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Home My WebLink About206-143• • 1rn~lg~ !~>~~c~j~~t W~11 ~#i~tc~l'g~ File ~~v~lr ~~~~ XIiVZE 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. - ~ ~.~ Well History File Identifier Organizing (done) ^ Two-sided ~~~ ~~~~~) ~~ ~~~ ~~ ~~~ ^ Rescan Needed ~~~ (~~~~~ (~ ~~ ~~~ ~~) RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~'~ /s/ Project Proofing III II IIII VIII II III BY: Maria Date: ~ ~' /s/ Scanning Preparation ~_ x 30 = ~ ~ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria' Daie: ~ /s/ Production Scanning III II'llllllll (IIII Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparat ion: ~/ YES NO BY: Maria Date: { ~ ~ ,~ ~ /s/ Stage 1 If NO in stage 1, page(s) discrepan cies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this poinf unless rescanning is required. II I II I) II I II () I I III ReScanned II I II II II I I III (IIII BY: Maria Date: /s/ Comments about this file: Quality Checked .I II I I' III II I II'I II I 10/6/2005 Well History File Cover Page.doc • ., r , : . y., ,. ~` '~ "" ~~ ,~ ~ , ~;. * ~~ -~ ~~__ ~~~~ MICROFILMED 6/30/2010 ~DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 8 .~ ~ ~,o-may DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061430 Well Name/No. PRUDHOE BAY UNIT E-11 B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20475-02-00 MD 11687 ND 9544 Completion Date 12/8/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ` Mud Log No Samples No Directional Survey "`~ DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /RES / NEU /DEN / PWD, MWD DIR / GR /RES / A (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No -- -- Start Stop CH Received Comments ---- --- -- D D Asc Directional Survey fief - 4797 11687 -- - --~ Open 1/28/2007 Sonic 5 Col 1 11050 11690 i Open 1/29/2007 Formation Micro Imager Log, DSI, GPIT, Caliper, GR 29-Oct-2006 ,Je~g Sonic 5 Col 1 4800 8930 Open 1/29/2007 DIS, GR 23-Oct-2006 ,,l dg Sonic 5 Col 1 8700 11690 Open 1/29/2007 DSI, FMI, GPIT, Caliper, GR 29-Oct-2006 C Las 15251 Completion 10766 11129 Open 7/2/2007 Jewlery Log, Gamm, CCL w/Graphics PDF and Tif ~C 15751 Induction/Resistivity 4666 11683 Open 12/13/2007 MD and TVD electric logs EWR, DGR, CTN, ALD w/PDF and EMF graphics 15752 LIS Verification 1 4666 11683 Open 12/13/2007 GR, RPS, FET, RPD, FCNT, NCNT, RHOB, DRHO, NPHI E~C Lis 15752 Induction/Resistivity 1 4666 11683 Open 12/13/2007 GR, RPS, FET, RPD, FCNT, NCNT, RHOS, DRHO, NPHI Sonic 25 Blu 1 -2 4800 11690 Open 1/22/2008 DSI, FMI, GPIT, Capitler, GR 29-Oct-2007 C Lis 15886 Sonic 4792 11692 Open 1/22/2008 LIS Veri, DAS, FMI Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received N umber Comments DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061430 Well Name/No. PRUDHOE BAY UNIT E-11 B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20475-02-00 MD 11687 TVD 9544 Completion Date 12/8/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/ N Chips Received? J(-HQ' Formation Tops QiN Analysis 'f`7R Received? Comments: Compliance Reviewed By: Date: 01/11/08 ~~ +I?~r~1~~Li~i~~~s~ NO. 4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Fietd: P.Bay, Milne Pt. Wull _Inh $ 1 nn nncrrin4inn n~ta RI Cnlnr Cn Z-06 11594523 STATIC TEMP LOG 09/09/07 1 14-186 11975743 SBHP SURVEY 12108107 1 14-02C 11767144 SBHP LOG - 11/02/07 1 H-24A 11963073 MEM CBL - j 11/30/07 1 C-35A 11624351 CEMENT BOND 8 GRAVEL PACK ^a 11/03107 1 MPH-19 11982423 USIT (p ~ 12/10/07 1 1 E-03A 11628773 MEM PROD PROFILE - j 05/09/07 1 E-11B 11434760 OH LDWG EDIT (DSI) - C ~ 10/29106 1 1 G-06A 11209587 MCNL - (~ ~-~ 02/25/06 1 1 D-07B 11162822 MCNL ~- J ~ 12/04/05 1 1 G-10C 11209607 MCNL Q(p - a 06/15106 1 1 G-096 11649989 MCNL ~ ~ - j ( j ~j~(} J 09111/07 1 1 K-086 11745243 MCNL g '~ ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12/06107 1 V-07 11978425 USIT 12/06/07 1 L2-33 11970801 RST j - V ~ 07107107 1 1 03-14A 40013340 OH MWDILWD EDIT ~ t 04/23/06 2 1 ~~ PLEASt AGKNUWLEDGE KEGEIPT BY SIGNING AND RETURNING UNE GUPY EACH TU: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 I~ ~; ,, „ ,.,.. 900 E. Benson Blvd. `" - `` Anchorage, Alaska 99508 Date Delivered: " ~ {j ~ f ""^ `~ f 3~~f l `t Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth j Received by: `~~~ ' s • WELL LOG TRANSMITTAL To: State of Alaska December 6, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9901 RE: MWD Formation Evaluation Logs : E-11B AK-MW-4667128 E-11B: Digital Log Images: 50-029-20475-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 -~ < -- ~- Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: C- ,~.,5/ ~o~- ~~f3 ~~5 • WELL LOG TRANSMITTAL To: State of Alaska December 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: E-11B AK-MW-4667128 1 LDWG formatted CD rom with verification listing. API#: 50-029-20475-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,~ ., Date: ~ a ~ ~ -'v' I BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: 5a WELL. LC) T1~,4/1~~11//fTTAL ~~. ProActive Diagnostic Services, Tnc. To: ABC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907] 245-8952 1) EDE Disk E - 11 B Jewelry Log 02-Jun-07 2] 3) 4] 5) c~Uto->L!3 ~ I S a5~f 6j 7) Signed : ~~n Print Name: ~i~[j~~p ~h "I~ ~ ti j ~~'; ~%iL ~ 2 2DO Date Oii ~ Gas Cars. Comrelissics r~~?ahara PROACTIVE DIAGNOSTIC SERVICES, WC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.8952 E-MAIL : PQSANCHORAGEC~MEMORYLOG.COM WEBSITE : VWV4U.MEMORYLOG.COM D:UNaster_Copy_00_PDSANC-2Woc\Z_Wocd\Uishibution\Transmittal_Sheets\Tiansmit_Origmal.doc 01 /25/2007 ~VE~~~i~/~~~~~~ 1 1 fl~ ~ ~ l Alaska Data & Consulting Services ;,l -~ A~ ~p'~, / 2525 Gambell Street, Suite 400 ~ „ ^~' ' ~~ I Anchorage, AK 99503-2838 ATTN: Beth ~ ~ ~ , Lzi! _ ._ - , NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay P2-37L1 11491392 MEM PROD PROFILE 11115/06 1~ Y-236 11418299 MEM PROD PROFILE 09/06/06 1 NK-07i4 11588698 MEM GLS 12/21106 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12120/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22106 1 DS 09-32 11555530 INJECTION PROFILE 12116!06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12106/06 1 S-02A 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFL/LDL 12114/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L1 11588700 MEM PROD PROFILE 12/23/06 1 E-116 11434757 DSI 10/24/06 1 E-118 11434760 DSI 10!29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 DI CACC Af`Il~lrlllln r BP Exploration (Alaska) Inc. `v` Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ... ...., ..nw .-........~. ~.. L~.~~.v VI~C VVr" 1 Cf1V 1"1 1 V. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: II~ u ~°\ C 13-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well E-11 B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files Tie-on Survey: 4,797.05' MD Window /Kickoff Survey: 4,860.00' MD (if applicable) Projected Survey: 11,687.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorapge, AK 99518 Date a ~~,1~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) STATE OF ALASKA ~ ~~ .0~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~E~ ~~AN 0 4 2007 ~~~~'~ (111 ~ ~8~ 6;OnS« CarnmlCCifln 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 2oAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other . ~~~ 1 b. Welt Class;QnChO[~e ®Development L!" Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. -1Fi9iQ986-- - ~0~ 12. Permit to Drill Number 206-143 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/16/2006 13. API Number ,~ S0-029-20475-02-00 4a. Location of Well (Governmental Section): Surface: 3' F S C ' 't 7. Date T.D. Reached ~ 10/28/2006 14. Well Name and Number: ~ PBU E-11 B 46 NL, 500 FEL, E . 06, T11N, R14E, UM Top of Productive Horizon: 4226' FSL, 1711' FWL, SEC. 32, T12N, R14E, UM 8. KB Elevation (ft): ~ 57.83' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4456' FSL, 1578' FWL, SEC. 32, T12N, R14E, UM 9. Plug Back Depth (MD+TVD) ' 11600 + 9466 Ft Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664452. y- 5976601 Zone- ASP4 10. Total Depth (MD+TVD) 11687 + 9544 ~ Ft 16. Property Designation: ADL 028299 TPI: x- 666543 y_ 5981337 Zone- ASP4 Total Depth: x- 666405 y- 5981565 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore ~ N/A MSL 20. Thickness of Permafrost ~ 1900' (Approx.) 21. Logs Run: TI !/~// O M !- MWD DIR / GR /RES /NEU /DEN / PWD, MWD DIR / GR /RES / ABI /NEU /DEN, DIPOLE SONIC 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD. SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM" TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2729' Surface 267 ' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-8 Surface rf 4382' 12-1/4" 145 u lass 'G' 130 cu ft AS 7" 26# L-80 4703' 11095' 4255' 9017' 8-1/2" 1016 cu ft LiteCrete 197 cu ft 'G' 4-1/2" 12.6# L-80 10947' 11687' 8884' 9544' 6-1/8" 129 cu ft Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 10963' 10906' MD TVD MD TVD 11103' - 11153' 9025 - 9070' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 2200' Freeze Protect w/ 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Attempted on 12/14/06 Method of Operation (Flowing, Gas Lift, etc.): Will Not Flow -Probably will be sidtracked in the future (Appraisal Well) Date of Test Hours Tested N/A PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL 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". : 4u~ } None ~ ~ ~S.~v ~ ~ 207 ,/ct7- ~ -O6 d R I G I I\I ~ I~ -~ o Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE >! i '~'E,~,;ti, ~ 28. GEOLOGIC MARKERS 29. TION TESTS Include and briefly summarize test results. List intervals tested, NnMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted state "None". Sag River 11102' 9024' None Shublik 11151' 9068' Sadlerochit 11224' 9133' Top CGL 11296' 9196' Base CGL 11384' 9274' Sadlerochit /Zone 1 11588' 9455' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Perf Operations, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble // Title Technical Assistant Date ~~ /~~ 0 PBU E-11 B 206-143 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Shane Gagliarrii, 564-5251 Permit No. / A royal No. 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPt (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). treM 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 26: 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 T Q Q Q fl. t~ W O O / LL T O ~ a x m d a a 3 H `~ O W a~ n co n`. ~i v ~ ~ f O I y I J ~ 7 ~ fA .N .N ~. d ~ N a ~ ~ ~, ~ ~ i ~o ~ N L Z ^y~ O ! ~ I n a N ~ L Q ' a v~ o ~ ~ n a, ~ ~ w ~ ; s ~ V~ ~ ~ i , o 0 m Y ' L d' N n ao i d ; O j i M O ~ 01 J ~ H D L i O O ~ a ~ d, _ G! ~ v ~ ~ d H i Q Q ' pNp~~'. TI T T ii ~ ~ T T W W ~ ^` W ~_ !_~ W C z I z O 'i y I O O f~ ~ ~ p N N ~ J U ~ ~_ r ~ N i O o ~ i BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations _L ~--_- - --- - -_ _- 10/7/2006 22:00 - 00:00 2.00 MOB P PRE Prep rig floor for move. MU pup joint and plumb-bob top drive and set in slips. Load out cuttings tank and remove berm. Blow down rig for move. 10/8/2006 00:00 - 00:00 24.00 MOB P PRE Preparing rig for exception move to E-11 B. Set rig mats on A-Pad. Perform rig maintenace and general housekeeping projects. Load out truckable items to E-Pad. 10/9/2006 00:00 - 00:00 24.00 MOB N WAIT PRE Waiting on weather (high winds) for exception move to E-11 B from A-Pad. Preparing rig for move. Performing general maintenace and housekeeping. Working on procedure amendments. 10/10/2006 00:00 - 09:00 9.00 MOB N WAIT PRE Wait on high winds to die down to be able to lower derrick. Perform general maintenance and housekeeping projects. 09:00 - 13:30 4.50 MOB P PRE Move sub off well and move to E-Pad. Soft road between A & D pads, wait on rig mats. 13:30 - 23:30 10.00 MOB P PRE Stage rig mats on road ahead of rig. 23:30 - 00:00 0.50 MOB N WAIT PRE Wait on security at D pad. 10/11/2006 00:00 - 04:00 4.00 MOB P PRE Move sub to E pad,stage on pad. 04:00 - 12:00 8.00 MOB N WAIT PRE Wait on pre-rig work,raise derrick,rig up floor. Perform derrick inspection and general maintenance & house keeping. 12:00 - 22:00 10.00 MOB N WAIT PRE Stage camp, pits and support buildings.Continue with general maintenance and house keeping. 22:00 - 22:30 0.50 MOB P PRE Set rig mats around well. 22:30 - 00:00 1.50 MOB P PRE Move sub down pad and line up to well. Set herculite. 10/12/2006 00:00 - 10:00 10.00 RIGU P PRE Spot and level rig over well. Spot Pits and support buildings. Prepare for rig acceptance. Install secondary annulus valve. 10:00 - 10:30 0.50 BOPSU P DECOMP Pre-Spud Safety meeting. 10:30 - 11:30 1.00 BOPSU P DECOMP Rig up circulating line, and test same.Test TWC to 1000 psi from below.Good test. Blow down and rig down circulating lines. 11:30 - 14:00 2.50 BOPSU P DECOMP Nipple down tree and adapter flange. Remove from cellar. Make dummy run with crossover for hanger. 14:00 - 17:00 3.00 BOPSU P DECOMP Nipple up BOP stack. Grease choke manifold and BOP valves. Install mouse hole and load pipeshed with 4" pipe. 17:00 - 18:30 1.50 BOPSU P DECOMP Fill stack & choke manifold and check for leaks. Attempt to body test BOP,bleeding off through TWC. Drain stack call DSM for replacement TWC. 18:30 - 20:30 2.00 BOPSU N WAIT DECOMP Wait on TWC. 20:30 - 21:30 1.00 BOPSU P DECOMP Rig up DSM lubricator,pull TWC. Rig down lubricator, dry rod new TW C. 21:30 - 00:00 2.50 BOPSU P DECOMP Fill stack,pressure up to 1000 psi for body test,good,bleed off pressure. Test BOP and all related valves to 250 psi low and 3500 psi high,record on chart. Test witness waived by AOGCC rep. John Crisp. Test witnessed by BP rep. Blair Neufeld and Nabors Drilling rep. AI Lunda. 10/13/2006 00:00 - 02:30 2.50 BOPSU P DECOMP Test BOP and all related valves to 250 psi low and 3500 psi high,record on chart. Test witness waived by AOGCC rep. John Crisp. Test witnessed by BP rep. Blair Neufeld and Nabors Drilling rep. AI Lunda. 02:30 - 03:00 0.50 BOPSU P DECOMP Rig down test joint. Blow down surface equipment. 03:00 - 04:00 1.00 BOPSU P DECOMP Rig up lubricator and pull TWC. Rig down lubricator and clear floor. 04:00 - 05:00 1.00 PULL P DECOMP Pre-Job safety meeting on pulling tubing hanger. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To E-11 A E-11 A REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 2ES Hours ! Task !Code; NPT Start: 10/6/2006 Rig Release: 11/1/2006 Rig Number: 2ES Phase Page 2 of 12 Spud Date: 8/20/1981 End: 10/28/2006 Description of Operations 10/13/2006 05:00 - 06:00 1.00 PULL P DECOMP Pull tubing hanger to floor,pulled free ~ 137k. Monitor well,static. 06:00 - 07:30 1.50 PULL P DECOMP Well overbalanced. Rig up circulating line. Circulate bottoms up ~ 9900', 10 BPM ~ 1300 psi. Monitor well static. Pump dry job,blow down surface equipment. 07:30 - 08:30 1.00 PULL P DECOMP Rig up Camco control line spooler. 08:30 - 11:00 2.50 PULL P DECOMP POOH & lay down 4 1/2", 12.6# tubing from cut at 9900'. 11:00 - 12:00 1.00 PULL P DECOMP Rig down control line spooler.Recovered 51 S.S. bands,5 pup joints, and 1 SSSV. 12:00 - 19:00 7.00 PULL P DECOMP POOH and lay down 4 1/2", 12.6# L-80 tubing. 19:00 - 20:00 1.00 PULL P DECOMP Rig down tubing handling equipment. Clear floor. 20:00 - 21:30 1.50 BOPSU P DECOMP Make up 4" test joint and set test plug. Test top & bottom rams and annular to 250 psi low and 3500 psi high.Rig down test joint set wear ring. 21:30 - 00:00 2.50 DHB P DECOMP Rig up Schlumberger wireline unit and run in hole with 6.05 gauge ring and junk basket. . 10/14/2006 00:00 - 01:00 1.00 DHB P DECOMP Run in hole with 6.05 gauge ring and junk basket. 01:00 - 02:00 1.00 DHB P DECOMP Recover 2 small pieces of cement from junk baskets. Make up EZSV. PJSM on setting EZSV. 02:00 - 03:30 1.50 DHB P DECOMP RIH with EZSV on wireline. 03:30 - 04:00 0.50 DHB P DECOMP Set EZSV at 9883' 04:00 - 05:00 1.00 DHB P DECOMP Pull out of hole with wireline and rig down wireline unit. 05:00 - 06:00 1.00 DHB P DECOMP Test casing to 3500 psi. hold for 30 mintutes and chart. 06:00 - 14:30 8.50 PXA P DECOMP Make up mule shoe and RIH picking up drill pipe. Tag EZSV at 9878',pick up to 9858' 14:30 - 16:00 1.50 PXA P DECOMP Rig up head pin and circulating lines. Pump 5 bbl. water and pressure test lines to 4000 psi. Pump 10 bbl. class G, 17.0 ppg cement,5 bbl. water and displace with 88 bbl. seawater. 16:00 - 16:30 0.50 PXA P DECOMP POOH slowly,from 9858' to 9393'.° 16:30 - 18:00 1.50 PXA P DECOMP Circulate bottoms up ~ 9393', 12 BPM ~ 1200 psi. Monitor well,static,pump dry job. Blow down top drive. 18:00 - 19:30 1.50 PXA P DECOMP Cut and slip drilling line,inspect brakes.Clean under drawworks. Inspect traction motor. 19:30 - 20:30 1.00 PXA P DECOMP Lubricate rig,service top drive. 20:30 - 22:30 2.00 PXA P DECOMP POOH from 9393' to 4947'. - 22:30 - 00:00 1.50 PXA P DECOMP PJSM D6 drill, strip in hole from 4947' to 5508'. Blow down surface equipment. 10/15/2006 00:00 - 02:00 2.00 PXA P DECOMP POOH 5508' to surface. Lay down mule shoe. 02:00 - 04:00 2.00 DHB P DECOMP PJSM. Rig up wireline unit and run 8.5" guage ring & junk basket. 04:00 - 06:30 2.50 DHB P DECOMP PJSM. Make up EZSV and RIH to 5000'. Locate casing collar ~ 4882'.Set EZSV 4' above collar @4878'. Rig down wireline unit. 06:30 - 07:00 0.50 DHB P DECOMP Test casing to 3500 psi. 07:00 - 08:30 1.50 STWHIP P WEXIT PJSM. Make up BHA to 94'. 08:30 - 10:00 1.50 STWHIP N SFAL WEXIT Up-load & orient. Surface test MWD,460 GPM @470 psi. Communication failure to MWD - re-upload tool. Attempt surface test,failed. 10:00 - 12:00 2.00 STWHIP N SFAL WEXIT Lay down MWD, and pick up new tool to floor. 12:00 - 13:30 1.50 STWHIP P WEXIT Make up MWD tools to 90'. Upload MWD tools,install UBHO. Shallow test MWD 450 GPM ~ 450 psi,OK. 13:30 - 16:00 2.50 STWHIP P WEXIT Make up & orient Whipstock. Pick up bumper sub,drill collars and HWDP to 1045'. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ;Code NPT Phase Description of Operations 10/15/2006 16:00 - 18:00 2.00 STWHIP P WEXIT Run in hole from 1045' to 4749'. Fill every 3000' & check MWD tools.lnstall blower hose. 18:00 - 19:00 1.00 STWHIP P WEXIT Orient whipstock ~ 4749' to 69 degrees left of highside,460 GPM ~ 1070 psi. Tag EZSV ~ 4882'. Set down 15k to set bottom trip anchor. Pick up 10k over then set down 35k to shear brass bolt. Final whipstock orientation 63 degrees left of highside, top of window 4861', bottom of window 4878'. 19:00 - 20:00 1.00 STWHIP P WEXIT Pump 50 bbl hi-vis sweep. Displace well to 9.2 ppg LSND milling fluid,504 GPM ~ 1300 psi. 20:00 - 00:00 4.00 STWHIP P WEXIT Mill 8 1/2" window from 4861' to 4877'. Up wt. 130k, down wt. 120k,rotating wt. 125k. Torque off bottom 4k, on bottom 6-9k. Mud wt. in and out 9.2 ppg. 10/16/2006 00:00 - 02:00 2.00 STWHIP P WEXIT Mill window and 20' of new hole to 4890'. Up wt. 130k,down wt. 120k, rotating wt. 125k. 100 RPM, 6-10k W06,6-10k ft/Ibs of torque,450 gpm ~ 1190 psi.Mud weight in and out 9.2 ppg. Circulate super sweep, work whipstock ramp with mills. 02:00 - 03:00 1.00 STWHIP P WEXIT FIT at 4861'. EMW of 11.9 ppg. Blow down kill line. 03:00 - 04:30 1.50 STWHIP P WEXIT Run MAD pass log with MWD from 4861' to 4700' ~ 250 FPH.Pump dry job,blow down surtace equipment,remove blower hose. 04:30 - 06:00 1.50 STWHIP P WEXIT POOH from 4700' to 1023'. Change out handling equipment. 06:00 - 08:30 2.50 STWHIP P WEXIT POOH from 1023' to 377'. Lay down drill collars, download MWD. Clear floor. 08:30 - 10:00 1.50 STWHIP P WEXIT Pull wear ring,flush and function BOP. Install wear ring. 10:00 - 15:00 5.00 STWHIP P WEXIT Make up 8 1/2" drilling assembly. Orient and up-load MWD. Shallow pulse test tool 450 GPM 03630 psi. Load radioactive sources. Make up BHA to 203'. Run in HWDP out of derrick to 387',pick up drilling jars. Run in with HWDP to 850',change out elevators. 15:00 - 17:00 2.00 STWHIP P WEXIT Pick up drill pipe from 850' to 2440' from pipe shed. Fill pipe,test MWD,blow down top drive. 17:00 - 18:00 1.00 STW HIP P WEXIT Run in hole from 2440' to 4772'. Install blower hose. 18:00 - 18:30 0.50 STWHIP P WEXIT Orient toolface to 69 degrees left of highside C~3 4772'. Slide through window with max 3k drag,no problems. Tag bottom at 4890'. Record slow pump rates. 18:30 - 00:00 5.50 DRILL P INTi Drill 8 1/2" hole from 4890' to 5263'. Slide time 2.34 hrs, rotate .90 hrs. Up wt. 135k,down wt. 105k,rotating wt. 120k. Torque off bottom 6k on bottom 6k. Mud wt. in and out 9.4 ppg. 10/17/2006 00:00 - 00:00 24.00 DRILL P INT1 Drill 8 1/2" hole from 5263' to 7106'. Up wt. 160k, down wt. 115k, rotating wt. 135k. Torque off bottom 7k, on bottom 8k. Mud wt. in and out 9.3 ppg. 10/18/2006 00:00 - 03:30 3.50 DRILL P INT7 Drill 8 1/2" hole from 7106' to 7387'. Up wt. 160k, down wt. 115k, rotating wt. 135k. Torque off bottom 7k, on bottom 8k. Mud wt. in and out 9.3 ppg.Drilled directional tangent section through Ugnu with 2 coal seams of note encountered, the first at 5250' to 5280' and the second at 5645' to 5730'. Intermittent torque experienced while drilling could have been due to coals as large pieces of coal recovered from shakers periodically. 03:30 - 04:30 1.00 DRILL P INT1 Circulate high vis sweep, no increase in cuttings noted when sweep returned to surtace. Blow down top drive. 04:30 - 06:30 2.00 DRILL P INT1 Short trip to window. No major problems -hole in good shape - clean up 2 coal seams. Pull 20k ~5750',pull 30k @ 5630',pull 50k @ 5540'. All tight spots were worked though with no extra Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: E-11 A Common W ell Name: E-11A Spud Date: 8/20/1981 Event Nam e: REENTE R+COM PLET E Start : 10/6/2006 End: 10/28/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 11/1/2006 Rig Name: NABOB S 2ES Rig Number: 2ES D t ~ F T ~ H T k ~ f C d NPT Ph D i ti ti f O a e rom - o ours as o e ~. ase escr p pera ons ~ on o 10/18/2006 04:30 - 06:30 2.00 DRILL P INTi weight needed to work down once the spots had been pulled through. 06:30 - 07:30 1.00 DRILL P INT1 Cut 63' of drilling line. Service and inspect drawworks & traction motor brushes. 07:30 - 08:30 1.00 DRILL P INT1 Service top drive-Inspect electrical 08:30 - 09:30 1.00 DRILL P INT1 Run in hole from 4861' to 7387',no tight spots. 09:30 - 10:30 1.00 DRILL P INT1 Circulate and condition hole due to high ECD's.Some large pieces of coal circulated up after short trip. 10:30 - 00:00 13.50 DRILL P INT1 Drill 8 1/2" hole from 7387' to 8165'. 24 hr slide hours 1.15, 24 hour rotate hours 12.54. Drilling tangent section of well plan with slight dropping tendency in rotary mode. Up wt. 185k, down wt. 120k, rotating wt. 145k. Torque on bottom 12k fUlbs. off bottom 10k ft/Ibs. Intermittent torque spike while drilling, difficult to determine if they are originating on bottom or up hole. Some smaller pieces of coal still coming over the shakers periodically. Mud weight in and out 9.3 ppg. Centrifuge and mud cleaner running continually and water being run from 20 to 25 bbl/hr to control weight from 9.3 to 9.3 heavy. Dump and dilute as volumes allow. Drilled through West Sak and into Coleville, on bottom ROP's between 70'-90'/hr.Fomtation tops coming in with no large variations from prognosis. 10/19/2006 00:00 - 06:00 6.00 DRILL P INT1 Drill 8 1/2" hole from 8165' to 8425'. Started drilling drop section of well plan currently no sliding has been necessary as assembly dropping while rotating. Up wt. 185k, down wt. 120k, rotating wt. 145k. Torque on bottom 12k ft/Ibs. off bottom 10k fUlbs. Lubricant concentration brought back to 2% from 1.5% and torque smoothed out noticeably while drilling, though pick up and slack offs remained constant. Mud weight in and out 9.3 ppg. Centrifuge and mud cleaner running continually and water being run from 20 to 25 bbl/hr to control weight from 9.3 to 9.3 heavy. Dump and dilute as volumes allow. Drilling ahead in Coleville (top at 8004') ROP's between 60'-80'/hr.Formation tops coming in with no large variations from prognosis. ECD's remaining constant from 10.0 to 10.04ppg. 06:00 - 16:30 10.50 DRILL P INT1 Drill 8 1/2" hole from 8425' to 8977'.Slid a total of 44'for this interval to stay with 1.5/100' directional plan. Up wt 200k,down wt. 125k,rotating wt. 155k. Hole drag seems to be increasing at a faster pace in this section of Coleville despite lubricant concentration of 2.5%. This is most likely due to a combination of hole geometry (drop section) and firming up of the Coleville, making the sides of the hole less smooth. ECD's are constant as is cuttings load at shaker so no indication of cleaning issues contributing to the torque & drag. Mud weight in and out 9.3 ppg., running centrifuge and mud cleaner 100% of the time. Added 290 BBL of dilution fluid to lower solids/MBT in preparation for weight up. ROP's averaging 50fUhr. Torque off bottom 10,000 ft/Ibs. on bottom 12,000 fUlbs. String continues to torque up periodically but more indications that torque is originating on bottom. Carried out a kick drill while drilling -new hire roustabouts were included in this drill and given a brief explanation of what happens in the wellbore that requires the BOPE to be closed on the drillpipe. 16:30 - 18:00 1.50 DRILL N RREP INTi Lost 100psi. Check pump found washed out valve seat. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Event Name: REENTER+COMPLETE Start: 10/6/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABORS 2ES Rig Number: 2ES Date j From - To I Hours I Task ~ Code ~ NPT I Phase Page 5 of 12 Spud Date: 8/20/1981 End: 10/28/2006 Description of Operations 10/19/2006 16:30 - 18:00 1.50 DRILL N RREP INT1 Circulate bottoms up ~ 267 GPM X875 psi. 18:00 - 00:00 6.00 DRILL N RREP INT1 Change out fluid end on Pump #1 cylinder #3. Sfow pump to 4 BPM ~ 560 psi. Add dilution fluid, Mud wt. in and out 9.3 ppg. 10/20/2006 00:00 - 15:00 15.00 DRILL P INTi Drill 8 1/2" hole from 8977' to 9200'. Up wt. 200k, down wt. 125k, rotating wt. 155k. Torque on bottom 12k ft/Ibs. off bottom 10k fUlbs. Lubricant concentration currently running at 2.5%. Mud weight in and out 9.3 ppg. Centrifuge and mud cleaner running continually and water being run from 20 to 25 bbl/hr to control weight from 9.3 to 9.3 heavy. Dump and dilute as volumes allow. Drilling ahead in Coleville (top at 8004') ROP's have slowed to 50'-80'/hr as the shales become more consolidated. ECD's have dropped to below 10.Oppg due to less cuttings being produced. As the hole angle decreases so does the amount of drop in rotary mode so slightly more sliding will be needed to complete planned drop.Start adding spike fluid ~ 9500' to bring weight to 10.7 by HRZ ~ +-9600'. 15:00 - 17:00 2.00 DRILL P INT1 Continue to bleed in 260 BBL. of 14.8ppg spike fluid to bring weight up to 10.7ppg before entering the HRZ. 17:00 - 00:00 7.00 DRILL P INT1 Drill 8 1/2" hole from 8977 to 9860'. Up wt. 215k,down wt. - 125k,rotating wt. 165k. Torque off bottom 11 k on bottom 13k,RPM 80 on bottom and 65 off bottom. 500 GPM ~ 3250psi off bottom and 3450 psi on bottom. WOB averaging 10-12k and ROP 50-80ft/hr rotating and 20-60 ft/hr sliding. Planned drop section now complete but assembly continues to drop in rotary mode so sliding now required to maintain tangent angle and complete planned turn. Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run periodically to even out heavy spots. ECD running in the range of 11.3ppg and cuttings load on shakers steady but lighter than previous 24 hrs. Drilling in HRZ and with no hole problems but seeing random (rare) slivers of coal on shakers. 10/21/2006 00:00 - 12:00 12.00 DRILL P INTi ` Drill 8 1/2" hole from 9860' to 10,252'. Up wt. 235k,down wt. 130k,rotating wt. 175k. Torque off bottom 12-14k, on bottom 15-16k,RPM 80 on bottom and 65 off bottom. 500 GPM Q 3280psi off bottom and 3500 psi on bottom. WOB averaging 10-12k and ROP 40-70ft/hr rotating and 20-60 Whr sliding. Planned drop section now complete but assembly continues to drop in rotary mode so sliding now required to maintain tangent angle and complete planned turn. Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run periodically to even out heavy spots. ECD running in the range of 11.3ppg. Lubricant concentration between 2.5%-3%.Drilled directly from the HRZ to the Kingak,no Kuparuk present so drill ahead without logging. 12:00 - 0.00 DRILL P INTi - Drill 8 1/2" hole from 10252' to 10,656'. Up wt. 240k,down wt. 135k,rotating wt. 175k. Torque off bottom 12-14k, on bottom 15-16k,RPM 80 on bottom and 65 off bottom. 500 GPM C~ 3390 psi off bottom and 3670 psi on bottom. WOB averaging 10-12k and ROP 40-70Whr rotating and 20-60 ft/hr sliding. Planned drop section now complete but assembly continues to drop in rotary mode so sliding now required to maintain tangent angle and complete planned tum. Have instructed directional drillers to let the well come off the "line" using more of the Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: E-11A Common W ell Name: E-11A Spud Date: 8/20/1981 Event Nam e: REENTE R+COM PLET E Start : 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 11/1/2006 Rig Name: NABOB S 2ES Rig Number: 2ES Date From - To Hours ~ Task ~ Code NPT Phase Description of Operations 10/21/2006 12:00 - 0.00 DRILL P INT1 target and sliding less. Sliding was 42% of 24 hour drilling time.Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run when required to control drilled solids. ECD running in the range of 11.3 to 11.4 ppg. Lubricant concentration between 2.5%-3% noting that adding .5% of concentration has the effect of lowering drilling torque from 15k to 12k. Drilled directly from the HRZ to the Kingak, no Kuparuk present so drill ahead without logging. 10/22/2006 00:00 - 04:00 4.00 DRILL P INT1 Drill 8 1/2" hole from 10,656' to 10,774'. Up wt. 250k,down wt. 140k,rotating wt. 180k. Torque off bottom 12-13k on bottom 13-14k,RPM 80 on bottom and 65 off bottom. 500 GPM ~ 3415 psi off bottom and 3720 psi on bottom. WOB averaging 10-12k and ROP 40-70ft/hr rotating and 20-60 ft/hr sliding. Planned drop section now complete but assembly continues to drop in rotary mode so sliding now required to maintain tangent angle and complete planned tum. Have instructed directional drillers to let the well come off the "line" using more of the target and sliding less. Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run when required to control drilled solids. ECD running in the range of 11.3 to 11.4 ppg. Lubricant concentration between 2.5% and 3%. Geological break-down 9918'-10,098' LCU/TKNG Well appears to have encountered Kingak shales abruptly below the HRZ. No indications of Kuparuk sands on logs. Upper Kingak JG section comprised of shales and thin sand stringers. 10,098'-10,250 'Kingak JF 100% silty shale. 30 api shift on GR (cooler) in interval. Resistivity averages 4-6 ohms in interval, versus overlying and underlying shale background of 2 ohms. 10,250'-10,590' Kingak JE Silty shale at top of interval, overlying cleaner shale with thin siltstone streaks. GR background averaging 120-135 api, resistivity background averages 2 ohms. 10,590- Kingak JD Predominantly massive siltstone interval. GR averages 90-105 api, 3 ohms background resistivity. Overall good correlation in Kingak with offset well data. MWD sensors: Dir 38.94'. GR 47.04'. Res 54.55'. Dens 81.68'. Neu 94.97'. PWD 62.67'. 04:00 - 05:30 1.50 DRILL N SFAL INT1 Work on mud pump #1 discharge cap leak 05:30 - 07:00 1.50 DRILL N SFAL INT1 Wait on pump part 07:00 - 08:30 1.50 DRILL N SFAL INT1 Change out swab on mud pump #2 08:30 - 12:30 4.00 DRILL P INT1 Drill 8 1/2" hole from 10,744' to 10,951'. Up wt. 255k,down wt. 140k,rotating wt. 180k. Torque off bottom 12-13k on bottom 13-14k,RPM 80 on bottom and 65 off bottom. 500 GPM ~ 3600 psi off bottom and 3760 psi on bottom. WOB averaging 10-12k and ROP 40-70ft/hr rotating and 20-60 ft/hr sliding. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To Hours Task Code NPT Phase I Description of Operations 10/22/2006 08:30 - 12:30 4.00 DRILL P INT1 Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run when required to control drilled solids. ECD running in the range of 11.3 to 11.4 ppg. Lubricant concentration between 2.5% and 3%. 12:30 - 13:00 0.50 DRILL N SFAL INTi Change out swab in pump #1 cylinder #2. 13:00 - 16:30 3.50 DRILL P INT1 Drill 8 1/2" hole from 10,951' to 11,095'. Up wt. 260k, down wt. 140k, rotating wt. 180k. Torque off bottom 12-13k on bottom 13-14k, RPM 80 on bottom and 65 off bottom. 500 GPM ~ 3600 psi off bottom and 3760 psi on bottom. WOB averaging 12-16k and ROP 40-70fUhr rotating and 20-60 ft/hr sliding. Mud weight in and out 10.7 ppg, with centrifuge and mud cleaner run when required to control drilled solids. ECD running in the range of 11.3 to 11.4 ppg. Lubricant concentration between 2.5% and 3%. 16:30 - 18:30 2.00 DRILL P INT1 Circulate bottoms up sample to determine if TD. 500 GPM ~ 2400psi. Slow pump rates. 18:30 - 19:00 0.50 DRILL N DFAL INT1 Trouble shoot loss of 1200 psi. Loss not found on surface and appears constant at 1200 psi. 19:00 - 20:30 1.50 DRILL P INT1 Circulate high vis sweep 500 GPM ~ 2200 psi. Sweep masks further pressure ioss temporarily. Pressure drops off an additional 200 psi. Shut pumps down. 20:30 - 00:00 3.50 DRILL P INT1 POOH wet 11,095' to 6362'. Pulled 25-30k ~ 8340',50k over ~ 7874' and 75k over ~ 7602. Hole appeared to have more drag overall through the HRZ transition to and through West Sak. Pipe pulled dry at 7300' and a washout in the drill pipe was found on the top single of stand # 57 at the pin end approx 2' above the TJ upset. The single was laid down then the BHA pulled through the coal seam ~ 6650'.BHA pulled 10-40k in spots in the Ugnu but no overpull in coal. 10/23/2006 00:00 - 03:00 3.00 DRILL P INT1 Run in hole from 5600' to 11,095'. Work tight spots at 7537',8173',9640'9980',and 10,032'. Tight spots in the HRZ and Kingak pulled 50k to 70k over when working up the first time after setting down when running in. 03:00 - 12:00 9.00 DRILL P INT1 Stage pumps up to keep ECD under 11.5 ppg. Circulate bottoms up,pump hi-vis sweep around. Some 11.7ppg mud circulated out of hole while circulating bottoms up. ECD's drop to 11.4 then rise to 11.6ppg. Pump rates need to be droppped to 367 GPM to keep ECD@ 11.7ppg while pumping up sweep. Hole appears to have larger than normal cuttings toad on bottom due to washout not allowing full circulation at TD.Circulate and condition mud, lower viscosity and yeid point. Change out swab on pump #2 cylinder #3. Even out mud to in and out weight of 10.8 ppg. 12:00 - 13:00 1.00 DRILL P INT1 Circulate bottoms up with 10.8ppg mud. 475 GPM X3650 psi, ECD 11.37ppg.Pump dry job. 13:00 - 18:00 5.00 DRILL P INTi POOH from 10,095' to 850'. Rabbit dropped once inside casing. 18:00 - 20:00 2.00 DRILL P INT7 POOH from 850' to 203',racking back HWDP and jars.Lay down 2 flex collars. PJSM,remove radioactive sources and lay down remaining flex collar. 20:00 - 22:00 2.00 DRILL P INT1 Download MW D. 22:00 - 00:00 2.00 DRILL P INT1 Flush MWD and motor. Lay down BHA from 108'.Clear floor. 10/24/2006 00:00 - 02:30 2.50 EVAL P INT1 Rig up E-line unit and pick up tools. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT Start: 10/6/2006 Rig Release: 11 /1 /2006 Rig Number: 2ES Page 8 of 12 Spud Date: 8/20/1981 End: 10/28/2006 Phase Description of Operations 10/24/2006 02:30 - 09:00 6.50 EVAL P INT1 Run Dipole Sonic log. Hung up at 8650' but worked through, ~,6~ stood up again at 8930' and unable to make any progress. This is in the Colevile and nothing was seen in these areas on short trip. No sliding in the two areas where it hung up. Log up from 8930'. POOH with E-line. 09:00 - 16:00 7.00 EVAL P INT1 Break down tool. Change out FMI and add hole finder. MU tools and RIH. Could not get past 4930'. POOH and rig down E-line. 16:00 - 17:30 1.50 EVAL P INT1 Make up clean out run BHA on 4" DP to 691'. Change out handling equipment. 17:30 - 19:00 1.50 EVAL P INT1 RIH to 4800' filling every 3000'. Up weight 120k, down 95k. 19:00 - 20:30 1.50 EVAL P INT1 Cut 91' of drilling line. Service crown and draworks. Inspect brushes. Service top drive and install blower hose. 20:30 - 00:00 3.50 EVAL P INT1 RIH to 10930' filling every 3000'. Worked tight spots at 4900'-5100', 6750' and 9030'. Had to work 2 dozen times through 9030' to wipe clean. Tight spots cleaned up after wiping. Up weight 250k, down 110k. 10/25/2006 00:00 - 04:00 4.00 EVAL P INT1 Wash to bottom with no problems. Circulate BU and pump sweep surface to surface. Hole clean. 04:00 - 09:30 5.50 EVAL P INT1 POOH. Pulling tight at 10865', 10555', 10510' - 100k over wipe back through. Pulling tight at 10318', 9700' and 9030 where it was tight going in. Pulled 75 over, wiped through. 09:30 - 12:00 2.50 EVAL P INT1 Lay down BHA, HWDP, Jars, flex collars, stabilizers, float sub and bit. Clear floor. 12:00 - 13:00 1.00 CASE P LNR1 Clear and clean floor. 13:00 - 15:30 2.50 CASE P LNR1 Change out top pipe rams to 7". Pull wear ring. Install test plug. / Rig up and test 7" rams to 250 psi low, 3500 psi high. Test OK. +/ Pull test plug and install wear ring. 15:30 - 16:30 1.00 CASE P LNR1 PJSM. Rig up 7" handling equipment. 16:30 - 17:30 1.00 CASE P LNR1 PJSM. Make up float equipment. 17:30 - 23:30 6.00 CASE P LNR1 RIH with 7" 26#, L-80 BTC-M liner to 4861'. Getting no displacement back. Slow down running speed from 90 fpm to 75 fpm. Still loosing displacement, slow running speed to 50 fpm. Still loosing displacement. Continue to run in hole at 50 fpm. 23:30 - 00:00 0.50 CASE P LNR1 Rig up head pin. Break circulation to 3 bpm with 450 psi. 10/26/2006 00:00 - 07:00 7.00 CASE P LNR1 PJSM. RIH to 6400' filling every joint. Change out elevators, MU Hanger assembly and XO. Change out elevators for 4" DP, MU stand and circulate down while rigging down liner handling equipment. RIH with 7" liner on 4" DP. Started getting full returns back around 8400'. Lost 60 bbls fluid up to 8400'. Tag bottom & MU cement head. Pull up to 350 klbs - no pipe movement. 07:00 - 08:30 1.50 CASE P LNR1 Break circulation and stage up to 6 bpm @ 1200 psi - no losses. Attempt to reciprocate. Pipe broke over at 375 klbs up but acted sticky coming down. Park pipe. 08:30 - 08:45 0.25 CEMT P LNR1 PJSM for cement job. 08:45 - 09:15 0.50 CEMT P LNR1 Cont circ while cementers air up & prime up. Review job procedure with rig crew. 09:15 - 09:45 0.50 CEMT P LNR1 Pump 5 bbls water. Test lines to 4000 psi. Mix & pump 100 bbls Mudpush II at 11.4 ppg. 09:45 - 10:45 1.00 CEMT P LNR1 Mix & pump 184 bbls (460 sx) 12.5 ppg LiteCrete cement with GasBlok at 4.8 bpm/1200 psi. Attempt to move pipe -moved 2' Printed: 71/6/2006 8:03:36 AM BP EXPLORATION Operations Summary Report Page 9 of 12 Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operatior+s 10/26/2006 09:45 - 10:45 1.00 CEMT P LNR1 and getting sticky coming back down. 10:45 - 11:00 0.25 CEMT P LNR1 Switch to tail. Mix & pump 34 bbls (175 sx) Class G tail slurry at 15.8 ppg. 3.5 bpm ~ 600 psi. 11:00 - 12:45 1.75 CEMT P LNR1 Release DP dart and kick out with 5 bbls water. Switch to mud and continue displacement 5 bpm ~ 540 psi @ start. Make one reciprocation of pipe 2-3'. Second try would not move up to 375 klbs. 200 bbls away and slow to 2 bpm ~ 1120 psi. Reciprocate x1 2-3'. Second attempt and pipe would not move up to 375 klbs. Park pipe for remainder of job. Bump plug as calculated. Pressure up to 3800 psi to set hanger. Bleed off to 500 psi and rotate off liner hanger. Bleed pressure to zero and check floats - OK. Pressure up to 1000 psi and PU out of hanger assembly - OK. Hanger is set. Circ 20 bbls at max rate to move excess cement up hole. CIP at 12:45 hrs. Circ Rotate DP at 30 rpm and set down 50 klbs to energise LTP - OK. 12:45 - 14:00 1.25 CEMT P LNR1 Circulate out excess cement -trace only with spacer. 14:00 - 15:00 1.00 CEMT P LNR1 Flush mud manifold. Lay down cement head. Pump dry job. Break down surface equipment. 15:00 - 17:00 2.00 CEMT P LNR1 POOH from 4703'. Lay down running tool. Clear and clean floor. 17:00 - 00:00 7.00 BOPSU P PROD1 Change out top rams to 3-1/2" x 6" variable. Rig up 4" test equipment. Test BOPE to 250 psi low, 3500 psi high. Test witness waived by Chuck Scheve. Test witnessed by Wellsite leader Mitch Skinner and Tour Pusher John Castle. Test 4-1/2" test joint by upper pipe rams. Rig down test equipment. Break down test equipment. Pull test plug. Install wear ring. 10/27/2006 00:00 - 05:30 5.50 DRILL P PROD1 PJSM. PU/MU BHA. MU bit, motor, float sub, stabalizer, MWD tools, circulating sub and flex collars. Scribe and upload MWD, pulse test and load nukes. PU and RIH with HWDP, Jars, HWDP and XO. Run in to 658'. 05:30 - 09:30 4.00 DRILL P PROD1 RIH to 9532'. Fill and test MWD every 30 stands. 09:30 - 10:30 1.00 DRILL P PROD1 Circulate DP volume at 225 gpm with 1960 psi. Test 7" x 9-5/8" casing to 3500 psi for 30 minutes. OK. 10:30 - 13:00 2.50 DRILL P PROD1 PJSM. Perform stripping drill of 5 stands. Blow down lines. Pull 5 stands. LD dart and TIW. 13:00 - 14:00 1.00 DRILL P PROD1 RIH to landing collar at 11011'. 14:00 - 16:30 2.50 DRILL P PROD1 Obtain drilling perameters. Up weight 240k, down 120k. Pump at 225 gpm with 1950 psi. Unable to rotate without reciprocating due to high casing torque of 14k. Rotate and reciprocate while adding steel tube. Drill out cement and float equipment to 11904' at 60 rpm with 14k torque pumping at 230 gpm with 2025 psi. Weight on bit 5-10k. 16:30 - 22:00 5.50 DRILL P PROD1 Circulate out cement. Rotate and reciprocate. Pump 100 bbls water, 45 bbls high vis spacer and displace well to 8.4 ppg Flo-Pro at 250 gpm with 1800 psi. Shut down, clean shaker possum bellies and troughs. Slow pump rates at shoe with new 8.4 ppg mud - 30/650 and 45/800 both pumps. 22:00 - 23:00 1.00 DRILL P PROD1 Drill out shoe and new hole to 11119'. Up weight 185k, down 150k, RT 170k pumping at 255 gpm with 1700 psi off, 1850 on. Torque 5k at 70 rpm. WOB 10k. 23:00 - 00:00 1.00 DRILL P PROD1 Line up and perform FIT to 10 ppg EMW. Blow down kill line. 10/28/2006 00:00 - 12:00 12.00 DRILL P PROD1 Drill ahead to 11688'. TSGR at 11102' appears oil laden. TSHU at 11150' and TSAD at 11225 +/-, both appear wet. Up weight Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To ~ Hours ~ Task Code NPT 10/28/2006 00:00 - 12:00 ~ 12.00 DRILL P 12:00 - 14:00 I 2.001 DRILL I P 14:00 - 15:00 I 1.001 DRILL I P 15:00 - 16:30 I 1.501 DRILL I P 16:30 - 17:00 I 0.501 DRILL P 17:00 - 19:00 I 2.00 I DRILL ( P 19:00 - 23:30 I 4.501 DRILL I P 23:30 - 00:00 0.50 DRILL P 10/29/2006 00:00 - 02:00 2.00 DRILL P 02:00 - 03:00 1.00 EVAL P 03:00 - 10:00 7.00 EVAL P 10:00 - 11:00 1.00 EVAL P 11:00 - 12:00 1.00 CASE P 12:00 - 16:00 4.00 CASE P 16:00 - 21:00 5.00 CASE P 21:00 - 21:30 0.50 CASE P 21:30 - 23:00 I 1.501 CASE I P 23:00 - 00:00 I 1.001 CASE I P 10/30/2006 100:00 - 01:15 I 1.25 CASE P 01:15 - 01:30 I 0.251 CEMT P 01:30 - 01:45 0.251 CEMT I P 01:45 - 02:00 I 0.251 CEMT I P 02:00 - 02:30 I 0.501 CEMT I P Spud Date: 8/20/1981 Start: 10/6/2006 End: 10/28/2006 I Rig Release: 11/1/2006 Rig Number: 2ES Phase Description of Operations PROD1 190k, down 155k, RT 170k. Torque 5k off bottom, 6k on bottom at 100 rpm. WOB - 10-15k. Pump at 260 gpm with 1800 psi off bottom, 2000 psi on bottom. PROD1 Pump sweep surface to surface at 250 gpm with 1800 psi until clean. PROD1 Monitor well. POOH to 11020' wet. Up weight 210k. No problems. Hole appears in good shape. PROD1 Service top drive and crown. Inspect top drive and backup wrench. Replace 3 sets of safety wires. PROD1 RIH. Pick up single and tag bottom at 11687'. Down weight 150k. No problems, again hole appears in good shape. PROD1 Break circulation, pump sweep surface to surface until clean. SPR at 11687'/1900 hrs, 30/730 and 45/840 both pumps. PROD1 Monitor well. POOH to 11020' wet. Drop dart, open circulating sub, pump dry job. Remove blower hose and POOH to 658'. PROD1 Lay down BHA. PROD1 POOH and remove nuke sources. Download MW D, flush BHA with fresh water. LD BHA, clear and clean floor. PROD1 PJSM. Rig up SWS, Di-pole Sonic log. PROD1 RIH with wireline sonic log. Run DSI and FMI logs from11687' to 8700'. POOH with wireline. PROD1 PJSM. Rig down wireline. RUNPRD Clear and clean floor. Bring up casing tools. RUNPRD PJSM. Rig up floor power tongs and backups. MU shoe track, fill and check floats. PU 17 joints 4.5" 12.6#, L-80 BTC-M liner, hanger assembly and XO to 750'. Change elevators. Make up stand of DP and circulate liner volume at 275 gpm with 110 psi. Rig down and clear floor. RUNPRD RIH at 120 fpm, slowing to 60 fpm in 7" liner. Filling every 10 stands to 11019'. RUNPRD Circulate DP/liner volume at 7" shoe at 126 gpm with 570 psi and 210 gpm with 750 psi. Up weight 190k, down 145k. RUNPRD RIH to 11672', PU and MU cement head and single. Wash down and tag at 11687' with no problems. RUNPRD Circulate and reciprocate 10-15' at 6 fpm. Pump at 126 gpm with 725 psi. Up weight 195k, down 150k. Increase rate to 210 gpm over 20 minute period with 975 psi. RUNPRD Circulate and reciprocate on bottom at 10-15' moving at 6 fpm. Hold PJSM. Begin hatching up for cement job. RUNPRD Pump 5 bbls H2O at 5 bpm with 1200 psi. Shut down, pressure test lines to 4500. Test OK. RUNPRD Start 13.0 ppg mudpush at 3 bpm bring up to 5 bpm with 623 psi dropping to 3 bpm with 38 bbls away at 60 psi. Pump a total of 40 bbls mudpush. RUNPRD Start 15.8 ppg tail cement. Reach 5 bpm at 357 psi with 5 bbls away. Slow to 2 bpm with 70 psi at 23 bbls away. Shut down with total cement pump away 23 bbls, 110 sacks Class G with Gasblok. Pump 8 bbls of pert pill to wash lines through tee. RUNPRD Start chasing cement with pert pill. Pump 12 bbls at 5 bpm with 87 psi. Switch over to 8.4 ppg mud. Pumping mud at 5 bpm with 90 psi. At 0217 saw first lift with 73 bbls away pumping at 5 bpm with 387 psi. Reciprocating pipe 10' at 5 fpm. Slow pumps to 4.2 bpm and 1087 psi with cement at 11687' shoe. Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ~ Code NPT 10/30/2006 02:00 - 02:30 ~ 0.50 CEMT ~ P 02:30 - 02:45 I 0.251 CEMT I P 02:45 - 04:00 I 1.251 CEMT I P 04:00 - 05:00 I 1.001 CEMT I P 05:00 - 06:00 I 1.00 ~ CEMT ~ P 06:00 - 08:00 I 2.001 CEMT I P 08:00 - 16:30 8.50 CEMT P 16:30 - 18:00 1.50 CEMT N 18:00 - 21:00 I 3.00 I CEMT I P 21:00 - 00:00 I 3.00 10/31 /2006 00:00 - 02:30 2.50 02:30 - 03:30 1.00 03:30 - 21:00 I 17.50 21:00 - 23:00 I 2.00 23:00 - 00:00 I 1.00 11 /1 /2006 100:00 - 03:00 I 3.00 03:00 - 04:30 I 1.50 RREP Phase Description of Operations RUNPRD Reciprocate 10' two times while cement went around shoe. At 0228 latched up with 112 bbls away at 2400 psi. Reciprocate one more time. Bumped plug with 122 bbls away at 1475 psi. Pressure up to 3500 psi to set hanger as per Baker rep. Bleed back 1.25 bbls, the same amount needed to pressure up. Floats holding. Liner on bottom at 11687'. No losses recorded during cement job. CIP 0230 hrs. RUNPRD Pressure up to 1000 psi and release hanger. Pressure dropped. Picked up pump rate to 5 bpm. Up weight 175k, down 95k. Set down 45k to verify hanger set. RUNPRD Circulate BU at 10.3 bpm with 2474 psi. Mudpush back to surface with a trace of cement. RUNPRD Lay down single and cement head. Rig down cement equipment. Blow down lines and lay down another single joint of DP. RUNPRD Displace well to clean seawater at 9.5 bpm with 1775 psi. Pump dry job, monitor well. Blow down topdrive. RUNPRD Cut and slip 83' of drilling line. Visual inspection of braking system. Check load cell gap. Inspect traction motor brushes. Service elmago spline. Service topdrive and draworks. RUNPRD POOH and LD DP to 3300'. RUNPRD Remove iron roughneck spinner assembly and replace ram. Bad head seal. RUNPRD POOH and LD DP, XO and running tool. Tool came out of hole in one piece. Run excess DP out of derrick into hole and LD same. RUNCMP MU XO and puller. Back out lock down screws and pull wear ring. Break and LD single. Clear and clean floor. PJSM. RU stabbing board. Remove saver sub and change out bales. RUNCMP Rig up to run tubing. RUNCMP Test casing to 3500 psi for 30 minutes. Record on chart. Test OK. RUNCMP Run 4.5" 12.6#, 13Cr-80 Vam Top completion tubing. Bakerlok connections below packer. Torque connections to 4440 ft/Ibs. Up weight 95k, down 85k. Run a total of 256 joints, 3 GLM, packer, and 4 X-nipples with 2 space out pups. Up weight 155k, down 105k. RUNCMP Tag, space out and make up pups. (9.88 and 7.77) Run last full joint. Pull air slips. Rig down stabbing board and compensator. Change out elevators. PU/MU landing joint. Rig down double stack tongs. Drain stack and land hanger. Run in lock down screws. Lay down landing joint. Total depth of tubing at 10962.77'. RUNCMP Line up on tubing annulus. Reverse circulate clean seawater and corrosion inhibitor at 126 gpm with 230 psi. RUNCMP Reverse circulate clean seawater and corrosion inhibitor at 126 gpm with 220 psi. Change out bales and saver sub on top drive. RUNCMP Drop ball and rod. Pressure up to 3500 psi on tubing. Set packer. Test tubing for 30 minutes, record on chart. Test OK. Bleed pressure to 2000 psi. Pressure up annulus to 3500 psi and test against packer for 30 minutes, record on chart. Test OK. Bleed tubing pressure and shear DCK valve. Circulate Printed: 11/6/2006 8:03:36 AM BP EXPLORATION Page 12 of 12 Operations .Summary Report Legal Well Name: E-11A Common Well Name: E-11A Spud Date: 8/20/1981 Event Name: REENTER+COMPLETE Start: 10/6/2006 End: 10/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/1/2006 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 11/1/2006 03:00 - 04:30 1.50 BUNCO RUNCMP both ways to check for flow - OK. 04:30 - 09:30 5.00 BOPSU P RUNCMP Install TWC. Pressure test to 1000 psi from below. ND BOPE. 09:30 - 13:30 4.00 WHSUR P RUNCMP Nipple up adapter flange and tree. Test adapter flange to 5000 psi for 10 minutes - OK. Check torque on tree bolts and nuts. Install blind flange on flow line wing. 13:30 - 15:00 1.50 WHSUR P RUNCMP Fill and test tree to 5000 psi. Test OK. 15:00 - 16:00 1.00 WHSUR P RUNCMP Rig up DSM lubricator. Pull TWC and rig down lubricator. 16:00 - 00:00 8.00 WHSUR P RUNCMP Rig up circulating lines to annulus and top of tree. Pressure test lines to 3000 psi. Reverse circulate 150 bbls of 80 degree diesel freeze protection. Freeze protect to 2200'. Taking seawater returns to cuttings tank. Blow down return line and u-tube well. Suck back tree. Remove hose manifold. Dry rod BPV and test from below to 1000 psi. Rig down circulating lines. Remove secondary annulus valve. Install gauges and needle valves. Secure well and cellar. Suck out and clean pits. Release rig at midnight. Printed: 11/6/2006 8:03:36 AM Digital Wellfile Page 1 of 1 Well Events for SurfaceWell - E-li~ Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> E -> E-11 Date Range: 17/Nov/2006 to 04/Jan/2007 Data Source(s): DIMS, AWGRS Events Source Well Date Description AWGRS E-11B 12/08/2006 ***CONTINUED FROM 7-DEC-2006*** PERFORATE 11,103-11,153 FT WITH 3-3/8" HSD, 6 SPF, 60 DEG PHASING ***JOB COMPLETE*** AWGRS E-116 12/07/2006 PERFORATE 11103' - 11153' WITH 3-3/8" HSD 3406 PJ, 6 SPF, 60 DEG PHASED. API DATA: PENETRATION = 36.5", ENTRANCE HOLE = 0.37", EXPLOSIVE LOAD = 22.7 G RUN 1: PERFORATE 11153' - 11133' CCL TO TOP SHOT = 4.1'; CCL STOP DEPTH = 11128.9' RUN 2: PERFORATE 11133' - 11113' CCL TO TOP SHOT = 4.1'; CCL STOP DEPTH = 11108.9' RUN 3: PERFORATE 11,103-11,113' CCL TO TOP SHOT = 4.1'; CCL STOP DEPTH = 11,098.9' ***JOB INCOMPLETE CONTINUED 8-DEC-2006** AWGRS E-11B 12/06/2006 ATTEMPT TO PERFORATE 11103' - 11153' USING 3.38" HST PJ OMEGA, 6 SPF, 60 DEG PHASED. DID NOT GET IN HOLE, CALLED AWAY TO RIG JOB. ***JOB INCOMPLETE*** AWGRS E-116 12/01/2006 T/I/O = 1,500/ 0/0/ 13 5/8" FMC BP original wellhead, 4 1/16" Upper Tree Inspect wellhead and upper tree for stud bolting. Removed and installed 8) 1 1/8" x 8 1/4" studs on FMC "75" 3 1/16" F/E 5m HWO Inner anulus valve to 3 1/16" 5m companion flange. Installed 1) 3/4" bolt on Baker CAC surtace safety valve actuator. Note: Wing valve to C/L of cross 29". Bottom of Master valve to C/L of cross 4' S" AWGRS. E-116 11/28/2006 ***JOB CONT. FROM 11/27/06*** SET STA.#3 BK-DOME @ 4120' SLM SET STA.#2 BK- ORIFICE @ 7551' SLM SET STA.#1 BK-DMY @ 9932' SLM PULL RHC PLUG BODY FROM 10937' SLM. DRIFT DOWN TO 11502' SLM WITH 3 3/8" DUMMY GUN, OAL 143" , NO SAMPLE RECOVERED IN BAILER. (PERF TARGET @ 11,103--11,153'MD) RIG DOWN TURN WELL BACK TO DSO. IA CASING VALVE WAS FOUND IN CLOSED POSITION WE ARRIVED, LEFT IN OPEN POSITION. AWGRS E-11B 11/27/2006 *** WELL SHUT IN ON ARRIVAL *** (post sdtrk) PULLED B&R @ 10927' SLM PULLED BK- DGLV IN STA.#1 @ 9932' SLM & BK-DGLV IN STA.#2 @ 7551' SLM PULLED BK-DCK IN STA.#3 @ 4120' SLM ***JOB CONT. ON 11/28/06*** AWGRS E-116 11/17/2006 PULL 4" CIW BPV POST RIG WORK Refresh List http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 1/4/2007 ~alliburton Company Survey Report C'ompany: BP Al110C0 - Dutc: 11'8.'2006 Cimc: __ 13:58.52 - --- Pale: I Picki: P~udhoe Bay Co-ordinatc(NP;1 Ref ereiuc W ell: E-17, True NO rih Site: PB E Pad S~ertical f"CVDI Kefcr ence: 25.8 + 32.03 Si .8 ~i'cll E-11 Section (VS)Reference: W ell (O.OON,O.OOE.22.76Azil ~ ~~'cll ath: E-1 1 B Surrey Calculation Method: Mi nimum Curvature Db: OraCIE~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Aiaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: E-11 Slot Name: 11 E-11 Well Position: +N/-S 3398.09 ft Northing: 5976601.00 ft Latitude: 70 20 32.551 N +E/-W 1987.27 ft Easting : 664452.00 ft Longitude: 148 39 54.999 W Position Uncertainty: 0.00 ft Wellpath: E-11 B Drilled From: E-11 500292047502 Tie-on Depth: 4797.05 ft Current Datum: 25.8 + 32.03 Height 57.83 ft Above System Datum: Mean Sea Level Magnetic Data: 10/4/2006 Declination: 24.23 deg Field Strength: 57653 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25 .80 0.00 0.00 22.76 Survey Program for Definitive Wellpath Date: 11/8/2006 Validated: N o Version: 29 Actual From To Survey Toolcode Tool Name ft ft 97.05 4797.05 Sperry Boss Gyro Multishot (97 BOSS-GYRO Sperry-Sun BOSS gyro mu ltishot 4860.00 11649.57 E-11B IIFR+MS+SAG (4860.00-116 MWD+IFR+MS MWD +IFR + Multi Station Survey :111) Incl 1.zim TVD Sys TVD N/S E/W MapN ~lapli Tool ft deg deg ft ft ft ft ft ti ! 25.80 0.00 0.00 25.80 -32.03 0.00 0.00 5976601.00 664452.00 TIE LINE 97.05 0.10 138.80 97.05 39.22 -0.05 0.04 5976600.95 664452.04 BOSS-GYRO 197.05 0.15 184.50 197.05 139.22 -0.24 0.09 5976600.76 664452.09 BOSS-GYRO 297.05 0.50 204.29 297.05 239.22 -0.77 -0.10 5976600.23 664451.91 BOSS-GYRO 397.05 0.97 215.29 397.04 339.21 -1.56 -0.77 5976599.12 664451.27 BOSS-GYRO 497.05 1.03 207.69 497.02 439.19 -3.35 -1.68 5976597.62 664450.40 BOSS-GYRO 597.05 1.00 206.00 597.01 539.18 -4.93 -2.48 5976596.02 664449.63 BOSS-GYRO 697.05 0.85 203.19 697.00 639.17 -6.39 -3.15 5976594.54 664448.99 BOSS-GYRO 797.05 0.78 220.39 796.99 739.16 -7.59 -3.88 5976593.32 664448.28 BOSS-GYRO 897.05 0.60 196.00 896.98 839.15 -8.61 -4.47 5976592.29 664447.72 BOSS-GYRO 997.05 0.63 209.19 996.97 939.14 -9.60 -4.88 5976591.30 664447.33 BOSS-GYRO 1097.05 0.42 184.10 1096.97 1039.14 -10.44 -5.18 5976590.45 664447.05 BOSS-GYRO 1197.05 0.30 164.70 1196.97 1139.14 -11.06 -5.13 5976589.83 664447.11 BOSS-GYRO 1297.05 0.28 168.90 1296.97 1239.14 -11.55 -5.02 5976589.34 664447.24 BOSS-GYRO 1397.05 0.47 163.20 1396.96 1339.13 -12.19 -4.85 5976588.71 664447.42 BOSS-GYRO 1497.05 0.30 151.70 1496.96 1439.13 -12.81 -4.61 5976588.09 664447.67 BOSS-GYRO 1597.05 1.77 88.90 1596.94 1539.11 -13.01 -2.94 5976587.93 664449.34 BOSS-GYRO 1697.05 4.55 66.90 1696.78 1638.95 -11.42 2.25 5976589.63 664454.50 BOSS-GYRO 1797.05 4.73 69.80 1796.46 1738.63 -8.44 9.77 5976592.77 664461.95 BOSS-GYRO 1897.05 5.37 37.29 1896.09 1838.26 -3.30 16.48 5976598.07 664468.54 BOSS-GYRO 1947.05 7.65 31.20 1945.76 1887.93 1.41 19.62 5976602.84 664471.58 BOSS-GYRO 1997.05 10.78 34.20 1995.11 1937.28 8.13 23.97 5976609.65 664475.78 BOSS-GYRO 2097.05 14.22 43.70 2092.74 2034.91 24.75 37.72 5976626.57 664489.16 BOSS-GYRO 2197.05 16.63 47.00 2189.13 2131.30 43.39 56.67 5976645.62 664507.70 BOSS-GYRO 2297.05 19.47 47.20 2284.20 2226.37 64.48 79.37 5976667.20 664529.93 BOSS-GYRO 2397.05 22.22 47.20 2377.64 2319.81 88.65 105.48 5976691.94 664555.50 BOSS-GYRO 2497.05 25.03 47.79 2469.25 2411.42 115.72 135.03 5976719.64 664584.45 BOSS-GYRO 2597.05 27.78 48.79 2558.81 2500.98 145.29 168.23 5976749.94 664616.99 BOSS-GYRO 2697.05 29.82 49.00 2646.44 2588.61 176.96 204.53 5976782.39 664652.59 BOSS-GYRO ' ~alliburton Company Survey Report Company: BP AmOCO Field: Prudhoe Bay tine: PB E Pad WeIL• E-1 i ~~'ellpath: E-1 1 B Survey MD Incl ft deg zim deg VD ft ys'I`VD ft Date: 11r'8~2006 time 13:58:52 Page: 2 Co-c~rt3inatc(NE) Kcference: WeIL E-11, True North Vertical ('I'Vll) Reference: 25.8 - 32,03 57.8 Section (VS) Reference: Well (O.OON,O.OOE.22.76Azi) Survey Calculation Method: Minimum Curvature Db: Oracle NlS FJW titapN MapE Tool ft ft ft ft 2797.05 32.42 51.79 2732.05 2674.22 209.86 244.37 5976816.15 664691.69 BOSS-GYRO 2897.05 33.72 54.50 2815.85 2758.02 242.56 288.03 5976849.80 664734.62 BOSS-GYRO 2997.05 34.95 55.00 2898.42 2840.59 275.11 334.10 5976883.35 664779.96 BOSS-GYRO 3097.05 35.58 57.90 2980.08 2922.25 307.00 382.21 5976916.29 664827.35 BOSS-GYRO 3197.05 37.52 60.00 3060.41 3002.58 337.69 433.23 5976948.09 664877.69 BOSS-GYRO 3297.05 37.75 59.90 3139.60 3081.77 368.27 486.09 5976979.82 664929.86 BOSS-GYRO 3397.05 37.85 60.29 3218.62 3160.79 398.82 539.22 5977011.53 664982.30 BOSS-GYRO 3497.05 38.03 59.70 3297.48 3239.65 429.57 592.46 5977043.43 665034.85 BOSS-GYRO 3597.05 38.25 60.20 3376.13 3318.30 460.50 645.92 5977075.52 665087.61 BOSS-GYRO 3697.05 38.08 60.00 3454.76 3396.93 491.30 699.49 5977107.49 665140.49 BOSS-GYRO 3797.05 38.03 59.70 3533.50 3475.67 522.26 752.79 5977139.61 665193.10 BOSS-GYRO 3897.05 38.00 60.20 3612.28 3554.45 553.10 806.10 5977171.61 665245.71 BOSS-GYRO 3997.05 37.65 60.29 3691.27 3633.44 583.53 859.34 5977203.20 665298.27 BOSS-GYRO 4097.05 37.53 60.29 3770.51 3712.68 613.77 912.32 5977234.59 665350.57 BOSS-GYRO 4197.05 37.40 60.20 3849.89 3792.06 643.96 965.13 5977265.93 665402.70 BOSS-GYRO 4297.05 37.27 60.00 3929.40 3871.57 674.19 1017.70 5977297.30 665454.60 BOSS-GYRO 4397.05 37.12 60.00 4009.05 3951.22 704.41 1070.05 5977328.67 665506.27 BOSS-GYRO 4497.05 36.87 59.29 4088.92 4031.09 734.82 1121.98 5977360.21 665557.51 BOSS-GYRO 4597.05 36.73 60.90 4169.00 4111.17 764.69 1173.90 5977391.20 665608.76 BOSS-GYRO 4697.05 36.65 59.90 4249.19 4191.36 794.20 1225.85 5977421.84 665660.05 BOSS-GYRO 4797.05 36.32 59.90 4329.59 4271.76 824.02 1277.29 5977452.78 665710.82 BOSS-GYRO 4860.00 36.50 60.08 4380.25 4322.42 842.71 1309.65 5977472.17 665742.76 MWD+IFR+MS 4916.44 37.16 53.58 4425.44 4367.61 861.21 1337.93 5977491.29 665770.62 MWD+IFR+MS 5011.28 38.88 43.06 4500.23 .4442.40 900.00 1381.35 5977531.02 665813.18 MWD+IFR+MS 5105.45 40.27 33.18 4572.89 4515.06 947.12 1418.22 5977578.94 665849.01 MWD+IFR+MS 5199.10 43.46 25.38 4642.67 4584.84 1001.60 1448.62 5977634.07 665878.20 MWD+IFR+MS 5292.75 43.62 24.67 4710.56 4652.73 1060.06 1475.91 5977693.10 665904.20 MWD+IFR+MS 5385.25 43.12 24.42 4777.80 4719.97 1 i 17.84 1502.30 5977751.45 665929.31 MWD+IFR+MS 5478.99 44.29 24.82 4845.56 4787.73 1176.72 1529.28 5977810.90 665954.99 MWD+IFR+MS 5572.19 47.50 24.89 4910.42 4852.59 1237.43 1557.41 5977872.21 665981.78 MWD+IFR+MS 5666.21 48.20 22.06 4973.52 4915.69 1301.36 1585.16 5977936.73 666008.12 MWD+IFR+MS 5759.19 47.99 22.02 5035.62 4977.79 1365.50 1611.13 5978001.42 666032.67 MWD+IFR+MS 5853.23 48.41 19.58 5098.31 5040.48 1431.03 1636.01 5978067.48 666056.12 MWD+IFR+MS 5947.11 48.15 19.29 5160.78 5102.95 1497.11 1659.33 5978134.05 666077.97 MWD+IFR+MS 6039.72 47,70 17.29 5222.85 5165.02 1562.37 1680.90 5978199.76 666098.11 MWD+IFR+MS 6133.71 49.96 15.24 5284.72 5226.89 1630.29 1700.70 5978268.09 666116.41 MWD+IFR+MS 6227.84 50.20 15.25 5345.12 5287.29 1699.94 1719.68 5978338.13 666133.86 MWD+IFR+MS 6322.13 49.24 16.06 5406.08 5348.25 1769.20 1739.09 5978407.80 666151.74 MWD+IFR+MS 6414.23 47.78 15.96 5467.10 5409.27 1835.51 1758.11 5978474.51 666169.31 MWD+IFR+MS 6507.82 48.55 17.21 5529.52 5471.69 1902.34 1778.02 5978541.75 666187.74 MWD+IFR+MS 6600.02 49.03 17.29 5590.27 5532.44 1968.58 1798.59 5978608.43 666206.85 MWD+IFR+MS 6691.59 48.32 17.15 5650.73 5592.90 2034.27 1818.95 5978674.54 666225.76 MWD+IFR+MS 6784.43 47.87 16.89 5712.74 5654.91 2100.34 1839.17 5978741.03 666244.53 MWD+IFR+MS 6877.84 48.93 17.71 5774.76 5716.93 2167.02 1859.95 5978808.15 666263.84 MWD+IFR+MS 6971.29 49.52 18.85 5835.79 5777.96 2234.22 1882.15 5978875.81 666284.56 MWD+IFR+MS 7064.63 49.27 17.56 5896.54 5838.71 2301.53 1904.29 5978943.59 666305.21 MWD+IFR+MS 7158.00 49.25 17.60 5957.47 5899.64 2368.97 1925.66 5979011.48 666325.09 MWD+IFR+MS 7251.56 49.14 16.80 6018.62 5960.79 2436.62 1946.60 5979079.57 666344.55 MWD+IFR+MS 7345.33 49.07 16.43 6080.00 6022.17 2504.55 1966.87 5979147.91 666363.32 MWD+IFR+MS 7436.69 50.60 18.39 6138.93 6081.10 2571.15 1987.77 5979214.96 666382.75 MWD+IFR+MS 7533.17 50.16 18.49 6200.46 6142.63 2641.65 2011.27 5979285.95 666404.70 MWD+IFR+MS 7627.41 50.08 17.90 6260.88 6203.05 2710.36 2033.85 5979355.13 666425.77 MWD+IFR+MS ' alliburton Company Survey Report Cump.u~~: BP AInOCO llate: 1118/2006 Time: 13:58:52 Page: 3 Hiekl: Pru dhoe Bay Co-ord inate(Si~;i C2cCeraux: Well: E-11, True N orth Site: PB E Pad Vertica l {CYUi kefe rence: 25.8 + 32.03 57.8 '~ «'ell: E-1 1 Section (VS) Referen ce: Well (O.OON,O.OOE. 22.76Azi} ~1'ellpath: E-1 1 B Survey Calculation ~Icth«i: Minlm wn Curvature Db: Orarle Survey' MD Incl Azim TVD S}s l'~~U N/ti 1~J1'1 MapN 111apE Tirol it deg deg ft ft ft tt ft ft 7720.88 49.18 19.26 6321.43 6263.60 2777.85 2056.54 5979423.11 666446.97 MWD+IFR+MS 7813.37 49.20 18.19 6381.87 6324.04 2844.15 2079.01 5979489.87 666467.98 MWD+IFR+MS 7908.35 48.70 18.67 6444.25 6386.42 2912.11 2101.65 5979558.30 666489.12 MWD+IFR+MS 7999.74 48.51 17.50 6504.68 6446.85 2977.27 2122.94 5979623.92 666508.97 MWD+IFR+MS 8093.47 47.78 18.07 6567.22 6509.39 3043.75 2144.26 5979690.84 666528.83 MWD+IFR+MS 8185.33 47.02 17.99 6629.40 6571.57 3108.05 2165.19 5979755.58 666548.34 MWD+IFR+MS 8279.87 46.07 17.28 6694.42 6636.59 3173.45 2185.98 5979821.42 666567.69 MWD+IFR+MS 8373.87 45.06 17.02 6760.23 6702.40 3237.58 2205.77 5979885.96 666586.07 MWD+IFR+MS 8467.50 44.28 16.92 6826.82 6768.99 3300.54 2224.99 5979949.32 666603.90 MWD+IFR+MS 8561.13 43.66 15.71 6894.20 6836.37 3362.92 2243.25 5980012.09 666620.79 MWD+IFR+MS 8655.16 43.24 12.30 6962.48 6904.65 3425.65 2258.90 5980075.14 666635.06 MWD+IFR+MS 8748.78 43.12 11.93 7030.75 6972.92 3488.28 2272.35 5980138.05 666647.13 MWD+IFR+MS 8842.85 42.62 11.31 7099.69 7041.86 3550.97 2285.24 5980201.00 666658.64 MWD+IFR+MS 8936.02 40.32 11.66 7169.50 7111.67 3611.43 2297.52 5980261.71 666669.59 MWD+IFR+MS 9029.96 39.59 11.98 7241.51 7183.68 3670.48 2309.88 5980321.01 666680.65 MWD+IFR+MS 9122.89 36.77 11.21 7314.55 7256.72 3726.74 2321.43 5980377.51 666690.97 MWD+IFR+MS 9217.19 35.82 10.12 7390.55 7332.72 3781.59 2331.77 5980432.57 666700.09 MWD+IFR+MS 9308.86 34.63 7.98 7465.44 7407.61 3833.80 2340.10 5980484.94 666707.28 MWD+IFR+MS 9404.23 33.36 7.69 7544.51 7486.68 3886.62 2347.37 5980537.91 666713.39 MWD+IFR+MS 9497.36 31.73 3.44 7623.02 7565.19 3936.45 2352.27 5980587.83 666717.19 MWD+IFR+MS 9589.22 30.98 3.21 7701.47 7643.64 3984.17 2355.04 5980635.59 666718.92 MWD+IFR+MS 9682.95 30.15 2.28 7782.17 7724.34 4031.78 2357.33 5980683.24 666720.16 MWD+IFR+MS 9777.00 29.25. 1.83 7863.87 7806.04 4078.34 2359.00 5980729.83 666720.81 MWD+IFR+MS 9870.94 28.58 359.39 7946.10 7888.27 4123.75 2359.49 5980775.23 666720.31 MWD+IFR+MS 9964.45 29.23 357.16 8027.96 7970.13 4168.92 2358.12 5980820.36 666717.95 MWD+IFR+MS 10057.36 29.83 354.70 8108.80 8050.97 4214.59 2354.87 5980865.94 666713.69 MWD+IFR+MS 10150.59 30.83 351.40 8189.28 8131.45 4261.31 2349.15 5980912.52 666706.95 MWD+IFR+MS 10242.39 30.92 347.83 8268.08 8210.25 4307.62 2340.66 5980958.63 666697.45 MWD+IFR+MS 10335.61 30.21 348.17 8348.34 8290.51 4353.99 2330.80 5981004.77 666686.57 MWD+IFR+MS 10428.78 28.62 345.12 8429.50 8371.67 4398.51 2320.27 5981049.04 666675.06 MWD+IFR+MS 10521.52 28.28 342.24 8511.05 8453.22 4440.90 2307.86 5981091.14 666661.73 MWD+IFR+MS 10614.97 29.38 337.63 8592.92 8535.09 4483.18 2292.38 5981133.08 666645.33 MWD+IFR+MS 10708.75 30.12 335.59 8674.34 8616.51 4525.89 2273.90 5981175.36 666625.92 MWD+IFR+MS 10800.00 29.49 335.28 8753.52 8695.69 4567.14 2255.05 5981216.19 666606.17 MWD+IFR+MS 10893.09 27.56 335.16 8835.31 8777.48 4607.50 2236.42 5981256.12 666586.66 MWD+IFR+MS 10986.44 26.13 335.29 8918.60 8860.77 4645.77 2218.75 5981294.00 666568.16 MWD+IFR+MS 11052.98 24.85 335.46 8978.66 8920.83 4671.80 2206.82 5981319.76 666555.66 MWD+IFR+MS 11101.36 24.85 331.90 9022.56 8964.73 4690.02 2197.81 5981337.77 666546.25 MWD+IFR+MS 11169.42 27.14 331.90 9083.73 9025.90 4716.33 2183.76 5981363.77 666531.63 MWD+IFR+MS 11262.74 28.61 327.94 9166.23 9108.40 4754.04 2161.87 5981400.99 666508.92 MWD+IFR+MS 11352.73 28.19 328.32 9245.39 9187.56 4790.39 2139.27 5981436.83 666485.53 MWD+IFR+MS 11446.89 27.30 329.79 9328.72 9270.89 4827.98 2116.73 5981473.92 666462.17 MWD+IFR+MS 11540.98 26.59 329.96 9412.60 9354.77 4864.86 2095.33 5981510.31 666439.96 MWD+IFR+MS 11632.95 25.76 330.68 9495.14 9437.31 4900.10 2075.24 5981545.10 666419.11 MWD+IFR+MS 11649.57 25.60 331.40 9510.12 9452.29 4906.40 2071.75 5981551.33 666415.48 MWD+IFR+MS 11687.00 25.60 331.40 9543.87 9486.04 4920.60 2064.01 5981565.35 666407.43 BLIND E-11 B~ctual Completion ~AFETY NOTES: L 2235' 4-112" Landing X Nipple, ID = 3.813" 2729' 13-3/8" CSG, 68#, L-80, ID = 12.415" r_~ GAS LIFT MANDRELS HangerlPacker 4703' Top of 9-5/8 4861, Window Bottom of 9-518 ~8, Window 9-5/8 x 7 BKR ZXP LNR PKR 5408' Window: 8782` - 8796 10167' ~ 9-5/8" CSG, 47#, L-80, ID = 8.681' 7" TBG, 26#, - L-80, ID = 6.276" ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4134 3800 37 KBG2 DOME BK 16 11/28/06 2 7560 6218 50 KBG2 SO BK 20 11/28/06 1 9939 8006 29 KBG2 DMY BK 0 11!28/06 TREE= - - 4-1/16CMJ WELLHEAD= FMC ACTUATOR= KB. ELEV = OTIS 68.77' BF. ELEV = KOP = 30.28' 2008' Max Angle = 50.6 @ 743T Datum MD = 1168T Datum TVDss= 9486' -=- _ = 4-1/2 X Nip., 10843, ID=3.813" - 7" x 4-1/2" 53 BKR PKR 10905' 4-1/2 X Nip., 10929', ID=3.813" -1/2" X Nip., 10950`, ID=3.813" -1/2" LNR TIEBACK, HMC HGR AND ZXP PKR 10963` ~ _ Hole in 9 5/8" CSG -5630` 100' Cement P&A Plug ~ , 4-1/2" 12.6#, 13Cr-80 Tubing, ID = 3.958" 7" LNR, 26#, L-80, '° ID = 6.276" 11095' a ~~ PERFORATION SUMMARY REF LOG: MWD ON 10/15-28/06 ANGLEATTOPPERF: 25 @ 11103' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11103-11153 O 12/07/06 XXN Plug 4-1/2" LNR, 12.6#,L-80 / ID = 3.953" 11687` 10975' 7"LNR, 26#, L-80, .0383 bpf, ID = 6.276 ~ 11812' ~TOPOF4-112"SLTDLNR .~ 4-1I2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11812' 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 12550' DATE REV BY COMMEMS DATE REV BY COMMENTS 11/01/06 MGS Sidetrack Producer 11109/06 /TLH CORRECTIONS 12/03/06 JG/TLH TREE CORRECTION & GLV C/O 12!07106 JMF/TLH INffIAL PERFS PRUDHOE BAY UNrf WELL: E 11 B PERMff No: API No: 50-029-20475-02 SEC 6, T11 N, R14E, 500' W EL & 463' SNL SP 6cploration (Alaska) t~a8i1, OIL A1~TD G.~s col~s~RVATaoH cor~n-IIssao~ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-11 B BP Exploration (Alaska) Inc. Permit No: 206-143 Surface Location: 463' FNL, 500' FEL, SEC. 06, Tl 1N, R14E, UM Bottomhole Location: 4440' FSL, 1570' FWL, SEC. 32, T12N, R14E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907} 659-3607 (pager). DATED this day of October, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ~ ~ ~ ~ ALASKA~AND GAS CONSERVATION COMMISSI~ ~'~~~'~ ~' PERMIT TO DRILL 20 AAC 25.005 ~/~b~~ OCT ~ 5 2Q06 AI~>tk~ [til 8~ G»~ COMB. GOtTNTtI$$10(1 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is p ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU E-11B i~~3 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11639 TVD 9500 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 463' FNL 500' FEL SEC T11 N R14E 06 UM 7. Property Designation: ADL 028299 Pool , , , . , , Top of Productive Horizon: 3618' FSL, 1883' FWL, SEC. 32, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Sp ;ate: Octobe 11 2006 Total Depth: 4440' FSL, 1570' FWL, SEC. 32, T12N, R14E, UM 9. Acres in Property: 2560 14. Distance to Ne st Property: 1800' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664452 y- 5976601 Zone- ASP4 10. KB Elevation Plan (Height above GL): 60 feet 15. Distance to Nearest Well Within Pool: 2200' 16. Deviated Wells: Kickoff Depth: 4750 feet Maximum Hole An le: 48 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3660 Surface: 3240 ~ 18. Casin Pr ram: S ecficatio ns To - Settin De th -Bo ttom Quanti of G ment c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 6449' 4600' 4178' 11049' 8984' 1011 cu ft LiteCrete 195 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 740' 10899' 8854' 11639' 9500' 120 cu ft Class'G' ~ 19. PRESE NT WELL CONDITION S UMMARY (l'o be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12550 Total Depth TVD (ft): g6gg Plugs (measured): 10798 Effective Depth MD (ft): 10798 Effective Depth TVD (ft): 8571 Junk (measured): 9958 using Length ize Cement Volume MD TVD Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2729 13-3/8" 3720 cu ft Arcticset II 2729' 2676' Intermediate 8782' 9-5/8" 1450 cu ft Class 'G' 130 cu ft Arcticset I 8782' 7552' Produ ti n Liner 5567' 7" 396 cu ft Class'G' 5408' - 10975' 4822' - 8634' Liner 1743' 4-1/2" 180 cu ft Class'G' 10807' - 12550' 8575' - 8688' Perforation Depth MD (ft): 11851' - 12548' Perforation Depth TVD (ft): 8697' - 8688' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer ~7 ~ Prepared By Name/Number: Si nature •-`-/~'j Phone 564-4166 Date ~''~ S ~'~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: API Number: 50-029-20475-02-00 Permit A royal See cover letter for Date: ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ^ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No i ,e S -~- p, a (~ ~ f -d 7j ~j pp ~p f,~' HZS Measures: ;$j Yes ^ No Di 'onal Survey Req'd: Yes ^ No er: I_ wv .u ~f fo 2~ ~.~ ZS . 0 35 «~ ~1~ , ~ {~~u~e ~o ~.2 r%s ~~ 1-vVed . Date `~^ ~^O,p APPROVED BY THE COMMISSION COMMISSIONER i Form 10-401 Revised 12/2005 ~ R ~ ~ ~ N A L ~ I " ~ Submit In Duplicate Planned Well Summary Well E-11 B Wele Slant Sidetrack Ob ect ve Zone 1 A AFE Number: Surface Northin Eastin Offsets TRS Location 5,976,601 664,452 463' FNL / 500' FEL 11 N, 14E, 6 API Number: 50-029-20475-02 T t Northin Eastin Offsets TRS arge L ti 5,980,733 666,731 1662; FNL / 1883; FWL 12N, 14E, 32 oca ons 5,981,309 666,555 1082 FNL / 1722 FWL 12N, 14E, 32 Bottom Northin Eastin Offsets TRS Location 5,981,548 666,397 840' FNL/ 1570' FWL 12N, 14E, 32 Planned KOP: 4,750' and / 4,292' tvd Planned TD: 11,639' and / 9,500' tvd Ri Nabor E CBE: 30.28' RTE: 60.0' Directional Program i A roved Well Ian: W 20 Exit oint: 4,750' and ! 4,292' tvd Maximum Hole Inclination: -48° in the tanned 8-'h" intermediate section. Proximity Issues: All surrounding wells pass major risk criteria. Wells E-104 and E-12 are the closest nei hborin wells, at 171.88' and 110.04' res ectivel . Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: 2200 ft. to the nearest well E-07A at to of Ivishak Nearest Pro a Line 1800 ft. northwest to the Prudhoe Ba Unit Bounda Logging Program Hole Section: Required Sensors /Service 8-'/z" intermediate: Real time MWD Dir/GR/Res/Neu/Den/PWD throughout the interval. MAD pass drop for Den/Neu for TKUP target if necessary. Collect sam les over Ku aruk tar et. 6-'/8" production: Real time MWD Dir/GR/Res/ABI/Neu/Den. Sam les at 50' intervals throu hout. Cased Hole: None Open Hole: Sonic (may be incorporated with MWD) in intermediate and production. Sidewall cores will be collected in the Ku aruk formation if resent. E-11 B Sidetrack Page 1 • Mud Proaram • Hole Section / o eration: Mill window in the 9 5/8" casin at 4,750' and T e LSND Densit 9.2 MBT N/C PV 16-30 YP 30-35 API FL H <6.0 9.0 -10.0 Hole Section /operation: Drilling 8-'h" interval from 4,750' and to 200' above THRZ T e LSND Densit 9.2 - 9.4 MBT <15 PV 14-26 YP 26-30 API FL H <6.0 9.0 -10.0 Hole Section / o eration: Drillin 8-'/z" interval from THRZ to TD T e Densit MBT PV YP API FL H LSND 1 .7 <15 15-22 26-30 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 6-'/8' reduction interval T e Densi LSRV PV YP API FL H FloPro SF 8.4 - 8.5 >20.000 8 -12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8-'/z " 7" 26.0# L-80 BTC-M 6449' 4600' / 4178' 1.1049' / 8984' 6-'/a" 4'/z" 12.6# L-80 IBT-M 740' 10899' / 8854' 11,639' / 9500' Tubin 4'/z" 12.6# L-80 TC-II 10899' Surface 10899' / 8854' Casing /Formation Integrity Testing Test Test Point Test Type Test pressure CMIT TxIA TTP to surface 30 min recorded 3,500 si surface 7" casin Bride lu / Cmt to surface 30 min recorded 3,500 si surface 9 5/e" casin 20' new formation FIT 11.9 EMW 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'/z" reduction liner Float a ui ment to surface 30 min recorded 3,500 si surface 4-'/z" reduction tubin 7" x 4-~/z" acker to surface 30 min recorded 3,500 si surface E-11 B Sidetrack Page 2 • Cementing Program Casin Strin 7", 26#, L-80, BTC-M P&A Plu Slurry Design Basis: Lead slurry: None planned. Tail slur :100' of 7" Casin on to of CIBP C~ 9,850' with 0% excesss. Pre-Flush None Planned Fl id S /V l S acer 10 bbl Fresh Water ahead / 1.5 bbl behind u s equence o ume: Lead Slur None tanned Tail Slur 10 bbl / 56 cf 56 xs Class `G', 17.0 ; 1.00 cf/sk. Casin Strin 7", 26#, L-80, BTC-M intermediate liner Lead slurry: 5,299' of 7" x 8-'/z" annulus with 40% excess Slurry Design Basis: Tail slurry: 1,000' of 7" x 8-'/z" annulus with 40% excess, plus 80' of 7", 26# " " ' " ' " x 4 shoe track, plus 150 of 7 x 9 5/8 liner lap, plus 200 of 9 5/s drill pipe annulus. Pre-Flush None tanned Fl id S /V l S acer 100 bbls MudPUSH .4 u s equence o ume: Lead Slur 180 bbls / 1011 cf xs Litecrete; 12.5 ; 2 f/sk. Tail Slur 34.7 bbl / 195 cf / _ xs Class `G', 15.8 /sk. Casin Strin 4-'/z", 12.6#, L-80, IBT-M solid roduction liner Lead slurry: none planned Slurry Design Basis: Tail slurry: 590' of 4-~/z" x 6-'/8" annulus with 40% excess, plus 80' of 4-~/2", " " " ' ' 12.6# shoe track, plus 150 of 7 x 4-/z Inver lap, plus 200 of 7 x 4 drill pipe annulus. Pre-Flush None Planned Fl id ± S /V l S acer 40 bbls MudPUSH at 13.0 u s equence ume: o Lead Slur None tanned - Tail Slur 21.3 bbl / 120 cf 103 x Class `G', 15.8 1.17 f/sk. ~~/ ~~ E-11 B Sidetrack Page 3 Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8-'/z" intermediate interval Maximum anticipated BHP: 4,050 psi at 8,100' TVD. (Midnight Sun Kuparuk Pressure) Maximum surface pressure: 3,240 pSl (based upon BHP and a full column of gas from TD @ 0.10 psilft) Calculated kick tolerance: 51 bbls with 11.7 ppg EMW FIT with 10.7 ppg mud Planned BOPE test pressure: 250 psi low / 3,500 psi high for both sets of pipe rams i 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations BOPE configuration for 7" C/O to 7" pipe rams while running 6,299' of 7" liner. Bonnets will be drilling liner. tested as per AOGCC regulations. Across over with `TIW" valve will be on hand durin this o eration. Well Interval: 6-%8" roduction interval Maximum antici ated BHP: 3,660 si at 9,200' TVDss. Sambuka Ivishak Pressure Maximum surface ressure: 2,740 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT w/ 8.5 mud. Planned BOPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle Drillin o erations i Planned com letion fluid: 8.4 seawater / 7.1 Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP equipment for-other than well control or equivalent purposes, exceot when the routine use of BOP equipment may have`compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. E-11 B Sidetrack Page 4 Geologic Prognosis Estimated Estimated H drocarbon Formation To s Formation To s Uncertaint Bearin Formation MD TVDss feet Yes/No NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV5 3105 SV4 3233 SV3 3607 SV2 3773 SV1 4187 Kickoff 4750 4192 UG4 4640 20 UG4A 5308 4680 20 UG3 5639 4882 20 UG1 6465 5432 20 WS2 7354 6024 20 No WS1 7685 6244 20 No CM3 7980 6440 20 No THRZ 9695 7735 40 No BHRZITKUP 9875 7892 40 Yes LCU/TKNG/TJF 9907 7920 40 No TJE 10345 8305 40 No TJD 10563 8497 40 No TJC 10710 8627 40 No TJB 10856 8755 40 No Sa River 11049 8924 40 Yes Shublik 11114 8981 40 Yes TSAD/TZ4 11 i 64 9025 40 Yes MHO/HOT 11176 9035 30 es POWC 11233 9085 30 No TCGUTZ3 11250 9100 40 ? BCGUTZ2C 11299 9143 40 ? TZ16 11521 9337 40 ? BSAD 11605 9410 40 ? TD Criteria: TD pilot hole 200' after hitting water. If Ivishak NLOC is >60', cement and selectively perforate. Fault Prognosis The proposed E-11 B well has been designed to avoid seismically recognizable faults. E-11 B Sidetrack Page 5 E-11 B Sidetrack and Complete Procedure Summary Pre-Rip Work: 1. Drift 4-~/2" tubing through planned cut depth (SL found collapsed tubing at 9,958' MD). 2. Chemical cut the 4-~h" tubing at 9,900' MD (or as required if collapse found higher). 3. Pressure test well to 3,500 psi to test integrity of `PX' plug at 10,798' SLM and 9 5/s" x 7" casing. 4. Circulate well to sea water through tubing cut and freeze protect with diesel. 5. Test the casing and tubing pack-offs. Test the OA. Function all Lock Down Screws. 6. Set BPV. Secure well. Remove the wellhouse. If necessary, level the pad. Rip Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to sea water. . 3. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. '~. 4. Pull 4-'/z" tubing from pre-rig cut. 5. RU a-line. Run GR/JB for 7", 26# casing to top of tubing stub. ~ 6. MU 7", 26# bridge plug on a-line with CCL. RIH and set just above tubing stub. 7. Pressure test casing to 3,500 psi for 30 minutes. 8. RIH with open ended DP to bridge plug. Spot 100' cement on top of bridge plug. POOH. „'L -9. RU a-line. Run GR/JB for 9 5/8" casing through planned set depth. `cY~ 10. Run and set 9 5/8" bridge plug to position top of whipstock at 4,750'. ~11. RIH with 9 5/8" whipstock and window milling assy. Orient and set whipstock. --. 12. Mill window in 9 5/a' casing at ±4,750' MD plus 20' from mid window. Perform FIT. POOH. ~J 13. MU 8-'/2" drilling assembly with Dir/GR/Res/Den/Neu (collect all data Real-time) and RIH. ~' 14. Drill the 8-'/z" intermediate interval to Top Sag River, estimated depth of 11,049' MD. POOH. ~ 15. RU a-line. Run Dipole Sonic and SWC to TD of 8-%2" hole section. Run SWC's and obtain 45 cores across Kuparuk sands (SWC dependant on presence of Kuparuk interval). O 16. Perform wiper trip as required. "'' 17. Run and cement 7", 26# drilling liner with lap extended 150' into 9 5/8" casing. POOH.:. _ 18. MU 6-'/s" BHA with Dir/GR/Res/Dens/Neu (collect all data Real-time). RIH to the landing collar. `~ Pressure test wellbore to 3,500 psi' for 30 minutes. 19. Drill shoe track. Swap over to 8.5 ppg Flo-Pro and drill 20' of new formation. Perform FIT. ~ 20. Drill the 6-'/8" production interval to TD, estimated at 11,640' MD. POOH. 4 21. RU a-line. Run Dipole Sonic to TD of 6-'/d' hole section. 4 22. Perform wiper trip as required. 23. Run and cement a 4-~h", 12.6# production liner with lap extending 150' into the 7" drilling liner. Displace cement with perf pill and mud. Release from liner. Displace well to clean seawater above liner top. POOH. LD DP. 24. Run 4-~/z", 12.6#, 13Cr80 completion tying into the 4-'/2" liner top. 25. Set packer and test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 26. Set and test TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. 28. Freeze protect the well to 2,200' and secure. 29. RDMO Post-Rip Work: 1. Install wellhouse, flowlines and instrumentation. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. Install gas lift valves. 3. RU a-line. Perforate and test Sagllvishak as required. Estimated Spud Date: 10/20/06 Shane Gagliardi Ops Drilling Engineer Office: 564-5251 Mobile: 632-6789 E-11 B Sidetrack Page 6 Phase 1: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 65.4 hours $347,356 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto E-11 B. Well E-104 is 71.88' to the North and well E-12 is 110' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the E-11A well bore will be secured with the following barriers: o Tubing: the tubing tail plug, kill weight fluid, and a BPV (tested from below through tubing cut). o IA: Annulus valves and kill weight fluid. o OA: Annulus valve, kill weight fluid and cement from 2,594' to ~ 2,194'. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - Must complete another CMIT T x IA prior to removing the tree. The test must be to 3,500: psi for 30 min. Record test; test results must be initialized by the WSL. - During ND/NU BOPE operations, the E-11A well bore will be secured with the following barriers: • Tubing: the tubing'tail plug, kill weight fluid, and a BPV (tested from below through tubing cut). • IA: Annulus valves and kill weight fluid. • OA: Annulus valve, kill weight fluid end cement from 2,594' to ~ 2,194'. - E-Pad is not designated as an H2S site./Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading E-104 0 ppm E-08A 10 ppm E-12 5 ppm E-03A 10 ppm The maximum level recorded of H2S on the pad was 10 ppm in well E-38 on 04/22/2006. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 22.9 hours $152,988 Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. E-11 B Sidetrack Page 7 - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 13-5/8" 5000 psi FMC with 6" CIW tree. Verify with FMC/Cameron that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Records indicate 7" TC4S top and 7" BTC bottom threads with a crossover below to 4-~/2" IBT. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 4-~/2" HES HXO SVLN at 2012' MD, there are two bare control lines with 54 stainless steel control bands. - Tubing is collapsed C~ 9,958' md. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 23.7 hours $184,759 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Records indicate no cement behind the 9 5/a" casing at KOP. - Once milling is complete, make sure all BOP equipment is operable. Use jetting/washing tool to ensure that the BOP stack is cleaned thoroughly paying close attention to ram cavities. -. Weigh and record the amount of metal brought back during milling operations. - Ensure that the CIBP and whipstock are set to avoid mill a collar if possible. Phase 5: Drill 8-~h" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 191.8 hours $1,225,152 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" Issues and Potential Hazards - For this well, the HRZ/LCU/Kingak will require a mud weight of 10.4 ppg. Maintain mud weight at 10.7 ppg, minimally, to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 9.7 ppg pore pressure, a fracture gradient of 11.9 ppg at the 9 5/s°' casing window, and 10.4 ppg mud in the hole, the kick tolerance is 50 bbls. - The above kick tolerance is based on an FIT of 11.9 ppg EMW; if this is not reached contact the ODE. - Ensure that a Centurion circulating sub is in the string in the event that losses occur. - Due to the uncertainty of the Kuparuk formation pressure in this block, virgin pressure from the Midnight Sun development was used for calculating the maximum anticipated surface pressure. Being that this maximum pressure may exceed 3,000 psi, both sets of rams must be installed and tested for this hole section. E-11 B Sidetrack Page 8 - The south side of the Kuparuk drill polygon is a hard line to avoid the Prudhoe North Bounding Fault. - If the Kuparuk formation has not been truncated by the LCU, rotary sidewall cores will be taken; additional sidewall cores may be taken in the Ivishak formation as well. Phase 6: Run and Cement 7" Intermediate Casino and Tieback Planned Phase Time Planned Phase Cost 43.1 hours $464,125 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - The completion design is to run a 7", 26#, L-80, BTC-M solid drilling liner and cement from the intermediate TD of 11,049' to the liner top at 4,600'. - Sufficient 7" liner will be run to extend -150' back up into the 9 5/8" casing. - Swab and surge pressure should be minimized with controlled casing running speeds and fay breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the -: potential for differential sticking. Phase 7: Drill 6 '/8" Production Hole Interval Planned Phase Time Planned Phase Cost 37.2 hours $342,136 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - KICK TOLERANCE: In the worst-case scenario of 7.7 ppg pore pressure, a fracture gradient of 10.0 ppg at the 7" casing shoe, and 8.4 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 10.0 ppg EMW; if this is not reached contact the ODE. - Hard lines exist on both the East and west sides of the polygon. The west hard line is to avoid a fault and the east hard line is to preserve space for a westbound lateral in the Sag River Formation at a later date. - Ensure that a Centurion circulating sub is in the string in the event that losses occur. - TD will be called 200' after hitting water. Phase 8: Run DPC/Wireline Logs Planned Phase Time Planned Phase Cost 46 hours $248,227 E-11 B Sidetrack Page 9 • • Reference RP • "wireline Pressure Control" RP • "Drill Pipe Conveyed Logging" RP Issues and Potential Hazards - As many as 45 total rotary sidewall core may be taken in the Kuparuk and Ivishak Formations. - Ensure good correlation with the Gamma Ray and depth shift as necessary to compensate for the differences in wireline versus drill pipe depths. - Ensure that there is no free gas in the breaking out in the mud system prior to running the sonic tool; the gas bubbles will cause cycle skipping that complicates the interpretation. Phase 9: Run 4~/s" Production Liner Planned Phase Time Planned Phase Cost 27.4 hours $171,163 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4-~/z", 12.6#, L-80 IBT solid liner throughout the production interval .Sufficient 4-'/2" liner will be run to extend 150' back up into the 7" liner shoe. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be -320 psi over balanced to the Ivishak.... formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the 4-~/z" liner top packer is set prior to POH. - This well will be perforated post rig via wireline. Phase 12: Run 4-'h", 12.6#, 13Cr80, VamTop Completion Planned Phase Time Planned Phase Cost 20.4 hours $446,815 Reference RP • "Completion Design and Running" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 Asia at 100° F. - The completion design will be a 4-~/z", 12.6#, 13Cr80, VamTop production tubing string with 7" x 4- '/z" Baker S-3 packer with 3 GLM's. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 21.9 hours $70,876 E-11 B Sidetrack Page 10 • ~ Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of E-11 B. Well E-104 is 71.88' to the North and well E-12 is 110' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. E-11 B Sidetrack Page 11 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. The Ugnu is may be over pressured. A 9.5 ppg EMW was required in Midnight Sun-01. This over pressure is not expected in this block, but may be present. II. Hydrates and Shallow gas A. All hydrates should be covered well above the kick off point. There are significant coal stringers that may present some free gas. The problems most commonly cause by these coal stringers are hole stability and torque problems. III. Lost Circulation/Breathing A. Lost circulation is not expected, but is always possible. The most likely depth for losses to occur in this well is at the top of the Sag River formation. Most of the losses in the Ivishak Formation were associated with faults. B. Breathing is not expected in this well. IV. Kick Tolerance/Integrity Testing A. The 7" casing will be cemented with 15.8 ppg tail and 12.5 ppg lead cement to the liner top at 4,600' md. a. The Kick Tolerance for the 9 5/s" casing window is 51.0 bbls with 10.7 ppg mud, 11.9 ppg FIT, and a 9.7 ppg pore pressure. Integrity Testing -11.7 ppg EMW FIT B. The 4-'/2" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing is infinte with 8.4 ppg mud, 10.0 ppg FIT and a 7.7 ppg pore pressure. Integrity Testing -10.0 ppg EMW FIT V. Stuck Pipe A. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ or Kingak shales give problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. B. The original well had significant problems in the Kingak. Monitor cuttings closely and adjust mud weight accordingly to avoid destabilization. C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide A. E Pad is no designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Personal monitors must be worn at all times. Recent H2S data from the pad is as follows: Adjacent Producers at Surface: Adjacent Producers at TD: E-104 N/A E-08A 10 ppm E-12 5 ppm E-03A 10 ppm ~ VII. Faults A. E-11 B has been designed to avoid all seismically recognizable faults; therefore, fault related losses are not expected. CONSULT THE E PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION E-11 B Sidetrack Page 12 'y ~' err -Sun -Draft Co KWA Planning Company: BP Amoco Date: 3/4/2004 Time: 10:38`.1$ Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-11, True North Site: PB E Pad Vertical (TVD) Reference: 20:110 114!2000 08:28 60.0 Well: E-11 Section (VS) References Well (O.OON,O:OOE,22.72Azi) Wellpath: Plan E-11 B Survey Calculation Method: Minimum Curvature Db: Oracle Casing Points MD TVD Diameter Hole Size Name ft ft in in 11048.70 8984.00 7.000 8.500 7" 11639.06 9499.99 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction... ft ft deg deg 5307.64 4718.17 UG4A 0.00 0.00 5639.10 4942.00 UG3 0.00 0.00 6465.40 5492.00 UG1 0.00 0.00 7354.80 6084.00 WS2 0.00 0.00 7685.32 6304.00 WS1 0.00 0.00 7979.78 6500.00 CM3 0.00 0.00 9695.20 7795.00 THRZ 0.00 0.00 9875.09 7952.00 BHRZ/TKUP 0.00 0.00 9907.04 7980.00 LCU/TKNG/TJF 0.00 0.00 10344.73 8365.00 TJE 0.00 0.00 10562.55 8557.00 TJD 0.00 0.00 10710.17 8687.00 TJC 0.00 0.00 10855.80 8815.00 TJB 0.00 0.00 11048.70 8984.00 TSag 0.00 0.00 11113.91 9041.00 SHU 0.00 0.00 11164.26 9085.00 TSAD/TZ4 0.00 0.00 11175.70 9095.00 MHO/HOT 0.00 0.00 11232.90 9145.00 POWC 0.00 0.00 11250.07 9160.00 TCGL/TZ3 0.00 0.00 11299.26 9203.00 BCGL/TZ2C 0.00 0.00 11521.23 9397.00 TZ16 0.00 0.00 11604.75 9470.00 BSAD 0.00 0.00 Plan: E-11 B wp20 Date Composed: 3/4/2004 Optimize for Wireline Log Access (lowest Inc.) Version: 28 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: bggm2003 Site: PB E Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973160.88 ft Latitude: 70 19 59.134 N From: Map Easting: 662538.97 ft Longitude: 148 40 53.054 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: E-11 Slot Name: 11 E-11 Well Position: +N/-S 3398.09 ft Northing: 5976601.00 ft Latitude: 70 20 32.551 N +E/-W 1987.27 ft Easting : 664452.00 ft Longitude: 148 39 54.999 W Position Uncertainty: 0.00 ft Wellpath: Plan E-11 B Drilled From: Tie-on Depth: 4750.00 ft Current Datum: 20:110 1/4/2000 08:28 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/18/2001 Declination: 26.41 deg Field Strength: 57519 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 22.72 -~' err -Sun -Draft p y Copy .,~~.~,~ KWA Planning ~ ~ Company: BP Amoco Date: 3/4/2004 Tine: 10.38:18 Page:. 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-11, True. North ' Site: PB E Pad Vertical (TYD) Reference: 2 0:1101/4/2000 08:28 60.0 WeIL E- 11 Section (VS) Reference: Well (O.OON,O :OOE,22.72Azi) Wellpath: Plan E-11 B Survey Calculation Method: Minimum Curvature Db; Orade Targets Map Map <-- Latitude ---> <-- Longitude.---> Name Description TV D +N/-S +E!-W Northing Easting Deg Min Sec Deg Mi n Sec Dip. Dir. ft ft ft ft ft E-11 B Al 7860. 00 4081 .30 2369.26 5980733.00 666731.00 70 21 12 .687 N 148 38 45.748 W -Circle (Radius: 200) -Plan hit target E-11 B B2 8984. 00 4660 .60 2205.77 5981308.54 666554.85 70 21 18 .385 N 148 38 50.521 W -Polygon 1 8984. 00 5081 .09 2028.09 5981725.00 666368.00 70 21 22 .520 N 148 38 55.712 W -Polygon 2 8984. 00 4673 .74 2357.65 5981325.00 666706.40 70 21 18 .513 N 148 38 46.082 W -Polygon 3 8984. 00 4543 .55 2136.43 5981190.00 666488.10 70 21 17 .233 N 148 38 52.549 W -Polygon 4 8984. 00 5001 .02 1847.97 5981641.00 666189.70 70 21 21 .733 N 148 39 0.978 W -Plan hit target Plan Section Informati on MD Incl Azim TVD. +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 4750.00 36.48 59.90 4292.14 809.39 1252.05 0.00 0 .00 0.00 0.00 4770.00 36.96 55.97 4308.17 815.74 1262.18 12.00 2 .41 -19.66 -80.00 5453.81 48.27 18.54 4818.67 1179.66 1518.57 4.00 1 .65 -5.47 -80.82 8289.38 48.27 18.54 6706.08 3186.02 2191.38 0.00 0 .00 0.00 0.00 9769.93 29.12 0.00 7860.00 4081.30 2369.26 1.50 -1 .29 -1.25 -155.84 E-116 Al 11048.70 29.07 328.45 8984.00 4660.60 2205.77 1.19 0 .00 -2.47 -104.05 E-11 B B2 11067.00 29.07 328.00 9000.00 4668.17 2201.08 1.20 0 .00 -2.47 -90.00 11639.07 29.07 328.00 9500.00 4903.89 2053.80 0.00 0 .00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD MapN MapE VS AHVS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 4750.00 36.48 59.90 4292.14 4232.14 5977437.60 665685.90 1230.22 0.00 0.00 0.00 MWD 4770.00 36.96 55.97 4308.17 4248.17 5977444.17 665695.89 1239.99 11.96 12.00 280.00 MWD 4800.00 37.17 54.01 4332.11 4272.11 5977454.87 665710.47 1255.28 30.04 4.00 279.18 MWD 4900.00 38.09 47.63 4411.33 4351.33 5977494.45 665756.86 1309.10 91.10 4.00 280.74 MWD 5000.00 39.34 41.55 4489.39 4429.39 5977539.93 665799.69 1367.10 153.64 4.00 285.79 MWD 5100.00 40.89 35.82 4565.89 4505.89 5977591.07 665838.77 1429.00 218.07 4.00 290.54 MWD 5200.00 42.70 30.47 4640.46 4580.46 5977647.63 665873.90 1494.51 284.71 4.00 294.92 MWD 5300.00 44.74 25.49 4712.75 4652.75 5977709.34 665904.91 1563.29 353.83 4.00 298.91 MWD 5307.64 44.91 25.13 4718.17 4658.17 5977714.26 665907.11 1568.67 359.21 4.00 302.51 UG4A 5400.00 46.99 20.88 4782.40 4722.40 5977775.90 665931.65 1635.01 425.59 4.00 302.77 MWD 5453.81 48.27 18.54 4818.67 4758.67 5977813.61 665944.22 1674.71 465.34 4.00 305.73 MWD 5500.00 48.27 18.54 4849.41 4789.41 5977846.52 665954.46 1709.09 499.81 0.00 0.00 MWD 5600.00 48.27 18.54 .4915.97 4855.97 5977917.77 665976.63 1783.52 574.44 0.00 0.00 MWD 5639.10 48.27 18.54 4942.00 4882.00 5977945.64 665985.30 1812.62 603.62 0.00 0.00 UG3 5700.00 48.27 18.54 4982.54 4922.54 5977989.03 665998.80 1857.95 649.07 0.00 0.00 MWD 5800.00 48.27 18.54 5049.10 4989.10 5978060.28 666020.96 1932.38 723.70 0.00 0.00 MWD 5900.00 48.27 18.54 5115.66 5055.66 5978131.54 666043.13 2006.81 798.33 0.00 0.00 MWD 6000.00 48.27 18.54 5182.22 5122.22 5978202.79 666065.30 2081.24 872.96 0.00 0.00 MWD 6100.00 48.27 18.54 5248.78 5188.78 5978274.05 666087.47 2155.67 947.59 0.00 0.00 MWD 6200.00 48.27 18.54 5315.34 5255.34 5978345.31 666109.64 2230.10 1022.22 0.00 0.00 MWD 6300.00 48.27 18.54 5381.91 5321.91 5978416.56 666131.80 2304.53 1096.85 0.00 0.00 MWD 6400.00 48.27 18.54 5448.47 5388.47 5978487.82 666153.97 2378.96 1171.48 0.00 0.00 MWD 6465.40 48.27 18.54 5492.00 5432.00 5978534.42 666168.47 2427.64 1220.29 0.00 0.00 UG1 6500.00 48.27 18.54 5515.03 5455.03 5978559.07 666176.14 2453.39 1246.11 0.00 0.00 MWD 6600.00 48.27 18.54 5581.59 5521.59 5978630.33 666198.31 2527.82 1320.74 0.00 0.00 MWD 6700.00 48.27 18.54 5648.15 5588.15 5978701.58 666220.48 2602.25 1395.37 0.00 0.00 MWD 6800.00 48.27 18.54 5714.72 5654.72 5978772.84 666242.64 2676.68 1469.99 0.00 0.00 MWD 6900.00 48.27 18.54 5781.28 5721.28 5978844.09 666264.81 2751.11 1544.62 0.00 0.00 MWD 7000.00 48.27 18.54 5847.84 5787.84 5978915.35 666286.98 2825.54 1619.25 0.00 0.00 MWD 7100.00 48.27 18.54 5914.40 5854.40 5978986.60 666309.15 2899.97 1693.88 0.00 0.00 MWD ~` ~ err - un -Draft p y 5 Copy .~~.~.~ KWA Planning ~~ .Company: BP Amoco Date: 3/4/2004 Time: 10`.38:18 Pager 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-11, True North - Site: PB E Pad Vertical (TVD) Reference: 20:110 1/4/2000 08:2 8 60:0 Well: E-1 1 Section (VS) Reference: Well (O.OON, O.OOE,22;72Azi) Wellpath: Pla n E-11 B Survey Calculafion Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS AHVS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 7200.00 48.27 18.54 5980.96 5920.96 5979057.86 666331.32 2974.40 1768.51 0.00 0.00 M W D 7300.00 48.27 18.54 6047.52 5987.52 5979129.11 666353.49 3048.83 1843.14 0.00 0.00 MWD 7354.80 48.27 18.54 6084.00 6024.00 5979168.16 666365.63 3089.62 1884.04 0.00 0.00 WS2 7400.00 48.27 18.54 6114.09 6054.09 5979200.37 666375.65 3123.26 1917.77 0.00 0.00 MWD 7500.00 48.27 18.54 6180.65 6120.65 5979271.63 666397.82 3197.69 1992.40 0.00 0.00 MWD 7600.00 48.27 18.54 6247.21 6187.21 5979342.88 666419.99 3272.12 2067.03 0.00 0.00 MWD 7685.32 48.27 18.54 6304.00 6244.00 5979403.68 666438.90 3335.62 2130.70 0.00 0.00 WS1 7700.00 48.27 18.54 6313.77 6253.77 5979414.14 666442.16 3346.55 2141.66 0.00 0.00 MWD 7800.00 48.27 18.54 6380.33 6320.33 5979485.39 666464.33 3420.98 2216.29 0.00 0.00 MWD 7900.00 48.27 18.54 6446.90 6386.90 5979556.65 666486.49 3495.41 2290.92 0.00 0.00 MWD 7979.78 48.27 18.54 6500.00 6440.00 5979613.50 666504.18 3554.79 2350.46 0.00 0.00 CM3 8000.00 48.27 18.54 6513.46 6453.46 5979627.90 666508.66 3569.84 2365.55 0.00 0.00 MWD 8100.00 48.27 18.54 6580.02 6520.02 5979699.16 666530.83 3644.27 2440.17 0.00 0.00 MWD 8200.00 48.27 18.54 6646.58 6586.58 5979770.41 666553.00 3718.70 2514.80 0.00 0.00 MWD 8289.38 48.27 18.54 6706.08 6646.08 5979834.10 666572.81 3785.23 2581.51 0.00 0.00 MWD 8300.00 48.12 18.45 6713.15 6653.15 5979841.66 666575.16 3793.12 2589.42 1.50 204.16 MWD 8400.00 46.76 17.61 6780.78 6720.78 5979912.18 666596.42 3866.53 2663.08 1.50 204.22 MWD 8500.00 45.40 16.72 6850.15 6790.15 5979981.44 666616.16 3938.22 2735.11 1.50 204.79 MWD 8600.00 44.05 15.80 6921.19 6861.19 5980049.41 666634.38 4008.15 2805.48 1.50 205.41 MWD 8700.00 42.71 14.83 6993.88 6933.88 5980116.02 666651.07 4076.25 2874.16 1.50 206.06 MWD 8800.00 41.37 13.80 7068.14 7008.14 5980181.25 666666.20 4142.49 2941.13 1.50 206.77 MWD 8900.00 40.05 12.73 7143.95 7083.95 5980245.03 666679.78 4206.83 3006.35 1.50 207.53 MWD 9000.00 38.73 11.59 7221.23 7161.23 5980307.34 666691.79 4269.21 3069.80 1.50 208.35 MWD 9100.00 37.43 10.38 7299.94 7239.94 5980368.12 666702.22 4329.59 3131.48 1.50 209.23 MWD 9200.00 36.14 9.10 7380.03 7320.03 5980427.33 666711.06 4387.94 3191.36 1.50 210.17 MWD 9300.00 34.86 7.75 7461.44 7401.44 5980484.94 666718.32 4444.21 3249.43 1.50 211.20 MWD 9400.00 33.60 6.30 7544.12 7484.12 5980540.90 666723.98 4498.37 3305.69 1.50 212.31 MWD 9500.00 32.36 4.75 7628.00 7568.00 5980595.18 666728.04 4550.37 3360.13 1.50 213.50 MWD 9600.00 31.14 3.09 7713.03 7653.03 5980647.74 666730.50 4600.19 3412.75 1.50 214.80 MWD 9695.20 30.00 1.41 7795.00 7735.00 5980696.15 666731.35 4645.55 3461.17 1.50 216.21 THRZ 9700.00 29.94 1.32 7799.16 7739.16 5980698.54 666731.36 4647.78 3463.57 1.50. 217.66 MWD 9769.93 29.12 0.00 7860.00 7800.00 5980733.00 666731.00 4679.72 3498.03 1.50 217.74 E-11 B Al 9800.00 29.04 359.29 7886.28 7826.28 5980747.61 666730.59 4693.17 3512.65 1.19 255.95 MWD 9875.09 28.84 357.49 7952.00 7892.00 5980783.89 666728.77 4726.27 3548.98 1.19 256.58 BHRZ/TKU 9900.00 28.78 356.89 7973.83 7913.83 5980795.87 666727.92 4737.10 3560.99 1.19 258.15 MWD 9907.04 28.76 356.71 7980.00 7920.00 5980799.25 666727.66 4740.15 3564.38 1.19 258.68 LCU/TKNG 10000.00 28.57 354.45 8061.56 8001.56 5980843.61 666723.25 4779.83 3608.97 1.19 258.83 MWD 10100.00 28.40 351.98 8149.46 8089.46 5980890.82 666716.58 4821.33 3656.66 1.19 260.82 MWD 10200.00 28.28 349.49 8237.48 8177.48 5980937.48 666707.92 4861.58 3704.13 1.19 262.99 MWD 10300.00 28.20 346.99 8325.58 8265.58 5980983.57 666697.27 4900.58 3751.45 1.19 265.18 MWD 10344.73 28.18 345.86 8365.00 8305.00 5981004.00 666691.86 4917.61 3772.58 1.19 267.38 TJE 10400.00 28.17 344.47 8413.72 8353.72 5981029.07 666684.63 4938.30 3798.68 1.19 268.37 MWD 10500.00 28.19 341.96 8501.87 8441.87 5981073.96 666670.01 4974.73 3845.90 1.19 269.60 MWD 10562.55 28.22 340.39 8557.00 8497.00 5981101.72 666659.86 4996.85 3875.46 1.19 271.82 TJD 10600.00 28.25 339.45 8589.99 8529.99 5981118.22 666653.41 5009.84 3893.18 1.19 273.20 MWD 10700.00 28.35 336.95 8678.05 8618.05 5981161.83 666634.85 5043.63 3940.59 1.19 274.03 MWD 10710.17 28.37 336.70 8687.00 8627.00 5981166.23 666632.85 5047.00 3945.42 1.19 276.23 TJC 10800.00 28.50 334.48 8765.99 8705.99 5981204.77 666614.33 5076.09 3988.19 1.19 276.45 MWD 10855.80 28.61 333.11 8815.00 8755.00 5981228.43 666602.03 5093.61 4014.86 1.19 278.40 TJB 10900.00 28.70 332.03 8853.79 8793.79 5981247.02 666591.86 5107.19 4036.06 1.19 279.61 MWD 11000.00 28.94 329.62 8941.41 8881.41 5981288.57 666567.44 5136.92 4084.26 1.19 280.55 MWD 11048.70 29.07 328.45 8984.00 8924.00 5981308.54 666554.85 5150.90 4107.87 1.19 282.67 E-11 B 62 11067.00 29.07 328.00 9000.00 8940.00 5981316.00 666550.00 5156.07 4116.77 1.20 269.80 MWD y ~' err -Sun -Draft Co y py .,.,~..~~.w KWA Planning ~'P Company: BP Amoco Date: 3/4/2004. Time: 10:38:18 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-11, True North Site: PB E Pad Vertical (TVD) Reference:. 20:110 1/4/2000-08:28 60.0 Well: E-1 1 Section (VS) Reference: Welt (O.OON, O:OOE,22.72Azi) Wellpath: Plan E-11 B Survey Calculation Method: Minimum Cu rvature Db: O~aGe Survey MD Incl Azim TVD Sys TVD MapN MapE VS AHVS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 11100.00 29.07 328.00 9028.84 8968.84 5981329.41 666541.21 5165.33 4132.80 0.00 0.00 MWD 11113.91 29.07 328.00 9041.00 8981.00 5981335.06 666537.51 5169.23 4139.56 0.00 0.00 SHU 11164.26 29.07 328.00 9085.00 9025.00 5981355.51 666524.09 5183.36 4164.02 0.00 0.00 TSAD/TZ4 11175.70 29.07 328.00 9095.00 9035.00 5981360.16 666521.04 5186.57 4169.58 0.00 0.00 MHO/HOT 11200.00 29.07 328.00 9116.24 9056.24 5981370.03 666514.57 5193.39 4181.39 0.00 0.00 MWD 11232.90 29.07 328.00 9145.00 9085.00 5981383.40 666505.80 5202.62 4197.38 0.00 0.00 POWC 11250.07 29.07 328.00 9160.00 9100.00 5981390.38 666501.23 5207.44 4205.72 0.00 0.00 TCGL/TZ3 11299.26 29.07 328.00 9203.00 9143.00 5981410.36 666488.12 5221.24 4229.62 0.00 0.00 BCGL/TZ2 11300.00 29.07 328.00 9203.64 9143.64 5981410.66 666487.93 5221.45 4229.98 0.00 0.00 MWD 11400.00 29.07 328.00 9291.05 9231.05 5981451.29 666461.29 5249.51 4278.57 0.00 0.00 MWD 11500.00 29.07 328.00 9378.45 9318.45 5981491.92 666434.64 5277.57 4327.15 0.00 0.00 MWD 11521.23 29.07 328.00 9397.00 9337.00 5981500.54 666428.99 5283.53 4337.47 0.00 0.00 TZ1 B 11600.00 29.07 328.00 9465.85 9405.85 5981532.55 666408.00 5305.64 4375.74 0.00 0.00 MWD 11604.75 29.07 328.00 9470.00 9410.00 5981534.48 666406.74 5306.97 4378.05 0.00 0.00 BSAD 11639.06 29.07 328.00 9499.99 9439.99 5981548.42 666397.59 5316.60 4394.72 0.00 0.00 41/2" 11639.07 29.07 328.00 9500.00 9440.00 5981548.42 666397.59 5316.60 4394.73 0.00 0.00 MWD CDh1P.WY UI~I,\ILS %I}IKI N('1:INk()RAf \III1N SUR\I'. Y-I'R<%.Rnhl Plan: k: llH xpZn lk.-I I. PIanL I1H) ~w~~ T "..>< ~ ' HI',\I ~ ~ t'f' ~~• ('~,.~rJ IN 1 R t N 11 l' m I~. I1. 1 N h . IApIh k n U.1 h I 1unry~l I' luul Crr.IleJ H): Ken \Ilen D le: ~ J ' IIIH ('v l.uW Af I W- I u~ ('llnalun~ - ' \rn-I 1\DIRt 1-IIIIIJ N Y. Sv I\'S R r Sh - II In N 1.1 _xl J: ~I JNI IIhN4 U~ Plaunvvl. l' I IH xp'_U V'~% hltiD l'heikrd: l D _ 11 Sn 1 ~r 1v .Ivn: 1\( S.an Al.nxrJ-. I re. ('~liivlrr Nunh Lrrur Surf .:r. r:lly,u.al ('avinE Alr~.un.l l%plh %vrvr•rt.e-. _'n:IIIIIJ INNI n,~.~N M ('alrnhln.n AlrlhuJ: AWulnlontlu,'alurt• IINI rlirxed : a e: Datr: \c,nl~w hlrml~J: %Illvx lf: d CASING DETAILS PURMATION TOP DETAILS `\cLL OCI,\Ils Nunlc N-S L'-l\ Nuniin~ I~:i.tn l- LIInNJr Laillgllwlr SIu1 No. TVD MD Namc Sizc No. TVDPuIh MDPath Formation li-n Uvx)w Ivxn~ s nre~ul.nu hwar_1 N1 ~o>zu?zssl N ux°1rsJ ~wvH' n " I 8984.00 11048.70 7 ZU00 1 4718.17 53U7b4 UG4A ' ? 9499.99 11639.06 4 U2" 4.500 2 4942.00 5639.10 UG3 In%rhI Dl rlnas - 3 5492.00 6465.40 UGI Nunes TVD N--S F'-k Nrtrlhing Iv.:nnp Slulx 4 60}{4.1)0 7354.80 WS2 li-I IIi AI 7RNLINI AWI?II ?1441(. s4M1?.i3.1%1 MM,7111NI I'uhn 5 6304.00 7685.3? WSI li-IIn HZ %YW INI J(NLW ]~IIS" 54%I SnS.iJ M,455J.85 1'°lyg°n G GSUUAO 7979 78 CM3 4001 Shur Dvl?,IW':475D'MD.4292.14T\'D . 7 7795.011 9695?(I THRZ SEC°PIUNDET;llLS V Suet Dir 4rIW':4770'MD. 4308.ITTVD 8 795?OU 9875.09 BHRZ:TKUP ~ 9 7980.00 9907A4 LCU/TKNGlI'JE Sec MD Inc A~i TVD +Nr-S +Er-W DLcg TFace VSce Target 10 8365.00 10344.73 TJE Il 8557.00 10562.55 TJD 1 4750.00 36.48 59.90 4292.14 809.39 1252.05 O.UU 0.00 1230.22 5000 12 8687.110 10710.17 TJC 2 4770.110 36.96 55.97 4308.17 811.74 1262.18 12.00 -80.00 1239.99 ' ' 13 8815.00 10855.80 T1B 3 5453.81 48.27 18.54 4818.67 1179 66 1518 57 4 00 -8(1 82 1674 71 i, ' End Uir :5453.81 MD.4818.6TTVD UG4A o~ 14 8984.00 11048.70 TSaS 4 828938 48.27 18.54 67U6A8 . 3186.02 . 2191.38 . . O.UO (L00 . 3785.23 IS 9041.00 11113.91 SHU S 9769.93 ?9.12 OAO 7860A0 4081.30 2369?6 1.50 -155.84 4679.72 E-IIBAI - 16 9085.00 11164?( TSAD'TZ4 G 11048.70 29.07 3?8.45 8984.011 4660.60 2205.77 1.19 -104.05 5150.90 E-I IB 62 5(1(11) - 17 90yi.UU 11175.70 MHO,HOT 7 IIU67A0 ?9.07 328.00 9000.00 4668.17 2201.08 I?0 -9UA(1 5156.07 _ __ l8 9145.00 II?32.90 POWC 8 11639A7 29.07 328.00 9500.00 4903.89 2053.80 0.00 0.00 5316.60 19 9160.00 11250.07 TCGLTZ3 20 9203.00 11299.26 BCGLiTZ2C ZI 939ZU0 11521?3 TZIB 22 9470.00 11604.75 BSAD DRAFT COPY ONLY 'J a 0 2 F I OUO Stan Dir L5. 100' 8?493%' VI D- 67ot, 08'TVD O I~ Stan Dir 1 .19. IUO' :976441' MD. 78M)'TV'D L-I I lF.-I LU JB 7„ $lart Dir L?; IW': I IU48.T MD. 8984'TVD Sa' End Dir : I IWT MD.9W0' TVD I HT 4 PDW'(' ), B L T z3 ~9 11 I VC ~2C Tura( Dcprh : I IG39AT MD, 95D0' TVU ~ ZIB ~ ~ SAU L'Wd H+L~Bn 4000 SUUU 6WU 7000 Vertical Section at 22.72° [IW01Uin] <m ~ ~ YZ N'J N Y F ti~w ~ E' rya-r^, r,ono ~ ' ~ E ~"'-vi v~~'~~pwO:~m np<=3:7Jm~ :7:7:7 ~^' y - _ _ _ N ] r anr~r`a^~c ^a^v'~° h.c '.~ ~ ri 2U-+-.-~ ~nS~n OJUNN 7'J233:~F0~._7FFF-F-F-,nF~~F9FO] ~~ ° ° ~ , _="~nav, v, v^i a F t ~ro^oNxoa-tn~nro o-,oooh.cnv, oNNn n ~ xn n - - Z ,y ~- rx n NOOn n- a N - a rav,o~navi ~nr-rN~vixnv~n rioa--t _ . ~ p o ~,c v,xnano•t .~-one-.~n M~naN~ u oo NOev,oo oo zoxooc F ~ .:~n~a.ox an~nnx o--- ,n Nan .o v, ~n .onnnaaaooco---------_ ~ ~i @ ~ ~zp`~~a `_ ~ _____________ _ ~ -+ ^; ~ ~' u ^o oo a := p `i a p ao Nri-i-t ~,nN O~nrrv,v-v, v, v,c.~no -caxooa~n x.o ~nx-x~xac,ooah '' - ~ ' p ~ ~ -NO oooo~ ) na~on~nnaan~n~xaooo--Nrn-r c „ = ' p . orvKO___o ` ~r a,na~o ,ohnnxxxx xaa as aaaa 9 u j {{ Z -N~+', e}vi .Oh x a-__~O V1~~~?NN N~ ~ s _ ~ nx~nx^ in.^.,x ' L' c ' {~ .5 ~~ ~ aV~-rf~ ~_- - _ Z ~ v [L p _ . Y 5 ~~ ~ Z zNr ^_^ r+'~ L D ^ ~ ~ ri,- ~^ S . r - ~ _nC?~K ~ ,. Z v. ~ ~ p ?n r_ooo^ ~ - - - _ zn»ao~n = _ - _ ~~ r v,onxaa a _ ? ^ vvo~no- Z ~ n n N n h n .: ~oxxaaaa i _ nr~.t-t ri r, r, r, =' 3 _ y - - p o^-moon J>>O rnanco ~ `r~x? M t - - ~ T`: nn cN~oo~c ~, - Cn - ~ = L W ~ < \ '>' ~l o h '/1 h R ..7 E F F ~~ zg x x p a Z ~v ~ y - '= Z ~3 i e o =~.x ?a h o.o nq _a b ~'_ Y U p Boa v ono _-_-_ ~ p V-._-._ 3 ~~~. ~~~ o?, > F ... ~ f<~==~ o?, z z e p ea a p p x _ zz s s ~ F a o a > F- O _ _ .. F :. ~ _ _ 2 "~" z _N a z Fi a ~ V e ~ - o ~ ? ~ a ~ - a 2C ~~~ `-~~. -23.E.± ~ __ < ~ ~a'j'~ a ~=Lu ~ _ _ ie;~t ~~h...E y i L~ L.I 'J 3 a~ a _I fJJ z 0 a 0 v w D O z n r ~ .+^.. ~ ~ aao N = w x x 3 ~._.~ I p ° I r, e ~ [w/UOOL1 ~+)4u~W(-)41noS TREE 6" CMJ WELLHEAD= FMC ACTUATOR = KB. ELEV = OTIS 68.7' BF. ELEV = 30.28' KOP = 2008' Max Angle = Datum MD = 99 @ 11432' N/A Datum TV D = 8800' SS ~ E-11A 13-318" CSG, 68#, L-80, ID = 12.415" i-j 2729' Minimum ID = 3.725" @ 10798' 4-1/2" HES XN NIPPLE TOP OF 7" LNR I-i 5408' PERFORATION SUMMARY REF LOG: SWS CBLNDL ON 09/05!81 ANGLE AT TOP PERF: 84 @ 11812' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE SLTD 11812 - 12550 10!24!97 9-518" CSG, 47#, L-80, ID = 8.681" ~ 10167' PBTD 10776' 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 10817' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 4190 6807 3792 5867 37 37 MMG KBG2 RK BM-I $40$' I~ 9-5(8 X 7 BKR ZXP LNR PKR MILLOUT WINDOW: 8782' - 8796' XXN Plug 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" '-I 10975' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11812' 4-112" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" I 12550' I DATE REV BY COMMENTS DATE REV BY COMMENTS _? ORIGINAL COMPLETION 02/04!04 CMO/TLP PERF SUMMARY CORRECTION 10/24/97 JLM SIDETRACKCOMPLETION 01/30/01 SIS-QAA CONVERTED TO CANVAS 02/27/01 SIS-LG FINAL 01/10102 RN(fP CORRECTIONS 07/11/03 CMO/TLP KB ELEVATION CORRECTION PRUDHOE BAY UNff WELL: E-11A PERMIT No: 1971720 API No: 50-029-20475-01 SEC 6, T11 N, R14E, 500' WEL & 463' SNL BP Exploration (Alaska) S ES: HORIZONTAL WELL - 70° @ 9593' AND 90° @ 11307' L I 4-1/2" HES SSSV LAND. NIP, ID = 3.813" 9958' SLM -~4-1/2" Collapsed Tubing 10743' 4-112'° HES X NIP, ID = 3.813 I .~ / ~` 10754' 7" X 4-112" BR KER SA B PKR, ID = 4 0" 10778' 4-1/2" HES X NIP, ID = 3.813" 10798' 4-112" HES XN NIP, ID = 3.725" 10806' 4-1/2" LNR TIEBACK AND PKR 10810' 4-112" WLEG ELMD TT NOT LOGGED 11812' TOP OF 4-112" SLTD LNR E ~1 B Pre-Rigs ST MD TV D DEV TYPE V LV LATCH PORT DATE 2 1 4190 6807 3792 5867 37 37 MMG KBG2 RK BM-I TREE = 6" CNV WELLHEAD= FMC ACTUATOR= KB. ELEV - BF. ELEV = __ KOP = OTIS 68.T ............30.28' 2008' Max Angle = 99 @ 11432' Datum MD = N1A Datum TV D = 8800' SS PERFORATION SUMMARY REF LOG: SWS CBWDL ON 09/05/81 ANGLE AT TOPPERF: 84 @ 11812' Note: Refer to Production DB for historical erf data SIZE SPF INTERVAL O n/S z DATE SLTD 11812 - 12550 10!24!97 ELMD TT NOT LOGGED .~ . ~ '' ------ DATE REV BY COMMENTS DATE REV BY COMMENTS _? ORIGINAL COMPLETION 02/04!04 CMO/TLP PERF SUMMARY CORRECTION 10/24!97 JLM SIDETRACK COM PLETION 01130!01 SIS-QAA CONVERTED TO CANVAS 02/27101 SIS-LG FINAL 01/10102 RN1TP CORRECTIONS 07/11/03 CMOlTLP KB ELEVATION CORRECTION PRUDHOE BAY UNIT' WELL: E 11A PERMIT No: 1971720 API No: 50-029-20475-01 SEC 6, T11 N, R14E, 500' WEL & 463' SNL BP Exploration (Alaska) TREE = 6" CNV WELLHEAD= FMC ACTUATOR = OTIS KB. ELEV = 68.T BF. ELEV = 30.28' KOP = 2008' Max Angle = 99 @ 11432' Datum MD = N/A Datum TV D = 8800' SS 2729' I-I 13-3/8" CSG, 68#, L-80, ID = 12.415" 540$' ~-~ 9-5/8 X 7 BKR ZXP LNR PKR ~ ~ Hole in 9 5/8" ~ CSG -5630` Planned Bridge Plug 100` Cement "9890 P&A Plug Planned Tubing Cut -9900` \ Collapsed Tubing 9958 I Window: R7R~` _ R7QR 11 0743' 114-1/2" HES X NIP, ID = 3.813" 10754' 7" X 4-112" BAKER SAB PKR, ID = 4.0" 10778' 4-1/2" HES X NIP, ID = 3.813" 10798' 4-1/2" HES XN NIP, ID = 3.725" 10$06' 4-1/2" LNR TIEBACK AND PKR ~ 10810' 4-1(2" WLEG ELMD TT NOT LOGGED 10975' 7"LNR, 26#, L-80, .0383 bpf, ID = 6.276 XXN Plug ~ \ 11812' TOP OF 4-1/2" SLTD LNR 10167' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10776' PBTD 10817' 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" ~ ` ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11812' ` , 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 12550' DATE REV BY COMMENTS DATE REV BY COMMENTS _? ORIGINAL COMPLETION 02/04!04 CMO/TLP PERF SUMMARY CORRECTION 10!24/97 JLM SIDETRACKCOMPLETION 01/30/01 SIS-QAA CONVERTEDTOCANVAS 02!27101 SIS-LG FINAL 01/10!02 RN/TP CORRECTIONS 07/11!03 CMO/TLP KB ELEVATION CORRECTION PRUDHOE BAY UNIT WELL: E-11A PERMfr No: 1971720 API No: 50-029-20475-01 SEC 6, T11 N, R14E, 500' WEL & 463' SNL BP Exploration (Alaska) E-11 B~roposed Compl -2200' 4-1/2" Landing X Nipple, ID = 3.813" 2729' 13-3/8" CSG, 68#, L-80, ID = 12.415" 9-5/8 x 7 BKR Gas Lift Mandrels ZXP LNR PKR (L-80) 4600' 1.3800' TVD 2. 6200' TVD 3. 8000' TVD m 4-1/2" 12.6#, L-80 Tubing, ID = 3.953" by of whipstock 4-1/2 X Nip., ID=3.813" 4750' 7" x 4-1/2" S3 BKR PKR 4-1/2 X Nip., ID=3.813" 4-1/2" XN Nip., ID=3.725" 9-5/8 x 7 BKR ZXP LNR PKR 4-1/2" LNR TIEBACK, HMC HGR 5408` _ AND ZXP PKR -10899' ~~ l \. ~ - Hole in 9 5!8" CSG -5630` . ~! 100` Cement P&A Plug ,~ ~., ' 7" LNR, 26#, L-80, ID = 6.276" 11049' 4-1/2" LNR, 12.6#,L-80 ID = 3.953" 11639` 10975' 7"LNR, 26#, L-80, .0383 bpf, ID = 6.276 Window: 8782` - 8796 / t 11812'-TOP OF 4-1 /2" SLTD LNR XXN Plug 10167' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10776' PBTD 10817' 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" ~ ` ~, 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11812' ` , 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ~ = 3.953" 12550' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: E-11B PERMIT No: API No: 50-029-20475-02 SEC 6, T11 N, R14E, 500' WEL & 463' SNL BP Exploration (Alaska) • • Terri Hubbie' ss-silzsr 306 BP Exploration AK Inc . ~" " - Mastercard Check Pa Box 196612 MB 7-5= Anchorage, AK 99519 T bar ~~- (J~ ~ •~ ~~ - e PAY TO THE _ _ ORDER OF ~ ~~. " : " First National a k Alas a Anchorage, AK 9 9501 QQ MEMO~IJ ~L25200060~99 4622715561!• 0306 • • TRANSMITTAL LETTER CHECKLIST WELL NAi~TE ~lJ~ ~ /~~ PTD# .Z, - ~~,L ~ y~~Development Service Exploratory Stratigraphic Test \ion-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter Cf-IECK I ADD-ONS WHAT i (OPTIONS) APPLIES ~ TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing i ~ (If last two digits API numb ~ well in ~ ' Permit No. , API No. 50- - er between 60-69) are i ;Production should continue to be reported as a function of the i' original API number stated above. ~' PILOT HOLE Irt accordance with 20 AAC 25.005(f), all records, data and logs !acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number ~ (50- - -_) from records, data and logs I acquired for well ~ SPACING ~ The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION ~ 2~.05~. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j exception. assumes the ~ I liability of any protest to the spacing exception that may occur. DRY DITCH j AI( dry ditch sample sets submitted to the Commission must be in SAMPLE ~ no greater than 30' sample intervals from below the permafrost or I ~ from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed Well for (name of well) until after (Com any Name) has designed and I implemented a water well testing program to provide baseline data ~ on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ~ Rev: 1!25106 C^jody\transmittal checklist -- WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150_. _ Well Name: PRUDHOE BAY UNIT E-11 B Program. DEV Well bore seg j PTD#:2061430 Company BP EXPLORATION_ (ALASKA~INC __ _- Initial Class/Type ___DEV! 1-O1L GeoArea 890 _ __ __ _ Unit 11650_ _ ___ On/Off Shore On _______ Annular Disposal i j Administration '1 Permit fee attached _ _ Yes - '2 Lease number appropriate - - Yes - - - 3 Unique well-name and number Yes - - i4 Well located in a-defined pool Yes 5 Well located proper distance from drilling unitboundary - - Yes 6 Well located proper distance from other wells Yes - - - - 7 Sufficient acreage available in drilling unit. Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party. Yes _ 10 Operator has appropriate bond in. farce _ _ Yes X11 Permit can be issued without conservation order Yes - 12 Permit can be issued without administrative approval Yes - . _ _ - - _ _ Appr Date 1 13 Can permit be approved before 15-daywait- - Yes - RPC 1015!2006 h4 Well located within area and strata authorized by-Infection Order# (put-10# in comments)-(For- NA - - - - 15 All wells Within 114-mile area of review identified (For service well only).. NA - - , 16 Pre-produced infector; duration of pn-production less_than 3 months. (For_service well only) - NA- - ~ 17 Nonconven, gas conforms to AS31.05,030Q.1,A),Q,2.A-D) - - - N_A- - - - - - 18 Conductor string provided --- _ - NA . - - - - __ - - 19 roteclsoll know U$DWs S rf i c - NA - - - - u ngp n a ecas Engineering 20 CMT vol-adequate to circulate on conductor & surf-csg NA- 21 CMT vol adequate to tie-in Jong string to surf csg_ - - _ _ tJA- _ _ _ _ - - ~ 22 CMT-will cover all known-productive horizons- Yes - - - Adequate excess.. - - - - - - ~1 23 Casing designs adequate f_or G, T, B &_permafrost_ Yes - - 24 Adequate tankage_or reserve pit Yes - Nabors 2E$. ' 25 If a re-drill, has a 10.403 for abandonment been approved Yes 101312006, x' 26 Adequate wellbore separation proposed Yes - - ~ 27 If tliverter required, does it_meetregulations. NA_ - Sidetrack. 28 Dril_linq fluid. program schematic & equip list adequate- Yes Max MW 10J ppg. Appr Date 29 BOPEs, do they meetregu_lation Yes WGA 10!912006 30 BOPE. press rating appropriate; test t_o-{put prig in comments)_ - - Yes - . - - - Test io 3500. psi. MSt? 3240 psi. 131 Choke manifold comp_Iies wIAPI RP-53 (May 84)_ - _ _ Yes - - 32 Work will occur without operation shutdown . _ Yes - - ~33 Is presence of H2$ gas probable No- - - Not an H2S pad_. 34 Mechanical condition of wells within AOR verified (For_sennce well only) - NA X 35 ,Permit-can be issued wlo-hydrogen-sulfide measures - No- - - - - - Geology 36 Data-presented on potential overpressure zones _ _ NA- - _ _ - 37 Seismic analysis of shallow gaSzones- - - _ _ _ _ _ _ __ _ NA_ - . - - - Appr Date ii38 Seabed condition survey (ifoff-shore) - _ NA- - _ RPC 10/5/2006 i39 Contact name/phone for weekly_progress reports-[exploratory only] - - - - - NA- Geologic Engineering Commissioner: Date: Co issioner: Date o m' er Date ~Jis Icy; 1 ~ ~ ~ f°-9-®~ ~a'p"°~6 n • Well History File APPENDIX Information of detailed nature that is not CJ particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~~ • • e-llb.tapx Sperry-sun Drillin services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 30 10:42:53 2007 Reel Header Service name .............LISTPE Date . ...................07/11/30 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/11/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA scientific Technical services Scientific Technical Services E-11B 500292047502 BP Exploration Sperry Drilling Services 30-NOV-07 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0004667128 w-0004667128 LOGGING ENGINEER: M. LEAFSTEDT J. BOBBITT OPERATOR WITNESS: J. RALL D. MASKEL SURFACE LOCATION SECTION: 6 TOWNSHIP: 11N RANGE: 14E FNL: 463 FSL: FEL: 500 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 57.83 GROUND LEVEL: 30.28 WELL CASING RECORD Page 1 MWD RUN 4 w-0004667128 J. BOBBITT D. MASKEL 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: n e-llb.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4861.0 6.125 7.000 11095.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. E-11B WAS DRILLED FROM A WHIPSTOCK IN THE E-11 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 4860'MD AND THE BOTTOM WAS AT 4878'MD. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A 8IT OF RAT HOLE. UPHOLE MAD DGR DATA ACQUIRED WHILE POOH AFTER REACHING TD OF RUN 2 WERE MERGED WITH RUN 2 MWD DATA. NO DATA WERE ACQUIRED ON RUN 1. 5. MWD RUNS 3-4 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), AND COMPENSATED THERMAL NEUTRON (CTN). RUN 3 ALSO INCLUDED PWD. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY RUN IN E-11 ON 9/2/81. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 11/15/07. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THIS SHIFTED DATASET IS THE PDCL FOR E-11B. 7. MWD RUNS 1-4 REPRESENT WELL E-11B WITH API#: 50-029-20475-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11687'MD/9544'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 - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE Page 2 e-llb.tapx MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE.. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" & 8.5" MUD WEIGHT: 8.6-10.7 PPG MUD SALINITY: 100-3500 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 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 4666.5 11627.0 RPS 4827.0 11634.0 FET 4827.0 11634.0 RPD 4827.0 11634.0 RPX 4827.0 11634.0 RPM 4827.0 11634.0 FCNT 4841.0 11598.5 NCNT 4841.0 11598.5 PEF 4841.0 11614.0 RHOB 4841.0 11614.0 DRHO 4841.0 11614.0 NPHI 4841.0 11598.5 ROP 4856.5 11683.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4669.5 4666.0 4671.5 4668.0 4680.5 4677.5 Page 3 4682.5 4685.0 4691.5 4731.5 4747.0 4758.5 4767.0 4781.0 4786.5 4790.5 4793.0 4805.0 4807.5 4810.0 4816.0 4825.5 11686.0 4678.5 4680.5 4688.0 4730.0 4745.5 4756.0 4764.5 4777.0 4783.5 4787.5 4790.5 4801.5 4804.0 4811.0 4815.5 4826.5 11687.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. e-llb.tapx MERGE TOP MERGE BASE 4666.0 4893.0 4893.0 11095.0 11095.0 11687.0 Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4666.5 11683 8174.75 14034 4666.5 FCNT MWD CNTS 117 4244.71 1059.02 13516 4841 Page 4 Last Reading 11683 11598.5 e-llb.tapx NCNT MWD CNTS 14402.7 193346 128388 13516 4841 11598.5 RHOB MWD G/CM 1.114 3.135 2.38229 13378 4841 11614 DRHO MWD G/CM -1.445 0.45 0.0423911 13378 4841 11614 RPD MWD OHMM 0.19 2000 22.3658 13615 4827 11634 RPM MWD OHMM 0.39 2000 17.3134 13615 4827 11634 RPS MWD OHMM 0.17 1424.57 4.70121 13615 4827 11634 RPX MWD OHMM 0.29 1912.88 5.33599 13615 4827 11634 FET MWD HOUR 0.27 128.38 2.48885 13215 4827 11634 GR MwD API 7.19 522.05 88.7487 13922 4666.5 11627 PEF MWD BARN 0.82 13.88 2.97501 13408 4841 11614 ROP MWD FT/H 0.07 447.66 94.4369 13654 4856.5 11683 NPHI MwD Pu-s 4.28 104.98 30.6338 13516 4841 11598.5 First Reading For Entire File..........4666.5 Last Reading For Entire File...........11683 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLI6.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4666.0 4837.0 ROP 4860.5 4893.0 LOG HEADER DATA DATE LOGGED: 16-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4893.0 TOP LOG INTERVAL (FT): 4860.0 BOTTOM LOG INTERVAL (FT): 4893.0 Page 5 e-llb.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ,0 MAXIMUM ANGLE: .Q TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4861.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 58.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 750 FLUID LOSS (C3): 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 ~.O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined 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 4666 4893 4779.5 455 4666 4893 GR MWD020 API 21.7 78.97 41.0801 343 4666 4837 ROP MWD020 FT/H 0.07 31.47 10.4065 66 4860.5 4893 Page 6 e-llb.tapx First Reading For Entire File..........4666 Last Reading For Entire File...........4893 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Ty e ................LO Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4831.0 11041.5 RPx 4831.0 11041.5 RPM 4831.0 11041.5 RPD 4831.0 11041.5 RPS 4831.0 11041.5 GR 4837.5 11049.0 FCNT 4845.0 11002.0 NPHI 4845.0 11002.0 PEF 4845.0 11015.0 DRHO 4845.0 11015.0 NCNT 4845.0 11002.0 RHOB 4845.0 11015.0 ROP 4893.5 11095.0 LOG HEADER DATA DATE LOGGED: 22-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11095.0 TOP LOG INTERVAL (FT): 4893.0 BOTTOM LOG INTERVAL (FT): 11095.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 7 ~~ MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD e-llb.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 24.9 50.2 TOOL NUMBER 97054 81390 1844674407370955 186328 8.500 4861.0 other 9.30 58.0 9.6 400 5.8 1.050 65.0 .490 147.0 1.890 65.0 1.630 65.0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 Page 8 • • e-llb.tapx PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MwD030 PU-S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 4831 11095 7963 12529 4831 11095 FONT MWD030 CNTS 424.46 3380.39 1094.47 12315 4845 11002 NCNT MWD030 CNTS 102850 193346 138100 12315 4845 11002 RHOB MWD030 G/CM 1.114 3.135 2.37997 12341 4845 11015 DRHO MWD030 G/CM -1.445 0.45 0.040544 12341 4845 11015 RPD MWD030 OHMM 0.19 2000 11.8887 12422 4831 11041.5 RPM MWD030 OHMM 0.7 1743.45 5.44751 12422 4831 11041.5 RPS MWD030 OHMM 0.17 1361.3 3.56639 12422 4831 11041.5 RPX MWD030 OHMM 0.29 1825.42 3.71475 12422 4831 11041.5 FET MwD030 HOUR 0.27 24.22 1.47327 12422 4831 11041.5 GR MWD030 API 7.19 386.24 93.4872 12424 4837.5 11049 PEF MWD030 BARN 0.82 13.88 3.00925 12341 4845 11015 ROP MWD030 FT/H 3.47 447.66 96.1184 12404 4893.5 11095 NPHI MWD030 Pu-s 7.69 104.98 31.0338 12315 4845 11002 First Reading For Entire File..........4831 Last Reading For Entire File...........11095 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......sTSLI6.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 11002.5 11602.5 NPHI 11002.5 11602.5 FONT 11002.5 11602.5 Page 9 • ~ e-llb.tapx RPX 11042.0 11638.0 RPM 11042.0 11638.0 FET 11042.0 11638.0 RPD 11042.0 11638.0 RPS 11042.0 11638.0 GR 11049.5 11631.0 PEF 11085.0 11618.0 ROP 11095.5 11687.0 DRHO 11100.0 11618.0 RHOB 11100.0 11618.0 LOG HEADER DATA DATE LOGGED: 28-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11687.0 TOP LOG INTERVAL (FT): 11095.0 BOTTOM LOG INTERVAL (FT): 11687.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.9 MAXIMUM ANGLE: 28.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record TOOL NUMBER 153879 1844674407370955 48783 1050894 6.125 11095.0 Polymer 8.60 65.0 9.1 3500 9.8 .750 68.0 .450 118.0 1,100 68.0 ,650 68.0 Page 10 e-llb.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MwD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MwD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MwD040 FT/H 4 1 68 48 13 NPHI MWD040 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11002.5 11687 11344.8 1370 11002.5 11687 FCNT MWD040 CNTS 117 4244.71 695.536 1201 11002.5 11602.5 NCNT MWD040 CNTS 14402.7 56607.1 28803.9 1201 11002.5 11602.5 RHOB MWD040 G/CM 2.214 3.107 2.40985 1037 11100 11618 DRHO MWD040 G/CM -0.269 0.355 0.0643722 1037 11100 11618 RPD MWD040 OHMM 0.4 2000 131.458 1193 11042 11638 RPM MWD040 OHMM 0.39 2000 140.866 1193 11042 11638 RPS MWD040 OHMM 0.37 1424.57 16.5175 1193 11042 11638 RPX MWD040 OHMM 0.36 1912.88 22.2171 1193 11042 11638 FET MWD040 HOUR 0.5 128.38 18.3975 793 11042 11638 GR MWD040 API 12.38 522.05 51.8623 1164 11049.5 11631 PEF MwD040 BARN 1.23 12.83 2.57892 1067 11085 11618 ROP MWD040 FT/H 4.43 166.01 81.5041 1184 11095.5 11687 NPHI MwD040 Pu-S 4.28 60.59 26.5312 1201 11002.5 11602.5 First .Reading For Entire File..........11002.5 Last Reading For Entire File...........11687 File Trailer Service name... .......STSLIB.004 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/11/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Page 11 e-llb.tapx Tape Trailer Service name .............LISTPE gate . ...................07/11/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................07/11/30 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 12