to tie -in MWD failure interminent pulses. 06:30 - 08:30 2.00 DRILL X DFAL PROD1 POH for MWD. 08:30 - 09:00 0.50 DRILL X DFAL PROD1 Change out pulser & motor. 09:00 - 10:50 1.83 DRILL X DFAL PROD1 RIH to 9035'. 10:50 - 11: 1 0 0.33 DRILL X DFAL PROD1 Tie - in correction -8'. 11 : 1 0 - 12:05 0.92 DRILL X DFAL PROD1 RIH MWD signal failed at 9970'. RIH At 1.6 bpm attenpt to start tool. ( Change pump rates Cycle pumps). Tag bottom at 10455' . NO signal. MWD failed. (This failure mode is a different than prior failure). Preliminary field investigation found the pulser solinoid valve stuck open. Further investigation requires tool tear down at shop. 12:05 - 12:35 0.50 DRILL X DFAL PROD1 POH for MWD to 9150. 12:35 - 13:45 1.17 DRILL X DFAL PROD1 Circulate bottoms up +. Nothing in returns. Sample caught for MI. Mud analysis found mud was in spec. 13:45-15:15 1.50 DRILL X DFAL PROD1 POH 15:15 - 16:00 0.75 DRILL X DFAL PROD1 Changout Entire MWD tool string + new bit. 16:00 - 17:50 1.83 DRILL X DFAL PROD1 RIH BHA # 16, 1.1 deg motor and new HyCalog DS 100. BHA 59.19'. RIH to 9035' 17:50 - 18:20 0.50 DRILL X DFAL PROD1 Tie - in Correction -6 ft CTD. 18:20 - 18:45 0.42 DRILL X DFAL PROD1 RIH clean to TD. Tag TD at 10,454 ft. 18:45 - 19:10 0.42 DRILL X DFAL PROD1 Orient TF to 120 L. 19:10 - 20:30 1.33 DRILL C PROD1 Drilling Z1 Lateral. 1.6 bpm, 3250-4000 psi, 120L, 92 deg incl, 100 fph, Drilled to 10545'. 20:30 - 21 :30 1.00 DRILL C PROD1 Drilling Z1 Lateral. 1.6 bpm, 3300-4000 psi, 90L, 91 deg incl, 70 fph, Drilled to 10,600 ft. 21 :30 - 23:00 1.50 DRILL C PROD1 Wiper trip to window. Clean hole. RIH. 23:00 - 23:20 0.33 DRILL C PROD1 Orient to high side. 23:20 - 00:00 0.67 DRILL C PROD1 Drilling Z1 Lateral. 1.6 bpm, 3300-4000 psi, 10L, 92 deg incl, Printed: 5/10/2004 9:22:09 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/28/2004 23:20 - 00:00 0.67 DRILL C PROD1 70 fph, Drilled to 10,633'. 4/29/2004 00:00 - 00:15 0.25 DRILL C PROD1 Orient TF to 65L. 00:15 - 01:15 1.00 DRILL C PROD1 Drilling Z1 Lateral, 1.7 bpm, 3400-4100 psi, 65L, 95 deg, 50 fph, stacking wt. Drilled to 10680'. 01 :15 - 01 :30 0.25 DRILL C PROD1 Orient TF to 120L 01 :30 - 02:30 1.00 DRILL C PROD1 Drilling Z1 Lateral, 1.6 bpm, 3400-4100 psi, 120L, 98 deg, 80 fph, stacking wt. Drilled to 10745' 02:30 - 04:50 2.33 DRILL C PROD1 Wiper trip to tubing tailpipe. Clean hole. Slow pump across window. Max rate in 7" liner. 27K up wt above window. No indication of fill in 7" liner. RIH. 04:50 - 05: 10 0.33 DRILL C PROD1 Orient TF to 130R. 05:10 - 05:40 0.50 DRILL C PROD1 Drilling Z1 Lateral, 1.6 bpm, 3500-4200 psi, 130R, 94 deg, 100 fph, Drilled to 10,775'. 05:40 - 06:00 0.33 DRILL C PROD1 Orient TF to 90R. 06:00 - 06: 15 0.25 DRILL C PROD1 Drill to 10779. Lost communication with the directional package. 06: 15 - 08:45 2.50 DRILL X DFAL PROD1 POH MWD failed. POH to 6600' <5degrees tool began to work. RIH to 6900 tool stopped again. Continue to POH. 08:45 - 09:30 0.75 DRILL X DFAL PROD1 Change out Directional package. Check Bit OK. 09:30 - 11 :15 1.75 DRILL X DFAL PROD1 RIH to 1100'. Shallow hole test good. Continue to RIH to 9035'. 11: 15 - 11 :40 0.42 DRILL X DFAL PROD1 Tie - in log. Correction = -1'. 11 :40 - 12:30 0.83 DRILL X DFAL PROD1 RIH 45R thru window and 177L at OH sidetrack. Set down at 10100 over pull. Survey indicates old hole. 12:30 - 13:30 1.00 DRILL X HMAN PROD1 Numerous attempts to enter OH side track at various low side tool faces. No GO. Investigate tool settings and found internal offset entry in the computer program incorrect. Off by 150 degrees. 13:30 - 13:50 0.33 DRILL X DFAL PROD1 Orient getting 10 degree clicks. TF 135R. 13:50 - 14:15 0.42 DRILL X DFAL PROD1 RIH tag at 10775'. 14:15 - 15:45 1.50 DRILL C PROD1 Directionally drill 1.6/1.6 bpm @ 4130 psi, 3800 psi FS, -5K surface weight, ROP 60, TF 105R, GR 30-35, INC 94 15:45 - 16:00 0.25 DRILL C PROD1 Directionally drill 1.6/1.6 bpm @ 4130 psi, 3800 psi FS, -3K surface weight, ROP 77, TF 177L, GR 30-35, INC 94. 16:00 - 16:15 0.25 DRILL C PROD1 Wiper to 10700'. 16:15 -16:30 0.25 DRILL C PROD1 Directionally drill 1.6/1.6 bpm @ 4050 psi, 3800 psi FS, +4K surface weight, 8K WOB, ROP 90, TF 11 OR GR 30-35, INC 92. 16:30 - 18:40 2.17 DRILL C PROD1 Wiper to window. Clean hole. 18:40 - 19:30 0.83 DRILL C PROD1 Drilling Z1 Lateral, 1.6 bpm, 3700 - 4100 psi, 75L, 91 deg incl, 80 fph, Drilled to 10,970'. 19:30 - 20:00 0.50 DRILL C PROD1 Orient to 100L. 20:00 - 22:30 2.50 DRILL C PROD1 Drilling Z1 Lateral, 1.6 bpm, 3700 - 4100 psi, 110L, 93 deg incl, 50 fph, Stacking wt. Drilled to 11030'. 22:30 - 00:00 1.50 DRILL C PROD1 Wiper trip to 3-1/2" tailpipe at 8720'. Clean hole. RIH. 4/30/2004 00:00 - 00:20 0.33 DRILL C PROD1 Log GR tie-in to BHCS/GR at 99035 ft. Added 10 ft CTD. 00:20 - 01:1 0 0.83 DRILL C PROD1 RIH clean to TD of 11,035 ft. 01:1 0 - 01 :40 0.50 DRILL C PROD1 Drilling Z1 Lateral, 1.5 bpm, 3700-4200 psi, 92 deg incl, 80 fph, Drilled to 11,068 ft. 01 :40 - 02:00 0.33 DRILL C PROD1 Orient TF to 11 OL. 02:00 - 02: 15 0.25 DRILL C PROD1 Drilling Z1 Lateral, 1.5 bpm, 3700-4200 psi, 92 deg incl, 80 fph, Drilled to 11,080'. 02:15 - 03:00 0.75 DRILL C PROD1 Orient TF to 150L 03:00 - 03:50 0.83 DRILL C PROD1 Drilling Z1 Lateral, 1.5 bpm, 3700-4200 psi, 92 deg incl, 80 Printed: 5/10/2004 9:22:09 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 4/30/2004 03:00 - 03:50 0.83 DRILL C PROD1 fph, Swapped to new FloPro at 11,100 ft. Saw a 400 psi drop in circ press with new mud. Sent old FloPro to MI plant to be re-conditioned. Drilled to 11,105 ft. 03:50 - 04:20 0.50 DRILL C PROD1 Orient TF to 120R. 04:20 - 05:20 1.00 DRILL C PROD1 Drilling Z1 Lateral, 1.7 bpm, 3400-3800 psi, 120R, 91 deg incl, 70 fph, Drilled to 11,155'. 05:20 - 05:50 0.50 DRILL C PROD1 Orient TF to 90R. 05:50 - 06:30 0.67 DRILL C PROD1 Drilling Z1 Lateral, 1.7 bpm, 3400-3800 psi, 80R, 90 deg incl, 90 fph, Drilled to 11,200'. 06:30 - 08:30 2.00 DRILL C PROD1 Wiper to window at 135L at 1.6 bpm to 9300'. RIH 72L thru OH side track no problem. 08:30 - 10:20 1.83 DRILL C PROD1 Directionally 1.6/1.6 bpm @ 3750 psi, psi = FS, Surface WOB -5K, , ROP 110 fph, TF 93R, UP wt 30K, Drill to 11312' Stacking. 10:20 - 10:30 0.17 DRILL C PROD1 Wiper to 11200. 10:30 - 10:50 0.33 DRILL C PROD1 Directionally 1.6/1.6 bpm @ 3880 psi, 3450 psi = FS, Surface WOB -8K, , ROP 110 fph, TF 93R, UP wt 30K, Drill to 11350'. 10:50 - 13:20 2.50 DRILL C PROD1 Wiper to TT. Orient 143L thru OH side track. RIH. No Problems Hole in good shape. 13:20 - 13:40 0.33 DRILL C PROD1 Orient 170R 13:40 - 15:00 1.33 DRILL C PROD1 Directionally 1.7/1.7 bpm @ 4020 psi, 3500 psi = FS, Surface WOB -6K, , ROP 150 fph, TF 11 OR, INC 84, Drill to 11410'. TD. 15:00 - 16:15 1.25 DRILL C PROD1 POH to 8686'. RIH to 9035'. 16:15-16:30 0.25 DRILL C PROD1 Tie - in log. Correction +9'. 16:30 - 17:30 1.00 DRILL C PROD1 RIH tag at 11,411'. 17:30 - 20:30 3.00 DRILL C PROD1 POH, Wash 7" liner up and down at max rate. Flag pipe at 6000 and 8600' EOP. POH. 20:30 - 21 :30 1.00 DRILL C PROD1 Layout MWD BHA. 21 :30 - 21:45 0.25 CASE P COMP SAFETY MEETING. Review procedure, hazards and mitigation for running 2-3/8" liner. 21 :45 - 00:00 2.25 CASE P COMP Run 2-3/8" Baker Float equipment and 2-3/8", 4.6#, L-80, STL Liner. 88 joints total. Drift each STL connection after make-up with 1.87" drift on 1" CSH joint and pup. Drifting procedure adds 1.5 minutes per joint, about extra 2 hours for 88 joints. 5/1/2004 00:00 - 02:45 2.75 CASE P COMP Run 2-3/8", 4.6#, L-80, STL Liner. Drift each connection after make-up with 1.87" drift on 1" CSH joint and pup. Drifting procedure adds 1.5 minutes per joint or about 2 hrs for 88 joints. 02:45 - 03:30 0.75 CASE P COMP M/U Baker 2.70" Deployment sleeve with 2-3/8" pup Jt to top of liner. Total length of liner = 2,724.44 ft. MU Baker CTLRT with liner wiper plug. Pull test with 30K. BHA with CTLRT = 2,726.74 ft. 03:30 - 04:00 0.50 CASE P COMP Insert dart and circ dart thu coil to check CT volume and clean CT. Pump 2.2 bpm at 2500 psi, Dart on seat at 40.2 bbls. 04:00 - 04:20 0.33 CASE P COMP M/U CTC to Baker CTLRT. M/U injecter head. Printed: 5/10/2004 9:22:09 AM II e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 5/1/2004 04:20 - 06:20 2.00 CASE P COMP RIH with 2-3/8" Liner on CT. Circ at 0.2 bpm, 700 psi. Correct -7' CTD at flag at 8727'. Run thru window with no wt loss. RIH at 60 fpm, 0.2 bpm at 1500 psi. Land liner at TD at 11,411 ft. Pick up and tag TD 2 times to ensure liner on bottom. 06:20 - 07:00 0.67 CASE P COMP Drop 5/8 ball and circulate ball to liner running tool. Release from liner. 07:00 - 08:30 1.50 CASE P COMP Change well over to KCL. Circulate one full Coil volume thru the cementing screen. 08:30 - 09:30 1.00 CASE N RREP COMP Investigate reel drive problem, Off drillers side reel drive not working. 09:30 - 10:00 0.50 CEMT P COMP PJSM cementing of liner 10:00 -11:45 1.75 CEMT P COMP Mix bio pill for displacement. Batch up . Pump 5 bbl H20. PT lines to 4000 psi. Pump cement zero in Mirco on in density. Pump 16 bb115.8 ppg class G laytex cement @ 1.9/1.8 bpm 2620 psi. Install dart and launch dart, Displace with 25 bbl 2# bio and KCL. Displace cement 1.89 /1.84 @ 2020 psi. At 34.4 bbl into displacement Zero out mirco motion. 1.88 /1.5 reduce to 1.43/1.2521245 psi, Dart shear @ 40.7 bbl 3000 psi,. 1.25/1.14 bpm @ 2660 psi. Land at 50.8 bbls calculated 51.0 bbl. .9 bbllost to formation. Bleed off . Flow check. No Flow floats holding. Pressure to 500 psi. Unsting POH filling steel displacement. 11 :45 - 14:30 2.75 CEMT P COMP POH (on one reel drive motor). 70 fpm. No problem. 14:30 - 19:00 4.50 CEMT P COMP UO Baker CTLRT. M/U mill and motor, MHA and PU 91 joints of 1" CS Hydril. 19:00 - 23:00 4.00 CEMT P COMP Wait on Cement. UCA sample at 50 psi at 2300 hrs 23:00 - 00:00 1.00 CEMT N RREP COMP Continue with repair of Reel drive motor shaft. Repair parts at machine shop. 5/2/2004 00:00 - 08:00 8.00 CEMT N RREP COMP Continue with repairs to reel drive motor shaft. Repaired at machine shop and re-installed. 08:00 - 10:50 2.83 CLEAN P COMP RIH with cleanout assy. .25 bpm @ 380 psi to loner top and at 1.13 bpm 2880 psi. thru liner.DN WT 15K, UP 31 K, Tag at 11401 un corrected. 10:50 - 13:15 2.42 CLEAN P COMP POH to HyDril. set back injector. Drop ball 13:15 - 13:30 0.25 CLEAN COMP PJSM, Stand back Hydril watching for ice falling from derrick, overhead loads, pinch points. 13:30 - 15:00 1.50 CLEAN P COMP Stand back 45 stands and a single. 15:00 - 15:15 0.25 EVAL P COMP PJSM, logging BHA. 15:15 - 15:30 0.25 EVAL P COMP MU logging tools. 15:30 - 17:15 1.75 EVAL P COMP Run in hole CSH. 17:15 - 18:45 1.50 EVAL P COMP RIH with SWS Memory CNUGRlCCL BHA on CT. 18:45 - 20:20 1.58 EVAL P COMP Stop at 8600'. Log down with SWS Memory CNUGRlCCL at 30 fpm. Circ. in 15 bbl New FloPro high Vis Perf pill. Clean trip to PBTD. Tag PBTD at 11,395' CTD. 20:20 - 21:10 0.83 EV AL P COMP Log up at 60 fpm, Lay in high vis perf pill from PBTD at 0.4 bpm, 800 psi. Up WT = 30K. Log up to 8600 ft. 21:10 - 22:30 1.33 EVAL P COMP POH with logging BHA. Circ. at f:2 bpm, 2900 psi while POH. 22:30 - 22:45 0.25 EVAL P COMP SAFETY MEETING. Review procedure, hazards and Printed: 5/10/2004 9:22:09 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 4/18/2004 5/4/2004 N1 Spud Date: 2/26/1990 End: 5/4/2001 5/2/2004 22:30 - 22:45 0.25 EVAL P COMP mitigation for laying out 1" CSH and standing back iin doubles. 22:45 - 00:00 1.25 EVAL P COMP Layout 22 jts of 1" CSH. 5/3/2004 00:00 - 00:30 0.50 EVAL P COMP Stand back 34 stds of 1" CSH. 00:30 - 00:45 0.25 EVAL P COMP SAFETY MEETING. Review procedure, hazards and mitigation for recovery of SWS memory CNUGR/CCL tools. 00:45 - 01 :00 0.25 EVAL P COMP Layout SWS logging BHA. Good log data. Faxed Log to Geo. Tie-in GR depth found PBTD at 11,375 ft. Top of 2-3/8" liner deployment sleeve at 8,682 ft. 01 :00 - 02:00 1.00 EVAL P COMP Pressure test liner lap. Initial pressure = 2120 psi, Final pressure = 1380 psi. Liner lap pressure test failed. Will need to set liner top packer after perforating. 02:00 - 03:00 1.00 PERF N WAIT COMP Wait on orders before running perf guns. CNUGR indicated gas in last 160 ft of open hole. SWS 1.56" PowerJet perf guns loaded in pipe shed. Geo gave orders to Perforate 10,670 - 11,100 ft. 430 ft at 6 SPF. 03:00 - 03:30 0.50 PERF P COMP Pick up SWS perf gun running equipment. Prep rig floor to run perf guns. 03:30 - 03:45 0.25 PERF P COMP SAFETY MEETING. Review procedure, SLB check list, hazards and mitigation for running SWS perforating guns. 03:45 - 04:45 1.00 PERF P COMP RIH with SWS 1.56" PowerJet perf guns, loaded at 6 SPF. 21 Guns total. SWS gun length with blank and firing head = 451.07 ft. 04:45 - 09:15 4.50 PERF P COMP RIH with BKR hyd Disc, XO and 38 stds of 1" CSH workstring. MU BKR, XO, HYD Disc, Checks and swivel. Perforating BHA = 2,822.75 ft. 09:15 - 10:30 1.25 PERF P COMP Tag TD. PU to Up WT 25500#. Correct depth to 11375'. PU to 11,102'. Pump 10 bbp perf pill. Drop 1/2" ball & displace with 10 bbl of pill and KCL. Circulate 1.1 bpm @ 3220 psi. Aluminum ball on seat at 51.8 bbl (calculated 41.7). May have been hung in them check valves. On seat 2 bbl after surging well at 1 bpm. Creep up hole while pressuring up. Fired with 3100 psi @ 11100.7'. Twobblloss. 10:30 - 12:00 1.50 PERF P COMP POH .6/.25 bpm at 840 psi. @ 120fpm. No 12:00 - 13:30 1.50 PERF P COMP LD CSH tubing. 13:30 - 13:45 0.25 PERF P COMP PJSM for layiing down guns.( Sharp edges, overhead loads, Drips and leak containment) 13:45 - 15:00 1.25 PERF P COMP LD guns. All shots fired. 6 SPF. PERFORATED INTERVAL: 10,670 -11,100 FT BKB. 15:00 - 15:30 0.50 PERF P COMP Clear floor. 15:30 - 16:15 0.75 RUNCOtvP COMP PU WF 3-1/2" PB Liner top packer, 2.241" seal assembly and running tools. 16:15 - 18:45 2.50 RUNCOtvP COMP RIH to 8590'. Drop ball. Circulate ball close to seat. Stop pump and let steel ball fall to ball seat. 18:45 - 19:10 0.42 RUNCOtvP COMP RIH. Up Wt above liner top at 8682' = 28K. Tag at 8686'. Stack 8K wt. Pick up to 28K. Press up on ball seat with 4400 psi. Hold press. Bleed off to zero. Press to 4800 psi, bleed off, Press up to 4800 psi and sheared. Circ at lbpm at 1600 psi. RIH and stack 8K wt down. Packer is set with seal assembly fully stung into Baker liner deployment sleeve. 19:10-21:00 1.83 RUNCOtvP- COMP POH with WF running tools. 21 :00 - 21 :45 0.75 RUNCOrvP COMP Layout WF running tools. P/U WF seal assembly to press test Printed: 5/10/2004 9:22:09 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-29 02-29 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2004 Rig Release: 5/4/2004 Rig Number: N1 Spud Date: 2/26/1990 End: 5/4/2001 5/3/2004 21 :00 - 21 :45 0.75 RUNCOMP COMP 21 :45 - 23:30 1.75 RUNCOMP COMP 23:30 - 00:00 0.50 RUNCOMP COMP 5/4/2004 00:00 - 00:30 0.50 RUNCOMP COMP 00:30 - 01 :45 1.25 RUNCOMP COMP 01:45 - 02:15 0.50 RUNCOMP COMP 02: 15 - 02:30 0.25 RUNCOMP COMP 02:30 - 03:00 0.50 RIGD P POST 03:00 - 03:15 0.25 RIGD P POST 03:15 - 04:15 1.00 RIGD P POST 04:15 - 08:00 3.75 RIGD P POST 08:00 - 10:00 10:00 - 11 :00 2.00 BOPSUP P 1.00 BOPSUPP POST POST packer seal. WF presently uses a 2 run system for the 3-1/2" packer, because their one run system has not been reliable. BHA = 9 ft. RIH with WF seal assembly BHA. Sting into top of packer with seal and latch. Stack 5K down wt. Press test WF liner top packer with 2000 psi in CT x tbg ann. Lost 400 psi in 15 min. Press back up to 2000 psi and double block all valves. Pressure Test WF Liner top packer with seal assembly stung into packer. PT down CT x Tbg ann. 2000 psi at 0000 hrs, 500 psi at 0030 hrs. Failed Pressure test. All surface lines / valves checked. No visible leaks. Leak was comparable to leak seen during liner lap pressure test before setting liner top packer. Well has a known leak in the 9-5/8" casing at 9,345 ft. Possible tubing leak to IA. Pull free from liner top packer at 31 K, 26K up wt after pulling free from packer. Shear release set for 2100#, so seal assembly was set in liner top packer. POH. Freeze protect 4-1/2" tubing from 2000 ft to surface with 50/50 MEOH. Lay in 100% MEOH from 100' to surface. Close master and swab valves. Layout seal assy BHA. Top seal and spacer were missing. Possible source of leak. Seal could have been damaged when stinging out of top of packer. Seal assy has 4 seals and 3 spacers. 1.81" OD. Jet BOP stack with side jetting nozzle. Pump 40 bbls fresh water into 2" coil. Pump 10 bbls of MEOH. SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 into coil. Displace water from coil with N2. 1500 cfm, 1300 psi. Displace all off water and MEOH from coil. Coil to be re-used. Bleed down coil pressure. Clean rig pits. Cut off CTC. Pull end of 2" coil to reel and secure coil stub for reel swap. Changing back to 2-3/8" coiled tubing for next well. C/O CT packoff and brass for 2-3/8" CT. Prep reel to pick with Peak crane. Nipple down BOPE. RID hard line. Move tanks and trailers. N/U tree cap and pressure test. RELEASED RIG AT 1100 HRS, 05/04/2004. TOTAL OF 15 DAYS, 14.5 HOURS FROM RIG ACCEPT TO RIG RELEASE. MOVE RIG TO DS 02-24A. Printed: 5/10/2004 9:22:09 AM . . 20-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~Lf. - ()6L.- DEFINITIVE Re: Distribution of Survey Data for Well 2-29C Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,829.16' MD 0.00' MD 11 ,411 .00' M D (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 Date c¡ ",,1'VW.-2M V\ Signed 1Lk O,~! Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ~ ú'-f - \1Ç( e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 02 02-29A - 2-29C 2004 Job No. AKMW3030695, Surveyed: 30 April, Survey Report 18 May, 2004 e Your Ref: API 500292201103 Surface Coordinates: 5950336.46 N, 688488.90 E (70016' 08.7421" N, 148028' 32.1955" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4263 Surface Coordinates relative to Project H Reference: 950336.46 N, 188488.90 E (Grid) Surface Coordinates relative to Structure Reference: 1514.96 N, 886.88 E (True) Kelly Bushing Elevation: 63.00ft above Mean Sea Level Kelly Bushing Elevation: 63.00ft above Project V Reference Kelly Bushing Elevation: 63.00ft above Structure Reference Sp:E!ï'ï'Y-SUI! [) ""II... I...IN G "s Ei ""VI c'è s A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-29A - 2-29C Your Ref: API 500292201103 Job No. AKMW3030695, Surveyed: 30 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9829.16 91.050 349.530 8851.47 8914.47 1133.38 N 3006.17 E 5951544.77 N 691465.74 E 428.09 Tie-on Point 9856.88 80.770 345.490 8853.44 8916.44 1160.34 N 3000.20 E 5951571.56 N 691459.11 E 39.825 455.70 9886.20 85.080 340.220 8857.05 8920.05 1188.12 N 2991.63 E 5951599.12 N 691449.84 E 23.110 484.70 9915.59 91.490 337.760 8857.93 8920.93 1215.53 N 2981.10 E 5951626.26 N 691438.63 E 23.358 513.77 9947.57 95.540 337.230 8855.97 8918.97 1245.01 N 2968.88 E 5951655.43 N 691425.68 E 12.772 545.25 e 9981.94 101 .600 341.620 8850.85 8913.85 1276.80 N 2956.94 E 5951686.91 N 691412.94 E 21.685 578.91 10010.38 98.700 344.960 8845.84 8908.84 1303.61 N 2948.90 E 5951713.51 N 691404.23 E 15.414 606.84 10041.48 94.390 339.160 8842.29 8905.29 1332.98 N 2939.38 E 5951742.63 N 691393.98 E 23.134 637.60 10069.12 91.050 345.310 8840.98 8903.98 1359.26 N 2930.96 E 5951768.69 N 691384.90 E 25.295 665.10 10101.24 93.080 350.410 8839.82 8902.82 1390.63 N 2924.21 E 5951799.88 N 691377.37 E 17.079 697.18 10132.66 93.690 357.970 8837.96 8900.96 1421.81 N 2921.04 E 5951830.97 N 691373.42 E 24.097 728.28 10165.71 90.180 358.850 8836.85 8899.85 1454.82 N 2920.12 E 5951863.95 N 691371.68 E 10.948 760.65 10209.40 91.140 7.460 8836.34 8899.34 1498.40 N 2922.53 E 5951907.58 N 691372.99 E 19.828 802.57 10240.90 92.200 11.510 8835.42 8898.42 1529.45 N 2927.71 E 5951938.75 N 691377.39 E 13.285 831.66 10271.00 94.660 18.890 8833.62 8896.62 1558.43 N 2935.58 E 5951967.91 N 691384.54 E 25.801 858.12 10307.11 95.620 19.770 8830.39 8893.39 1592.36 N 2947.49 E 5952002.13 N 691395.59 E 3.600 888.51 10338.22 92.900 16.600 8828.08 8891.08 1621.83 N 2957.16 E 5952031.83 N 691404.52 E 13.404 915.05 10371.40 95.620 12.030 8825.61 8888.61 1653.88 N 2965.34 E 5952064.08 N 691411.90 E 15.995 944.43 10401.30 97.380 7.290 8822.22 8885.22 1683.16 N 2970.33 E 5952093.47 N 691416.15 E 16.814 971.84 10441.55 91 .930 7.990 8818.96 8881. 96 1722.90 N 2975.66 E 5952133.34 N 691420.49 E 13.651 1009.37 10474.78 91.320 7.110 8818.02 8881.02 1755.83 N 2980.03 E 5952166.36 N 691424.02 E 3.221 1040.47 e 10511.08 92.200 2.720 8816.90 8879.90 1791.97 N 2983.14 E 5952202.57 N 691426.23 E 12.329 1074.98 10547.50 90.530 6.410 8816.03 8879.03 1828.26 N 2986.03 E 5952238.92 N 691428.21 E 11.118 1109.69 10580.88 89.470 357.790 8816.03 8879.03 1861.58 N 2987.25 E 5952272.26 N 691428.60 E 26.018 1141.88 10617.87 92.460 359.020 8815.41 8878.41 1898.55 N 2986.23 E 5952309.19 N 691426.65 E 8.740 1178.13 10648.87 96.240 355.510 8813.06 8876.06 1929.41 N 2984.75 E 5952340.01 N 691424.40 E 16.616 1208.54 10680.37 99.930 346.720 8808.62 8871.62 1960.19 N 2979.95 E 5952370.66 N 691418.83 E 30.003 1239.61 10710.63 97.030 345.840 8804.16 8867.16 1989.26 N 2972.85 E 5952399.54 N 691411.01 E 10.006 1269.53 10747.86 94.660 339.690 8800.36 8863.36 2024.61 N 2961.88 E 5952434.61 N 691399.15 E 17.622 1306.45 10790.10 91.850 341.100 8797.96 8860.96 2064.34 N 2947.74 E 5952473.97 N 691384.02 E 7.440 1348.33 10836.59 91.320 346.720 8796.68 8859.68 2108.97 N 2934.86 E 5952518.26 N 691370.03 E 12.138 1394.72 10877.53 93.950 353.580 8794.79 8857.79 2149.24 N 2927.87 E 5952558.34 N 691362.03 E 17.928 1435.52 10911.58 90.770 6.910 8793.38 8856.38 2183.18 N 2928.02 E 5952592.27 N 691361.33 E 40.210 1468.56 10940.29 90.530 359.380 8793.06 8856.06 2211.82 N 2929.59 E 5952620.95 N 691362.18 E 26.239 1496.12 10974.18 93.080 356.560 8791.99 8854.99 2245.67 N 2928.39 E 5952654.75 N 691360.14 E 11.215 1529.36 18 May, 2004 - 14:11 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-29A - 2-29C Your Ref: API 500292201103 Job No. AKMW3030695, Surveyed: 30 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11005.59 93.600 355.680 8790.16 8853.16 2276.95 N 2926.27 E 5952685.97 N 691357.23 E 3.250 1560.32 11044.00 91.850 348.130 8788.33 8851.33 2314.91 N 2920.87 E 5952723.78 N 691350.88 E 20.155 1598.52 11071.71 93.430 350.590 8787.06 8850.06 2342.11 N 2915.76 E 5952750.85 N 691345.09 E 10.543 1626.18 11102.31 90.610 346.720 8785.98 8848.98 2372.08 N 2909.74 E 5952780.66 N 691338.33 E 15.641 1656.74 e 11133.40 90.880 354.450 8785.57 8848.57 2402.73 N 2904.66 E 5952811.17 N 691332.48 E 24.876 1687.74 11185.36 88.770 358.500 8785.73 8848.73 2454.57 N 2901.47 E 5952862.92 N 691327.99 E 8.788 1738.98 11227.12 90.530 3.070 8785.99 8848.99 2496.32 N 2902.04 E 5952904.67 N 691327.52 E 11.726 1779.52 11274.77 91.230 9.570 8785.25 8848.25 2543.65 N 2907.28 E 5952952.11 N 691331.57 E 13.718 1824.46 11299.87 90.090 15.550 8784.96 8847.96 2568.13 N 2912.74 E 5952976.73 N 691336.41 E 24.252 1847.09 11332.74 87.010 21.880 8785.80 8848.80 2599.24 N 2923.27 E 5953008.08 N 691346.17 E 21.409 1875.02 11369.34 84.110 24.860 8788.63 8851.63 2632.73 N 2937.74 E 5953041.93 N 691359.79 E 11 .343 1904.40 11395.54 83.320 29.080 8791.50 8854.50 2655.93 N 2949.55 E 5953065.42 N 691371.02 E 16.291 1924.35 11411.00 83.320 29.080 8793.30 8856.30 2669.35 N 2957.01 E 5953079.02 N 691378.14 E 0.000 1935.75 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 347.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11411.00ft., The Bottom Hole Displacement is 3983.64ft., in the Direction of 47.927° (True). e 18 May, 2004 - 14:11 Page 3 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-29A - 2-29C Your Ref: API 500292201103 Job No. AKMW3030695, Surveyed: 30 April, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9829.16 11411.00 8914.47 8856.30 1133.38 N 2669.35 N 3006.17 E Tie-on Point 2957.01 E Projected Survey e Survey tool program for 02-29A - 2-29C From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9241.70 0.00 9241.70 8540.86 11411.00 8540.86 BP High Accuracy Gyro (02-29A) 8856.30 MWD Magnetic (2-29CPB1) e 18 May, 2004 - 14:11 Page 4 of 4 DrillQuest 3.03.06.002 . . 20-May-04 ~OCj. -- ð sf AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2-29C PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,241.70' MD 9,244.00' MD 10,872.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 Date Cf JVrLÀM ~ Signed ~.ð~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ),0'1-0)( Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 02 02-29A - 2-29CPB1 e Job No. AKMW3030695, Surveyed: 26 April, 2004 Survey Report 18 May, 2004 Your Ref: API 500292201170 Surface Coordinates: 5950336.46 N, 688488.90 E (70016' 08.7421" N, 148028' 32.1955" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 950336.46 N, 188488.90 E (Grid) Surface Coordinates relative to Structure Reference: 1514.96 N, 886.88 E (True) Kelly Bushing Elevation: 63.00ft above Mean Sea Level Kelly Bushing Elevation: 63.00ft above Project V Reference Kelly Bushing Elevation: 63.00ft above Structure Reference spe..........y-sul! DAILLINGSERVICeS « '" """UN A Halliburton Company Survey Ref: svy4262 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-29A - 2-29CPB1 Your Ref: API 500292201170 Job No. AKMW3030695, Surveyed: 26 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) 9241.70 11.680 71.770 8477.86 8540.86 838.35 N 3152.62 E 5951253.49 N 691619.54 E 107.67 Tie-on Point MWD Magnetic 9244.00 11 .680 71.770 8480.11 8543.11 838.49 N 3153.06 E 5951253.65 N 691619.98 E 0.002 107.72 Window Point 9276.11 23.910 66.470 8510.63 8573.63 842.12 N 3162.15 E 5951257.50 N 691628.97 E 38.382 109.21 e 9312.14 21.370 63.170 8543.88 8606.88 848.00 N 3174.70 E 5951263.69 N 691641.37 E 7.880 112.11 9342.66 17.580 32.250 8572.73 8635.73 854.43 N 3182.15 E 5951270.31 N 691648.65 E 35.502 116.70 9372.49 18.460 2.720 8601.15 8664.15 862.97 N 3184.78 E 5951278.91 N 691651.07 E 30.452 124.43 9403.32 23.030 340.570 8630.02 8693.02 873.56 N 3183.00 E 5951289.45 N 691649.03 E 29.204 135.15 9436.35 24.780 320.880 8660.26 8723.26 885.04 N 3176.48 E 5951300.77 N 691642.22 E 24.618 147.80 9467.64 27.770 304.010 8688.36 8751.36 894.22 N 3166.28 E 5951309.69 N 691631.79 E 25.611 159.04 9498.46 33.490 294.160 8714.88 8777.88 901.73 N 3152.55 E 5951316.85 N 691617.88 E 24.638 169.45 9529.93 40.780 299.080 8739.96 8802.96 910.29 N 3135.62 E 5951324.98 N 691600.74 E 24.998 181.60 9560.75 46.230 307.520 8762.32 8825.32 921.98 N 3117.97 E 5951336.23 N 691582.80 E 25.819 196.96 9595.22 51.940 314.730 8784.91 8847.91 939.13 N 3098.43 E 5951352.89 N 691562.84 E 22.879 218.07 9633.80 57.660 322.810 8807.16 8870.16 962.85 N 3077.74 E 5951376.08 N 691541.57 E 22.626 245.83 9668.82 65.740 325.630 8823.75 8886.75 987.86 N 3059.76 E 5951400.63 N 691522.96 E 24.134 274.24 9707.20 74.710 332.130 8836.74 8899.74 1018.76 N 3041.17 E 5951431.05 N 691503.61 E 28.275 308.53 9736.68 79.450 335.470 8843.33 8906.33 1044.53 N 3028.50 E 5951456.50 N 691490.29 E 19.504 336.49 9768.11 82.090 344.430 8848.38 8911.38 1073.64 N 3017.88 E 5951485.34 N 691478.95 E 29.362 367.25 9798.01 87.540 350.760 8851.08 8914.08 1102.70N 3011.50 E 5951514.23 N 691471.84 E 27.864 397.00 9829.16 91.050 349.530 8851.47 8914.47 1133.38 N 3006.17 E 5951544.77 N 691465.74 E 11.940 428.09 9864.34 93.600 354.280 8850.04 8913.04 1168.17 N 3001.22 E 5951579.42 N 691459.93 E 15.314 463.10 e 9913.13 90.700 0.430 8848.21 8911.21 1216.85N 2998.97 E 5951628.02 N 691456.46 E 13.927 511.04 9957.36 89.210 4.830 8848.24 8911.24 1261.02 N 3001.00 E 5951672.23 N 691457.38 E 10.503 553.62 9987.65 86.750 3.420 8849.31 8912.31 1291.21 N 3003.18 E 5951702.47 N 691458.80 E 9.359 582.54 10035.30 89.120 9.220 8851.03 8914.03 1338.51 N 3008.42 E 5951749.89 N 691462.86 E 13.141 627.46 10071.30 88.330 12.030 8851.83 8914.83 1373.88 N 3015.06 E 5951785.41 N 691468.61 E 8.106 660.43 10102.50 89.210 10.800 8852.50 8915.50 1404.46 N 3021.23 E 5951816.13 N 691474.01 E 4.847 688.83 10133.70 94.040 8.520 8851.61 8914.61 1435.19 N 3026.46 E 5951846.99 N 691478.47 E 17.117 717.60 10169.90 94.390 4.830 8848.95 8911.95 1471.04 N 3030.66 E 5951882.93 N 691481.77 E 10.212 751.59 10206.70 92.990 3.770 8846.58 8909.58 1507.66 N 3033.41 E 5951919.61 N 691483.61 E 4.768 786.65 18 May, 2004 - 14:05 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-29A - 2-29CPB1 Your Ref: API 500292201170 Job No. AKMW3030695, Surveyed: 26 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10258.90 97.400 357.320 8841 .85 8904.85 1559.60 N 3033.91 E 5951971.55 N 691482.81 E 14.924 837.15 10324.10 94.040 352.700 8835.35 8898.35 1624.21 N 3028.27 E 5952035.99 N 691475.54 E 8.732 901.37 10376.10 90.440 351 .290 8833.32 8896.32 1675.65 N 3021.03 E 5952087.24 N 691467.02 E 7.434 953.12 10409.70 92.810 345.670 8832.37 8895.37 1708.54 N 3014.33 E 5952119.95 N 691459.50 E 18.145 986.68 10448.50 96.590 340.220 8829.19 8892.19 1745.49 N 3003.00 E 5952156.61 N 691447.25 E 17.053 1025.23 e 10483.40 92.550 339.340 8826.41 8889.41 1778.13 N 2990.98 E 5952188.93 N 691434.41 E 11 .846 1059.73 10516.50 90.260 346.190 8825.59 8888.59 1809.71 N 2981.18 E 5952220.26 N 691423.83 E 21.813 1092.71 10547.60 89.910 345.840 8825.55 8888.55 1839.89 N 2973.66 E 5952250.24 N 691415.56 E 1.592 1123.81 10576.80 93.340 348.830 8824.72 8887.72 1868.36 N 2967.26 E 5952278.54 N 691408.45 E 15.579 1152.99 10609.30 91.930 355.680 8823.22 8886.22 1900.51 N 2962.89 E 5952310.57 N 691403.27 E 21.496 1185.30 10647.20 89.740 358.150 8822.67 8885.67 1938.35 N 2960.85 E 5952348.35 N 691400.29 E 8.709 1222.62 10678.80 89.120 358.500 8822.98 8885.98 1969.93 N 2959.93 E 5952379.90 N 691398.57 E 2.253 1253.60 10708.80 86.750 359.730 8824.07 8887.07 1999.91 N 2959.47 E 5952409.85 N 691397.36 E 8.899 1282.92 10734.90 85.430 4.120 8825.85 8888.85 2025.93 N 2960.34 E 5952435.88 N 691397.58 E 17.526 1308.07 10765.80 84.990 2.890 8828.43 8891.43 2056.66 N 2962.22 E 5952466.65 N 691398.69 E 4.215 1337.59 10801.10 88.420 359.730 8830.46 8893.46 2091.88 N 2963.03 E 5952501.88 N 691398.61 E 13.201 1371.73 10832.60 91.050 357.440 8830.60 8893.60 2123.37 N 2962.25 E 5952533.34 N 691397.05 E 11.070 1402.58 10872.00 91.050 357.440 8829.88 8892.88 2162.72 N 2960.49 E 5952572.64 N 691394.30 E 0.000 1441.33 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. e The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 347.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10872.00ft., The Bottom Hole Displacement is 3666.31ft., in the Direction of 53.8510 (True). 18 May, 2004 - 14:05 Page 3 of 4 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 . 02-29A - 2-29CPB1 Your Ref: API 500292201170 Job No. AKMW3030695, Surveyed: 26 April, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) Comment 9241.70 9244.00 10872.00 8540.86 8543.11 8892.88 838.35 N 838.49 N 2162.72 N 3152.62 E 3153.06 E 2960.49 E Tie-on Point Window Point Projected Survey e Survey tool program for 02-29A - 2-29CPB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9241.70 0.00 9241.70 8540.86 10872.00 8540.86 BP High Accuracy Gyro (02-29A) 8892.88 MWD Magnetic (2-29CPB1) e 18 May, 2004 - 14:05 Page 4 of 4 DrillQuest 3.03.06.002 CrN GEN 4 WELLHEAD = CrN 62' Datum TVD = 900' 102 @ 9982: 9570' 8800' SS \13-3/8" CSG, 68#, H K-55, ID'" 12.415" J TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 113-3/8" CSG, 68#, ID = 12.415" H Minimum ID of 1.54" at 8682 ft in WF Liner top Packer seal assembly. TOPOF7" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" 104' 3011' 3923' 8683' I 8740' I 19-518" CSG, 47#, L-80, 10'" 8.681" l-i 8999' -f Old Cement top 9356' PERFORA TION SUMMARY REF LOG: SWS MCNL 1 GR 1 CCL OF 05/03/04 ANGLE AT TOP PERF: 96 @ 10,670' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sq;¡:: DATE 1.56" 6 10670 -11100 I 7" LNR, 29#, L-80, 9680' I . - l ç-¡" 2239' 1-14-1/2" PORT 3011' -f4-1/2" X 3-112" xol GAS LIFT MANDRELS MD TVD DEV VLV 1 3361 3211 27 MMG RK 2 4564 4265 29 MMG RK 3 5669 5254 26 MMG RK 4 6802 6277 26 MMG RK 5 7137 6579 26 MMG RK 6 7723 7103 27 MMG 7 8057 7403 24 MMG I STI MD I TVD DSlI·t· VLV ..lATCHiPORT[> DATE I 1 854878621 16MMGLTSROOME .RK<O.18805/14/90 1 ... 8633' 8636' 8740' I 9370' !-iTOP of )-1 0.0371 bpf, 10 = 6.184" 1--1 9791' ~-i10486' I DATE 02/26/90 01/02/01 02/14/01 02/02/02 10/07/03 RSI BY COMMENTS ORIGINAL COMPLETION SIS-SLT CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS MSE Proposed CTD sidetrac.k DATE REV BY COMMENTS 05/04/04 RRW eTD Hori:zontal Sidetrack 9450' 9556' SEe . (ill . ®- {~1~ IlÙ ~¿~~ FRANK H. MURKOWSKI. GOVERNOR A.I',ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 02-29C BP Exploration (Alaska) Inc. Permit No: 204-051 Surface Location: 887' SNL, 1740' EWL, SEC. 36, TllN, R14E, UM Bottomhole Location: 1540' NSL, 4536' EWL, SEC. 25, T11N, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you fÌ'om obtaining additional permits or approvals required by law fÌ'om 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission t ness any required test. Contact the Commission's North Slope petroleum field in ctor 3607 (pager). BY ORDER ºf THE COMMISSION DA TED this~day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 887' SNL, 1740' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 56' SNL, 1740' EWL, SEC. 36, T11N, R14E, UM Total Depth: 1540' NSL, 4536' EWL, SEC. 25, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688489 y- 5950336 Zone- ASP4 16. Deviated Wells: Kickoff Depth 1~;Cas¡ng.··Prògrarri Size CasinQ 2-3/8" . STATE OF ALASKA I ALAS~OIL AND GAS CONSERVATION C MMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory II Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 02-29C / 6. Proposed Depth: 12. Field I Pool(s): MD 11150 TVD 8805 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028308 v.J C:,A- "'S i z. ~{'¿CI(!1tf 1 9. 8. Land Use Permit 13. Approximate Spud Date: April 8, 2004 / 14. Distance to Nearest Property: 30,000' 9. Acres in Property: 2560 Maximum Hole Angle 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 63' feet 2-09A is 655' away at 10886' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 psig Surface: 2420 rpsig 9250 ft 940 Hole 3" WeiQht 4.6# Grade L-80 CouplinQ LenQth STL 2466' MD 8684' TVD MD TVD (includinQ staQe data) 7931' 11150' 8805' 58 sx Class 'G' 7 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD 10707 8873 NIA 10707 8873 Structural Conductor 112' 20" 2150# Poleset 112' 112' Surface 3923' 13-3/8" 2000 sx CS III, 600 sx 'G', Top Job: 250 sx CSII 3923' 3704' Intermediate 9099' 9-518" 450 sx Class 'G' 9099' 8401' Production liner 1108' 7" 250 sx Class 'G' 8683' - 9443' 7993' - 8738' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): None 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 181 20 AAC 25.050 Requirements Date: Contact Thomas McCarty, 564-4378 Perforation Depth MD (ft): None 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer Phone IAPI _Number: Zo ~ - ðS / 50- 029-22011-03-00 Conditions of Approval: Samples Required Hydr n Sulfide Measures . DO P ~/ . Approved Form 10-401 DYes ,gNO ~es 0 No Permit Approval Date: Mud Log Required Directional Survey Required See cover letter for other requ~'rements ...g Yes No ~ Yes No BY ORDER OF THE COMMISSION Date34t lad %~'% ~ &Plicate OR'G'~LÄL . . BP 2-29C Sidetrack Summary of Operations: We1l2-29B is scheduled for a through tubing sidetrack with the SLB/Nordic 1 CTD rig. The sidetrack, 2- 29C, will exit"OMt'.ef1he existing 7" liner from a cement ramp and target Zone 1 reserves. The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) 1) Slickline -Drift tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. 2) CTV- Pump 17ppg Cement plug 3/11/04 CTD Sidetrack Summary (phase 2) 1) MIRV CTD rig. 2) Mill 2.74" OD window at approx 9250' md off cement ramp 3) Drill 3" OR sidetrack to -11150' TD with MWD/gamma ray. 4) Run memory CNLlCCLlGR in OR 5) Run 2-3/8" liner co plêf n. Top of liner will be at approx 8684' md in 3 Y2" tubing 6) Cement liner wi 12 s of 15.8 ppg cement. 7) Perforate. 8) RDMO. /' Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2: 8.6 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. / Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · A 23/8" solid cemented liner completion from 8684' to TD at 11150'. The liner cement volume is planned to be -12 bbls of 15.8 ppg class G. Perforate liner as per Asset instructions. Parent Well Casings 90/." 47#, L-80 7" 29#, L-80 Burst (psi) 6870 8160 Collapse (psi) 4760 7020 / Sidetrack Casings 2-3/8" 4.6#, L-80, STL - Prod LNR 11200 11780 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. / Directional · See attached directional plan. Max. planned hole angle is 94 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 2-29C will be approx 655' ctr-ctr away from well 2-09A at 10886'md (nearest BHL). · 2-29C will be approx 30,000' from the unit boundary, (Prudhoe Bay Unit). Logging · MWD Gamma Ray log will be run over all of the open hole section. · A memory CNL/GR/CCL open hole log is planned prior to running the liner. . . Hazards .,.- . DS 2 is...!lQt considered an H2S pad. No H2S measurements have been taken for well 2-29B (it has never produced). The max recorded H2S was on the parent well 2-29 at 100ppm in 1992. All H2S monitoring equipment will be in use. · One small 10' throw fault is predicted. Lost circulation risk is considered "low". . Shale instability is expected in the target. Reservoir Pressure · Res. press. is estimated to be 3300 psi at 88oo'ss (7.2 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2420 psi. ,,/ . lREE = OW GEN 4 WELLI-EA D = OW AClUA TOR = AXELSON i<B: ELBi= ··-62' BF. ELEV = NA KOP= 900' MJx .An~le = 29 @ 3600' Datum IvD = 9570' Datum TV D = 8BOO'SS 113-318" CSG, 68#, K-55, ID = 12.415" H 4-1/Z' IFC ìBG, 12.6#, L-BO, BTC MOD, H .0152 bpf, ID = 3.958" I 113-318" CSG, 68#, L-BO, ID = 12.415" H 104' 3011' 3923' . 02-298 SAÆTY NOTES: REDRlLL NOT SIDETRACKED, 9-5/8" CSG LEAK LDL 06122/03, OA DOWNSOZ'D 07/31/03 *OPEN HOLE= 9443' -10707' WIO LNR* ~, ~ . 2239' H4-1/Z'AVATRSV,ID=3.813" 1 L - ,/ ~ 3011' H4-1/Z'X3-1/2"XO1 GAS LIFT MANDRELS ·ST IvD TVD DEV TYPE VLV LATCH PORT ()II.1E 1 3361 3211 27 MM3 RK ..1. 2 4564 4265 29 MM3 RK . 3 5669 5254 26 MM3 RK 4 6B02 6277 26 MM3 RK 5 7137 6579 26 MM3 RK 6 7723 7103 27 MM3 RK 7 8057 7403 24 MM3 RKP CI-EMCA L MANDRB-.S ISTIIvD I TVDIDEVI TYPE I VLV ILATCH PORT ()II.1E I 8 8548 7862 16 MM3L TSR DOllIE RK - 05114190 LlõAK IN 9-518" H 6345' r-- Minimum ID = 2.992" @ 8740' 3-1/2" TUBING 13-1/2" TOO, 9.3#, L-80, .0087 bpf, ID = 2.992" H 19-518" CSG, 47#, L-80, ID = 8.681" H I TOP OF GMT AND START OF 2.74" H PILOTHOLE FOR CMT RA I'vP EXIT I· TOPOF2" COIL FISH - BHÞ. 52' X 2.70" I\MX OD H I." 8740' I J 9099' ~ 9355' 9375' PERFORATION SlJI,1l\M RY REF LOG: SWS ŒT ON 03/13190 ANGLEATTOPPffiF: 11@9631' I\bte: Refer to A"oductbn œ for historical perf data SIZE SA" INTffiVAL Opn/Sqz DATE 2-118" 4 9631 - 9646 S ffiOFQSED 2-518" 4 9664 - 9668 S ffiOFQSED 2-518" 4 9671 - 9682 S ffiOFQSED I FBTD H 17" LNR. 29#, L-BO, BTC, .0371 bpf, ID = 6.184" H I TD H 9680' 9791' 10486' - .:.......b J k H3-1/Z' BAKffi LOCSEAL ASSY I H 9-5/8" X 3-1/2" SA KER MODEL D PKR 1 H3-1/Z' BAKffi MLLOUT EXT, D = 6.00" I 8633' 8636' 8655' II 8683' HTOP OF 7' LNRBAKERHYDRO IIHGR 8727' H3-1/2" 011S XN NIP, MILLED TO ID = 2.80" 8739' H 3-1/2" BAKER Sl-EAR OUT SUB I 8740' H 3-1/2"TOO TAIL W/WLB31 8719' H ELMDTT LOGGED 04/26/90 1 \ ~ ¡ WINDOW 9443' - 9450' I OÆN I-OLE 18" erc EXT CSG A<R H H 10707' 1 DATE REV BY COM\o1ENTS ()II. TE REV BY 02/26/90 ORIGINAL COMPLETION 10/07/03 TM I\VTLP SUSPEtÐEDCTDSICETRACK COM\o1ENTS ffiLDHOE SA Y UI\IT WELL: 02-29B PERMrrNo: 2031460 AR No: 50-029-22011-01 Sa::; 36, T11 N, R14E, 161.2Z FB.. & 5259' FNL BP Exploration (Alas k a) TREE = WELLHEAD = ACTUATOR = , ,.~..,..~~~w.w KB. ELEV = BF. ELEV = ~ .W....M~.~~~~~w~~~_w~.~.w~ < KOP = 900' Max Angle = 29 @ 3600' ".. ~..,~.,,~~w.~w<_..~_.~___~, Datum MD = 9570' Datum TVD = 8800' SS . CrN GEN 4 CrN AXELSON 62' 113-3/8" CSG, 68#, 1-1 K-55, ID = 12.415" 4-112" IPC TBG, 12.6#, L-80, BTC MOD, 0.0152 bpf, ID = 3.958" 3011' 113-3/8" CSG, 68#, L-80, ID = 12.415" H 3923' I LEAK IN 9 5/8" H TOPOF7" LNRBAKERHYDRO II HNGR H 8683' 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" H 8740' 19-5/8" CSG, 47#, L-80, ID = 8.681" H 8999' TOP of Cerrent H 9075' I Old Cerrent top H 9356' PERFORATION SUMMARY REF LOG: SWS GET ON 03/13/90 ANGLE AT TOP PERF: 11 @ 9631' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 4 9631-9646 sqzd proposed 2-5/8" 4 9664-9668 sqzd proposed 2-5/8" 4 9671-9682 sqzd proposed I PBTO H 9680' 17" LNR, 29#, L-80, BTC, 0.0371 bpf,ID=6.184" H 9791' ~-I 10486' I DATE 02/26/90 01/02/01 02/14/01 02/02/02 10/07/03 REV BY COMMENTS ORIGINAL COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS MSE Proposed CTD sidetrack 3011' 1-f4-1/2" X 3-1/2" XO I GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 27 MMG RK 29 MMG RK 26 MMG RK 26 MMG RK 26 MMG RK 27 MMG RK 24 MMG RKP CHEMICAL MANDRELS IST MD I TVDI DEVI TYÆ I VLV ILATCH PORTI DATE I 1 8548 7862 16 MMGL TSR DOME RK 0.188 05/14/90 02-29 . Proposed CTD Sidetrack 104' I~ 1 I~ r'¡1 ffi L 1- :", !], ~I -- I -g ~~ J ~..k.C.: ''''' :~ 6345' 1-\ - c J~ g--~ r .4 ~ 2239' ST MD TVD 1 3361 3211 2 4564 4265 3 5669 5254 4 6802 6277 5 7137 6579 6 7723 7103 7 8057 7403 8633' 8636' 8655' 8684' 8727' 8739' 8740' 8719' SAFETY NOTES: REDDRlLL NOT SIDETRACKED. 9 5/8" eSG LK LDL 6/22/03,OA DOWNSQZD 7/31103 H4-1/2" AVA TRSV, ID = 3.813" I -f3-1/2" BAKER LOC SEAL ASSY I \-f9-5/8" X 3-1/2" BAKER MODEL D A<R 1-13-1/2" BAKER MILLOUT EXT 10=6" I I 1 Top of 2-3/8" Liner I -f3-1/2" OTIS XN NIP, mìlled to ID:: 2.80" I l-f 3-1/2" BAKER SHEA R OUT SUB 1 -13-1/2" TUBING TAIL WIWLEG 1 -f ELMD TT LOGGED 04/26/90 1 HTop of P&A i KO cerrent plug H Cerrent Ramp Liner Exit 1 /' 1 2-3/8" cerrented & perforated liner H 11150' 1 / 9370' I~op of fish I )-i 10706' HOpenhole TO I 9450' 1-1 Cerrent ramp window 9556' H 8" CTC EXTERNAL CSG A<R I DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 02-298 ÆRMIT No: 203-146 API No: 50-029-22011-01 SEe 36 T11N R14E 161.22 FEL 5259 FNL BP Exploration (Alaska) BP Amoco WELLPATH DETAILS Plan.1' 02-2.C 500212201103 ...,."tW.llJlathl 02-2'A Tle.a MOl 1241.70 Rig. 11 21112211... 00;00 '3.0Oft R",Da..r'" V.s.ctlon Origin ~~= ::::';t,D AnIle ON,.. 347.00' 0.00 0.00 33.00 REFERENCE INFORMATION Co-V~d~r:r ~6~ ~:~:~g~~ ~~e~~~:~~2S;~ALe~~e North Section (VS) Reference: Slot· 29 (O.DON,a.DOE) Measured Depth Reference: 57: 291122/1990 00:00 63.00 Calculation Method: Minimum Curvature Plan: Plan #16 (02-29NPlan#16 02-29C) Created By: Brij Potnis Cnnt8Ct Jn1orrnaUor:: Bai<.er Huøhes Azimuths to True North Magnetic North: 25.43' Magnetic Field Strength: 57595nT Dip Angle: 80.86' Date: 3/9/2004 Model: bggm2003 T I\M f é g~=~~~ ~g~=~~~~ Plan#1602-29C . . ....21 00· C ~2001 o ~1901 .... +180 ..... .s: 1:: 1701 o l!!!: 1601 - I :ë1501 .... ::J 01401 en 301 T..... "- = æ ~ """' """' SECTtoN DETAILS TVD +fU.a +£I.W OU. TFace vaec !ªä ª!~ ¡¡¡~¡¡ ~:!¡ !§¡¡¡ ¡~i :=::: 1:::= ~~:~~ ~:gg 27J:gg ;;H~ 8846.07 1340.88 3&40.58 12.00 90.00 822,.5. ::: 1m;: == !i:: ~!::: 15Hi 8826.52 17t1a.ez 21I94.1e 12.00 85.00 1048.75 ::~;:;I ~=~:: I:~::~ U::: 28J:gg UU:l~ ·.9170 2~'1714 2701.7' 1~ 271\09.719.1' TARGETOETAlL$ Name 'JVO +NI-S +EPN ~--29CF-..I11 0.00 1698.43 287MO liiª1 i:i ~~:~ ~1i ~--29CFau/l7 0.00 1898.133891.88 ~~g~16.2 &:88 1m:~ ~m:~ 02-29CT16.5 8805.00 2430.05 2784.711 02~T16.4 8817.002024.302926.68 02~9CT18.3 6830.00 1724.51 299320 02-29CT16.2 8845.00 1410.30 3039.~ 02-29CT16.1 8849.00 1112.13 3042.39 ,,""ot.tlo. .., KO' 3 · · · T · · " 11 1Z U .. T' See MD Ine Azl 1 8241.70 1'.ea 71.77 ~ =:~= ~;:~: ~:~: : ~~5 ~i:;! 3~!; ~ ::::: ::~: =:~~ ¡ijf~H¡ ª!! ~i! ~: ~::.::~ :::; ~;:: ,.,11.0.... 01.7::1 ....~" ANNOTATIONS TVD MD 1477." 1241.70 I4IUI, 12$0.00 '41'.$4 1284.00 '545.'. .314.00 ISIO." U...OO "37.84 .414.00 1707.'2 141'.00 ......1. .71..07 1148.07 1001..07 1144.71 10143.07 113..67 102'..07 .121.'2 10403.07 ::~:.:~ ~:~l·~~ 1.12.70: 10.0..07 '104.7111110.00 i' I ' ii, , " . i 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 31"00 3200 33"00 3400 3500 3600 3700 3800 3900 4000 41"00 4200 43"00 2:20 PM 3/10/2004 "'1 750 800 Vertical Section at 347.00' [50ft/in] 1800 1700 600 ....8400 C ~8450 o II) 8500··· .... :5 8500-: Co GI . CI 8600 '5 86W-: i 8700- > GI 875~ 2 m ... 8800-:: 8800-:: 1 1 . BP-GDB Baker Hughes INTEQ Planning Report . Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northiug: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638.44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: 53.847 N 58.060 W True 1.43 deg Well: 02-29A Slot Name: 02-29A Well Position: +N/-S 1514.17 ft Northing: 5950336.13 ft Latitude: +E/-W 888.73 ft Easting: 688489.10 ft Longitude: Position Uncertainty: 0.00 ft 29 70 16 8.739 N 148 28 32.190W Wellpath: Plan#1602-29C 500292201103 Current Datum: 57 : 29 1/22/199000:00 Magnetic Data: 3/9/2004 Field Streugth: 57595 nT Vertical Section: Depth From (TVD) ft 33.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-29A 9241.70 ft Mean Sea Level 25.43 deg 80.86 deg Direction deg 347.00 Height 63.00 ft Targets 02-29C Fault 1 0.00 1698.43 2878.50 5952106.00 691324.00 70 16 25.437 N 148 27 8.380 W -Polygon 1 0.00 1698.43 2878.50 5952106.00 691324.00 70 16 25.437 N 148 27 8.380 W -Polygon 2 0.00 1803.39 3241.27 5952220.00 691684.00 70 16 26.468 N 148 26 57.817 W -Polygon 3 0.00 1911.45 3440.05 5952333.00 691880.00 70 16 27.530 N 148 26 52.028 W -Polygon 4 0.00 1803.39 3241.27 5952220.00 691684.00 70 16 26.468 N 148 26 57.817 W 02-29C Fault 2 0.00 1680.37 2241.81 5952072.00 690688.00 70 16 25.262 N 148 2726.918 W -Polygon 1 0.00 1680.37 2241.81 5952072.00 690688.00 70 16 25.262 N 148 2726.918 W -Polygon 2 0.00 1653.41 2519.24 5952052.00 690966.00 70 16 24.996 N 148 27 18.841 W -Polygon 3 0.00 1424.70 2863.64 5951832.00 691316.00 70 16 22.745 N 148 27 8.816 W -Polygon 4 0.00 1653.41 2519.24 5952052.00 690966.00 70 16 24.996 N 148 27 18.841 W 02-29C Fault 3 0.00 1814.22 2569.29 5952214.00 691012.00 70 16 26.577 N 148 27 17.382 W -Polygon 1 0.00 1814.22 2569.29 5952214.00 691012.00 70 16 26.577 N 148 27 17.382 W -Polygon 2 0.00 1820.25 2887.56 5952228.00 691330.00 70 1626.635 N 148 27 8.115 W 02-29C Fault 6 0.00 2308.36 2251.54 5952700.00 690682.00 70 16 31.438 N 148 27 26.629 W -Polygon 1 0.00 2308.36 2251.54 5952700.00 690682.00 70 16 31.438 N 148 27 26.629 W -Polygon 2 0.00 2033.70 2353.70 5952428.00 690791.00 70 16 28.737 N 148 27 23.657 W 02-29C Fault 5 0.00 2416.91 2590.39 5952817 .00 691018.00 70 16 32.505 N 148 27 16.762 W -Polygon 1 0.00 2416.91 2590.39 5952817.00 691018.00 70 16 32.505 N 148 27 16.762 W -Polygon 2 0.00 2168.85 2629.19 5952570.00 691063.00 70 16 30.065 N 148 27 15.634 W 02-29C Fault 4 0.00 2469.90 3070.89 5952882.00 691497.00 70 16 33.024 N 148 27 2.769 W -Polygon 1 0.00 2469.90 3070.89 5952882.00 691497.00 70 16 33.024 N 148 27 2.769 W -Polygon 2 0.00 2330.84 3430.55 5952752.00 691860.00 70 16 31.655 N 148 26 52.299 W 02-29C Fault 7 0.00 1898.13 3891.88 5952331.00 692332.00 70 16 27.397 N 148 26 38.872 W -Polygon 1 0.00 1898.13 3891.88 5952331.00 692332.00 70 16 27.397 N 148 26 38.872 W -Polygon 2 0.00 2427.53 4243.27 5952869.00 692670.00 70 16 32.602 N 148 26 28.632 W . . BP-GDB Baker Hughes INTEQ Planning Report Targets 02-29C Polygon16.2 0.00 957.99 2924.98 5951367.00 691389.00 70 16 18.155 N 148 27 7.035 W -Polygon 1 0.00 957.99 2924.98 5951367.00 691389.00 70 1618.155N 148 27 7.035 W -Polygon 2 0.00 1876.74 2748.92 5952281.00 691190.00 70 16 27.192 N 148 27 12.151 W -Polygon 3 0.00 2302.89 2669.56 5952705.00 691100.00 70 1631.383N 148 27 14.457 W -Polygon 4 0.00 2652.32 2737.34 5953056.00 691159.00 70 16 34.819 N 148 27 12.480 W -Polygon 5 0.00 2683.92 3033.24 5953095.00 691454.00 70 16 35.129 N 148 27 3.863 W -Polygon 6 0.00 2488.53 2966.32 5952898.00 691392.00 70 16 33.208 N 148 27 5.814 W -Polygon 7 0.00 1890.40 3082.39 5952303.00 691523.00 70 16 27.325 N 148 27 2.442 W -Polygon 8 0.00 1576.20 3165.55 5951991.00 691614.00 70 16 24.234 N 148 27 0.024 W -Polygon 9 0.00 1039.53 3144.10 5951454.00 691606.00 70 16 18.956 N 148 27 0.655 W 02-29C Fault 8 0.00 1512.65 4025.28 5951949.00 692475.00 70 16 23.605 N 148 26 34.994 W -Polygon 1 0.00 1512.65 4025.28 5951949.00 692475.00 70 16 23.605 N 148 26 34.994 W -Polygon 2 0.00 1251.76 4096.77 5951690.00 692553.00 70 1621.039N 148 26 32.917 W 02-29C T16.5 8805.00 2430.05 2784.79 5952835.00 691212.00 70 16 32.633 N 148 27 11.101 W 02-29C T16.4 8817.00 2024.30 2928.68 5952433.00 691366.00 70 1628.642 N 148 27 6.916 W 02-29C T16.3 8830.00 1724.57 2993.20 5952135.00 691438.00 70 16 25.694 N 148 27 5.040 W 02-29C T16.2 8845.00 1470.30 3039.85 5951882.00 691491.00 70 1623.193 N 148 27 3.685 W 02-29C T16.1 8849.00 1172.13 3042.39 5951584.00 691501.00 70 16 20.261 N 148 27 3.615 W Annotation 9241.70 9250.00 9264.00 9314.00 9364.00 9414.00 9489.00 9768.07 10018.07 10143.07 10268.07 10403.07 10453.07 10718.07 10908.07 11150.00 8477.86 8485.99 8499.54 8545.68 8590.96 8637.84 8707.62 8848.98 8846.07 8844.76 8839.67 8829.92 8826.52 8816.82 8812.75 8804.79 TIP KOP 3 4 5 6 7 8 9 10 11 12 13 14 15 TD Plan: Plan #16 Identical to Lamar's Plan #16 Principal: Yes Date Composed: Version: Tied-to: 3/9/2004 6 From: Definitive Path Plan Section Information 9241.70 11.68 71.77 8477.86 838.33 3152.62 0.00 0.00 0.00 0.00 9250.00 11.70 71.78 8485.99 838.86 3154.22 0.24 0.24 0.12 5.79 9264.00 17.24 68.50 8499.54 840.07 3157.50 40.00 39.59 -23.41 350.00 9314.00 27.96 51.24 8545.68 850.16 3173.60 25.00 21.44 -34.52 320.00 9364.00 22.99 24.25 8590.96 866.47 3186.80 25.00 -9.93 -53.98 235.00 9414.00 18.70 350.67 8637.84 883.35 3189.53 25.00 -8.59 -67.15 235.00 9489.00 26.24 304.04 8707.62 904.68 3173.70 25.00 10.06 -62.18 270.00 9768.07 90.70 340.23 8848.98 1094.58 3061.11 25.00 23.10 12.97 39.00 . BP-GDB Baker Hughes INTEQ Planning Report . Plan Section Information 10018.07 90.61 10.23 8846.07 1340.86 3040.56 12.00 -0.04 12.00 90.00 10143.07 90.59 355.23 8844.76 1465.35 3046.50 12.00 -0.02 -12.00 270.00 10268.07 94.06 340.62 8839.67 1587.14 3020.48 12.00 2.78 -11.69 283.60 10403.07 94.17 356.87 8829.92 1718.76 2994.28 12.00 0.09 12.03 89.00 10453.07 93.63 2.85 8826.52 1768.62 2994.16 12.00 -1.09 11.98 95.00 10718.07 90.46 331.19 8816.82 2023.36 2935.38 12.00 -1.20 -11.95 265.00 10908.07 91.97 353.94 8812.75 2203.39 2878.83 12.00 0.80 11.98 86.00 11150.00 91.72 324.90 8804.79 2427.34 2794.75 12.00 -0.10 -12.01 270.00 Survey 9241.70 11.68 71.77 8477.86 838.33 3152.62 5951253.09 691619.55 107.66 0.00 0.00 TIP 9250.00 11.70 71.78 8485.99 838.86 3154.22 5951253.66 691621.14 107.82 0.24 5.79 KOP 9264.00 17.24 68.50 8499.54 840.07 3157.50 5951254.94 691624.39 108.25 40.00 350.00 3 9275.00 19.43 63.18 8509.98 841.49 3160.65 5951256.44 691627.50 108.93 25.00 320.00 MWD 9300.00 24.80 54.63 8533.14 846.40 3168.65 5951261.56 691635.37 111.92 25.00 325.05 MWD 9314.00 27.96 51.24 8545.68 850.16 3173.60 5951265.44 691640.23 114.47 25.00 332.98 4 9325.00 26.47 46.18 8555.46 853.47 3177.38 5951268.84 691643.92 116.84 25.00 235.00 MWD 9350.00 23.87 32.78 8578.11 861.59 3184.15 5951277.13 691650.48 123.23 25.00 239.50 MWD 9364.00 22.99 24.25 8590.96 866.47 3186.80 5951282.07 691653.02 127.38 25.00 251.64 5 9375.00 21.53 18.10 8601.14 870.34 3188.31 5951285.98 691654.43 130.82 25.00 235.00 MWD 9400.00 19.22 1.34 8624.59 878.83 3189.84 5951294.50 691655.74 138.75 25.00 240.69 MWD 9414.00 18.70 350.67 8637.84 883.35 3189.53 5951299.01 691655.32 143.22 25.00 256.42 6 9425.00 18.89 342.15 8648.25 886.78 3188.69 5951302.42 691654.40 146.75 25.00 270.00 MWD 9450.00 20.68 324.38 8671.80 894.23 3184.88 5951309.77 691650.40 154.87 25.00 278.07 MWD 9475.00 23.95 310.29 8694.94 901.11 3178.43 5951316.49 691643.78 163.02 25.00 294.81 MWD 9489.00 26.24 304.04 8707.62 904.68 3173.70 5951319.94 691638.96 167.57 25.00 307.85 7 9500.00 28.43 307.67 8717.39 907.64 3169.61 5951322.80 691634.80 171.37 25.00 39.00 MWD 9525.00 33.68 314.26 8738.80 916.12 3159.92 5951331.03 691624.91 181.82 25.00 35.77 MWD 9550.00 39.20 319.22 8758.91 926.95 3149.79 5951341.61 691614.50 194.65 25.00 30.12 MWD 9575.00 44.88 323.11 8777.48 940.00 3139.33 5951354.39 691603.72 209.72 25.00 26.12 MWD 9600.00 50.67 326.30 8794.27 955.12 3128.66 5951369.23 691592.67 226.84 25.00 23.22 MWD 9617.72 54.82 328.24 8805.00 966.98 3121.04 5951380.90 691584.76 240.12 25.00 21.08 02-29C T 9625.00 56.53 328.99 8809.10 972.11 3117.91 5951385.95 691581.50 245.82 25.00 19.90 MWD 9640.03 60.08 330.43 8817.00 983.16 3111.46 5951396.83 691574.78 258.03 24.95 19.48 02-29C T 9650.00 62.45 331.33 8821.79 990.79 3107.21 5951404.36 691570.34 266.43 25.08 18.73 MWD 9669.23 67.02 332.97 8830.00 1006.17 3099.09 5951419.52 691561.84 283.24 25.00 18.29 02-29C T 9675.00 68.40 333.44 8832.19 1010.93 3096.69 5951424.22 691559.32 288.42 25.00 17.59 MWD 9700.00 74.37 335.38 8840.16 1032.29 3086.46 5951445.32 691548.56 311.53 25.00 17.41 MWD 9721.39 79.50 336.95 8845.00 1051.35 3078.05 5951464.16 691539.67 331.99 25.00 16.79 02-29C T 9725.00 80.36 337.21 8845.63 1054.62 3076.67 5951467.39 691538.21 335.49 25.00 16.44 MWD 9750.00 86.36 338.97 8848.52 1077.65 3067.41 5951490.18 691528.38 360.01 25.00 16.39 MWD 9768.07 90.70 340.23 8848.98 1094.58 3061.11 5951506.95 691521.66 377.92 25.00 16.19 8 9775.00 90.70 341.06 8848.90 1101.11 3058.81 5951513.42 691519.20 384.81 12.00 90.00 MWD 9800.00 90.70 344.06 8848.59 1124.96 3051.32 5951537.07 691511.12 409.73 12.00 90.01 MWD 9825.00 90.70 347.06 8848.29 1149.16 3045.09 5951561.11 691504.28 434.71 12.00 90.05 MWD 9850.00 90.69 350.06 8847.99 1173.66 3040.14 5951585.48 691498.71 459.70 12.00 90.08 MWD 9875.00 90.68 353.06 8847.69 1198.39 3036.47 5951610.10 691494.43 484.62 12.00 90.12 MWD 9900.00 90.67 356.06 8847.39 1223.27 3034.10 5951634.92 691491.44 509.40 12.00 90.16 MWD 9925.00 90.66 359.06 8847.10 1248.24 3033.04 5951659.85 691489.75 533.97 12.00 90.19 MWD 9950.00 90.65 2.06 8846.81 1273.24 3033.28 5951684.84 691489.37 558.27 12.00 90.23 MWD 9975.00 90.64 5.06 8846.53 1298.19 3034.84 5951709.82 691490.30 582.22 12.00 90.26 MWD 10000.00 90.62 8.06 8846.26 1323.02 3037.69 5951734.71 691492.53 605.78 12.00 90.29 MWD . BP-GDB Baker Hughes INTEQ Planning Report . Survey 10018.07 90.61 10.23 8846.07 1340.86 3040.56 5951752.62 691494.95 622.51 12.00 90.33 9 10025.00 90.61 9.40 8845.99 1347.68 3041.75 5951759.47 691495.96 628.90 12.00 270.00 MWD 10050.00 90.60 6.40 8845.73 1372.44 3045.18 5951784.31 691498.78 652.25 12.00 269.99 MWD 10075.00 90.60 3.40 8845.47 1397.35 3047.32 5951809.26 691500.29 676.04 12.00 269.96 MWD 10100.00 90.60 0.40 8845.20 1422.33 3048.15 5951834.25 691500.49 700.19 12.00 269.93 MWD 10125.00 90.59 357.40 8844.95 1447.32 3047.67 5951859.22 691499.39 724.65 12.00 269.90 MWD 10143.07 90.59 355.23 8844.76 1465.35 3046.50 5951877.22 691497.77 742.48 12.00 269.87 10 10150.00 90.78 354.42 8844.68 1472.25 3045.88 5951884.10 691496.98 749.34 12.00 283.60 MWD 10175.00 91.48 351.51 8844.18 1497.06 3042.82 5951908.82 691493.30 774.20 12.00 283.59 MWD 10200.00 92.18 348.59 8843.38 1521.66 3038.50 5951933.31 691488.36 799.15 12.00 283.53 MWD 10225.00 92.88 345.67 8842.28 1546.01 3032.94 5951957.50 691482.19 824.12 12.00 283.44 MWD 10250.00 93.57 342.74 8840.87 1570.02 3026.14 5951981.34 691474.80 849.05 12.00 283.31 MWD 10268.07 94.06 340.62 8839.67 1587.14 3020.48 5951998.31 691468.71 867.00 12.00 283.15 11 10275.00 94.07 341 .46 8839.18 1593.68 3018.23 5952004.79 691466.30 873.88 12.00 89.00 MWD 10300.00 94.11 344.46 8837.40 1617.52 3010.93 5952028.43 691458.40 898.75 12.00 89.06 MWD 10325.00 94.15 347.47 8835.60 1641.70 3004.88 5952052.46 691451.75 923.68 12.00 89.27 MWD 10350.00 94.17 350.48 8833.78 1666.18 3000.11 5952076.80 691446.37 948.59 12.00 89.49 MWD 10375.00 94.18 353.49 8831.96 1690.86 2996.64 5952101.39 691442.28 973.43 12.00 89.71 MWD 10400.00 94.17 356.50 8830.14 1715.70 2994.46 5952126.17 691439.48 998.12 12.00 89.93 MWD 10403.07 94.17 356.87 8829.92 1718.76 2994.28 5952129.22 691439.23 1001.14 12.00 90.15 12 10425.00 93.94 359.49 8828.37 1740.62 2993.59 5952151.05 691437.98 1022.59 12.00 95.00 MWD 10450.00 93.66 2.49 8826.71 1765.56 2994.02 5952175.99 691437.79 1046.80 12.00 95.19 MWD 10453.07 93.63 2.85 8826.52 1768.62 2994.16 5952179.06 691437.86 1049.75 12.00 95.38 13 10475.00 93.40 0.23 8825.17 1790.50 2994.75 5952200.94 691437.90 1070.93 12.00 265.00 MWD 10500.00 93.12 357.24 8823.75 1815.45 2994.20 5952225.87 691436.72 1095.37 12.00 264.84 MWD 10525.00 92.84 354.25 8822.45 1840.34 2992.34 5952250.71 691434.25 1120.04 12.00 264.67 MWD 10550.00 92.55 351.26 8821.28 1865.11 2989.19 5952275.39 691430.48 1144.89 12.00 264.51 MWD 10575.00 92.25 348.27 8820.23 1889.69 2984.76 5952299.85 691425.42 1169.83 12.00 264.37 MWD 10600.00 91.95 345.28 8819.31 1914.01 2979.04 5952324.01 691419.10 1194.81 12.00 264.25 MWD 10625.00 91.64 342.30 8818.53 1938.00 2972.07 5952347.82 691411.53 1219.76 12.00 264.14 MWD 10650.00 91.32 339.31 8817.88 1961.60 2963.85 5952371.21 691402.72 1244.60 12.00 264.05 MWD 10675.00 91.01 336.33 8817.38 1984.74 2954.41 5952394.10 691392.71 1269.27 12.00 263.97 MWD 10700.00 90.69 333.35 8817.01 2007.36 2943.79 5952416.45 691381.52 1293.71 12.00 263.91 MWD 10718.07 90.46 331.19 8816.82 2023.36 2935.38 5952432.23 691372.72 1311.18 12.00 263.86 14 10725.00 90.51 332.02 8816.77 2029.45 2932.08 5952438.24 691369.27 1317.86 12.00 86.00 MWD 10750.00 90.72 335.01 8816.50 2051.82 2920.94 5952460.32 691357.57 1342.17 12.00 86.01 MWD 10775.00 90.93 338.00 8816.14 2074.75 2910.97 5952482.99 691347.03 1366.74 12.00 86.04 MWD 10800.00 91.13 341.00 8815.69 2098.16 2902.22 5952506.17 691337.70 1391.52 12.00 86.08 MWD 10825.00 91.33 343.99 8815.15 2121.99 2894.70 5952529.81 691329.59 1416.44 12.00 86.14 MWD 10850.00 91.53 346.99 8814.53 2146.18 2888.44 5952553.83 691322.72 1441.42 12.00 86.20 MWD 10875.00 91.72 349.98 8813.82 2170.67 2883.45 5952578.18 691317.12 1466.40 12.00 86.28 MWD 10900.00 91.91 352.98 8813.02 2195.37 2879.75 5952602.79 691312.80 1491.30 12.00 86.36 MWD 10908.07 91.97 353.94 8812.75 2203.39 2878.83 5952610.78 691311.68 1499.32 12.00 86.46 15 10925.00 91.97 351.91 8812.17 2220.18 2876.75 5952627.51 691309.18 1516.15 12.00 270.00 MWD 10950.00 91.96 348.91 8811.31 2244.81 2872.59 5952652.03 691304.40 1541.09 12.00 269.93 MWD 10975.00 91.95 345.91 8810.46 2269.19 2867.14 5952676.27 691298.35 1566.07 12.00 269.83 MWD 11000.00 91.93 342.91 8809.61 2293.26 2860.43 5952700.15 691291.03 1591.02 12.00 269.72 MWD 11025.00 91.91 339.91 8808.77 2316.94 2852.46 5952723.62 691282.48 1615.89 12.00 269.62 MWD 11050.00 91.88 336.90 8807.94 2340.17 2843.26 5952746.61 691272.70 1640.59 12.00 269.52 MWD 11075.00 91.85 333.90 8807.13 2362.88 2832.87 5952769.06 691261.74 1665.07 12.00 269.42 MWD 11100.00 91.81 330.90 8806.33 2385.02 2821.29 5952790.91 691249.62 1689.24 12.00 269.33 MWD 11125.00 91.77 327.90 8805.55 2406.53 2808.57 5952812.08 691236.36 1713.06 12.00 269.23 MWD 11150.00 /91.72 324.90 8804.79 2427.34 2794.75 5952832.54 691222.02 1736.45 12.00 269.14 TD Nordic 1 slim hole All Measurements are from top of Riser 3/17/2004 1IIIIIIIIIIIIIIIIIIIIIIl ~ <D en .- a:: top of bag ,~ r) ~- BAG 71/16" 5000psi 1~I~~(~L r ~-~ t.,~ = ì:.~ bttm of bag middle of slips Blind/Shears ...... ...;<.. ................... middle of pipes TOTs 2" combi ram/slips L..........············71/16" 5000psi middle of blind/shears .......... Mud Cross '---' I f 23/8" ram I J 2" combi ram/slips ..........' ........... Mud Cross 7 1/16" 5000psi middle of flow cross middle of pipe/slips I···· ....;,.< ......................... TOTs t.............·········7 1/16" 5000psi ..' .¡ III!; ~ . , 'J,lJt' H( r_~ ~ ''''' - ![ , ¡ ~ f Flow Tee p055231 DATE 1/6/2004 . INVOICE I CREDIT MEMO PR010504M DESCRIPTION PERMIT TO DRILL THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: . TO THE ORDER OF: STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE ANCHORAGE, AK 99501-3539 GROSS NATIQNA.. CITY BANK Ashland, Ohio DATE I 1/6/2004 CHECK NO. 055231 VENDOR DISCOUNT NET H o~ .?-OÇ- 56-389 412 "No. P 055231 CONSOliDATED COMMERCIAL ACCOUNT AMOUNT .Ja~ual)' 6'4004/ ****~~~$1ÖO.00******i N9¿'Y."~. "'~~I:f"~.Jf.~.9t~§,....~- ~~":<\.,"::~:.."~:;"... .:.:.:.:-:;\:. :;;,. II· 0 5 5 ~ :1 * II· I: 0... ¡. ~ 0 :1 B q 5 I: 0 ¡. ~ ? B Iì b liD . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ;9fa O;z.-29 L PTD# 2o~-ò~<;'J x- Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic "CLUE" Tbe permit is for a new wellboresegment of existing well Permit No, API No. Production sbould continue to be reported as a function ·of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ;¡ conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrough target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 02-29C Program DEV Well bore seg PTD#: 204051 0 Company BP EXPLORATION (ALASKA) INC Initial Classrrype DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 1 Permittee attache.cL ........................ . . . . . . . . . . . . Yes ............................................... ....................... 2 .Lease.number .appropri<lte. . . . . . . . . . . . . . . . . . . . .. ... Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .U.nlque weltn.arne.anq Ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WeUJoc<lted lnad.efine~Lpool. . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . .. .......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 WeJlJoc<lted proper .dlstance from driJling unitbound.ary. . . . . . . . . . . . . . . . . . . Yes. .......... ............... . . . . . . . 6 WeU Joc<lted properdlstance. from other wells. . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 .Sutficientacreage.aYail<lble indJilliog unjt . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . .. ....... . . . . . . . . . . . . . . . . . .. ........... ......... 8 Jf.deviated. js weJlbore platincJuded . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 .Operator only affected party. . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator has.apprpprlale. b.ond lnJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . 11 Permit can Þe lssl!ed without conservaiion order. . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . .. ........... . . . . . . . . 12 Permit cao Þe lSSl!ed without ad.milJi$tratille.apprpvaJ . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . .. ........ ...................... . . . . . . . . . . . . . . . . . . 3/22/2004 13 Can permit be approved before 15-day wait Yes 14 WellJocated wlthin area and strata .authorlzed by.lnjectioo Order # (puUO# in.comrnentsUfor. Yes. 15 AJlweIJs.withtnJI4J1Jile.area.ofreyiewid.eot[fied(Fpr$ervjc.ewellonly)............... .Yes.... _............... _...................................................... 16 PJe-produ.ced injector; duration.of pre-productiOIJ less. than 3 months (for.servtce well onJy) . . Yes. 17 ACMP F.inding.of Con.ststenc;yhas ÞeenJ$sued forJhis project . . . . . . . . . . . . . . . . . . . Yes. Administration Appr RPC Date Engineering Appr Date WGA 3/23/2004 Geology Appr RPC Date 3/22/2004 Geologic Commissioner: ùT S - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 .C.onductor $tring.PJovided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . .. ........... . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .Surfaœca$ing. pJotects all known. USDW$ . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 .CMTv.oladec¡l!ateJocirculateo.n.cOlJductor&$uJt(:$g........................ NA . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . .. . . . . . . . . . . . . . . . . 21 .CMT vol adec¡u.ateto tie-tnJongstring to.surf C$g . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 .CMTwill coyer aU klJow.n.produc;tiye horizon.s. . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 .C.asing design$ adequaie for C,l", B&. permafr.ost . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . .. .................... . . . . . . . . 24 AdequateJankage.oJ reserve pit. ........... . . . . . . . . . . . . . . . . . Yes. CTDU. . . . . . . . . .. ....... ............ . . . . . . . 25 Jf.are-dri1thas.a.to-403forabandonmentbeeoapPJoved ......... Yes. .3/19/200'k......................... ............ 26 Adequate.wellbore $epar<ltio.n.propQ$ed. . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . 27 Jtdiverterreq.uiJed, does it meet reguJations. . . . . . . . . .. ......... . . NA . . . . . . . Sidetrack. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28 .DJilliog fJuidprogram schematic & eq.uipJistadequ<lte. . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . Max MW8J~ ppg, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29 BOPEs,.d.o they meet reguJatiOIJ . . . . . . . . . . . . . . . . . .. ............. Yes . . . . . . .. ............... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 BOPEpressraiiog appropriate;tesHo.(pui p$ig tncomments). . . . . . . . . . . . . . . . . . . . Yes . TesH03500. psLMSF' 2420 psi. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . 31 Choke manifold compJie$ w/APt RF'-53 (May 84). . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . .. .................... 32 WQrk will oc;c.ur withoutoperation .shutdown . . . . . . . . . . Yes. . . . . . . .. .................. . . . . . . . . . . . . . . . . . . . . 33 J$ pre$eoce. of H2S gas. prob.aÞle. . . . . . . . . . . . . . . . . . . . . . .No . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34 MeçhanlcatcoodJt[on pf weUs wlthin ~Oß yerified (for.s.erviœ welJ onJy). . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35 Permit cao Þe lssl!ed w/o hydrogen. $ulfide meas.ures. . . . . . . . . . . . No. 36 D.ata.PJeselJted on. potential oveJpre$sure .ZOnes. . . . . . . . . . .. .... NA 37 .5elsmic.analysJs. of shaJlow gaszooes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA 38 .Seabedc<;mditioo survey.(if Qff-$ho(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . 39 . CQnta.ct namelphQneJor.weelsly progre$sreports [explQratoryonlYl . . . . . . . . .NA . - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Public Commissioner Date ] 1~11- o . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. e Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Rev~sion: 4 $ Fri Sep 10 16:04:26 2004 e O(l; (-OS / 11 1 uíf {Ìv Reel Header Service name.......... ...LISTPE Date.................... .04/09/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. _ _ . . . _ _ _ _ _ _ . . . UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/09/10 Origin...................STS Tape Name................ UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003030695 S. LATZ EGBEJIMBA/KO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003030695 B. JAHN S. KOLSTAD 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW0003030695 B. JAHN S. KOLSTAD 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 15 MW0003030695 B. JAHN B. LAULE 1 R # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 2-29C 500292201103 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 10-SEP-04 MWD RUN 2 MW0003030695 S. LATZ EGBEJIMBA/KO MWD RUN 6 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 11 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 16 MW0003030695 B. JAHN B. LAULE 1 R 36 11N 14E 887 1740 63.00 MWD RUN 4 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 7 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 12 MW0003030695 B. JAHN S. KOLSTAD 1 RECEIVED t"Ir-o .' ."T" ¡ "',."I4...~î . 200¿J AlaSka On & Gas Cons. Commìssion .f.' MfìC!10Jage e e DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2.740 7.000 9851.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THE MAIN TARGET INTERVAL OF THIS WELLBORE WAS DRILLED AS AN OPEN-HOLE SIDETRACK, EXITING THE 2-29C PB1 WELLBORE AT 9850'MD. 2-29C PB1 WAS DRILLED OFF OF A CEMENT RAMP IN THE 2-29B WELLBORE. THE TOP OF THE WINDOW IS AT 9251'MD AND THE BOTTOM IS AT 9255'MD. 4. MWD RUNS 1 - 8, 11 - 16 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. MWD WERE TO CREATE THE RAMP, MILL AND DRESS WINDOW, AND DRILL ABOUT HOLE. SGRD DATA FOR THESE RUNS ARE PRESENTED FOR TIE-IN PURPOSES FOR DATA QUALITY. NO DATA FROM MWD RUNS 9 & 10 ARE PRESENTED. RUNS 1 - 3 15' OF NEW - SROP DATA 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE 2-29C WELLBORE ON 3 MAY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 1 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 16 REPRESENT WELL 2-29C WITH API#: 50-029-22011-03. THIS WELL REACHED A TOTAL DEPTH(TD)OF 11411'MD/8793'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name.... .........STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP S 1 clipped curves; all bit runs merged. .5000 START DEPTH 9011.0 9173.0 STOP DEPTH 11378.0 11402.0 e - BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9011.0 9012.0 9018.5 9021. 5 9025.0 9028.0 9041.5 9062.0 9149. 0 9153.0 9167.5 9171. 5 9174.0 9179.5 9183.5 9187.0 9200.0 9202.0 9208.0 9217.5 9218.5 9221.5 9241. 5 9246.0 9251. 5 9255.0 9267.5 9274.0 9279.0 9285.0 9289.5 9291. 0 9298.0 9300.0 9301.0 9320.0 9333.0 9355.0 9371.5 9382. 0 9386.5 9388.0 9398.0 9403.5 9405.0 9438.5 9445.5 9469.0 9472.0 9483.5 9486.0 9490.0 9496.0 9497.0 9533.0 9554.5 9560.5 9562.0 9565.0 9568.5 9576.5 9583.0 9584.5 9586.5 9590.0 9596.0 9608.5 9611.0 9614.0 9620.5 9623.0 GR 9011.0 9012.0 9018.5 9021. 5 9025.0 9028.0 9042.0 9062.0 9148.0 9151.5 9167.0 9171. 5 9175.0 9179.5 9182.0 9183.5 9199.5 9201.0 9207.5 9217.0 9218.0 9220.5 9239.0 9245.5 9250.5 9253.0 9267.0 9273.5 9278.5 9285.0 9288.5 92 90.5 9297.5 9299.0 9300.5 9318.0 9330.0 9352.0 9370.0 9380.0 9385.5 9386.5 9397.5 9403.0 9405.5 9439.0 9445.0 9469.0 9472.0 9483.0 9486.0 9489.5 9495.5 9497 .0 9532.5 9554.0 9560.0 9562.0 9564.5 9568.5 9576.5 9582.5 9584.0 9586.0 9589.0 9594.5 9608.0 9610.0 9613.5 9620.0 9622.5 e e 9631.5 9639.5 9642.5 9650.5 9656.5 9660.0 9662.0 9666.0 9679.5 9693.0 9708. 0 9722.0 9724.0 9736.0 9739.0 9753.0 9758.5 9759.5 9765.0 9769.5 9772.5 9784.0 9790.0 9795.0 9799.5 9804.0 9812.0 9820.0 9830.0 9834.5 9840.5 9851.0 9854.5 9861. 5 9867.0 9868.5 9878.0 9882.5 9887.0 9893.5 9918.5 9928.5 9946.0 9949.5 9971.5 9980.0 9992.5 10015.0 10021. 5 10026.5 10032.5 10045.0 10062.5 10084.0 10111. 5 10156.0 10158.0 10160.5 10172.5 10176.5 10185.0 10190.0 10191. 0 10215.0 10221. 0 10225.0 10227.5 10236.5 10239.0 10244.5 10246.0 10249.0 10253.5 10260.5 10261. 5 9631.0 9639.0 9642.0 9649.5 9655.5 9659.0 9661.5 9666.0 9679.5 9692.0 9709.0 9722.5 9724.5 9734.5 9739.5 9753.5 9758.0 9759.5 9764.5 9770 . 0 9773.5 9784.5 9790. 0 9795.0 9800.0 9806.0 9815.0 9823.5 9834.0 9838.5 9844.0 9853.5 9856.5 9863.5 9869.5 9871. 0 9881. 0 9885.0 9889.0 9896.0 9921. 0 9929.5 9945.5 9950.0 9971. 0 9980.0 9991. 5 10012.0 10017.5 10023.5 10029.5 10041.5 10058.5 10080.0 10109.0 10155.0 10158.0 10160.5 10173.5 10178.5 10187.5 10192.0 10193.0 10218.5 10224.5 10227.0 10228.5 10239.0 10242.5 10246.5 10248.5 10249.5 10253.0 10260.5 10261.5 e e 10271. 5 10295.0 10307.5 10309.5 10327.0 10331. 5 10339.5 10344.0 10348.0 10370.5 10389.0 10397.5 10417.0 10420.0 10424.0 10432.0 10450.5 10481.0 10507.5 10509.5 10516.0 10565.5 10579.5 10648.5 10657.5 10675.0 10678.0 10681.5 10687.5 10695.0 10698.0 10714.5 10730.5 10736.0 10745.0 10748.0 10752.0 10757.0 10778.5 10877.5 10884.5 10886.5 10900.5 10907.0 10919.0 10926.0 11007.5 11028.0 11033.5 11038.5 11043.5 11060.0 11062.5 11076.0 11079.0 11091. 5 11095.5 11101. 5 11104.5 11106.5 11109.0 11113.5 11128.5 11147.0 11180.0 11208.0 11216.5 11219.0 11224.0 11228.0 11239.0 11240.0 11242.0 11247.5 11257.5 10271.5 10299.0 10311. 5 10314.5 10329.5 10334.5 10343.5 10347.0 10350.0 10372.5 10391. 0 10399.0 10418.5 10422.5 10426.5 10434.5 10453.0 10483.0 10509.5 10511. 5 10518.5 10567.0 10581. 0 10647.5 10657.5 10674.5 10678.0 10681.5 10688.0 10694.5 10698.0 10715.0 10726.5 10732.5 10742.0 10745.5 10749.5 10754.5 10777.5 10875.5 10882.0 10886.0 10899.0 10905.5 10917.5 10925.5 11012.5 11035.5 11040.0 11043.5 11048.5 11067.5 11070.0 11083.0 11084.5 11098.5 11102.5 11108.0 11110.0 11112.0 11116.0 11120.5 11135.5 11154.5 11187.0 11216.5 11223.0 11226.0 11231. 0 11235.0 11246.5 11248.0 11249.5 11254.5 11268.0 11268.0 11282.5 11287.5 11294.0 11325.5 11345.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: e 11278.0 11294.0 11298.0 11300.0 11337.0 11354.5 BIT RUN NO 1 2 4 5 6 7 8 11 12 15 16 MERGE TOP 9011.0 9250.0 9265.0 9335.0 9347.0 9448.0 9825.0 9850.5 9932.0 10450.0 10780.0 MERGED MAIN PASS. $ e MERGE BASE 9250.0 9265.0 9335.0 9347.0 9448.0 9825.0 9850.0 9932.0 10450.0 10780.0 11411.0 # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order MWD MWD Units FT FT!H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9011 11402 10206.5 4783 9011 11402 ROP MWD FT!H 0.23 1827.91 76.7344 4459 9173 11402 GR MWD API 16.45 222.31 54.6795 4577 9011 11378 First Reading For Entire File..........9011 Last Reading For Entire File...........11402 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04!09!10 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name........ .....STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04!09!10 Maximum Physical Record..65535 e Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 9011.0 917 4.0 STOP DEPTH 9223.0 9250.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units...... . ., . . . . . . . . . . . . . . Datum Specification Block sub-type...O 19-APR-04 Insite Memory 9250.0 9175.0 9250.0 .0 .0 TOOL NUMBER TLG015 2.740 8999.0 KCL Water 8.50 65.0 11.0 15000 9.6 .000 .000 .000 .000 .0 124.0 .0 .0 e e Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size Nsam Rep Code 4 1 68 4 1 68 4 1 68 Offset Channel o 1 4 2 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9011 9250 9130.5 479 9011 9250 ROP MWD010 FT/H 1.45 84.47 49.8895 153 9174 9250 GR MWDOIO API 17.74 182.36 41. 4635 269 9011 9223 First Reading For Entire File..........90ll Last Reading For Entire File...........9250 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/10 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...........l.O.O Date of Generation.......04/09/l0 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9223.5 9250.5 STOP DEPTH 9238.5 9265.0 # 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: 20-APR-04 Insite Memory 9265.0 9250.0 9265.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG015 # BOREHOLE AND CASING DATA e e OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2.740 8740.0 # 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: Biozan 8.30 65.0 11.0 15000 10.0 Water .000 .000 .000 .000 .0 146.0 .0 .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.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units........ . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT!H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9223.5 9265 9244.25 84 9223.5 9265 ROP MWD020 FT!H 0.33 82.95 17.4617 30 9250.5 9265 GR MWD020 API 21.37 29.42 24.1558 31 9223.5 9238.5 First Reading For Entire File.._.......9223.5 Last Reading For Entire File...........9265 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number........ . . .1.0.0 Date of Generation.......04!09!10 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.......04!09!10 e Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 4 .5000 START DEPTH 9239.0 9265.5 STOP DEPTH 9311 . 5 9335.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units... . . . . . . . . . . . . . . . . . . . . 21-APR-04 Insite Memory 9335.0 9265.0 9335.0 11.7 23.9 TOOL NUMBER TLG013 3.000 8740.0 Flo Pro 8.60 60.0 9.0 24000 6.0 .000 .000 .000 .000 .0 141.7 .0 .0 e e Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9239 9335 9287 193 9239 9335 ROP MWD040 FT/H 0.23 66.37 29.3896 140 9265.5 9335 GR MWD040 API 22.39 1l0.15 35.3695 146 9239 9311. 5 First Reading For Entire File..........9239 Last Reading For Entire File...........9335 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...... .... .STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 9312.0 9335.5 STOP DEPTH 9322.5 9347.0 # 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: 21-APR-04 Insite Memory 9347.0 9335.0 9347.0 11.7 23.9 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG <; BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 e e BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 8740.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/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: Flo Pro 8.60 60.0 9.0 24000 6.0 .000 .000 .000 .000 .0 141.7 .0 .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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point.... ..........Undefined Frame Spacing.....................60 .1IN Max frames per record. ............Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 MWD050 MWD050 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9312 9347 9329.5 71 9312 9347 ROP MWD050 FT/H 0.34 58.53 17.3808 24 9335.5 9347 GR MWD050 API 20.26 27.22 23.8795 22 9312 9322.5 First Reading For Entire File..........9312 Last Reading For Entire File...........9347 File Trailer Service name........ .....STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .... ......STSLIB.006 Service Sub Level Name... Version Number...........l.O.O e Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 e header data for each bit run in separate files. 6 .5000 START DEPTH 9323.0 9347.5 STOP DEPTH 9423.0 9448.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value......................-999 21-APR-04 Insite Memory 9448.0 9347.0 9448.0 17.6 23.0 TOOL NUMBER TLG013 3.000 8740.0 Flo Pro 8.60 60.0 9.0 15000 9.2 .000 .000 .000 .000 .0 137.5 .0 .0 e e Depth Units..................... . . Datum Specification Block sub-type. ..0 Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name Service Order DEFT ROP MWD060 GR MWD060 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9323 9448 9385.5 251 9323 9448 ROP MWD060 FT/H 0.25 55.45 13.8938 202 9347.5 9448 GR MWD060 API 16.45 46.51 24.4733 201 9323 9423 First Reading For Entire File..........9323 Last Reading For Entire File...........9448 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/09/l0 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...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 header data for each bit run in separate files. 7 .5000 START DEPTH 9423.5 9448.5 STOP DEPTH 9802.0 9825.0 # 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: 22-APR-04 Insite Memory 9825.0 9448.0 9825.0 27.8 87.5 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG " BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 e # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): II 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.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 GR MWD070 Size 4 4 4 Nsam Rep Code 1 68 1 68 1 68 Uni ts FT FTIH API e 3.000 8740.0 Flo Pro 8.60 65.0 9.5 21000 9.8 .000 .000 .000 .000 .0 141.7 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9423.5 9825 9624.25 804 9423.5 9825 ROP MWD070 FTIH 0.8 559.19 64.2341 754 9448.5 9825 GR MWD070 API 18.84 207.67 44.2823 758 9423.5 9802 First Reading For Entire File..........9423.5 Last Reading For Entire Fi1e...........9825 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation. ......04/09/10 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... e Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 e header data for each bit run in separate files. 8 .5000 START DEPTH 9802.5 9825.5 STOP DEPTH 9850.0 9850.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 ~~ 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.....O Logging Direction... .... ..........Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined 23-APR-04 Insite Memory 9850.0 9825.0 9850.0 86.8 95.0 TOOL NUMBER TLG015 3.000 8740.0 Flo-pro 8.70 60.0 9.3 21000 6.8 .000 .000 .000 .000 .0 145.9 .0 .0 e e Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD080 MWD080 Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9802.5 9850 9826.25 96 9802.5 9850 ROP MWD080 FT/H 11.96 95.95 68.0823 50 9825.5 9850 GR MWD080 API 58.17 97.17 73.3355 96 9802.5 9850 First Reading For Entire File..........9802.5 Last Reading For Entire Fi1e...........9850 File Trailer Service name............. STSLIB. 008 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/l0 Maximum Physical Record..65535 File Type............... .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.......04/09/l0 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 header data for each bit run in separate files. 11 .5000 START DEPTH 9850.5 9850.5 STOP DEPTH 9910.5 9932.0 # 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: 26-APR-04 Insite Memory 9932.0 9850.0 9932.0 80.8 90.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray TOOL NUMBER TLG013 e e $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2.740 8740.0 # 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: Flo-pro 8.60 65.0 9.1 25000 6.4 .000 .000 .000 .000 .0 146.0 .0 .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.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units...... . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 MWD110 MWDll 0 Nsam 1 1 1 Rep 68 68 68 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9850.5 9932 9891.25 164 9850.5 9932 ROP MWD110 FT/H 4.53 139.69 82.653 164 9850.5 9932 GR MWD110 API 45.57 135.61 71.3183 121 9850.5 9910.5 First Reading For Entire File..........9850.5 Last Reading For Entire File...........9932 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number. . . . . . . . . . .1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.OI0 Physical EOF File Header Service name..... ........STSLIB.OI0 e Service Sub Level Name... Version Number...........l.O.O Date of Generation... ....04/09/10 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 10 e header data for each bit run in separate files. 12 .5000 START DEPTH 9911. 0 9932.5 STOP DEPTH 10427.0 10450.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL 1FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 IPPM): 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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............ ..Undefined Frame Spacing..................... 60 .1IN 28-APR-04 Insite Memory 10450.0 9932.0 10450.0 85.1 101. 6 TOOL NUMBER TLG013 2.740 8740.0 Flo-pro 8.60 65.0 9.2 25000 5.2 .000 .000 .000 .000 .0 150.0 .0 .0 e e Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR MWDl20 MWDl20 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Service Order Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9911 10450 10180.5 1079 9911 10450 ROP MWD120 FT/H 1.53 1827.91 82.4108 1036 9932.5 10450 GR MWDl2 0 API 31. 92 142.65 54.8 1033 9911 10427 First Reading For Entire Fi1e..........9911 Last Reading For Entire File...........10450 File Trailer Service name.............STSLIB.010 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record. .65535 File Type................LO Next File Name...........STSLIB.011 Physical EOF File Header Service name.............STSLIB.011 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 11 header data for each bit run in separate files. 15 .5000 START DEPTH 10427.5 10450.5 STOP DEPTH 10754.5 10780.0 # 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: 29-APR-04 Insite Memory 10780.0 10450.0 10780.0 89.5 99.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER e PCG $ Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..... ........ .Undefined Frame Spacing.............. .......60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD150 GR MWD150 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code TLG013 2.740 8740.0 Flo-Pro 8.60 65.0 9.5 44400 12.4 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 .0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10427.5 10780 10603.8 706 10427.5 10780 ROP MWD150 FT/H 2.08 1731.88 93.4561 660 10450.5 10780 GR MWD150 API 29.76 148.05 74.3909 655 10427.5 10754.5 First Reading For Entire File..........l0427.5 Last Reading For Entire File...........l0780 File Trailer Serv~ce name........... ..STSLIB.Oll Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type............... .LO Next File Name......... ..STSLIB.012 Physical EOF File Header e Service name.............STSLIB.012 Service Sub Level Name... Version Number....... ....1.0. Date of Generation.......04!09!10 Maximum Physical Record..65535 File Type............... .LO Previous File Name.. .....STSLIB.Oll Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 12 e header data for each bit run in separate files. 16 .5000 START DEPTH 10755.0 10780.5 STOP DEPTH 11387.0 11411.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined 30-APR-04 Insite Memory 11411.0 10780.0 11411.0 99.9 83.3 TOOL NUMBER TLG015 2.740 8740.0 Flo-Pro 8.60 65.0 9.1 26500 5.2 .000 .000 .000 .000 .0 159.0 .0 .0 e e Frame Spacing.....................60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWDl60 GR MWDl60 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10755 11411 11 083 1313 10755 11411 ROP MWD160 FT/H 1.2 1050.33 90.9978 1262 10780.5 11411 GR MWD160 API 31. 58 222.31 58.2966 1265 10755 11387 First Reading For Entire File..........10755 Last Reading For Entire File...........11411 File Trailer Service name.............STSLIB.012 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Next File Name. ..........STSLIB.013 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04 / 09/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04/09/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Reel Header Service name.............LISTPE Date. . ..... . . . . ..........04/09/10 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Li.brary. e Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 10 15:13:50 2004 e ~e¡-OSI 1f 11?- (:L Scientific Technical Services Tape Header Service name.............LISTPE Date.. ...................04/09/10 Origin. . . . . . . . . . .. . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/!1AD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003030695 S. LATZ EGBEJIMBA/KO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003030695 B. JAHN S. KOLSTAD 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW0003030695 B. JAHN S. KOLSTAD 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2-29C PBl 500292201170 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 10-SEP-04 MWD RUN 2 MW0003030695 S. LATZ EGBEJIMBA/KO MWD RUN 4 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 6 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 7 MW0003030695 B. JAHN S. KOLSTAD 1 MWD RUN 9 MW0003030695 B. JAHN S. KOLSTAD 1 36 11N 14E 887 1740 63.00 RECEIVED OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) SEP 1 ". 2004 AJaske 0" & Gas Cons. CommiSSiun Anchorage 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: e e 2.740 9251.0 7.000 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A CEMENT RAMP IN THE 2-29B WELLBORE. THE TOP OF THE WINDOW IS AT 9251'MD AND THE BOTTOM IS AT 9255 'MD. 4. MWD RUNS 1 - 9 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUNS 1 - 3 WERE TO CREATE THE RAMP, MILL AND DRESS WINDOW, AND DRILL ABOUT 15' OF NEW HOLE. SGRD DATA ARE PRESENTED FOR TIE-IN PURPOSES - SROP DATA FOR DATA QUALITY. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-29C WELL BORE ON 3 MAY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 1 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 9 REPRESENT WELL 2-29C PBl WITH API#: 50-029-22011-70. THIS WELL REACHED A TOTAL DEPTH(TD)OF 10872'MD/8830'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type...... _........ .LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PEU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9011. 0 9035.0 STOP DEPTH 10844.5 10868.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9011. 0 9012.0 9018.5 9021.5 9025.0 GR 9011.0 9012.0 9018.5 9021.5 9025.0 e e 9028.0 9041. 5 9062.0 9149.0 9153.0 9167.5 9171.5 917 4.0 9179.5 9183.5 9187.0 9200.0 9202.0 9208.0 9217.5 9218.5 9221. 5 9241. 5 9246.0 9251.5 9255.0 9267.5 9274.0 9279.0 9285.0 9289.5 92 91.0 9298.0 9300.0 9301. 0 9320.0 9333.0 9355.0 9371. 5 9382.0 9386.5 9388.0 9398.0 9403.5 9405.0 9438.5 9445.5 9469.0 9472.0 9483.5 9486.0 9490.0 9496.0 9497.0 9533.0 9554.5 9560.5 9562.0 9565.0 9568.5 9576.5 9583.0 9584.5 9586.5 9590.0 9596.0 9608.5 9611.0 9614.0 9620.5 9623.0 9631.5 9639.5 9642.5 9650.5 9656.5 9660.0 9662.0 9666.0 9679.5 9028.0 9042.0 9062.0 9148.0 9151.5 9167.0 9171.5 9175.0 917 9.5 9182.0 9183.5 9199.5 9201.0 9207.5 9217.0 9218.0 9220.5 9239.0 9245.5 9250.5 9253.0 9267 . 0 9273.5 9278.5 9285.0 9288.5 9290.5 9297.5 9299.0 9300.5 9318.0 9330.0 9352.0 9370.0 9380.0 9385.5 9386.5 9397.5 9403.0 9405.5 9439.0 9445.0 9469.0 9472.0 9483.0 9486.0 9489.5 9495.5 9497.0 9532.5 9554.0 9560.0 9562.0 9564.5 9568.5 9576.5 9582.5 9584.0 9586.0 9589.0 9594.5 9608.0 9610.0 9613.5 9620.0 9622.5 9631.0 9639.0 9642.0 9649.5 9655.5 9659.0 9661.5 9666.0 9679.5 9693.0 9708.0 9722.0 9724.0 9736.0 9739.0 9753.0 9758.5 9759.5 9765.0 9769.5 9772.5 9784.0 9790.0 9795.0 9799.5 9804.0 9812.0 9820.0 9830.0 9834.5 10868.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: e e 9692.0 9709.0 9722.5 9724.5 9734.5 9739.5 9753.5 9758.0 9759.5 9764.5 9770.0 9773.5 9784.5 9790.0 9795. 0 9800.0 9806.0 9815.0 9823.5 9834.0 9838.5 10872.5 BIT RUN NO 1 2 4 5 6 7 8 9 MERGE BASE 9250.0 9265.0 9335.0 9347.0 9447.0 9825.0 10193.0 10872.5 MERGE TOP 9011 . 0 9250.0 9265.0 9335.0 9347.0 9447.0 9825.0 10193.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction... ..............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.................... . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD Units FT FT/H API Code Channel 1 2 3 Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Offset o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9011 10868.5 9939.75 3716 9011 10868.5 ROP MWD FT/H 0.18 3187.32 72.8356 3505 9035 10868.5 GR MWD API 16.45 249.89 78.7003 3510 9011 10844.5 First Reading For Entire Fi.le.......... 9011 Last Reading For Entire File...........10868.5 File Trailer Service name... ..........STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/10 Maximum Physical Record..65535 e File Type................ LO Next File Name..... ......STSLIB.002 Physical EOF File Header Service name............. STSLIB. 002 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......04/09/l0 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 1 .5000 S1'ART DEPTH 9011.0 9035.5 STOP DEPTH 9223.0 9250.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (La/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 (nT): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 19-APR-04 Insite Memory 9250.0 9175.0 9250.0 .0 .0 TOOL NUMBER TLG015 2.740 8999.0 KCL Water 8.50 65.0 1l.0 15000 9.6 .000 .000 .000 .000 .0 124.0 .0 .0 e e $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9011 9250 9130.5 479 9011 9250 ROP MWD010 FT/H 1. 45 84.47 50.5937 265 9035.5 9250 GR MWD010 API 17.74 182.36 41. 4635 269 9011 9223 First Reading For Entire File..........9011 Last Reading For Entire File...........9250 File Trailer Service name.......... ...STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/10 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...........l.0.0 Date of Generation.......04/09/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 2 .5000 START DEPTH 9223.5 9250.5 STOP DEPTH 9238.5 9265.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): 20-APR-04 Insite Memory 9265.0 e TOP LOG INTERVAL (tT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing............... ......60 .1IN Max frames per record....... ......Undefined Absent va1ue......................-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code MWD020 MWD020 e 9250.0 9265.0 .0 .0 TOOL NUMBER TLG015 2.740 8740.0 Biozan 8.30 65.0 11. 0 15000 10.0 Water .000 .000 .000 .000 .0 146.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9223.5 9265 9244.25 84 9223.5 9265 ROP MWD020 FT/H 0.33 2127.26 101.416 30 9250.5 9265 GR MWD020 API 21. 37 29..42 24.1558 31 9223.5 9238.5 First Reading For Entire File........... 9223.5 Last Reading For Entire File...........9265 File Trailer Service name. ............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 e 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...........l.O.O Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 4 .5000 START DEPTH 9239.0 9265.5 STOP DEPTH 9311. 5 9335.0 # LOG HE}\DER 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): " 21-APR-04 Insite Memory 9335.0 9265.0 9335.0 11.7 23.9 TOOL NUMBER TLG013 3.000 8740.0 Flo Pro 8.60 60.0 9.0 24000 6.0 .000 .000 .000 .000 .0 141.7 .0 .0 e e REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR Code Offset o 4 8 Channel 1 2 3 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 MWD040 MWD040 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9239 9335 9287 193 9239 9335 ROP MWD040 FT/H 0.23 66.37 29.3896 140 9265.5 9335 GR MWD040 API 22.39 110.15 35.3695 146 9239 9311 . 5 First Reading For Entire File...__.....9239 Last Reading For Entire File...........9335 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type.............. ..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.......04/09/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 9312.0 9335.5 STOP DEPTH 9322.5 9347.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 21-APR-04 Insite Memory e 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Size Nsam Rep Code 4 1 68 4 1 68 4 1 68 Units FT FT/H API 9347.0 9335.0 9347.0 11. 7 23.9 TOOL NUMBER TLG013 3.000 8740.0 Flo Pro 8.60 60.0 9.0 24000 6.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 141.7 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9312 9347 9329.5 71 9312 9347 ROP MWD050 FT/H 0.34 58.53 17.3808 24 9335.5 9347 GR MWD050 API 20.26 27 .22 23.8795 22 9312 9322.5 First Reading For Entire File..........9312 Last Reading For Entire File...........9347 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 e Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type.............. ..LO 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.......04/09/10 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 e header data for each bit run in separate files. 6 .5000 START DE PTH 9323.0 9347.5 STOP DEPTH 9423.0 9447.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): 21-APR-04 Insite Memory 9448.0 9347.0 9448.0 17.6 23.0 TOOL NUMBER TLG013 3.000 8740.0 Flo Pro 8.60 60.0 9.0 15000 9.2 .000 .000 .000 .000 .0 137.5 .0 .0 e e # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT Rap GR MWD060 MWD060 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9323 9447 9385 249 9323 9447 Rap MWD060 FT/H 0.25 55.45 14.0208 200 9347.5 9447 GR MWD060 API 16.45 46.51 24.4733 201 9323 9423 First Reading For Entire File..........9323 Last Reading For Entire File...........9447 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/10 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...........l.O.O Date of Generation.. .....04/09/10 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 7 header data for each bit run in separate files. 7 .5000 START DEPTH 9423.5 9447.5 STOP DEPTH 9802.0 9825.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 22-APR-04 Insite e DATA TYPE (MEMORY OR REAL-TIME) : TO 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 GR MWD070 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API e Memory 9825.0 9448.0 9825.0 27.8 87.5 TOOL NUMBER TLG013 3.000 8740.0 F10 Pro 8.60 65.0 9.5 21 000 9.8 .000 .000 .000 .000 .0 141.7 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9423.5 9825 9624.25 804 9423.5 9825 ROP MWD070 FT/H 0.8 559.19 64.0673 756 9447.5 9825 GR MWD070 API 18.84 207.67 44.2823 758 9423.5 9802 First Reading For Entire File..........9423.5 Last Reading For Entire File...........9825 File Trailer Service name.............STSLIB.007 Service Sub Level Name... e Version Number...........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/09/10 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 e header data for each bit run in separate files. 8 .5000 START DEPTH 9802.5 9825.5 STOP DEPTH 10169.5 10193.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FTI: 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (SI: MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MTI: MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 23-APR-04 Insite Memory 10193.0 9825.0 10193.0 86.8 95.0 TOOL NUMBER TLG015 3.000 8740.0 Flo-pro 8.70 60.0 9.3 21000 6.8 .000 .000 .000 .000 .0 145.9 .0 .0 e e EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT Rap GR MWD080 MWD080 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9802.5 10193 9997.75 782 9802.5 10193 Rap MWD080 FT/H 0.37 3187.32 99.6958 736 9825.5 10193 GR HWD080 API 31. 74 207.4 89.8131 735 9802.5 10169.5 First Reading For Entire File..........9802.5 Last Reading For Entire File...........10193 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......04/09/10 Maximum Physical Record. .65535 Fi 1 e Type................ La Next File Name...........STSLIB.009 Physical EOF File Header Service name........ .... .STSLIB.009 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/10 Maximum Physical Record..65535 Fi 1 e Type................ La Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUHBER: DEPTH INCREHENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 9 header data for each bit run in separate files. 9 .5000 START DEPTH 10170.0 10193.5 STOP DEPTH 10848.5 10872.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 25-APR-04 Insite e DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL 1FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED IRPM): HOLE INCLINATION IDEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING ITOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY ILB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES IPPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE IMT): 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.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-ti~e...O Name Service Order DEPT ROP MWD090 GR MWD090 Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code Memory 10872.0 10193.0 10872.0 85.0 97.4 TOOL NUMBER TLG015 3.000 8740.0 Flo Pro 8.80 65.0 9.3 26000 5.2 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 154.3 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10170 10872.5 10521.3 1406 10170 10872.5 ROP MWD090 FT/H 0.18 1705.43 81.3127 1359 10193.5 10872.5 GR MWD090 API 32.4 249.89 113.988 1358 10170 10848.5 First Reading For Entire File..........l0170 Last Reading For Entire Fi1e...........10872.5 File Trailer Service name.............STSLIB.009 e e Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04!09!lO Maximum Physical Record..65535 File Type.............. ..LO Next File Name...........STSLIB.OIO Physical EOF Tape Trailer Service name.............LISTPE Date.....................04!09!lO Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04!09!lO Origin...................STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments...... ...........STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File