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Home My WebLink About201-242 STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMIARION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon [] Repair Well U Plug Perforations U Perforate U OtherL Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developments Exploratory ❑ 201 -242 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20108 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028286 ` PBU A -01A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10125 feet Plugs measured None feet true vertical 8831 feet Junk measured None feet Effective Depth measured 9220 feet Packer measured 7847 feet true vertical 8861.56 feet true vertical 7846.31 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 70 30" STOVE PIPE 19 - 89 19 - 89 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 14 - 7972 14 - 7971.26 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" TIW HBBP Packer 7847 7846.31 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): p Treatment descriptions including volumes used and final pressure: SCANNED APR 2 2 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 49 1195 1738 1718 215 Subsequent to operation: 45 1543 1080 1131 160 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Development PI Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 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 Nita Summerhays Email Nita.SummerhaVS(c76P.com Printed Name Nita Su _ m- i Title Petrotechnical Data Technician Si na�� i ® � Phone 564-4035 Date 3/19/2013 F ISDMS MAR 202013 t { "3 Form 10 -404 Revised 10/2012 ' AX:, Submit Original Only • • Daily Report of Well Operations ADL0028286 A YJTY ∎As.h SUMMAR `bT #6 �./5" c5oil Tubing - o• scope = Irift/log, set CIBP, *e Mobilize to A pad 9/11/2012 « <Job continued on 9/12/2012 »> CTU #9 1.75" Coil Tubing - Job Scope = Log / Set CIBP / Perf « <Job continurd from 9/11/2012 »> MIRU. Make up BOT MHA w/ SLB memory gamma ray /ccl logging tool w/ a 2.25" drift nozzle. RIH to 9300' ctm. Log up to 9200' ctm and flagged pipe. Logged up to 8500' ctm. POOH. Good data at surface. RIH w/ BOT 2 7/8" CIBP. Tied in at the flag to 9191.7' elm center of element, RIH and set the plug at 9220' elm. POOH 9/12/2012 « <Job in Progress »> CTU #9 1.75" Coil Tubing - Job Scope = Log / Set CIBP / Perf « <Job continued from 9/12/2012 »> Job aborted due to leaking SSV and swab. 9/1 3/2012 « <Job Suspended »> CTU 8 w/ 1.5" CT. Scope; ad -perf. 2/22/2013 Rig up. **job continued on WSR 02- 23 -13 ** Continued from WSR 02 -22 -13 CTU 8 w/ 1.5" CT. Scope; ad-perf. RIH w/ BHA; 1.5" ctc, 1.69" dfcv, disco, 2.12" crossover, 2.2" carrier with GR and CCR inside, 2" crossover, 2.25" nozzle. (oal= 14.26') Tag CIBP @ 9154' CTM.. log 40 fpm to 7700' pooh. Good data indicates top of CIBP at 9217' corr. depth. Job suspended for Phase 2 weather 2/23/2013 CTU 8 w/ 1.5" CT. Scope; adperf. Dig out equipment post phase 2 weather.. * *job continued on WSR 02- 2/24/2013 25 -13 ** Continued from WSR 02- 24 -13. CTU 8 w/ 1.5" CT. Scope; ad -perf. RIH w/ 1.5" ctc, 1.69" dfcv, disco, 2.12" crossover,2.13" firing head, 2" x 20' PJ Omega perf gun (oal= 27.08').perforated from 8986- 9006'md and 8960- 8980'md. Trim 150 ' pipe. MU BHA gun # 3, 1.5" ctc, 1.69" dfcv, disco, 2.12" crossover,2.13" firing head, 2" x 30' PJ Omega perf gun (oal= 38.56'). * *job continued on WSR 02- 26 -13 ** 2/25/2013 Continued from WSR 02- 25 -13, CTU 8 w/ 1.5" CT. Scope; ad -perf RIH w/ BHA gun # 3 ; 1.5" ctc, 1.69" dfcv, disco, 2.12" crossover,2.13" firing head, 2" x 30' PJ Omega perf gun (oal= 38.56'). Held Well Control Drill.. Tag CIBP, correct depth and shoot 8846'- 8876'md and 8$22' - 8840'md . pooh, RD. * *job complete ** 2/26/2013 FLUIDS PUMPED BBLS 184 60/40 METH 184 TOTAL Perforation Attachment ADL0028286 / S N Operatiolrgate� f Vperati —Per Code -" Meas Depth Top Meas Depth B ase TVD Dep Top TVD`�Depth B t —� A -01 A 2/26/201T APF 8822 8840 8815.06 8829.45 A -01A 2/26/2013 APF 8846 8876 8833.94 8853.77 A -01A 2/25/2013 APF 8960 8980 8881.11 8881 A -01A ^ 2/25/2013 . APF,,,_ 8986 „ , 9006 8881.57 8881 A -01A - 1/1672006 - OF 901'4 - -- '9034- 8880.82 a 8880.15 A -01A 9/12/2012 BPS 9470 9530 8836.02 8831.01 A -01A 9/12/2012 BPS 9530 9620 8831.01 8822.11 • A -01A 9/12/2012 BPS 9620 9650 8822.11 8819.11 A -01A 9/12/2012 BPS 9650 9680 8819.11 8816.34 A -01A 9/12/2012 BPS 9680 9710 8816.34 8813.7 A -01A 9/12/2012 BPS 9710 9712 8813.7 8813.53 A -01A 9/12/2012 BPS 9776 10124 8811.64 8831.86 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADLOO28286 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 30" STOVE PIPE 19 - 89 19 - 89 LINER 830 7" 29# N -80 7906 - 8736 7905.28 - 8734.34 8160 7020 LINER 834 3- 3/16" 6.2# L -80 7942 - 8776 7941.27 - 8773.62 LINER 1349 2 -7/8" Slotted Liner 8776 - 10125 8773.62 - 8831.87 PRODUCTION 2086 13 -3/8" 72# N -80 17 - 2103 17 - 2102.9 4930 2670 PRODUCTION 6318 9 -5/8" 47# L -80 2103 - 8421 2102.9 - 8419.91 6870 4760 • SURFACE 1456 18 -5/8" 96.5# K -55 18 - 1474 18 - 1473.9 930 870 SURFACE 841 20" 133# K -55 1474 - 2315 1473.9 - 2314.9 2320 1500 TUBING 7958 4 -1/2" 12.6# 13Cr80 14 - 7972 14 - 7971.26 8430 7500 • TREE= 4" GW • Y LIEAD = MoEVOY SAFETY NOTES: *"*WELL ANGLE> 70°0 8920' *** 4- - ACTUATOR= BAKER C A -0 1 A 1/2" CHROME TBG °*" 2 -718" SLID LNR IS ACTUALLY NMI KB. ELEV = 66.4' PRE -DRLD @ FOUR 1/2" HOLES/FT *** WARPING: BF.Et.EV= 47.4' RADIO TRANSMITTER INWEATI- RSHACKMUSTBE KOP= 766' i ■ :4 I TLI OFFBWO REUSINGEXPLOSIVES. 0 II3x Angie = 98° 9220'' ■ D atum ND= 8901' 130" COND — 89' ► i i Datum1VD= .___ 8800'SS ► i i 18-5/8" CSG, 96.5#, K -55 BTRS, D = 17.655" H 1474' I— i i —{ 1474' —118-5/8" XO TO 20", D = 17.655" 0 ■ 2021' 1-4-1/2" OTIS SSSV N, D = 3.813" _I 1 13 -5/8" CSG, 72.5#, N-80 BTRS, D --- = IH 2093' I ■ � , 2103' —113-3/8" X 9 -518" XO, D = 8.681" 2143' —I9 -518" FOC 20" CSG, 133#, K -55 BTRS, D = 18.750" H 2315' GAS LFT MANDRELS ST MD IVD DEV TYFE VLV LATCH PORT DATE 4 3186 3186 1 011S-LBD DOME RA ► 16 02/21/02 3 5856 5856 1 OTIS -LED SO RA ' 20 02/21/02 — Minimum ID = 2.30" 9428' 2 7586 7585 1 OTC -LBD DMY RA ' 0 12/05/01 1 7731 7730 1 011S -LBD DMY RA r 0 12/05/01 MILLED -OUT BAKER LNDNG COLLAR 7$35' H4 -1/2" SWS PARKER MP D = 3.813" ►M� ►M 7847' —I9 -5/8" X 4-1/2" 11W HBBP PKR, D = 4.000" 1 1. 7899" —14-1/T SWS PARKER NE', D = 3.813" I 7" TAN LNR TACK SLEEVE H 7906' I - 1 /2 ' 1 2 . 7 5 0 ' H 7951' I II 7942' - OD BKR DEPLOYMENT SLV, D = 3.000" 13-1/2" X 3-3/16" XO, ID= 2.786" H 7953' , a 7949' H4 -1/2" SWN NP, Iu _LED TO 3.80" D 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, D = 3.958" —1 7971' ' 7972' H4 -1 /2" WLEG, D = 4.000" I 7976' H ELM) TT LOGGED 08 /04/91 I 9-5/8" CSG, 47 #, L -80 SEA -LOCK, ID = 8.681" I 8421' ∎ 14 7" MR MLLOLJT WINDOW (A -01A) 8730' - 8736' ITOPOF W-IPSTOCK H 8725' 4, 4, RA RP TAG --I 8735' 8776' 3-3/16" X 2 -7/8" LNR XO, D = 2.377" 17" LNR 29#, N-80 SEAL -LOCK, D = 6.184" H —$73s t t e ," 9220' amp H2 -7/8" CUP (09/12/12) I 'WOW" PERFORATION SLNTAARY ��1�•�•�• • • 9428' H2-7/ BKS' R LC, NILE =a TO 2.30" D REF LOG: SFERRY M D/GR/RES/ROP ON 02/11/02 11 • (• • • 1, 0'1e ` ANGLE AT TOP FERE: 33" @ 8822' • ∎�•� ∎� ∎1. ■ \ Note: Refer to Production DB for historical perf data ,•ej•. 4 444 ■ " \ •••.. 6•4 ■ SPF IYEff2VAL✓ upn/Sgz�y3fiDT' SQZ �. `\ 2' 6 8822 - 8840 0 02/26/13 _, 2" 6 8846 - 8876 0 02/26/13 ` \ 2" 6 8960 - 8980 0 02/26/13 `\ ■ \ 2" 6 8986 -9006 0 .02/26/13 `e ■ E._- _ 8960=`8980 O 01716/06_ `\ 2" 6 9014 - 9034 0 01/16/06 I PBTD 1 10124' ` , 2" 4 9470 - 9710 C 08/01/02 2 -7/8" SLID 9470 - 9712 C 02/11/02 2 -718" SLTD LNR, 6.5#, L -80, .0058 bpf, ID = 2.377" 10125" 2 -7/8" SLTD 9776 - 10124 C 02/11/02 DATE REV BY CONVENTS . DATE REV BY COMMENTS PRUDHOE BAY L.I4T 01/17/78 ROW 36 ORIGINAL COMPLETION 02/01/10 JLW /PJC CSG CORRECTIONS WELL: A -01A 04/01/85 N18E RWO 09/14/12 SJW /JMD SET 2 -7/8" CUP (09/12/12) PeRNIT hi,: 2012420 05/02/88 N1 E'S RWO 10/03/12 JCC/JMD TREE C/O (09/30112) AR No: 50 -029- 20108 -01 07/26/91 N26E WORKOVER 03/01/13 KB/JMD ADPERFS (02/26/13) SEC 35, T11N, R13E, 2300' FPL & 922' FR 02111/02 0-16 GTE/SIDETRACK (A -01A) 01/19/06 KCF /PAG ADD FERFS (01/16/06) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 May 18,2012 °+� ev fl I-1 Mr. Jim Regg d a012 Alaska Oil and Gas Conservation Commission �� AUG 1 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A 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, 4k k - L(L-r- Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration Alaska p � ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01 A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 • A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ ` ~;~ j~g 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 Q Exploratory ^ 201-2420 v" 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20108-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028286 r PBU A-01A % 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL / 11. Present Well Condition Summary: / Total Depth measured 10125 feet Plugs (measured) None feet true vertical 8831.87 feet Junk (measured) None feet Effective Depth measured 10124 ~ feet Packer (measured) 7847' true verticai 8831.86 / feet (true vertical) 7846' Casing Length Size MD ND Burst Collapse Structural Conductor 89 30" Surface - 89 Surface - 89 Surface 1474 18-5/8" 96.5# K-55 Surface - 1474 SurFace - 1474 930 870 Surface 841 20"133# K-55 1474 - 2315 1474 - 2315 2320 1500 Production 2103 13-3/8" 72# N-80 SurFace - 2103 Surface - 2103 4930 2670 Liner 824 7" 29# L-80 7906 - 8730 7905 - 8728 8160 7020 Liner 834 3-3/16" 6.2# L-80 7942 - 8776 7941 - 8774 Slotted Liner 1349 2-7/8" 6.5# L-80 8776 - 10125 8774 - 8832 10570 11160 Production 6318 9-5/8" 47# N-80 2103 - 8421 2103 - 8420 6870 7020 PerForation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ ` _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 14' - 7972' 14' - 7971' Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer 7847' 7846' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,~,~,; ~ r'.~ 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: 76 1007 1838 195 Subsequent to operation: 77 1024 1809 209 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well 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: 309-269 / Contact Gary Preble Printed Name Gary Prebl, Title Data Management Engineer Signature Phone 564-4944 Date 9/15/2009 _ ~ ,` ' , ~~ ~ P~~' q~~ t # x a»^ Form 10-404 R~vised 7/2009 €~,,;~~~,r~ ~:s,~,~ / Submit Original Only .~5 :' ~ e~~~u ~~I'~'~j A-01 A 201-242 PERF OTTACHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base A-01A 2/11/02 SL 9,470. 9,712. 8,836.02 8,813.53 A-01A 2/11/02 SL 9,776. 10,124. 8,811.64 8,831.86 A-01A 7/31/02 PER 9,620. 9,650. 8,822.11 8,819.11 A-01A 7/31/02 PER 9,680. 9,710. 8,816.34 8,813.7 A-01A 8/1/02 PER 9,530. 9,620. 8,831.01 8,822.11 A-01A 8/2/02 PER 9,470. 9,530. 8,836.02 8,831.01 A-01A 10/1/04 BPS 10,124. 10,128. 8,831.86 8,831.9 A-01A 1/16/06 APF 8,960. 8,980. 8,881.11 8,881.71 A-01A 1/16/06 APF 9,014. 9,034. 8,880.82 8,880.15 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 • ~ L~ A-OlA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/11/2009~T/I/0= 400/1380/200 Temp=Hot Assist SLB Cementers (Gel Treatment) FLUIDS PUMPED BBLS 10 DIESEL 10 12.0 PPG 100 MESH SAND SLURRY 10 10.5 PPG BENTONITE & CELLOFLAKE 10 9.8 PPG HEC GEL 40 TOTAL • • ~ ~~ ~ ~ ~~~a ~~ ~~ ~ ~~~ ~ ~ ~E ` ~ `-' „~ ~"~~ g ~5 ~~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~' ~ ~ ~ ~ ~ ~~ ~ ~; SEAN PARNELL, GOVERNOR ~ ~v ~ ~ ~~~ ~~~ ~~ ~ ~ ~~~~ ~~~ ~~ ~ ~~ ~ ~~.~ ~S~ ~I~ ~ t][t~-.7 ~~ 333 W. 7th AVENUE, SUITE 100 COI~SERQATIOI~T CODII-IISSIOI~T a~ ANCHORAGE, ALASKA 995013539 ~ PHONE (907) 279-1433 ~' FAX (907)276-7542 Ms. Tiffany Quy WIE BP Exploration (Alaska), Inc. P.O. Box 196612 ~~,,~ ~ Anchorage, AK 99519-6612 ~~ ~ ~ Re: Prudhoe Bay Field, Prudhoe Oil Pool, A-OlA Sundry Number: 309-269 ~~~~. w ~~ i_ ~i~l~`;> ...~ ~~~.'.Y~. ~.~~ I-,~f'_ .- ~' ~v Dear Ms. Quy; Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the C~mmission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this :etter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of August, 2009 Encl. " ~ ~ STATE OF ALASKA ~ ~+r ~ i~p~~ ALA OIL AND GAS CONSERVATION COMMIS N ~~~i ~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 P~ ~~~a~~~3~~~~~ f F 3~ '~ '.F ~ i,' 4 i~J ('v vj 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver Q,, „ _ _ Other , ° r sm ~ Alter casing ~ Repair well ^ Plug Pertorations ^ Stimulate ~ Time Exteri~~Nl""~ '`°'~ '~~"(~~ J~ ~ Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ ~' `~'~ `~`~'' ~ 2. Operator Name: 4. Current Weil Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~, Exploratory ~ 201-2420 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20108-01-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required7 Yes ^ No ^ A-01A- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): _ ADLO-028286 ~ 66.4 KB ' PRUDHOE BAY Field / PRUDHOE OIL Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10125 - 8831.87 . 10124 - 8831.86 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 89 30" Surface 89 Surface 89 Surface 14~4 18-5/8"96.5# K-55 Surface 1474 Surface 1474 930 870 Surtace 841 20"133# K-55 1474 2315 1474 2315 2320 1500 Production 2103 13-3/8" 72# N-80 Surface 2103 Surface 2103 4930 2670 Production 6318 9-5/8" 47# n-SO 2103 8421 2103 8420 6870 4760 Liner 824 7" 29# L-80 7906 8730 7905 8728 8160 7020 Liner 834 3-3/16" 6.2# L-80 7942 8776 7941 8774 Slotted Liner 1349 2-7/8" 6.5# L-80 8776 10125 8774 8832 10570 11160 Pertoration Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE A7TACHED - - 4-1/2" 12.6# 13Cr80 14 - 7972 Packers and SSSV Type: 4-1/2" TIW HBBP PACKER Packers and SSSV MD (ft): 7847' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ~ Development Q- Service ~ 15. Estimated Date for 16. Weii Status after proposed work: Commencing Operations: 8/10/2009 Oil ^~ - Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Quy Printed Name Tiffany Quy Title W~E Signature Phone Date ~ 907-659-5525 7/27/2009 COMMISSION USE ONLY ti!'v ~! Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .. Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ '~~" ~ r~.`Jt~ i 4t 1DD9 Subsequent Form Required: /~ ,_ ~~y l APPROVED BY ' ~~~ ~ Approved by: C MMISSIONER THE COMMISSION Date: Iii~SS.< -S-a9 Form 10-403 Revised 06/2006 Submit in Duplicate -PG` ~~` "` i A-01 A 201-242 PFRF ATTO[_HMFNT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base A-01A 2/11/02 SL 9,470. 9,712. 8,836.02 8,813.53 A-01A 2/11/02 SL 9,776. 10,124. 8,811.64 8,831.86 A-01A 7/31/02 PER 9,620. 9,650. 8,822.11 8,819.11 A-01A 7/31/02 PER 9,680. 9,710. 8,816.34 8,813.7 A-01A 8/1/02 PER 9,530. 9,620. 8,831.01 8,822.11 A-01A 8/2/02 PER 9,470. 9,530. 8,836.02 8,831.01 A-01A 10/1/04 BPS 10,124. 10,128. 8,831.86 8,831.9 A-01A 1/16/06 APF 8,960. 8,980. 8,881.11 8,881.71 A-01A 1/16/06 APF 9,014. 9,034. 8,880.82 8,880.15 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 • ~~ ~ r To: Jerry Bixby/Clark Olsen Date: July 24, 2009 NSU, ADW Well Operations Supervisor From: Tiffany Quy, WIE ~ Subject: A-01A Load OA with Gelled Brine Est. Cost: $20M AFE: PBAPDWL01 IOR: (Req Compl) Please add the following steps to the WBL: Step Type Procedure 1 F Pump 30 bbls Gelled 9.8 ppg brine w/ corrosion inhibitor in OA. Fill OA to surface with diesel. Current Status: On line producer Last Well Test: 112 bopd, 2434 bwpd, 942 mscf/stbo Latest H2S value: 44 ppm 08/04/2009 DISCUSSION A-01 curently has an OA FL C«3 1450'. Current practice is to load any outer annuli with fluid levels below 500'. A deep OA fluid level can represent a hazard in the event of a surface casing failure - potentially resulting in the release of a large gas volume. Loading the OA also reduces this risk as well as the potential of pushing gas out of the OA shoe. A-01 has been loaded multiple times and the OA FL continues to drop. A gelled mixture (diesel or brine) is used for wells which require multiple OA loads to prevent the slow loss of fluid from an OA with a slowly dropping FL. The non-freezing gelled mixture is used which will form a filter cake and seal off small leaks below the SC shoe. The placement of the gel is done by filling the OA void and allowing it to migrate down to plug the leak over time. It may not be possible to displace the gelled mixture to the leak if the leak-off rate from the OA is very small. The gel should be placed in the OA and over time the sand and bentonite will migrate to and plug off the leak. Recent Well History: ^ 06/07/09: OA FL ~ 1450' ^ 05/18/09: OA FL C«~ 1380' ^ 12/24/09: Bled OAP to 180 psi (prep for OA diesel load) ^ 12/14/09: OA FL C~ 1260' • 12/f 6/07: OA FL @ 324' (post diesel load) • 12/14/07: Load OA w/ 40 bbls crude ^ 12/09/07: OA FL C~ 500' • 01/10/07: OA FL Cc~ 384' (post OA load) ^ 12/29/06: Load OA w/ 80 bbls crude ^ 12/29/06: OA FL C~ 732' cc: w/a: Well File NSU, ADW Well Integrity Engineer • JOB PLANNING DETAILS: • Design considerations The treatment consists of four stages. (NOTE: Brine will be 9.8 ppg w/ corrosion inhibitor) 1. The first stage is 10 bbls gelled brine with 6 ppa of 100 mesh sand mixed in. This results in 2500 Ibs of 100 mesh sand and 12.7 bbls slurry volume. The fine mesh sand helps fill any cracks in the formation and gives the bentonite a better surface to form a filter cake against. 2. The second stage is 10 bbls of gelled brine with 2000 ppt of bentonite and'h Ib/bbl of cello-flake additives. This requires 850 Ibs of bentonite and 5 Ibs of celloflake. These additives will form a filter cake over the leak and prevent further fluid loss. 3. The third state is 10 bbls gelled brine displacement fluid. This sweeps any remaining solids from the mixing tub and lines and displaces into the well. 4. Finally displace the gel with straight diesel to fill up the annulus. Pressure and pump rate considerations: The OA is effectively a tank filled while pumping diesel into it. The initial pumping should kill any residual OA pressure and make it possible to pump into the OA at max rate. Watch for any OA pressure rise as the total volume pumped approaches the OA fill-up volume. Be prepared to slow the pump if a rapid pressure increase is observed. Gelled Diesel Recipe Put the required amount of 9.8 ppg Brine w/ corrosion inhibitor into a transport truck and heat with a Hot Oil pump truck. Add 3 gpt of J453 gelling agent and 1.5 gpt of J601 gel activator and leave mixing until ready to pump the job. For a 30 bbls gel mixture, 3.8 gallons of J453 and 1.9 gallons of J601 will be required. Safety Consideration This procedure results in the OA being liquid packed. It is preferable to do this procedure on a warm well with warm fluid to prevent the possibility of a large annular fluid expansion. If the procedure is done on a cold well it must be clearly communicated to Operations that the OA is fluid packed and will require close monitoring as the well is put on production. The IA pressure should also be monitored for rising pressure as the warm fluid is pumped into the OA. The solids can cause problems monitoring the OA pressure. These solids can plug surface pressure gauge orifices resulting in erroneous readings. The final stage of straight diesel helps to flush any solids away from the surface jewelry. CAUTION If this job was performed on a cold well there is potential for annular fluid expansion (AFE) and OA pressure increase. Operations need to be clearly aware that this well will need close monitoring while being POP'ed. Recommended Equipment 1. Double valve connection to OA, terminating in a 2" 1502 connection. 2. DS pump truck. 3. Tank for DS pump truck to wash up into. 4. Tanker of hot brine for mixing gel. ~ . Job Preparation: 1. D: Confirm OA pressure and FL. Bleed the OAP to below 200 psi. Calculate OA void volume. a. Last OA FL C«? 1450' (~200 bbls) 06/07/09. 2. Ensure pump truck and gel ingredients are available. 3. Prior to the job have required amount of brine loaded into a transport and heated by LRS. Add the gelling agents and allow mixing (preferably overnight). Procedure: 1. Lay hardline from the pump truck to the OA valve. 2. Take OA pressure reading. 3. Pressure test hardline and double valves to 3000 psi. 4. Make sure the piping is empty of water (less than 10 gallons) before adding the diesel to the batch mixer. Water (or any impurities) will have a detrimental effect on the gelling of the diesel. 5. Spear into the OA with 5bbls MeOH. 6. Pump Treatment down OA C~3 ~3-4 bpm if pressure allows. Maximum treating pressure is 2000 psi. The treatment can either be batch mixed and pumped in discrete stages, or can be mixed on the fly into the mixing tub. The treatment should be pumped as follows. a. 10bbls of gelled 9.8 ppg NaCI brine w/ corrosion inhibitor & 6 ppa 100 mesh sand, b. 10bbls of gelled 9.8 ppg NaCI brine w/ corrosion inhibitor & with 2000 ppt bentonite and'/2 ppb celloflake additives, c. 10 bbls remaining gelled 9.8 ppg NaCI brine w/ corrosion inhibitor displacement to clear mixing tub and lines of any solids d. Straight diesel flush into the OA to bring OA fluid level to surface (~170 bbls) 7. Notify Operations of well condition. A yellow caution tag should be hung on the OA valve handle, clearly stating fluids pumped and date. Post Treatment Gel will take time to settie though existing OA fluid and seal off leak. Monitor the OA pressure and fluid level. A second treatment or OA load with crude or diesel is not uncommon. The OA fluid level may drop as the gel migrates downhole. ~ A U1 A ~~,~:.-~,~~~ET~~~,$-S~To • Llit1.4ACTWLlYPR60~D~ WtRt1l2"NDL~/Fi VY~L ltNGLE> T~ ~ 8920' 3> 90° ~ 8980'. WARlMIG: RAOfO TRAt~L4M RTHt N WFATt1Bt SNACK MUST ~ Tl~ bf€ B~i~ IlSNG DCPLOBNE3. 7&5~' ,CSG, ~.SAt, K 55, ID=17]55" 1474' ~ as~g x 2a* xo ~ 2021• a-~rroTSSSSVwm=a.ai~ 21U3' 13-3t8" X 9-516' XO ~= a_~~te~t~w W!H.ltf~1D= McEVOY ACTtb1T~d = BAIC@2 ~. ~,, ~_~. 8F. ~EV - 4T.4' KOP= ~86• A~c An~e = 9$ ~ ~20' €iQWnro bU = ~A4' Da~tn N D= BBOd SS M~~num ID = 2.30" @ 9428' M~LED-0UT BAKER LNDNG COLLAR 12D" cSG~ 133M, K-55. Y~ =18.730~ I J I 5&58I 57~ I t 2 7568 7520 7 1 7730 7@84 1 7835 4 784~~ SL~/E ~ 3-U2 XN hp, D= 2750' U2' X 3-3i1$' XO, D= 2.786' 13-CR .0~52 bpt, lQ- 3.958' 9-5~' CSG, dT#. L-$0. D= 8.681' H $421' P~RATIad SI~AAh4RY ~ ~ac: sa~zr -~n+o~c~~aa ozr»roz ANCaLE ATTOPP6~: 88 ~ 896d' Nota: faetet b P-od~tbn 08 for hiabriCal peH date se rrra~vnt oF~ an~ r s s~o. aseo 0 ov~s~~ 2' 8 9014-9034 O 01/16/~ 2' 4 9d70 - 9T10 O U8/01lQ2 ~7B` SLTD 9470-9T12 O 02l77/02 2-78' SLTD 9T76 - 1Q12d O 02/11/02 L-it, ~, L-80. ID = 8.184' ~ LFT SO RA 20 DMY RA 0 DMY RA 0 = 3.813' 79$Z' 3.70' OD BFQ2 D~lOY1~ET SLV, ID = 3.000' 7!~q,q' 4-12" SWN I~, M.L~ TO 3.St1' D BY CTD 7972' 4-1/2• WI.EG, ID=4.~D" 7976~ 6.IuD TT LOGG~ 08~04/91 T LM2 f~f.LOUf W/~OVV (A-01A) D9'1/Y _ OY!¢• ! (tGG UIL~LT(Y+Of \ ~~ " l ~^ ~ f ~ $~]6' 3-3+18' X 2-7/8' Lt~R XO, ID = 2.377' I 942$' 2-Tt8" BKR LC, Mq1.~'I~Q 2.30' D I 9470' roP oF 2-rta• st~ro ~r~t ~ \ ~`~Q s~~r 2-7/8'SQLIDL~t • I ~ ( \ ~ sn6 2-n~ s~Ta ~r~z \ ~ I ~ 1 ~ ~ • ~ I ` ~ t t i ~ FBTD 10124 - \ ~ 2-7/8' SLTD LPF2, 6.5#. L-B0. -0058 bpf, ID = 2.37T' 10125' C5~1TE f~i/ BY CQMu6YTS Q4TE REV BY OOMNB~lT$ 81ft7r/8 OFOGB~f11LGONPLETION 0712b191 YYOFA~1/Ht 42Htp2 CTD~ETRACK (A-OtA) U3aQt,II2 pYTP COF~Cf~ OBlU2~2 SF2H1th ADOP~P5 Qti19l0$ Kt~~PAG AOD PB3FS (Qil9B108) PRIAHOEBAY t~tlT 4V~L: A-01A PBiMf No: 2D1-242p AR No: 50-029-2(i10&01 SEC 35, T71N, R13~ 229T SPl & 922 W~ ~ Bcploration ~Alaaka) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker. doc RECEIVED ) STATE OF ALASKA ') AL.A...). Oil AND GAS CONSERVATION COMrv,....I~ION REPORT OF SUNDRY WELL OPERATIONS FEB 2 4 2006 D Stimulate D Other ,0_ . . D Waiver D "AlMkatOtib&'~ Cons. CommiSSion o Re-enter Suspended Wel~horage 5. Permit to Drill Number: Exploratory Di 201-2420 Service 6. API Number: 50-029-20108-01-00 9. Well Name and Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 66.4 KB ADL-028286 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Surface Production Production Liner Liner Slotted Liner Perforation depth: measured 10125 true vertical 8831.87 measured 10124 true vertical 8831.86 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ß?]: Stratigraphic C A-O 1 A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool feet feet Plugs (measured) Junk (measured) feet feet . \ I ,1" 11M' \\l~-;\" I \PC w:~¡ ~, ~~ 2.005 ðt;",,:,¡,,~;,,'ÿL.. \ LIiJ " Length Size MD TVD 89 30" Conductor stove pir Surf - 89 Surf - 89 1474 18-5/8" 96.5# K-55 Surf - 1474 Surf - 1473.9 841 20" 133# K-55 1474 - 2315 1473.9 - 2314.9 2103 13-3/8" 72# N-80 Surf - 2103 Surf - 2102.9 6318 9-5/8" 47# N-80 2103 - 8421 2102.9 - 8419.91 824 7" 29# L-80 7906 - 8730 7905.28 - 8728.35 834 3-3/16" 6.2# L-80 7942 - 8776 7941.27 - 8773.62 1349 2-7/8" 6.5# L-80 8776 - 10125 8773.62 - 8831.67 Measured depth: 8960 - 8980 True Vertical depth: 8881.11 - 8881.71 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9014 - 9034 9470 - 9712 8880.82 - 8880.15 8836.02 -,8813.53 4-1/2" 12.6# 13CR80 4-1/2" TIW HBBP Packer None None Burst Collapse 930 2320 4930 6870 8160 870 1500 2670 4760 7020 10570 11160 9776 - 10124 8811.64 - 8831.86 14 - 7972 7847 Treatment descriptions including volumes used and final pressure: RBDMS BFL FEB 2 J' 2006 13. Oil-Bbl 95 120 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 1207 2126 550 1191 2325 500 15. Well Class after oroposed work: Exploratory r Development ¡;¡ 16. Well Status after proposed work: Oil po Gas L WAG r GINJ C 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal / I Printed Name Sharmaine Vestal '" ,/, ' -, ~~ " ') t., #-/ Signatu~~"L-?~0/1..tZ-, ~.~~t..f Phone 564-4424 ORIGINAL Form 10-404 Revised 04/2004 Title Data Mgmt Engr Tubing pressure 439 215 Service r WINJ L WDSPL r Sundry Number or N/A if C.O. Exempt: N/A Date 2/22/2006 Submit Original Only ) ) A-01 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/15/2006 CTU # 9. Tie in Log/Perforate. RU and RIH with PDS 2.20" OD GR/CCL. ... Continue on 1-16-05 WSR ... 1/16/2006 CTU # 9. Tie In Log/Perforate. ... Continue from 1-15-06 WSR. RIH with 2.20" OD PDS logging tools. Make tie in pass from 9250' - 8600' at 40 fpm. Flag pipe @ 8975' ctmd. POOH. Surface. Confirm good data. Subtract 13'. Log tied in to SS MWD 2-11-02. Cap well with 10 bbls 60/40 meth and RIH with Gun # 1 to flag. Correct to top shot and shoot from 9014'-9034' w/PJ2006 HMX 2" 6 spf gun. Good indication of guns firing. POOH. All shots fired. Make up Gun #2. RIH to flag and correct to top shot and shoot from 8960'·8980' w/PJ2006 HMX 2" 6 spf gun. Good indication of guns firing. POOH. Cap well w/5 bbls 60/40 methanol water. Well is not freeze protected. S-riser is freeze protected, flowline is not freeze protected. Blow down reel w/N2. Well is not freeze protected. Pad Operator to POP ASAP. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 147 60/40 Meth 147 TOTAL Permit to Drill MD 10125 -- 1-01L Current Status 1-01L UIC N L ~ fIlJ;.;,,--;l&<J Y DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 ~ grU,~ 2012420 Well Name/No. PRUDHOE BAY UNIT A-01A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20108-01-00 NO 8832 /' Completion Date 2/14/2002 .....--- Completion Status REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name fE'ð/ 0 (;.(1458 ,Ç.í§\f~If¡~tí9R:~ ~ I Log ~ Log Log Log ~ eo }~ <.LED l 0 C Asc C Asc C Pdf C Pdf ¡êÎ~ýÞri~(9§~¥,. Log Log Run Scale Media No 1 1 Blu 1 1 1 2 2 2 Blu Blu Q'VV- \~, ~ 1 1 1 f ) ~~ ~ )..... 2 Blu 1-3 1-3 J 11746 11746 11746 11746 25 25 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? Formation Tops Chips Received? -- " I N Analysis Received? ~ (data taken from Logs Portion of Master Well Data Maint) -- Interval OH I Start Stop CH Received 8534 1 0080 Open 1/3/2003 8700 10125 Open 12/18/2002 9350 10115 Case 8/9/2002 8534 1 0080 Open 1/3/2003 9350 10115 Case 8/9/2002 9350 10115 Case 8/9/2002 9350 10115 Case 8/9/2002 8700 10125 Open 12/18/2002 Comments , -'------¡ I i ¡ [ 85340 10125 85340 10125 8746 10125 Open 8746 10125 Open ROP, NGP, DGR, EWR ROP, NGP, DGR, EWR .-." Sample Set Number Comments (9tN ()/N DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012420 Well Name/No. PRUDHOE BAY UNIT A-01A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20108-01-00 MD 10125 NO 8832 Completion Date 2/14/2002 Completion Status 1-01L Current Status 1-01L UIC N Comments: Compliance Reviewed By: ~ Dale: I 7 ~~)}-~<i ------ ~',c- ,-~- ( ~ (' ?b I ~~?-- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 May 09, 2003 RE: MWD Formation Evaluation Logs: A-O 1 A, AK-MW-22021 A-OIA: Digital Log Images 50-029-20108-01 1 CD Rom , 114b PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: fc. I D ' D 3 Signed: ~ ~ , E'CE'V .,~.::." . ~~ \.m ED MAY 13 2003 Aia$ka Ot¡ & Gas Cons. CommiNion AnmOflge , (, ~ dO j-{Jlj d II 45r; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska December 19, 2002 RE: MWD Formation Evaluation Logs A-01^ AK-MW-22021 1 LDWG formatted Disc with verification listing. API#: 50-029-20108-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- T echnicalOata Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: & ~ Date: RECEIVED JAN 0 3 200.3 Alaetto;¡ , Ga Con~ f'.Nn-~ ~ ~~nllltion (" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ilOil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-242 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-201 08-01 ,- '" , 4. Location of well at surface :-:<:;~"o:,-",,:_, "',1 L()f,..A liONS 9. Unit or Lease Name 2300' SNL, 922' WEL, SEC. 35, T11N, R13E, UM ~ -"',' "I V~~Ir;n Prudhoe Bay Unit ,'-~~'~"f$~~~; At top of productive interval 2391' SNL, 927' WEL, SEC. 35, T11 N, R13E, UM , -.. -'.., " ç L 10. Well Number At total depth :\.'.'-::l ':'-', ¡ ti tr.. "r.r"'\ ~~ ~" ,.\. ,: .,. '. ~'- ~:".......,¡c.~,.;~~;. A-01 A 3278' SNL, 200' WEL, SEC. 35, T11N, R13E, UM j,:":,~",..,:"":,-,,-,,,,,' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool KBE = 66.40' ADL 028286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 2/8/2002 2/11/2002 2/14/2002 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10125 8832 FT 10124' 8832 FT iI Yes ONo (Nipple) 2021' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, ROP 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Stove Pice Surface 89' 36" 1200 sx Permafrost II 20" x 18-5/8" 96.5# 1 133# K-55 Surface 2315' 26" 6250 sx Permafrost II 13.318" x 9-5/8" 72# 1 47# N-80 Surface 8421' 12-1/4" 1500 sx Class 'G' 450 sx PF II 7" 29# N-80 7906' 8730' 8-1/2" 345 sx Class 'G' 3-3116" x 2-7/8" 6.2# 1 6.16# L-80 7942' 10125' 3-3/4" 74 sx Class 'G' 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) 2-7/8" Slotted Liner 4-1/2", 12.6#, 13Cr 7972' 7847' MD TVD MD TVD 9470' - 9712' 8836' - 8814' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9776' - 10124' 8812' - 8832' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 23, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water:' Šùbmìt core chips. No core samples were taken. (;" .. ", t. ,: " , ' ,:" ,:' ',:',:" '0 {;,,;:~" ". ..,'" .,' " I ,~,,", t j! ~ .» t f ~\! 1\: ~ I ? ~ub?n1i~ln Duplicate Form 10-407 Rev. 07-01-80 " Þ :'-~"." I. :': " RBOMS 8Fl ,.." I '. ..,," , , -""M'~:,ljl.\.,}¡;/ ¡1::"'~",i~ MAR " ,-,no~ c,f ( 29. Geologic Markers Measured True Vertical Depth Depth 8741' 8739' 8772' 8770' 8788' 8785' 8820' 8813' 8877' 8854' 9130' 8873' Marker Name Shublik A Shublik B Shublik C Sadlerochit I Zone 48 45N 44N (Invert) 31. List of Attachments: Summary of Daily Drilling Reports, Surveys ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. II" 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ Title Technical Assistant Date 03. ~J..O A-01A Well Number 201-242 Permit No.1 A roval No. INSTRUCTIONS Prepared By Name/Number: Terrie Hubble, 564-4628 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 24: 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 (OF, 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 27: 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 11 \1 I' I: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/30/2002 1/31/2002 2/1/2002 2/2/2002 2/3/2002 2/4/2002 2/5/2002 2/6/2002 2/7/2002 (' (' BP EXPLORATION Operations Summary Report A-01 A-O 1 A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 06:00 - 12:30 From - To Hours Activity Code NPT PRE 12:30 - 14:00 14:00 - 17:30 17:30 - 00:00 00:00 - 00:00 00:00 - 09:00 09:00 - 00:00 00:00 - 12:30 12:30 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 00:00 00:00 - 01 :00 01:00 -13:00 13:00 - 19:00 19:00 - 00:00 00:00 - 05:30 05:30 - 13:00 13:00 - 00:00 00:00 - 06:00 06:00 - 00:00 00:00 - 16:00 16:00 - 16:30 16:30 - 18:00 18:00 -18:30 18:30 - 20:30 20:30 - 20:45 20:45 - 22:00 22:00 - 22:45 22:45 - 00:00 00:00 - 00:30 00:30 - 00:45 00:45 - 02:00 02:00 - 05:00 6.50 MOB 1.50 MOB 3.50 MOB 6.50 MOB 24.00 MOB 9.00 MOB 15.00 MOB 12.50 MOB 4.00 MOB 1.50 MOB 0.50 MOB 1.00 MOB 4.50 MOB 1.00 MOB 12.00 MOB 6.00 MOB 5.00 MOB 5.50 MOB 7.50 MOB 11.00 MOB 6.00 MOB 18.00 MOB 16.00 MOB 0.50 MOB 1.50 MOB 0.50 MOB 2.00 MOB 0.25 MOB 1.25 MOB 0.75 MOB 1.25 MOB 0.50 MOB 0.25 MOB 1.25 MOB 3.00 MOB P P PRE P PRE N N N PRE WAIT PRE WAIT PRE N WAIT PRE N P WAIT PRE PRE P P P P P N PRE PRE PRE PRE PRE WAIT PRE N N N N N WAIT PRE WAIT PRE WAIT PRE WAIT PRE WAIT PRE N N WAIT PRE WAIT PRE N WAIT PRE P PRE P P PRE PRE P P PRE PRE P P P PRE PRE PRE P P P P PRE PRE PRE PRE Page 1 of 7 Start: 1/8/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Phase Description of Operations Cut off CTC. LD gooseneck. Store injector. General RD. Move off 13-32ai. Clean location Move rig from OS 13 past Security checkpoint w/ derrick up to DS 6 front pad and set down Winds above 15 mph. Can't lower windwalls for derrick down move. Prep rig as far as possible (set derrick jacks, stand, etc) Place rig on Standby rate at 1700 hrs. WO wind 14-21 mph Waiting on wind (21 mph), Phz 1 WOW (wind) on OS 6 to RD prior to move to A Pad. Wind above 15 mph WOW (temperature) on DS 6 prior to move to A Pad. Temp is -37 to -40 F WOW (temperature). Varied between -36 and -41 F. PJSM Temp above -35 F. Begin RD for derrick down move. LD windwalls. Scope down derrick and lay down in pipeshed Warm up moving system Safety mtg re: rig move Jack upllevel out rig and move to access road Left DS-6. Move to A pad. Continue moving to A pad. Set rig down on Pad near A-01. Start Standby rate due to wind (16-26 mph). WOW Phz 1 (winds 23-32 mph) Phz 2 (winds 30 -40 mph ) WOW. Phz 2 (winds 32 - 45 mph) WOW. Phz 3 (winds 34-56 mph) WOW. Phz 3 (winds 28-58 mph). Crew XO w/966 and Excursion (!) arranged thru IMT. Fuel received WOW. Phz 3 (winds 25-52 mph) Convoy crew change with loader. Phz 2 on Spine Rd while Phz 3 on Access Rds. Continue stanby WOW. Wind Steady/Gust: 23/38MPH. Continue standby WOW. Phz 1 on Spine Rd while Phz 2 on Access Rds due to drifting snow. Wind Steady/Gust: 24/42MPH. Wind slowed to 8-18 mph at 16:00 SAFETY MEETING. Review procedure and hazards of raising derrick. Raise Derrick with no problems. M/U guywires. Crew change. SAFETY MEETING. Review procedure and hazards for raising wind walls. Raise derrick windwalls & pin. Hook-up guy lines. SAFETY MEETING. Review procedure and hazards for securing retracting rams. Secure retracting rams. R/D winch lines & snub lines. PJSM. Hook-up P/U slings + BOP & hand BOPE. Prepare to move rig onto well. NO tree cap. N/U adapter flange on A-01A. Continue N/U adapter flange on A-01A. PJSM & HA/HM on moving rig onto well. Move rig over tree and set down. Level up. PJSM. NU BOPE. P/U injector & gooseneck. P/U CT for stab-in. Meanwhile R/U outside equipment, trailers, hardlines & tanks. Printed: 2/20/2002 11 :26:35 AM (' " ( BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: A-01 Common Well Name: A-01A Spud Date: 11/3/1971 Event Name: REENTER+COMPLETE Start: 1/8/2002 End: 2/14/2002 Contractor Name: NORDIC CALISTA Rig Release: 2/14/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/7/2002 05:00 - 07:30 2.50 BOPSUF P DECOMP ACCEPT RIG AT 05:00 HRS. 02-07-02. Change out pack-off. Rig up berms for green tank and flowback tank. 07:30 -14:15 6.75 BOPSUF P DECOMP Perform initial pressure / function test of BOPE. AOGCC witness waived by Chuck Scheve. Chart and send test report to AOGCC. Grease crew pumped open SSV. 14:15 -14:45 0.50 STWHIP P WEXIT M/U OS CTC. Pull test w/ 35K. Fill coil with KCL water. 14:45 -15:15 0.50 STWHIP P WEXIT SAFETY MEETING. Review well plan. Review procedure and hazards of BHA M/U. 15:15 -16:00 0.75 STWHIP P WEXIT M/U Milling BHA #1, 3.80" HC diamond speed mill, 2-7/8" BHI straight motor, 2 jts PH6, MHA. Total length = 65.7 ft. 16:00 - 17:30 1.50 STWHIP P WEXIT RIH with BHA #1. Add Biozan to slick KCL water. 17:30 - 18:30 1.00 STWHIP P WEXIT Tag XN nipple at 7976 ft CTD. [7953 FT bkb]. Correct depth [ -23 FT CTD]. Mill out XN nipple to 3.80". 2.5/2.5 bpm, 1800 psi. Back ream and ream nipple. OK 18:30 -18:45 0.25 STWHIP P WEXIT RIH & tag TOC @ 8724'. P/U & retag same depth. 18:45 - 19:00 0.25 STWHIP P WEXIT Ease in & begin milling cement @ 2.5/2.5 bpm, 1675/1900 psi. Stall & observe pinch point @ 8734.4'. Correct depth to 8729.5' (-4.9' CTD, TOWS to pinch pt = 4.5'). 19:00 - 20:40 1.67 STWHIP P WEXIT Flag pipe & begin milling window from 8729.5' @ 2.45/2.45bpm & 1550/1650psi. Mill to 8731' & observe pressure climb up to 2830psi. 20:40 - 23:00 2.33 STWHIP P WEXIT Reduce rate to 2.1/2.1 bpm, 1150/2650psi & stack up to 7.5k. Stall motor twice. Milled to 8731.8' while changing rates/pressures. Try 2.4/2.4bpm & 3250psi and milled to 8732.2'. Acting like a worn mill with no further progress. Decide to POOH to inspect BHA. However, had good amount of metal on magnets. 23:00 - 00:00 1.00 STWHIP P WEXIT POOH BHA#1. 2/8/2002 00:00 - 00:20 0.33 STWHIP P WEXIT Continue POOH BHA#1. 00:20 - 01 :00 0.67 STWHIP P WEXIT OOH. Observe diamond speed mill worn down to 3.77" 00. Wear does not indicate any crossing of liner wall. String reamer still in guage @ 3.80" OD. Check motor with wrenches - seems OK. Chageout diamond speed mill. 01 :00 - 02:25 1.42 STWHIP P WEXIT RBIH with window milling BHA #2 & tag-up @ 8762'. Correct to 8732.2' 02:25 - 06:00 3.58 STWHIP P WEXIT Had 2 stalls. Ease in & resume milling window @ 2.5/2.5 bpm, 1700/1850 psi. Mill to 8736.4' & observe pressure climb up to 2540psi & then going down. Also getting wt back from 17k to 19k. 06:00 - 08:00 2.00 STWHIP P WEXIT Mill window. Exit 7" liner at 8735.5 ft Corrected CTD. Top window at 8729.5 ft. Drill formation to 8748 ft. Back ream window. Ream down. 2.6 / 2.6 bpm, 2000# 08:00 - 08:30 0.50 STWHIP P WEXIT Ream window area while swapping well to FloPro. Ream window total of 4 times up and down. Stop pumps, RIH thru window with no weight loss. Window is clean. Corrected TO is 8746 ft. 08:30 - 10:30 2.00 STWHIP P WEXIT POOH while circ well to FloPro. Printed: 2/20/2002 11 :26:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( BP EXPLORATION Operations Summary Report A-01 A-01A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 2/8/2002 10:30 -10:45 From - To Hours Activity Code NPT 10:45 - 12:30 12:30 - 14:20 14:20 - 14:45 14:45 - 16:45 16:45 -17:15 17:15 - 18:00 18:00 -18:45 18:45 - 20:30 20:30 - 21 :00 21:00 - 21:30 21 :30 - 23:00 23:00 - 23:15 23:15 - 23:45 2/9/2002 23:45 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:50 04:50 - 05:15 05:15 - 06:15 06:15 - 06:30 06:30 - 08:00 08:00 - 10:15 10:15 -12:15 12:15 -14:00 14:00 - 14:30 14:30 - 16:00 0.25 DRILL 1.75 DRILL 1.83 DRILL 0.42 DRILL 2.00 DRILL 0.50 DRILL 0.75 DRILL 0.75 DRILL 1.75 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 1.83 DRILL 0.42 DRILL 1.00 DRILL 0.25 DRILL 1.50 DRILL 2.25 DRILL 2.00 DRILL 1.75 DRILL 0.50 DRILL 1.50 DRILL P P P P P P P P P P P P P P P P P N Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 WAIT PROD1 P P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 3 of 7 Start: 1/8/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Description of Operations SAFETY MEETING. Review procedures and hazards for BHA change out. Layout milling BHA #2, M/U MWD BHA #3, 3.75" M09 bit, 2.83 deg SR BHI motor, 2 jts 2-3/8" PH6 tbg, MWD, MHA. Total length = 131.64 ft. Extra length to keep MWD inside 7" liner while drilling first 50 ft of open hole. RIH with MWD BHA #3. Shallow test MWD tools. RIH. 0.2 bpm. Correct to flag at 8524 ft. [-32 ft]. RIH to above window. Orient TF to 60lo Drilling. TF = 60L, 2.5/2.5 bpm, 3600 psi, Drilled to 8777 ft. Drilling. TF = 60L, 2.5/2.5 bpm, 3600 psi, Drilled to 8785 ft. Drilling. TF = 40L, 2.5/2.5 bpm, 3600 psi, Drilled to 8800 ft. Wiper trip to window. Hole clean. RIH to TO of 8800 ft. Circulate btms up. Paint EOP flag @ 8400' & POOH BHA#3. OOH. LID BHA#3. M/U Gyro BHA#4, 1/2 jt 2-3/8" PH6 tbg carrier with gyro tool + MHA. Total length = 22.46ft. RIH with BHA#4 @ 0.2bpm. Correct to flag at 8458' (-35'). RIH without bobbles thru window & tag btm @ 8798'. P/U free wi. SD pumps & park @ btm for 3mins to activate gyro survey. PUH in 10' stages & park for 3 mins/stage for next 8 survey shots. Final shot @ 8820'. Paint EOP flag @ 8400' & POOH BHA#4. Continue POOH BHA#4. LID BHA#4. M/U MWD BHA #5 with 3-3/4" M09 bit, 2.83 deg SR BHI motor, MWD & MHA, OAL- 64.77'. Meanwhile download memory gyro data. Wait on gyro data download. Survey @ 8788' shows 21.86degs incl, 89.72degs AZM & 37 degs DLS. Well on right path. Decide to RIH with 2.83 degs motor bend. RIH with MWD BHA#5. SHT MWD tools - OK. Continue RIH. Correct to flag at 8456' (-34.5'). Orient TF to 90lo RIH without bobbles thru window & tag btm @ 8790'. Log-up for GR tie-in. Add 12 ft per Geologist. Hard to see RA in high GR of Shublik. Orient TF to 18R. Drilling build section. TF = 6R, 2.3/2.2 bpm, 3100 psi, Incl = 26 deg. Fluid loss of 0.1 bpm to formation. Drilled to 8824 ft. Drilling build section. TF = 35R, 2.5/2.5 bpm, 3300 psi, Incl = 53deg. Drilled to 8892 ft. Drilling build section. TF = 35R, 2.5 / 2.5 bpm, 3300 psi, Incl = 84deg. Drilled to 8975 ft. Ended build section. Well landed at 8972 ft. 8815 ft TVDSS. POOH for lateral BHA. Flag CT at 8400' EOP. LlO build BHA. M/U 0.80 deg motor, Bit #5 [DS49}, MWD Resistivity/GR/Dir. Test Res. at surface. BHA = 89.57 ft. Printed: 2/20/2002 11 :26:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/9/2002 2/1 0/2002 2/11/2002 (' ( BP EXPLORATION Operations Summary Report A-01 A-01A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 16:00 - 17:40 17:40 - 17:50 17:50 - 18:00 18:00 - 19:30 19:30 - 20:00 20:00 - 21:11 21:11-21:15 21:15 - 00:00 00:00 - 02:30 02:30 - 04:05 04:05 - 04:35 04:35 - 05:50 05:50 - 06:40 06:40 - 07:10 07:10 - 07:45 07:45 - 08:30 08:30 - 09:15 09:15 - 09:30 09:30 - 11: 15 11:15 -12:15 12:15-13:45 13:45 - 15:45 15:45 - 16:15 16:15 - 17:45 17:45 -18:30 18:30-18:50 18:50 - 20:20 20:20 - 20:35 20:35 - 20:45 20:45 - 21 :00 21 :00 - 22:35 22:35 - 00:00 00:00 - 00:40 00:40 - 01 :00 1.67 DRILL 0.17 DRILL 0.17 DRILL 1.50 DRILL 0.50 DRILL 1.18 DRILL 0.07 DRILL 2.75 DRILL 2.50 DRILL 1.58 DRILL 0.50 DRILL 1.25 DRILL 0.83 DRILL 0.50 DRILL 0.58 DRILL 0.75 DRILL 0.75 DRILL 0.25 DRILL 1.75 DRILL 1.00 DRILL 1.50 DRILL 2.00 DRILL 0.50 DRILL 1.50 DRILL 0.75 DRILL 0.33 DRILL 1.50 DRILL 0.25 DRILL 0.17 DRILL 0.25 DRILL 1.58 DRILL 1.42 DRILL 0.67 DRILL 0.33 DRILL p p p p p p p p p p p p p p p p p p p p p p P N Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 P P P P P P P P C C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 4 of 7 Start: 118/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Description of Operations RIH with MWD BHA #6. Shallow test MWD. RIH. Correct Depth to CT flag, [-33 ft CTD]. Orient TF to high side. RIH to TD of 8975 ft. Hole clean. Log MAD pass up from TO to window. Continue logging up for Final GR tie-in of RA tag to open hole logs. RIH to TD. Orient TF to 45R. Drilling Lateral, 2.4 / 2.4 bpm, 3200 psi, TF = 45R drill to 9023 Sticky. Wiper trip to window at 8725 ft. Drill lateral, 2.4/2.4 bpm 3765 psi 3350 psi,FS TF 45R . Stacking weight. Directionally drill to 9107'. Directionally drill to 9200. Swap to new mud while drilling ahead. Directionally drilling, 2.5/2.5 bpm, 3700psi, TF 64R., Drilled to 9300'. Wiper trip to window at 8725'. Directionally drilling, 2.5/2.5 bpm. @ 3620 psi. TF 76R, FS 3260 psi. Drilled to 9394 Orient to 50R Drilling lateral, 2.5 / 2.5 bpm, 3450 psi, TF = 70R, Incl = 94.5 deg. Drilled to 9465 ft. Wiper trip to window at 8725 ft. Motor work in shales at 9090 ft. Log tie-in to RA tag at 8735 ft. Added 11 ft to CTD. Ream shales at 9090 ft. RIH to TO at 9473 ft. Orient TF to 50R. Drilling, TF = 50R, 2.6/2.6 bpm, 3500 psi, Incl. = 95 deg. Drilled to 9606 ft. Wiper trip to window. Hole Clean. RIH to TD. Hole Clean. Full returns. Drilling, TF = 11 OR, 2.6 / 2.6 bpm, 3500 psi, Incl. = 95 deg. Drilled to 9705 ft. Drilling, TF = 170R, 2.6/2.6 bpm. 3500 psi, Incl = 92 deg. Drilled to 9764 ft. Started losing returns at 9740 ft. 1.2 bpm losses. Order LCM Mix 2 and 260 bbls used FloPro from MI. Wiper trip to window. 2.5 /1.3 bpm, 3250 psi. Wait on LCM [Mix 2] and used mud. Mix 30 bbl LCM pill with FloPro and 25 PPB Mix 2. RIH to TO. Circ. LCM pill to bit. Circ. LCM past loss eirc. point. Losses decreased to 0.4 bpm at 2.4 bpm in. Orient TF to lowside. Drilling, TF = 146R 2.3/2.0 bpm @ 3490 psi Orient TF 40R Directionally drill to 9834' Orient TF 76R Directionally drill, TF 76R, 2.3/2.2 bpm @ 3500psi, drill to 9900'. Wiper trip to window 1125'. RIH stacking at 9060. Orient 55R 9077 , 9095 stacking Wiper trip to window. tight @ 9150 Orient TF 84R Printed: 2/20/2002 11 :26:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/11/2002 2/12/2002 Date r' ( ("' \, BP EXPLORATION Operations Summary Report A-01 A-O 1 A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 01:00 - 04:10 From - To Hours Activity Code NPT 04:10 - 05:50 05:50 - 07:45 07:30 - 09:00 09:00 - 09:45 09:45 - 13:00 13:00 -14:15 14:15 - 14:30 14:30 - 15:45 15:45 -16:00 16:00-21:00 21 :00 - 23:00 23:00 - 23:40 23:40 - 00:00 00:00 - 02:20 02:20 - 03:00 03:00 - 04:00 04:00 - 04:15 04:15 - 06:00 06:00 - 06:30 06:30 - 07:00 3.17 DRILL 1.67 DRILL 1.92 DRILL 1.50 DRILL 0.75 DRILL 3.25 DRILL 1.25 DRILL 0.25 DRILL 1.25 DRILL 0.25 CASE 5.00 CASE 2.00 CASE 0.67 CASE 0.33 CASE 2.33 CASE 0.67 CEMT 1.00 CEMT 0.25 CEMT 1.75 CEMT 0.50 CEMT 0.50 CEMT C C C P P P P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Page 5 of 7 Start: 1/8/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Description of Operations Directionally drill 2.4/2.3 bpm @ 3680 psiTF 58R FS 3320 psi. Drill to 10,050'. Wiper trip to window. Over pull at 9060' and had to work thru while running in hole but greatly improved over previous trip. Directionally drilling, TF = 100R, 2.5 / 2.4 bpm @3800 psi, FS 3320 psi. Incl = 90 deg. Circulated second 35 bbl, LCM pill, Mix 2 at 25 PPB. Second pill made no immediate notable change to loss rate but gradually continued to heal fatcture. Pill did not plug up MWD tools. Drilled to 10,100 ft. Geologist called well at TO. Wiper trip to window. Up Wt = 31 K, Own Wt = 18K. Ream shales, shale at 9100 ft had some motor work and overpull, but is OK. Log tie-in with RA tag at 8735 ft. Added 30 ft CTD. RIH. Ream shales at 9100 ft. RIH. Tag Final TD at 10,125 ft BKB. Lay in 25 bbls very high viscosity new FloPro in open hole. Ream shales again at 9100 ft. Shales in good condition. POOH. Flag CT at 6400' EOP. POOH with MWD BHA. SAFETY MEETING. Review procedure and hazards for laying out MWD BHA. Layout drilling BHA. Download Resistivity tool. SAFETY MEETING. Review procedures and hazards for running liner. Run 11 jts, 2-7/8", STL Perforated liner, 2 Jts, 2-7/8", STL Solid liner, 7 Jts, 2-7/8" STL Perforated Liner, 1 Jt. 2-7/8" STL Liner. M/U BKR Diverter collar with AL Baffle Plate. M/U BKR 4 ft perforated pup. M/U BKR Float CLLR. M/U BKR 4 ft pup Jt. M/U BKR Landing CLLR. 2-7/8 STL XO 3-3/16 STL liner XO XN nipple 2.813" bore, 2.75" No Go pup Deployment sleeve. RIH with Iiner.Stacking at 8990 thru 9200. RIH to Bottom No problems. Liner top at 7941', baffle at 9438', solid 9712-9775'. Drop ball and circulate to running tool. Disconnect. Change over to KCL Continue to change over to KCL. Mix cement. Pressure test lines. Pump15 bbls 15.8 ppg cement and displace with 2% KCL. Picked up liner wiper plug on calculated volume. Bump plug on calculated volume. Floats held. Unstung and circulate liner top @ 2.9 bpm. POH with liner running tools. PJSM crew change and LD running tools Set back injector, Layout BKR CTLRT. Printed: 2/20/2002 11 :26:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/12/2002 2/13/2002 Date (' ( BP EXPLORATION Operations Summary Report A-01 A-O 1 A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 07:00 - 07:15 From - To Hours Activity Code NPT COMP 07:15 - 09:45 09:45 - 12:00 12:00 - 12:30 12:30 - 13:15 13:15 - 22:30 22:30 - 00:00 00:00 - 03:00 03:00 - 04:15 04:15 - 05:00 05:00 - 06:45 06:45 - 07:50 07:50 - 08:10 08:10 - 12:45 12:45 -14:15 14:15 -15:40 15:40 -16:00 16:00 - 16:30 16:30 - 17:15 17:15 - 20:30 20:30 - 22:00 Phase 0.25 CEMT P 2.50 CEMT P COMP 2.25 CEMT P COMP 0.50 CEMT P COMP 0.75 CEMT P COMP 9.25 CEMT P COMP 1.50 CEMT P COMP 3.00 CLEAN N CEMT COMP 1.25 CLEAN N CEMT COMP 0.75 CLEAN N 1.75 CLEAN N CEMT COMP CEMT COMP 1.08 CLEAN N CEMT COMP 0.33 CLEAN N CEMT COMP 4.58 CLEAN N STUC COMP 1.50 CLEAN N STUC COMP 1.42 CLEAN N STUC COMP 0.33 CLEAN N 0.50 CLEAN N 0.75 CLEAN N STUC COMP STUC COMP STUC COMP 3.25 CLEAN N STUC COMP 1.50 CLEAN N STUC COMP Page 6 of 7 Start: 1/8/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Description of Operations SAFETY MEETING. Review procedure and hazards to run CSH workstring. M/U 2.3" diamond parabolic mill, 2.12" motor, MHA. Pick up 74 Jts. 1.25" CSH workstring in singles. RIH with CMT cleanout BHA. No wt loss at top of liner. No wt loss at XO to 2-7/8" liner. Clean out 2-7/8" liner at 1.1 bpm, Tag top of liner wiper plug at latch collar at 9438 ft CTD, Actual = 9426 ft BKB. Wait on cement. OS lab UCS cement sample at 2000 psi at 12:30. Pressure test liner lap with 2160 psi, chart and hold 30 min. End press = 2070 psi. Good Test. Mill Liner wiper plug [2.5 ft long, Alum. and rubber] with 2.3" mill. 1.7 bpm, 2050 psi. Start at 9437.4 ft. Milling slowly. Make @1.5' and stall repeatedly. Drill 1.6 BPM at 2600 psi FS 2000 psi. Drill to 9439. RIH to 9472. Drill cement 2500 psi 1.5 bpm cleanout from 9472' to 9535'. FS 2000 psi. Drill cement from 9535'to 9600 @ 1.7 bpm 2700 to 2300 psi FS= 2000psi. Loss since drill out 25 bbl. Drill cement from 9600' to 9635' 1.9 bpm 2800 psi 1.8/1.7 bpm. Wiper trip to 8780'. Clean through float equipment. Drilling 1.7 /1.6 to 1.7 bpm @ 2800 psi. Drill out cement 30-45 fph to 9680'. Make short trip and pump slug of Biozan. Make 9708'. See circ. pressure drop off as Biozan exits bit. Make short trip to 9400'. RIH clean. See cement at 9708'. Continue drilling out cement from 9708'. 1.7 bpm, 2300/3000 psi. 5.5k# wob. 45 fph. Stall motor @ 9712.8'. Reduce rate and pick up. BHA stuck @ 9705'. Pump 5Bbl pill of biozan. Stack weight. Previous pill to surface. Jog pump and work pipe. Pressure up back-side and surge. Order out 15% inhibited HCL, Crude and extra 2% KCL. Pump 20 Bbls crude into coil. Spot 10 Bbls out bit. Work pipe w/o success. Pump 1/2 bpm, work pipe...Free in the up motion pulling 20k# over pickup weight of 30k#. Consult with town team. Circulating KCL at 1.7 bpm 2300 psi. Run back into hole and confirm motor work. POH for bi-directional jars. Release Acidizing equipment. Acid will be used by Wells group 2/14/02 on well 14-40. Pull out of hole to pick up jars and a new motor. Circulate crude to green tank. Break off Injector and stand aside. PJSM regarding standing back CSH. Prepare floor for standing back CSH. Take on 200Bbls 2% KCL. Pull CSH. Change out motor and add jars to BHA. Mill is cored out. Slow ROP was likely due to mill condition. PU hydril tubing. RIH to 9,447'. Printed: 2/20/2002 11 :26:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/13/2002 2/14/2002 Date (" ( BP EXPLORATION Operations Summary Report A-01 A-01 A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 22:00 - 22:30 From - To Hours Activity Code NPT 22:30 - 22:45 22:45 - 23:15 23:15 - 00:00 00:00 - 03:00 03:00 - 06:00 06:00 - 06:15 06:15 - 07:00 07:00 - 07:30 07:30 - 08:25 08:25 - 08:50 08:50 - 09:00 09:00 - 09:45 09:45 - 09:55 09:55 - 13:00 13:00 - 13:05 13:05 -14:00 0.50 CLEAN P 0.25 CLEAN N 0.50 CLEAN N Phase COMP STUC COMP CEMT COMP 0.75 CLEAN P 3.00 CLEAN P 3.00 CLEAN P 0.25 CLEAN P 0.75 CLEAN P 0.50 CLEAN N 0.92 CLEAN P COMP COMP COMP COMP COMP DFAL COMP COMP 0.42 CLEAN P 0.17 CLEAN P 0.75 CLEAN P 0.17 RIGD P 3.08 RIGD P 0.08 RIGD 0.92 RIGD P COMP COMP COMP COMP COMP COMP COMP Page 7 of 7 Start: 1/8/2002 Rig Release: 2/14/2002 Rig Number: Spud Date: 11/3/1971 End: 2/14/2002 Description of Operations Mill through float equipment. 3400 psi @ 1.6 bpm 2550 psi FS RIH to 9712' tag up. Drill @ 9,712' with 1.6 bpm and 2460 psi. 2080 psi FS. Drill to 9,730'. RIH from 9,730' to 9,738' (@ 2,180 psi 1.6 bpm. ROP increased f/30 to 100 ftlhr). Drill from 9,738' to 9,798' (@ 2,580 psi.1.6/1.6 bpm. 50-100ftlhr) RIH from 9,798' to 9,937' ROP 800 ftlhr 2200 psi. 1.6/1.6 bpm. RIH from 9,937' to 10,134' ctm ROP 1350 ftlhr TO! Circulate liner out with 2% KCL. Drop 1/2" circulation sub ball. POH to CS Hydril. LD CS Hydril tubing. PJSM crew change. Lay down milling BHA. Do not find 1/2" ball. Make up stinger and 2.5" nozzle. Circulate 3.5 BPM. Recover 1/2" ball. RIH with nozzle to 2000' for freeze protection. Lay in SO/50 Methanol water from 2000' and 100% methanol from 200'. Rig up N2 unit. PJSM prior to N2 pumping. Pump N2 to purge coil. Blow down reel to tiger tank. PJSM for injector storage. Clean out pits and tanks. Remove injector gooseneck and coil. Set injector in pipe bin. PJSM for ND Nipple down BOP. Nipple up and pressure test tree cap. Rig Released at 13:00 2/14/2002 Printed: 2/20/2002 11:26:35 AM , AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well A-1 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,700.00' MD Window / Kickoff Survey 8,725.00' MD Projected Survey: 10,125.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) .;J I~. a6/-~ a'l~ 22-Feb-02 RECEIVED F [3 ? ~-: 2002 Alaska 0;1 & Gas Cons. Commission Anchorage DEFINITIVE North Slope Alaska BPXA PBU _WOA A Pad, Slot A-O1 A-O1 A Job No. AKMW22021~ Surveyed: 11 February~ 2002 -, SURVEY REPORT 21 February, 2002 Your Ref: API 500292079801 Surface Coordinates: 5948146.10 N~ 654469.90 E (70015' 54.8261" N~ 148045' 03.6297" W) Kelly Bushing: 66.40ft above Mean Sea Level ,..-- 0 sp e.."y-su I! DRILLING SeRVI CESS A Halliburton Company Survey Ref: 5vy11110 ,~::f[j;~, ,c, ;#fi)Jøe Sperry-Sun Drilling ServÎëés' Survey Report for A-01A Your Ref: AP/500292079801 Job No. AKMW22021, Surveyed: 11 February, 2002 BPXA North Slope Alaska PBU WOA A Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 8700.00 3.330 160.000 8632.00 8698.40 88.33 S 31.37 W 5948057.15 N 654440.35 E 23.54 Tie On Point --, MWD Magnetic 8725.00 3.330 160.000 8656.96 8723.36 89.69 S 30.87 W 5948055.79 N 654440.87 E 0.000 24.72 Window Point 8738.00 3.790 114.080 8669.93 8736.33 90.22 S 30.35 W 5948055.27 N 654441.40 E 21.600 25.45 8768.00 14.440 90.500 8699.52 8765.92 90.66 S 25.69 W 5948054.93 N 654446.07 E 36.895 29.55 8823.69 34.010 95.110 8750.06 8816.46 92.12 S 3.01 W 5948053.93 N 654468.77 E 35.279 49.15 8877.87 55.110 97.920 8788.45 8854.85 96.58 S 34.52 E 5948050.24 N 654506.39 E 39.106 82.73 8920.84 71.980 101.260 8807.53 8873.93 103.05 S 72.29 E 5948044.55 N 654544.29 E 39.864 117.64 8951.72 83.890 99.380 8813.98 8880.38 108.44 S 101.95 E 5948039.77 N 654574.05 E 39.024 145.22 8983.40 91.540 102.150 8815.24 8881.64 114.35 S 133.02 E 5948034.50 N 654605.23 E 25.677 174.26 9015.29 91.540 105.150 8814.38 8880.78 121.87 S 163.99 E 5948027.62 N 654636.36 E 9.404 204.12 9052.12 93.040 1 07.260 8812.91 8879.31 132.14 S 199.33 E 5948018.07 N 654671.89 E 7.025 239.14 9085.60 94.010 110.610 8810.85 8877.25 142.98 S 230.93 E 5948007.88 N 654703.71 E 10.399 271.39 9118.79 96.480 111.140 8807.82 8874.22 154.76 S 261.81 E 5947996.74 N 654734.83 E 7.610 303.56 9154.17. ~7.090 114.840 8803.63 8870.03 168.48 S 294.15 E 5947983.69 N 654767.44 E 10.527 338.03 9187.17 97.270 116.600 8799.51 8865.91 182.68 S 323.65 E 5947970.09 N 654797.22 E 5.320 370.42 9220.32 97.970 121.180 8795.11 8861.51 198.55 S 352.41 E 5947954.82 N 654826.30 E 13.856 403.13 9256.87 97.710 122.950 8790.13 8856.53 217.77 S 383.09 E 5947936.23 N 654857.37 E 4.850 439.31 ~, 9289.47 96.920 127.700 8785.97 8852.37 236.47 S 409.46 E 5947918.08 N 654884.12 E 14.654 471.63 9320.62 96.560 131.050 8782.32 8848.72 256.09 S 433.37 E 5947898.95 N 654908.43 E 10.742 502.43 9359.17 95.590 134.050 8778.23 8844.63 282.01 S 461.61 E 5947873.62 N 654937.19 E 8.137 540.34 9390.00 94.100 136.510 8775.63 8842.03 303.83 S 483.22 E 5947852.24 N 654959.25 E 9.304 570.48 9423.47 94.360 138.450 8773.16 8839.56 328.43 S 505.78 E 5947828.11 N 654982.31 E 5.832 602.95 9467.60 94.360 140.920 8769.81 8836.21 361.98 S 534.24 E 5947795.15 N 655011.45 E 5.581 645.33 9502.77 94.800 144.620 8767.00 8833.40 389.89 S 555.45 E 5947767.68 N 655033.23 E 10.561 678.54 9533.95 95.330 147.440 8764.24 8830.64 415.65S 572.80 E 5947742.29 N 655051.11 E 9.168 707.34 9565.79 95.590 150.790 8761.21 8827.61 442.84 S 589.07 E 5947715.43 N 655067.93 E 10.505 736.06 9616.20 96.040 154.660 8756.10 8822.50 487.41 S 612.05 E 5947671.35 N 655091.82 E 7.690 780.07 9659.54 95.330 156.600 8751.81 8818.21 526.69 S 629.84 E 5947632.44 N 655110.41 E 4.746 816.83 9713.79 94.890 160.300 8746.98 8813.38 576.94 S 649.69 E 5947582.61 N 655131.28 E 6.841 861.43 9743.40 91.630 161.360 8745.29 8811.69 604.86 S 659.39 E 5947554.89 N 655141.56E 11.575 885.12 21 February, 2002 - 15:53 Page 2 of 4 DrillQuest 2.00.08.005 tr< , - , - Sperry~Sun Drilling ServIces Survey Report for A-01A Your Ref: API 500292079801 Job No. AKMW22021, Surveyed: 11 February, 2002 . BPXA North Slope Alaska PBU WOA A Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9772.15 88.900 164.000 8745.16 8811.56 632.30 S 667.95 E 5947527.63 N 655150.68 E 13.209 907.59 .--¿. 9810.00 86.430 162.060 8746.70 8813.10 668.4 7 S 678.99 E 5947491.70 N 655162.45 E 8.295 937.01 9844.57 85.460 165.060 8749.15 8815.55 701.54 S 688.74 E 5947458.84 N 655172.89 E 9.100 963.63 9875.15 85.110 165.240 8751.66 8818.06 731.00 S 696.56 E 5947429.55 N 655181.30 E 1.286 986.61 9905.15 84.410 167.700 8754.40 8820.80 760.04 S 703.54 E 5947400.65 N 655188.89 E 8.493 1008.68 9949.54 84.850 172.640 8758.56 8824.96 803.57 S 711.09 E 5947357.29 N 655197.32 E 11 .124 1039.34 9985.45 85.730 174.220 8761.51 8827.91 839.12 S 715.18E 5947321.82 N 655202.14 E 5.023 1062.66 10022.25 87.220 173.870 8763.77 8830.17 875.65 S 718.99 E 5947285.38 N 655206.70 E 4.159 1086.29 10057.32 89.430 179.330 8764.80 8831 .20 910.63 S 721.07 E 5947250.45 N 655209.50 E 16.789 1107.62 10125.00 89.430 179.330 8765.4 7 8831.87 978.30 S 721.86 E 5947182.81 N 655211.68 E 0.000 1146.22 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Decli':lation at Surface is 26.37f?0 (07-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 124.100° (True). A."?~, Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0125.00ft., The Bottom Hole Displacement is 1215.80ft., in the Direction of 143.578° (True). 21 February, 2002 - 15:53 Page 3 of 4 DríllQuest 2.00.08.005 North Slope Alaska Comments Measured Depth (ft) 8700.00 8725.00 10125.00 . ."., Sperry-Sun Drilling ServIces Survey Report for A-01A Your Ref: API 500292079801 Job No. AKMW22021, Surveyed: 11 February, 2002 . 88.33 S 89.69 S 978.30 S Survey tool program for A-01 A BPXA PBU WOA A Pad Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8698.40 8723.36 8831.87 From Measured Vertical Depth Depth (ft) (ft) 0.00 ' 8700.00 0.00 8698.40 To Measured Vertical Depth Depth (ft) (ft) 8700.00 10125.00 8698.40 8831.87 Comment ,""""~, 31.37 W 30.87 W 721.86 E Tie On Point Window Point Projected Survey Survey Tool Description AK-1 BP _HG - BP High Accuracy Gyro (A-01) MWD Magnetic (A-01A) -" 21 February, 2002 - 15:53 DrillQuest 2.00.08.005 Page 4 of 4 ¡ ( ~1r~1rŒ (ID~ fÆ~fÆ~[ßfÆ (, ALAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 M. S. Endacott . ,CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit A-01A BP Exploration (Alaska) Inc Permit No: 201-242 Sur Loc: 2300' SNL, 922' WEL, SEC. 35, T11N, R13E, UM Btmhole Loc: 2978' SNL, 123' WEL, SEC. 35, T11N, R13E, UM Dear Ms. Endacott: 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. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit A-01A. 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. Sincerely, ( ~Akl"ý-'~ C~; ~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 18th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA ( STATE OF ALASKA - AND GAS CONSERVATION COMM( PERMIT TO DRILL 20 AAC 25.005 ION n y{lv\, , -)\ ~')í)i 124\0 ~)"I' . ~ 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic ]Þst Grbevelopment Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas r:¡¡iSingle Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 66.40' Prudhoe Bay Field 1 Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028286 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2300' SNL, 922' WEL, SEC. 35, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2395' SNL, 950' WEL, SEC. 35, T11 N, R13E, UM A-01 A Number 2S1 00302630-277 At total depth 9. Approximate spud date 2978' SNL, 123' WEL, SEC. 35, T11N, R13E, UM 02/01/02 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047472,2300' MD No Close Approach 2560 9868' MD 1 8752' TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8725' MD Maximum Hole Angle 94 Maximum surface 2184 psig, At total depth (TVD) 8800' 1 3240 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement (ize Tco Bottom Hole Casino Weicht Grade CouDlina Lenath MD TVD MD TVD linclude staae data) 3-3/4" 3-3/16" x 2-7/8" 6.2# / 6.5# L-80 ST-L 1948' 7920' 7919' 9868' 8752' 167 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9270 feet Plugs (measured) Sandback with Cement Cap at 8880' (06/00) true vertical 9268 feet Effective depth: measured 8880 feet Junk (measured) 1/2 Bullnosed rubber and 3 wire grab prongs at 9198' true vertical 8878 feet Casing Length Size Cemented MD TVD Structural Conductor 89' 30" 200 sx Permafrost II 891 89' Surface 2315' 20" x 18-5/8" 6250 sx Permafrost II 2315' 2315' Intermediate 8421' 13-3/8" x 9-518" 1500 sx Class 'G', 450 sx PF II 8421' 8420' Production Liner 1354' 7" 345 sx Class 'G' 7906' - 9260' 7905' - 9258' RECEIVED Perforation depth: measured Open: 8720' - 8740', 8820' - 8870' DEC 1 4; 2001 Sqzd: 8718' - 8720', 8870' - 8873', 8878' - 9023' true vertical Open: 8718' - 8738" 8818' - 8868' Alaska 011 & Gas Cons. Commissìon Sqzd: 8716' - 8718', 8868' - 8871', 8876' - 9021' Anchorage 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the ~ing It¡:rJ;d ~ to thl!')lest ~my knowledge I 2, /41 ó ¡ Signed M.S. Endacott tv.... l-,-~11/ '!l ~ -ðtA Title CT Drilling Engineer Date ",'.,;":., , .'.."" :'. ,.,.,:"'""",.,"""'",.".",:",..",.!",,~,'."".".':"""""""""fll..,,:,:',:';',:,,':\,..:',,,:::,('":."."~,.,¡,:,.,,,,;,,':~:,:,'i!:ØÞ~:ro:i:~$iQQ:~~'~8~ ,I." ,""!,,,' ",:",',,':1,:':',' ,',',,'1' 'II ""',, ".,II~l'lr,"" ""',,, I",", "", ..," ," ,.' ,', ',".": ',' '..: '","'... ,'.'i' ..'"",, I'" ,:".'" ' , """ , '"", "','", ,"" "':"', "/:';-"'.I'"','I"'"',,I"( .'"1:,/'1;",',,,.,",';:.':"':,;,::."",' ",', Permit Number y 2 API Number APpr/,-~X' /C I See cover letter 2-L ~ I oi" 2... . 50- 029-20108-01 for other reauirements ,/ - Conditions of Approval: Samples Required 0 Yes SNo Mud Log Requifed' 0 Yes ,$"No Hydrogen Sulfide Measures )QVes ONo Directional Survey Required ~es 0 No 1rrrt Required Working Pressure for BOPE 02K 03K 04K 05K 010K 0 15K ~.5K psi for CT OthOnginai Signed By by order of !-J../~f'} ;i; / Cammy Oechsli Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 SutJmit In íri licate ORIGINA L p ( ( :( BPX A-01 A Sidetrack Summary of Operations: A CTO sidetrack of well A-01 A will be drilled. Specific prep work, (Phase 1), and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. the perforations below the whipstock. Planned for January 15, 2002 . Drift tubing and liner, and run a caliper across the liner at the proposed whipstock setting depth. . Liquid pack and Integrity test IA. . Set through tubing whipstock using coil at approx. 8,725' MD (8,723' TVDss). . Squeeze the perforations 8720' -8855' with approximately 10 barrels of cement. . Mill window with service coil if available. Squeeze Phase 2: Drill and Complete CTD sidetrack: Planned for February 1, 2002 2-3/8" coil will be used to drill a -1 ,150 foot, 3-3,4" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3-3/16" x 2-7/8" liner completion. Mud Program: . Phase 1: Seawater . Phase 2: Flo-Pro (8.6 - 8.7 ppg) andlor 3% KCI water. Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . A combination 3-3/16" x 2-7/8" , L-80, solid liner will be run from approximately 7,920' md (7919' TVDss) to TO at approx 9,868'md. Liner will be cemented in place with approximately 34 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2200 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray and resistivity log will be run over the open hole section. . A memory CNL may be run inside the liner. Hazards The H2S concentration for A-01 was recorded in January 2001 at 30 ppm. However, an H2S level of 80 ppm was recorded from this well in 1998. The proposed well-path will cross 1 mapped fault. The risk of lost circulation from the fault is considered to be low because it's orientation is perpendicular to the prevailing maximum principle stress direction. Further, the fault will be crossed by the proposed wellbore perpendicular to its orientation. Reservoir Pressure Res. pressure is estimated to be 3240 psi at 8800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2184 psi. ," .. TREE = 4" Cameron WaLHEAD= McEvoy ACTUATOR= Baker KB. B..EV = 66.4' BF. B..EV = 47.4' KOP= 766' Max Angle = 3 @ 8400' Datum MD = 8868' Datum lVD= 8800'SS 118-5/8" CSG, 96.5#, K-55. [) = 17.755" I 1474' I TOP OF 9-5/8" CSG I 2255' 20" CSG, 133#, K-55, ID = 18.730" 2315' Minimum ID = 3.725" @ 7949' SWS NIPPLE I TOP OF 7" LNR I 7906' I 4-1/2" TBG, 12.6#, 13 CR, TDS, ID = 3.958" I 7972' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8421' PERFORA TION SUMMARY REF LOG: BHCS ON 11/24/71 Run 4c ANGLE AT TOP PERF: 3 @ 8718' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 33/8 8 8718' - 8720' S 04/12/91 33/8 6 8720' - 8740' 0 08/18/91 33/8 -10 8824' - 8870' 0 08/04/91 4 8870' - 8873' S 04/12/91 4 8878' - 8932' S 04/12/91 4 8942' - 8968' S 04/12/91 4 8978' - 8992' S 04/12/91 4 8997' - 9004' S 04/12/91 4 9013' - 9023' S 04/12/91 3-3/8" 6 8820' - 8836' 0 01/22/01 3-3/8" 6 8840' - 8855' 0 02/22/01 7" LNR, 29#, L-80, SEAL LOCK, .0371 bpf, ID = 6.184" 9260' A-O1 (8 ( WARNING: RADIO TRANSMITTER IN WEATHER SHACK MUST BE TURNED OFF BEFORE USING EXPLOSIVES 1474' --i 20" X 18-5/8" X-OV ER ---i OTIS SSSV LANDING NIPPLE, 10 = 3.813" I 9-5/8" BTRS XNSC X-OV ER SCREWED ON DURING '88 RWO 2021' 2255' GAS LIFT MANDRELS STA MD lVD DEV TYPE MAN LATCH 4 3186 3120 1 OTIS-LBD RA 3 5856 5790 1 OTIS-LBO RA 2 7586 7520 1 OllS-LBD RA 1 7730 7664 1 OTIS-LBO RA 9198' DATE REVBY COMMENTS DATE REV BY COMMENTS ####### ORIGINA L COMA.. ETlON 1Hf;¡U II ¡¡H WORKOVER 01/03/01 SIS-MD 2ND REVISION 03/26/01 RN/TP CORRECTIONS 7835' 7847' 7899' 7949' 7972' I 7976' ., 4-1/2" "SWS" NIPPLE (PARKER), ID = 3.813" I "95/8" TIN PACKER(HBBP), ID = 4.0"; TIW LATCH I -i 4-1/2""SWS"NPR..E(PARKER),ID=3.813" I ---i 4-1/2" "SWN" NPR..E (PARKER), ID = 3.725" I ---I 41/2" TaG TAIL PARKER WLEG, ID = 3.99" I l---i B..MD- TT - LOGGED 8/4/91 I 8880' WL ---I TOC - Sandback w /Cmt Cap 5/13/00; Recap 6/14/00 I 1/2 BULLNOSED RUBBER & 3 WIREGRAB PRONGS PRUDHOE BA Y UNIT WB..L: A-01 ÆRMIT No: 171-027 API No: 50-029-20108-00 Sec.35,T11N,R13E BP Exploration (Alaska) 1 I '\I..>- - .. Vel II It:: I 011 W8.LHEAD= McEvoy 'ACTUÄTÓ~' '-- '-"'Baker . tŒi:1ii:ÿ';'-"""""""S6.4; ""-"--'-......,,- "".,......--..-.-..-, BF. B.EV = 47.4' '---'-""""""-""'" """""""---' KOP = 766' ""-""""'--""-"" ... -....-.--,.-.. Max Angle = 3 @ 8400' -------...---.., """-"..--...--..-..- Datum M) = 8868' ------.-.--...",.. """"-"-"--"'" Datum TVD= 8800' SS 18-5/8" CSG, 96.5#, K-55. ID = 17.755" ( ~1 a Proposed Completion 1474' TOP OF 9-5/8" CSG 2255' 20" CSG, 133#, K-55, 10 = 18.730" 2315' Minimum ID = 3.725" @ 7949' SWS NIPPLE TOP OF 7" LNR 7906' I 4-112" TBG, 12.6#, 13 CR, TDS, 10 = 3.958" I 7972' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8421' PERFORA TION SUMMARY REF LOG: BHCS ON 11/24/71 Run 4c ANGLEATTOPÆRF: 3@8718' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 33/8 8 8718' - 8720' S 04/12/91 33/8 6 8720' - 8740' 0 08/18/91 33/8 -10 8824' - 8870' 0 08/04/91 4 8870' - 8873' S 04/12/91 4 8878' - 8932' S 04/12/91 4 8942' - 8968' S 04/12/91 4 8978' - 8992' S 04/12/91 4 8997' - 9004' S 04/12/91 4 9013' - 9023' S 04/12/91 3-3/8" 6 8820' - 8836' 0 01/22/01 3-3/8" 6 8840' - 8855' 0 02/22/01 7" LNR, 29#, L-80, SEAL LOCK, .0371 bpf, Ð = 6.184" 8 STA 4 3 2 1 7835' 7847' 7899' 7949' 7972' I 7976' (' WARNING: RADIO TRANSMITTER IN WEATHER SHACK MUST BE TURNED OFF BEFORE USING EXPLOSIVES 1474' --i 20. X 18-5/8" X-OVER ] 2021' 9-5/8" BTRS XNSC X-OVER SCREWED ON DURING '88 ~O OTIS SSSV LANDING NIPPlE, D = 3.813" 2255' GAS LIFT MANDR8.S MD TVD DEV TYÆ MAN LA TŒi 3186 3120 1 OTlS-LBD RA 5856 5790 1 OTIS-LBO RA 7586 7520 1 OTlS-LBD RA 7730 7664 1 OTlS-LBD RA 4-112" "SWS. Nm..E (PARKER), D = 3.813" 9 5/8" TIN PACKER(HBBp), ID = 4.0"; TIN LATCH --i 4-1/2" .SWS. NIPPLE (PARKER), D = 3.813" I --i 4-1/2" "SWN" NIPPLE (PARKER), ID = 3.725" ---i 4 1/2" TBG TAIL PARKER WLEG, ID = 3.99" l--i B.MD- IT - LOGGED 8/4/91 I xxx XXX XXX XXX XXX XXX Whipstock to be set at approx. 87251 Perfs to be sqz'ed past whipstock 8880' WL --i TOC.. Sandback w /Ort Cap 5/13/00; Recap 6/14/00 9260' 9198' DATE REVBY COMMelTS DATE REV BY COMMENTS iff /If iUi II n ORIGINAL COMR..ETION tI If iW l! iUf WORKOV ER 01/03101 SIS-MD 2ND REVISION 03/26/01 RNITP CORRECTIONS ---i 1/2 BULLNOSED RUBBER & 3 WIREGRAB PRONGS PRUDHOE BA Y UNrr WELL: A-01 ÆRMrrNo: 171-027 API No: 50-029-20108-00 Sec.35,T11N,R13E BP exploration (Alaska) -.---.-------,------...----..,------ -----,. ,-----------..,--------.-..--- -- Vertical Section 0 8550 z-8800 Q) Q) LL. - c ~8850 8600 8650 8700 8750 8900 8950 9000 9050 9100 500 Angle @ K.O... 3 deg MD:8725 A-O1 Path Distance (Feet) 1 ,000 rei MS 1,500 2,000 -TSGR . TSAD 87 SO .; -~.~-~._~--~---8,805 . ,~-- ...'--- ./ // A-01a case 102 Nov. 6 Tot 0r1d:1143 ft 9868 TO Marker Depths fX)rIg Wellbore TSGR I 8,6491ft TVD I 8,750ft TVD 8,8051 8,805 1ft TVD 1 TSAD 8750 0 Olft TVD Kick Off 8,657 ft TVD 8,725 ft MD Deprtr @KO 110 ft -." I I MD KO Pt MD New Hole 8,725 1143 Total MD TVD TO 9,868 8,752 DLS deg/100 Tool Face Length ~- Curve 1 6 0 20 Curve 2 40 -21 238 Curve 3 10 90 160 Curve 4 10 90 335 Curve 5 10 -90 390 , , , 43 ,- ----., '.._---, --..,., .---. _._-----,------,-,-----_.._---,------------,. A-O1 .9 ~ (J) E .g Q) u r::: œ ~ .!!l "0 >- 0 fault A-O 1 a Case 102 Nov. 6, 2001 Ted x4694 1 ,000 T i ! I I I I I 500 t I I I I I I I I O..!- ! I I -500 I I I 1,000 l -500 0 X distance from Sfc loc 500 -,---- 1,000 'wen Name A-a 1 I CLOSURE I Distance 1,047 ft I Az 129 de~ NEW HOlE E/W (X) N/S (Y) Kick Off -29 -90 TO 812 -662 State Plane 655,283 5,947,485 Surface Loc 654,471 5,948,147 -, DLS deg/l00 Tool Face Length Curve 1 6 0 20 Curve 2 40 -21 238 Curve 3 10 90 160 Curve 4 10 90 335 Curve 5 10 -90 390 1 ,143 -. Drawn: 11/6/2001 8:53 Case 122 Plan Name: Well A-O1 A (' BOP-Tree ( Rig Floor Lubricator 10 = 6.375" with 6" Otis UnIOns ......... c:Iftilt~.:::~:: ~ ' , , , 17 1/16' 5000 psi BOP's. 10 = 7.06" , ... l:t:Mi~f:~@::timBX~~:~;:::::::H::~ I ... 11/4 Turn L T VaJve , 13" 5000 psi I 12 '1/16w ~ psi, RX-24 , 7'1/16°,6000 psi (RX-46) or ' 41/16',5000 psi (RX-39) Swab Valve , SSV , Master Valve , :-~:-., :- .:-: .'k"............. .,,", ""', .'. ..:-::,:-:, ~:~:~~,"=-::;.~.:.~~~ :.':-: :.:.,;::\~:~t:.~..>,::..~ . .:-.}.:::::;:t:..U(...;~:::::~-::~ '. .~~'rvr:{:::-"::-'f.L~L : ... ., ':-:-' ':-m. »,,-, m .. . )~>i~:f~;:';/: . .~/S::..~.:Y:'.;;;:'~ ; . ..'. ,.'.. ...,... Base Flanve ~ Page 1 / ",/' i / ./ { ~: ~ .'-. , " ..! -""-, ,( "" /" // H 198755 ro DASmJi 9/2 ~NO I 755 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 092701 CKO92701S PYMT OMMENT5: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terri Hubb e X4628 FJ - (JI A- RECEIVED DEC 1 2001 Alaska Oil & Gas C s. Commission Anchor " TOTAL ~ 100.00 100.00 HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 198755 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 ~ 00198755 PAY ONE HUNDRED 8c OO/100************************~************ US DOLLAR DATE. 09/28/01 II AMOUNT $100., To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOTVALID AFTER 120 DAYS AK 99501 \2. ...~- 0"'.,-'" . ,'" . ~ \~ , "', ~ßr~"iL{_.- III ¡. g B 7 5 5 III I: 0'" ¡. 2 0 :ì B g 5 I: 0 0 B ...... ¡. g III ¡' ~, ,í ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME fð¿j A - 0//1 CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONSY MULTI LATERAL (If api number last two (2) digits are between 60-69) :~iM¡ PILOT HOLE (PH) EXPLORATION / ANNULAR DI~OSAL ( , Á NO V INJECTION WELL ANNULAR DISPOSAL <--> YES INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well , Permit No, . API No. . . Production should continue to be reported as a function of the original API number stated above. ' In accordance with 2.0 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. .. . ANNULUS L-) YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to periorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume tbe liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION COMPANY PROGRAM: exp ~ INIT CLASS GEOL AREA 1.Permitfeeattached....................... N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . ,; N 12. Permit can. be issued without administrative approval.. . . . . ,N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided . . . . . . . . .. . . . . . . . . . Y ~ . 15. Surface casing protects all known USDWs. . . . . . . . . .. AJtl V-N R.lcln /( ~ ¿f-/~-:f;~ t:<.l-iYr ~ 16. CMT vol adequate to drculate on conductor & suñ csg. . . .. . Y NN' . . 0" ' 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . .'. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N Q$\C;~~ ,,'\. ~ ( ~ö~""t.. ~~~~ t;,\- 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~() \- ~ '-\. ~ "f 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N . 23. If diverter required, does it meet regulations. . . . . . . . . . .¥ - t4 - ~ ~ 24. Drilling .fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . :.-¿.,..,:^. . . . . . N 26. BOPE press rating appropriate; test to 3..> ~.J psig. N . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. . N 28. Work will occur without operation shutdbwn. . . . . . . . . . . . 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . y.~, ~> ~~\.Ð'\>~ . èiJ~ <X \'\~..' ~~ '\~~~'\",~ ~ <:;.ct.~(,~\'~' ü.\ ~: ~:;::,:,:~~~s:e:.,~~~r;:~~~~~e z:~::u.~s.. : : :.' ~ ~- A - D I rlUd4¿- 3D ~ ~S L4C- ~ . Z<'b I. 4~ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . -- tl ~ . . DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . ~ Y N It- ,14.(.,')1 34. Contact name/phone for weekly progress reports {explofátory only] Y N ANNULAR DlSPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " to surface; .' (C) will not impair mechanical integrity pf 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 MC 25.252 or 20 MC 25.412. Y N 1-, GEOLOGY: ENGINEERING:' UIC/Annuiar COMMISSION: ~ \~ w~,§g~z41 ~"l Aj]; DA T~ I ¡Z /'1.0 ENGINEERING !il!Æ; PtTIE~ GEOLOGY APP- APPR DATE Y N Y N c:\msoffice\wordian\diana\checklist (rev. 11/01/100) dev Vredrll serv wellbore seg _ann. disposal para req- UNIT# C) / / ~ ON/OFF SHORE 4 c 0 Z 0 -t :E :tJ l '. - -t m - Z -t .J: - en :Þ ::0 m » ( .~.C\.~,,~\~\. '\~\~'c.::: " ~ ~ ~""CèèJ ~ Com m e ntsllnstructions: i( t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically.,. . organize this category of information. { ( ó? D /-¿;('~ / /4Sc:a Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 18 15:35:17 2002 Reel Header Service name......... ... .LISTPE Date.....................02/12/18 Origin...................STS Reel Name.......... "... . UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/12/18 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA A-1A 500292010801 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 18-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22021 B. JAHN R. WHITLOW / MWD RUN 2 AK-MW-22021 B. JAHN R. WHITLOW / MWD RUN 3 AK-MW-22021 B. JAHN R. WHITLOW / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 llN l3E 2300 922 66.40 47.38 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 8725.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . ( (' 3. THIS WELL WAS SIDETRACKED OFF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT APPROXIMATELY 8725'MD IN THE A-1 WELLBORE. 4. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUN 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. EWR4 DATA FOR THE MWD RUNS 1 AND 2 INTERVALS WERE ACQUIRED ON AN UP PASS AFTER RIH FOR RUN 3, BUT PRIOR DRILLING. THESE DATA WERE MERGED WITH THE EWR4 DATA FROM MWD RUN 3 - NO SEPARATE MAD PASS PRESENTATION IS INCLUDED. AN UNEXPLAINED SGRD DATA GAP (8746'MD - 8771.5'MD WITHIN RUN 2) WAS FILLED-IN WITH DATA FROM THE ABOVE-MENTIONED UP PASS. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 2/19/02. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL A-1A WITH API#: 50-029-20108-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10125'MD / 8765'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX ROP FET $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8534.5 8734.5 8734.5 8734.5 8734.5 8746.0 8746.5 STOP DEPTH 10080.5 10091. 0 10091. 0 10091.0 10091. 0 10125.0 10091. 0 # ( ( BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 MERGE TOP 8534.5 8800.0 8975.0 MERGE BASE 8800.0 8975.0 10125.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction............. ....Down Optical log depth units. ......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8534.5 10125 9329.75 3182 8534.5 10125 ROP MWD FT/H 0.35 3362.29 74.0677 2736 8746 10125 GR MWD API 21.08 873.66 65.126 3093 8534.5 10080.5 RPX MWD OHMM 0.29 2000 50.9836 2714 8734.5 10091 RPS MWD OHMM 0.49 2000 51. 3809 2714 8734.5 10091 RPM MWD OHMM 0.81 2000 44.5033 2714 8734.5 10091 RPD MWD OHMM 0.57 2000 87.9509 2714 8734.5 10091 FET MWD HOUR 0.3 56.84 4.41109 2690 8746.5 10091 First Reading For Entire File......... .8534.5 Last Reading For Entire File...... .... .10125 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record..65535 File Type............. ...LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type............... .LO (' Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 8534.5 8746.0 STOP DEPTH 8703.0 8800.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # , Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order 08-FEB-02 Insite Memory 8800.0 8746.0 8800.0 3.3 3.3 TOOL NUMBER 002 3.750 8725.0 Flo-pro 8.60 60.0 8.1 18000 6.0 .000 .000 .000 .000 .0 124.0 .0 .0 Units Size Nsam Rep Code Offset Channel (' ( DEPT ROP MWD010 GR MWD010 FT FT/H API 4 4 4 1 1 1 68 68 68 0 4 8 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8534.5 8800 8667.25 532 8534.5 8800 ROP MWD010 FT/H 1 38.06 20.0828 109 8746 8800 GR MWD010 API 56.18 102.26 83.353 338 8534.5 8703 First Reading For Entire File......... .8534.5 Last Reading For Entire File.......... .8800 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 8703.5 8800.5 STOP DEPTH 8945.0 8975.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 09-FEB-02 Insite Memory 8975.0 8800.0 8975.0 3.8 83.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ TOOL NUMBER 002 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 8725.0 # (' BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O Flo-Pro 8.62 22.0 8.5 23000 5.8 .000 .000 .000 .000 Name Service Order DEPT ROP MWD020 GR MWD020 units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 8703.5 0.39 22.72 Max 8975 130.12 873.66 First Reading For Entire File......... .8703.5 Last Reading For Entire File.......... .8975 File Trailer Service name. ........... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.003 Mean Nsam 8839.25 544 49.5721 327 112.125 484 ( .0 137.5 .0 .0 First Reading 8703.5 8800.5 8703.5 Last Reading 8975 8975 8945 (' Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 ( header data for each bit run in separate files. 3 .5000 START DEPTH 8734.5 8734.5 8734.5 8734.5 8746.5 8945.5 8975.5 STOP DEPTH 10091.0 10091.0 10091.0 10091.0 10091.0 10080.5 10125.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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..................O Data Specification Block Type.....O Logging Direction.. ............,. . Down optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing... ................, .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 10-FEB-02 Insite 4.3 Memory 10125.0 8975.0 10125.0 84.4 98.0 TOOL NUMBER 72830 125939 3.750 8725.0 Flo-Pro 8.50 .0 9.0 21000 7.6 .110 .050 .210 .120 68.0 155.9 68.0 68.0 (' ( Depth Units..... . . . . . . . . . . . . . . . . .. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8734.5 10125 9429.75 2782 8734.5 10125 ROP MWD030 FT/H 0.35 3362.29 80.1088 2300 8975.5 10125 GR MWD030 API 21.08 194.07 52.3969 2271 8945.5 10080.5 RPX MWD030 OHMM 0.29 2000 50.9836 2714 8734.5 10091 RPS MWD030 OHMM 0.49 2000 51. 3809 2714 8734.5 10091 RPM MWD030 OHMM 0.81 2000 44.5033 2714 8734.5 10091 RPD MWD030 OHMM 0.57 2000 87.9509 2714 8734.5 10091 FET MWD030 HOUR 0.3 56.84 4.41109 2690 8746.5 10091 First Reading For Entire File......... .8734.5 Last Reading For Entire File.......... .10125 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/12/18 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.....................02/12/18 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File