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200-011
STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Starting Head Weld Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 200-011 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21132-02-00 7. Property Designation(Lease Number): ADL 0028331 8. Well Name and Number: PBU 03-34B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED M!�'�o"o� J D Total Depth: measured 11263 feet Plugs measured feet true vertical 8752 feet Junk measured feet DEC 1 9015 6 Effective Depth: measured 11263 feet Packer measured See Attachment feet V L J true vertical 8752 feet Packer true vertical See Attachment feet OG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 2470 13-3/8"72#L-80 26-2496 26-2496 4930 2670 Intermediate 7475 9-5/8"47#L-80 24-7499 24-7040 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9923-11263 feet (1 ip SCOTrue vertical depth: 8729 8752 feet ° � .C 0 8 "L6 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 175 2359 1551 301 Subsequent to operation: Shut In 10 100 14.Attachments:(required Per 20 AAc 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro)6:44.1 Title PDC Principal Engineer Signature , / 4 Phone +1 907 564 4424 Date 12/16/15 Form 10-404 Revised 5/2015 VTL 1212 3//c RBDMS DEC 112015 Submit Original Only • • Packers and SSV's Attachment PBU 03-34B SW Name Type MD TVD Depscription 03-34B PACKER 7312.32 6874.22 7" Baker ZXP Mech Top Packer 03-34B TBG PACKER 9240.99 8527.57 4-1/2" HES Chrome Perm Packer 03-34B TBG PACKER 10173.64 8739.36 4-1/2" HES TNT Perm Packer • • Q.0 0 0 0 0 0 0 vcop. r� L � O N Lor- N- N- U ) 0 0 0 0 0 0 0 i 6) co N ct co co co Nr 0) CO N V ct m cf CO co co CO CO O (7o N V CA O O) a) La O co O CO N- O N- N I,- CO CO CO CO 0 H O r� co N N N N CO C N CO C CD CO O CO O MO Cr CA oD (� O co NO N r,- O) r O) VI I LJ.1 m. 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"C N 0 Et v) Z 0 u) ?) > OU23 � m130) t > o> mooO > Of c 0O -0ai c coa5c Z NII U) mO0 - EE � OO Vc -O Uc) O 0_C n 0WQ � c — /) `C Loo = J II •C " U) II ' Q_ W II a .0 - rn O U > IIOr r U) Q U) J Z 0 -0 � Wj00 `aU) 0) O 0 ma > O Ti; c � U) OwvO a) cn > � O )) o - a) p » a) > * U) Nr > Ca * W *) H 3U) U) H 0) _c .EF: 3W : II U) U) : .s F- c .E o_ U) HQF- U) t, U) U) U) U) U) U) U) U) r r r r r r r ,- c) c) o O O o 0 o O N N N N N N N 4co CD ti 00 r O r r r r r N N N r r r 1— r r r r r r r r r r r r • • c O E L Q d 2 F-- 0- 0 - QO m L2 � � -a (� M N M N O a) � o rn0 C = � co � � a) 2 2 2 O O a * 0 0 _ LL Tis• LF 0 0> W J U' 0J N W > m W W -I O 0 z 2QZ OQQQccccmaC70 F- F- F- v- NNI- Z � W O U) ZDDOWWW F- F- � QJ OH J J H F- J J w D D O W W WD 0 > N o_ a d O) U) U) d d 0 N r N m TREE= CNN • A I Y tV 70 I ES: WELL ANGLE> "a saw-4-1/Z" WAD= �EVOY 03-34B CHROME TBG'K'COMPOSITE WRAP REPAIR SHLEAK- ACTUATOR= BAKER C ���///-T DO NOT MIT-OA OVER 1200 PSI OLE TO DESIGNS) KB.ELEV= 54' PRESSURE RATING OF REPAIR 8 DO NOT PUMP METH BF.ELEV= I I OR METH BLEND INTO OA DUE TO CHEM KOP= 309gle 2' INCOMPATIBIUTY w/EPDXY RESIN***03-34A MILLOUT Max An = 92"@ 9703' Datum MD= 11394' ' II1989' -{4 112"HES X NP,D=3.813' DatumTVD= 8800'SS GAS LET M4NDREIS 13-3/8"CSG,72#,L-80,D=12.34r H 2501' ST MD TVD DEV TYPE VLV LATCH PORT DATE Lii 3804 3754 25 WAG DOMES RK 16 11/27/15 Minimum ID = 3.725" 9446' 2 6411 6080 28 WAG SO RK 20 11/27/15 3 7937 7450 16 KBG-2 DMY BK 16 06/14/13 4-1/2" HES XN NIPPLE 4 9133 8471 58 KBG-2 DMY BK 0 11/27/15 TOP OF 7'LNR H 7315' I— 7315' -I9-5/8"X 7"ZXP LIP,0=6.276" 7330' -I9-518"X 7"HMG LNR HGR D=6.188" 9-518"CSG,47#,L-80,D=8.681" H 7501' 9-5/8"MLLOUT VVWDOW(03-34B) 7501'-7515' r 9210' H4-1/2"FES XMP,D=3.813" Com' X- 9239' -17"X 4-1/2-HES PERM PKR,D=3.856" I ' 9274' --I4-1/2"HES X tom,D=3.813' I I 9344' H4-112"HTS XN NP,D=3.725" 4-1/2"TBG, 12.6#, 13CR 80 VAM TOP, -I 9373' .0152 bpf,ID=3.958' TBG STUB(04/16/10) H 9383' 1 9388' -17"X 4-1/2'UNIQUE OVERSHOT I , 9407' H4-1/2"X NP,D=3.813" S I 9428' -I 7"X 4-1/2'HES TNT PKR,D=3.875" ' r----I 9446' H41/2"FES XN NP,D=3.725" 4-112"TBG,12.6#,L-80 BTC-M, - 9457' I""'-7 \'--1 9457' -14-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" IH 9588' PERFORATION SUIMAARY - '-_- '-"'___-'" 9591' H PARTED LPB2 REP LOG:BRCS ON 04/XX/1992 ANGLE AT TOP PERF:90"@ 10911' Note:Refer to Ftoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ' ' 4-1/2" SLID 9923-11263 SLOT 03/24/00 I I I 4-1/2"LW,12.6#,L-80,.0152 bpf,D=3.958" -I 11263' , , DATE REV BY (X)PJ ITS [GATE REV BY COMFITS PRUDHOE BAY UNIT 03/01/86 WSR1 ORIGINAL COMPLETION 12/02/15 RJK/JI D GLV GO(11/27/15) WELL: 03-348 04/15/92 N2ES SIDETRACK(03-34A) 12/02/15 JTG/JMD PULLED PLUG(11/27/15) PERM T No:"2000110 03/24/00 N9BS SIDETRACK(03-34B) AR No: 50-029-21132-02-00 04/21/10 N4E5 RWO SEC 11,T10N,R15E,97'FSL 8 846'FWL 06/15/13 LEF/PJC GLV GO/SET PX PLUG (06/14/13) 06/16/13 L8/PJC SET FLOW SLEEVE(06/15/13) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) [] Two-Sided RESCAN [] Color items: -~/~rayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA ~"/' Diskettes, No./ [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTALPAGES: ~ ~ NOTES: ORGANIZED BY; BEVERLY BREN~SHERYL MARIA LOWELL [] Other DATE: Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BRE~ SHERYL MARIA LOWELL Scanned (done} PAGES' SCANNED BY: (at the time of scanning) BEVERLY BREN VINCEN~ MARIA LOWELL F~ESCANNEDBY: BEVERLY B~HERYL MARIA LOWELL General Notes or Comments about this file: PAGES' Quality Checked (done) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 a o o - © I 03 4.1 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 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, y ' �� F EB9.2.Zt:121 Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTO # API # cement pumped cement off date inhibitor sealant date ft bbls ft gal 03 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03-02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03-03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03-06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03-07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03-08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03 -10 1790210 50029203610000 Sealed conductor NA NA NA NA NA , 03-11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03-12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03-14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03-15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03-16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03 -17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03-19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03-20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03-21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03-22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03-23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03-24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/12/2011 13.6 7/17/2011 03-26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03-27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/172011 03-28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 03-29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 03-33B 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 ^ 03-34B 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03-35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 03-37 2091390 50029234210000 2.5 NA 2.5 NA 16.2 8/2/2010 , . STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei FURMANITE WRAP Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ - 200 -0110 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 � 50- 029 - 21132 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADL 028327 & 028331 .. PBU 03 -34B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11263 feet Plugs (measured) None feet true vertical 8752.48 feet Junk (measured) None feet Effective Depth measured 11263 feet Packer (measured) 9239 9428 feet true vertical 8752.48 feet (true vertical) 8527 8623 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" SURFACE - 110 SURFACE - 110 Surface 2501' 13 -3/8" 72# L -80 SURFACE - 2501 SURFACE - 2501 4930 2270 Production 7501' 9 -5/8" 47# L -80 SURFACE - 7501 SURFACE - 7501 6870 4760 Liner 2273' 7" 26# L -80 7315 - 9588 6877 - 8699 7240 5410 Liner 1810' 4 -1/2" 12.6# L -80 9453 - 11263 8635 - 8752 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 26 - 9397 26 - 8607 4-1/2" 12.6# L -80 9383 - 9457 8600 - 8637 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" HES PERM PKR 9239 8527 4 -1/2" HES TNT PKR 9428 8623 *414116E0 APR ► 2 loft FC EIV 12. Stimulation or cement squeeze summary: Intervals treated (measured): APR y) 4 2. 1` Treatment descriptions including volumes used and final pressure: Wks Com Commission F�1i 13. Representative Daily Average Production or Injection. Uf Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratoryD Development 0 1 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. ig 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 e J. - Lastu a . t r Title Data Manager Signatu • 1 111 1 • Phone 564 -4091 Date 4/1/2011 RBDAAS APR 08 2011 Ci Li. /Z • // Form 10 -404 Revised 10/2010 Submit Original Only 2 03 -34B 200 -011 PERF ATTACHMENT . Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -34B 3/24/00 SL 9,923. 11,263. 8,729.43 8,752.48 03 -34B 7/28/08 BPS 9,407. 11,263. 8,612.31 8,752.48 03 -34B 8/27/08 BPP 9,407. 11,263. 8,612.31 8,752.48 03 -34B 7/31/09 BPS 9,430. 9,923. 8,623.83 8,729.43 03 -34B 8/7/09 MLK 9,591. 9,592. 8,700.38 8,700.77 03 -346 2/11/10 BPS 9,394. 9,923. 8,605.77 8,729.43 03 -34B 4/19/10 BPP 9,430. 11,263. 8,623.83 8,752.48 03 -34B 12/17/10 BPS 9,274. 11,263. 8,544.58 8,752.48 03 -34B 3/29/11 BPP 9,274. 11,263. 8,544.58 8,752.48 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 III • • l• 03 -34B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/15/2011 T /I /O= 8Nac /3. Temp =SI. Bleed IA & OA to 0 psi, install N2 cap, pull grating (pre- Furmanite). ALP =710 psi, SI @ casing valve. OA FL near surface. Bled OAP from '3 psi to 0 psi in 30 secs (all gas). Monitored 30 mins, OAP remained the same. Purged OA w /N2 twice, installed a 25 psi N2 cap. Bled ALP from 710 psi to 100 psi. Removed floor grating, flagged & tagged both doors. Final T /I /O= 8Nac /25. I ** Job in Progress ** SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. 3/16/2011 T /I /O= 8Nac /27. Temp =Sl. Assist CCI sand - blasting, bleed OAP to 0 psi, maintain an open OA bleed (Furmanite). ALP =100 psi, SI @ casing & lateral valves. OAP increased 2 psi overnight. Monitored air quality during sand - blasting operations. Bled OAP from 27 psi to 0 psi in 4 mins (all gas). Maintained an open OA bleed for I Furmanite E -glass application (see log for details). Continued on night shift. * In Progress ** 3/17/2011 Continued from 3 -16 -11 WSR T /I /O = 0/ Vac /0. Temp = SI. Maintain open bleed on OA for Furmanite. Job ( continues into 2nd day. ALP = 160 psi SI @ casing valve. C/O with night crew. See log for details. 3/18/2011 Continued from 3 -17 -11 WSR. °T /I /O= NA/0 /0. Maintain open OA bleed. (Furmanite). Continue 3rd day. AL SI @ (casing valve. ALP =160 psi. C/O with night crew. See log for details. � i 3/19/2011 IT /I /O =NA/0 /0. Maintain open OA bleed. (Furmanite). Continued from 3 -18 -11 WSR. AL SI @ casing valve. ALP =160 psi. See log for details. Continued on next days IAWGRS. Final WHPs= NA/0 /0. E � I 3 /20 /20111 from 03 -19 -11 WSR IT /I /O= NA/0 /0. Temp =SI. Maintain open bleed on OA (Furmanite). AL is connected, SI @ casing valve & lateral. ALP =220 psi. Furmanite starting post cure. See log for I details. * *Drill performed on heater fire with WIE** 3/21/20111 Continued from 03/20/2011 1 T /l /O= 15/0/0. Temp= SI. Maintain an open bleed on OA ( Furmanite). ALP= 220 psi SI @ casing valve & lateral. Furmanite ongoing post cure. 'See log for details. Fumanite bleed complete RDMO. Final WHPs= 15/0/0. ;Job complete. SV, WV =C. SSV, MV =O. IA &OA =OTG. NOVP. FLUIDS PUMPED BBLS NONE USED TREE = • CIW • SAFETY NO. WELL ANGLE> 70° @ 9609' * ** 4-1/2" WELLHEAD = MCEVOY CHROM ET * COM POSBTE WRAP REPAIR SH LEAK- 'ACTUATOR = BAKER C DO NOT MIT -OA OVER 1200 PSI DUE TO DESIGNED KB. ELEV = 54' PRESSURE RATING OF REPAIR & DO NOT PUMP METH BF. ELEV 1 I OR METH BLEND INTO OA DUE TO CHEM KOP = 3092' INCOMPATIBILITY w/ EPDXY RESIN ** *03 -34A M ILLOUT Max Angle= 92° @ 9703' Datum MD = 11394' ' ' 1989' H4-1/2" HES X NIP, ID = 3.813" 1 Datum TV D = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2501' FA ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3804 3754 25 MMG DOME RK 16 04/26/10 Minimum ID = 3.725" @ 9446' 2 6411 6080 28 MMG DOME RK 16 04/26/10 3 7937 7450 16 KBG -2 DOME BK 16 04/26/10 4 -1/2" HES XN NIPPLE 4 9133 8471 58 KBG -2 SO BK 20 04/26/10 I TOP OF 7" LNR H 7315' 7315' H9-5/8" X 7" ZXP LTP, ID = 6.276" I 7330' H9-5/8" X 7" HMC LNR HGR, ID = 6.188" 1 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I - 1 7501' I- 9-5/8" MILLOUT WINDOW (03 -34B) 7501' - 7515' 1 ( 9210' H4-1/2" HES X NIP, ID = 3.813" 1 g ( 9239' 1-17" X 4 -1/2" HES PERM PKR, ID = 3.856" 1 1 I 9274' H4-1/2" HES X NIP, ID = 3.813" I 1 1 9344' 1 HES XN NIP, ID = 3.725" 1 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, — 9373' .0152 bpf, ID = 3.958" 1TBG STUB (04/16/10) I 9383' I 9388' 1 - 17" X4 -1/2" UNIQUE OVERSHOT 1 ' 1 1 9407' 1 - 14 - 1/2" X NIP, ID = 3.813" 1 g I 9428' H " X 4 -1/2" HES TNT PKR, ID = 3.875" 1 ' ' 1 9446' H4-1/2" HES XN NIP, ID = 3.725" 1 4 -1/2" TBG, 12.6 #, L -80 BTC-M, —1 9457' 9457' H4 -1/2" WLEG, ID = 3.958" 1 .0152 bpf, ID = 3.958" 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 9588' 1 • PERFORATION SUMMARY —�� 1 9591' I - 1 PARTED LINER 1 REF LOG: BHCS APR 92 ANGLE AT TOP PERF: 90 @ 10911' Note: Refer to Production DB for historical perf data SIZE I SPF INTERVAL Opn /Sqz DATE 1 SLOTTED 9923 - 11263 O 03/24/00 1 1 1 4 -1/2" LNR -SLTD, 12.6 #, L -80, .0152 bpf, ID = 3.958" I— 11263' I A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/01/86 WSR1 ORIGINAL COMPLETION 02/26/11 MW /PJC SFTY NOTE (COMPOSITE WRAP) WELL: 03 -34B 04/15/92 N2ES SIDETRACK (03 -34A) 03/31/11 JCM/PJC PULL PX PLUG (03/29/11) PERMIT No: ° 2000110 03/24/00 N9ES SIDETRACK (03 -34B) API No: 50- 029 - 21132 -02 -00 04/21/10 N4ES RWO SEC 11, T1ON, R15E, 97' FSL & 846' FWL 01/02/11 WEC/PJC SET PX PLUG (12/17/10) 01/02/11 WEC/PJC XN NIP CORRECTION @ 9344' BP Exploration (Alaska) ALAS IL AND GAS CONSE VA ON COMMI N REPO~OF SUNDRY WELL OPERA~NS MAY~82010 1. Operations Performed: (~IISSIGi ;; 1dSKc~ t~H~ ~ ~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-011 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21132-02-00 7. Property Designation: ~ 8. Well Name and Number: ~ ADL 028327 & 028331 PBU 03-34B 9. Field / Poal(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 11263' feet true vertical 8752' feet Plugs (measured) None Effective depth: measured 11263' feet Junk (measured) None true vertical 8752' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2501' 13-3/8" 2501' 2501' 4930 2670 Intermediate 7501' 9-5/8" 7501' 7042' 6870 ~ 4760 Production Liner 2273' 7" 7315' - 9588' 6877' - 8699' 7240 5410 Liner 1810' 4-1/2" 9453' - 11263' 8635' - 8752' 8430 7500 Perforation Depth: Measured Depth: Slotted Liner: 9923' - 11261' True Vertical Depth: 8729' - 8752' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr80 / L-80 9457' 8637' Packers and SSSV (type, measured and true vertical depth): 7" x 4-1 /2" HES Chrome Perm Packer; 9239' 8527 ; 4-1/2" x 7" HES 'TNT packer 9428' 8623' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: , r .y ~ ~~;'~ ~ ;ilk.. ~.... ~ . ~- 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 4. Well Class after work: ^ Exploratory ®Development ^ Service Re ort of Well O erations ® Dail y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 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 Hank Baca, 564-5444 N/q Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: Signature Phone 564-4628 Date ~ $ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 ~~D"c uAY ~ ~ 'n~~7 C Submit Original Only ~3~~ ~J • 03-34B, Well History (Pre Rig Workover) Date Summary 2/5/2010 T/IA/OA= SI/160/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T : RU 1 HP BT onto THA 0 psi, opened SBS verified 0 psi flushed void until clean returns achieved. Pressured void to 5000 psi for 30 min, 4900/ 15 mins, 4900/ 30 mins. Bled void to 0 psi, RD test equipment, re-installed Alemite cap. Cycle and torque LDS "Standard" (1) LDS was very hard to break free all others were in good working and visual condition. PPPOT-IC : RU 1 HP BT onto IC 100 psi bled to 0 psi, opened SBS verified 0 psi flushed void until clean returns achieved. Pressured to 3500 psi for 30 minutes, 3400/ 15 minutes, 3400/ 30 minutes. Bled void to 0 psi, RD test equipment, re-installed Alemite cap. Cycle and torque LDS "Standard" all were in good working and visual condition. *** Notified W IE LDS C~ 3:00 needs to be pulled to verify pin is not broke *** 2/7/2010 T/I/O = 0/130/30. Temp=Sl. Bleed WHPs to 0 psi (pre RWO). AL spool is dropped. Integral on IA. IA FL Q 200'. Bled IAP to BT from 130 psi to 0 psi in 6 hr. OA FL near surface. Bled OAP from 30 psi to 0 psi in 10 min., fluid to surface. Monitor IAP & OAP for 1 hr. IAP increased 1 psi, rebled IAP to 0 psi in 1 min. OAP unchanged. Heater is working and directed ~ pack-offs. Cameron arriving upon departure. Job complete. Final WHPs=O/0/0. 2/7/2010 T/IA/OA= 0/0/0 temp=warm PPPOT-T (PASS) (Verified LDS not broke) PPPOT-T : RU 1 HP BT onto ThiA 50 psi bled to 0 psi, opened SBS verified 0 psi in void. Removed G/N and LDS from flange no damage on threads or nose of pin, installed back into well head. Torqued LDS and made up G/N. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD all test equipment. Job complete. 2/11/2010 WELL S/I ON ARRIVAL. DRIFT TO 4-1/2" BKR COMPOSITE PLUG AT 9,416' SLM_/ 9,430' MD W/ 3.80" G-RING. SET 4-1/2" BAKER QUIK-DRILL COMPOSITE PLUG AT 9,394' SLM. JOB IS NOT COMPLETE, LRS STILL NEEDS TO CMIT- TxIA TO 3500 PSI. WELL LEFT S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 2/13/2010 T/I/0= 0/0/0 Temp= SI CMIT TxIA PASSED to 3500 psi, MIT-OA PASSED to 1000 psi (Pre RWO). Pressured up T/IA to 3500 psi w/ 26.4 bbls crude. 4th test results - T/IA lost 40/40 psi in 1st 15 min, T/IA lost 40/40 psi in 2nd 15 min, 3rd 15 min lost 20/20 for a total loss of 120 psi in 45 min test. Bled back 8 bbls. Pressured up OA to 1000 psi w/ .8 bbls crude. 1 st 15 min OA lost 80 psi, 2nd 15 min OA lost 20 psi with a total loss of 100 psi in 30 min test. Bled back 1 bbl crude. Final WHPs= 300/380/50 2/28/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 220/100/0 PSI. JET CUT TUBING WITH 3.65" SLB POWERCUTTER AT 9376'. CCL TO CUTTER: 16.3'. CCL STOP DEPTH: 9359.7'. FINAL T/I/O: 0/100/0 JOB COMPLETE. 3/8/2010 T/I/0=40/80/0 Temp= SI Circ-Out TxIA (Pre RWO). Attempted to verify flow path down FL. Pumped 4 bbls meth, FL pressured up. Bled pressure back, well support in route to RU hardline jumper to 03-32. Currently standing by for HL. 3/9/2010 Circ Out, CMIT TxIA PASSED to 1000 psi. (PRE RWO) Pumped 2 bbls meth, 842 bbls seawater down the tubing through cut C~ 9376' up the IA down the flowline on well 3-32 (flowing). Freeze protect with 150 bbls 110°f diesel. Freeze protect hardline with 2 bbls meth and 10 bbls 110°f diesel. Pumped 1.5 bbls of diesel down IA to achieve test pressure. 2nd test results - 1st 15 min T/IA lost 40/40 psi, 2nd 15 min T/IA lost 10/10 psi with a total loss of 50/50 psi in 30 min test. Bled pressures to 0 psi. Final WHPs= 0/0/0 Page 1 of 1 • BP EXPLORATION Operations Summary Report- Legal Well Name: 03-34 Page 1 of 1 Common Well Name: 03-34 Spud Date: 3/7/2000 Event Name: MOBILIZATION Start: 4/15/2010 End: 4/17/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations. 4/14/2010 03:00 - 06:00 3.00 MOB P PRE LD DERRICK AND PERP FOR RIG MOVE 06:00 - 09:00 3.00 MOB P PRE LOAD PITS AND PIPE SHED FOR MOVE TO DS-3 -MOVE RIG OFF DS-17-08 -TRAVEL TO DS-3 09:00 - 11:00 2.00 MOB P PRE -ON LOCATION X0900 HRS 4/14/2010 -SPOT RIG ON WELL 34 @ 1000 HRS 11:00 - 13:00 2.00 RIGU PRE -RAISE DERRICK @ 1100 HRS ""RIG ACCEPTED AT 1300 HRS 4/14/2010 *" 13:00 - 15:00 2.00 RIGU P PRE TAKE ON HEATED SEAWATER -RU SECOND IA VALVE -RU TIGER TANK AND HARD LINE 15:00 - 18:00 3.00 RIGU P PRE MU DSM LUBRICATOR - PJSM, RETIME AXELSON ACTUATOR. - INSTALL FUSEABLE CAP. - TEST TO 500 PSI W/ DIESEL - PULL BPV, LD LUBRICATOR. OA ON VAC, IA AND TUBING 0 PSI - RD LUBRICATOR - PRESSURE TEST KILL LINES TO 4000 PSI. Printed: 5/6/2010 10:39:56 AM • • BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: 03-34 Common Well Name: 03-34 Spud Date: 3/7/2000 Event Name: WORKOVER Start: 4/17/2010 End: 4/21/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task ~ Code ~ NPT ~ Phase 4/14/2010 18:00 - 18:30 0.501 KILL P 18:30 - 23:30 I 5.001 KILL I P 23:30 - 00:00 I 0.501 KILL I P 4/15/2010 100:00 - 02:00 I 2.001 KILL I P 02:00 - 03:00 1.00 WHSUR P 03:00 - 05:00 I 2.001 WHSUR I P 05:00 - 07:00 2.001 BOPSUp P 07:00 - 07:30 0.50 BOPSUF~ P 07:30 - 14:00 6.50 BOPSU P Description of Operations DECOMP RU SUFACE LINES TO TREE -PJSM ON WELL KILL OPERATIONS -TEST SURFACE LINES TO 3500 PSI DECOMP CIRCULATE WELL. SWAP WELL OVER TO SEAWATER. -REVERSE CIRCULATED 65 BBLS DOWN THE IA TAKING RETURNS UP THE TUBING THROUGH THE CHOKE OUT TO THE TIGER TANK, --PUMPED 60 BBLS BEFORE GETTING RETURNS - 2-4 BPM ,30-240 PSI , PUMPED DOWN TUBING AND UP THE IA, -3- 5 BPM @ 170-470 PSI -PUMPED 12,000 TOTAL STROKES. --CIRCULATED 710 BBLS TOTAL DECOMP SHUT DOWN AND MONITOR WELL -TUBING PSI 0 , IA PSI 0 -ND AND BLOW DOWN LINES -WAITING ON DSM TO FINISH ON ENDICOTT JOB DECOMP SHUT DOWN AND MONITOR WELL -TUBING PSI 0 , IA PSI 0 -ND AND BLOW DOWN LINES -WAITING ON DSM TO FINISH ON ENDICOTT JOB DECOMP DRAIN TREE, DRIFT TREE -DRILL SITE MAINTENCE TO DRY ROD A 5" ISA BPV -500 PSI TEST FROM BELOW 10 CHARTED MIN DECOMP N E -BLEED ADAPTOR -CAMERON INSPECT HANGER THREADS. GOOD CONDITION - MU THE LANDING JNT 6-1/8" LH ACME XO TO THE HANGER TOOK 9 TURNS - INSTALLED BLANKING PLUG ON BPV DECOMP NU 13-5/8" GK HYDRIL ROPE -JEFFJONES, STATE AOGCC INSPECTOR WAIVED WITNESS FOR TEST @ 20:30 ON 4/13/2010 DECOMP HELD H2S DRILL WITH DAY CREW. DECOMP TEST ROPE PER BP/AOGCC REQUIREMENTS: -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 3-1/2" X 6" VBR'S WITH 3-1/2" & 4-1/2" TEST JOINTS. -TESTED ANNULAR WITH 3-1/2" TEST JOINT T/ 3,500 PSI -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY NABOBS TOOLPUSHER / WSL -TESTED FLOOR VALVES. -PERFORM KOOMEY TEST -200 PSI BUILD UP TO 3000 PSI FROM 1650 PSI = 46 SECONDS. -FULL BUILD UP TO 3000 PSI = 187 SECONDS. -4 BOTTLES x 1850 PSI. -TESTED 3 1/2" KELLY AND KELLY VALVE Printed: 5/6/2010 10:40:04 AM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: 03-34 Common Well Name: 03-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT Spud Date: 3/7/2000 Start: 4/17/2010 End: 4/21 /2010 Rig Release: 4/21 /2010 Rig Number: 4ES Phase Description of Operations 14/15/2010 07:30 - 14:00 6.50 BOPSU P DECOMP *** CHUCH SCHEVE AOGCC STATE INSPECTOR WAIVED WITNESS OF TEST @ 0720 HRS 4/15/2010*** 14:00 - 14:30 0.50 WHSUB P DECOMP PULL BLANKING PLUG FROM BPV. 14:30 - 15:00 0.50 WHSUB P DECOMP NU RISER SPACER AND DUTCH SYSTEM , 15:00 - 16:00 1.00 WHSUB P DECOMP PU LUBRICATOR AND TEST TO 500 PSI. -WELL SUPPORT PULL ISA CAMERON BPV -LD LUBRICATOR AND DUTCH SYSTEM. 16:00 - 17:00 1.00 WHSUB P DECOMP MU LANDING JOINT WITH TIW VALVE -TBG / IA / OA = (0) PSI -CAMERON REP BOLDS -PULL HANGER TO FLOOR PUW = 105K. SOW = 93K. -LD TBG HANGER -MU TIW VALVE 17:00 - 18:30 1.50 PULL P DECOMP CIRCULATE BOTTOM UP 4-5 BPM C~ 300 PSI -CIRCULATE A TOTAL OF 501 BBLS. 18:30 - 19:00 0.50 PULL P DECOMP POOH WITH 4-1/2" L-80 TUBING FROM 9,376' 19:00 - 20:00 1.00 PULL N SFAL DECOMP WHILE BREAKING OUT A JNT OF 4-1/2" TUBING PIECE OF METAL FELL FROM THE ELEVATORS ,HIT THE POWER TONGS THEN RICHOCHET UP AND HIT A FLOOR HAND IN THE FACE. -OPERATIONS WERE STOPPED AND THE AREA CLEARED. -THE IP WAS CHECKED OUT & MADE SURE HE WAS OK. -DRILLER THEN CALLED TP AND WSL. -RIG HAND WENT UP TO INSPECT THE ELEVATORS SO THAT WE MAY SAFELY LD THE JNT OF CASING. -SENT THE IP TO THE MEDIC, LD THE JNT AND ELEVATORS FOR INSPECTION. ON CLOSER INSPECTION IT WAS FOUND THAT A INSERT TAB ON THE INSIDE OF THE ELEVATORS HAD BROKE AND FALLEN OUT. -IR IN TRACTION # 3459612 20:00 - 00:00 4.00 PULL P DECOMP RELIEVED NEW ELE R M _ -CONY: POOH WITH 4-1/2" L-80 TUBING FROM 9,376' 4/16/2010 00:00 - 06:00 6.00 PULL P DECOMP POOH , LD 4-1/2" L-80 TUBING FROM 9,376' MD TO JOINT #212 06:00 - 06:30 0.50 PULL P DECOMP PERFORM PRE-TOUR CHECKS /RIG SERVICE. 06:30 - 07:30 1.00 PULL P DECOMP POOH , LD 4-1/2" L-80 TUBING FROM JOINT # 212 TO SURFACE. -SMALL HOLES FOUND IN THE LAST 4 JOINTS. -CUT JOINT # 227 = 19.40' 07:30 - 08:30 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. -4-1/2" HANDLING EQUIP. 08:30 - 10:00 1.50 CLEAN P DECOMP PJSM-1/4HRS WITH BAKER REP ON BHA. -PU/MU 4-1/2" DRESS-OFF MILL ASSEMBLY -6" X 4-9/16" DRESS OFF SHOE, (4) EXTENSION, INNER MILL, -BOOT BASKET, XO, 7" SCRAPER, XO, BUMPER SUB, - (9) 4-314" DC'S = 310.34' 10:00 - 20:00 10.00 CLEAN P DECOMP RIH WITH BHA #1 -PU 3-1/2" DP FROM PIPE SHED I -ONE BY ONE. Printed: 5/6/2010 10:40:04 AM • BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 03-34 Common Well Name: 03-34 Spud Date: 3/7/2000 Event Name: WORKOVER Start: 4/17/2010 End: 4/21/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date I From - To I Hours I Task I Code I NPT I .Phase. 4/16/2010 110:00 - 20:00 I 10.00 I CLEAN I P 20:00 - 21:30 1.501 CLEAN P 21:30 - 23:00 I 1.501 CLEAN I P 23:00 - 00:00 I 1.001 CLEAN I P Description of Operations DECOMP -TO JOINT #226 ~ 1700 HRS. -WORK PIPE TO INTER 7" LINER TOP @ -7315' MD -PUW=97K, SOW=87K. -PU JOINT # 227 - 291 TAG 4-1/2" STUB C~ 9,382'MD DECOMP PU KELLY AND TAG 4-1/2" TBG STUB C~2 9,382"MD -PUW =130K, -DRESS OFF 4-1/2" TUBING STUB -SOW = 107K, RPM-60, ROT/TQ.-160 AMP -3 BPM / 470 PSI -TOP OF STUB ~ 9,383' DECOMP POOH LD 3-1/2" DP -PULL OUT OF 7" LINER TO -7,300' TO SET STORM PACKER -RICIPROCATED PAST THE NEW PACKER SETTING DEPTH -7,200' 4 TIMES. DECOMP PU HALLIBURTON 9-5/8" STORM PACKER 4/17/2010 100:00 - 01:00 I 1.00 WHSUR P 01:00 - 02:30 I 1.501 BOPSUS P DECOMP SET HALLIBURTON 9-5/8" STORM PACKER -SET PACKER 23' IN -SECOND BARRIER CBP C~ 9,407' MD -RU TEST EQUIPMENT -TEST FOR 10 CHARTED MIN ~ 1000 PSI. -SUCK OUT STACK & BLOW DOWN LINES, RD TEST EQUIPMENT. DECOMP ND & SET BACK 13-5/8" BOPE 02:30 - 06:00 3.50 WHSUR P DECOMP REPLACE TUBING SPOOL AND 9-5/8" PACK OFF. -PULLED 9-5/8" PACK OFF -ATTEMPTED TO PULL TBG SPOOL UNSUCESSFULLY -WRAP THE SPOOL AND PUT STEAM IT TO TRY AND GET IT TO FREE UP. 06:00 - 10:00 4.00 WHSUR P DECOMP USED WEDGES AND "FLANGE SPREADER' WITH RIG BLOCKS TO REMOVE TBG SPOOL. 10:00 - 12:00 2.00 WHSUR P DECOMP INSTALL NEW McEVOY SSH A3-5/8" X 13-5/8" 5M. 2 SSO -MCEVOY 9-5/8" YBT MANDREL PACKOFF. -PACKOFF TESTED 5000 PSI F/ 30 MINUTES, WITNESSED BY WSL. 12:00 - 13:30 1.50 BOPSU P DECOMP NU BOPE, INSTALL UPPER TEST PLUG. 13:30 - 14:30 1.00 BOPSU P DECOMP TEST BOPE -TEST ALL BREAKS -250 / 3,500 PSI FOR 5 CHARTED MINUTES. -CONFIR WITH ADW RWO ENG ON CHASE CBP TO 9460' MD. 14:30 - 15:30 1.00 CLEAN P DECOMP ENGAGE AND RELEASE 9-5/8" STORM PACKER -(0) PRESSURE -LD STORM PACKER 15:30 - 16:00 0.50 WHSUR P DECOMP INSTALL SHORT WEAR RING 16:00 - 20:00 4.00 CLEAN P DECOMP POH F/ 7,300' MD -STAND 3-1/2" DP IN DERRICK. -DISCUSSED WITH AOGCC STATE INSPECTOR CHUCK SCHEVE THAT WE WILL RE-TEST ANNULAR BECAUSE Printed: 5/6/2010 10:40:04 AM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 03-34 Common Well Name: 03-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date -From - To Hours Task Code NPT Spud Date: 3/7/2000 Start: 4/17/2010 End: 4/21 /2010 Rig Release: 4/21/2010 Rig Number: 4ES Phase Description of Operations 4/17/2010 16:00 - 20:00 4.00 CLEAN P DECOMP WE USED IT WHILE RELEASING STORM PACKER. 19:25 HRS 4/17/2010. 20:00 - 22:00 2.00 CLEAN P DECOMP BREAK AND LAY DOWN BHA # 1 -1/2 GAL OF METAL SHAVINGS AND SCALE RECOVERED FROM BASKET. 22:00 - 00:00 2.00 BOPSU P DECOMP CLEAN & CLEAR RIG FLOOR -RU TEST EQUIPMENT FOR BOP TESTING -PU, MU 3-1/2" TEST JOINT AND TEST PLUG -TEST THE ANNULAR TO 250 PSI LOW , 3500 PSI HIGH -BARRIERS IN PLACE CBP Q9,414' MD AND TEST PLUG IN TBG SPOOL AND CLOSED BLIND RAMS IN BOP. 4/18/2010 00:00 - 00:30 0.50 BOPSU P DECOMP TEST 13-5/8" ANNULAR -TEST THE ANNULAR TO 250 PSI LOW , 3500 PSI HIGH -TEST FAILED 00:30 - 02:00 1.50 BOPSU N RREP DECOMP -ANNULAR FAILED TO TEST. -DECISION WAS MADE TO CHANGE OUT RUBBER ELEMENT. -LD 3-1/2" TEST JOINT -ND DUTCH RISER FLANGE 02:00 - 06:00 4.00 BOPSU N RREP D ECOMP PJSM ON REMOVAL AND CHANGE OUT OF ANNULAR ELEMENT -PULLED THE LID OFF THE TOP -CHANGING OUT RUBBER ELEMENT. -BARRIERS IN PLACE ARE CLOSED TESTED BLIND SHEARS AND A COMPOSITE BRIDGE PLUG SET @ 9,414' 06:00 - 06:30 0.50 BOPSU N D ECOMP RIGSERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 13:00 6.50 BOPSU N D ECOMP NU DUTCH FLANGE AND RISER SYSTEM. -PU 3-1/2" TEST JOINT -NEW ELEMENT BEING STUBBORN TO TEST -PU 2-7/8" TEST JOINT AND FLEX CLOSING MANY TIMES. -TEST 250 PSI / 3,500 PSI FOR 5 CHARTED MINUTES. -RD TEST EQUIPMENT AND SUCK-OUT BOP STACK. 13:00 - 13:30 0.50 WHSUR P D ECOMP INSTALL 9.25" I.D. WEAR RING 13:30 - 15:00 1.50 CLEAN P D ECOMP MU BHA #2 -CONVEX JUNK MILL, XO, (3) JTS 2-7/8" HT PAC DP, XO, BUMPER SUB, PUMP-OUT-SUB, (9) 4-3/4" DC's = 385.51' 15:00 - 21:30 6.50 CLEAN P D ECOMP RIH W/ BHA #2 ON 3-1/2" DP FROM DERRICK -TIH W/ 96 STANDS , 24' PUP TO 9,398' MD 21:30 - 00:00 2.50 CLEAN P D ECOMP CIRCULATE AND CONDITION -DISPLACE WELL WITH 8.45 PPG HEATED SEAWATER Q 5 BPM, 1500 PSI. -SHUT DOWN MONITOR WELL -PUMPED TOTAL OF 560 BBLS. 4/19/2010 00:00 - 01:00 1.00 CLEAN P D ECOMP NABOBS WEEKLY SAFETY MEETING. -REVIEWED IADC INCIDENTS AND NEAR MISSES -REVIEWED ADW WEEKLY SAFETY -ROUGH NECK TRAINER GAVE THE HANDS DIRECTIONS ON GAS DETECTORS 01:00 - 03:00 2.00 CLEAN P D ECOMP RIH & TAGGED FIRST CBP ~ 9 414' MD -UP WT 134K ,DOWN WT 115 WITH KELLY -STARTD MILLING WITH 50 RPM, 3-BPM @ 540PS1 ,ROT WT-125K, Printed: 5/6/2010 10:40:04 AM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 03-34 Common Well Name: 03-34 Spud Date: 3/7/2000 Event Name: WORKOVER Start: 4/17/2010 End: 4/21/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 14/19/2010 101:00 - 03:00 I 2.001 CLEAN I P 03:00 - 12:30 9.50 ~ CLEAN P 12:30 - 14:00 I 1.501 CLEAN I P 14:00 - 14:30 0.50 14:30 - 17:00 2.50 17:00 - 00:00 I 7.001 RUN 4/20/2010 100:00 - 06:00 I 6.001 RU 06:00 - 10:00 I 4.00 10:00 - 12:00 I 2.00 12:00 - 12:30 I 0.50 12:30 - 15:00 ~ 2.50 DECOMP 170-185 AMPS. -TAGGED SECOND CBP C~ 9,430' MILLED AT 50 RPM, 3-BPM C~ 540PSI ,ROT WT-125K, 170-185 AMPS -MILLED AND PUSHED OUT OF TAILPIPE TO 9,460' -MAINTAINING 60 BPH HOLE FILL. DECOMP RU TO TOH W /MILLING BHA #2 -RACK BACK KELLY -POH LD 3-1/2" DP, F/ 9,460' MD -MAINTAINING 60 BPH HOLE FILL. -FLOW CHECK AT THE BHA, 60 BPH WITH NO RETURNS. DECOMP LD MILLING BHA # 2 -MILL WAS GRADED AT 50 % WORN. -TIP NOT WORN BAD. -HALF WAY BACK ON THE CONE THE CARBIDES WERE WORN 50 RUNCMP PULL WEAR RING -PULLED 9.25" ID WEAR RING RUNCMP RU TO RUN COMPLETION. -RU TORQUE TURN EQUIPMENT. -SINGLE JT COMPENSATOR. -RU STABBING BOARD. -SETUP DOUBLE STACK TONGS. RUNCMP RIH WITH 4-1/2", 12.6, 13CR80 COMPLETION PER --_ -- , _ , _------ PROGRAM -MU 4-1/2",12.6# ,13CR-80, USING COMPENSATOR AND TORQUE TURN, -USING JET LURE SEAL GUARD THREAD COMPOUND -TORQUE 4,400 FT-LBS -RAN 105 JNT IN. RUNCMP RIH WITH 4-1/2", 12.6 #/FT, 13CR-80 COMPLETION PER PROGRAM -F/JNT 115 TO JNT 190 -MU 4-1/2",12.6# ,13CR-80 ,USING COMPENSATOR AND TORQUE TURN, -USING JET LUBE SEAL GUARD THREAD COMPOUND -TORQUE 4,400 FT-LBS RUNCMP RIH WITH 4-1/2", 12.6, 13CR80 COMPLETION PER PROGRAM -F/ JT #190 TO JT #218. RUNCMP SPACE OUT 4-1/2" COMPLETION -WORK, FLUSH AND THEN WORK OVER 4-1/2" STUB (W/ PUMPS OFF) -OVER PULL TO 20K -SOW=40K ON NO-GO -LD JT #218 AND ADD 2.06' PUP BELOW JT #217. -PUW=207K, SOW=87K RUNCMP LAND TUBING -MU TIW VALVE /LANDING JOINT / TBG HANGER -LAND AND CAMERON REP RILDS. RUNCMP DISPLACE WELL -PJSM W/TRUCK DRIVERS -REVERSE CIRCULATE 450 BBLS, 120 Deg CORROSION INHIBITED SEAWATER IN THE I.A. Printed: 5/6/2010 10:40:04 AM f BP EXPLORATION Page 6 of 6 Operations Summary'Report Legal Well Name: 03-34 Common Well Name: 03-34 Spud Date: 3/7/2000 Event Name: WORKOVER Start: 4/17/2010 End: 4/21/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 4/20/2010 12:30 - 15:00 2.50 15:00 - 19:00 I 4.00 19:00 - 20:30 ~ 1.501 WHSUR P 20:30 - 22:30 2.00 BOPSU P 22:30 - 00:00 1.50 WHSUR P 4/21/2010 00:00 - 01:30 1.50 WHSUR P 01:30 - 02:30 I 1.001 WHSUR I P RUNCMP -RETURNS TO SURFACE AFTER PUMPING 275 BBLS. 3.5 BPM / 230 PSI. RUNCMP DROPE BALL & ROD -OBSERVE SHEAR SET @ 1,950 PSI -SET 7" X 4-1/2" HES PERMANENT PACKER @ 9239' MD -PRESSURE SET WITH 2.8 BBLS TO 4,000 PSI DOWN THE TBG -TESTED TO 3.500 P,SJ f/ ~ CHARTED MINUTES.. -BLEED TBG TO 1,500 PSI -PUMPED 6 BBLS DOWN THE IA AND TESTED TO 3,500 PSI F/ 30 CHARTED MINUTES. -BLEED TBG SLOWLY AND OBSERVED DCK VALVE SHEAR ~ 1,300 PSI. -BLEED TBG AND IA TO (0) PSI. -CIRCULATE DOWN THE TBG, 3 BPM / 275 PSI -CIRCULATE IN THE IA, 3 BPM / 275 PSI -CONFIRMS VALVE IS OPEN. -BLOW DOWN ALL LINES. RUNCMP TWC -CAMERON REP, DRY ROD TWC -PRESSURE TEST 3,500 PSI F/ ABOVE AND 1,000 PSI F/ BELOW -CHARTED BOTH F/ 10 MINUTES. RUNCMP ND 13-/5/8" BOPE RUNCMP NU McVOY ADAPTER AND TREE. RUNCMP NU McVOY ADAPTER AND TREE. -TESTED TO 5,000 PSI RUNCMP PULL TWC__ -RU /TEST LUBRICATOR TO 500 PSI -D.S.M. PULL TWC -LD LUBRICATOR 02:30 - 06:00 3.50 WHSUR P RUNCMP FREEZE PROTECT -RU L.R.S. AND TEST LINES T/ 3,500 PSI -PUMP 145 BBLS DIESEL FREEZE PROTECT DOWN IA -3 BPM / 175 PSI -'U-TUBE' IA TO TBG -SET 4" TYPE 'H' BPV /TESTED FROM BELOW TO 1000 PSI 4" TYPE 'H' BPV ***RELEASE RIG AT 0600 HRS 4-21-2010*** RDMO TO MPE-08 Printed: 5/6/2010 10:40:04 AM TREE _ ~ 5x7 McEVOY WELLHEAD= McEVOY ACTUATOR = AXELSON KB. ELEV = 54' BF. ELEV...- KOP = 3092' Max Angle = 92 @ 9703' Datum MD = 11394' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2501 TOP OF 7" LNR ~~ 7315' 9-5/8" CSG, 47#, L-80, ID = 8.681" (~ 7501' 9-5~8" MILLOUT WINDOW (03-346} 7501' - 7515' 19$9' ~--~=+-1/2"XNIP(9CR},ID=3.813„ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3804 3753 25 MMG DCK RKP 0 G4/1911 G 2 6411 8080 28 MnRG D(41Y RKP d G4119!1G 3 7937 7450 16 MMG DMY BK G G4?10i1G 4 9133 8471 58 Mn~1G DMY BK 0 G~I19;1G 9209' I-14-1/2° X NIP (9CR}, ID = 3.813" 9239® 7" x 4 ii2" HES (CR) PERM PKR, !(} = 3.856" 9274' 4-1/2" X NIP (9CR}, ID = 3.813" 4-112" TBG, 12,6#: 13CR-80, VAM, I-~~37'3' 93c)4' 4-112" XN NIP{9CR), ID = 3.725" 0.0152 bpf, ID = 3.958" TUBING STUB (04/16/10) 9383' 9388' 7" x 4-1/2" UNIQUE OVERSHOT 9407' 4-1/2" X NIP, ID = 3.813" 9428' HES 4-1/2" X 7" TNT PKR, ID = 3.875" 91 aye' I--~ 4-1/2" HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 9457' 9457' 4-1/2" WLEG TOP OF 4-1/2" LNR 9458' "~'`' ~ ELMD TT NOT LOGGED 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" ~~ 9588' PERFORATION SUMMARY REF LOG: BHCS APR 92 A NGLE AT TOP PERF: 90 @ 10911' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SLTD 9923 - 11263 O 03/24/00 I I I ~ I I I 1 11 4-1/2" SOLID/SLTD LNR, 12.6#, L-80, 11263' --^I 0.0152 bpf, ID = 3.958" I I 1 I I I I I 9591' (~ PARTED LINER DATE REV BY COMMENTS DATE REV BY COMMENTS 03/01/86 WSR1 ORIGINAL COMPLETION 04/15/92 N2ES SIDETRACK (03-34A) 03/24/00 N9ES SIDETRACK (03-346) 04/21/10 N4ES RWO 04/21/10 SV DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 03-346 PERMff No: 2000110 API No: 50-029-21132-02 SEC 11, T10N, R15E, 2273.71 FEL 2492.55 FNL BP Exploration (Alaska) SAFETY: **COM POSITE WRAP REPAIR SH 03 34~ LEAK-D PUMP METHORMETHBLENDINTOOA ~ DUETO CHEM INCOMPATIBILITY W/EPOXY RESIN IN WRAP** HORIZONTAL WELL 70° @ 9609' AND 90° @ 9672'. PARTED LINER DURING CTD DRLG ATTEM PT. 40 BBLS METH TO x3804` **03-34A MILLOUT WINDOW NOT SHOWN** `**CHROMETBG & JEWELRY** STATE OF ALASKA ALAS IL AND GAS CONSERVA710N COMMIS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other Q SH REPAIR Pertormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ FURMANITE Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ REPAIR 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development Q Exploratory ~ 200-0110 3. Address: P.O. Box 196612 Stratigraphic^ Service Q' ~API Number: Anchorage,AK 99519-6612 50-029-21132-02-00 8. Property Designation (Lease,, Number) : Well Name and Number: ~° r f , ~ ADLO-028331 ~ ~~ ~ PBU 03-346 ~~r 10. Field/Pool(s): n~T ~ ~ ~~0~ ~ ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: ~~85~8 rylI ~t G~$ ~;On$. ~iQ(~(~j Y Total Depth measured ~, 11263 feet Plugs (measured) 9430' 7/31/09 feet ARCh0~8~B true vertical 8752.48 feet Junk (measured) None feet Effective Depth measured 11263 feet Packer (measured) 9428' true vertical 8753 feet (true vertical) 8623' Casing ~ength Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2501 13-3/8" 72# L-80 SURFACE - 2501 SURFACE - 2501 4930 2670 Intermediate Production 7501 9-5/8" 47# L-80 SURFACE - 7501 SURFACE - 7042 6870 4760 Liner 2273 7" 26# L-80 7315 - 9588 6877 - 8699 7240 5410 Liner 1810 4-1/2" 12.6# L-80 9453 - 11263 8635 - 8752 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# ~ SURFACE - 9457' SURFACE - 8637' Packers and SSSV (type, measured and true vertical depth) 4-1/2"X7" TNT PKR 9428' 8623' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~ ~ •~F~. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbi Casing Pressure Tubing pressure Prior to well operation: 1388 13927 0 815 Subsequent to operation: 1514 10274 11 1102 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Welf Operations X . Weii Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/15/2009 sion ~-~ ~~~~s t~~~ ~ ~ ~ ~~ ~o~r~~dy Form 10-404 Revised 7/2009 Submit Original Only 03-34B 200-011 PFRF oTTOCMENT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-34B 3/24/00 SL 9,923. 11,263. 8,729.43 8,752.48 03-34B 7/31/09 BPS 9,430. 11,263. 8,623.83 8,752.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 03-34B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/21/2009~T/I/0= VAC/20/40. Temp= SI. Assist w/ open bleed for Furmanite wrap ~(wellhead repair). AL blinded & disconnected. Integral installed on IA. No Ichange in WHPs overnight. OA FL near surface. Alutiiq sand blasted SH. ~Bleed OAP from 40 psi to 0 psi. Assisted Furmanite, holding open OA bleed. 'Furmanite Technicians applied E-Glass layer of wrap. Continued OA bleed during curing process with no change in WHPs. Relived by night crew. Final iWHPs= VAC/20/0. ;SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. 9/22/2009~T/I/0= VAC/38/0. Temp= SI. Assist w/open bleed for Furmanite wrap ~;(wellhead repair). AL spool disconnected. Continued w/open bleed on OA. ;No WHPs changes in WHPs over 12 hours. Final WHPs= Vac/38/0. ~SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. Day crew will ~continue monitoring bleed. 9/22/2009ET/I/O=Vac/40/0. Temp=Sl. Assist w/open bleed for Furmanite wrap (wellhead ;repair). AL spool disconnected. WHPs unchanged. Continued bleed on OA 'for 12 hours, no fluid or gas returns. Final WHPs=Vac/40/0. ~DHD day crew in control of well. 9/22/2009iT/I/O=Vac/38/0. Temp=Sl. Assist with open bleed for Furmanite wrap I(wellhead repair). AL spool disconnected. Furmanite tech Applied first layers ~of carbon. Continued to hold open bleed for 12 hrs. WHPs unchanged. Turned Eover well to night shift. Final WHPs=Vac/38/0. ~SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. • • ~~~ ~ 9/23/2009 T/I/O=Vac/38/0. Temp=Sl. Assist w/ open OA bleed for Furmanite wrap ~ ~ (wellhead repair). AL spool disconnected. Maintained open OA bleed. ? Furmanite techs applied final layer and composite wrap application complete i ~ ~ ~ @ 0900. Night tech has control of well. ~ I ~ i ~ ~ ~ ~ 9/24/2009 ~ T/I/0= Vac/40/0. Temp= SI. Assist w/ open bleed for Furmanite wrap , ~ (wellhead repair). Integral flange installed on IA. AL spool piece dropped. ? Changed out w/ night crew. No change in WHPs overnight. Continued to ~ monitor WHPs for 12 hrs. No change in WHPs. FWHPs= Vac/40/0. ~ ~ ***Night crew has control of wellhead*** ~ i i 3 t ~...~,........ . 9/24/2009~ . _~ . .............. ..........~_ ......... ~ TI0=vac/40/0. SI. Assist w/open bleed for Furmanite wrap (wellhead repair). ~ ? AL spool disconnected, integral installed on IA. Change out with day crew and ~ ~ continue open bleed on OA, no change in pressures. Final WHPs=Vac/40/0. , ~ i ~ 'l I ~ DHD day crew in control of well. ~ ~ 9/25/2009 T/I/O = VAC/40/0. Temp=Sl. Assist w/ open OA bleed for Furmanite wrap ~ (WH repair). AL spool is dropped. IA has integral installed. Temperature @ ; e ~SH=85 degrees. BT has 14.5 in fluid. Monitor OAP during open bleed until ? ~ 1600 hrs, instructed to perform BUR (see log) on OAP. Monitored OAP for 1 j hr. No change in WHPs. RDMO. Final WHPs=VAC/40/0. ( ~ ~ l ~WV=Closed. SV, SSV,MV=Open. IA,OA=OTG. NOVP. ~ ~ ~ ~ 9/25/2009 ~ °TIO=vac/40/0. SI. Assist w/open bleed for Furmanite wrap (wellhead repair). ~AL spool disconnected, integral installed on IA. Change out with day crew and ! continue open bleed on OA, no change in pressures. Final WHPs=Vac/40/0. ~ ~ t i i i DHD day crew in control of well. ~ ; i i ~ ~ __~._ ~ ~ ~ _ ~J • E 9/26/2009 I ~ ~ ~ ; ~ ~ ~ ~~..._.....~_.._.. E T/1/O=Vac/40/0. Temp=Sl. Monitor WHPs, bleed OAP to 0 psi if needed ~ (Furmanite). AL disconnected. OAP is 0 psi @ 8:30 pm & 4:15 am. Heater is ~ installed & working. ~ SV, WV=Closed. SSV, MV=Open. IA & OA=OTG. NOVP. ; ; ~ , ~ 1 v ~ ~ .__ _.. . ."_" .__.._.. j 9/26/2009~ T/UO = VAC/40/0. Temp=Sl. WHPs, bleed OAP if needed (furmanite repair). i ~ AL spool is dropped. Integral installed on IA. WHPs unchanged. Heater is ~ working properly. ~ I ~ ' ~ j 4 ~ f 3 I ~ WV=Closed. SV,SSV,MV=Open. IA,OA=OTG. NOVP. ~ ~ ~ ~ ~~~ 9/27/2009 T/I/0= VAC/40/0. Temp= SI. WHPs, Bleed OAP if needed. AL spool piece ; dropped. Integral flange installed on 1A. WHPs unchanged overnight. Heat is ~ working properly. ~ ~ 1 SV= C. WV, SSV, MV= O. IA, OA= OTG. NOVP. ~ ~ ~ 1 ~ ~~ ~ ~ ~ [ 9/28/2009 T/I/O = Vac/40/0. Temp = SI. WHP's, Bleed OAP if needed (Furmanite ~ repair). AL is disconnected. 2" integral installed on IA. No leaks detected on ~ furmanite wrap. Heater is working properly. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. P ~ ~ ~~ ~ ~ ~ d 9/28/2009 i . T/I/O=Vac/40/0. Temp=Sl. WHPs, Bleed OAP if needed. AL is disconnecte ~ Integral on IA. WHPs unchanged overnight. Heater is working properly. ~ WV=Closed. SV=Opened & flagged per DSO. SSV, MV=Open. IA & ~ ~ ~ OA=OTG. NOVP. 1 6 i ~ ~ ~ ,_.__..~. ~......._._._......,~ i ~ I ¢ i € ' ~ _...._ ._.....~.. _""____""_""___. ~...., .e..~.. ~___m. ~ ~ • ~ 9/29/2009 T/I/O = VAC/40/0. Temp=Sl. WHPs, Bleed OAP if necessary. Integral ~installed on IA. WHPs unchanged overnight. Heater is working properly. SV ~left open for thermal expansion. ~WV=Closed. SV,SSV,MV=Open. IA,OA=OTG. NOVP. ~ [ ~ ~ [ ~ ~ [ ~ ~._.._...~ 10/5/2009 T/I/0= 0/100/0 Temp= SI MIT OA PASSED to 1200 psi (Repair SH leak) ' ; Pressured up OA to 1200psi w/ 4.6 bbls 70" Crude. MIT-OA (3rd attempt) lost ~ ` 50 psi in 1 st 15 mins, and 10 psi in 2nd 15 mins, w/a total loss of 60 psi over ~ 30 min test. Bled OAP back. Bled back -2.5 bbls. FWHP's= 0/40/0. ~ ***Annulus casing valves tagged and left open to gauges upon departure*** ~ [ , ~ ~ ~ ~ I ~ ~ _ ~~__ ~ ~~.~~. ~..___ ~ ~ ~ ..~i 1 Ktt = 5X / IVIGtV UY WE~~HFAD= McEVOY ACTUA70R = AXELSON KB. ELEV = 54' BF. ELEV = KOP = 3092' Max Angle = 92 @ 9703' Datum MD = 11394' Datum 7V D= 8800' SS ~ 0~-346 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2501' Minimum ID = 3.725" @ 9446' XN NIPPLE TOP OF 7" LNR 7315~ 9-5(8" Ezsv ~--~ 7526' SAFE~aTES: HORIZONTAI WELL 70° @ 9609' AND 90° @ 9672'. PARTm LINER DURING CTD DRLG ATTEM PT. 40 BBLS M ETH TO -3800' -j4-1/2" X-NIP, ID = 3.813" GRS LIFf MANDRELS ST MD N D DEV TY PE V LV LATCH PORT DATE 1 3842 3788 25 MMG-M DOM RK 16 09/12I08 2 6089 5796 28 MMG-M DC}M RK 16 09/12l08 3 7461 7006 27 KBG2LS DMY INT 0 4 83Q0 7800 15 KBG2LS DMY INT 0 5 9177 8494 5$ KBG2LS SO INT 22 09/12/08 MILLOUT WINDOW 7501' -7515' 9407' 4-1/2" X NIP, ID = 3.813" 9428~ HES 4-1l2" X 7" TtJT PKR, ID = 3.875" 9430~ 4-112" BKR COMPOSffE PLUG (07/31109) 9446' 4-1/2" HES XN NIP, ID = 3.725" 9457' 4-1l2" WLEG ~~ E~MD Tf NOT LOGGED~ 9591' (--I PARTED LINER I 9-5J8" CSG, 47#, L-$0, ID = 8.681" ~-L $010~ ~ ~1~~ 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 945T TOPOF4-1/2" LNR 9458~ ~~` 7" LNR, 26#, ~-80, 0.0383 bpf, ID = 6.276" 9588' ~ `~~ • TOPOF4-1/2" LNR-SL~ 9923~ `~~` 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ~D = 3.958~ 9923~ V PERFORATION SUMMARY REF LOG: BHCS APR 92 ANGLE AT TOP PERF: 9d @ 10911' Note: Refer to Productiqn DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE S~OTTED 9923 - 11263 C 03/24/00 4-112" ~NR-SLTD, 12.6#, L-80, 0.0152 bpt, ID = 3.958" ~~ 11263~ DATE REV BY CAMMENTS DATE REV BY COMMENTS 04/15l92 ORIGINAL COMPLETION 09l21lOS SWC/SV GLV CJO (09/12/08) 03l00 SIDETRACK (03-348) 09/OS/09 RRD/TLH COMPOSffE PLUG SEf (07l31/09 01 /09/02 RN/TP CORRECTIUNS 03/11/02 DAC/tlh PARTED ~NR (CTD ABORTED) 06/26/02 BHC/tlh PERF CORRECTION 08/24/08 DSNVSV TREEC/O(08111/OS) PRUDHOE BAY UNff WELL: 03-346 PERMIT No: 200-0110 API No: 50-029-21132-02 SEC 11, T10N, R15E, 2273.71 FEL 2492.55 FN~ BP Ezploration (Alaska) P~ `~~i~ ~~: PROAc1ivE Dinynos~ic SEevice, (nc. Leak Detection - WLD 29-Aug-09 To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907~ 793-1225 RE : Cased Hole/Open Ho1e/Mechanical Logs and/orTubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petratechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and Leak Detection - WLD 06-Aug-09 ProActinre Diagnostic Services, lnc. Attn: Rvbert A. Richey 130 West International Airport Road ~N~•~.`r!" ~~..:~ :. ~^~~~`~ Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1j _~ 2) _.__----- Signed : Print Name: • • ~~LL Lf1G ~~~~~~~~+ ^~ C-12A j~ BL/ EDE 50-029-21387-01 03-34B BL / EDE 50-029-211 ~U -O ~~ l ~ 5~~~ date : ~ `: PROACTiVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUlTE C, ANCHORAGE, AK 99518 PHOwE: (907)245-8951 Fnx: (907)245-88952 E-MAIL . _ _~~ t ~'~.~ ~~.rt ~,'., WEBSPTE _~' •= ='' ___.__ C:`,Documents and Settings\~wner~Desktop\Ttar~smit_BP.docx F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .~., . - . Id,. - ~ ' \ .'.... .~'~. . '. r.,. .,"\ " 1 'II, Permit to Drill No. 2000110 MD 11263 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT 03-34B Operator BP EXPLORATION (ALASKA) INC 8753 Completion Date 3/24/2000 ~'~ Completion Status 1-OIL AP1 No. 50-029-21132-02-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run Scale Media No Start Stop OH / Dataset CH Received Number Comments 55 11263 OH 4/4/2000 SPERRY 7491.. Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~..~ Chips Received? Analysis Received? Comments: Daily History Received? Formation Tops Receuived? (~ N Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska May 14, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs - 03-34B, AK-MM-90259 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~ Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 I LDWG formatted Disc with verification listing. API#: 50-029-21132-02. RECEIVED Alalla Oil & Gas Cons. Cad'on ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution- Final Print(s) 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 · Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE RI WELL DATE TYPE OR SEPIA PRINT(S) CD-ROM FILM C Open Hole I I 1 Res. Eval. CH I I 1 03-34b 3/8/02 Mech. CH 1 ~L~ Caliper Survey --__ REPORT OR )LOR Signed' ~~ Date' RECEIVED Print Name: Alaska Oii& Gas Cons. Comm~o~ Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com MEMORANDUM State of Alaska ~ Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: January 15, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site 03 January 15, 2001' I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-14-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15-00jc NON-CONFIDENTIAL SVS PBU DS 03 1-15-01jc.doc Alaska Oil and Gas ConserVation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Womble AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field DS 03 Separator psi: LPS 185 HPS 1/15/01 690 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI 'Trip Code Code Code Passed GAS or CYCLE 03-01 1750750 185 150 100 P P OIL 03-02 1760240 185 150 120 P" P OIL 03-03 1760390 185 150 110 P P OIL 03-04 1760510 03-05 1760570 03-06 1760600 03-07 1760530 03-08 1760730 185 150 130 P P 03-09 1790220 185 150 100 P P OIL 03-10 1790210 03-11 1790470 03-12 1790580 03-13 1790710 03-14 1790820 185 150 100 P P OIL 03-15A 1930150 185 150 100 P P OIL 03-16A '1970330 · 03-17 1791020 03,18A 1930420! 03-19 1830920 185 150 90 P P OIL 03-20A 1930470 185 150 1001 P P OIL 03-21 1831120! 185 150 100 P P OIL 03-22 1831230. 690 600 4201 P P O~L 03-23 1831270 185 150 0 1 P OIL 03-24A 1980060 690 600 530 P P OIL 03-25A 1930230 03-26 1831510 185 150 110 P P OIL 03-27 1840620 185 150 100 P P OIL 03-28 1840720 03-29 1840790 185! 150 110 P P OIL . 03-30 1840830 185: 150 90 P P OIL 03-31 1840920 185 150 140 P P OIL 03-32A 1940540 185 150 -110 P P OIL 03-33A 1970390 03-34B 2000110 185 150 0 1 P OIL 1/1R/fl1 Pa~e 1 of 2 SVS PBU DS 03 1-15-01c.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed CAS or CYCLE 03-35 1910800 185 150 90 P P OIL 03-36 1930190 Wells: 21 Components: 42 Failures: 2 Failure Rate: 4.8% 12300 oar Remarks: ~ ,~ o;~ Paoe 2 of 2 SVS PBU DS 03 1-15-01c.xls 30-Mar-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3-34B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 7,491.55' MD 9,501.00' MD 11,263.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) APR O4 2000 Alaska Oil & Gas Cons, Commission Anchorage MEMORANDUM TO: Robert Christenson~~-0 Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldit~/~',,..,.~ Petroleum InstC)ector State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 15, 2000 SUBJECT: Blowout Preventer Test Nabors 9ES Arco Flow Two DS-3 3-34B ~ay Field NON- CONFIDENTIAL Operator Rep.' Contractor Rep.' Bill Bixby Op. phone: 659-4833 Rig phone: 659-4806 Op. E-Mail: Rig E-Mail: Test Pressures Rams: MISC. INSPECTIONS: P/F Location Gen.' P Sign: Housekeeping: P Rig cond: PTD On Location P Hazard: Standing Order: P Annular: Choke: TEST DATA FLOOR VALVES: P/F Quantity P/F P Upper Kelly 1 P P Lower Kelly 1 P P ..- Ball Type 1 P Inside BOP 1 P BOP STACK: Quantity Size P/F Annular Preventer I 13 5/8 P Pipe Rams 1 3 1/2 x 6 P Lower Pipe Rams 1 4 P Blind Rams 1 N/A P Choke Ln. Valves 1 4 P HCR Valves 2 4 P Kill Line Valves 3 3 P Check Valve 0 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P ACCUMULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi P/F Quantity P/F System Pressure 3100 P No. Valves 14 P After Closure 1600 " P Man. Chokes 1 P 200 psi Attained :23 P Hyd. Chokes 2 P Full Pressure 2:30 P Blind Covers (All Stations): P N2 Bottles (avg): 6 bott. 2100psi Test's Details The rig was picking up the test joint xvhen I arrived. All BOP equipment was tested this evening with no failures observed. The crew peribrmed the test well and seemed practiced in their procedure. The area surrounding the rig was very clean and orderly. This rig is well maintained as the appearance and test perIbrmance show. Total Test Time: Number of failures: cc: Shared Se~wfces Drillinc~ None Attatchments: None Sheet by L.G. 3/18/00 BOP Nabors 9ES 3-15-00 LG 4/10/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 200-011 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 · ~ 50-029-21132-02 4. Location of well at surface ~ ~i?ii~;i:';~'"'~'i<i~ii'?i -- ,,-,,'~Ef-J]:~=r~~! 9. Unit or Lease Name 97' NSL, 846' EWL, SEC.At top of productive interval11' T10N, R15E, U M i; !~ :'~_~ ' r~~ P rudhoe Bay Unit 2279' SNL, 656' WEL, SEC. 15, T10N, R15E, UM ! ~i~'!.~. i i'~', '"'~-"~-~-,-~_ 10. Well Number At total depth i ......... 03-34B 2495' SNL, 2274' WEL, SEC. 15, T10N, R15E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 53.55' ADL 028331 12. Date Spudded 3/7/2000 113' Date T'D' Reached 114' Date cOmp'' Susp'' or Aband' 3/21 ~2000 3~24/2000 115' Water depth' if Offshore N/A MSL II 16' No' of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11263 8753 FTI 11263 8753 FTI [] Yes [] NoI (Nipple) 2201' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" Conductor H-40 Surface 110' 30" 1865 # Poleset 13-3/8" 72# L-80 Surface 2501' 17-1/2" 2300 sx Coldset III 9-5/8" 47# L-80 Surface 7501' 12-1/4" 500 sx Class 'G', 300 sx Coldset I 7" 26# L-80 7315' 9588' 8-1/2" 413 sx Class 'G' 4-1/2" 12.6# / 12.75# L-80 9453' 11263' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 9457' 9428' MD TVD MD TVD 9923' - 10911' 8676' - 8745' 10951' - 11261' 8745' - 8752' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 154 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 29, 2000 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL A~$ka 0ii & Gas Cons. C0mmi'~si0n Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9629' 8713' Shublik 11038' 8747' APR 20 2000 , 81. List of A~aohments: Summa~ of Daily Drilling Repo~s, Su~eys 32. I hereby oe~i~ that the foregoing is true and oorreot to the best of my knowledge Signed TerrieHubble~~~ ~ Title TechnicalAssistantlll Date 03-34B 200-011 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND ~)4; If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 03 Well 03-34B Page 1 Rig Nabors 9ES Date 27 March 00 Date/Time 01 Mar 00 21:00-06:00 21:00-06:00 02 Mar 00 06:00-06:00 06:00-09:30 09:30 09:30-19:30 19:30 19:30-23:00 23:00 23:00-06:00 03 Mar 00 06:00-08:30 06:00-08:30 08:30 08:30-14:00 08:30-11:00 11:00 11:00-13:30 13:30 13:30-14:00 14:00 14:00-17:00 14:00-14:30 14:30 14:30-17:00 17:00 17:00-23:30 17:00-20:00 20:00 20:00-23:30 23:30 Duration 9 hr 9 hr 24 hr 3-1/2 hr 10hr 3-1/2 hr 7 hr 2-1/2 hr 2-1/2 hr 5-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 2-1/2 hr 6-1/2 hr 3 hr 3-1/2 hr Activity Move rig Rig moved 80.00 % L/D Derrick, RDMO to well location 3-34B. Laying herculite and spotting substructure @ report time. Move rig (cont...) Rig moved 90.00 % At well location - Cellar Lay Herculite. Spot substructure, camp, pits and workshop. Hook up service lines. Serviced Top drive Work completed, Top drive changed out Continue installation of service loop for top drive. Rigged up Drillfloor / Derrick Equipment work completed Raise and Pin Derrick. Raise chute. Lower Blocks and bridle down. PFLI blocks to top drive. Serviced Draw works Replace Brake bands on Drawworks. Currently putting drwaworks back together. Anticipate rig ready for acceptance 1000-1100 hrs. Move rig (cont...) Serviced Draw works Complete changing out brake bands on drawworks. Rig Accepted @ 0830 hrs. Equipment work completed Wellhead work Removed Hanger plug Equipment work completed R/U lines to x-tree and install secondary annulus valve. R/U DSM- no pressure. Pull BPV. Circulated at 7733.5 ft String displaced with Seawater - 100.00 % displaced Circulate out Freeze Protect- 220 bbls of Diesel. Installed Hanger plug Equipment work completed Install TWC and test from below to 1000 psi. Wellhead work Held safety meeting Completed operations Hold Pre-spud Meeting and discuss environmental issues and H2S concerns for DS3. Removed Xmas tree Equipment work completed Remove x-tree and adaptor. BOP/riser operations - BOP stack Rigged up BOP stack Equipment work completed Tested BOP stack APR 20 2000 Ala~ka Oil & Gas C~x~s. Corem Anchorage Pressure test completed successfully - 3500.000 psi Install Test joint. R/U and test BOPE to 3500 psi. a~sm oFa~u..~ ~ ~~ wasvvu Wit~CSS. ~_n .... is,~ion Facility PB DS 03 Progress Report Well 03-34B Page 2 Rig Nabors 9ES Date 27 March 00 Date/Time 23:30-00:30 23:30-00:30 04 Mar 00 00:30 00:30-02:00 00:30-02:00 02:00 02:00-06:00 02:00-04:00 04:00 04:00-06:00 06:00-00:00 06:00-09:30 09:30 09:30-10:00 10:00 10:00-22:00 22:00 22:00-00:00 05 Mar 00 00:00 00:00-06:00 00:00-03:30 03:30 03:30-04:00 04:00 04:00-06:00 06:00-16:00 06:00-10:00 10:00 10:00-11:30 Duration lhr 1 hr 1-1/2 hr 1-1/2 hr 4 hr 2 hr 2 hr 18hr 3-1/2 hr 1/2 hr 12hr 2 hr 6 hr 3-1/2 hr 1/2 hr 2 hr 10hr 4 hr 1-1/2 hr Activity accumulator function test. Wellhead work Retrieved Hanger plug Equipment work completed BHA run no. 1 Made up BHA no. 1 BHA no. 1 made up Make up 4.1/2" double spear assembly on 3.1/2" HWDP. Pull Single completion, 4-1/2in O.D. Retrieved Casing hanger Completed operations BOLDS. Spear tubing- could only engage first pup joint below hanger with one grapple. Pulled tubing free w/25K o/pull. Up weight 130 klbs. Release spear and L/D fishing equipment and hanger. Rigged up Tubing handling equipment R/U Chrome handling equipment. Preparing to pull tubing @ report time. Pull Single completion, 4-1/2in O.D. (cont...) Laid down 2300.0 ft of Tubing Stopped · At sub-assembly POOH laying down 50 joints 4.1/2" Chrome tubulars using Chrome handling equipment and thread protectors. 56 SS bands recovered. Retrieved SCSSSV nipple assembly Completed operations L/O SSSV valve and clear rigfloor of control line spooling equipment. Laid down 5200.0 ft of Tubing Completed operations Continue to L/O 4.1/2" Chrome Tubing. 179 joints in total. L/O 23 joints 3.1/2" Chrome plus 2 GLM and cut off @ 15.17 ft. Rigged down Tubing handling equipment Equipment work completed Clear rig floor. Load Pipe shed with HWDP and clean rig up prior to next operation. BHA run no. 2 Made up BHA no. 2 BHA no. 2 made up Install wear ring. M/U Whiptsock mill assembly, 9 x 6.1/2" DC's and 18 x HWDP. Serviced Block line Line slipped Slip 40' drilline Singled in drill pipe to 1533.5 ft RIH picking up 4" drillpipe. BHA run no. 2 (cont...) Singled in drill pipe to 7733.5 ft Single in 4" drillpipe to 7700'. 220 joints picked up Circulated at 7773.5 ft Tag Top of 7" liner @ 7740'. Up/Down Weight= 195/175 klbs, rotating 185 klbs. Torque 3,500 ftlbs. o w~lJ IlUl~ ~l~dll E JUU UI I¥l/ ·/~JU I J31, R _CE, wt APR 20 20011 Alaaka Oil & Gas Cons. C0mm Anchorage ~ion Progress Report Facility PB DS 03 Well 03-34B Page 3 Rig Nabors 9ES Date 27 March 00 Date/Time 11:30 11:30-15:15 15:15 15:15-16:00 16:00 16:00-19:00 16:00-19:00 19:00 19:00-20:00 19:00-20:00 20:00 20:00-06:00 20:00-22:30 22:30 22:30-03:00 06 Mar 00 03:00 03:00-03:30 03:30 03:30-06:00 06:00-12:15 06:00-11:00 11:00 11:00-12:15 12:15 12:15-13:00 12:15-13:00 13:00 13:00-17:30 13:00-13'15 13:15 13:15-15:30 15:30 15:30-17:30 17:30 Duration 3-3/4 hr 3/4 hr 3 hr 3 hr 1 hr 1 hr 10hr 2-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 6-1/4 hr 5 hr 1-1/4 hr 3/4 hr 3/4 hr 4-1/2 hr 1/4 hr 2-1/4 hr 2 hr Activity Obtained bottoms up (100% annulus volume) Pulled out of hole to 133.5 ft At BHA Pulled BHA BHA Stood back Electric wireline work Installed Permanent packer Equipment work completed R/U Schlumberger and run 9.5/8" EZSV and correlate. Set Bridge plug at a siltstone interval @ 7,526 ft. Perform integrity test Tested Casing Pressure test completed successfully - 3000.000 psi R/U and test casing and bridge plug to 3000 psi/30 minutes pumping 7 bbls. BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up M/U Whipstock BHA and surface test MWD. R.I.H. to 7564.5 ft At Top of packer' 7564.5 ft Functioned Tubing cutting tools Equipment work completed Orientate whipstock and set bottom anchor with 15 klbs shear, mills sheared @ 45 klbs. Whipstock set @ 85 degs R of highside. Circulated at 7534.5 ft Displace well to 10.2 ppg Milling Fluid. Preparing to mill window @ report time. BHA run no. 3 (cont...) Milled Casing at 7531.0 ft Completed operations Mill window f/7,501' to 7,517' and new hole to 7,531' Circulated at 7531.0 ft Hole swept with slug - 100.00 % hole volume Sweep hole clean. Window clean but open hole taking some weight. Cleaned up with circulating. Perform integrity test Performed formation integrity test Obtained leak off 12.5 ppg EMW Conduct FIT with 10.1 ppg mudweight. Injection noted @ 880 psi. Shut down pump and monitor wellbore pressures. 2.6 bbls pumped, 2 bbls returned. BHA run no. 3 Circulated at 7531.0 ft Check window- good, Pump dry job. Heavy slug spotted downhole Pulled out of hole to 1000.0 ft /qP~ ~0 200( At BHA Pulled BHA A]~ka 0il & G~s Cons. (;or BHA Laid out Ancha~'afle Laid outw,,,t,~,,,.,-"-: ....... BIIA. D Facility Date/Time 07 Mar 00 08 Mar 00 PB DS 03 Progress Report Well 03-34B Page 4 Rig Nabors 9ES Date 27 March 00 17:30-18:30 17:30-18:30 18:30 18:30-06:00 18:30-21:30 21:30 21:30-22:30 22:30 22:30-01:00 01:00 01:00-03:30 03:30 03:30-04:00 04:00 04:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:00 06:00-06:00 06:00-19:30 06:00-13:30 13:30 13:30-14:30 14:30 14:30-18:00 18:00 18:00-19:30 19:30 Duration 1 hr 1 hr 11-1/2 hr 3 hr 1 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 24 hr 24 hr 13-1/2 hr 7-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr Activity gauge. 4in. Drillpipe workstring run Circulated at 30.0 ft Began precautionary measures Flush BOP stack of any residual metal. BHA run no. 4 Made up BHA no. 3 BHA no. 3 made up PFLI Drilling assembly and orientate same. Serviced Lines / Cables Line slipped and cut And service Top Drive Singled in drill pipe to 2590.0 ft 81 joints picked up R.I.H. to 7500.0 ft At Window: 7500.0 ft Circulated at 7500.0 ft Began precautionary measures R CE vED APR 20 0ii & Gas C0~'~s. Anch0rage Attempt to obtain communication to Sperry Sun Rig Floor displays. Troubleshoot same. Reamed to 7531.0 ft On bottom Ream/wash to bottom. Drilled to 7540.0 ft Initiate kick off in 8.1/2" Hole. Drilled to 7540.0 ft Drill and survey from 7,540' to 8,130'. ART = 15-1/4; AST = 6-1/4; Pumped hi-vis sweep at 8,040' - no visible increase in cuttings; good hole conditions; BHA run no. 4 (cont...) Drilled to 8130.0 ft (cont...) Drill and survey from 7,540' to 8,130'. ART = 15-1/4; AST = 6-1/4; Pumped hi-vis sweep at 8,040' - no visible increase in cuttings; good hole conditions; BHA run no. 4 (cont...) Drilled to 8314.0 ft Reached planned end of run - Maximum hours on bit Directionally drill 8.1/2" Hole f/8,130' to 8,314'. Penetration performance averaging 20-25 ft/hr. Approaching high K-revs for bit, decision made to pull for PDC. Circulated at 8314.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean. Flowcheck. Pulled out of hole to 300.0 ft At BHA POOH- hole in good shape. Downloaded MWD tool Completed operations Download MWD and break out Motor and bit. Bearings still effective, one cone easy to move. Even wear. On Bottom Krevs @ 325,000, On/Off Bottom @ 350,000 Facility Date/Time 09 Mar O0 10 Mar O0 PB DS 03 Progress Report Well 03-34B Page 5 Rig Nabors 9ES Date 27 March 00 19:30-06:00 19:30-21:30 21:30 21:30-00:30 00:30 00:30-01:00 01:00 01:00-01:30 01:30 01:30-06:00 06:00-21:30 06:00-13:30 13:30 13:30-15:00 15:00 15:00-18:30 18:30 18:30-21:30 21:30 21:30-00:00 21:30-00:00 00:00 00:00-06:00 00:00-02:30 02:30 02:30-05:00 05:00 05:00-06:00 06:00-06:00 06:00-07:30 07:30 07:30-13:00 13:00 13:00-14:00 14:00 14:00-14:30 Duration 10-1/2 hr 2 hr 3 hr 1/2 hr 1/2 hr 4-1/2 hr 15-1/2 hr 7-1/2 hr 1-1/2 hr 3-1/2 hr 3 hr 2-1/2 hr 2-1/2 hr 6 hr 2-1/2 hr 2-1/2 hr 1 hr 24 hr 1-1/2 hr 5-1/2 hr 1 hr 1/2 hr Activity BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up R.I.H. to 7475.0 ft Stopped · To service drilling equipment Serviced Top drive Line slipped and cut R.I.H. to 8314.0 ft On bottom Hole in Good shape. Drilled to 8435.0 ft Bed in bit and directionally drill 8.1/2" Hole. No Drag, no losses. Slidng at time of report @ 20-25 ft/hr. BHA run no. 5 (cont...) Drilled to 8515.0 ft MWD failed - Circulate Directionally drill 8.1/2" hole f/8,435' to 8,515'. Having problems holding toolface @ low P-rates ( 7-12 fi/hr). BUR @ 3 deg/100', need 8. MWD Tool failure @ 8,515'. Circulated at 8515.0 ft MWD failed - End BHA run Troubleshoot Tool Failure. Attempt to get tool to switch back on- no go, no pulse. Pulled out of hole to 300.0 ft At BHA Hole in Good Shape. Downloaded MWD tool Completed operations Download MWD and Break out bit and MWD. Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi R/U and test BOPE. Witness waived by John Crisp- AOGCC. BHA run no. 6 Made up BHA no. 6 BHA no. 6 made up R.I.H. to 7475.0 ft At Window: 7475.0 ft Serviced Block line Slip and cut 80 ft drilline. BHA run no. 6 (cont...) R.I.H. to 8515.0 ft On bottom Wash last stand as a precaution. Drilled to 8610.0 ft Standpipe manifold failed - Short trip Directionally Drill 8.1/2" hole. No Drag No Losses. Mus Pump Discharge line failure. Pulled out of hole to 7475.0 ft At Window: 7475.0 ft Serviced Standpipe manifold ~,PR 20 2000 A~a~ka Oil & Gas Cons. Commi~ Anchorage ion Progress Report Facility PB DS 03 Well 03-34B Page 6 Rig Nabors 9ES Date 27 March 00 Date/Time 14:30 14:30-15:00 15:00 15:00-06:00 11 Mar 00 06:00-17:30 06:00-12:00 12:00 12:00-12:30 12:30 12:30-15:30 15:30 15:30-17:30 17:30 17:30-06:00 17:30-18:30 18:30 18:30-22:00 22:00 22:00-06:00 12 Mar 00 06:00-06:00 06:00-13:00 13:00 13:00-13:30 13:30 13:30-22:00 22:00 22:00-22:30 22:30 Duration 1/2 hr 15hr 11-1/2 hr 6 hr 1/2 hr 3 hr 2 hr 12-1/2 hr 1 hr 3-1/2 hr 8hr 24 hr 7 hr 1/2 hr 8-1/2 hr 1/2 hr Activity Equipment work completed Repair failed gasket in mud pump discharge line. R.I.H. to 8610.0 ft On bottom Drilled to 8770.0 ft Directional Drill 8.1/2" hole f/8,610 to 8,770'. Achieving doglegs- some slow digging. P-rates down to 5-10 ft/hr. BHA run no. 6 (cont...) Drilled to 8813.0 ft ROP dropped from 10.0 ft/hr to 5.0 fl/hr - Formation change Directionally Drill 8.1/2" Hole. P-rates low @ 5-10 ft/hr. Good differential pressure but with high WOB. Pump Sap/Nutplug pills for bit bailing- no change. Circulated at 8613.0 ft Obtained clean returns - 50.00 % hole volume Pulled out of hole to 200.0 ft At BHA Pulled BHA BHA Laid out Laid out Bit and Motor. Bit completely worn. Appears K5 marker @ 8,538' took away tungsten carbide coating and teeth gradually wore to nothing. Some heat checking too. Bit In gage. BHA run no. 7 Made up BHA no. 7 BHA no. 7 made up Make up PDC and performance motor. R.I.H. to 8813.0 ft On bottom RIH checking MWD @ 3552. Wash last stand to bo~ Drilled to 8900.0 ft Directionally Drill 8.1/2" Hole f/8813' to 8900. No drag, no losses. BHA run no. 7 (cont...) Drilled to 9031.0 ft Directionally Drill 8.1/2" Hole to 9,031'. No drag, no losses. Above HRZ pumping periodic pills to help sliding and pre-empt bit balling. W oo Top HRZ @ 9,091'. Top Sag Prog= 9,580' MD / 8696' TVD Began precautionary measures Circulated at 9031.0 ft Obtained clean returns - 100.00 % hole volume Sweep hole clean w/rotation after extensive sliding. Drilled to 9204.0 ft Mud pumps failed - Short trip Mud pump discharge line to pop offs developed leak. Pulled out of hole to 8968.0 ft At top of check trip interval Make short trip to above HRZ while fixing pump- did ll~,Jt Wallt LU L, IGC:tLI~ ~ IGU~G. Progress Report Facility PB DS 03 Well 03-34B Page 7 Rig Nabors 9ES Date 27 March 00 Date/Time 22:30-06:00 22:30-06:00 13 Mar 00 06:00-06:00 06:00-11:00 11:00 11:00-12:30 12:30 12:30-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-17:30 17:30 17:30-19:30 19:30 19:30-22:30 22:30 22:30-01:00 14 Mar 00 01:00 01:00-04:00 04:00 04:00-04:45 04:45 04:45-05:30 Duration 7-1/2 hr 7-1/2 hr 24 hr 5 hr 1-1/2 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 2 hr 3 hr 2-1/2 hr 3 hr 3/4 hr 3/4hr Activity Drilled to 9438.0 ft Drill ahead to 9,438' to casing point. No Drag, no losses. Drilled to 9438.0 ft Continue drilling from 9438' to 9590' section TD, building angle to projected inclination of 65.5 degrees. BHA run no. 7 (cont...) Drilled to 9590.0 ft (cont...) Continue drilling from 9438' to 9590' section TD, building angle to projected inclination of 65.5 degrees. Reached planned end of run - Section / well T.D. Circulated at 9590.0 ft Circulate, reciprocate sweep at TD 480 gpm. PUW 200, SOW 175, RW 185 Obtained clean returns - 120.00 % hole volume Pulled out of hole to 8378.0 ft Short trip past last trip depth. 20-25K over 9160-9000' and 8950-9000'. At top of check trip interval , R.I.H. to 9590.0 ft No tight areas on trip back in. [~,['~F~ ~ 0 ~0{ On bottom Circulated at 9590.0 ft CBU and spot 5% lubetex pill in openhold''dS'Ska Obtained bottoms up (100% annulus volume) Anfll0~"acje Pulled out of hole to 7460.0 ft Tight at 9342' and 9000', up to 50K over, worked tight areas. At Window: 7501.0 ft Serviced Block line Clearm rig floor, slip and cut drill line, adjust brakes. Line slipped and cut Circulated at 7460.0 ft Weight up surface and downhole (to window) mud to 11.8 ppg. Hole displaced with Water based mud - 100.00 % displaced R.I.H. to 9590.0 ft Work tight areas below 8950' to TD. On bottom Circulated at 9590.0 ft Condition openhole mud to 11.8 ppg, circ sweep. Cuttings cleaning up to a degree but not completely. Hole displaced with Water based mud - 100.00 % displaced Pulled out of hole to 8800.0 ft Short trip past tight areas. Drag decreased but still up to 35K 9000-9160'. At top of check trip interval R.I.H. to 9590.0 ft Light drag (20-25K) running in hole. ~mmisaion Progress Report Facility PB DS 03 Well 03-34B Page 8 Rig Nabors 9ES Date 27 March 00 Date/Time 05:30 05:30-06:00 06:00-14:30 06:00-08:00 08:00 08:00-12:30 12:30 12:30-14:30 14:30 14:30-06:00 14:30-16:00 16:00 16:00-16:30 16:30 16:30-21:00 21:00 21:00-22:00 22:00 22:00-22:30 22:30 22:30-23:00 23:00 23:00-02:00 15 Mar 00 02:00 02:00-03:30 03:30 03:30-05:30 Duration 1/2 hr 8-1/2 hr 2 hr 4-1/2 hr 2 hr 15-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 1/2 hr 3 hr 1-1/2 hr 2 hr Activity On bottom Circulated at 9590.0 ft Continue circulating hi-vis sweep, 8.75 bpm 22350 psi. Returns cleaned up considerably to only a small amount of fine cuttings after bottoms' up. Spot 150-bbl 5% LubeTex pill in openhole. BHA run no. 7 (cont...) Circulated at 9590.0 ft (cont...) Continue circulating hi-vis sweep, 8.75 bpm 22350 psi. Returns cleaned up considerably to only a small amount of fine cuttings after bottoms' up. Spot 150-bbl 5% LubeTex pill in openhole. Obtained clean returns - 110.00 % hole volume Pulled out of hole to 755.0 ft Max drag through open hole: 25K lbs 9000-9500'. Drift drillpipe w/2-3/8" rabbit at window. At BHA Pulled BHA Download MWD in pipeshed. BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting PJSM on casing running procedures. Completed operations Ran Liner to 2250.0 ft (7in OD) Run 55 joints of 7" 26#/ft L-80 MBtrs w/85' shoe joint, five centralizers (joints 1,3-6). Began precautionary measures Installed Liner hanger Baker 9-5/8" x 7" HMC hanger, ZXP packer, HR setting tool (Rotatable). Average casing make-up torque 8500 ft-lbs. Equipment work completed Ran Liner on landing string to 3490.0 ft RIH w/liner on 6 stands of 5" HWDP. Stopped: To circulate Circulated at 3490.0 ft Circulate 85 bbls at 6 bpm, 320 psi. PUW/SOW = 114K lbs. String displaced with Water based mud - 100.00 % displaced Ran Liner on landing string to 7420.0 ft RIH 90 seconds per stand. At Window: 7501.0 ft Circulated at 7420.0 ft CBU @ 6 bpm 800 psi. Clean returns. PUW 175, SOW 150, RW 165, 4000 ft-lbs torque. Obtained clean returns - 105.00 % hole volume Ran Liner on landing string to 9570.0 ft No excess drag until 8890' when intermitten drag began up to 35K lbs. Pick up one time at 8890', continue with same drag to 9480'. Worked pipe several times (slowly) and pumped past tight spot. Continue RIII. / ,PR 20 200 Oil & Gas C<ms. Co Ancho~e.qe Facility PB DS 03 Progress Report Well 03-34B Rig Nabors 9ES Page 9 Date 27 March 00 Date/Time 05:30 05:30-05:45 05:45 05:45-06:00 06:00-10:30 06:00-08:15 08:15 08:15-08:30 08:30 08:30-08:45 08:45 08:45-09:00 09:00 09:00-09:45 09:45 09:45-10:30 10:30 10:30-17:00 10:30-11:00 11:00 11:00-12:15 Duration 1/4 hr 1/4 hr 4-1/2 hr 2-1/4 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 3/4 hr 6-1/2 hr 1/2 hr 1-1/4 hr Activity Stopped: To pick up/lay out tubulars Installed Cement head Make up cement head and single joint. Equipment work completed Ran Liner on landing string to 9590.0 ft RIH to TD, Cement: Liner cement Circulated at 9588.0 ft APR 20 2000 Break circulation with liner 2' off bottom. Begin at 2 bpm / 500 psi, end at 6.5 bpm / 1675 psi, ramping up 1 bpm each openhole annluar volume. No indication of packing off. Total pumped: 785 bbls. Hole displaced with Water based mud - 100.00 % displaced Held safety meeting PJSM w/all hands, Dowell, Peak: H2S, Phase 1, spill potential, procedures and responsibilities. Completed operations Tested High pressure lines Pressure test Dowell to cement head. Pressure test completed successfully - 4500.000 psi Pumped Water based mud spacers - volume 38.000 bbl Pump 38 bbls Arco B45 spacer weighted to 12.3 ppg. Required volume of spacer pumped Mixed and pumped slurry - 86.000 bbl Mix on the fly and pump 412 sacks 15.8 ppg class G w/req'd additives. Shut down to release wiper dart, kick out with 5 bbls fresh water. Released Dart Displaced slurry - 148.000 bbl Displace slurry with rig pumps at 6.5 bpm (caught up to cement at 30 bbls pumped). Slowed down at 65 bbls away to check for wiper plug latch-up: no indication. Continue displacement at 82 bbls away at 6.5 bpm. At 93 bbls pumped, packoff occurred. Plug bumped Regained circulation with a short pipe reciprocation and continue displacement at 3.0 bpm, no further packing off, no fluid lost to the formation. Nump plug at 148 bbls away (on-strokes for 100% pump efficiency). Run Liner, 7in O.D. Functioned Liner hanger Set liner hanger w/2500 psi and continue up to 3800 psi to release running tool (seals still in-tact), release pressure, check floats, pick up 6' to open packer setting dogs. Set packer at 40K lbs (surface indication of shear pins) Equipment work completed Circulated at 7315.0 ft Apply 1000 psi, pick-up 12' to disengage seals, break circulation. Circulate at the liner top (reciprocating) for annular volume plus 40% at 10.5 bpm. D nis~,ion Facility Date/Time 16 Mar 00 PB DS 03 Progress Report Well 03-34B Page 10 Rig Nabors 9ES Date 27 March 00 12:15 12:15-15:00 15:00 15:00-16:30 16:30 16:30-17:00 17:00 17:00-20:30 17:00-20:30 20:30 20:30-23:30 20:30-23:30 23:30 23:30-01:00 23:30-01:00 01:00 01:00-06:00 01:00-02:00 02:00 02:00-06:00 06:00-07:00 06:00-07:00 07:00 07:00-08:30 07:00-08:30 08:30 08:30-19:30 08:30-09:00 09:00 09:00-14:00 14:00 14:00-17:00 17:00 17:00-19:30 19:30 19:30-21:00 19:30-21:00 Duration 2-3/4 hr 1-1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 3 hr 3 hr 1-1/2 hr 1-1/2 hr 5 hr 1 hr 4 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr llhr 1/2 hr 5 hr 3 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr Activity weight increase. Obtained clean returns - 140.00 % hole volume Pulled Drillpipe in stands to 560.0 ft Completed operations Laid down 555.0 ft of 5in OD drill pipe Lay down HWDP and hanger running tool. 18 joints laid out Rigged down Drillstring handling equipment Top drive XO and saver sub. Equipment work completed Test well control equipment Tested BOP stack 250 psi / 3500 psi. Test witnessed by Lou Grimaldi, AOGCC. Pressure test completed successfully - 3500.000 psi BHA run no. 8 Made up BHA no. 8 6-1/8" Smith XR20HTDG + 1.75 degree 4-3/4" motor + MWD. Calibrate MWD depth recorder and upload. MWD failed - Continue Repair Repaired Survey instruments Troubleshoot MWD interference. Equipment work completed BHA run no. 8 Made up BHA no. 8 Completed operations R.I.H. to 7500.0 ft BHA run no. 8 (cont...) R.I.H. to 9000.0 ft (cont...) Stopped · To test equipment Perform integrity test Tested Liner Hold safety meeting, close upper rams, test liner f/30 minutes, charted. No bleed-off. Pressure test completed successfully - 3000.000 psi BHA run no. 8 R.I.H. to 9436.0 ft Continnue in hole to top of cement (no stringers). At Top of cement · 9436.0 ft Drilled installed equipment - Float shoe Drill through cement, LC/FC at 9502 at to shoe.. Completed operations Circulated at 9585.0 ft Change well over to 8.4 QuikDril'n. 90 bbl water and 50 bbls vis'd water spacers. Clean-up after spacers within 30 bbl. Hole displaced with Water based mud - 100.00 % displaced Drilled to 9610.0 ft Rotate thru shoe and 5' of new formation. Slide 15' more. Stopped · To perform FIT Perform integrity test Performed formation integrity test 725 psi = 10.0 ppg EMW. Straight line pressure ncreas¢, no ~,,c~u uuw, altcl -,v 111111. / PR 20 2000 Oil & G.,2s £,¢ms. 6ommimor Ancho~"a§e Facility PB DS 03 Progress Report Well 03-34B Page 11 Rig Nabors 9ES Date 27 March 00 Date/Time 17 Mar 00 18 Mar 00 21:00 21:00-06:00 21:00-06:00 21:00-06:00 06:00-00:00 06:00-07:30 07:30 07:30-08:30 08:30 08:30-12:30 12:30 12:30-15:00 15:00 15:00-18:00 18:00 18:00-22:00 22:00 22:00-23:00 23:00 23:00-00:00 00:00 00:00-06:00 00:00-03:30 03:30 03:30-05:00 05:00 05:00-06:00 06:00-06:00 06:00-06:15 06:15 06:15-07:15 Duration 9 hr 9 hr 9 hr 18hr 1-1/2 hr 1 hr 4 hr 2-1/2 hr 3 hr 4 hr 1 hr 1 hr 6hr 3-1/2 hr 1-1/2 hr 1 hr 24 hr 1/4 hr 1 hr Activity Obtained required level of integrity - 10.0 ppg EMW BHA mn no. 8 Drilled to 9715.0 ft Continue drilling from 9715'. Drilled to 9715.0 ft Drill (sliding) to 9715' MD. Added lubricant to help sliding. Achieving 30 degree/100' build rate. AST 6.25 hfs, ART 2.0hrs BHA run no. 8 (cont...) Drilled to 9734.0 ft (cont...) Drill (sliding) to 9715' MD. Added lubricant to help sliding. Achieving 30 degree/100' build rate. AST 6.25 hfs, ART 2.0hfs Stopped: To circulate Pulled out of hole to 9530.0 ft Pull up into casing shoe at 9588' and slightly past to MAD pass over section of questionable data. At top of check trip interval Washed to 9724.0 ft Pump sweeps and work pipe to clean up cuttings beds (and apparart ledging) from the shoe to TD. Sweeps returned shale, sand, cement, and Barafiber, cleaning up in time. On bottom Drilled to 9765.0 ft AST 1/2 hour, ART 1.0. Only 5 rpm surface rotation allowable + 75 rpm at the motor. MWD/LWD failed - End BHA run Circulated at 9734.0 ft Pump sweep and circulate to POH. Obtained clean returns - 150.00 % hole volume Pulled out of hole to 200.0 ft At BHA Pulled BHA Send motor and ABI in to make-up ABI to new motor. BHA Laid out Downloaded MWD tool Completed operations BHA run no. 9 Serviced M.W.D. tool Change out MWD components. Pulser seat shattered. Equipment work completed Made up BHA no. 9 6-1/8" Smith XR 20, 1.15 degr. motor with ABI, MWD. BHA no. 9 made up R.I.H. to 2200.0 ft Shallow test MWD, RIH. BHA run no. 9 (cont...) R.I.H. to 4000.0 ft (cont...) Shallow test MWD, RIH. Stopped · To service drilling equipment /!,PR 2 0 20, Alaska Oii& Gas Cons. 6 Serviced Brake Anchorage Adjust cooling system glycol distribution to brake. ED )0 Facility PB DS 03 Progress Report Well 03-34B Page 12 Rig Nabors 9ES Date 27 March 00 Datefrime 07:15 07:15-09:00 09:00 09:00-10:00 10:00 10:00-11:30 11:30 11:30-15:00 15:00 15:00-17:00 17:00 17:00-19:00 19:00 19:00-06:00 19:00-06:00 19 Mar 00 06:00-06:00 06:00-07:30 07:30 07:30-09:00 09:00 09:00-14:00 14:00 14:00-14:15 14:15 14:15-06:00 Duration 1-3/4 hr 1 hr 1-1/2 hr 3-1/2 hr 2 hr 2 hr llhr llhr 24hr 1-1/2 hr 1-1/2 hr 5 hr 1/4 hr 15- 3/4 hr Activity Equipment work completed R.I.H. to 7300.0 ft Stopped: To service drilling equipment Serviced Block line Line slipped and cut R.I.H. to 9580.0 ft Unable to re-enter hole Washed to 9615.0 ft Work pipe through first 20' out of the shoe. Persistent packing off. Stopped: To circulate Circulated at 9590.0 ft Circulate hi-vis sweep. Packing off still occurring just outside of shoe. Returns 50/50 sand and brittle shale (2x sand grain size) plus traces of cement. Obtained clean returns - 150.00 % hole volume Washed to 9766.0 ft Hole conditions improved after bottoms' up. Very little resistance below 9680'. On bottom Drilled to 10010.0 ft Continue drilling from 10,010'. Drilled to 10010.0 ft Kingak: 8700' TVD, 9590 MD TSag: 8712 TVD, 9629' MD Top Target: 8726' TVD, 9882' MD Base Target: 8736' TVD Base Sag: 8750' TVD Dip: 89.3 degrees BHA run no. 9 (cont...) Drilled to 10055.0 ft (cont...) Kingak: 8700' TVD, 9590 MD TSag: 8712 TVD, 9629' MD Top Target: 8726' TVD, 9882' MD Base Target: 8736' TVD Base Sag: 8750' TVD Dip: 89.3 degrees RL.C Et v L-..- ' , / ,PR 20 200(} Alaska Oil & Gas Cons. Comr~ Stopped · To circulate Circulated at 10055.0 ft Sliding difficulty, circulate sweep to clean up hole. Obtained clean returns - 115.00 % hole volume Drilled to 10175.0 ft Sliding improved, continue drilling. Got stuck whilst pipe stationary Worked stuck pipe at 10175.0 ft Experienced brief differential sticking tendancy afer completing a slide. Worked torque don into string to break free. No further complications. Pipe came free Drilled to 10600.0 ft ssion Facility Date/Time 20 Mar 00 21 Mar00 22 Mar 00 PB DS 03 Progress Report Well 03-34B Page 13 Rig Nabors 9ES Date 27 March 00 06:00-06:00 06:00-20:15 20:15 20:15-21:15 21:15 21:15-03:00 03:00 03:00-03:45 03:45 03:45-06:00 06:00-05:00 06:00-12:30 12:30 12:30-14:30 14:30 14:30-15:30 15:30 15:30-16:00 16:00 16:00-17:00 17:00 17:00-20:00 20:00 20:00-02:00 02:00 02:00-03:30 Duration 24 hr 14-1/4 hr 1 hr 5-3/4 hr 3/4 hr 2-1/4 hr 23 hr 6-1/2 hr 2 hr 1 hr 1/2 hr 1 hr 3 hr 6 hr 1-1/2 hr Activity as required. Pumped sweeps at 10,560', 10,725', BHA run no. 9 (cont...) Drilled to 11045.0 ft (cont...) Continue drilling from 10,600' to 11,045', sliding as required. Pumped sweeps at 10,560', 10,725', 10,925', and 11,080'. Sweeps reurning 10-20% increase of cuttings at shaker. Stopped · To service drilling equipment Serviced Top drive pipe handler Remove die blocks from top drive gripper (found loose). Equipment work completed Drilled to 11138.0 ft Sliding down to return to higher quality sands. Stopped ' To service drilling equipment Serviced Top drive pipe handler ,!~.PR Re-installed gripper die blocks. Equipment work completed /qaka 0ii & Gas Drilled to 11175.0 ft Continue drilling from 11,175' to 11,263'. Sliding down with little response, low torque and slow ROP. Pick TD for ROP. BHA run no. 9 (cont...) Drilled to 11263.0 ft (cont...) Continue drilling from 11,175' to 11,263'. Sliding down with little response, low torque and slow ROP. Pick TD for ROP. ROP dropped from 40.0 ft/hr to 10.0 ft/hr - Formation change Circulated at 11263.0 ft Circulate sweep w/10-15% cuttings increase on returns. Obtained clean returns - 115.00 % hole volume Pulled out of hole to 9500.0 ft Short trip to 7" casing shoe. Tight ( up to 50K over) pulling through 10,900' area and again (20K over) at -9760'. No excess drag in shoe area. At 9588in casing shoe Serviced Top drive Drop electronic multi-shot, service top drive. Equipment work completed R.I.H. to 11263.0 ft Downward drag immediately out of shoe (9616') indicative of ledging. Set down once up to 45K then continue in hole to TD without excess drag. On bottom Circulated at 11263.0 ft CBU at TD and spot 75-bbl hi-vis liner running pill in open hole. Hi-Vis mud spotted downhole Pulled out of hole to 200.0 ft Pull slowly through openhole and 7" casing. No excess drag in openhole. At BHA Pulled BHA Flush out jars and lay down same. Recover EMS, OlGdK k)li Ult. Anchor~ , Con,minion Facility Date/Time 23 Mar 00 PB DS 03 Progress Report Well 03-34B Page 14 Rig Nabors 9ES Date 27 March 00 03:30 03:30-04:30 04:30 04:30-05:00 05:00 05:00-06:00 05:00-05:45 05:45 05:45-06:00 06:00 06:00-05:00 06:00-09:30 09:30 09:30-10:00 10:00 10:00-13:00 13:00 13:00-14:00 14:00 14:00-15:30 15:30 15:30-16:30 16:30 16:30-17:00 17:00 17:00-19:00 19:00 19:00-05:00 Duration 1 hr 1/2 hr 1 hr 3/4 hr 1/4 hr 23 hr 3-1/2 hr 1/2 hr 3 hr 1 hr 1-1/2 hr 1 hr 1/2 hr 2 hr 10hr Activity BHA Laid out Downloaded MWD tool Completed operations Pulled BHA Lay down motor and MWD. Completed operations Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting Completed operations Run Liner, 4-1/2in O.D. (cont...) Ran Liner to 1788.0 ft (4-1/2in OD) 45 joints slotted x solid liner. Stopped: At sub-assembly Rigged up sub-surface equipment - Liner hanger 7" x 5" Baker Flex II w/xo's to 4-1/2". Bakerlok'd two IBT connections in string. Equipment work completed Ran Liner on landing string to 9570.0 ft RIH on 4" DP to 7" shoe. No indication of 7" liner top. At Top of new hole section: 9588.0 ft Circulated at 9570.0 ft Break circulation and hold safety meeetin w/NAD President, Jim Denney. Circ 200 bbls at 5 bpm, 800 psi. PUW = 178, SOW = 160, RW = 170, TQ = 3000 fl-lbs. Broke circulation Ran Liner on landing string to 11263.0 ft Set down several times at 9626', up to 60K., orient 180 degr, continue setting down, orient 90 degr, RIH after 35K momentary set-down. Continue RIH to TD w/10-25K drag. On bottom Circulated at 9500.0 ft Set liner on bottom, make up top drive, drop setting ball, circulate into place @ 1.75 bpm, 36 bbls. Dropped ball Set Liner hanger at 9453.3 ft with 2000.0 psi Set hanger, bleed off pressure, set down 35K to confirm set. Pressure to 2500 to release, pick up to confirm. Shear ball seat at 3500 psi, disengage seals from running tool, pick up and break circulation. Equipment work completed Circulated at 9450.0 ft Pump 40-bbl high-vis sweep and circulate, reciprocate at 9.5 bpm, 1400 psi, 725 bbls until returns cleaned. Obtained clean returns - 150.00 % hole volume Laid down 11550.0 ft of 4in OD drill pipe POH, LDDP. Seals on running tool in-tact. zo ooo[ Facility Date/Time 24 Mar 00 PB DS 03 Progress Report Well 03-34B Page 15 Rig Nabors 9ES Date 27 March 00 22:00-03:30 22:00-22:15 22:15 22:15-23:00 23:00 23:00-01:30 01:30 01:30-02:15 02:15 02:15-02:30 02:30 02:30-03:30 03:30 03:30-06:00 03:30-06:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-06:00 06:00-06:00 06:00-08:00 06:00-07:00 07:00 07:00-07:30 07:30 07:30-07:45 07:45 07:45-08:00 08:00 08:00-09:30 08:00-08:45 08:45 08:45-09:30 Duration 5-1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 3/4 hr 1/4 hr 1 hr 2-1/2 hr 2-1/2 hr 1 hr 1 hr 24 hr 24 hr 2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 3/4 hr 3/4 hr Activity Wellhead work Tested Hanger plug Test BPV and tubing hanger seals 500 psi. Visual confirm no leak, pressure holding. Pressure test completed successfully - 500.000 psi Removed BOP stack Equipment work completed Installed Xmas tree NU tree and adapter flange. Equipment work completed Installed Hanger plug Pull BPV w/lubricator, set tree test plug. Equipment work completed Tested Xmas tree Test tree 250/5000 psi, pull test plug. Pressure test completed successfully - 5000.000 psi Rigged up High pressure lines RU circulating lines to tree. Equipment work completed Fluid system Reverse circulated at 9456.9 ft 350 bbls clean inhibited sea water. 372 joints laid out Test well control equipment Tested BOP stack Continue testing BOPs 250/5000. Test witness waived by John Spaulding, AOGCC. String displaced with Inhibited brine - 100.00 % displaced Test well control equipment (cont...) Tested BOP stack (cont...) Continue testing BOPs 250/5000. Test witness waived by John Spaulding, AOGCC. Run Tubing, 4-1/2in O.D. Functioned Permanent packer RD lines from reverse circ. Drop 1 7/8" ball/rod, RU HB&R. Stopped · To hold safety meeting Held safety meeting PJSM on pressure testing and packer setting procedures. Completed operations Tested High pressure lines Pressure test HB&R lines to 4900 psi Pressure test completed successfully - 4900.000 psi Functioned Production packer Set packer w/4800 psi. Equipment work completed Perform integrity test Tested Tubing Bleed pressure to 3000 psi, hold for 30 minute, recorded on chart, bleed to 1500 psi. Pressure test completed successfully - 3000.000 psi Tested Production packer - Via annulus Test to 3000 psi, 30 minutes. Bleed off tubing Facility PB DS 03 Progress Report Well 03-34B Page 16 Rig Nabors 9ES Date 27 March 00 Date/Time 09:30 09:30-12:00 09:30~12:00 12:00 12:00-13:30 12:00-12:30 12:30 12:30-13:30 13:30 13:30-06:00 Duration 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1 hr 16-1/2 hr Activity off well pressure. Pressure test completed successfully - 3000.000 psi Fluid system Freeze protect well - 154.000 bbl of Diesel Reverse in 54 bbls diesel. U-tube for freeze protection to 2200'. Completed operations Wellhead work Rigged up Hanger plug Set BPV w/DSM lubricator. Equipment work completed Rigged down High pressure lines Remove rig lines from tree, clean cellar area, secure tree. RELEASE RIG 13:30 hrs 3/24/2000 Equipment work completed Move rig fi, PR 20 2000 North Slope Alaska Alaska State Plane 4 PBU EOA DS 03 03-34B Surveyed: 21 March, 2000 SURVEY REPORT 30 March, 2000 Your Ref: AP1-500292113202 Surface Coordinates: 5936161.37 N, 714142.62 E (70° 13' 42.6317"N, 148° 16' 17.4115" W) Kelly Bushing: 53.55ft above Mean Sea Level '.0, ~,,,'i L-'L. ! N Q' Se,~ ',Vmmms Survey Ref: svy9723 Sperry-Sun Drilling Services Survey Report for 03-34B Your Ref: API-500292113202 Surveyed: 21 March, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 7491.55 26.870 200.500 6979.94 7033.49 7501.00 26.890 200.460 6988.37 7041.92 7571.41 26.420 203.480 7051.30 7104.85 7604.85 24.470 205.200 7081.49 7135.04 7635.35 21.020 206.980 7109.62 7163.17 7666.58 19.360 209.060 7138.93 7192.48 7695.38 19.050 208.970 7166.13 7219.68 7725.97 19.100 207.850 7195.04 7248.59 7791.56 17.850 213.160 7257.25 7310.80 7881.95 15.880 215.240 7343.75 ' 7397.30 7975.17 15.810 209.940 7433.43 7486.98 8072.13 15.470 209.980 7526.80 7580.35 8165.02 15.480 210.820 7616.32 7669.87 8258.22 15.110 212.760 7706.22 7759.77 8347.11 15.150 213.850 7792.03 7845.58 8441.79 16.050 217.370 7883.23 7936.78 8470.91 17.330 220.670 7911.12 7964.67 8501.29 19.090 224.180 7939.98 7993.53 8531.25 20.530 227.530 7968.16 8021.71 8564.03 21.930 231.620 7998.72 8052.27 8593.15 22.970 233.490 8025.63 8079.18 8627.49 24.630 236.610 8057.05 8110.60 8661.51 27.920 242.990 8087.56 8141.11 8689.54 31.440 246.370 8111.91 8165,46 8721.97 34.740 248.920 8139.08 8192,63 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1898.45 S 555.53 W 5934247.92 N 713641.20 E 1902.45 S 557.03 W 5934243.87 N 713639.82 E 1931.74 S 568.83 W 5934214.26 N 713628.85 E 1944.83 S 574.75 W 5934201.01 N 713623.31 E 1955.42 S 579.92 W 5934190.27 N 713618.44 E 1964.94 S 584.98 W 5934180.62 N 713613.66 E 1973.22 S 589.57 W 5934172.21 N 713609.30 E 1982.02 S 594.33 W 5934163.28 N 713604.80 E 1999.92 S 604.84 W 5934145.08 N 713594.79 E 2021.62 S 619.55 W 5934122.98 N 713580.70 E 2043.04 S 633.25 W 5934101.17 N 713567.62 E 2065.69 S 646.31 W 5934078.17 N 713555.21 E 2087.07 $ 658.85 W 5934056.44 N 713543.28 E 2107.96 S 671.79 W 5934035.19 N 713530.94 E 2127.35 S 684.53 W 5934015.44 N 713518.75 E 2148.03 S 699.37 W 5933994.35 N 713504.51 E 2154.52 S 704.64 W 5933987.72 N 713499.42 E 2161.52 S 711.05 W 5933980.54 N 713493.21 E 2168.58 S 718.34 W 5933973.28 N 713486.13 E 2176.26 $ 727.38 W 5933965.34 N 713477.31 E 2183.02 S 736.21 W 5933958.34 N 713468.67 E 2190.94 S 747.57 W 5933950.09 N 713457.54 E 2198.46 S 760.59 W 5933942.20 N 713444.74 E 2204.38 S 773.14 W 5933935.94 N 713432.36 E 2211.09 S 789.52 W 5933928.76 N 713416.19 E Dogleg Rate (°/lOOft) 0.285 2.036 6.235 11.533 5.79O 1.081 1.208 3.194 2.279 1.554 0.351 0.242 0.678 0.323 1.379 5.468 6.824 6.119 6.215 4.332 6.066 12.733 13.901 11.042 LPR 20 2000 ~a~ka 0il & Gas Cons. ~mmissmn -2- Alaska State Plane 4 PBU_EOA DS O3 Vertical Section (ft) Comment 978.87 981.25 999.50 10o8.28 1015.75 1022.87 1029.25 1 o35.91 1050.28 1069.60 1087.88 1 lO5.81 1122.95 114o.37 1157.24 1176.45 1183.07 1190.93 1199.65 121o.22 1220.37 1233.26 1247.66 1261.24 1278.72 Tie-on Survey Window Point Continued... DrillQuest 1.05.04e Anchorage Sperry-Sun Drilling Services Survey Report for 03-34B Your Ref: API-500292113202 Surveyed: 21 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8749.98 36.420 250.230 8161.86 8215.41 8781.70 37.650 251.340 8187.18 8240.73 8812.81 39.580 251.940 8211.49 8265.04 8847.44 41.650 250.640 8237.77 8291.32 8875.99 43.410 252.670 8258.81 8312.36 8908.49 45.270 253.660 8282.06 8335.61 8939.32 48.280 255.740 8303.17 8356.72 8971.00 49.980 255.630 8323.90 8377,45 9000.79 51.020 256.650 8342.85 8396.40 9031.46 53.650 257.160 8361.59 8415.14 9061.81 56.390 256.890 8378.98 8432,53 9092.67 57.480 257.580 8395.82 8449.37 9122.55 57.670 256.850 8411.84 8465.39 9188.92 58,390 257.590 8446.98 8500.53 9214.54 58.730 258.680 8460.35 8513.90 9250.35 58.960 259.030 8478.87 8532.42 9281.92 59.050 259.080 8495.13 8548.68 9313.90 59.250 257.900 8511.53 8565.08 9374.50 59.550 258.490 8542.38 8595.93 9471.58 60,410 258.650 8590.95 8644.50 9502,42 60,490 257.940 8606.16 8659.71 9531.24 61,110 258.340 8620.22 8673.77 9576.11 64.440 259.370 8640.74 8694.29 9608,65 70.180 260.070 8653.29 8706.84 9638.59 78,730 261.840 8661.31 8714.86 R,...CEiVED /,PR 20 2000' Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 2216.78 S 804.79W 5933922.64 N 713401.08 E 2223.06 S 822.83W 5933915.85 N 713383,23 E 2229.17 S 841.26W 5933909.21 N 713364.98 E 2236.41S 862.61W 5933901.38 N 713343.85 E 2242.48 S 880.92W 5933894.79 N 713325.71 E 2249,05 S 902.66W 5933887,60 N 713304,16 E 2254.97 S 924.33W 5933881.07 N 713282.67 E 2260.89 S 947.54W 5933874.49 N 713259.64 E 2266.40 S 969.86W 5933868.36 N 713237.49 E 2271.90 S 993.50W 5933862.19 N 713214.01E 2277.48 S 1017.73W 5933855.92 N 713189.95 E 2283.19 S 1042.96W 5933849.49 N 713164.90 E 2288.77 S 1067.55W 5933843.21 N 713140.47 E 2301.23 S 1122,46W 5933829.21 N 713085.94 E 2305.72 S 1143.85W 5933824.11 N 713064.68 E 2311.64 S 1173.92W 5933817.33 N 713034.79 E 2316.78 S 1200.49W 5933811.44 N 713008.38 E 2322.26 S 1227.39W 5933805.20 N 712981.65 E 2332.93 S 1278.45W 5933793.09 N 712930.91E 2349.59 S 1360.84W 5933774.10 N 712849.03 E 2355.03 S 1387.11W 5933767.91 N 712822.92 E 2360.20 S 1411.73W 5933762.05 N 712798.46 E 2367.91S 1450.87W 5933753.23 N 712759.55 E 2373.26 S 1480.40W 5933747.04 N 712730.19 E 2377.78 S 1508.86W 5933741.72 N 712701.87 E 6.586 4.413 6.319 6.457 7.816 6.106 10.930 5.373 4.378 8.676 9.057 3.998 2.158 1.439 3.865 1.055 0.316 3.229 0.973 0.897 2.019 2.469 7.697 17.751 29.118 Alaska State Plane 4 PBU_EOA DS 03 Vertical Section (ft) Comment 1294.89 1313.90 1333.24 1355.68 1374.90 1397.58 1420.02 1443.97 1466.96 1491.24 1516.10 1541.96 1567.18 1623.48 1645.33 1675.95 1702.99 1730.43 1782.57 1866.58 1893.40 1918.55 1958.41 1988.38 2017.11 Continued... ~n ~,.-,r,-h ~nnn- 10:17 Alaska Oil & Gas Cons, Commissio~ -3- DrillQuest 1.05,04e Sperry-Sun Drilling Services Survey Report for 03-34B Your Ref: AP1-$00292113202 Surveyed: 21 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9672.00 88.090 260,000 8665.14 8718.69 9702.81 91.910 259.900 8665.14 8718.69 9734.44 86.670 260.310 8665.53 8719.08 9763.93 84,140 259.950 8667.89 8721.44 9795.53 86.490 260.680 8670.47 8724.02 9827.11 88.960 261.050 8671.73 8725.28 9858.69 89.020 261.400 8672.28 8725.83 9889.41 86.550 261,250 8673.47 8727,02 9920.85 85.260 261.070 8675.71 8729.26 9951.05 85.190 260,640 8678.23 8731.78 9979.34 85.250 260.390 8680.59 8734,14 10010.60 85.880 260.970 8683.00 8736.55 10043.70 88.150 260.610 8684.73 8738.28 10074.70 89.320 261,230 8685.41 8738.96 10100.40 89.260 261.430 8685.73 8739.28 10134.40 89.630 261.860 8686.06 8739.61 10166.20 90.800 260.530 8685.94 8739.49 10199.40 91.470 260.920 8685,28 8738.83 10228.60 91.600 260.550 8684.50 8738.05 10260.00 91.480 260.910 8683.66 8737.21 10292.30 90.250 261.740 8683.17 8736,72 10323.70 90.000 261.500 8683,10 8736.65 10355.60 90.060 261.460 8683.08 8736.63 10383.70 90.040 261.390 8683,06 8736.61 10416.90 88.520 263,510 8683.48 8737.03 ,,PR 20 2000 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2383.02 S 1541.59W 5933735,55 N 712669,30 E 2388.39 S 1571.92W 5933729.32 N 712639.13 E 2393.83 S 1603.07W 5933723.00 N 712608.15 E 2398.86 S 1632.03W 5933717.15 N 712579,35 E 2404.16 $ 1663.07W 5933710.97 N 712548.47 E 2409.17 S 1694.22W 5933705.08 N 712517.47 E 2413,99 $ 1725.43W 5933699.38 N 712486.41 E 2418.62 $ 1755.77W 5933693.89 N 712456.21 E 2423.44 $ 1786.76W 5933688.19 N 712425.38 E 2428.22 S 1816.47W 5933682.57 N 712395.81 E 2432.86 S 1844,28W 5933677.13 N 712368.15 E 2437.91 S 1875.03W 5933671.21 N 712337.55 E 2443.20 S 1907.66W 5933665.00 N 712305.08 E 2448.09 S 1938.26W 5933659.24 N 712274.63 E 2451.97 S 1963.67W 5933654,65 N 712249.35 E 2456,91S 1997.30W 5933648.76 N 712215.86 E 2461.77 S 2028,73W 5933643.00 N 712184.59 E 2467.12 S 2061.49W 5933636.72 N 712152.00 E 2471.82 S 2090.30W 5933631.21N 712123.33 E 2476.88 S 2121.27W 5933625.27 N 712092.51 E 2481,75 S 2153.20W 5933619.50 N 712060.74 E 2486.33 S 2184.26W 5933614.04 N 712029.81 E 2491,05 S 2215.81W 5933608.42 N 711998.41 E 2495.24 S 2243.60W 5933603,44 N 711970.76 E 2499.60 S 2276.51W 5933598.15 N 711937.99 E Dogleg Rate (°/100ft) 28.544 12.403 16.617 8.665 7.785 7.909 1.124 8.055 4.143 1.438 0,9o6 2.736 6.943 4.271 0.812 1.668 5.570 2.335 1.343 1.208 4.594 1.104 0,226 0.259 7.857 Alaska State Plane 4 PBU_EOA DS 03 Vertical Section (ft) Comment 2050.17 2080.92 2112.48 2141.82 2173,25 2204.72 2236.19 2266,78 2298.04 2328.06 2356,19 2387.28 242O,24 2451,15 2476.76 2510.63 2542.33 2575.44 2604.55 2635.86 2668.05 2699.33 2731.12 2759.12 2792.14 Continued... Ancho~'~e -4- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 03-34B Your Ref: API-500292113202 Surveyed: 21 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°/lOOft) 10448.30 87.170 263.080 8684.66 8738.21 2503.27 S 2307.67 W 10478.40 87.230 263.600 8686.13 8739.68 2506.75 S 2337.53 W 10511.20 87.790 263.180 8687.55 8741.10 2510.53 S 2370.08 W 10540.40 89.160 261.740 8688.33 8741.88 2514.36 S 2399.02 W 10571.20 89.380 262.140 8688.72 8742.27 2518.68 S 2429.51 W 10603.30 89.260 262.740 8689.10 8742.65 2522.90 S 2461.33 W 10638,40 88.370 261.740 8689.83 8743.38 2527.64 S 2496.10 W 10669.40 88.720 262.090 8690.62 8744.17 2531.99 S 2526.78 W 10698.20 89.020 262,280 8691.18 8744.73 2535.91 S 2555.31 W 10791.90 89.570 263.260 8692.34 8745.89 2547.70 S 2648.25 W 10884.80 90.980 263.590 8691.89 8745.44 2558.34 S 2740.54 W 10978.80 88.960 265.920 8691.94 8745.49 2566.93 S 2834.13 W 11072.40 89.080 263.920 8693.54 8747.09 2575.22 S 2927.35 W 11162.70 88.160 265.490 8695.72 8749.27 2583.55 S 3017.23 W 11 195.30 88.150 265.470 8696.77 8750.32 2586.12 S 3049.71 W 11263.00 88.150 265.470 8698.95 8752.50 2591.46 S 3117.17 W 5933593.60 N 711906.94 E 5933589.27 N 711877.19 E 5933584.58 N 711844.76 E 5933579.93 N 711815.95 E 5933574.74 N 711785.59 E 5933569.62 N 711753.90 E 5933563.90 N 711719.28 E 5933558.67 N 711688.73 E 5933553.95 N 711660.33 E 5933539.52 N 711567.76 E 5933526.27 N 711475.81E 5933515.02 N 711382.50 E 5933504.09 N 711289.55 E 5933493.21 N 711199.94 E 5933489.73 N 711167.55 E 5933482.47 N 711100.27 E 4.512 1,737 2.133 6.805 1.482 1.906 3.813 1.596 1.233 1.199 1.559 3.280 2.140 2.015 0.069 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.381° (04-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 256.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11263.00ft., The Bottom Hole Displacement is 4053.69ft., in the Direction of 230.262° (True). R CEivEO /.PR 20 2000 ~a~ka Oil & Gas Cons. Commisskm 10:17 - 5 - Alaska State Plane 4 PBU_EOA DS O3 Vertical Section (ft) Comment 2823.31 2853.17 2885.71 2914.75 2945.42 2977.35 3012.28 3043.14 3071.80 3164.95 3257.20 3350.25 3442.86 3532.24 3564.44 3631.30 Projected Survey Continued... DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 03-34B Your Ref: AP1-$00292113202 Surveyed: 21 March, 2000 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 03 Comments Measured Depth (ft) 7491.55 75Ol .oo 11263.o0 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7033.49 1898.45 S 555,53 W 7041,92 1902,45 S 557,03 W 8752.50 2591,46 S 3117.17 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) o.oo o.oo To Measured Vertical Depth Depth (ft) (ft) 11263.00 8752.50 Survey Tool Description MWD Magnetic 20 2000 Gas Co~s. Con~mi~or~ o~ ,A~.~, ~nnn_ ~n.~? -6- DrillQuest 1.05.04e TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMPlISSION Dan Stone Senior Drilling Engineer ARCO Alaska Inc. POBox 196612 Anchorage, AK 99519-6612 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ~3192 PHONE; (907) 279-1433 FAX: (907) 276-7542 R.e: Prudhoe Bay Unit 3-34B ARCO Alaska Inc. Permit No: 200-011 Sur. Loc. 97'NSL, 846'EWL, Sec. l 1, T10N, R15E, UM Btmhole Loc. 2578'SNL, 2627'WEL, Sec. 15, T10N, R15E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF T iltoE~OM MISSION DATED this day of February, 2000 dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmcntal Conservation w/o encl. STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION CC. ,,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [:]...Re-Entry [] DeepenI [] Se.rvice E::]..Development Gas [] Single Zone [] Multiple Zone ......... 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. RKB = 57.75' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation ~';Z '? B~ay.Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028331/~.,j ~,~.,~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 97' NSL, 846' EWL, SEC. 11, T10N, R15E, UM Prudhoe Bay Unit ........ At top of productive interval 81 Well Number Number U-630610 2225' SNL, 508' WEL, SEC. 15, T10N, R15E, UM 03-34B At total depth 9. Approximate spud date Amount $200,000.00 2578' SNL, 2627' WEL, SEC. 15, T10N, R15E, UM 02/20/00 12. Distance"~o neareSt property 'lir~e'/':! ~. Distance"'to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028328,...~5.78' MD I 17-14 is 100' away at 10982' 2560 11617' M D / 8743' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7710' MD Maximum Hole Angle 90° Maximum surface 2235 psig, At total depth (TVD) 8685' / 3100 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1920' 7560' 7037' 9474' 8649' 324 sx Class 'G' 6-1/8" 4-1/2" L-80 BTc-M"'~& DSS 2317' 9300' 8564' 11617' ' ........ 12.6# & 12.75# 8685' Uncemented Slotted Liner , ,i,u,r,,,,u u,u,n n r, , i , ,,,,,, ,, , ,,, ,,,, ,,,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Tagged PBTD at 9848' MD (04/21/99) Total depth: measured 9978 feet Plugs (measured) true vertical 9213 feet Effective depth: measured 9848 feet Junk(measured) kl A true vertical 9095 feet 0RIGI~ "' 'L Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 1865 # Poleset 110' 110' Surface 2439' 13-3/8" 2300 sx Coldset II 2501' 2501' Intermediate Production 7948' 9-5/8" 500 sx Class 'G', 300____ .... __.. o,....,=~sx Coldset I 8010' 7498' Liner 2236' 7" 426 sx Class 'G' RkO ~_.lVl:::[~,. 9978, 7257' - 9213' ,.... FEB 0,3 2000 Perforation depth: measured 9482'- 9806' (five intervals) AlaSka Oil & Gas Cons. Oommi-i true vertical 8762'- 9057' (five intervals) jl~t~li01'~ 20. Attachments [] Filing Fee [] ProPerty Plat [] BOP Sketch [] Diverter Sketch [] Drilling'"Program ..... [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lowell Crane, 564-4089 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~-~'~'---~"v'/. ~ Title Senior Drilling Engineer Date , Commission Use Only Permit Number I APl Number I Approva, Date I See cover,attar '..~- ~ ~..)//// 50-029-21132-02 c:~ - ~/~ '" O~ for other requirements Conditions of Approval: Samples Required .)~.Yes ~No Mud Log Required [] Yes ]~'No Hydrogen Sulfide Measure~- .~Yes[~ No Directional Survey Required '[~Yes 'Il'No Required Working Pressure fof BOPE 1'-12K; 1'-13K; [-14K; 1~5K; []10K;' r"115K~,,..q~..~-~%~, Other~)RIGINAL SIGNED BY by order of Approved By Robert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate ,~.N,V~'8 Permit to Drill I Well Name: 103-34B Sidetrack Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: Target Location: (Sag) Bottom Hole Location: X = 714142.62 Y = 5936161.37 97' FNL 846' FWL Sll T10N R15E X = 712857.59 Y = 5933801.68 2225' FNL 508' FEL S15 T10N R15E X = 710750.00 Y = 5933390.00 2578' FNL 2627' FEL S15 T10N R15E Umiat Umiat Umiat AFE Number: I 4J0432.0 I Estimated Start Date: 102-20-00 I IMD:111,617'1 ITVD:I8743 I IRig: I Nabors9ES I Operatin~l days to complete: 125 Cellar Box/MS: 127.8' I IRKS= 157.8' I Well Design (conventional, slimhole, etc.): I conventional horizontal sidetrack I Obiactive: I Sag River Sand Stone Mud Program: 8-1/2" Intermediate Hole (7,710' - 9,474'): 6% KCI Polymer Interval Density Viscosity YP LSR YP pH APl HTHP (ppg) (seconds) Filtrate Filtrate KOP to 10.0 38-50 25-35 5-8 9.0-9.5 6cc < 15 Casing to to to Point 10.8 <5 <10 6-1/8" Production Hole (9,474' - 11,617') Quickdril-n Interval Density Viscosity YP' LSR YP pH (ppg) (seconds) Production 8.3 - 8.5 40 25 <12,000 8,5-9.5 Hole RECEIVED FEB 0 ~ ~000 Alaska Oil & Gas Cons. Commmion ,W'fl~ermit to Drill Directional: KOP: 1 7710' MD Maximum Hole Angle: Close Approach Wells: 90° in Sag River Reservoir 17-14 to be mitigated Logging Program: Intermediate Hole Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling' MWD / GR / RES Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost Not penetrated in this sidetrack SV5 / T8 Not penetrated in this sidetrack SV3 / T5 Not penetrated in this sidetrack SV1 /T3 Not penetrated in this sidetrack 9-5/8" Surface Csg Not penetrated in this sidetrack Ugnu Not penetrated in this sidetrack K10 7894' 7340' K5 8579' 7990' HRZ 9052' 8400' (374' md, 230' tvd of HRZ. Build f/44° to 64°) Sag River 9464' 8645' 3100 psi, ( 6.9 ppg EMW) TD 11,617' 8685' In Sag River Casinq/'l'ubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD ss MD/TVD ss 8-1/2" 7" 26# L-80 BTC-M -1920' 7560'/7037' 9474'/8649' 6-1/8" 4-1/2" 12.6# & L-80 BTC-M -2317' 9300'/8564' 11,617'/8685' Slotted 12.75# &DSS Tubing 4-1/2" 12.6# L-80 IBTC-M -9300' GL 9300'/8564' Cement Calculations: I Casing Size 17" Intermediate Liner RECEIVED FEB 05 AlaSka 0il & 6as C0ns. 60am~ N~ Permit to Drill Basis: Tail' Based on 1920' of liner to be cemented. 150' of liner lap + 1770' of open hole with 50% excess + 80' shoe track volume. Total Cement Volume: 1 67 bbl / 376 ft~ / 324 sks of Dowell Premium 'G' at 15.8 ppg and 1 1.16 cf/sk. Casing Size 14-1/2" Slotted Production LinerI Basis' I Lead: NA Tail:' NA I Total Cement Volume: Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate / Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Planned completion fluid: 3100 psi @ 8685' TVDss - Sag River. 2235 psi (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 3500 psi 8.4 ppg filtered sea water/6.8 ppg Diesel RECEIVED & Gas Cons. NV-18 Permit to Drill Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · Drill Site 3 is an H2S Drill Site and Standard Operating Procedures for H2S precautions will be followed at all times. The highest level of H2S recently measured on DS 03 has been 688 ppm in well 3-09 in August of 1999. DRILLING CLOSE APPROACH: One close approach issue is being mitigated. One deep close approach well, 17-14, is anticipated to be approximately 100' below the horizontal interval of 3-34B at a depth of -10,982' MD (in 03-34B.) INTERMEDIATE SECTION' · Hole condition and shale stability will be the most significant risk in this hole section. The HRZ shale is planned to be drilled with a maximum inclination of -64© which will require an anticipated mud weight of 10.8 ppg in order to maintain stability. · The planned sidetrack will cross one known fault in the shale section above the K5 marker. No lost circulation is anticipated. · The FIT test is planned to 12.5 ppg, which is -1.7 ppg above the planned mud weight at TD of the hole interval. No permeable intervals are anticipated in the intermediate hole. · Kick tolerance for the 9-5/8" window would be an infinite volume assuming an influx (assumes gas) at section TD of 9464 MD in the Sag River. This scenario is worse case based on a 6.9 ppg EMW pore pressure, a minimum fracture gradient of 12.0 ppg EMW at the 9-5/8" window and 10.8 ppg mud in the hole. PRODUCTION SECTION' · Differential sticking will be a problem if loss circulation is occurring or if the drill string is left stationary for an extended period or time. · No faults are mapped in the Sag River section of the well bore. · The FIT test is planned to 10.0 ppg, which is -1.5 ppg above the maximum mud weight planned for this interval. · Kick tolerance for the 7" shoe would be an infinite volume assuming an influx (assumes gas) at section TD of 11,617' MD in the Sag River. This scenario is worse case based on a 6.9 ppg EMW pore pressure, a minimum fracture gradient of 10.0 ppg EMW at the 7" liner shoe and 8.4 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class tl wastes to 04 for injection. Haul all Class I wastes to Pad 3 for disposal. RECEI I D FEB 05 2000 Alaska Oil & Gas Cons. ComndaMon NV-18 Permit to Drill · . SIDETRACK PROCEDURE SUMMARY Pre-Riq Work 1. Drift tubing, RU coil and P&A existing perforations to place TOC at 9300'MD. Tag and test to meet AOGCC requirements. Pressure test 9-5/8" casing against P&A to 3000 psi. 2. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the 9 5/8" packoff tests, completely back out and check each lock down screw for breakage (check one at a time). 3. Cut the 4-1/2" by 3-1/2" 13CR production tubing near 8500' (Ensure cut is above cement in the annulus from the packer squeeze.) Cut point is in the 3-1/2" tubing. 4. Set a BPV in preparation of the rig move. Assure annuli are freeze protected. Ri.q Workover Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. 2. Pull 4 Y2" and 3-1/2" 13CR tubing down to the tubing cut at 8500'. 3. Replace 9-5/8" packoff if necessary 4. Make GR/JB run to 8000'MD. Set BP at +/-7950'MD, test 9-5/8" against BP. 5. Section mill from 7700' to 7750'MD. Spot balanced plug of 17.0 ppg cement across the section milled exit point. Note: There is a possibility that a whipstock & mill could be used to initiate the sidetrack instead of the section mill. This decision is still pending the results of research into the original 3-34 9-5/8" casing cement job and the formations that exist near the desired KOP. 6. Sidetrack from the existing wellbore in 8-1/2" hole at 7710'MD/7171'TVDss approx. 7. Drill 8-1/2" hole through Colville shales to land at high angle in the Sag River at approx. 9500'MD. 8. Run and cement 7" 26# drilling liner in the Sag River at approx. 9500'MD P. Drill 6-1/8" horizontal hole from 9700' to 11617' in Sag River formation. Run MWD/GR/Res real time LWD. RECEIVED FEB 000 Alaska 0il & Gas Cons. Commission NV-18 Permit to Drill ]0. Run 4-1/2" slotted production liner (and cement if Bonzai.) ! ]. Pressure test casing strings to 3000 psi ]2. Run 4-1/2" 12.6#, L80, IBT-Mod production tubing. Set packer near 9400'. Plan 6- GLM's ]3. Freeze protect permafrost zone thru GLM. ]4. Set BPV, ND BOPE, NU and test tree. RDMO. Estimated Spud Date: 2-22-00 Lowell R. Crane Shared Services Drilling 564-4089 RECEIVED FEB 05 Alaska ~1 & Gas Cons. ~mi~ TREE: 03-34B Proposed Orig RKB = 62' WELLHEAD: 13-3/8", 72 CC/fi, LB0, BTC X Nipple 6-GLMs, 1-1/2 to top 7 inch, 1 inch below the liner top 4-1/2" 12.6# L-80, IBT*~Mod Tubing surface to 9550 approx. 7 in., 26CC, L-80 drilling liner from 7550 ft 9464 ft in the Sag river formation Top of 7" Liner at ~ 9-5/8", 47 CC/ft, L80, ~ BTC Coil to spot/squeeze t5,8 Ppg cmt across perfs to Place TOC at 9350, approx. HES TNT 7" x 4-1/2' production packer at 9300' single "XN" qipple in the tailpipe, Stab WLEG into 4-1/2" liner top 4-1/2" Slotted liner below 7 inch liner shoe, TOL has 100' of lap into the 7 inch liner, TD at 11617'MD/8743'TVD Peds 9482~9806 7", 26 CC/ft, L80 ~ & 26CC/ft t3CR 1/12/2000 JES Proposed 3-34B Well 2/1/2000 LRC Corrected Perf depths 2/3/2000 LRC Production liner is all slotted PRUDHOE BAY UNIT WELL~ 03-34B APl NO:50-029-2ii-320-xx Shared Services Drilling REE: 03"34A P&A Or,gRKB=62' WELLHEAD: 13-3/8", 72 #/ft, L80, BTC 4-1/2" TRSV SSSV Nipple 3 each 4~1/2"x1-1/2 GLMs 6 each 3-1/2 x 1-1/2 GLMs -- 4~1/2" 12.6# 13CR Tubing Top of 7" Liner at ~ 9-5/8", 47 #/it, L80, ~ BTC 3-1/2" 9.2# 13CR Tubing (XO at 7729) Cut 3-1/2" Tubing at 8500' approx. (above PI(R) Landing Nipple@ 9119 3-1/2" TIW HBBP Production Packer @9187MD 3-1/2" 'X' Landing Nipple@ 9224 'XN' Landing Nipple@ 9242 3-1/2" tubing tail @ 9255 Coil to spot/squeeze 15.8 ppg crnt across perfs to place TOC at 9350' appro×, 132' above top perf Pen's 9482-9 7 , 26 #,ft. L80 & 26fi/ft 13CR PRUDHOE BAY UNIT WELL: 03-34 APl NO:50-029-211'320-01 Sha[ed SerViceS Drilling 7200 7600 8000 8400 '- 8800 -- Shared Services Drilling 03-34B Wp10 Proposal Data for 03-34B WP10 Vertical Origin:Well Horizontal Origin: Well Measurement Units: tt North Reference:Tree North Dogleg severity:Degrees per lOOft Vertical Section Azimuth: 256.650° Vertical Section Description.Well Vertical Section Odgin: 0.00 N,O.OO E Measured Incl. Azim. Vertical Northings Eastings VerticalDogleg Depth Depth Section Rate 7710.00 26.771200.558 7228.33 1990.50 S 589.8(} W 1033.47 7750.00 26.77121t.226 7264.06 2006.65 S 597.64 W 1044.82 7891.04 18.32624t.490 7394.62 2044.59 S 633.77 W 1088.74 8539.57 18.326241.490 8010.27 2141.92 S 812.96W 1285.56ILt)00 8590.15 22.t811) 251.627 8057.75 2148.711 S828.95 W 13112.68 10,1100 8743.57 22.18111 251.627 8200.00 2166.82 S 883.49 W 1359.930,11011 91152.0243.591251,627 8457.75 2219.17 S 1041.11 W 1525.387.0181 9327.35 54.604251,627 8637.75 2284.66 S 1238.29 W 1732.364.0t10 9463.51 68.220251.627 87112.75 2322.26 S 1351.49 W 1851.1810.0eX) 9493.51 68.220251.627 8713.88 2331.1)4 S1377.93 W 1878.93I}.0t)0 9580.09 89.000251,627 8730,89 2357.65 S 1458.04 W 1963.0224.01X) 9660.52 89.6811 261,255 8731.81 2376.48 S 1536.13 W 2043.3512.01)0 11617.0989.681) 261,255 8742.75 2673.95 S 3469.92 W 3993.570.001) : Start Dir @ 12.000°/100ft: 7710.00ft MD 7228.33ft TVD Rate Decrease @ 10.000°/100ft: 7750.00ft'MD, 7264.06ft TVD Dir' 7891.04ft MD, 7394.62ft TVD ........... ~'1'6 RECEIVEI I DrillQuest" Single Well Target Data for 03-34B WPS Measurement Units:ft Coordinate Target Point TVDrkb TVDss Northings Eastings ASP Y ASP X Name Type 03-34B Wpl0 FLTOIEntry Point 1463.23 S 1082.59 W 5934668.00 N 713102.(X) E Boundary Point A 1463.23 S 1082.59 W 5934668.(X) N 713102.00 E B 2054.77 S 966.34 W 5934080.(X) N 713235.(X) E C 2623.52S 736.39W 5933518.(X)N 713481.(X)E D 2054.77 S 966.34 W 5934080.(X) N 713235.(X) E 03-34B Wpl0 FLT02 Entry Point 2032.19 S 4192.(X) W 5934011.(X)N 7I(X)I0.(X) E Boundary Point A 2032.19S 4192.(X)W 5934011.00N 71(X)IO.(X)E B 2470.41 S 3662.22 W 5933588.(X) N 710552.(X) E C 2032.19S 4192.(X)W 5934011.(X)N 71(X)I0.(X)E 03-34B Wpl0 FLT03Entry Point Boundary Point A B C D E G H 1 J K .o*° FEB 0,3 000 · ' Pi() Line-Up Entry Point 03-34B WP,O Line-Up ¢,1~,~,Iq ' ~ ~ & ~ ~ns. ~ 8057. 75 TVD ~ ~ --~ ,~ ~m~ 03-34B Wp 10 Po ygon nn~ ~ont ~~f~5 ~~~~~~5~~ ~ ~ ~Q ~ ~ ~ ~ ~ 03-34B ~10 TD EnVy Poi~ 8057.75 8(XX).O0 8702.75 8645.(X) 3362.64 S 5146.15 W 5932654.(X) N 709094.(X) E 3362.64 S 5146.15 W 5932654.(X) N 709094.00 E 3320.65 S 4405.66 W 5932717.(X) N 709833.{X) E 3156.79S 3517.65W 5932906.(X) N 710716.(X) E 3078.41S 3142.27W 5932995.(X) N 711089.(X) E 3082.36 S 2334.06 W 5933014.(X) N 711897.(X) E 3073.49 S 1765.58 W 5933039.(X) N 712465.(X) E 2875.24S 1172.71W 5933254.(X) N 713052.(X) E 2559.56S 311.40W5933594.(X) N 713904.(X) E 2875.24S 1172.71W 5933254.(X) N 713052.(X) E 3073.49 S 1765.58 W 5933039.00 N 712465.00 E 3082.36S 2334.06W 5933014.(X) N 711897.00E 3078.41S 3142.27W 5932995.(X) N 711089.(X) E 3156.79S 3517.65W 5932906.(X) N 710716.(X) E 3320.65 S 4405.66W 5932717.00N 709833.(X) E 2148.70 S 828.95 W 5933990.(X) N 713375.(X) E 2143.91S 3322.82W 5933924.lX)N 710882.00E 2143.91S 3322.82W 5933924.(X)N 710882.{X)E 2670.76 S 3511.85 W 5933392.(X) N 710708.(X) E 2778.13S 3464.88W 5933286.(X)N 710758.(XlE 2766.59S 2110.(X)W 5933336.00N 712112.(X)E 2487.76 S 1289.76 W 5933638.00 N 712924.00 E 1986.92S 1382.58W 5934136.(X)N 712817.00E 8742.75 8685.(X) 2673.95 S 3469.92 W 5933390.(X) N 710750.(X) E Current Well Properties We;l: 03-34B WI: Horizontal goo~c~r~tes: i~oe[: SGir ucl°ball~ro RC°(xe%rnaet~c~: ~.%¥ ~ ReL ~r~h~ ~di~les: 70~ 13' 42. R~ E~a~: 57 75~ ~ 57.75lt a~ Gr~ N~ ~v~: 1.~7~ 03-348 WPS 5936161.37 N, 714142..62 E 3056,47 S, 1851.14 E 7O° 13' 42.6317' N, 148° ~6' 17.4~ 15'W 57 75fi above Mean Sea Level 57.751t above Structure Relerence 1.627° K2/Top HRZ- 8457.75 TV/) 7" Liner 9473.51 MD 8706.46 TVD 03-34B WPIO TD 8742.75 TVD 2673.95 S, 3469.92 W 5 ........ BHRZ/LC'U-&587.75TVD ': :~/~b'~': ....... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........ ::::j,~ ::::: ::::::. $,gR.8702.75TVD · . · -_ .......... Shublik - 8737. 75 7q, q) 03-34B WPIO 7 4 1/2" Liner 11617.09 MD 8742.75 TVD I I I 1200 1600 2000 I I I I I 2400 2800 3200 3600 4000 Scale: linch = 400ft Vertical Section Section Azimuth: 256.650° (True North) Shared Services Drilling 03-34B Wp10 I DrillQuestTM Proposal Data for 03-34B WP10 Vertical Origin: Well Horizontal Origin: Well MeasurementUnits: ft North Reference: True North Dogleg sevedty: Degrees per 100ft Vertical Section Azimuth : 256.650° Vertical Section Description:Well Vertical Section Odgin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 7710.(X126.771 2(X).558 7228.33 1990.50 S 589.80 W 1033.47 7750.(X)26.771 211.226 7264.06 2(X)6.65 S 597.64 W 1044.82 12.(XX) 7891.04 18.326 241.490 7394.62 2044.59 S 633.77 W 1088.74 10.(XX) 8539.57 18.326 241.490 8010.27 2141.92 S 812.96 W 1285.56 8590.15 22.0{X)251.627 8057.75 2148.70 S 828.95 W 1302.68 10.(XX) 8743.57 22.(XX)251.627 82(X).(X) 2166.82 S 883.49 W 1359.93 O.(XX) 9052.02 43.591 251.627 8457.75 2219.17 S 1041.11 W 1525.38 7.(XX) 9327.35 54.604 251.627 8637.75 2284.66 S 1238.29 W 1732.36 4.(XX) 9463.51 68.220 251.627 87{)2.75 2322.26 S 1351.49 W 1851.18 10.(XX) 9493.51 68.220 251.627 8713.88 2331.04 S 1377.93 W 1878.93 0.(XX) 9580.09 89.(XX)251.627 8730.89 2357.65 S 1458.04 W 1963.02 24,(XX) 9660.52 89.680 261.255 8731.81 2376.48 S 1536.13 W 2043.35 12.(XX) 11617.09 89.680 261.255 8742.75 2673.95 S 3469.92 W 3993.57 0.(XX) Current Well Properties Well: 03-34B WPS Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: Grid North Convergence: North Reference: Units: 5936161.37 N, 714142.62 E 3056.47 S, 1851.14 E 70° 13' 42.6317" N, 148° 16' 17.4115" W 57.75ft above Mean Sea Level 57.75ft above Structure Reference 1.627° Grid North Feet Scale: linch = 400ft -4000 I -2000 t -3600 -3200 -2800 I I I -2800 -- 4 1/2" Liner 11617.09 MD 8742.75 TVD Eastings Oir · . -2400 -2000 I 0/7 %re De Oir Rate ~_ Start Oir @ Ob Rate - "'eCrease @ _ Increase @ ~.000o/ -1' 200 -800 I 03-34B WPIO TD 8742.75 TVD 2673.95 S, 3469.92 W 7" Liner 9473.51 MD 8706.46 TVD I I I I I I I I -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -2000 ~2400 -2800 Scale: 1 inch = 400ft Eastings Reference is True North North Slope Alaska Alaska State Plane 4 PBU_EOA DS 03, Slot 03-34 WPS 03-34B WPS- 03-34B WPIO PROPOSAL REPORT 15 December, 1999 Surface Coordinates: 5936161.37N, 714142.62 E (70° 13' 42.6317"N, 148° 16' 17.4115" W) Kelly Bushing: 57. 75ft above Mean Sea Level RECEIVED FEB 03 2000 DRILLING SERVtI~EE Proposal Ref: pro9523 RECEIVED FEB 03 2000 Sperry-Sun Drilling Services Proposal Report for 03-34B WPS - 03-34B WPIO North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 7710,00 26.771 200.558 7170.58 7750.00 26.771 211.226 7206.31 7800.00 23.185 219.503 7251.64 7891.04 18.326 241,490 7336,87 7894.33 18.326 241,490 7340.00 7900.00 18.326 241.490 7345.38 8000.00 18,326 241.490 7440.31 8100.00 18.326 241.490 7535.24 8200.00 18.326 241.490 7630.16 8300.00 18.326 241.490 7725.09 8400.00 18.326 241,490 7820.02 8500.00 18.326 241.490 7914.95 8539.57 18.326 241.490 7952.52 8579.40 21.173 249.757 7990.00 8590.15 22.000 251.627 8000.00 8600.00 22.000 251.627 8009.13 8700.00 22,000 251,627 8101.85 8743,57 22.000 251.627 8142,25 8800.00 25.950 251.627 8193.80 8900.00 32.950 251.627 8280.82 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 7228.33 1990.50 S 589.80W 5934154.93 N 713609.56 E Dogleg Rate (°/100ft) 7264.06 2006,65 S 597.64W 5934138.56 N 713602.18 E 12.000 7309.39 2023.89 S 609.74W 5934120.99 N 713590.57 E 10.000 7394.62 2044.59 S 633.77W 5934099.62 N 713567.14 E 10.000 7397,75 2045.08 S 634.68W 5934099,10 N 713566.25 E 0.000 7403.13 2045.93 S 636.25W 5934098.20 N 713564,71 E 0.000 7498.06 2060.94 S 663.88VV 5934082,41N 713537.51E 0.000 7592.99 2075.95 S 691.51W 5934066.63 N 713510.32 E 0.000 7687.91 2090.96 S 719.14W 5934050.84 N 713483,13 E 0.000 7782.84 2105.96 S 746.77W 5934035,06 N 713455.94 E 0.000 7877.77 2120.97 S 774.40W 5934019.27 N 713428.74 E 0.000 7972.70 2135.98 S 802.03W 5934003.48 N 713401.55 E 0.000 8010.27 2141.92 S 812,96W 5933997.24 N 713390.79 E 0.000 8047.75 2147.40 S 825.21W 5933991.41N 713378.70 E 10.000 8057.75 2148.70 S 828.95W 5933990.00 N 713375.00 E 10,000 8066.88 2149.87 S 832.45W 5933988.74 N 713371.53 E 0.000 8159.60 2161.68 S 868.00W 5933975.93 N 713336.33 E 0.000 8200.00 2166.82 S 883.49W 5933970.34 N 713320,99 E 0.000 8251.55 2174.05 S 905.25W 5933962,50 N 713299.45 E 7.000 8338.57 2189.53 S 951.88W 5933945.70 N 713253.28 E 7.000 Alaska State Plane 4 PBU_EOA DS 03 Vertical Section (ft) 1033.47 1044.82 1060.58 1088.74 1089,74 1091.46 1121,81 1152.16 1182.50 1212.85 1243.20 1273.55 1285.56 1298.75 1302.68 1306,36 1343.67 1359.93 1382.77 1431.72 Comment KOP: Start Dir @ 12.000°/100ft: 7710.00ft MD, 7228.33ft TVD Dir Rate Decrease @ 10.000°/100ft: 7750.00ft MD, 7264.06ft TVD End Dir' 7891.04ft MD, 7394.62ft TVD K10 Start Dir @ 10.000°/100ft: 8539.57ft MD, 8010.27ft TVD K5 End Dir: 8590.15ft MD, 8057.75ft TVD .arget, - 0...3-3,4B .W,P10 me-up, t~eo~og~ca~ Start Dir @ 7.000°/100ft · 8743.57ft MD, 8200.00ft TVD Continued... 15 December, 1999 - 15:44 - 2 - DrillQuest 1.05.04c RECEIVED FEB 0 ; 000 asia Oil & Gas Cons, mmission North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 9000.00 39.950 251.627 8361.21 9052.02 43.591 251.627 8400.00 9100.00 45.510 251.627 8434.19 9200.00 49.510 251.627 8501.72 9300.00 53.510 251,627 8563.95 9327.35 54.604 251,627 8580.00 9400.00 61.870 251.627 8618.22 9426.11 64.480 251.627 8630,00 9463.51 68.220 251.627 8645.00 9473.51 68.220 251.627 8648.71 9493.51 68.220 251.627 8656.13 9500.00 69.779 251.627 8658.46 9580.09 89.000 251.627 8673.14 9600.00 89.166 254.010 8673.45 9660.52 89.680 261.255 8674.06 9700.00 89.680 261.255 8674.29 9800.00 89.680 261.255 8674.84 9900.00 89.680 261.255 8675.40 10000.00 89.680 261.255 8675.96 10100.00 89.680 261.255 8676.52 Sperry-Sun Drilling Services Proposal Report for 03-34B WPS - 03-34B WPIO Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8418.96 2208.25 S 1008.23 W 5933925,39 N 713197.49 E 8457.75 2219,17 S 1041.11 W 5933913.54 N 713164.93 E 8491.94 2229.78 S 1073.05W 5933902.03 N 713133.30 E 8559.47 2253.02 S 1143.02W 5933876.81 N 713064.02 E 8621.70 2277.69 S 1217.28W 5933850.05 N 712990.48 E 8637.75 2284.66 S 1238.29W 5933842.48 N 712969.68 E 8675.97 2304.12 S 1296.88W 5933821.36 N 712911.67 E 8687.75 2311.47 S 1318.99W 5933813.39 N 712889.78 E 8702.75 2322.26 S 1351.49W 5933801.68 N 712857.59 E 8706.46 2325.19 S 1360,31W 5933798.50 N 712848.86 E 8713.88 2331.04 S 1377.93W 5933792.15 N 712831.41 E 8716.21 2332.95 S 1383.68W 5933790.08 N 712825.72 E 8730.89 2357.65 S 1458.04W 5933763.28 N 712752,09 E 8731.20 2363.53 S 1477.06W 5933756.86 N 712733.25 E 8731.81 2376.48 S 1536.13W 5933742.24 N 712674.57 E 8732.04 2382.49 S 1575.15W 5933735.13 N 712635.73 E 8732.59 2397.69 S 1673.99W 5933717.13 N 712537.37 E 8733.15 2412.89 S 1772.82W 5933699.12 N 712439.00 E 8733.71 2428.10 S 1871.66W 5933681.12 N 712340.64 E 8734.27 2443.30 S 1970.50W 5933663.12 N 712242.27 E Dogleg Rate (°/100ft) 7.000 7.000 4.000 4.000 4.000 4.000 10.000 10.000 10.000 0.000 0.000 24.000 24.000 12.000 12.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS O3 Vertical Section (ft) 1490.86 1525.38 1558.91 1632.35 1710.30 1732.36 1793.85 1817.06 1851.18 1860.43 1878.93 1884.97 1963.02 1982.88 2043.35 Comment Dir Rate Decrease @ 4,000°/100ft: 9052.02ft MD, 8457.75ft TVD K2/Top HRZ Dir Rate Increase @ 10.000°/100ft · 9327.35ft MD, 8637.75ft TVD BHRZ/LCU End Dir: 9463.51ft MD, 8702.75ft TVD SagR 7" Liner Start Dir @ 24.000°/100ft: 9493.51ft MD, 8713.88ft TVD Dir Rate Decrease @ 12.000°/100ft · 9580.09ft MD, 8730.89ft TVD End Dir' 9660.52ft MD, 8731.81ft TVD 2082.70 2182.38 2282.05 2381.73 2481.40 Continued... 15 December, 1999 - 15:44 - 3 - DrillQuest 1.05.04c RECEIVED FEB 03 000 Alaska O{i & 6as Cons, Cumm on North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 03-34B WPS - 03-34B WPIO Measured Sub-Sea Ve~ical Local Coordinates Depth Incl. Azim. Depth Depth Nothings Eastings Nothings (fi) (ft) (fi) (ft) (fi) (ft) 10200.00 89.680 261.255 8677.08 8734.83 2458.50S 2069.33W 5933645.12N 10300.00 89.680 261.255 8677.64 8735.39 2473.71S 2168.17W 5933627.11N 10400.00 89.680 261.255 8678.20 8735.95 2488.91S 2267.00W 5933609.11N 10500.00 89.680 261.255 8678.76 8736.51 2504.11S 2365.84W 5933591.11N 10600.00 89.680 261.255 8679.32 8737.07 2519.32 S 2464.68W 5933573.10 N 10700.00 89.680 261.255 8679.87 8737.62 2534.52 S 2563,51W 5933555.10 N 10722.46 89.680 261.255 8680.00 8737.75 2537.94 S 2585.71W 5933551.06 N 10800.00 89.680 261.255 8680.43 8738,18 2549.72 S 2662.35W 5933537.10 N 10900.00 89.680 261.255 8680.99 8738.74 2564,93 S 2761.18W 5933519.10 N 11000.00 89.680 261.255 8681.55 8739.30 2580.13 S 2860.02W 5933501.09 N 11100.00 89,680 261.255 8682.11 8739.86 2595.33 S 2958.86W 5933483.09 N 11200.00 89.680 261.255 8682.67 8740.42 2610.54 S 3057,69W 5933465.09 N 11300.00 89.680 261.255 8683.23 8740.98 2625.74 S 3156.53W 5933447.08 N 11400.00 89.680 261.255 8683.79 8741.54 2640.94 S 3255.36W 5933429.08 N 11500.00 89.680 261.255 8684.35 8742.10 2656.15 S 3354.20W 5933411.08 N 11600,00 89.680 261.255 8684.90 8742.65 2671,35 S 3453.04W 5933393.08 N 11617.09 89.680 261.255 8685.00 8742.75 2673.95 S 3469.92W 5933390.00 N Global Coordinates Eastings (ft) 712143.91E 712O45.55 E 711947.18 E 711848.82 E 711750.45 E 711652.09 E 711629.99 E 711553.72 E 711455.36 E 711356.99 E 711258.63 E 711160.26 E 711061.90 E 710963.54 E 710865.17 E 710766.81E 710750.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°/100.) 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS 03 Ve~ical Section (fi) 2581.08 2680.76 2780.43 2880.11 2979.78 3079.46 3101.85 3179.13 3278.81 3378.49 3478.16 3577.84 3677.51 3777.19 3876.86 3976.54 3993.57 Comment Shublik Total Depth: 11617.09ft MD, 8742.75ft TVD 4 1/2" Liner Tarqet - 03-34B WP10 TD, Geological The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 256.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11617.09ft., The Bottom Hole Displacement is 4380.68ft., in the Direction of 232.382° (True). Continued... 15 December, 1999 - 15:44 - 4 - DrillQuest 1.05.04c RECEIVE: .D FEB 000 North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 03-34B WPS - 03-34B WPIO Alaska State Plane 4 PBU_EOA DS O3 Comments Measured Depth (ft) 7710.00 7750.00 7891.04 8539.57 8590.15 8743.57 9052.02 9327.35 9463.51 9493.51 9580.09 9660.52 11617.09 Station TVD (~) 7228.33 7264.06 7394.62 8010.27 8057.75 Coordinates Northings Eastings (fi) (ft) 1990.50 S 2006.65 S 2044.59 S 2141.92 S 2148.70 S 589.80W 597.64W 633.77W 812.96W 828.95W 8200.00 8457.75 8637.75 8702.75 8713.88 2166.82 2219.17 2284.67 2322.26 2331.04 883.49W 1041.11W 1238.30W 1351.50W 1377.93W 8730.89 8731.81 8742.75 2357.65 2376.48 2673.95 1458.04W 1536.13W 3469.92W Comment KOP: Start Dir @ 12.000°/100ft: 7710.00ft MD, 7228.33ft TVD Dir Rate Decrease @ 10.000°/100ft: 7750.00ft MD, 7264.06ft TVD End Dir: 7891.04ft MD, 7394.62ft TVD Start Dir @ 10.000°/100ft: 8539.57ft MD, 8010.27ft TVD End Dir: 8590.15ft MD, 8057.75ft TVD Start Dir @ 7.000°/100ft: 8743.57ft MD, 8200.00ft TVD Dir Rate Decrease @ 4.000°/100ft: 9052.02ft MD, 8457.75ft TVD Dir Rate Increase @ 10.000°/100ft: 9327.35ft MD, 8637.75ft TVD End Dir: 9463.51ft MD, 8702.75ft TVD Start Dir @ 24.000°/100ft: 9493.51ft MD, 8713.88ft TVD Dir Rate Decrease @ 12.000°/100ft· 9580.09ft MD, 8730.89ft TVD End Dir' 9660.52ft MD, 8731.81ft TVD Total Depth · 11617.09ft MD, 8742.75ft TVD Continued... 15Decembe~ 1999 - 15:44 - 5 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 03-349 WPS - 03-349 WPIO North Slope Alaska Alaska State Plane 4 PBU_EOA DS O3 Formation Tops Measured Depth (ft) 7894.33 8579.40 9052.02 9426.11 9463.51 10722.46 Vertical Sub-Sea Depth Depth Northings Eastings Formation Name (fi) (fi) (ft) (it) 7397.75 7340.00 2045.088 634.68W KIO 8047.75 7990.00 2147.408 825.21W K5 8457.75 8400.00 2219.178 1041.11W K2/TopHRZ 8687.75 8630.00 2311.47 S 1318.99 W BHRZ/LCU 8702.75 8645.00 2322.26 S 1351.50W SagR 8737.75 8680.00 2537.94 S 2585.71W Shublik Casing details From Measured Vertical Depth Depth (~) (it) 7710,00 7228.33 7710.00 7228.33 To Measured Vertical Depth Depth (ft) (it) 9473.51 8706.46 11617.09 8742.75 Casing Detail 7" Liner 4 1/2" Liner RECEIVED FEB 200O Alaska Oil & ~as ~ns, Commion Continued... 15 December, 1999 - 15:44 - 6 - DrillQuest 1.05.04c H 1 59955 VEN~R ALASKAOILA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT N~-T 1 2OC~C~9 C½ 1 209C~9H 1 OO. GO 1 OO. GO HANDL]N~ INST' S/H TERRI HUBBLE RE3EIVED FEI~ 0,3 2000 Alaska 0it & (;as Cons, Co~ THE ATTACHED CHECK IS mN PAYMENT FOR rrEM~ DESCRIBED ABOVE. (ALASKA).,:::.ING, ...... ' .... : 99519-6612 :::" ' :FIBST I~ATIo~IAlu.:BANK':OF ASHtCAND AN:AEmI41ATE: GE .... '"" ,:. NA1]ONAL.:CITY, BANK ':' 'i. :'. :: CLEVEI~AND, OHIO ' "56-389 412 No., H :.:'.::.::1 5 9.9 5"5: CONSOLID;~EO ., 00159~55: PAY ANCHORAGE US:.:.:DOLLAR :.::!:.AMOUNT $100.00 AK 9950:1 NO?~!VALID AFTER 120 DAYS FIELD & POOL & ?/'(~_~' i ~"~ INIT CLASS .../,~ ~/~'~-'/'~ GEOL AREA ADMINISTRATION R DATE 1. Permit fee attached ........................ 2. Lease number appropriate.>a~. ~ ~,/'~.,'-./ze'.~ .~.-~././,>..-.9..~'~/ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells: .~.. ...... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING ,~,~ DATE ~f~ -~ t 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 'z~,~'~)"~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... ,',/.~'? 32. Seismic analysis of shallow gas zones ............ ,-f//-~ ~ redrll J serv__ wellbore seg ann. disposal para req__ UNIT# ON/OFFSHORE Y Y Y Y N Y N Y N APPR DATE 33. Seabed condition survey (if off-shore) ............. .'¢''~) Y N ~ ~"~ ~: -O'~,~ 34. Contact name/phone for weekly progress reports [e~ploratory oMy]~] N ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/~nnular RPC BEW ~. WM ~'~ JDH z ~ ~ c:\msoffice\wordian\diana\checklist (rev. 09~27~99) COMMISSION: DWJ RNC-- . co CommentS/Instructions: Well Histo.ry 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Apr 26 15:50:43 2002 Reel Header Service name ............. LISTPE Date ..................... 02/04/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 3-34B 500292113202 Arco Alaska, Inc. Sperry Sun 26-APR-02 MWD RUN 2 MWD RUN 3 AK-MM-90259 AK-MM-90259 E. CRIBBS J. FOLEY G. KIDD G. KIDD MWD RUN 4 AK-MM-90259 J. FOLEY G. KIDD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 MWD RUN 6 AK-MM-90259 AK-MM-90259 J. FOLEY J. FOLEY G. KIDD P. SMITH iST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. MWD RUN 7 AK-MM-90259 M. HANIK P. SMITH 11 i0N 15E 97 846 .00 53.55 27.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.000 9.625 7531.0 6.125 7.000 9588.0 ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD'.. 3. 3-34B KICKS OFF FROM 3-34A AT WHIPSTOCK WiTH TOP SET AT 7509.5' MD, 7050.5' TVD. 4. MWD RUN i IS DIRECTIONAL ONLY. 5. MWD RUNS 2-7 ARE DIRECTIONAL W~TH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MULLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. DIGITAL AND LOG DATA BLOCK-SHIFTED DOWN 8.5 FEET PER THE E-MAIL OF 3/29/2002 FROM D. SCHNORR'OF BP EXPLORATION (ALASKA) INC. 7. MWD RUNS 2-7 REPRESENT THE MWD DATA FOR WELL 3-34B WITH API# 50-029-21132-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11271.5' MD, 8752.7' TVDSS. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) .SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 7511.5 11271.5 FET 7541.5 11228.0 RPD 7541.5 11228.0 RPM 7541.5 11228.0 RPS 7541.5 11228.0 RPX 7541.5 11228.0 GR 7550.0 11221.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 7550.0 7541.5 9292.0 9283.5 10986.0 10977.5 11221.0 11212.5 $ EQUIVALENT UNSH!FTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 2 3 4 5 6 7 MERGED MAIN PASS. $ MERGE TOP 7533 0 8314 5 8513 0 8813 5 9624 0 9762 5 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order MERGE BASE 8314 0 8513 0 8813 0 9623 5 9762 0 11263 0 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 7511.5 11271.5 ROP MWD FPH 0 354.17 GR MWD API 39.8 443.44 RPX MWD OHMM 0.63 497.16 RPS MWD OHMM 0.64 498.23 RPM MWD OHMM 0.61 2000 RPD MWD OHMM 0.36 2000 FET MWD HR 0.1998 84.0051 Mean Nsam 9391.5 7521 36.4165 7448 144.47 7343 8.64832 7340 10.485 7340 19.538 7340 15.7116 7340 3.59641 7340 First Reading For Entire File .......... 7511.5 Last Reading For Entire File ........... 11271.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 7511.5 7511.5 7550 7541.5 7541.5 7541.5 7541.5 7541.5 Last Reading 11271.5 11271.5 11221 11228 11228 11228 11228 11228 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and Icg header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7533.0 8281 5 RPX 7533.0 8281 5 RPS 7533.0 8281 5 RPD 7533.0 8281 5 RPM 7533.0 8281 5 GR 7541.5 8289 5 RO? 7567.5 8314 0 $ LOG HEADER DATA DATE LOGGED: 08-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8315.0 TOP LOG INTERVAL (FT): 7531.0 BOTTOM LOG INTERVAL (FT): 8315.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.1 MAXIMUM ANGLE: 19.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 8.000 KCL/Polymer 10.30 39.0 9.0 30000 3.9 .318 60.0 .000 156.0 .220 60.0 .400 60.0 Depth Units ....................... Datum, Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 ROP MWD020 FPH 4 i 68 GR MWD02C AP1 4 i 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 I 68 FET MWD020 HR 4 1 68 0 i 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7533 8314 ROP MWD020 FPH 0 100.51 GR MWD020 API 39.8 220.68 RPX MWD020 OHMM 0.63 5.14 RPS MWD020 OHMM 0.64 4.68 RPM MWD020 OHMM 0.61 6.2 RPD MWD020 OHMM 0.64 5.34 FET MWD020 HR 0.1998 17.8607 First Reading For Entire File .......... 7533 Last Reading For Entire File ........... 8314 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean 7923.5 32.7229 121.679 1.98923 2.07915 2.12734 2.15264 1.37007 Nsam 1563 1494 1497 1464 1464 1464 1464 1464 First Reading 7533 7567.5 7541.5 7533 7533 7533 7533 7533 Last Reading 8314 8314 8289.5 8281.5 8281.5 8281.5 8281.5 8281.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW F~WD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8278.0 8476.0 RPD 8278.0 8476 0 RPM 8278.0 8476 0 RPS 8278.0 8476 0 RPX 8278.0 8476 0 GR 8286.5 8486 0 ROP 8314.5 8513 0 $ # LOG HEADER DATA DATE LOGGED: 09-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TiME): TD DRILLER (FT): TOP LOG iNTERVAL (FT : BOTTOM LOG iNTERVAL FT): BIT ROTATING SPEED iRPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM] VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM/~LA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 66.16 Memory 8513.0 8315.0 8513.0 15.1 16.0 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 8.000 KCL/Polymer 10.50 39.0 9.3 29000 3.9 .318 60.0 .000 60.0 .220 60.0 .400 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD030 FPH 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8278 8513 ROP MWD030 FPH 0 95.54 GR MWD030 API 56.92 146.32 RPX MWD030 OHMM 0.86 10.93 RPS MWD030 OHM~ 0.85 10.61 RPM MWD030 OHMM 0.85 8.15 Mean 8395.5 44.4047 109.948 1.79426 1.80904 1.78174 Nsam 471 398 4OO 397 397 397 First Reading 8278 8314.5 8286.5 8278 8278 8278 Last Reading 8513 8513 8486 8476 8476 8476 RPD MWD030 OH~ 0.91 7.62 FET MWDO30 HE 0.4795 13.7803 First Readinc For Entire File .......... 8278 - Last Reading For Entire File ........... 8513 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLiB.004 i.78836 4.31645 397 397 8278 8278 8476 8476 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8478.5 8776.0 RPS 8478.5 8776.0 FET 8478.5 8776.0 RPD 8478.5 8776.0 RPM 8478.5 8776.0 GR 8487.0 8784.5 ROP 8513.5 8813.0 $ LOG HEADER DATA DATE LOGGED: Il-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8813.0 TOP LOG INTERVAL (FT): 8513.0 BOTTOM LOG INTERVAL (FT): 8813.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.3 MAXIMUM ANGLE: 36.4 TOOL STRING {TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02100HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.000 BOREHOLE CONDITIONS MUD TYPE: KCL/Polymer MUD DENSITY (LB/G): 11.20 MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE !DEGF) MUD AT MEASURED TEMPERATURE MUD AT MA3[ CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 38.0 9.0 28000 3.8 .2!0 .102 .100 .680 REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 I 68 8 3 RPX MWD040 OHMM 4 i 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 i 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 i 68 28 8 69.0 149.0 69.0 69.0 Name Service Unit Min Max Mean Nsam DEPT FT 8478.5 8813 8645.75 670 ROP MWD040 FPH 0.22 68.36 23.9528 600 GR MWD040 API 92.24 295.85 190.35 596 RPX MWD040 OHMM 0.85 6.48 1.8918 596 RPS MWD040 OHMM 0.87 6.33 1.91815 596 RPM MWD040 OHMM 0.83 5.88 1.89755 596 RPD MWD040 OHMM 0.85 5.3 1.88374 596 FET MWD040 HR 1.3424 21.7271 5.52279 596 First Reading 8478.5 8513.5 8487 8478.5 8478.5 8478.5 8478.5 8478.5 Last Reading 8813 8813 8784.5 8776 8776 8776 8776 8776 First Reading For Entire File .......... 8478.5 Last Reading For Entire File ........... 8813 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 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 ....... 02/04/26 Maximuur, Physical Record..65535 File Type ................ LO Previous File Name ....... STSLiB.004 Commen~ Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8776 5 9557.0 RPD 8776 5 9615.0 RPM 8776 5 9615.0 RPS 8776 5 9615.0 RPX 8776 5 9615.0 GR 8785 0 9623.5 ROP 8813.5 9589.0 $ LOG HEADER DATA DATE LOGGED: 14-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: In$ite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9590.0 TOP LOG INTERVAL (FT): 8813.0 BOTTOM LOG INTERVAL (FT): 9590.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.3 MAXIMUM ANGLE: 61.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02100HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.000 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: KCL/Polymer MUD DENSITY (LB/G): 11.20 MUD VISCOSITY (S): 41.0 MUD PH: 100.0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE {MT): .210 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .102 163.4 MUD FILTRATE AT MT: .100 69.0 MUD C~2KE AT MT: .680 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Fee~ DaTa Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD050 FPH 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 I 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8776.5 9623.5 ROP MWD050 FPH 8.43 88.67 GR MWD050 API 100.44 443.44 RPX MWD050 OHMM 1.17 15.08 RPS MWD050 OHMM 1.8 16.35 RPM MWD050 OHMM 1.66 17.36 RPD MWD050 OHMM 1.72 15.52 FET MWD050 HR 0.6853 22.9405 Mean 9200 41.545 211.208 4.54764 4.98843 5.54636 5.60993 2.37569 First Reading For Entire File .......... 8776.5 Last Reading For Entire File ........... 9623.5 Nsam 1695 1552 1568 1565 1565 1565 1565 1562 First Reading 8776.5 8813.5 8785 8776.5 8776.5 8776.5 8776.5 8776.5 Last Reading 9623.5 9589 9623.5 9615 9615 9615 9615 9557 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 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 ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD ~urves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9541.0 RPX 9548.0 RPS 9548.0 RPM 9548.0 R?D 9548.0 FET 9548.0 STOP DEPTH 9712 5 9719 5 9719 : 9719 5 9719 5 9719 5 ROP 9529.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE iMEMORY OB REAL-TiME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG iNTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9762.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 17-MAR-00 Insite 66.16 Memory 9762.0 9590.0 9762.0 78.7 88.1 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 8.000 QUIKDRIL-N 8.40 40.0 9.4 1200 12.4 .040 63.0 .015 176.0 .200 63.0 .180 63.0 Name Service Order DEPT FT 4 1 68 ROP MWD060 FPH 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 First Last Name Service Unit Min Max DEPT FT 9541 9762 ROP MWD06O F?H 0.21 101.25 GR MWD060 APl 56.75 252.59 RPX MWD06C OHMS. 2.23 497.16 RPS MWD060 OHMS. 2.87 498.23 RPM MWD060 OHStM C. ~ 2000 RPD MWD060 OHMLM 0.35 2000 FET MWD060 HR 2.5767 84.0051 First Reading For Entire File .......... 9541 Last Reading Fol Entire File ........... 9762 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Mean 9651.5 23.6419 '32.885 12.892 i4.2711 241.474 119.763 24.6411 Nsam 443 346 344 344 344 344 344 344 Reading 954i 9589.5 9541 9548 9548 9548 9548 9548 Reading 9762 9762 9712 5 9719 5 9719 5 9719 5 9719 5 9719 5 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9715.0 11212.5 RPD 9721.5 11219.5 RPM 9721.5 11219.5 RPS 9721.5 11219.5 RPX 9721.5 11219.5 FET 9721.5 11219.5 ROP 9762.5 11263.0 $ # LOG HEADER DATA DATE LOGGED: 21-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11263.0 TOP LOG INTERVAL (FT): 9762.0 BOTTOM LOG INTERVAL (FT): 11263.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 91.6 TOOL STRING iTOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 DGR DUAL GAMMA RAY PB02100HWRG6 $ BOREHOLE AND CASING DAYA OPEN HOLE BIT SIZE .iN): DRILLER'S CASING DEPTH 8.000 BOREHOLE CONDITIONS MUD TYPE: QUiKDRiL-N MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 4i.0 MUD PH: 9.3 MUD CHLORIDES (PPM~: 28000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .040 MUD AT MAX CIRCULATING TERMPERATURE: .017 MUD FILTRATE AT MT: .180 MUD CAKE AT MT: .180 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD070 FPH 4 1 68 GR MWD070 API 4 1 68 RPX MWD070 OHMM 4 1 68 RPS MWD070 OHMM 4 1 68 RPM MWD070 OHMM 4 1 68 RPD MWD070 OHMM 4 1 68 FET MWD070 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 63.0 160.0 63.0 63.0 Name Service Unit Min Max DEPT FT 9715 11263 ROP MWD070 FPH 0 354.17 GR MWD070 API 65.02 436.87 RPX MWD070 OHM~ 3.09 78.46 RPS MWD070 OHMM 3.39 98.6 RPM MWD070 OHMM 3.5 79.39 RPD MWD070 OHM~ 3.64 72.42 FET MWD070 HR 0.9301 36.4247 First Reading For Entire File .......... 9715 Last Reading For Entire File ........... 11263 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/26 Maximum Physzcal Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Mean 10489 38.9775 116.767 15.7497 19.8318 21.0983 22.008 2.7414 Nsam 3097 3002 2996 2997 2997 2997 2997 2997 First Reading 9715 9762.5 9715 9721.5 9721.5 9721.5 9721.5 9721.5 Last Reading 11263 11263 11212.5 11219.5 11219.5 11219.5 11219.5 11219.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape N~me ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/04/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
