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E N E a 0 N N � � .... ,./ a o E Z � � u = �nn ry n c c Io u a a y Li I f.. a s ° m • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q,~ - Q ~ ~ Well History File Identifier Organizing (done) ^ Two-sided tl I II ~I ~I I~ II I II IIt ^ Rescan Needed II I II~I1~ I~ I I ~I I ~II R CAN DIG AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~, ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~' Q /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ' 30 b !sl Scanning Preparation ~ x 30 = ~~ + ~~~ =TOTAL PAGES ~ v (Count does not include cover sheet) BY: __ Maria Date: I l l ~/°l / A"1 r7' /s/ 1 1 I Production Scanning Stage 7 Page Count from Scanned File: _s~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre/partition: _~ YES _ BY: Maria Date: ~ ~/~~ / Stage ~ If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO NO Y ~ r" iiuiiiiuiiiiim ReScanned BY: Maria Date: /s/ Comments about this file: o~.~,~~~Kea mimmiuiiim 10/6/2005 Wel( History File Cover Page.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, • ~.: ,_ .... ~ _ _ ~ ~~`e~~~~~i~ti aos- o~ c~ i~-3ap Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 1a-o1A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA 14-O6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-OSA 2022100 500292033001 Sealed Conductor NA NA 1a-O9B 1820340 500292053402 Sealed Conductor NA NA 14-to 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 1a-12 1811090 500292063100 Sealed Conductor NA NA 1a-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 1a-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10!20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 ~ STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMM ION REPORT OF S~JNDRY WELL OPERATIONS 1~~ ~~~~ ~~~~ AUG ~ ~ ?~ICJ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ t er ~( ;, , ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time E ~~~~ U~~~` "~ r~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Weil ~ ~"~`~~°~ ;`~~'"' 2. Operator BP Expioration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: tvame: De~elopment ~ Exploratory ~ 205-0940 3. Address: P.O. Box 196612 Stratigraphic r Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20679-01-00 7. KB Elevation (ft): 9. Well Name and Number: 71.8 KB PBU 14-30A 8. Property Designation: 10. Field/Pool(s): ADLO-028314 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12531 feet Plugs (measured) None true vertical 8891.04 feet Junk (measured) None Effective Depth measured 12465 feet true vertical 8902.47 feet Casing Length Size MD TVD Burst Collapse Conductor 76 20" 91.5# H-40 Surface - 76 Surface - 76 1490 470 Surface 2615 13-3/8" 72# N-80 Surface - 2615 Surface - 2611 4930 2670 Production 9885 9-5/8" 47# L-80/SOO-9: Surface - 9885 Surface - 8317 6870 4760 Liner 10520 7" 26# L-80 SurFace - 10520 Surface - 8802 7240 7240 Liner 2169 4-1/2" 12.6# 13cr80 10359 - 12528 8692 - 8892 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 10366' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 10308' PAYZONE EXTERNAL PKR 11941' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ;~, ~ ~-1y~ ~~~~ , (+ ~ rR ~ ~ Yvv L ~ ~t~. N~ 4Ny~ ~~1fEf.f Y.r&.M~ t y,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: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~~ Development r! Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas ~ WAG ~ GINJ r WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/5/2009 ~i:iii ; `~s ~~{~~# SubmitOri inal,Onl Form 10-404 Revised 04/2006 ~~~ ~~~- ~,~~G ` 9 Y ~l3 r!~r ~-~~~s'! 14-30A 205-094 PERF ATTACHMENT n ~..J Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14-30A 8/10/05 PER 10,860. 10,900. 8,914.41 8,913.01 14-30A 8/10/05 PER 11,190. 11,320. 8,899.98 8,898.47 14-30A 8/10/05 PER 11,440. 11,470. 8,898. 8,897.88 14-30A 8/10/05 PER 11,720. 11,730. 8,910.27 8,911.13 14-30A 8/10/05 PER 11,800. 11,840. 8,916.99 8,920.69 14-30A 8/10/05 PER 12,290. 12,310. 8,929.97 8,927.07 14-30A 8/10/05 PER 12,410. 12,430. 8,911.58 8,908.32 14-30A 7/30109 APF 10,526. 10,546. 8,805.71 8,818.28 14-30A 7/30/09 APF 10,708. 10,732, 8,893.17 8,899.99 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 14-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/30/2009~*** WELL SHUT-IN ON ARRIVAL"'"'" (E-LINE ADPERF) ~INITIAL T/I/O/O: 250/1400/0/0 ;SSV=O, MV=O, WV=C, SV=C, IA/OA=OTG ;DEPTHS REFERENCED TO PER SPERRY SUN MWD GR DATED 24-JULY ;TO 3-AUG-2005 ~3.375 GUN DIAMETER 6.00 SHOT DENSITY 60 SHOT PHASE PERFORATE INTERVALS 10708'-10732' AND 10531'-10551'. ;RAN GR/CCL FOR TIE-IN LOG (JEWELRY LOG) ~ ;UCI" 1 I'IJ KCrCKCIVIiCU I V I IC-IIV LVI~ VVCKC 1'KVIVI:_ 10708'-10732' AND 10526'-10546' WITH 3-3/8" HSD PJ HMX 3406 FINAL T/I/O/0 = 600/1350/0/0 ;SSV=O, MV=C, WV=C, SW=C, IA/OA=OTG 'WELL SHUT-IN ON DEPARTURE, DSO NOTIFIED ;*"*JOB COMPLETE"** FLUIDS PUMPED BBLS 1 diesel 2 METH 3 Total STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~.~~~IVI~ ~,~ ~~~ ~ ~ ~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~, ~~~~r~,~ ~yaS ~Uil5.~R1wS Performed: Alter Casing ~ Puli Tubing ~ PerForate New Pool ~ Waiver~ Time Extension ~ ~6iC~R~~'~~£" Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~lopment r- Exploratory ~~ 205-0940 - 3. Address: P.O, Box 196612 Stf'atigf'aphlC r Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20679-01-00° 7. KB Elevation (ft): 9. Weil Name and Number: 71.8 KB - PBU 14-30A . 8. Property Designation: 10. Field/Pool(s): ADLO-028314 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12531 - feet Plugs (measured) None true vertical 8891.04- feet Junk (measured) None Effective Depth measured 12465 - feet true vertical 8902.47 , feet Casing Length $ize MD TVD Burst _,, ,r, Collapse _ . ,...... Conductor 110 20" 91.5# H-40 Surface - 76 Surface - 76 ~~ ~ 9490 470 Surface 2615 13-3/8" 72# N-80 Surface - 2615 Surface - 2611 5380 2670 Production 9885 9-5/8" 47# I-80/soo-95 Surface - 9885 Surface - 8317 6870 4760 Liner 10520 7" 26# L-80 24 - 10520 24 - 88Q2 7240 5410 Liner 1989 4-1/2" 12.6# 13CR80 10359 - 12528 8692 - 8892 8430 7500 ~,'` ~r~~~~~: ,~~.li~ s= t~ ~DO~` ~ x Perforation depth: Measured depth: SEE ATTACHED - _ _ " ' _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-8 SURFACE - 10366' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 10308' EXT CSG PKR 11941' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 49 1360 1268 294 Subsequent to operation: 226 2091 6408 262 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Dev~elopment ~- Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas ~ WAG 1- GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature ,,;a Phone 564-4944 Date 7/10/2009 tQt1 Form 10-404 evised 04/2006 ' "° ~, ~~„ ,i~~ j~ Z~~9 r Submit Ori mal Only ~,~.. ~~~,~~r~ 14-30A 205-094 PFRF ATTAC_HMFNT • Sw Name Operation Date PerF Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14-30A 8/10/05 PER 10,860. 10,900. 8,914.41 8,913.01 14-30A 8/10/05 PER 11,190. 11,320. 8,899.98 8,898.47 14-30A 8/10/05 PER 11,440. 11,470. 8,898. 8,897.88 14-30A 8/10/05 PER 11,720. 11,730. 8,910.27 8,911.13 14-30A 8/10/05 PER 11,800. 11,840. 8,916.99 8,920.69 14-30A 8/10/05 PER 12,290. 12,310. 8,929.97 8,927.07 14-30A 8/10/05 PER 12,410. 12,430. 8,911.58 8,908.32 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 • ~ ~ 14-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 15 METH 76 15% HCL ACID 91 Total 11 !05/07 5chlumb~rger NO. 4360 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C Well .Inh it Inn tlacrrinfinn 1~~4n RI Cnlnr Cn S-400A 11855508 USIT (REVISED) ~ 09/18/07 1 C-30 11695080 LDL 10/16!07 1 Z-22B 11594525 SBHP SURVEY - 10/06/07 1 14-31 11890316 LDL 10/18107 1 NK-22A 11855822 DRIFT TDILDL (- 10/25/07 1 MPG-07 N/A CORRELATION/DDL C_ 09/08/07 1 MPG-07 11628799 MEM INJ PROFILE C, 10/20/07 1 MPF-10 11767140 MEM INJ PROFILE U= - 09/15/07 1 MPS-05 11745237 MEM PPROF SUPPLEMENT LOG -' 3'~ 10/09/07 1 P2-19A 11649963 _ MCNL ~ ~ {~~ -~ 04/22/07 1 1 OWDW-SW 11221548 RST ~ 03/05/06 1 1 W-17A 11588701 MCNL _ ~ zl 12/26/06 1 1 14-30A 11485775 MCNL --(5 O 11/22/06 1 1 L-51 40013624 OH MWD/LWD EDIT 06/26/06 2 1 PLtASt AI:KNUWLtDGt KtGE1PT BY SIGNING AND RETURNING ONE DOPY EACH TO: ~ ~~~ , BP Exploration (Alaska) Inc. ~ -~ ya Petrotechnical Data Center LR2-1 r --~ ~ ~" 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~~qF ~1 ~~ ,~~~-~ "v ar ,_, , Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ' ATTN Beth ~ Received by: • • ~Y ~ ,~ ~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050940 Well Name/No. PRUDHOE BAY UNIT 14-30A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20679-01-00 MD 12531 TVD 8891 Completion Date 8/12!2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey (Yes ~ ~'~~ DATA INFORMATION Types Electric or Other Log s Run: (data taken fro m Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 9800 12531 Open 9/7/2005 IIFR ~D D Asc Directional Survey 9800 12531 Open 9/7/2005 MWD , I~t 13930 LIS Verification 1-3 9885 12531 Open 6/8/2006 ;,f=`6 D Lis 13930 LIS Verification 1-3 9885 12531 Open 6/8/2006 GR EWR4 ABI ROP PWD ~og Cement Evaluation 2 Col 1 10400 12430 Case 12/13/2006 SCMT, GR, CCL, CBL, VDL 22-Nov-2006 g Production 2 Blu 1 10750 12400 Case 12/13/2006 Mem PPL, GR, CCL, Pres, Temp, Gradio, Spin, Deft 21-Nov-2006 ~D C Las 14450 '1"nduction/Resistivity 9595 12545 Open 1/29/2007 LIS Veri, GR, ROP, FET i, w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /' Daily History Received? Chips Received? ~--~-+id-"^ Formation Tops Q~ N Analysis `Y-tid--"" Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050940 Well Name/No. PRUDHOE BAY UNIT 14-30A Operator BP EXPLORATION (ALASKA) INC MD 12531 TVD 8891 Completion Date 8/12/2005 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-029-20679-01-00 UIC N .~ lF`~' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • November 14, 2006 RE: MWD Formation Evaluation Logs: 12-14 L1_L1 PB1, 14-17A, 14-30A, 15-38A_PB1. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd. , Anchorage, AK 99518 12-14A L1_L1 PB1: a0a -l~~ ~ l~/~lSl Digital Log Images: 1 CD Rom ~0-029-20659-60, 71 14-17A: U=C go3-ood '~I~I~tY`~ Digital Log Images: 1 CD Rom 50-029-20562-01 14-30A: a OS -O ~}~/ ~ I~~/5 O Digital Log Images: 1 CD Rom 50-029-20679-O1 15-38A_PB 1: ~ ~ 3 - ~ i (~ ~ l ~l'-/~ ~9 Digital Log Images: 1 CD Rom 50-029-20679-0 l ~> 12/11/06 • ~C~llll~~~pg~p Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Bath Well Job # Log Description NO. 4070 Company: Alaska Oil 8. Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Date BL Color Cp V-211 40011188 OH EDIT OF MWD/LWD 11/17/04 2 1 S-213A OS 09-13 40011201 11491394 OH EDIT OF MWD/LWD MEM PROD PROFILE 12/11/04 11/24/06 2 2 1 14-30A DS 09.36C 11485775 1149225 MEM PROD PROFILE INJECTION PROFILE 11/21/06 11/23/06 2 2 W-12A Y-29A 11418301 11485776 MEM PROD PROFILE MEM PROD PROFILE 09(10!08 11/25/06 2 2 NK-43 6-13A 11414407 77212899 PROD PROFILE W/DEFT USIT ~ 10126/06 11I05/O6 2 1 14-30A 11485775 SCMT 11122106 1 DS 02-39L1 11491395 SCMT 11/25/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. - ~, g/I'""'^ ~' ''~, Petrotechnical Date Center LR2-1 I, ' 4s k~^^ 900 E Benson Blvd ~•~ : ~ P1~ ~°-~" fit"'"~ Anchorage AK 99508-4254 ~(~""r- "" Date Delivered ,~ ,~„ ~ ~~~~~~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-263 ATTN: Beth ~~ Received by: 12/11/06 Schlum6~ger Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # log Description NO. 4070 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orf on Prudhoe Bay Date BL Color CD V-211 40011188 OH EDIT OF MWD/LWD 11/17/04 2 1 5-213A DS 09-13 40011201 11491384 OH EDIT OF MWD/LWD MEM PROD PROFILE 12111/04 11/24/06 2 2 1 14-30A DS 09-36C 11485775 1149225 MEM PROD PROFILE INJECTION PROFILE 11/21/06 11123106 2 2 W-12A V-29A 11418301 71485776 MEM PROD PROFILE MEM PROD PROFILE 09/10/06 11/25/06 2 2 NK-43 6-13A 11414407 11212899 PROD PROFILE W/DEFT USIT 10126/06 11/05/06 2 1 14-30A DS 02-39L1 11485775 11491395 SCMT SCMT 11122/06 11/25/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. -.~ (((i 1 / I ""'' i ~~, Petrotechnical Data Center LR2-1 ~ ~ ~ ~ .-i ~ ~ 900 E Benson Blvd. f ° ~ 1t,,,, Anchorage AK 99508-4254 ~1 _. Date Delivered: ~,~ ~ ~~~~.7~~~- 'pf; ra ~14"~`c.;~=.. Schlumberger-DCS 2525 Gambell St, Suite 400 /t Anchorage, AK 99503-283 ATTN: Beth e~ Received by: \ / ' c -- a os - (~~ Lll • • WELL LOG TRANSMITTAL To: State of Alaska May 1 S, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-30A, AK-MW-3$43032 l LDWG formatted Disc with verification listing. API#: 5 0-029-2067 9-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUI2NINGA COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date] Qif & Gas Cons. Cc-mmissfon An;~orag~a BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: - r~5 -09y ~t3~3r~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One P Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/12/2005 ~ 12. Permit to Drill Number 205-094 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/26/2005 13. API Number 50-029-20679-01-00 4a. Location of Well (Governmental Section): Surface: 2 0 ' FN 7 ' F 7. Date T.D. Reached 8/2/2005 ~ 14. Well Name and Number: PBU 14-30A ' 1 8 L, 8 2 EL, SEC. 09, T10N, R14E, UM Top of Productive Horizon: 5271' FNL, 2835' FWL, SEC. 10, T10N, R14E, UM g_ KB Elevation (ft): 71.8' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1470' FNL, 1858' FWL, SEC. 15, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 12465 + 8903 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675622 ' y- 5938242 ''Zone- ASP4 10. Total Depth (MD+TVD) 12531 + 8891 ' Ft 16. Property Designation: ADL 028314 TPI: x- 679409 y- 5935167 Zone- ASP4 Total Depth: x- 678470 ~ Y- 5933665 'Zone- ASP4 11. Depth where SSSV set (Nipple) 2112' MD 17. Land Use Permit: _ 18. Directional Surve Y ®Yes ^ No 19. Water depth, if offshore NIA MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: "T~u1vrt.c~c~c: ,' ~I~/J~`iLtD~ ~ j`7 ~~'?'~/~ 2. ASING, LINER AND EMENTING RECORD CASING ETTwG EPTH MD ETTING EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE Op OTTOM OP OTTOM SIRE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 76' Surface 76' 30" 1818# Poleset 13-3/8" 72# N-80 Surface 2615' Surface 2611' 17-1/2" 2800 sx Arcticset III, 400 sx AS II 9-5/8" 47# L-80 / S00-9 Surface 9885' Surface 8317' 12-1 /4" 500 sx Class 'G' 7" 26# L-80 24' 10520' 24' 8802' 8-1 /2" 192 sx Class 'G', 833 sx Class 'G' 4-1/2" 12.6# 13Cr80 10359' 12528' 8692' 8892' 6-118" 917 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and ' " 24. TueING .RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 10366' 10308' MD TVD MD TVD 10860' - 10900' 8914' - 8913' 11190' - 11320' 8900' - 8899' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11440' - 11470' 8898' - 8898' 11720' 11730' 8910' 8911' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 11800' -11840' 8917' - 8921' 2200' Freeze Protect with 78 Bbls of Diesel 12290' - 12310' 8930' - 8927' 12410' -12430' 8912' - 8908' 26• PRODUCTION TEST Date First Production: August 18, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 9/8/2005 Hours Tested 6.2 PRODUCTION FOR TEST PERIOD ~ OIL-BBL g6 GAS-MCF 1,086 WATER-BBL 1,212 CHOKE SIZE 86.38 GAS-OIL RATIO 12,630 Flow Tubing Press. 25 Casing Pressure 1,702 CALCULATED 24-HOUR RATE OIL-BBL 333 GAS-MCF 4,204 WATER-BBL 4,690 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r „~° E; , I Oti ~NIS ~F~, s~P ~ ~ 2D0~ ~ ~ z e ~l None V~~R 0 __. ~~___..4.._... Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ("-'` 9°' • ~ r^~ ~ ~. ~ ~; ~ ' I (' ~ ~ _~ ~ _...~., il• r~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10524' 8804' None Shublik A 10558' 8826' Shublik. B 10601' 8850' Shublik C 10635' 8866' Sadlerochit 10712' 8894' 30. List of Attachments: Summary of Daily Drifting Reports, We11 Schematic Diagram, Surveys 31. f hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date ~ ` ` S •b PBU 14-30A 205-094 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. ! A rOVal NO. Drilling Engineer: Phil Smith, 564-4897 INSTRUCTIONS GeNEw-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 2ti: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 8/15/2005 1:07:16 PM BP EXPLORATION Page 1 of 11 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 14-30 14-30 Spud Date: 1/17/1982 REENTER+COMPLETE Start: 7121/2005 End: 8/12/2005 NABOBS ALASKA DRILLING I Rig Release: 8!12/2005 NABOBS 2ES Rig Number: Date ~ From - To Hours Task /2005 00:00 - 05:00 5.00 MOB 05:00 - 07:00 2.00 MOB 07:00 - 09:30 2.50 MOB 09:30 - 13:30 4.00 MOB 13:30 - 15:30 2.00 MOB Code ~ NPT ~ Phase Description of Operations P PRE Rig down floor, top drive, bridle up derrick. Lay derrick down. Move pits & camp to DS 14. Move sub off well. N PRE Rig on standby waiting on security to change out. P PRE PJSM w/security, fairweather -move sub to DS 14. P PRE Spot and level sub on 14-30A. Set pits, camp and slop tank. P PRE Raise and pin derrick & shoot. Unbridle, hang lines, spot shops. 15:30 - 17:00 1.50 MOB P PRE R.U. floor. 17:00 - 17:30 0.50 DEMOB P DECOMP Accept rig @ 1700 hrs 7-21-05. Pre spud saftey meeting w/ crew and DSL. PJSM. 17:30 - 18:00 0.50 WHSUR P DECOMP R.U. Iubricator.Pull bpv. 140 psi SITP, 300 psi SICP. 18:00 - 20:30 2.50 KILL P DECOMP Rig up to circ well and install double valvle on annulus. Pressure test lines to 250 / 3,500 psi. 20:30 - 00:00 3.50 KILL P DECOMP SITP 140 psi SICP 300 psi. Blow gas off csg thur seperator - crude oil to surface wf 90 psi on csg. Switch returns to cutting pit. Circ thru choke to cutting pit. @ 6 BPM 180 psi. w/ 20 returns. Continue circ out crude oil and gas. Pumped 780 bbls SW. 7/22/2005 00:00 - 02:00 2.00 KILL P DECOMP Circ /Kill well. Pump down tbg w/ returns thru choke C~ 6 BPM 350 psi. -Circ out crude oil and gas. Pumped total 990 bbls SW. No returns. Monitor well -annulus had small gas blow - tbg press 0 psi. Circ out 120 bbls oil. 02:00 - 03:00 1.00 KILL P DECOMP Bull head 178 bbls SW down csg C~ 6 bpm 200 psi. Monitor well. Tbg &csg on vaccum. R.U. trip tank to annulus to keep hole loaded. Taking 165 BPH sea water. 03:00 -04:00 1.00 WHSUR P DECOMP RU lubricator and set BPV. Dry rod test dart. RD lubricator. Test BPV from top to 1,000 psi. OK. 04:00 - 06:00 2.00 WHSUR P DECOMP PJSM. ND tree and adapter. Function LDS. Inspect tbg hanger threads. 06:00 - 08:30 2.50 BOPSU P DECOMP PJSM. NU BOP's. Pumped 50 bbls LCM pill w/ 50 # 1 bbl down annulus. Still losing 140 - 150 bbls / hr. 08:30 - 09:00 0.50 BOPSU P DECOMP MU test jt. R.U. to test. 09:00 - 14:30 5.50 BOPSU P DECOMP Test BOPE as per BP policy to 250 psi low / 3,500 psi high. Test witness waived by Chuck Sheeve w/ AOGCC. Witness by BP DSL John BALL and Charlie Henley -Nabors. RD test equip and blow down fines. 14:30 - 16:00 1.50 BOPSU P DECOMP R.U. dry rod. Attempt to pull tree test dart. RU TD &circ on test dart to clean out. Pulled dart. R.U. lubricator. Pulled BPV R.D. Lubricator. 16:00 - 17:00 1.00 PULL P DECOMP Make up landing jt. B.O.L.D.S. Pulled tbg hanger to rig floor. Pulled 200k. 17:00 - 18:30 1.50 PULL P DECOMP Pump 50 bbls LCM pill w/ 80 #/bbl LCM down tubing to 6,165'. Close bag and bullhead LCM into perfs 66PM @ 390 psi. 18:30 - 19:30 1.00 PULL P DECOMP CBU from 6,165' - 4 BPM @ 100 psi. Monitor well. No losses. 19:30 - 20:30 1.00 PULL P DECOMP L.D. tbg hanger. Clear rig floor. R.U. tbg handling tools & control line spooler. 20:30 - 23:30 3.00 PULL P DECOMP L.D. 51 jts 4.5" tbg /spool up control lines. 23:30 - 00:00 0.50 PULL P DECOMP L.D. SSSV. Recovered 29 SS bands. CBU C 4,033' - 12 BPM C~3 500 psi. R. D. control line spooler. Ciear floor. 7/23/2005 00:00 - 03:30 3.50 PULL P DECOMP Finished laying down 4.5" production tubing. Recover 147 jts, SSSV, and 2 - GLM's. Last joint (#147) -Pin pulled out of tbg collar due to sever corrosion, joint had 3' split and partially collapsed.. Top of fish @ 6,165' is 4.5" tubing collar looking Printed: 8/15/2005 1:07:24 PM BP EXPLORAT{ON Operations Summary Report Legal Well Name: 14-30 Common Well Name: 14-30 Event Name: REENTER+COMPLETE Start: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date li From - To Hours Task Code NPT Phase - - __ __ 7/23/2005 00:00 - 03:30 3.50 PULL P DECOMP up. 03:30 -04:00 0.50 PULL P DECOMP R.D. tubing handling tools. Clear rig floor. 04:00 - 06:00 2.00 BOPSU P DECOMP Set test plug. R.U. to test. Test bottom and top pipe rams and 06:00 - 10:00 4.001 FISH P DECOMP 10:00 - 11:30 I 1.501 FISH I P I I DECOMP 1 i:30 - 15:00 3.50 FISH P 1 DECOMP 15:00 - 15:30 0.50 FISH P DECOMP 15:30 - 17:30 2.00 FISH P ' DECOMP 17:30 - 18:30 1.00 FISH ~ P DECOMP 18:30 - 19:00 0.50 FISH P ~ DECOMP 19:00 - 23:00 4.00 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 7/24/2005 00:00 - 03:30 3.50 DHB P DECOMP 03:30 - 05:00 7 1.501 CLEAN 1 P I 1 DECOMP 05:00 - 08:00 3.00 CLEAN P DECOMP 08:00 - 09:00 1.00 CLEAN P DECOMP 09:00 - 09:30 0.50 CLEAN P DECOMP 09:30 - 11:30 2.00 CLEAN P DECOMP 11:30 - 13:00 1.50 CLEAN P DECOMP 13:00 - 16:00 3.00 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 20:00 I 3.001 DHB I P 20:00 - 21:00 I 1.00 {DHB I P 21:00 - 00:00 I 3.001 PXA I P 7/25/2005 00:00 - 02:30 2.50 PXA P 02:30 - 06:00 3.50 PXA P 06:00 - 07:00 1.00 PXA N 07:00 - 10:00 3.00 PXA N DFAL DFAL DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP hydril to 250 psi low and 3,500 psi high with 4" test jt. Test witnessed by Mike Whiteley and Jim Henson. Pulled test plug and set wear ring. PJSM. R.U. Schlumberger wire line. RIH w/ 3.65" O.D. jet cutter. Cut 4.5" production tubing @ 9,960' W.L. measurement. POOH. R. D. SWS. PJSM. M. U. fishing BHA - 8 1/8" O.D. Overshot wf 5 1/8" grapple, 5" HWDP, bumper sub, 5" HWDP. Change handling tools. RIH picking up 4" D.P. to 6,189'. UP 133K DWN 119K. Engage fish @ 6,189'. Pull fish free w/ 190K. UP 183k. Monitor well. Stable. POOH w/ overshot Release Overshot. L.D. overshot and bumper sub. R.U. handling tools for 4.5" tbg. PJSM. POOH laying down 83 jts + 29' cut-off piece 4.5" tubing and 10 GLM's. R.D. tubing handling tools. Clean and clear rig floor. R.U. Schlumberger wire line. PJSM. Ran 8.5" GR/ JB /CCL to 9,960'. Ran CCL log. POOH. Recovered plastic armor from control lines, SS band, paraffin, LCM, and scale. R.D. Schlumberger. M.U. Clean out BHA - 8.5" bit, ,csg scraper, Junk basket, B.S. RIH w/ 5" HWDP. RIH picking up 4" D.P to 5,149'.. Fill pipe. Slip and cut drilling line. Adjust brakes. Service top drive. RlH -tagged up C«~ 9,973'. CBU -pump high vis sweep around. 12 BPM C~? 1500 psi. Lots of paraffin and encapsulated plastic in bottoms up. POOH to BHA. Stand back HWDP. L.D. bit, csg scraper, and junk basket. Had 1/2 gallon scale in junk basket. R.U. SWS. M.U. EZSV. RIH w/ EZSV on wire line. Set EZSV C~ 9,899' wire line measurement. POOH. R.D. SWS. Test 9 5/8" csg to 3,500 psi for 30 min. Held. Test witnessed by Jimmy Henson -Nabors and Mike Whiteley -Fairweather. M.U. cement stinger. RIH to 9,906'. Break circ and pump 10 bbls sea water to clear DP. PJSM. M. U. head pin. Up 180K, DW 145K. Sting into retainer ~ 9,911'. Set 30K on retainer. Pressure annulus to 1,000 psi. to test DP; Held. Test lines to 3,500 psi. Attempt to establish pump in rate. Pressure up 2,600 psi (3 bbls pumped). held 2,600 psi. Unsting from retainer 4x and wash down. Pressure DP to max 3,600 psi. 4X. Unable to pump into formation. Unable to pump thru retainer. POOH w/ cement stinger. L.D. stinger. R. U. and test 9 5/8" csg to 3,500 psi for 30 min. Held. Wait on orders. Jeff Cutler (BP) received verbal approval from AOGCC to continue operation without cementing. 7/21(2005 8/12/2005 Page 2 of 11 Spud Date: 1/17/1982 End: 8!12!2005 Description of Operations Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: 14-30 Common Well Name: 14-30 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ~ From - To ~'~ Hours Task Code ~ NPT Spud Date: 1/17/1982 Start: 7/21/2005 End: 8/12/2005 Rig Release: 8/12/2005 Rig Number: Phase Description of Operations 7/25/2005 10:00-13:30 3.50 STWHIP P WEXIT 13:30-14:00 0.50 STWHIP N DFAL WEXIT 14:00 - 15:30 1.50 STWHIP P WEXIT 15:30 - 20:30 5.00 STWHIP P WEXIT 20:30 - 21:30 1.00 STWHIP P WEXIT 21:30 - 22:00 0.50 WHIP P WEXIT 22:00-22:301 0.501STWHIPIP I IWEX{T 22:30 - 00:00 1.50 STWHIP P WEXIT 7/26/2005 00:00 - 07:00 7.00 STWHIP P WEXIT 07:00 - 07:30 I 0.501 STWHIP( P I I WEXIT 07:30 - 11:00 3.50 STWHIP P WEXIT 11:00 - 13:00 2.00 STWHIP P WEXIT 13:00 - 14:30 1.50 STWHIP P WEXIT 14:30-17:301 3.OOISTWHIPIP I (WEXIT 17:30 - 18:30 1.00 STWHIP P WEXIT 18:30 - 21:30 3.00 STWHIP P WEXIT 21:30 - 22:00 0.50 STWHIP P WEXIT 22:00 - 23:00 1.00 STWHIP P WEXIT - 00:00 f 1.001 DRILL I P I I LNR1 7/27/2005 f 00:00 - 13:00 I 13.001 DRILL I P I I LNR1 13:00 - 15:00 2.001 DRILL P LNRi 15:00 - 15:30 0.50 DRILL P LNR1 15:30 - 17:00 1.50 DRILL P LNR1 17:00 - 18:00 1.00 DRILL P LNR1 18:00 - 18:30 0.50 DRILL P LNR1 18:30 - 20:30 2.00 DRILL P LNRi 20:30 - 21:00 0.50 DRILL P LNR1 21:00 - 00:00 3.00 DRILL P LNRi 00:00 - 02:30 2.50 DRILL P LNR1 02:30 -04:00 1.50 CASE P LNR1 M.U. Whipstock BHA -Orient. Initalize MWD / LWD's. M.U. whipstock. Orient UBHO. Shallow test MW D tools - 500 gpm C~ 550 psi. UBHO set screw leaking under pressure. C.O. UBHO and test. P.U DC's and bumper sub. RIH w/HWDP. RIH w! whipstock to 9,816'. UP 225K DW 115k. Fill pipe and check MWD every 3,000'. Lubricate rig and top drive. Orient Whipstock 54 DEG RHS ~ 9,816'. Tag EZSV @ 9,907'. Set 25K down to set bottom trip anchor. Pulled 10k over. Set down 40k to shear lug. Pump hi vis spacer. Displace well w/ 11.2 ppg LSND mud - 475 gpm - 1350 psi. Take SPR. Mill window in 9 518" csg f! 9,885' - 9,888'. Mill window in 9 5/8" csg f/ 9,888' - 9,902'. Drill new hole to 9,913' (20'). Pump high vis super sweep around and polish window. Up 195K, DN 160K, RT 177K, 455 gpm C~3 2250 psi. TO on 7300, TQ off 6300. Recovered 240 Ibs metal cutting from milling. Circ out 2 pieces plastic encapsulation (1' & 8" long) from control lines - Perform FIT to 12.5 ppg EMW - 11.1 ppg mud, 605 psi, 9,885' MD 18,317' TVD. Pump slug -remove blower hose. POOH to BHA. Stand back HWDP. L.D. BHA. Mills full gage. Clear floor. Service wear ring .Flush out stack, function rams, clean out surface equipment. M.U.Dir. Drilling BHA. Initalize MWD / LWD toots. Shallow test 450 gpm C«~ 670 psi. P. U. NM f{ex collars. RIH w1 HWDP 1 jars. Service rig, top drive, and adjust brakes. RIH to 9,640'. Fi{I pipe !test MWD every 3,000'. Mad pass f/ 9,640' to 9,690' C~3 200 fph. Take SPR's. Install blower hose. Orient 45 LHS. Slide thru window C~ 9,885' to 9,910'. Wash to btm ~ 9,913'. Dir Drill f19,913' - 9962'. AST .77 hrs, ART .13 hrs. UP 190K, DN 145K, RT 170K, TQ OFF 6K, TO ON 7K. ECD 11.7 PPG. Dir. Drill ff 9,962' -10,520'. AST 5.54 hrs, ART 3.26 hrs. UP 200K, DN 150K, RT 175K, 500 gpm -3100 psi ON , 3000 OFF. TQ ON 8500, TO Off 7,000. ECD 11.58 ppg. Circ for samples @ 10,520'. 500 gpm @ 3100 psi. Pump high vis sweep around and circ clean. Monitor well. Static. Wiper trip -POOH to 9,914'. No problems. Mad pass f/ 9,914' to 9,680' - 200 fph. Cut drilling line. RIH to 10,520. No problems. Pump high vis sweep around and circ clean. Spot 50 bbl liner running pill in open hole.. Monitor well. Static. Drop 2 3/8' rabbit. POOH to 9,850'. Slug D.P. and remove blower hose. POOH to BHA. L.D. HWDP. L.D. BHA. Down load LWD's and clear rig floor. Change top rams to 7". Pull wear ring and set test plug. Test 7" rams to 250 psi low and 3,500 psi high. Test witness by Mike Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: 14-30 Common Well Name: 14-30 Spud Date: 1/17/1982 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/12/2005 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 8!12/2005 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~ Hours ~~~ Task i, Code ~ NPT Phase ~ Description of Operations 7/28/2005 02:30 - 04:00 1.50 CASE P LNR1 04:00 -04:30 0.50 CASE P LNRi 04:30 - 07:30 3.00 CASE P LNR1 07:30 - 08:00 0.50 CASE P LNR1 08:00 - 13:15 5.25 CASE P LNR1 13:15 - 13:45 0.50 CASE P LNR1 13:45 - 14:15 0.50 CASE P LNR1 14:15 - 15:00 I 0.751 CASE I P { I LNRi 15:00 - 15:15 0.25 CASE P LNR1 15:15 - 15:45 0.50 CASE P LNR1 15:45 - 16:00 0.25 CEMT P LNRi 16:00 - 17:00 I i .001 CEMT I P I 1 LNRi 17:00 - 18:00 1.001 CEMT I P I LNR1 18:00 - 18:30 0.50 CASE P LNRi 18:30 - 21:30 3.00 CASE P LNR1 21:30 - 22:30 1.00 CASE P LNRi 22:30 - 00:00 1.50 CASE P LNR1 (29/2005 00:00 -04:00 4.00 CASE P LNR1 04:00 - 05:30 1.50 CASE P LNR1 05:30 - 06:00 0.50 CASE P LNR1 06:00 - 08:00 I 2.001 CASE I P I I LNR1 08:00 - 09:30 1.50 CASE P TIEBi 09:30 - 10:00 0.50 CASE P TIEBi 10:00 - 16:30 6.50 CASE P TIEBi 16:30 - 17:30 1.00 CASE P TIEBi 17:30 - 21:00 3.50 CASE P TIEB1 21:00 - 23:00 2.00 CASE P TIEBi Whiteley -Fairweather. R.U. to run 7" liner. PJSM. RIH picking up 19 jts 7" liner. MU liner hanger/packer assembly & space out pups. Circ one liner volume. RIH with 7" liner on 4" DP. 90 fpm run speed. Circ 1.5X liner & DP vol at window. 5 bpm C~3 700 psi. Continue running liner in open hole to bottom ~ 10520' MD - 60 fpm run speed. No problems or obstructions. MU plug dropping head and lines. Break circulation & stage pumps up to 5.5 bpm. PJSM BP, NAD, Baker, Veco. Continue circulating while hatching up slurry. Line up valves on head. Pump 3 bbls water to fill lines and test to 4500 psi - OK. Pump 25 bbls Mudpush li spacer at 12.2 ppg. Switch to cement and pump 40 bbls (192 sx) 15.8 ppg Class Gslurry - batch mixed. 5 bpm ~ 1600 psi. Release dart and kick out with 5 bbls water followed by mud. 5.6 bpm ~ 990 psi start. Slow to 3 bpm and PU liner wiper plug at 93 bbls away. Continue displacement - 3 bpm @ 750 psi. Bump plug at 120 bbls away. Pressure up to 4000 psi to set hanger/packer. Slack off 70 klbs and bleed pressure to zero to check floats - OK. CIP at 15:40 hrs. Pressure up to 1000 psi & PU running tool out of hanger - observe pressure loss. Circ 500 stks at 12 bpm to clear cement from hanger. PU & verify free of hanger - OK. Set back down 70 klbs to set LTP. Rotate to complete set. CBU at 12 bpm to circ out excess cement from liner top. Got back approx 5 bbls cement. Slug DP. R.D. cementing head, valves, & hoses. POOH to 2,339'. P.U. Halliburton 9 5/8" storm packer & set 5' below csg head. Pulled wear ring. test pkr to 1,000 psi from top. N.D BOP's and remove 2nd annular valve.. N.D. and remove 13 516" 5M Gray tubing head. N.U. 13 5/8" 5M Gray Csg Head and new 9 5/8" pack-off. Test to 5,100 psi for 10 min. Held. N.U. BOP's. Set test plug and rig up to test. Test 13 518" csg head /BOP flange to 250 psi low and 3,500 psi high. Test witnessed by Mike Whiteley -Fairweather. Sting into storm packer -Pull and L.D. packer. POOH w/ 4" DP - L.D. liner hanger running tools. Clear floor. Pull wear ring. Test 7" liner to 3,500 psi for 30 min. Held. R.U. to run 7" csg. PJSM. RIH picking up 7" 26# BTCM csg to 5771'. Change out tongs - R.U. to torque turn. RIH picking up 7" 26# L80 TCII csg to 9,710'. Install long bails and 150 ton elevators. MU XO joint and cementing head. Land & Space out tie back seal assembly to circ. 270 UP, 170K down. Circ 45 min. 6bpm - 1200 psi. PJSM. Printed: 8!15/2005 1:07:24 PM BP EXPLORATION Operations Summary Report Page 5 of 11 Legal Well Name: 14-30 Common Well Name: 14-30 Spud Date: 1/17/1982 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/12/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/12!2005 Rig Name: NABOBS 2ES Rig Number: I Date From - To , Hours j I T Phase ~ Description of Operations ~~ - --' Task Code NPT - -- -- --- _..--- 7/29/2005 23:00 - 00:00 1.00 CEMT P TIE61 Start cement job -Test lines to 4,000 psi. Pumped 15 bbl hi vis spacer. 7/30!2005 00:00 - 01:00 i.00 CEMT P T1EB1 Pumped 70 bbls diesel , btm plug, 172 bbls (830 sx) Class "G" cement C~ 15.8 ppg - 4.4 bpm. 01:00 - 02:30 1.50 CEMT P TIEB1 Dowell displaced with 370.7 bbls mud ~ 5.5 bpm. Plug did not bump. CIP @.0220 hrs. Diesel to surface. Lower tie back stem into tie back sleeve w/ 25k on no go and bleed off pressure. Float held. 02:30 - 04:00 1.50 CEMT P TIEB1 Blow down lines. R.D. cementing head and lines. Drain stack. Suck out 7" csg to 30'. 04:00 - 05:00 1.00 WHSUR P TIEB1 N.D. BOP's and pick up stack. 05:00 - 06:00 1.00 WHSUR P TIEB1 Set slips on 7" - 240K. Cut off 7". L.D. cut off jt and stand back stack. 06:00 - 12:30 6.50 WHSUR P TIEBi Install 7" packoff. N.U. Tubing head. Rig Bridge crane to pick up stack. N.U. BOP's. Test 7" packoff to 3,750 psi. Hold 10 min. Double valve tubing head annulus. Finish N.U. BOP's. 12:30 - 14:30 2.00 BOPSU P TIEB1 Change top pipe rams to 3.5" x 6" var. Complete NU BOP's. 14:30 - 20:00 5.50 BOPSU P TIEBi Test BOP's as per BP policy to 250 psi low and 3,500 psi high. Test witnessed by John Crisp w/ AOGCC & Dick Maskell w/ BP. RD test equip. Test 7" tieback string to 3,500 psi for 5 min. Held. 20:00 - 22:30 2.50 DRILL P PRODi M.U. 6 1/8" BHA - 6 118" PDC bit / 1.76 deg motor -Orient, initalize tools, and surface test MWD. 270 gpm / 1400 psi. 22:30 - 00:00 1.50 DRILL P PROD1 RIH picking up 4" DP. 7/31/2005 00:00 - 01:00 1.00 DRILL P PROD1 RIH picking up 4" DP to 2,884'. 01:00 - 03:00 2.00 DRILL P PROD1 RIH to 9,612'. Fill pipe and install blower hose. 03:00 - 03:30 0.50 DRILL P PROD1 Break circ. Wash to top of cement @ 9,642'. Drlg plugs and soft cement to 9,687'. Drlg F.C. C~ 9,687'. Drlg cement to 9,718'. Wash down to 9,797'. Circ. 03:30 - 04:30 1.00 CASE P PRODi Test 7" csg to 3,500 psi for 30 min. Held. Witnessed by mike Whiteley -Fairweather. 04:30 - 05:00 0.50 DRILL P PROD1 RIH to 10, 360'. 05:00 - 05:30 0.50 DRILL P PRODi Service top drive gripper dies. 05:30 - 07:30 2.00 DRILL P PROD1 Washdown to 10,420'. Drill plugs cement to 10434'. Drill landing collar ~ 10434'. Drill cement t floats to 10,515'. RPM 40, TQ 8K, 260 gpm / 2680 psi Off, 3,000 psi ON, WOB 5 - 15k, UP 190 K, DN 125K, RT 150K. 07:30 - 11:00 3.50 DRILL P PROD1 Circ cement up hole. Pump 75 bbls water, 40 bbls hi vis sweep and displace well with 8.4 ppg Flo-Pro mud @ 240 gpm. TO 4k, UP 175K, DN 145K, RT 160D. Change screens & clean bellies & troughs. 11:00 - 12:00 1.00 DRILL P PROD1 Drill shoe and 20' new hole to 10,540'. 12:00 - 13:00 1.00 DRILL P PROD1 Circ 270 gpm ~ 1750 psi. Perform F.I.T. to 9.89 ppg EMW w/ 8.4 ppg mud, TVD 8,317', 605 psi surface pressure. 13:00 - 00:00 11.00 DRILL P PROD1 Dir. Drill 6 1/8" hole f/ 10,540' to 10,970'. ART= .07 hrs, AST = 7.3 hrs. All slide. UP 175K DN 140K 280 gpm C~ 2,050 psi. WOB 10k. 8/1/2005 00:00 - 11:00 11.00 DRILL P PROD1 Dir. Drill f/ 10, 970' to 11, 575'. AST = 2.14 hrs, ART= 3.84 hrs 175K UP, 135K DN, 160K ROT, 52 RPM, TQ ON 6K, TQ Off 5K, 284 gpm ~ 1950 psi OFF, 2,150 psi ON. Problem sliding - wall sticking. 11:00 - 13:30 2.50 DRILL P PROD1 Back ream out of hole f! 11,575' - 10520'. 284 gpm / 1950 psi. 30 RPM , 4K TO C~3 20 fpm. No problems. Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Operations Summary Report Page 6 of 11 Legal Well Name: 1 4-30 Common W ell Name: 1 4-30 Spud Date: 1/17/1982 Event Nam e: REENTE R+COM PLET E Start : 7/21/2005 End: 8/12/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 8/12/2005 Rig Name: NABOB S 2ES Rig Number: Date From - To Hour Task I { Code ~ NPT ~ Phase ~ Description of Operations - _ _ ~ _ ~ - 8/1/2005 13:30 - 15:00 1.50 DRILL P PROD1 Cut drilling line, service crown, inspect brakes, service top drive. 15:00 - 15:30 0.50 DRILL P PROD1 RIH. Washed stand to bottom. Hole in good shape. 15:30 - 00:00 8.50 DRILL P PROD1 Dir. drill from 11,575' to 12,010'. AST = 1.i6, ART = 2.86, UP 175K, DN 135K, RT i60K, RPM 50, WOB 7K, 284 gpm 2,150 psi OFF, 2,550 psi ON, TO 5K OFF, TO 7D ON. 8/2/2005 00:00 - 01:00 1.00 DRILL P PROD1 Dir drill f/ 12,010' to 12,058'. Lost partial returns. 01:00 - 01:30 0.50 LCR P PROD1 Monitor well. Static loss 120 BPH. 01:30 - 02:30 1.00 LCR P PROD1 Mix and pump 40 bbl LCM pill w/ 40 ppb Safe carb 40 / 250 and drill to 12,075' C~ 150 gpm 1,100 psi. No returns. 02:30 - 03:30 1.00 LCR P PRODi POOH to 10,454' -inside 7" csg. Filing hole wJ seawater. 03:30 - 07:00 3.50 LCR P PROD1 Monitor well -Static loss 120 BPH. Mix 80bb1 LCM pill w/ 80 ppb Safe carb 40 & 250. Static loss rate increased to 160 bph. Pump 80 bbls LCM pill out bit C~3 10, 454'. Monitor well, losses increased to 200 bph. 07:00 - 08:00 1.00 LCR P PRODi RIH slow, fill backside continually. DWT = 125K. 08:00 - 13:30 5.50 DRILL P PRODi Drill with seawater from 12075' to 12531'. Pump ~ 250 gpm. 1700 psi on bottom 1500 off. Torque = 9-10K C~ 60 rpm. WOB = 5K, no returns, fill hole from top, + 450 bph losses. ART = 1.04 hr. 13:30 - 15:00 1.50 DRILL P PROD1 Pump high vis sweep ~ 225 gpm C~ 1480 psi, spot pill, losses = 450 bph while pumping. Spot liner running pill. 15:00 - 16:00 1.00 DRILL P PROD1 POH from 12531' to 10453', monitor well, losses = 390 bph. Remove top drive blower hose. 16:00 - 18:30 2.50 DRILL P PROD1 POH from 10453' to 569i', losses increased to 450 bph. 18:30 - 20:00 1.50 DRILL P PRODi RIH from 5691' to shoe C~ 10520'. 20:00 - 00:00 4.00 DRILL C PROD1 Rig up on kill line # 2 & fill hole with mud pump. Losses ~ 350 bph. Prepare pipe & equipment to run 4.5" solid liner. Remove slotted liner from pipe shed. Ship liner componets out for reconfigure. 8/3/2005 00:00 - 08:30 8.50 DRILL C PROD1 Bit C~ 7" shoe C 10520'. Well taking 360 bph, filling through kill line # 2 with mud pump. Prepare to run 4 1/2" solid liner instead of slotted liner. 08:30 - 09:30 1.00 DRILL C PRODi Install top drive blower hose. RIH to bottom C~ 12531', hole in good shape. DWT = 130/100K. 09:30 - 10:30 1.00 DRILL P PROD1 CBU, spot FloPro liner running pill, losses decreased to 25 bph. UWT = 240K, DWT = 120K, 10:30 - 12:00 1.50 DRILL P PROD1 POH from 12531' to 7" shoe C~ 10520', hole in good shape. Losses increasing. Remove top drive blower hose, blow down mud lines. Line up & fill hole through kill line # 2 with mud pump, losing 300+ bph. 12:00 - 16:00 4.00 DRILL P PROD1 POH from 10520' to 363', loses ~ 300 bph. 16:00 - 18:00 2.00 DRILL P PROD1 L/D BHA, down load MWD, clear rig floor. Loses C~ 200 bph. 18:00 - 19:00 1.00 CASE P RUNPRD PJSM. R/U to run 4.5" liner. 19:00 - 20:00 1.00 CASE P RUNPRD PJSM with drill crew, Tool pusher, Baker & WSL. M/U float equipment, check floats held. RIH with 4 1/2" 12.6#, 13Cr-80, NSCT liner to 2139'. 20:00 - 00:00 4.00 CASE P RUNPRD P!U liner hanger, mix & install PAL mix to top of liner hanger. Rig down casing equipment. Liner weight = 55K. 8/4/2005 00:00 - 06:30 6.50 CASE P RUNPRD RIH with 4 1/2", 12.6#, 13Cr-80, NSCT liner on drill pipe. Losing 269 bph of fluid to formation. Running speed = 1 min per stand. 90 seconds in open hole. Fill backside continually. Fill drill pipe on the run. HWT = 200K, DWT = 135K @ 10520', Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 14-30 Common Well Name: 14-30 Spud Date: 1/17/1982 Event Name: REENTER+COMPLETE Start: 7!2112005 End: 8/12/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/12/2005 Rig Name: NABOBS 2ES Rig Number: Date '~, From - To Hours ~ Task ~ Code ~~ NPT ; Phase ~ Description of Operations 814/2005 00:00 -06:30 6.50 CASE P RUNPRD (7" shoe) RIH to 12504'. HWT = 250K, make up cement head. Tag bottom @ 12531'. Pull string up to 225K and park. 06:30 - 07:30 1.00 CEMT C RUNPRD Break circ, pump @ 3 bpm ~ 250 psi, R/U cement crew. Static loss to well = 160 bph. 07:30 - 08:30 1.00 CEMT C RUNPRD PJSM with Schulmberger cement crew, drill crew & WSL. Batch up. 08:30 - 10:30 2.00 CEMT X CEMT RUNPRD Pump 3 bbl water, pressure test lines to 3500 psi. Pump 28 bbl 9.4 ppg spacer followed by 42 bbl 15.8 ppg class "G" cement. Wash up 10 bbl. Drop top plug and kick out. Did not see plug indicator trip. Displace & observe latch-up 32 bbl early. Shut down pumping, confirm volume pumped. Continue job as per plan. Displace cement 3 bbl past original calculated strokes to bump. Did not bump plug, bleed off & check floats, flowed back approx 12 bbls. 10:30 - 11:30 1.00 CEMT X CEMT RUNPRD L/D cement head, M/U top drive to drill pipe. P/U 240K to confirm liner is not released. 11:30 - 13:30 2.00 CEMT X CEMT RUNPRD Circ out cement ~ 470 gpm @3350-psi. Losses to well = 90 ~ . bph while pumping. Circ out 42 bbl cement to surface. Clean cement from surface equip. Attempt to pull liner, P/U 50K over up weight, no movement. Release from liner hanger. Losses = 45 bph. 13:30 - 15:00 1.50 CEMT X CEMT RUNPRD POH from 10361' to 7568'. Losses = 10 bph. 15:00 - 15:30 0.50 CEMT X CEMT OTHCMP Circulate Ca? 9 bpm to check loss rate, losses = 9 bph. 15:30 - 18:30 3.00 CEMT X CEMT RUNPRD POH from 7568', L/D liner running tool & pup jts, clear rig floor. 18:30 - 23:30 5.00 CEMT X CEMT RUNPRD PJSM. R/U 2 7/8" power tongs & handling equipment. M/U cment tools on 2 7/8" Fox inner string, P/U 49 jts to 1608'. R/D handling equipment. P/U 2 ea 4" HT40 space out pup jts. 23:30 - 00:00 0.50 CEMT X CEMT RUNPRD RIH with 2 7/8" Fox inner string & cement tools on 4" HT40 drill pipe. 8/5/2005 00:00 - 08:00 8.00 CEMT X CEMT RUNPRD RIH with 2 7/8" inner string & cement tools on HT40 drill pipe to cement 4.5" liner. Running speed to 10360' = 90 fpm, running speed to 11920' = 25 fpm. Tag obstruction C~ 11920' [top of HMCV cement valve] Swab cup on bottom of inner string would not pass through HMCV valve, set 10K weight down, no go. Make several attempts, set down 25K no go. 08:00 - 13:00 5.00 CEMT X CEMT RUNPRD POH from 11920' to 1627'. 13:00 - 16:00 3.00 CEMT X CEMT RUNPRD L/D 2 7/8" pipe & Baker tools. Clear rig floor. 16:00 - 18:00 2.00 CEMT X CEMT RUNPRD M/U mule shoe , 49 jts of 2 7/8" FOX tubing & seal assy. RIH to cement 4.5" liner. 18:00 - 19:30 1.50 CEMT X CEMT RUNPRD RIH from 1568' to 5304'. 19:30 - 20:30 1.00 CEMT P RUNPRD PJSM. Cut & slip 96 'drill line. 20:30 - 21:00 0.50 CEMT P RUNPRD Service top drive & crown. 21:00 - 23:00 2.00 CEMT X CEMT RUNPRD RIH from 5304' to 10360' [top of 7" liner] Slow running speed to 90 fpm to 11886'. 23:00 - 00:00 1.00 CEMT X CEMT RUNPRD R/U cement head & single of drill pipe, attempt to break circ, valve on cement manifold plugged. Clean out. 8/6/2005 00:00 - 02:30 2.50 CEMT X CEMT RUNPRD Break circ, tag TOL with seal assy ~ 10358', 3' high. [2 7/8" mule shoe spaced out 30' above HMCV cement valve] Attempt to stab seal assy into top of tie-back sleeve, tagged up 3' high. Circ, rotate & attempt to get down. P/U 15' & pump C~3 4 bpm @ 640 psi, pump @ top of tie-back @ 4 bpm C~3 700 psi. Unsure if seals are in tie-back. 02:30 - 06:30 4.00 CEMT X CEMT RUNPRD POH for 6' pup jt to space seal assy out 6' from dog sub. Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Operations Summary Report Page 8 of 11 Legal Well Name: 14-30 Common Well Name: 14-30 Spud Date: 1/17/1982 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/12/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/12/2005 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~~ Hours ~ Task Code /6/2005 06:30 - 07:00 ~ 0.50 CEMT X 07:00 - 10:30 3.50 CEMT X 10:30 - 11:00 0.50 CEMT X 11:00 - 11:30 0.50 CEMT X 11:30 - 13:30 I 2.001 CEMT I X 13:30 - 14:30 I 1.001 CEMT I X 14:30 - 15:00 0.50 CEMT X 15:00 - 15:30 0.50 CEMT X 15:30 - 16:30 1.00 CEMT X 16:30 - 20:00 3.50 CEMT X 20:00 - 23:30 3.50 CEMT X 23:30 - 00:00 0.50 CEMT X 8/7/2005 00:00 - 04:00 4.00 CEMT X 04:00 - 09:00 I 5.001 CEMT I X 09:00 - 09:30 I 0.501 CEMT I X 09:30 - 10:00 0.501 CEMT X 10:00 - 11:30 1.50 CEMT X 11:30 - 12:00 0.50 CEMT X 12:00 - 16:00 4.00 CEMT X 16:00 - 17:00 1.00 CEMT X 17:00 - 18:00 1.00 CEMT X 18:00 - 19:00 1.00 CEMT X 19:00 - 23:00 4.00 CEMT X 23:00 - 00:00 1.00 CEMT X 8/8/2005 100:00 - 02:30 I 2.501 CEMT I X NPT I Phase Description of Operations CEMT RUNPRD Change out seal assy and P/U 6' pup jt. CEMT RUNPRD RIH, seal assy @ top of 7" liner C~ 10361', 2 7/8" mule shoe 22' above HMCV, [HMCVvalve ~ 11920'.] CEMT RUNPRD P/U single of drill pipe & cement head. CEMT RUNPRD Establish circ, pump ~ i64 gpm ~ 645 psi. Stab seal assy into tie-back. CEMT RUNPRD PJSM with Schlumberger cement crew, drill crew & WSL. Batch mix cement. Pump 5 bbl water and test lines to 3500 psi. Pump 26 bbls 9.4 ppg spacer followed by 54 bbl of 15.8 ppg class "G" latex/aggregate cement. Displace w/ water @ 4 bpm leaving 4 bbls cement in string. Set down 60K & set liner top packer. Attempt to squeeze 2 bbl cement through HMCV, no go. CEMT RUNPRD Switch to rig pumps, unsting seal assy from TOL and CBU ~ 9 bpm C~ 3900 psi. Reciprocate 185K up, 125K down. Circ until clean, 25 bbls of spacer & 26 bbl of cement returned to surface. Sting seals into tie-back, close annular preventor & pressure up annulus to 1000 psi. Hold test for 5 min, OK. Bleed off pressure. Pull seals from tie-back & monitor well, no flow. Gauge hole = 26.5 bbl, left 28.5 bbl in well. CEMT RUNPRD UD cement head, blow down lines. CEMT RUNPRD POH from 11898' to 10361'. CEMT RUNPRD CBU ~ 7" liner top. Pump 10 bpm C~ 3900 psi. CEMT RUNPRD POH from 10360' to 1573' CEMT RUNPRD L/D 2 7/8" FOX pipe and tools. Make service breaks on Baker tools. Clear & clean rig floor. CEMT RUNPRD P/U Baker 2.857 X-Treme mud motor to clean out 4.5" liner. CEMT RUNPRD P/U Baker 2.875 X-Treme mud motor on 2 7!8" PAC pipe & RIH. Break circ &circ string volume every 20 jts picked up to prevent motor from getting plugged. CEMT RUNPRD RIH w/ 2 7/8" drill pipe on 4" HT40 pipe. Fill pipe @ 1800' intervals. Slow running speed through 4.5" liner. CEMT RUNPRD Drill cement & stringers from 11902' to 11925'. Pump @ 103 gpm C 1010 psi, WOB = 2-4K. CEMT RUNPRD Test well to 1000 psi for 20 min. Pressure dropped from 1000 psi 715 psi. CEMT RUNPRD Drill cement from 11925' to 11987'. CEMT RUNPRD RIH to 12471'. CEMT RUNPRD Drill cement stringers from 12471' & tag liner wiper plug C~ 12477'. Drill liner wiper plug & float equipment. WOB = 3K, pump C 100 gpm ~ 925 psi off bottom, 1200 on. Pump sweeps. Lost returns ~ 12478'. Establish static loss rate ~ 200 bph. Fill hole through kill line # 2. Drill plugs & float equip to 12481'. RIH, tag shoe @ 12528', drill shoe to 12530'. Losses = 240 bph. CEMT RUNPRD POH wet from 12530' to 7" casing C~3 10361'. UWT = 230K. CEMT RUNPRD Spot 12 bbl high vis sweep 20' above liner top & allow losses to sweep liner volume through shoe. CEMT RUNPRD RIH to bottom @ 12530' to clear any debris from well bore. CEMT RUNPRD Drop dart & open circ sub. POH from 12530' to 2218'. CEMT RUNPRD R/U power tongs & handling equip. POH UD 2 718" PAC drill pipe. Static losses = 170 bph. CEMT RUNPRD R/U power tongs and handling tool for 2 7/8" pipe. POH UD 2 Printed: 8/15/2005 1:07:24 PM BP EXPLORATION Operations Summary Report Legal Well Name: 14-30 Common Well Name: 14-30 Event Name: REENTER+COMPLETE Start: 7121/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/12/2005 Rig Name: NABOBS 2ES Rig Number: Date % From - To Hours Task Code ~ NPT I~, Phase 8/8/2005 00:00 - 02:30 2.50 CEMT X CEMT RUNPRD 02:30 - 05:30 3.00 CEMT X CEMT RUNPRD 05:30 - 10:30 5.00 CEMT X CEMT RUNPRD 10:30 - 11:00 0.50 CEMT X CEMT RUNPRD 11:00 - 12:00 1.00 CEMT X CEMT RUNPRD 12:00 - 13:30 1.50 CEMT X CEMT RUNPRD 13:30 - 15:45 1 2.251 CEMT I X I CEMT I RUNPRD 15:45 - 16:30 0.751 CEMT X (CEMT RUNPRD 16:30 - 00:00 I 7.50 {CEMT { X CEMT I RUNPRD 00:00 - 03:00 { 3.001 CEMT lX CCEMT {RUNPRD 03:00 - 04:00 I 1.001 CEMT I X I CEMT I RUNPRD 04:00 - 05:00 1.00 CEMT X CEMT RUNPRD 05:00 - 06:30 i.50 CEMT X CEMT RUNPRD 06:30 - 07:30 1.00 CEMT P RUNPRD 07:30 - 08:00 0.50 CEMT P RUNPRD 08:00 - 09:00 1.00 CEMT X CEMT RUNPRD 09:00 - 10:30 1.50 CEMT X CEMT RUNPRD 10:30 - 12:00 1.50 CEMT X CEMT RUNPRD 12:00 - 14:30 2.50 CEMT X CEMT RUNPRD 14:30 - 17:30 3.00 CEMT X CEMT RUNPRD 17:30 - 17:30 I 24.00 I CEMT ! X I CEMT I RUNPRD Page 9 of 11 Spud Date: 1/17/1982 End: 8/12/2005 Description of Operations 7/8" PAC drill pipe from 2100', UD X-Treme mud motor. P/U HOWCO cement retainer for 4.5" liner cement job &RIH on 2 7/8" FOX pipe. Rig down power tongs. RIH with 4" HT40 drill pipe to 12465', slow running speed through 4.5" liner. M/U pump in sub &circ lines, break circ. Set cement retainer ~ 12465'. Establish injection rate, 4 bpm C~3 860 psi. 2 bpm @ 85 psi. PJSM with Schlumberger cementers, drill crew &WSL. Batch mix cement. Pump 2 bbl water & test lines to 3500 psi. Pump 5 bbl 15.8 G neat cement, 10 bbl with 2.5 ppb fiber ~ 3.6 bpm @ 70 psi, followed by 60 bbl of 15.8 ppg class "G". Total cement pumped is 75 bbls (360 sx). Displace with fresh water. During displacement, with 74 bbl away pressure increased to 400 psi C~3 3.5 bpm. With 85 bbl away pressure = 600 psi, 90 bbl away slow to 2 bpm C~ 750 psi. With 93 bbl away lost all pressure. With 100 bbl away @ 1 bpm pressure up to 160 psi. Displace 105 bbls & leave 10 bbls in cementing string. CIP at 14:15 hrs. Perform hesitation squeeze. Pumped 6 bbl in 1 bbl increments C~ 15 min intervals - no pressure build up. Un-sting from retainer, break circ. Had to pump 12 bbl to get returns. CBU ~ 330 gpm ~ 3550 psi. Residual cement only in returns. WOC for 500 psi compressive strength. Wash down to top of retainer. P/U & circ C 2 bpm C~3 260 psi. WOG to get to 500 psi compressive strength after pumping & squeezing 4.5" liner. Establish injection rate through cement retainer set ~ 12465'. Pump C~3 500 psi at 1 bpm and slowly bleeds off. Spot 33 bbl pert pill. POH LDDP from 12465' to 10325' UD drill pipe. Cut & slip drill line. Service top drive. Wait on orders. Decesion for cement squeeze. RIH to 12441', M/U pump in sub &circ lines. Sting into retainer @ 12465', establish injection rate. Pumped 12 bbl C~3 1000 psi. Pump C~3 1 bpm ~ 1200 psi. Wait on orders, RIU cementers. PJSM with drill crew, Schlumberger cement crew &WSL. Unsting from retainer. Break circ. swap to Schlum. Pump 2 bbl water, test lines to 3500 psi. Mix cement, pump cement C~ 3 bpm Ca? 250 psi. Displace with water ~ 6 bpm, caught cement 7 bbl away, displace ~ 4.5 bpm ~ 600 psi. 40 bbl away = 600 psi. 60 bbl away = 770 psi. Shut down pumping leaving 20 bbl cement & 15 bb{ water in cement string. Sting into retainer & pump C~ 1 bpm ~ 340 psi, 15 bbl water away = 1080 psi. With cement Q retainer pump/squeeze cement, 1st bbl = 820 psi, pump 15 bbl, final pressure = 1400 psi ~ 1 bpm. Unsting pressure afters min = 600 psi. Unsting from retainer, circ out cement, pump C~3 335 gpm C 3650 psi, +- 5 bbl cement returns to surface. Pump & spot 33 bb{ high vis F1oPro pert pill. Printed: 8/15/2005 1:07:24 PM • BP EXPLORATION Operations Summary Report Page 10 of 11 Legal Well Name: 14-30 Common Well Name: 14-30 Spud Date: 1/17/1982 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/12/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/12/2005 Rig Name: NABOBS 2ES Rig Number: Date I From - To ~ Haurs I Task 8/9/2005 117:30 - 19:00 1.501 CEMT 19:00 - 23:00 4.00 CEMT 23:00 - 00:00 1.00 CEMT 8/10/2005 00:00 - 02:30 2.50 CEMT 02:30 - 03:30 1.00 PERF~ 03:30 - 06:00 2.501 PE 06:00 - 06:30 I 0.50 06:30 - 10:30 I 4.001 PE 10:30 - 11:30 1.00 PE 11:30 - 13:00 1.50 PE 13:00 - 14:30 I 1.50 14:30 - 20:00 5.50 20:00 - 21:00 1.00 21:00 - 00:00 3.00 8/11/2005 100:00 - 04:00 4.00 I PE 04:00 -04:30 0.50 PE 04:30 - 05:30 1.00 PE 05:30 - 06:30 1.00 RU 06:30 - 07:30 1.00 RU 07:30 - 21:00 13.50 RU 21:00 - 22:00 I 1.001 R 22:00 - 00:00 2.001 RU 8/12/2005 100:00 - 00:30 I 0.501 RU 00:30 - 03:00 I 2.50 I R Phase ' Description of Operations I Code ~NPT - _ _ _ _ _ __ X I CEMT I RUNPRD Test well bore to 1000 psi for 5 min, OK. Clean shaker possum belly & troughs. X CEMT RUNPRD R/D cement lines, install air slips, POH from 12465' to 2134'. X CEMT RUNPRD R/U power tongs & 2 7/8" handling equipment. POH UD 2 7/8" FOX tubing. X CEMT OTHCMP POH UD 2 7/8" FOX cement string. Clear rig floor. C OTHCMP Load pipe shed w/ 2.88 pert guns & 2 7/8" PAC drill pipe. Guns are 2906 PowerJet HMX guns C~ 6 spf, 60 degree phasing. C OTHCMP PJSM with SWS Perf. crew, rig crew, toolpusher &WSL. RIH P1U 2.88 pert guns. C OTHCMP R/U power tongs & handling tools, RIH with pert guns on 2 7/8" PAC drill pipe. C OTHCMP RIH with HT40 drill pipe. Tag EZSV cement retainer ~ 12461', 4' of fill. Rack back 1 stand of drill pipe. C OTHCMP WOO, assure guns are on correct depth. C OTHCMP Drop ball, pump down to firing head, ball on seat, fire guns. Monitor well. UD drill pipe pup & POH from 12461' to 10830'. Fill well through kill line # 2, well taking 15 bph. Perf intervals = 10860'-10900' 11190'- 11320' 11440'-11470' 11720'-11730' 11800'- 11840' 12290'-12310' 12410'- 12430'. Total = 290'. C OTHCMP CBU 1.5 times @ 250 gpm ~ 1750 psi. Losses to well = 15 bph. C OTHCMP POH UD 4" drill pipe from 10830' to 2144'. Static losses = 2 bph. C OTHCMP R!U power tongs & handling tools, UD PAC drill pipe. C OTHCMP PJSM with SWS, drill crew &WSL. POH UD perf guns from 1654'. C OTHCMP POH from 1150' UD 2.88" perf guns, all guns fired. Clear and clean rig floor. C OTHCMP M/U mule shoe &RIH with 5" drill pipe from derrick to 1700'. C OTHCMP POH LDDP. RUNCMP Pull wear ring, M/U landing jt, clear rig floor. RUNCMP R/U power tongs & handling equip for 4.5" 13Cr-80 tubing. RUNCMP RIH with 4.5", 12.6#, Vam Top, 13Cr-80 tubing. Tag bottom of tie back sleeve @ 10371'. Space out tubing. Shoe landed C~ 10365'. RUNCMP R/D power tongs & handling equipment. Drain BOP stack. M!U hanger & landing joint, land tubing & RILDS. RUNCMP R/U circ lines, reverse circ. displacing well to clean seawater, spot 70 bbls of corrossion inhibited seawater in annulus ~ 3 bpm ~ 200 psi. RUNCMP Complete displacement of corrossion inhibitor, 3 bpm C~3 200 psi. RUNCMP Drop ball & rod, test tubing to 3500 psi, OK. Test annulus to 3500 psi, OK. Shear DCK valve in GLM # 4 C~3 6527'. 03:00 - 03:30 0.50 BOPSU P OTHCMP Set 2 way check valve & test to 1000 psi. 03:30 - 04:30 1.00 BOPSU P OTHCMP N/D BOPE. 04:30 - 09:00 4.50 WHSUR P OTHCMP N/U tree & adaptor flange & test to 5000 psi. 09:00 - 09:30 0.50 WHSUR P OTHCMP R/U DSM Pull TWC. R/D DSM 09:30 - 11:00 1.50 WHSUR P OTHCMP R/U Little Red freze protect to 2200' w/ 78 Bbls diesel. Allow to U-tube. Blow down lines. Printed: 8!15!2005 1:07:24 PM Printed: 8/15/2005 1:07:24 PM T{2EE = 4 1/8" GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV - 71' SS BF. ELEV = 26.4' MD KOP= 9913 Max Angle = 100 deg. Datum MD = 12,531' Datum TV D = 8891' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2615' -~ 7" 26#, L-80 Liner tieback TOC ±3000' 7", 26#, TGII, L-80, ID = 6.276" ±4000' 'I~-30A as Complei~d 2112' ~~ 4-1/2" X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3358 3314 39 KBG2 DUM BK 1" 8/12/2005 4 6528 5704 41 KBG2 DCK BEK2 1" 8/12/2005 3 8381 7111 38 KBG2 DUM BK 1" 8/12/2005 2 9512 8011 37 KBG2 DUM BK 1" 8/12/2005 1 10218 8588 41 KBG2 DUM BK 1" 8/12/2005 4 1/2" 12.6# 13Cr-80 Vam Top 7", 26#, BTGM, L-80, ID = 6.276" 9715' Minimum ID = 3.725" XN' Nipple @ 10,353' 9705` -Top of Liner 9888' 9 5/8" Window 10,520' 7" 26# L-80 (6.276" ID) 9-5/8" CSG, 47#, L-80, ID = 8.681" 10382' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 11296' TOP OF 7" LNR 10075' 10,287' 4 1/2" X Nipple (3.813" ID) 10,308' 7" x 4 1/2" Baker S3 Packer 10,331' 4 1/2" X Nipple (3.813" ID) 10,353' 4 1/2" XN Nipple (3.725" ID) 10,359' 4 1/2" Hanger /liner top packer 10365' 4 1/2" WLEG 4 1/2" 12.6# 13Cr-80 solid PBTD 12,465' 6 1/8" Hole TD 12,531' PERFORATION SUMMARY REF LOG: BHCS ON 02105/82 ANGLE AT TOP PERF: 90 @ 10850' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10860-10900 O 08/10/05 2-7/8" 6 11190-11320 O 08/10/05 2-7/8" 6 11440-11470 O 08/10/05 2-7/8" 6 11720-11730 O 08/10/05 2-7/8" 6 11800-11840 O 08/10/05 2-7/8" 6 12290-12310 O 08/10/05 2-718" 6 12410-12430 O 08/10/05 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/82 ORIGINAL COMPLETION 05/07/82 LAST WORKOV ER 01/08/02 RN/TP CORRECTIONS 06/08/05 PGS Proposed 2005 Rig Sidetrack PRUDHOE BAY UNff WELL: 14-30A PERMff No: 1811660 API No: 50-029-20679-01 SEC 9, T10N, R14E, 2358.04' FEL & 119.11' FNL BP Exploration (Alaska) Halliburton Sperry-Sun North Slope Alaska BPXA 14-30A Job No. AKZZ3843032, Surveyed: 2 August 2005 S u r v e y R e p o r t 15 August, 2005 Your Ref.• API 500292067901 ' Surface Coordinates: 5938242.15 N, 675622.47E (70° 14' 12.8802" N, 148° 34' 54.8497" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 71.80ft above Mean Sea Level C3FtlL~tNG__ SEI~VECES Survey Ref:svy4645 A Hailibunan Carnpany Halliburton Sperry-Sun Survey Report for 14-30A Your Ref.• API 500292067901 Job No. AKZZ3843032, Surveyed: 2 August 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9800.80 34.000 150.150 8175.75 8247.55 2557.43 S 3603.62E 5935769.34 N 679284.68E 4018.86 Tie On Point MWD+IIFR+MS --. 9885.00 33.990 151.750 8245.56 8317.36 2598.59 S 3626.48E 5935728.73 N 679308.49E 1.063 4065.93 Window Point 9912.78 34.290 154.250 8268.55 8340.35 2612.48 S 3633.55E 5935715.01 N 679315.88E 5.164 4081.49 10004.47 35.190 162.270 8343.94 8415.74 2660.93 S 3652.83E 5935667.02 N 679336.28E 5.077 4133.08 10097.32 36.230 169.990 8419.37 8491.17 2713.46 S 3665.75E 5935614.80 N 679350.43E 4.978 4185.02 10190.50 38.540 175.900 8493.43 8565.23 2769.56 S 3672.62E 5935558.88 N 679358.60E 4.578 4237.01 10285.21 41.870 173.160 8565.75 8637.55 2830.39 S 3678.49E 5935498.20 N 679365.89E 3.981 4292.60 10376.70 43.930 173.460 8632.77 8704.57 2892.25 S 3685.75E 5935436.53 N 679374.58E 2.263 4349.76 10440.28 46.600 176.860 8677.52 8749.32 2937.24 S 3689.52E 5935391.64 N 679379.40E 5.662 4390.59 10464.24 48.270 175.660 8693.73 8765.53 2954.84 S 3690.68E 5935374.07 N 679380.97E 7.886 4406.40 10536.86 50.960 174.480 8740.78 8812.58 3009.95 S 3695.44E 5935319.09 N 679387.01E 3.905 4456.48 10568.03 54.520 174.050 8759.65 8831.45 3034.63 S 3697.92E 5935294.48 N 679390.07E 11.474 4479.08 10595.55 58.170 173.280 8774.90 8846.70 3057.39 S 3700.45E 5935271.78 N 679393.13E 13.466 4500.05 10629.23 62.840 172.060 8791.47 8863.27 3086.45 S 3704.20E 5935242.81 N 679397.55E 14.219 4527.08 10659.05 66.530 172.500 8804.22 8876.02 3113.16 S 3707.82E 5935216.19 N 679401.79E 12.446 4552.00 10689.98 70.370 173.160 8815.58 8887.38 3141.70 S 3711.41E 5935187.75 N 679406.04E 12.573 4578.50 10718.88 73.290 175.380 8824.59 8896.39 3169.02 S 3714.14E 5935160.50 N 679409.42E 12.464 4603.51 10755.25 78.000 178.110 8833.61 8905.41 3204.18 S 3716.13E 5935125.39 N 679412.22E 14.851 4634.94 10783.17 82.070 179.930 8838.44 8910.24 3231.67 S 3716.60E 5935097.92 N 679413.33E 15.928 4658.96 10817.81 87.100 181.450 8841.71 8913.51 3266.14 S 3716.18E 5935063.45 N 679413.72E 15.163 4688.59 10849.56 89.630 185.360 8842.62 8914.42 3297.81 S 3714.30E 5935031.74 N 679412.57E 14.663 4715.05 10878.04 92.040 189.320 8842.20 8914.00 3326.05 S 3710.66E 5935003.43 N 679409.59E 16.275 4737.66 10910.61 93.700 194.140 8840.57 8912.37 3357.89 S 3704.05E 5934971.44 N 679403.73E 15.634 4761.91 10942.21 93.700 198.800 8838.53 8910.33 3388.12 S 3696:11 E 5934941.01 N 679395.49E 14.716 4783.59 10971.52 93.460 203.900 8836.70 8908.50 3415.36 S 3684.47E 5934913.54 N 679385.49E 17.386 4801.83 11002.12 93.950 208.650 8834.72 8906.52 3442.73 S 3670.95E 5934885.86 N 679372.61E 15.573 4818.75 11035.72 94.010 212.010 8832.39 8904.19 3471.66 S 3654.03E 5934856.54 N 679356.37E 9.977 4835.30 11064.14 92.780 213.790 8830.70 8902.50 3495.47 S 3638.62E 5934832.37 N 679341.52E 7.604 4848.19 11095.97 90.860 215.840 8829.69 8901.49 3521.59 S 3620.46E 5934805.84 N 679323.97E 8.822 4861.69 11127.47 90.860 215.670 8829.22 8901.02 3547.15 S 3602.06E 5934779.86 N 679306.17E 0.540 4874.59 11157.79 90.930 215.530 8828.75 8900.55 3571.80 S 3584.41E 5934754.80 N 679289.10E 0.516 4887.08 11189.33 91.110 215.280 8828.18 8899.98 3597.50 S 3566.14E 5934728.68 N 679271.43E 0.977 4900.17 11221.58 91.540 215.010 8827.44 8899.24 3623.87 S 3547.58E 5934701.89 N 679253.49E 1.574 4913.69 11251.20 90.800 215.050 8826.83 8898.63 3648.12 S 3530.58E 5934677.25 N 679237.06E 2.502 4926.16 11283.79 89.810 215.160 8826.66 8898.46 3674.78 S 3511.84E 5934650.16 N 679218.95E 3.056 4939.84 • ~~ 15 August 2005 - 15:31 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1 4-30A Your Ref: API 500292067901 Job No. AKZZ3843032, Surveyed: 2 August 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coo rdinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11314.93 90.120 214.760 8826.68 8898.48 3700.30 S 3494.00E 5934624.23 N 679201.70E 1.625 4952.98 11344.57 90.370 214.250 8826.55 8898.35 3724.72 S 3477.20E 5934599.42 N 679185.48E 1.916 4965.71 11377.14 90.800 214.250 8826.22 8898.02 3751.65 S 3458.88E 5934572.08 N 679167.79E 1.320 4979.82 11408.87 89.630 214.700 8826.10 8897.90 3777.80 S 3440.92E 5934545.52 N 679150.44E 3.951 4993.46 11437.19 90.000 214.650 8826.19 8897.99 3801.09 S 3424.80E 5934521.86 N 679134.88E 1.318 5005.54 11471.74 90.430 213.950 8826.06 8897.86 3829.63 S 3405.33E 5934492.87 N 679116.08E 2.378 5020.49 11502.37 88.950 215.310 8826.23 8898.03 3854.84 S 3387.93E 5934467.27 N 679099.26E 6.562 5033.58 11533.04 88.890 215.710 8826.81 8898.61 3879.80 S 3370.12E 5934441.90 N 679082.04E 1.319 5046.25 11565.04 87.220 216.760 8827.89 8899.69 3905.59 S 3351.21E 5934415.67 N 679063.74E 6.164 5059.10 11594.93 87.040 218.240 8829.39 8901.19 3929.27 S 3333.04E 5934391.57 N 679046.12E 4.982 5070.49 11623.55 86.050 219.440 8831.11 8902.91 3951.53 S 3315.13E 5934368.91 N 679028.73E 5.430 5080.77 11659.43 86.050 219.380 8833.59 8905.39 3979.18 S 3292.40E 5934340.73 N 679006.66E 0.167 5093.32 11690.60 85.240 220.320 8835.95 8907.75 4003.04 S 3272.49E 5934316.41 N 678987.30E 3.974 5103.99 11718.11 84.990 220.640 8838.29 8910.09 4023.89 S 3254.69E 5934295.16 N 678970.00E 1.473 5113.12 11752.55 85.240 220.460 8841.23 8913.03 4049.96 S 3232.38E 5934268.57 N 678948.30E 0.893 5124.51 11783.34 85.240 221.160 8843.78 8915.58 4073.19 S 3212.33E 5934244.89 N 678928.80E 2.266 5134.56 11811.97 85.060 221.640 8846.20 8918.00 4094.59 S 3193.46E 5934223.05 N 678910.44E 1.785 5143.62 11846.39 83.690 224.170 8849.58 8921.38 4119.68 S 3170.15E 5934197.43 N 678887.71E 8.328 5153.65 11877.76 83.570 225.000 8853.06 8924.86 4141.88 S 3148.26E 5934174.72 N 678866.35E 2.657 5161.90 11905.64 83.940 225.260 8856.09 8927.89 4161.43 S 3128.62E 5934154.72 N 678847.17E 1.619 5168.98 11940.46 83.070 225.780 8860.03 8931.83 4185.67 S 3103.94E 5934129.91 N 678823.06E 2.906 5177.59 11971.49 83.260 225.290 8863.72 8935.52 4207.25 S 3081.95E 5934107.82 N 678801.58E 1.683 5185.25 12000.92 83.570 225.040 8867.10 8938.90 4227.87 S 3061.22E 5934086.73 N 678781.33E 1.350 5192.70 12092.02 87.350 223.540 8874.31 8946.11 4292.86 S 2997.82E 5934020.28 N 678719.46E 4.462 5217.18 12184.73 96.120 218.300 8871.50 8943.30 4362.78 S 2937.19E 5933948.96 N 678660.48E 11.015 5247.32 12273.58 98.100 216.490 8860.50 8932.30 4432.82 S 2883.65E 5933877.69 N 678608.59E 3.009 5281.10 12371.28 99.030 215.130 8845.95 8917.75 4511.17 S 2827.13E 5933798.06 N 678553.90E 1.674 5320.58 12463.63 99.730 213.430 8830.90 8902.70 4586.45 S 2775.81E 5933721.60 N 678504.35E 1.968 5360.02 12485.15 100.020 213.070 8827.21 8899.01 4604.18 S 2764.18E 5933703.60 N 678493.14E 2:129 5369.54 _ 12531.00 100.020 213.070 8819.23 8891.03 _ 4642.02 S 2739.55 E - 593665.20 N 678469.39E 0.000 5389.94 All data is in Feet (US Survey) unless ot herwise stated. Directions and coordinates are rel ative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 1 00 feet (US Survey). Vertical Section is from Well Reference and calcula ted along an Azimuth of 149.930° (True). BPXA Comment • i Projected Survey 15 August, 2005 - 15:31 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 14-30A Your Ref.' API 500292067901 Job No. AKZZ3843032, Surveyed: 2 August 2005 North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 12531.OOft., The Bottom Hole Displacement is 5390.12ft., in the Direction of 149.452° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) ift) lft) (ft) 9800.80 8247.55 2557.43 S 3603.62E Tie On Point 9885.00 8317.36 2598.59 S 3626.48E Window Point 12531.00 8891.03 4642.02 S 2739.55E Projected Survey BPXA • Survey tool program for 14-3OA From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 9800.80 8247.55 To Measured Vertical Depth Depth (ft) (ft) 9800.80 8247.55 12531.00 8891.03 Survey Tool Description CB-GYRO-MS (14-30) MWD+IIFR+MS (14-30A) 15 August, 2005 - 15:31 Page 4 of 4 DrillQuest 3.03.06.008 • 29-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-30A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PD1= files. Tie-on Survey: 9,800.80' MD Window /Kickoff Survey: 9,885.00' MD (if applicable) Projected Survey: 12,531.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ ~ e ~ ;~ ~ ~I r.... Date ~' . ~; ~ Signed ~- ~ `~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 29-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-30A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,800.80' MD Window /Kickoff Survey: 9,885.00' MD (if applicable) Pro}ected Survey: 12,531.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Cart Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ;~~~ , ~ n j,: i' f ~f Date ..~~~ ~~ Signed ` Please call me at 273-3545 if you have any questions or concerns. Regards, Car{ Ulrich Survey Manager Attachment(s) s ''l "'" L. ~ Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99.519-6612 Re: Prudhoe Bay 14-30A BP Exploration (Alaska) Inc. Permit No: 205-094 Surface Location: 2108' FNL, 872 FEL, SEC. 09, T10N, R14E, UM Bottomhole Location: 1452' FNL, 1794 FWL, SEC. 15, T10N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of th mmission to witness any required test. Contact the Commission's petrol f eld inspector at (907) 659- 3607 (pager). ~ ~ , DATED this day of June, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. NlGh- ~/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ~ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Developm 4M Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Wsetl Ns~rt>ae`:~rid'Afumber. PBU 14w3QA ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12530 TVD 9011 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location ofi Well (Governmental Section): Surface: 2108' FNL 872' FEL SEC 09 T10N R14E UM ~ 7. Property Designation: ADL 028314 Pool , , . , , , Top of Productive Horizon: 233' FNL, 2761' FWL, SEC. 15, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: /, July 15, 2005 Total Depth: 1452' FNL, 1794' FWL, SEC. 15, T10N, R14E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675622 y- 5938242 Zone- ASP4 10. KB Elevation Planned (Height above GL): 71.3' feet 15. Distance to Nearest Well Within Pool 1,175' to 13-32A 16. Deviated Wells: Kickoff Depth: 9925 feet Maximum Hoie Angle: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)/ Do ole: 3250 Surface: 2370 asing rogram: Size Spec cations Setting Depth 1 S~ To Bottom 'Quantity o ement c.f. or sacks Hofe Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M .784' 7400' 10534' 8792' 183 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr80 VAM To 2060' 10390' 8698' 12450' 9011' Uncemented Slotted Liner 19. PRESENT'W ELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11300 Total Depth TVD (ft}: 9534 Plugs (measured): 10066'& 10731' Effective Depth MD (ft): 10731 Effective Depth TVD (ft): 9033 Junk (measured): None Casing Length Size Cement Volume MD TVD tr t I on u for 76' 20" 1818# Poleset 76' 76' 2615' 13-3/8" 2800 sx Arcticset III, 400 sx AS II 2615' 2611' t 10382' 9-5/8" 500 sx Class 'G' 10382' 8732' Pr u ti n 1221' 7" 00 sx Class 'G' 10075' - 11296' 8475' - 9530' Perforation Depth MD (ft): 10454' - 10736' Perforation Depth TVD (ft): 8793' - 9037' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name ill Isaacson Title Senior Drilling Engineer prepared By Name/Number: Si nature Phone 564-5521 Date ~O/It+/05 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~~5-- ~ API Number: 50- 029-20679-01-00 Permit Approval See cover letter for Date: ,r / o ~ other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes ~ No Hydr a Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No Other: ~~ 5 ~ ~ ~~ lj ~ c;7 C' i/J S i, ~e,~ ~ S , 5 (C.) C i ~ ~ ~l ~~~~-Yi~~~~~e l3~ ~~r~- >~ S a.. f'~~us~ ~( , .~ ~ j `~ ~ APPROVED BY /` ~ D~ A roved ~ ~ ~ '~ e .a I I h ~ THE COMMISSION Date (~ Form 10-401 rised 00 ~+--~~ Sll~mit Ir~DupliCate • • Well Name: 14-30A Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Horizontal Sidetrack Producer Surface Location: X = 675,622 Y = 5,938,242 AS-BUllt 2107' FNL 872' FEL Sec. 9, T10N, R14E Umiat f Target Location: X = 679,341 Y = 5,934, ~ ~ TVDss 8845' ivishak Zone 4 233' FNL 2761' FWL Sec. 15, T Umiat Bottom Hole Location: X = 678,405 Y = 5,933,6 `"-~~ TVDss 8940' 1452' FNL 1794' FWL Sec. 15, meat AFE Number: PBD4P2386 Ri Nabors 2ES / Estimated Start Date: 07/15/05 O eratin da s to com lete: 17.0 MD: 1 3 TVD: 9,011' GL: 412.8' KB: 28.5' KBE: 71.3' Well Desi n conventional, slimhole, etc.: Two Strin Horizontal Sidetrack Ob'ective: Ivishak Zone 4 ulrecilvnal -Sperry wp0 9 KOP: 9925' MD Maximum Hole Angle: -50° in the 8-1/2" intermediate section , -97° in the 6-1/8" horizontal section Close Approach Wells: All welts pass major risk criteria for the planned 14-30A sidetrack. The closest well is DS13-32A at 1175' center-center and 390' allowable deviation. Surve Pro ram: MWD Standard + IIFR /Cassandra Nearest Pro ert Line: 13,500' to the nearest PBU propert line Nearest Well within Pool: ±1175' to 13-32A Casing/Tubing Program Hole Size Csg/Tbg O.D. WUFt Grade ~' Conn / Length toGlr Top MDlTVD Btm MD/TVD 8-1/2" 7" 26# L-80 BTC-M X784' 8,750'R,400' 10,534'!8,792' 6-1/8" 4 ~/z" Slotted 12.6# 13Cr-80 VAM To 2060' 10,390'/8698' 12,450'/9011' Tubin 4-1/2" 12.6# 13Cr-80 VAM To -10,360' GL 10,385'/8695' 14-30A Permit to Drill Page 1 Formation Markers C] Formation Tops (wp09) MD TVD TVDss Comments CM1 7495 -?424 ABOVE KOP THRZ 7960 -7889 " BHRZ 8119 -8048 " LCU 8157 -8086 TJD ±9900 8330 -8259 KOP 9925 8350 -8279 TJB 10,252 8603 -8532 TSGR 10,536 8793 -8721 TSAD 10,718 8885 -8814 45N 10,780 8904 -8$32 45P 11,832 8931 -8860 44N 12,075 8959 -8888 44P 12,235 8977 -8906 43N 12,349 8991 -891.9 TD /HOT 12,530 9011 -8940 OWC 9061 -8990 Not penetrated TD Criteria: Pro ose TD at HOT will rovide sufficient rat hole. Mud Program Section Milling Mud Properties: LSND Whip Stock Window 9-5/8", 47#~ Densit Viscosit PV YP TauO MBT PH 11.2 45-55 15-22 28-35 3-5 <20 9.0-9.5 Intermediate Mud Properties: LSND 8-1/2" hole section Densit Viscosit PV YP TauO MBT PH 1. 38-45 15-22 22-30 2-4 <20 9.0-9.5 Production Mud Properties: FloPro Densit Viscosit PV YP LSVR H APt FI 8.4 - 8.5 45-55 <10 25-35 >35,000 8.5 - 9.0 9-9.5 Lo in Pro ram 8-1/2" Intermediate: Sample Catchers -None Drilling: Dir/GR Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers -over entire interval, samples described Drilling:. Dir/GRlRes/AB{ Open Hole: None Cased Hole: None I I ~'Z- ~)~ ~ W 14-30A Permit to Drill Page 2 • • Cement Pro ram -Based on 227°F @8800' TVD Casing Size 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 609' of 7" X 8-1/2" open hole with 40% excess, 150' of 7" X 9 5/8" Liner Lap, and 200' of 9 5/8" X 4" DP excess. Tail TOC: 9775' MD TOL Total Cement Volume: Spacer 25 bbls Mudpush II @ .1.,2.2 ppg Tail 37.8 bbls, 212 ft3 /sacks Class G @ 15.8 ppg, .1 3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blindJshear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3100 si @ 8400' TVDss 7.1 EMW) Maximum surface ressure 226 si .10 si/ft as radient to surface Kick tolerance I Hite°with an 12.5 FIT Planned BOP test pressure R s test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 psi surface ressure Inte rit Test - 8-1/2" hole 12.5 FIT after drillin 20' from middle of window 7" Drilling Liner The VBRs will not be changed to accommodate the 760-ft 7" drilling liner. Instead, the current and best practice of picking up a joint of drillpipe, with crossover to the casing thread, will be employed in the event of a kick. This practice provides two rams capable of closing on the i e across the BOP stack instead of ~ust a sin le 7" ram. Production Interval Maximum antici ated BHP 3250 si @ 8800' TVDss (7.1 EMW Maximum surface ressure 2370- si .10 si/ft as radient to surface) Kick olerance fini with a 10.0 p FIT Planned BOP test pressure s test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin /7" Liner Test 3500 si surface pressure Inte rit Test - 6-1/8" hole 10.0 p FIT after drillin 20' of new hole Planned com letion fluids 8.5 p Seawater J 7.2 p Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 14-30A Permit to Drili Page 3 • • Sidetrack and Complete Procedure Summary Current Condition: / 100K lbs Carbolite frac'd into formation in 1989 and 1990 / Calipered tubing: good to poor condition with probable part at 6165' Holes in several joints, general and line corrosion. Restricted lD to 2.66" at 6151' 12/5/04 / IBP set below packer at 10,066; but unseated during 3/16/05 pressure test 1/21/05 / LIB showed SS bands of IBP (no fishing neck) at 10,104' 3/27/05 / Uncemented 13 3/8" x 9 5/8"annulus passes 2000 psi pressure test, but leaks to gas when on gas lift. Scope Pre-Riq Work: 1. Displace the well to clean seawater by circulating down the tubing through the tubing part. Continue to circulate until clean seawater returns to surface. Shut down and restart as required to allow all hydrocarbons to migrate and circulate out. 2. Perform infectivity test for cement squeeze. 3. Freeze protect to 2,100' MD with diesel. 4. Bleed casing and annulus pressures to zero. 5. Cycle the tubing hanger LDS and test the 9 5/8" mandrel packoff to 5000 psi. 6. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Riq Operations: 1. Ml f RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVlTWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPV/TWC. 4. R/U. Pull 4'/z" tubing from the parted depth at 6,165' MD and above. 5. RIH w/ 8'h" gauge ring /junk basket to top of tubing stub. 6. RIH with overshot on 4 ~/z" tubing workstring, latch parted tubing stub. 7. RU Schlumberger jet cutter and cut the tubing at ±9975', just above the AVA patch at 9987'. 8. Pull and lay down 4'/i" workstring and remaining, tubing. 9. RIH with HES EZSV and set the cement retainer as required to avoid cutting casing collar and place top of whip stock at 9925. 10. Pressure-test the 9 518" casing to 3,500psi for 30 minutes. Record test. 11. RIH with EZSV stinger and perform cement squeeze with 22 bbls (600' in 7" liner) class G cement. TOC= ±10,150' (tubing tail depth / 300' above top perf). 12. UCH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, , and set on bridge plug. Shear off of whip stock. 13. Displace the well to 11.2 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. ~~ I ~%' ° ~'~1t4. Mill window in 9 5/8" casing at ± 9,925' MD, plus approximately 20' beyond middle of window. ~~ ~ Circulate well bore clean. G~,r Y~ 15. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. 16. M/U 8'h" DirlGR assembly. RIH, kick off and drill the 81/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. i7. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3500 p '. 18. Run 7" liner tieback from TOL to surface. Cement from tieback sleeve to 30 ' MD. 19. Break BOP stack set casin on sli s rou h cut casin standback BOPs. - 9 P ~ 9 9~ 20. Dress casing stub and install packoff and casing and tubing spoof 21. NU and test BOPs 22. Test the 7" liner to 3,500psi for 30 minutes. Record the test. 23. M/U 6 1/8" Dir/GR/Res/ABI assembly. RIH to the landing collar. 14-30A Permit to Drill Page 4 • • 24. Drill out the 7" tieback and liner float equipment and cement to the shoe. / 25. Displace the well to 8.4 ppg Flo-Pro drilling fluid. / 26. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit / BHA change. 27. RIH, drill horizontal section to planned TD, short trip as necessary. ~~ 28. Circulate, short trip, spot liner running pill, POOH. 1 29. Run a 4'/z", 12.6#, 13Cr-80 slotted production liner. POOH L/D all drill pipe. 30. R!U and run 4112", 12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. j 31. Set a TWC and test to 1000 psi 32. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 33. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 34. Shear the DCK valve and freeze protect the well to 2,100'. Secure the well. /~ 35. Rig down and move off. Post-Rig Work: 1. Install well house and instrumentation 2. MI J RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP welt to test unit until cleaned up. 14-30A Drilling Program Job 1: MIRU Hazards and Contingencies - 14-30 is toward the end of the pad between 14-9A and 14-29 on 120' centers. Nowell houses will require removal or shut-in for the rig move onto 14-30. - LJ# ®s a ein# J-f~ site. Review H2S SOP and post H2S contingency plan in the doghouse. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL 14-29 30 1/28/2003 #2 Closest SHL 14-09B 20 12/9/2002 #1 Closest BHL 14-28 15 2(912005 #2 Closest BHL 14-26 25 11/11/2004 - DS14-30 last H2S 25ppm 9/8/03. Highest recorded on Pad: 1 4-07 8/22/04 200 ppm - Post Permit to Drill in the dog house and camp prior to spud Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies - A December 2004 caliper log indicates g good to poor tubing with a probable part at 6165'. Holes in several joints, general and line corrosion exist but are not expected to weaken the tensile strength bellow the 80°to rated level. 14-30A Permit to Drill Page 5 • • - Have a chemical cutter available for call-out in the event the tubing is not parted where expected. Discuss options for outside cutting or a blind back-off if the condition of the recovered end of the tubing suggests the remaining fish may be a difficult catch. - NORM test all retrieved well head and completion equipment. - Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP • "De-completions" RP Job 4: Window Mill Hazards and Contingencies - Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. - The 9 5/8" casing was cemented with 102 bbls of class G at 15.8 ppg. Partial returns were reported during the job with an estimate TOC at 9200' Cement is expected at the KOP. Reference RP • "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and;Contingencies - The intermediate section will kick off near the top of the Kingak D and TD at the top of Sag River. With relatively high inclination, 11.2 ppg mud weight will be required through the entire section. Follow all shale drilling practices to minimize potential problems. - Must tie MWD - GR back to GR log of parent well 14-30 (copy provided in wellsite geologist's package). - KICK TOLERANCE:, In the worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture gradie of j2.5 ppg at the 9-5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance is ' fi ' e. Reference RP ~" • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner and Liner Tieback Hazards and Contingencies - Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. - Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. 14-30A Permit to Drill Page 6 • • Reference RP • "Intermediate Casing Cementing Guidelines" RP • "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies - Hardlines are defined as follows: • Southwest: Due to proximity to fault and historical off-take at 14-08 location • NE is proximity to 14-26 • NW and SE are governed by proximity to injectors 14-27 and 13-32A - The planned wellbore is expected to cross two faults. Fault 1 has about 30' downthrown to upthrown character; it has a low to moderate risk of lost returns. Fault 2 is interpreted at the limits of detection, N-S trending, with a 10-15' throw upthrown to downthrown. It may not be seen during drilling. MD ~~ intersections are approximated. Minimize use of LCM and limit it to CaCO3 unless losses are catastrophic. - Be prepared to switch to a solid and cemented liner in the event of a significant lost circulation event. - KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fr ure gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance is fi ' e. `Reference RP • "Standard Operating Procedure: Leak-off and Formation .Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Slotted Production Liner Hazards and Contingencies - Differential sticking is a concern. The 8.5 ppg mud will be --700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will need to be run to extend 150' back up into the 7" intermediate liner. Reference RPs • "Use of 13-Cr Tubulars" • "Running and Handling 13-Cr" 14-30A Permit to Drill Page 7 • • Job 12: Run Completion Hazards and Contingencies - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP • "Completion Design and Running" RP • "Tubing connections" RP • "Use of 13-Cr Tubulars" • "Running and Handling 13-Cr" Job 13: ND/NU/Release Rig Hazards and Contingencies - No wells will require well house removal or shut-in for the rig move off of 14-30A. See MIRU section for nearest wells. Reference RP • "Freeze Protecting an Inner Annulus" RP 14-30A Permit to Drill Page 8 TREE _ ~ GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON - ~..F KB. ELEV = ~ 71' BF. ELEV - KOP = 2500' Max Angle = 44 @ 3900' Datum MD = . . 10545' ._ ,,,._... _..,,_pamw.. n Datum TV D = . ____..mV ~~~. 8800' SS ~ 14-30 ~ 0! 5-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 2$' TOP OF 4-1/2" TBG, 28' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2615' Minimum ID = 2.441" @ 9987' AVA PATCH TOP OF 7" LNR ~-~ 10075' ~4-1I2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10140' 9-5/8" CSG, 47#, L-80, ID = 8.681" 103$2' PERFORATION SUMMARY REF LOG: BHCS ON 02!05/82 ANGLE AT TOP PERF: 31 @ 10454' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-118" 4 10454 - 10476 O 09!01189 2-718" 4 10564 - 10582 O 12/27/82 2-718" 4 10592 - 10619 O 12/27!82 2-7/8" 4 10625 - 10650 O 12/27!82 4" 0 10734 - 10736 O 05/04/82 PBTD 11257' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11296' 2$' --I 5-1/2" X 4-112" XO f 2199' 4-1/2" CAM BAL-O SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2938 2923 18 MMG RK 2 5274 4752 41 MMG RK 3 7058 6097 42 MMG RK 4 8124 6912 39 MMG RK 5 8840 7473 38 MMG RK 6 9159 7728 37 MMG RK 7 9239 7792 37 MMG RK 8 9565 8053 37 MMG RK 9 9636 8111 35 MMG RK 10 9749 8205 34 MMG RK 11 9824 8267 34 MMG RK 12 9906 8335 34 MMG RK 13 9989 8404 34 MMG RK I 99$7' AVA DWP PATCH ID = 2 441" I I , . 10016' 4 1/2 BAKER PBR ASSY 10033' 9-518" X 4-1/2' BAKER SAB PKR 10066' ELM 4-112" (?) IBP (01!21/05) 10{ 12T f--+ 4-1/2" CAM DB-6 LANDING N1P; ID = 3.687" 10139' 4-1/2" BAKER SHEAROUT SUB 10140' 4-1/2" TUBING TAIL 10137' ELMD TT LOGGED 09!01!89 10731' 1---t cMr RETAINER DATE REV SY COMMENTS DATE REV BY COMMENTS 02!10182 ORIGINAL COMPLETION 01/21!05 NBF/PJC IBP SET 05107!82 LAST WORKOVER 01(08/02 RN/TP CORRECTIONS 09!29102 BM/7P WAVER SAFETY NOTE 02/20/03 lTLH WAVER SAFETY NOTE 11/06!04 JLW /TLP WAVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 14-30 PERMfT No: 1811660 API No: 50-029-20679-00 SEC 9, T10N, R14E, 2358.04' FEL & 119.11' FNL 8P Expioration (Alaska) _ GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV KOP = 2500' Max Angle - Datum MD Datum TV D = 8800' SS 14~OA Pro osed NOTES: p 13-3/8" CSG, 72#, N-80, ID = 12.347" 2615' -, 7" 26#, L-80 Liner tieback TOC ±3000' 7", 26#, TGII, L-80, ID = 6.276" ±4000' 4 1/2" 12.6# 13Cr-80 Vam Top 7", 26#, BTGM, L-80, ID = 6.276" 9755' 2100' )-~ 4-1l2" X NIP, ID = 3.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 MMG RK 4 MMG RK 3 MMG RK 2 MMG RK 1 MMG RK 9775` -Top of Liner 9925' 9 5/8" Window 10,340' 4 1/2" X Nipple (3.813" ID) Minimum ID = 3.725" ~ XN 10,350' 7" x 41/2" Baker S3 Packer 10,360' 4 1/2" X Nipple (3.813" ID) 10,.380' 4 1/2" XN Nipple (3.725" ID) 10,385' 4 1/2" Hanger /liner top packer 1 10390' 4 1/2" WLEG 10,534' 7" 26# L-80 {6.276" ID) '~ooo GAS LIFT MANDRELS TOP OF 7" LNR 10075' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10382' PERFORATION SUMMARY REF LOG: BHCS ON 02/05/82 ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 11296' l DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/82 ORIGINAL COMPLETION 05/07/82 LAST WORKOVER 01 /08/02 RN/TP CORRECTIONS 06/08/05 PGS Proposed 2005 Rig Sidetrack 4 112" 12.6# 13G-80 slotted PBTD 12,450' 6 1/8" Hole TD 12,530' PRUDHOE BAY UNff WELL: 14-30A PERMIT No: 1811660 API No: 50-029-20679-01 SEC 9, T10N, R14E, 2358.04' FEL & 119.11' FNL BP Exploration (Alaska) CCM1PAr,Y DETAILS REFF.RETCE R:FORMA7'10I: SLRVI:Y PR(IGRAM Plan: 14-30A wpM (14-30xPlan 14-30A1 yp Auaco CooN (R+1 R f N 11 CetWe IL70, Tm<~mh Depth Fm Uepth l' o Smvey?Im Tool Crated By. Digital BNSinesS Client User Date: 6x72005 1)~ Calenlar Metlnd'MinimumCmveture Ert S ISCWSA ~ Vm at lT~Ul k•f e. -42.87110 Sct I~S)Ref Skt 70 (OOON,OOOEI Mea. dtyeph RCf g. -42g 7110 992500 12530.H1 Plamxsd:14 30Awp09V56 MN'U-IFR-MS Checked'. Dale. hnd~: Tnv CylvWer ~o~ Scan Md CalcWo~ion MnhM Mminnm~(.tavaNrt Reviewed. Date: Emor Surf F.Wptiml-(using d ' tl d R le B s a+c N amvmg Me a : u -- FORMATION TOP DETAILS WELL Der.vl fSame -t::-S -FJ-W AoMmg tas0og Leotude Langtmde Slol CASING DETAILS No. TVDPath MDPath Formation lalo - u7o.lx taao.oa s97g2ao 97 6756'_169 70`14'12.1{698 lagili'S4871N' 10 No. TVD MD Name Size 1 8603.01 10251.98 TJB TARGET DETAILS 2 8792.67 10536.41 TSGR 1 8792.30 10535.82 7" 7.000 ~ 3 8885.49 10717.82 TSAD Name T'VD +N/-S +E/-W Northing Easting Shape 2 9011.27 12530.00 4 I/2" 4.500 114 8903.63 10779.72 45N 5 8931.37 11831.59 45P 14-30A T2 wp09 8886.30 -3753.01 3471.00 5934570.07 679178.93 Point 800 6 8959.22 12075.04 44N 14-30A TI N'P09 8916.30 -3403.01 3641.00 5934923.91 679340.72 Point - I ~ ~ ~ 7 8977.49 12234.81 44P 14-30A T3 wp09 901 L30 -4623A1 2676.39 5933681.85 678404.85 Point . ~ ~ I 8 8990.55 12348.92 43N - I. ~ ~ i I - -I ~ i ~ I SECTION DETAILS ~ ~ f ~' I ~ i I 1~ I ~ i I ~ Sec ', MD Inc Az i TVD +N/-S +E/-W DLeg TFace VSec Target l I -: l I - -- ~ - 1 9925.00 33.99 1 52.97 8350.43 -2618.63 3637.01 0.00 0.00 4088.49 ~. i _ _ _ ` 2 9945.00 35.57 1 56.13 8366.86 -2628.94 3641.91 12.00 50.00 4099.86 3 10467.83 50.72 1 77.57 8749.25 -2974.01 3712.83 4.00 52.42 4434.03 820 4 10533.77 50.72 1 77.57 8791.00 -3025.00 3715.00 0.00 0.00 4479.24 - _ _ ~ i - _ _ ~ 5 I 10553.77 50.72 1 77.57 8803.66 -3040.47 3715.66 .0.00 0.00 4492.96 - ~ _ _ -- _ - ~ 6 10899.42 90.68 200.00 8916.90 -3352.68 3659.31 X13.0 32.70 4734.93 g ~ ~ 1 I _ ~ 7 10947.76 90.68 200.00 8916.33 -3398.10 3642.78 {k00 0.00 4765.95 _.~ _ ,. ~ R 10952.98 90.00 200.00 8916.30 -3403.01 3641.00 "'ff(3.00 179.97 4769.30 I4-30A TI wp09 r , I , - I 9 11010.03 96.68 203.23 8912.98 -3455.92 3620.04 13.00 25.68 4804.60 - 10 11133.48 96.68 203.23 8698.62 -3568.60 357 L68 0.00 0.00 4877.88 I " I ~' ' Stmt 12'+YI00' ~~ 43TVD~ ~ - S' MD N35A - - - I l 11344.37 90.00 214.00 8886.30 -3753.01 3471.00 6.00 121.44 4987.03 14-30A T2 wp09 I i , . 12 11531.58 83.43 223.13 8897.04 -3898.94 3354.71 6.00 125.97 5055.06 . i '~ I I - _ _ 13 12530.30 83.43 223.13 9011.30 -4623.01 2676.39 0.00 0.00 5341.84 14-30A T3 wp09 840 ' ~ Siatt Dir4 ~ 1 j ~• ° ' _ _ _ I ` I ~ l I i ~ f ~ I I I - - _ ~.. 'I I i ~I f I ~ I ~ i ~ i o ~ i I 11j C ~ I End Uir .., lOp6 .8T MD,i87p9.2 i I _ I , ~ ~ f. ~ - .. . _ D r I /I '~: 10583.71 MA. RR 03~. I I ~ ~ ~' - _ _ yl - _ _ - - ' f j' ~~ ~. ~ - f I I . - - : [ ~ L ~ 860 , ~ ~ I ~ 1 ' u F ~ ~ - - i - - ~ _ ~ _ dDir ! Sta :10899.41'MD. rt Dir 13/100'.: 1 916. 7. 9"R'D 75' MII. 891 33'IVD. I - ~ '. ~ j ~' f ~ ~ ' _ _ ' ' " ~ - i 1 ~ ~ ~ ~ _ - ~ - r i I F.nd Dtr. 1 10 0.02 ' MA, 89t2.9 ' 8 I D ~ _ i~ / ~ ~ .._ I + j II Start r 6 1 :11.133.4 00 1 MD, 8898. 27V D ~ ~ .... -- - I ~ i ~ , ~ ~ - _ I t - I - ~ ~ En - d Dh :.l 153 57[ M p ' 8. - Z -' - -- _ ~ 4 ~ ~ ~ r- - ~ ~ ~ ~ ~' ~ /'hb :e 880 - I I I GR ~ - I - - - I ~ }. ~ i ~~ I ~~ I i _ i e~ ~ I I " ~ ~ -` ~ II TSAD ~ / .~ ~ ~5N ~ .~~ lo• 1 ! ~. LI _ ` 500~ . :,._ :- i ~ I I I _ 4400 4600 4800 5000 5200 5400 5600 5800 Vertical Section at 149.93° [200tVin~ cor.>YAn'r oeran.s tlP Amoco Cakvlxlion Medud~ Mmunum C.rmaane I:nnr Syslem~ ISCWSA Scan Medved: Trav ('yhMC AoM I.rtor Svfec<- LWplz~el - Ca.®g N'amin8 Method. Rules tleeN Co-ob~am<11:'kl Ref ore: Well Cane: 10.6, Tme f:cnh Venkal l7VDl Rekmrce. 28.5-42 8 ]I JO Uplh Fm Depth To Survry4'ho Tool Plan: I4-30A wp09114-30/Plan 14-30A1 . 5eclim IvSI Re(er<nre~ Sbt -1010.00~,0OOLI Mnsumd UCplh Re(ernxr: 08 5_428 4i'2S~ 12530_10 Plamad:l0.bA x7A9 V56 M - ('rested By: Digital Business Client User Dale: N7/2005 . ]I.IU ('ekuletion M<+hN Minmean Cws'ature WD-II R-AfS Checked: Date: K'ELL D(TAILS _ ~®e -t;l-S -E/-W M1pthing taslin 8 Lalinde Longinde Slot 10.6 -11]0.18 1440.01 5938240.9) 6]56'_1.69 fi'14'12.869A 148°34'Sd.B]3W 30 ', : ~~ ~ ~ ~ TARGET DETAILS - - - ~ ~ Nartle TVD +N/-S +E/-W Northin g Easting Shape - ; _ ~- ~ ~ 14-30A Poly 14-30A T2 wp09 8886.30 -2978.07 8886.30 -3753 01 3181.02 3471 00 5935337.99 678871.00 Polygon . - ' ~ ~ 14-30A TI wp09 4 . 8916.30 -3403.01 . 3641.00 5934570.07 679178.93 5934923.91 679340 72 Point P i t - 7806 ~ ~ 1 -30A Fault! 14-30A Fault 2 8971 30 -3501.16 8971.30 -4210 36 3005.77 2875 21 . 5934810.99 678708.00 o n Polygon . ~ __ I ~ _ ~ I I f i I4-30A T3 wp09 . 90!1.30 -4623.01 . 2676.39 5934098.99 678594.00 5933681.85 678404.85 Polygon Point FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8603.01 10251.98 TJB 2 8792.67 10536.41 TSGR 3 8885.49 10717.82 TSAD 4 8903.63 10779.72 45N 5 8931.37 11831.59 45P 6 8959.22 (2075.04 44N 7 8977.49 12234.R1 44P 8 8990.55 12348.92 43N c_ g h .~q 0 5 0 CASING DETAILS No. TVD MD Name Size I 8792.30 10535.82 7" 7.000 2 9011.27 12530.00 4 I/2" 4.500 ' ~ ~ : - ~ ~ ~ - ~ SECTION DETAILS ~ ~.' ;3'41D,4011.3'YVp ~' ' '~, ~ ~ Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target -~ ~ ' - ~ I ! ~ ! ~ ~ 1 2 9925.00 9945.00 33.99 35.57 152.97 156.13 8350.43 8366 86 -2618.63 -2628 94 3637.01 0.00 0.00 4088.49 ' ~ ~ ~ ~ ~ ~ ~ 3 (0467.83 50.72 177.57 . 8749.25 . -2974.01 3641.9! 3712 83 12.00 4 00 50.00 52 4099.86 - ~ -. i 4 10533.77 50.72 177.57 8791.00 -3025.00 . 3715 00 . 0 00 .42 0 00 4434.03 5 10553.77 50.72 177.57 8803 66 -3040 47 . . . 4479.24 I 6 10899.42 90.68 200.00 . 8916 90 . -3352 68 3715.66 0.00 0.00 4492.96 1 ' 7 10947.76 90.68 200.00 . 8916.33 . -3398.10 3659.31 3642 78 13.00 0 00 32.70 0 00 4734.93 ' 8 9 10952.98 1010.03 90.00 6 68 200.00 03 23 8916.30 9 -3 403.01 . 364 1.00 . I 3.00 . 79.97 4765.95 769.30 _ 14 3 OA TI w 09 10 11133.48 . 96.68 . 203.23 12.98 8898.62 -3455.92 -3568.60 3620.04 3571 68 13.00 0 00 25.68 0 4804.60 p ) 4000 II 12 11344.37 11531.58 90.00 83.43 214.00 223 13 8886.30 8897 04 -3753.01 . 3471.00 . 6.00 .00 121.44 4877.88 4987.03 14-30A T2 wp09 West(-)/East(+) [SOONinj 13 12530.30 83.43 . 223.13 . 9011.30 -3898.94 -4623 01 3354.71 2676 39 12 84 - . . 0.00 0.00 5341. 14-30A i3 wp09 • Sperry-Sun BP Planning Report Company: BP Amoco Date: 6(7!2005 Time: 16:57:05 Page: 1 Field: Prudhoe Bay Ce-ordinate(NE) Reference: WeA: 1430, True North Site: PB DS 14 Vertical (TVD) Reference: 28.5 + 42.8 71.3 Well: 14-30 Section (VS) Reference: Well (O.OON,O.OOE,149.93Azi) We(Ipath: Plan 1430A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 1430A wp09 Date Composed: 4/4/2005 Version: 56 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 14 TR-10-14 UNITED STATES :North Sbpe Site Position: Northing: 5939577.43 ft Latitude: 70 14 26.346 N From: Map Easting: 674150.48 ft Longitude: 148 35 36.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.32 deg Well: 1430 Slot Name: 30 14-30 Well Position: +N/-S -1370.18 ft Northing: 5938240.97 ft Latitude: 70 14 12.869 N +E/-W 1440.04 ft Easting : 675621.69 ft Longitude: 148 34 54.873 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10535.82 8792.30 7.000 8.500 7" 12530.00 9011.27 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 WS1 0.00 0.00 0.00 CM2 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 0.00 BHRZ 0.00 0.00 0.00 LCU 0.00 0.00 10251.98 8603.01 TJB 0.00 0.00 10536.41 8792.67 TSGR 0.00 0.00 10717.82 8885.49 TSAD 0.00 0.00 10779.72 8903.63 45N 0.00 0.00 11831.59 8931.37 45P 0.00 0.00 12075.04 8959.22 44N 0.00 0.00 12234.81 8977.49 44P 0.00 0.00 12348.92 8990.55 43N 0.00 0.00 0.00 HOT 0.00 0.00 0.00 OWC 0.00 0.00 0.00 TCGL 0.00 0.00 0.00 32SB 0.00 0.00 0.00 31 SB 0.00 0.00 0.00 BCGL 0.00 0.00 0.00 23S6 0.00 0.00 0.00 22TS 0.00 0.00 0.00 21 TS 0.00 0.00 0.00 TZ1 B 0.00 0.00 0.00 TDF 0.00 0.00 0.00 BSAD 0.00 0.00 • Sperry-Sun BP Planning Report • r Company: BP Amoco Date: 6fl/2005 Time: 16:57:05 Page: 2 I Field: Prttdhce Bay Ce-erdinate(NE) Reference: Weil: 14-30, True North Site: PB DS 14 Vertical (TVD) Reference: 28.5 + 42.8 71.3 WeA: 14-30 Section (YS) Reference: Well (O.OON,O.OOE,149.93Azi) Wellpath: .Plan 14-30A Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude --> ~-- I.ongitade ---> Name Description TVD +N!-S +Ef-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 14-30A Poly 8886.30 -2978.07 3181.02 5935337.99 678871.00 70 13 43.573 N 148 33 22.457 W -Polygon 1 8886.30 -2978.07 3181.02 5935337.99 678871.00 70 13 43.573 N 148 33 22.457 W -Polygon 2 8886.30 -3583.52 3793.12 5934746.99 679497.00 70 13 37.615 N 148 33 4.683 W -Polygon 3 8886.30 -5107.26 2643.25 5933196.99 678383.00 70 13 22.634 N 148 33 38.102 W -Polygon 4 8886.30 -4787.77 2154.52 5933504.99 677887.00 70 13 25.778 N 148 33 52.294 W -Polygon 5 8886.30 -2978.07 3181.02 5935337.99 678871.00 70 13 43.573 N 148 33 22.457 W 14-30A T2 wp09 8886.30 -3753.01 3471.00 5934570.07 679178.93 70 13 35.950 N 148 33 14.043 W 14-30A T1 wp09 8916.30 -3403.01 3641.00 5934923.91 679340.72 70 13 39.392 N 148 33 9.100 W 14-30A Fauft 1 8971.30 -3501.16 3005.77 5934810.99 678708.00 70 13 38.429 N 148 33 27.555 W -Polygon 1 8971.30 -3501.16 3005.77 5934810.99 678708.00 70 13 38.429 N 148 33 27.555 W -Polygon 2 8971.30 -3755.60 3579.04 5934569.99 679287.00 70 13 35.924 N 148 33 10.905 W 1430A Fault 2 8971.30 -4210.36 2875.21 5934098.99 678594.00 70 13 31.454 N 148 33 31.355 W -Polygon 1 8971.30 -4210.36 2875.21 5934098.99 678594.00 70 13 31.454 N 148 33 31.355 W -Polygon 2 8971.30 1t751.57 2876.61 5933557.99 678608.00 70 13 26.132 N 148 33 31.321 W 14-30A T3 wp09 9011.30 -4623.01 2676.39 5933681.85 678404.85 70 13 27.397 N 148 33 37.135 W Plan Section Information MD Incl Aim TVD +N!-S +E!-W DLS Bu~7d Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9925.00 33.99 152.97 8350.43 -2618.63 3637.01 0.00 0.00 0.00 0.00 9945.00 35.57 156.13 8366.86 -2628.94 3641.91 12.00 7.92 15.80 50.00 10467.83 50.72 177.57 8749.25 -2974.01 3712.83 4.00 2.90 4.10 52.42 10533.77 50.72 177.57 8791.00 -3025.00 3715.00 0.00 0.00 0.00 0.00 10553.77 50.72 177.57 8803.66 -3040.47 3715.66 0.00 0.00 0.00 0.00 10899.42 90.68 200.00 8916.90 -3352.68 3659.31 13.00 17.56 6.49 32.70 10947.76 90.68 200.00 8916.33 -3398.10 3642.78 0.00 0.00 0.00 0.00 10952.98 90.00 200.00 8916.30 -3403.01 3641.00 13.00 -13.00 0.01 179.97 14-30A T1 wp09 11010.03 96.68 203.23 8912.98 -3455.92 3620.04 13.00 11.71 5.66 25.68 11133.48 96.68 203.23 8898.62 -3568.60 3571.68 0.00 0.00 0.00 0.00 11344.37 90.00 214.00 8886.30 -3753.01 3471.00 6.00 -3.17 5.11 121.44 14-30A T2 wp09 11531.58 83.43 223.13 8897.04 -3898.94 3354.71 6.00 -3.51 4.88 125.97 12530.30 83.43 223.13 9011.30 -4623.01 2676.39 0.00 0.00 0.00 0.00 14-30A T3 wp09 Survey MD Incl Azim TVD SysTVD N!S E1W DLS MapN MapE TooUComm t ft deg deg ft ft ft ft deg/10fJft ft ft 9925.00 33.99 152.97 8350.43 8279.13 -2618.63 3637.01 0.00 5935707.92 679318.47 Start Dir 12?/1 9945.00 35.57 156.13 8366.86 8295.56 -2628.94 3641.91 12.00 5935697.74 679323.60 Start Dir 4?/10 10000.00 36.95 159.03 8411.21 8339.91 -2659.01 3654.30 4.00 5935667.97 679336.69 MWD+IFR+MS 10100.00 39.62 163.84 8489.71 8418.41 -2717.72 3673.94 4.00 5935609.73 679357.69 MWD+IFR+MS 10200.00 42.47 168.13 8565.14 8493.84 -2781.41 3689.76 4.00 5935546.43 679374.99 MWD+IFR+MS 10251.98 44.00 170.17 8603.01 8531.71 -2816.37 3696.46 4.00 5935511.64 679382.50 TJB 10300.00 45.45 171.96 8637.13 8565.83 -2849.76 3701.70 4.00 5935478.39 679388.51 MWD+IFR+MS 10400.00 48.56 175.41 8705.33 8634.03 -2922.43 3709.68 4.00 5935405.92 679398.19 MWD+IFR+MS 10467.83 50.72 177.57 8749.25 8677.95 -2974.01 3712.83 4.00 5935354.43 679402.54 End Dir :1046 10500.00 50.72 177.57 8769.62 8698.32 -2998.89 3713.89 0.00 5935329.59 679404.18 MWD+IFR+MS 10533.77 50.72 177.57 8791.00 8719.70 -3025.00 3715.00 0.00 5935303.51 679405.89 MWD+IFR+MS 10535.82 50.72 177.57 8792.30 8721.00 -3026.59 3715.07 0.00 5935301.93 679406.00 7" 10536.41 50.72 177.57 8792.67 8721.37 -3027.04 3715.09 0.00 5935301.47 679406.03 TSGR 10553.77 50.72 177.57 8803.66 8732.36 -3040.47 3715.66 0.00 5935288.06 679406.91 Start Dir 13/10 10600.00 55.84 181.49 8831.30 8760.00 -3077.50 3715.92 13.00 5935251.05 679408.04 MWD+IFR+MS 10700.00 67.27 188.57 8878.90 8807.60 -3164.84 3707.94 13.00 5935163.55 679402.10 MWD+IFR+MS • Sperry-Sun BP Planning Report Compaey: BP Amoco Date: 6/7/2005 Tim e: 16:57:05 Page: 3 FSeId: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-30, True North Site: PB DS 14 Vertical (TVD} Reference: 28.5 + 42.8 71.3 Well: 14-30 Sectio n(VS)Reference: WeII(O.OON,O.OOE,149.93Azi) WellpatL: Plan 14-30A Survey Calculation Metbod: Minimum Curvature Db: Qrade Survey MD Intl Azim TVD Sys TVD N/S F./W DLS MapN MapE ToollComm t ft deg deg ft ft ft ft deg/100ft ft ft 10717.82 69.34 189.69 8885.49 8814.19 -3181.19 3705.32 13.00 5935147.15 679399.85 TSAD 10720.13 69.60 189.83 8886.30 8815.00 -3183.31 3704.95 13.00 5935145.02 679399.53 14-30A Poly 10779.72 76.57 193.38 8903.63 8832.33 -3239.12 3693.46 13.00 5935088.96 679389.35 45N 10800.00 78.95 194.53 8907.93 8836.63 -3258.35 3688.68 13.00 5935069.63 679385.02 MWD+IFR+MS 10899.41 90.68 200.00 8916.90 8845.60 -3352.67 3659.32 13.00 5934974.65 679357.86 End Dir :1089 10900.00 90.68 200.00 8916.90 8845.60 -3353.23 3659.11 0.17 5934974.09 679357.67 MWD+IFR+MS 10947.76 90.68 200.00 8916.33 8845.03 -3398.10 3642.78 0.00 5934928.85 679342.39 Start Dir 13/10 10952.98 90.00 200.00 8916.30 8845.00 -3403.01 3641.00 13.00 5934923.91 679340.72 14-30A T1 wp0 11000.00 95.51 202.66 8914.04 8842.74 -3446.74 3623.92 13.00 5934879.79 679324.67 MWD+IFR+MS 11010.03 96.68 203.23 8912.98 8841.68 -3455.92 3620.04 13.00 5934870.52 679321.00 End Dir :1101 11100.00 96.68 203.23 8902.51 8831.21 -3538.04 3584.79 0.00 5934787.61 679287.68 MWD+IFR+MS 11133.47 96.68 203.23 8898.62 8827.32 -3568.59 3571.68 0.00 5934756.77 679275.28 Start Dir 6/100 11133.48 96.68 203.23 8898.62 8827.32 -3568.60 3571.68 0.01 5934756.76 679275.28 MWD+IFR+MS 11200.00 94.59 206.64 8892.08 8820.78 -3628.61 3543.77 6.00 5934696.12 679248.78 MWD+IFR+MS 11300.00 91.41 211.74 8886.85 8815.55 -3715.74 3495.08 6.00 5934607.88 679202.13 MWD+IFR+MS 11344.37 90.00 214.00 8886.30 8815.00 -3753.01 3471.00 6.00 5934570.07 679178.93 14-30A T2 wp0 11400.00 88.04 216.70 8887.25 8815.95 -3798.36 3438.82 6.00 5934523.98 679147.82 MWD+IFR+MS 11500.00 84.53 221.58 8893.73 8822.43 -3875.73 3375.87 6.00 5934445.17 679086.69 MWD+IFR+MS 11531.57 83.43 223.13 8897.04 8825.74 -3898.93 3354.72 6.00 5934421.48 679066.08 End Dir :1153 11531.58 83.43 223.13 8897.04 8825.74 -3898.94 3354.71 6.00 5934421.47 679066.08 MWD+IFR+MS 11600.00 83.43 223.13 8904.87 8833.57 -3948.54 3308.24 0.00 5934370.81 679020.78 MWD+IFR+MS 11700.00 83.43 223.13 8916.31 8845.01 X021.04 3240.32 0.00 5934296.75 678954.57 MWD+IFR+MS 11800.00 83.43 223.13 8927.75 8856.45 -4093.54 3172.40 0.00 5934222.69 678888.36 MWD+IFR+MS 11831.59 83.43 223.13 8931.37 8860.07 -4116.45 3150.94 0.00 5934199.30 678867.45 45P 11900.00 83.43 223.13 8939.19 8867.89 -4166.04 3104.48 0.00 5934148.64 678822.16 MWD+IFR+MS 12000.00 83.43 223.13 8950.63 8879.33 ~t238.54 3036.57 0.00 5934074.58 678755.95 MWD+IFR+MS 12075.04 83.43 223.13 8959.22 8887.92 -4292.95 2985.60 0.00 5934019.00 678706.27 44N 12100.00 83.43 223.13 8962.07 8890.77 -4311.04 2968.65 0.00 5934000.52 678689.74 MWD+IFR+N-S 12200.00 83.43 223.13 8973.51 8902.21 -4383.54 2900.73 0.00 5933926.46 678623.54 MWD+IFR+MS 12234.81 83.43 223.13 8977.49 8906.19 -4408.77 2877.09 0.00 5933900.69 678600.49 44P 12300.00 83.43 223.13 8984.95 8913.65 -4456.04 2832.81 0.00 5933852.41 678557.33 MWD+IFR+MS 12348.92 83.43 223.13 8990.55 8919.25 -4491.51 2799.58 0.00 5933816.17 678524.94 43N 12400.00 83.43 223.13 8996.39 8925.09 -4528.54 2764.89 0.00 5933778.35 678491.12 MWD+IFR+MS 12500.00 83.43 223.13 9007.83 8936.53 -4601.04 2696.97 0.00 5933704.29 678424.92 MWD+IFR+MS 12530.00 83.43 223.13 9011.27 8939.97 X622.79 2676.60 0.00 5933682.07 678405.05 4112" 12530.30 83.43 223.13 9011.30 8940.00 -4623.01 2676.39 0.00 5933681.85 678404.85 14-30A T3 wp0 TERRIE L RUBBLE ss-s~,ze2 208 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612- MB 7-5 ~ o.~ ANCHORAGE, AK 995.19-6612 DATE J PAY TO THE (~~ ORDER OF ~ ~ ' ~ • DOLLARS First National Bank Alaska Anchorage, AK 99501 MEMO~~~ ~~~~I~~P!/ 1 i ~~~F~~~v~. c ~~ L 25.200060:99 L4~~~6 2 27~~~ 1556~~' 0 208 • • TRANSMITAL LETTER CHECK LIST APPROPRIATE LETTER/PARAGRAPHS TO INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ ~~ PTD# ~-d S~ - ~~~~ - CHECK WH T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (p)~ 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 welt (name on permit). SPACING The permit is approved subject to fall EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\tra nsm itta{_cfiecklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 Well Name: PRUDHOE BAY UNIT 14-30A Program DEV Well bore seg ^ PTD#:205D940 Company BP EXPLORATION (ALASKA) INC Initial Classlfype DEV 11-OIL GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mikfeeattached----------------------------------- --------Yes --------------------------------------------------.- 2 Lease number appropriate__________________-__--______- _---__-_Yes -_- --__, 3 Uniquewell.nameand number______________ _ Yes _____-- 4 Welllocat_edina_defned_pool---------------------------- ---__---Yes -----.----------------------__ - - - - 5 Well locatedproperdistanGefromdrillingunitboundary_-_--_______ _________Yes _-__--__,___-______-___-___-__-__-__--__-___-______---___-__-____--__--_ 6 Well located properdistancef[omotherwells____________ ________ _________Yes _____-__- - - - - ------ 7 Sufficient acreageavail_ablein_drillingunit__--__-__.__-._____-_ __-__--_Yes ______________ 8 If deviated, is-we_Ilboreplat_included_-___-___________________ ____---Yes -___--__,__-___-___,_--__-___-__- 9 Oper_atoronlyaff_ectedparty_--_-.______________________ __-_- __Yes ____--__._ - - 10 Operakorhasappropriate-bondinforce---- --- ------- -- -- -- -----Yes ----- -- --- -------- -- -- ------ -- -- ------------ ---- -- ---- 11 Permitcanbeissuedwithoutconservatipnorder__________________ __,__-__Yes -__-_____--______-__-___-_____-__ -------------------------------------- Appr Date 12 Permit_canbeissuedwithoutadministrative_approval---------------- --------- Yes ____-__-___-___-___,___-__ ----------------------------------------------- RPC 6!17/2005 13 Can permit be approved before 15-day wait Yes ' 14 Well located within area andslrataauthorizedby-Injeotion0r-der#(put_10#in_comments)_(For_ NA_ _-_______________________ __--___-_-----_______--_-__-___-_-_---__-- 15 All wells-within1f4-mile area ofreyiewidentified(FO[servicewell only)______ _________NA_ _-__--__-________-___-___-__-___-_____-___________-___--__.-__--_-,--_----- 16 Pre-produced injector; dur_akion of preproduction less than_ 3 months_(For servi-ce well only) - _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ - _ - - _ - - _ _ - _ _ - - _ - . _ 17 ACMP_FindingofConsistency_hasbeenissued_for_thisproject__________ ________-NA_ _____________________--_-__-__- Engineering 18 Condu_ctorstring_p_rovided__-__-________-- ___ ___--____ NA_ ___--___ 19 Surface casing-protects all known i1SDWs - - - - - - - NA - - - - - - - - - - 20 CMT_voladeguate_tocirculake-onconductoc&surf_csg-_____________ _________ NA_ __--__.___--_-__--_.-__.-__.___,_-_____________-------------__--_-_,-__- 21 CMT_vol-adequate_totie-in long string to surf csg--_--_-_--___ __-__-NA- _-------------------------- - - - - - 22 .C_MT-will coyer all knownproductive horizons_ _ , - - _ _ - No_ _ . Slotted_production liner. - - - 23 CasingdesgnsadequateforC,_T,B&_per-maf[ost_-_-.--- --- -- --- --_--Yes --------,---------- ----------------------------------- ----------------- 24 Adequatetankage_orreseruepit- ------------------------_ -__--_--Yes ___-__-Nabors2ES,__--__--_--__-__--_ - - 25 If_a_re-drill,has_a_1.0-403 forabandon_mentbeenapproved___-__-___-_ ____ -__-Yes -______'-_____-________________--__-- ________-_--_-.-__--__--_-_--__- 26 pdequatewellboreseparation-Proposed- ------ ----- - --- --- - Yes --- --- -- --- -- -- -- --------- --- -- -- ----- - -- ----- -- - 27 If_diverterrequired,doesitmeetregulations______________________ _________ NA_ _-___$idetrack.-_-_-_________--__-_____-__-__-__--__-__--__-.-_ Appr Date 28 D_rillingfluid-program sehematic&equiplistadequate___-___-_______ _________Yes _-----_MaxMW_11,2-ppg._-__-__-______________.___-_--_-.-__---_---_----_ WGA 6120!2005 29 BOPEs,-do they meet regula_tion_.-__-_ _.Yes ________________-_____- __-__--_--__--__-____--_ __----_---_-----.-_- 30 BOPE.press rating app[opriate; tesk to_(put prig in comments)_ _ _ _ _ _ _ _ - _ _ _ _ - - _ Yes _ _ _ - _ Test to 3500_ psi. -MSP 2370 psi, - - _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . , 31 Choke_manifoldcompliesw/APIRP-53(May84)__.___-___-_______ _________Yes- -___.__-______--_-___-__--________-______-___,______--__--__---_--_-- --_ 32 Work will occurwithoutAperationshutdown____________ ________ ______-__Yes ____--__-_ _-_____.-_,___ -___-___--__----__-_--_--_____---__-__--_- 33 Is presence of H2S gas-probable - - Yes _ 25 ppm• - - - 34 Mechanical_conditionofwellswithinAORverified(For_servicewellonly)_____ _________NA__ __-__--_--_---__--_------__,-_-___---_--_--__--__-__ ___-__-,___-----_- Geology 35 Pe[mit_eanbeissuedwlohydrogen_sulfidemeasu[es-_______-_,-__ -__-_____ No- -__________________________ 36 Data_presented on-potential overpressure zones_ - - NA_ - - Appr Date 37 Seismic analysis of sballpw gas_zones_ . - - _ - _ _ - - - . NA - - RPC 6!1712005 38 Seabed condition survey-(ifoff-shore) - - - NA 39 _Conta_ctna_m_elphonefor_weeklyprogressrepo[ts[exploratoryonly) _______ __________N_A__ __-__ ___.--_--__-__--_--__-_______--_---_--__--__-.-_--_ Geologic Engineering P is Commissioner: Date: Commissioner: Date ion r Date ~~~. ~'~ ~ °s~ ~ Zo 0 • 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 infom~ation, information of this nature is accumu{ated at the end of the file under APPENDIX. No special effort has been made to chronologically organi2e this category of information. a~~ a9y Sperry-Sun Drilling Services LI5 Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 11 07:47:23 2006 Reel Header Service name ........ .....LISTPE Date ................ .....06/O5/11 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....06/OS/11 Origin .............. .....STS Tape Name ........... .....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: MW0003843032 LOGGING ENGINEER: N. WHITE OPERATOR WITNESS: J. RALL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD '~ r3°~3~ Scientific Technical Services Scientific Technical Services 14-30A 50029206790100 BP Exploration (Alaska) Inc. Sperry Drilling Services 11-MAY-06 MWD RUN 2 MWD RUN 3 MW0003843032 MW0003843032 N. WHITE A. SHANAHAN J. RALL D. MA5KELL 9 lON 14E 2107 872 71.80 42.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 13.625 2615.0 2ND STRING 6.125 7.000 10520.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 14-30 • • WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9885'MDf8317'TVD. 4. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 1. 5. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4) RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD), AND RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) TIE-IN SGRC DATA OVER THE INTERVAL 9610'MD-9883'MD WERE ACQUIRED DURING A MAD PASS. THESE DATA ARE MERGED WITH RUN 2 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER CNL GAMMA RAY LOG RUN IN 14-30 ON 5 FEBRUARY 1982. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 8 MAY 2006, AS AUTHORIZED BY BOB GERIK(BP PE). 7. MWD RUNS 1-3 REPRESENT WELL 14-30A WITH API#: 50-029-20679-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12531'MD/8891'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/11 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9602.5 12473.0 ROP 9881.0 12526.5 RPX 10469.5 12480.5 RPS 10469.5 12480.5 RPM 10469.5 12480.5 RPD 10469.5 12480.5 FET 10469.5 12480.5 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9602.5 9610.0 9604.0 9611.5 9605.0 9614.0 9607.0 9615.5 9609.0 9618.0 9615.0 9624.0 9618.0 9627.0 9623.0 9631.5 9630.5 9638.5 9635.0 9643.0 9637.0 9645.5 9643.5 9651.5 9648.0 9657.0 9657.0 9661.5 9659.0 9662.5 9664.5 9669.0 9668.0 9671.5 9678.5 9680.5 9685.5 9688.0 9691.5 9695.0 9694.5 9697.0 9697.5 9700.5 9701.5 9703.5 9713.5 9717.0 9717.0 9720.0 9722.5 9726.0 9729.0 9732.5 9745.5 9749.5 9756.5 9760.0 9766.5 9770.0 9769.0 9773.5 9772.5 9776.0 9778.5 9781.0 9786.0 9790.0 9795.5 9799.5 9805.0 9808.5 9806.5 9810.5 9809.5 9813.0 9815.5 9819.5 9819.5 9824.0 9823.5 9828.0 9832.5 9836.0 9860.0 9865.0 9862.0 9868.0 9870.5 9874.5 9876.0 9879.5 9877.5 9881.5 9879.5 9884.0 12526.5 12531.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9885.5 9912.0 MWD 2 9912.0 10520.0 MWD 3 10520.0 12531.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9602.5 12526.5 11064.5 5849 9602.5 12526.5 RPD MWD OHMM 0.09 2000 44.403 4023 10469.5 12480.5 RPM MWD OHMM 0.37 2000 43.1751 4023 10469.5 12480.5 RPS MWD OHMM 1.13 1509.61 14.7256 4023 10469.5 12480.5 RPX MWD OHMM 1.15 1597.98 14.2657 4023 10469.5 12480.5 FET MWD HOUR 0.28 97.08 3.42056 4023 10469.5 12480.5 GR MWD API 13.13 578.57 64.7046 5742 9602.5 12473 ROP MWD FT/H 0.72 443.89 103.637 5292 9881 12526.5 First Reading For Entire File..........9602.5 Last Reading For Entire File...........12526.5 File Trailer Service name .......... ...STSLIB.001 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/O5/11 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..... ..06/O5J11 Maximum Physioal Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9885.5 9912.0 LOG HEADER DATA DATE LOGGED: 25-JUL-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9912.0 TOP LOG INTERVAL (FT) 9885.0 BOTTOM LOG INTERVAL (FT) 9912.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 • • MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT): 2615.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) 11.20 MUD VISCOSITY (S) .0 MUD PH: .0 MUD CHLORIDES (PPM): 0 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 9885.5 9912 9898.75 54 9885.5 ROP MWDO10 FT/H 1.69 22.71 6.33667 54 9885.5 First Reading For Entire File..... .....9885.5 Last Reading For Entire File...... .....9912 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O5/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Last Reading 9912 9912 Physical EOF File Header • • Service name .............STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/OS/11 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9610.0 10490.0 ROP 9912.5 10520.0 LOG HEADER DATA DATE LOGGED: 27-JUL-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10520.0 TOP LOG INTERVAL (FT) 9912.0 BOTTOM LOG INTERVAL (FT) 10520.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.0 MAXIMUM ANGLE: 48.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 143792 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 2615.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 11.20 MUD VISCOSITY (S) 59.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 4.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 156 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................ ..0 Data Specification Block Type... ..0 Logging Direction ............... ..Down Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .12N • • Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9610 10520 10065 1821 9610 10520 GR MWD020 API 54.22 203.73 113.617 1761 9610 10490 ROP MWD020 FT/H 1.77 178.74 74.7508 1216 9912.5 10520 First Reading For Entire File..........9610 Last Reading For Entire File...........10520 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/OS/11 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....... 06/O5/11 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10474.0 12485. 0 RPM 10474.0 12485. 0 RPS 10474.0 12485. 0 RPX 10474.0 12485. 0 RPD 10474.0 12485. 0 GR 10490.5 12477. 5 ROP 10520.5 12531. 0 LOG HEADER DATA DATE LOGGED: O1-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12531.0 TOP LOG INTERVAL (FT) 10520.0 BOTTOM LOG INTERVAL (FT) 12531.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.0 • • MAXIMUM ANGLE: 100.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10520.0 BOREHOLE CONDITIONS MUD TYPE: FLOPRO SF MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 4600 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .450 179.0 MUD FILTRATE AT MT: .900 70.0 MUD CAKE AT MT: 1.150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-t ype...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10474 12531 11502.5 4115 10474 12531 RPD MWD030 OHMM 0.09 2000 44.403 4023 10474 12485 RPM MWD030 OHMM 0.37 2000 43.1751 4023 10474 12485 RPS MWD030 OHMM 1.13 1509.61 14.7256 4023 10474 12485 RPX MWD030 OHMM 1.15 1597.98 14.2657 4023 10474 12485 FET MWD030 HOUR 0.28 97.08 3.42056 4023 10474 12485 GR MWD030 API 13.13 578.57 42.9837 3975 10490.5 12477.5 ROP MWD030 FT/H 0.72 443.89 113.677 4022 10520.5 12531 First Reading For Entire File..........10474 Last Reading For Entire File...........12531 • • File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O5/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/O5/11 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 .....................06/O5/11 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