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206-012
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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 Hiistory File Identiifiier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIII II II III II RE CAN DIGITAL DATA Color Items: ~iskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: Date: ^ Logs of various kinds: NOTES: ^ Other:: BY: _ Maria Date: `j 3 0 ~ b U /s/ Project Proofing BY Scanning Preparation BY: Production Scanning I III II'lII IIIII II III 1 Stage 7 Page Count from Scanned i=ile: _~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date:C~ ~T~ y~ ¢ lsl Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II IIN IIIII IIIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III III! III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) /s/ _~ x 30 = ~C ~ + ~ =TOTAL PAGES IGJ~ rr ,,et~~ (Count does not include cover sheet) ~/~ Date: ~ `~ O I V~ /s/ 1 1 P 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission EAU LIE 333 West 7th Avenue Anchorage, Alaska 99501 a.,0 6 -019- Subject: Corrosion Inhibitor Treatments of GPB G -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G-02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 I G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 i G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 --Jr G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -098 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -128 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -238 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -265 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G-31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 • # r._ ^~. ~. ._, :~ .,,,t ~~ ,~~ ~;- {~.• ~'. ~~;~: .: 4._ ;. MICROFILMED 6/30/2010. DO NOT PLACE. ANY .NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc ~4~~ DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2060120 Well Name/No. PRUDHOE BAY UNIT G-06A MD 11650 TVD 8993 Completion Date 2/26/2006 REQUIRED INFORMATION Mud Log No Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20358-01-00 Completion Status 1-OIL Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD/ SGRD /SGRC / SROP, MWD /EWR /SGRD /SGRC / SROP Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED D Asc - -- Directional Survey f ~ Leak ~g Ce nt Evaluation } ~D t/` C Las 15522 amma Ray ~og Ne utron tt" C Lis / 15884 ,Gamma Ray "' ~ [ !!! LIS Verification rED C Lis C Lis 16059r~nduction/Resistivity 16059v~nduction/Resistivity Induction/Resistivity Log In duction/Resistivity ~ ~D C 16100 "See Notes Well Cores/Sampl es Information: Name Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 9332 11650 Open 4/17/2006 'i 25 Blu 1 200 9110 Case 8/23/2006 I LDL, Spin, Temp, Pres, I, Gradio, GR, CCL 6-Apr- ', 2006 5 Col 1 7692 8253 Case 11/29/2006 SCMT-CB, PBMS 31-Oct- ': 2006 8511 11536 Open 10/3/2007 FCNL, GR, NCNL w/EMF and PDS graphics 25 Blu 8523 11523 Open 1/22/2008 Mem CNL in Carriier, Mem LEE CCL, GR 25-Feb-2006 8521 11522 Open 1/22/2008 LIS Veri, GR, CNT 8975 11650 Open 3/24/2008 i LIS Veri, GR< FET, RPX, RPS, RPD, RPM, ROP I 8975 11650 Open 3/24/2008 LIS Veri, GR< FET, RPX, RPS, RPD, RPM, ROP 25 Col 9345 11650 Open 4/10/2008 MD ROP, DGR, EWR 21- Feb-2006 25 Col 8757 8929 Open 4/10/2008 TVD DGR, EWR 21-Feb- ~ 2006 i 0 0 4/10/2008 TVD and MD of EWR in PDS, EMF and CGM graphics li Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2060120 Well Name/No. PRUDHOE BAY UNIT G-06A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20358-01-00 MD 11650 TVD 8993 Completion Date 2/26/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y~N Daily History Received? ~N Chips Received? ~ N Formation Tops ~ N Analysis 1~`tid'~ Received? Comments: - _ - - - -- ---- Compliance Reviewed By: _ Date: __~~ _ ~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : G-06A March 28, 2008 AK-MW-4214919INUM G-06A: 2" x S" MD Resistivity & Gamma Ray Logs: SO-029-20358-01-00 2" x S" TVD Resistivity & Gamma Ray Logs: S 0-029-203 S 8-01-00 Digital Log Images: SO-029-203 S 8-01-00 1 Color Logs 1 Color Logs 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: ~ -O l a ~ 1(ol1X~ a ~ WELL LOG TRANSMITTAL To: State of Alaska March 18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: G-06A AK-MW-4214919 1 LDWG formatted CD rom with verification listing. API#: 50-029-2035801-00 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: ~,, ,~ ~~ t ?~i~,}{ t ~ %'-' BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: c~~ ~o ~~ ~a ~ ~~~~ - ~{iI1~~~U~s~~~h Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth welt r.. ~..x ~~rl~1717~~ ,)UIY ~.$' 3 ~UUt7 NO. 4547 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. 01/11/08 ~~ Z-06 11594523 ~~~~ ~~~~~ STATIC TEMP LOG uate tst_ Color CD ` 14-18B 11975743 ~ - SBHP SURVEY 09/09/07 1 - 12/08/07 1 14-02C 117 67144 SBHP LOG - 11/02/07 1 H- 24A 11963 073 MEM CBL - ~ 11/30!07 1 C-35A 11624351 CEMENT BOND 8 GRAVEL PACK --a 11/03/07 1 MPH-19 E-03A 11982423 11628773 USIT (p ~S5 12/10/07 1 1 MEM PROD PROFILE - ~ 05/09/07 1 E-11 B 1143 7 4 60 OH LDWG EDIT (DSI) ~- G ~ 10/29/06 1 1 G-06A 11209587 MCNL ~,~T ~-~ . ~~ ~ 02/25/06 1 1 D-07B 11162822 MCNL ~- ~ ~ 12/04/05 1 1 G-10C 11209607. MCNL ~(p - ~ 06!15/06 1 1 G-09B 11649989 MCNL ,~ '} ,)) (~ 1 ~ L51 09/11/07 1 1 K-08B 11745243 MCNL Gj ~~ ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL - 12/06/07 1 V-07 11978425 USIT - L ( 12/06/07 1 L2-33 11970801 RST j - O '~- 07!07/07 1 1 03-14A 40013340 OH MWD/LWD EDIT # t 04/23/06 2 7 PLEASE ACKNOWLEDGE RE CEIPT uv aicu iuc n~ln o~Ti iouu~r± r,ar .....,., .-.,,. ~ .r BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 9DD E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~t ~ krtH' - 5~ ~ ~~( 13 ~ YY w F 1 ~; ~,- y ~7' ' ~ S, )fi~JY{r,~ t~Id ! il Y,;]Y~ A<i,. 4:1 ~~ • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth / r Received by • Date 09-28-2007 Transmittal Number:92905 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) f you have anv questions, please contact llouglas Uortch at trie r1x~ at ~n4-4y i~ Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-35B ~OCo'062 ~ tSS~g 07-07B ~}Cp -O Z5~ ~ lSSi~ C-16B ~bC~-r]5 1 ~15u l'~- C-34A odd (o -C~3~- # 65'J^Z D-07Bo?4S~1$1 ~' i$~ iG-06A ~b to -bl c~ ~ !5'J e~a 10C o~U~-00°i ~ 155 ®-~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-66 1 2 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.comJ Sent: Tuesday, August 28, 2007 1:11 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU G-06A / PTD # 206-012 H i Art, Please reference the following well: Well Name: PBU /G-06A Permit #: 206-012 API #: 50-029-2035$-01-00 Top Perf MD: 10140' Bottom Perf MD: 11520' This well began Production on August 19, 2007 Method of Operations is: Flowing Date of Test: 08/18/07 Hours Tested: 6 24-Hour Rate /Oil-Bbl: 852 24-Hour Rate leas-Mcf: 21,931 24-Hour Rate /Water-Bbl: 11 Test Rate /Oil-Bbl: 213 Test Rate IGas-Mcf: 5,483 Test Rate /Water-Bbl: 3 Choke Size: 128 Gas-Oil Ration: 25,741 Flow Tubing Pressure: 1,000 Casing Pressure: 840 Oil Gravity-API: Unavailable 8/28/2007 ~~ o~ ~ w STATE OF ALASKA ?~ i j~ 2 4 2~~ j -: ;. ALA A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~~I$a tlil & Gas Cons. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Ot f a~BID TREATMENT Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~, 206-0120 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20358-01-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 64.38 KB r PBU G-06A ° 8. Property Designation: 10. Field/Pool(s): ADLO-028304 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11650 ~ feet Plugs (measured) None true vertical 8993.46 feet Junk (measured) 11585' Effective Depth measured 11614 ' feet true vertical 8995 - feet Casing Length Size MD TVD Burst Collapse Conductor 80' 30" Insulated Surface - 110' Surface - 110' Surface 2698' 13-3/8" 72# N-80 Surface - 2698' Surface - 2698' 4930 2670 Production 8754' 9-5/8" 47# L-80 Surface - 8754' Surface - 8291' 6870 4760 Liner 1107' 7" 29# L-80 8228' - 9335' 7808' - 8810' 8160 7020 Liner 3054' 3-1/2"x3-1/16'x2-7/8" 8596' - 11650' 8147' - 8993' 10530 10160 8.81 #/6.2#/6.4# 8520 7660 Perforation depth: Measured depth: 10140 - 10340 10370 - 10540 10580 - 10640 10830 - 11250 11480 - 11520 True Vertical depth: 8997.55 - 8985.73 8985.64 - 8987.8 8987.31 - 8987.48 8988.69 - 8996.93 8989 - 8991 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 9335' - 9520' Packers and SSSV (type and measured depth) 9-5/8" X 4-1/2" TIW HBBP-R 8061' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ BUG ~ 91DD7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 1263 65373 0 0 803 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~~" .Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/22/2007 `. Form 10-404 evised 04/2006 ~~~~~ m~ riginal Only o~iGi~A~. ~~ • G-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ... h ''"' 1 ~ I I'~ f1 ACTIVITYDATE SUMMARY ~ 8/14/2007. CTU #8 w/ 1.75" OD CT. Acid treatment; MIRU. MU and RIH w/ 2.0" OD JSN. Attempt injectivity, unable to inject at 1000 psi WHP. Spot 12.7 bbls 11.8% HCI acid from 11585' ctmd to 9471' ctmd. PUH and stop at 9000' ctmd and wait for 2 hrs. to let acid soak. Establish injectivity of 0.7 bpm at 1500 psi WHP with backside liquid packed with 1 % KCI. Contact town, opt to continue with full acid treatment. Pumped a total of 178 bbls of 12% HCL while reciprocating across perfs. Started to see break down with 3 bbls out nozzle. At' 5 bbls out nozzle well went on a vac. Shut down at 125 bbls into job due to leak in treatment line. Cont' on WSR 8/15/07 ... 8/15/2007 CTU #8, Acid Stim; Cont' from WSR 8/14/07 ... PT treatment lines after leak repair. Continue pumping acid treatment. Well remained on a vac for the remainder of the treatment. Displaced acid to formation with 290 bbls of 1 KCL. POOH. Performed injectivity test from surface; 5 bpm @ 725 psi WHP (slow climb), 4 bpm ~ 605 psi WHP (slow climb), 3 bpm C 525 psi WHP (relatively flat), 2 bpm @ 300 psi WHP (relatively flat), 1 bpm C~ <0 psi WHP (on vac). Secured well. Performed weekly BOP test -passed. Stand by for N2 'pumper. N2 pumper on location. RIH taking returns through ASRC to G-23 flow line. Periodically deepen lift point to 8000' CTMD. Returns beginning to be acidic, switch liquid leg of returns to tanks. Well producing 1500 blpd, 90% WC (still cleaning up after acid job), 8.0 mmscf/d gas. Come down on N2. Monitor well, no change in WHP or production rates. POOH. Park in lubricator and monitor well performance. Cont' on WSR 8/16/07 8/15/2007 ASRC test unit #3 acid flowback. 8/16/2007 CTU #8, Acid; Cont' from WSR 8/15/07 ... Standby monitoring well~~ performance. As of 0400 hrs: Liquid rate 1800 bpd, Gas rate 19 mmscf/d, WC 4%, pH 4, solids 0.01%, cumulative liquid produced 746 bbls, FWHP = 1100 psi. Well still cleaning up through ASRC test separator. RD CTU #8. **" Job ':.Complete *"'` FLUIDS PUMPED BBLS 50 12% HCL 7 FRESH WATER 415 1 %KCL 10 50/50 METH 2250 GALLONS OF N2 USED 482 TOTAL 11 /28/06 -3 Sch~nngerger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth weu In6 ~ ~ .... n..~...:..~:.... N0.4058 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~a_ H-34 11477983 LDURST 11/07/08 Y-01B 11485488 MPPROF WlDEFT & GHOST 11/07/06 2-08/K-16 11487771 LDL 11/12/08 1 X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1 DS 09-51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485489 MPPROF 8~ INJECTION PROF 11109/08 1 N-07A 11296715 PROD PROFILE W/GHOST 09/10/08 1 DS 08-31C 11483591 INJECTION PROFILE 11/20108 1 G-08A 11422979 SCMT 11/01108 1 P2-59A 11414775 SCMT 11105/08 1 NGI-O6 11414773 USIT 11/01/08 1 A-43 11414774 USIT 11/03/06 1 01-26A 11001225 RST-SIGMA 05124/05 1 1 .-~+vc nvn~w~~a.cvvc Rc~+ur ~ or ~wmnv N17V RC 1l/R1Ylnll7 VIYC liVr'T CAl.r7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 , , t^-^^ ~ ' ~ - '~ - ~ ~: 900 E. Benson Blvd. ~ ~ „.~,„J/'3.. ~ '~~! --, C~ - Anchorage, Alaska 99508 Date Delivered: ~~ ,~'+~, ~ )(~[~(~ " ~t ~ ;e09 ~ i eayr, (r ,'~r r?1"'.'Bk "•61 F fd6,'. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth r Received by: -- f • ~ ~~ STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations 0 Stimulate Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Q ~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development "'~ Exploratory 206-01 20 3. Address: P.O. Box 196612 Stratigraphic ~ ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-20358-01-00 7. KB Elevation (ft): 9. Well Name and Number. 64.38 KB PBU G-06A 8. Property Designation: 10. Field/Pool(s): ADLO-028304 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11650 feet Plugs (measured) None true vertical 8993.46 feet Junk (measured) None Effective Depth measured 11614 feet true vertical 8995 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 30" Insulated Surface - 110' Surface - 110' Surface 2698' 13-3/8" 72# N-80 Surface - 2698' Surface - 2698' 4930 2670 Intermediate 8754' 9-5/8" 47# L-80 Surface - 8754' Surface - 8291' 6870 4760 Production 1107' 7" 29# L-80 8228' - 9335' 7808' - 8810' 8160 7020 Liner 3054' 3-1/2"X 3-1/16"X2-7/8" 8596' - 11650' 8147' - 8993' 10530 10160 8.81 #/6.2#/6.4# 8520 7660 Perforation depth: Measured depth: 10140' - 11520' _ True Vertical depth: 8998' - 8991' Tubing: (size, grade, and measured depth) 4-1/2" 12.65# L-80 9335' - 9520' Packers and SSSV (type and measured depth) 9-5/8" X 4-1/2" TIW HBBP-R 8061' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT IN 0 0 0 0 Subsequent to operation: SHUT IN 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Servi ce Daily Report of Well Operations x 16. Well Status after proposed work: Oil ~' Gas ~ WAG GINJ "` WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gary Preble Printed Name Gary P ~ bl Title Data Engineer (~ Signature 1- '' yPhone 564-4944 Date 11/27/2006 NOV 2 S 2006 issia Form 10-404 Re sed 04/2004 ~ 4~\ ~ <.i I i V ~~~ L- _~~~ ~~. ~~~i~; ~, ~ ~oo~ Submit Original Only ,. • • G-06A DESCRIPTION OF WORK COMPLETED. NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/24/2006 `"WELL SHUT IN ON ARRIVAL. *** ~ 'SET BAKER 3-3/8" IBP AT 8290' MID ELEMENT DEPTH. POSITIVE INDICATION OF SET SEEN ON SURFACE. '' NO PROBLEMS RIH OR POOH. FINAL T/ I/ O = 50/ 0 / 225. JOB COMPLETE. 'WELL LEFT SHUT IN. ':TURNED OVER TO DSO. *""JOB COMPLETE*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL ~~~ Sehium~erger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth A~.G 2 3 ZODo =^Jc~(~ ~~ ~' ~S CvC15. (',QtTliitiSSlGf1 ~.t`Gilr1('d~ ~~~~_~r N0.3914 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 08/15/06 1122160 LDL 08 02106 1 - 111 41 9 0 1 P-14 11212851 LDL 04/28106 1 F-24 N/A PRODUCTION LOG 03/29106 1 E-10A• 11047361 SENSA/MEMORY LDL 10/19105 1 H-30 • 11223103 LDL 03/19/06 1 A-37 11225946 PROD PROFILE W/DEFT 03/20/06 1 B-12A 11211386 PROD PROFILE W/DEFT & GHOST 03/31/06 1 G-O6A 11258691 LDL 04!06106 1 G-24 11258689 LDL 03/21106 1 H-30 11217258 USIT 06(09106 1 A-30A 40010566 OH EDIT OF MWD/LWD 06/26/04 2 1 A-30A P81 40010566 OH EDIT OF MWD/LWD 06/21/06 2 1 A-30A P62 40010566 OH EDIT OF MWD/LWD 06/25/06 2 1 Hiasxa vata es< ~onswung services PetrOtechnlcal Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. BenSOn Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth • • ' STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~r°6 k .~. , _, ~ ~., ~- _. ~ .,' I, ;gin 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAaczs.,os 2oAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba d. ?J28~~998' 2 d6 12. Permit to Drill Number 206-012 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/14/2006 13. API Number 50-029-20358-01-00 4a. Location of Well (Governmental Section): Surface: 2653' FNL 1974' FEL SEC 12 T11 N R13E 7. Date T.D. Reached 2/19/2006 14. Well Name and Number: PBU G-06A , , . , , , UM Top of Productive Horizon: 4278' FNL, 46' FWL, SEC. 07, T11 N, R14E, UM g. KB Elevation (ft): 64.38' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 4020' FNL, 1917' FWL, SEC. 07, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11614 + 8995 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 658254 y- 5968996 Zone- ASP4 10. Total Depth (MD+TVD) 11650 + 8993 Ft 16. Property Designation: ADL 028304 TPI: x- 660309 y- 5967414 Zone- ASP4 Total De the x- P 662173 Y- 5967712 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Surve Y ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD /SGRD /SGRC / SROP, MWD / EWR /SGRD /SGRC / SROP, MGR / CCL / CNL ASING, INER AND EMENTING ECORD CASING ETTiNG EPTH MD EITING PTH ND HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 30" x 20" Insulated Conductor Surface 110' Surface 110' 36" 279 cu ft Permafrost 13-3/8" 72# L-80 Surface 2698' Surface 2698' 17-1/2" 4241 cuftArcticset 9-5/8" 47# L-80 Surface 8754' Surface 8291' 12-1/4" 1250 cu ft Class'G', 140 cu ft AS 7" 29# L-80 8228' 9335' 7808' 8810' 8-1/2" 312 cu ft Class'G' 3-1/2' x 33/16° x zaia• s.a,a i s.2# i s.a# L-80 8596' 11650' 814T 8993' 4-1 /8" 197 cu ft Class 'G' 23. Perforations open,to Production (MD +TVD of Top and, B tt I l S " ' 24. TUBING RECORD o om nterva , lze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9335' 8061' MD TVD MD TVD 10140' - 10340' 8998' - 8986' 10370' - 10540' 8986' - 8988' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10580' - 10640' 8987' - 8987' 10830' - 11250' 8989' - 8997' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11480' -11520' 8989' - 8991' 2000' Freeze Protected with 60/40 McOH 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested 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". None ~ ';~~..._ ~,~~~'s B~~ APR 7L ~~~,~~~..~ g33~~~g'8"I ~- 7"~'D 2 5 2006 Form 10-407 wised 12/2003 ~ ~ ~ ~NjINI~D ON REVERSE SIDE G 28. GEOLOGIC MARKE 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 2A / 21 TS 9427' 8889' None Zone 1 B 9542' 8963' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / D~ Signed Terrie Hubble Title Technical Assistant Date ` ~ ~~ (© PBU G-06A 206-012 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Robert Laughlin, 440-0684 Permit No. /Approval No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 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". h•eM 29: list all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Spud Date: 4/23/1979 Event Name: REENTER+COMPLETE Start: 2/9/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/28/2006 Rig Name: NORDIC 1 Rig Number: Date 'From.- To 'I Hours Task Code NPT Phase Description of Operations 2/11/2006 13:00 - 13:30 0.50 MOB P PRE Rig released from 02-35B @ 13:OOHrs on 2/11/2006. Prep to move rig off well. 13:30 - 13:45 0.25 MOB P PRE PJSM. Jack-up rig & pull rig off well. Conduct post-operations pad inspection. 13:45 - 14:00 0.25 MOB P PRE Held pre-move safety meeting with crew, security & tool services. 14:00 - 00:00 10.00 MOB P PRE Move rig from DS#02 to G-pad. Meanwhile Wells Group 2/12/2006 100:00 - 00:30 I 0.501 KILL I P I I PRE 00:30 - 03:45 3.25 KILL N WAIT PRE 03:45 - 06:00 2.25 KILL N DPRB PRE 06:00 - 06:15 0.25 MOB P PRE 06:15 - 06:30 0.25 MOB P PRE 06:30 - 10:00 3.50 RIGU P PRE 10:00 - 16:00 6.00 BOPSU P PRE 16:00 - 16:30 0.50 RIGU P PRE 16:30 - 16:45 0.25 RIGU P PRE 16:45 - 17:30 0.75 RIGU P PRE 17:30 - 18:00 0.50 RIGU P PRE 18:00 - 19:30 1.50 RIGU P PRE 19:30 - 20:00 0.50 RIGU P PRE 20:00 - 21:00 1.00 RIGU P PRE 21:00 - 21:45 0.75 ZONISO P WEXIT 21:45 - 22:00 0.25 ZONISO N SFAL WEXIT 22:00 - 00:00 2.00 ZONISO P WEXIT 2/13/2006 00:00 - 01:15 01:15 - 01:30 1.25 ZONISO P WEXIT 0.25 ZONISO P WEXIT mobilize LRS to load & kill well with 5bbls of MEOH, 270bb1s of 2% KCL-water & 15bbls of diesel. Initial T/I/O = 2450/0/Opsi. Final T/I/O = 0/0/Opsi. Finished well kill C~? 23:00 Hrs. Arrive @ G-pad & position rig in front of G-06. Check WHP & observe 500psi. Attempt to bleed off pressure to a bleed tank, but WHP keep increasing. SI well & remobilize LRS & 2% KCL kill fluid to load & kill well. Well is swapping out real fast -built 500psi WHP in 1 hour. W.O. LRS & 2% KCL kill fluid. LRS load & kill G-06 with 225bb1s of 2% KCL-water. Initial WHP = 1300psi. Final WHP = Opsi. PJSM. Review procedure, hazards & mitigation for backing rig over well. N/D tree cap. Back rig over well & set down. ACCEPT RIG AT 06:30 HRS ON 02/12/2006. N/U BOPE & grease tree valves. Perform initial BOPE press /function test. Witness waived by AOGCC Jeff Jones. BOPE testing witnessed by Rick Whitlow, BP WSL. Change out coil packoff. Held PJSM for cutting CT. R/U hydraulic cutter to cut 1000' of CT. Meanwhile load rig pits with 2% KCL water. Held weekly HSE meeting, pre-tour TLM &PJSM for cutting CT. Cut 1000' of CT. Have 12340' of CT left on the reel. Rehead & M/U W FD CTC. Pull test to 35k. Install dart catcher. Pump 5bbls of 2% KCL ahead. PT MP#2 valve seat to 3800psi. Load wiper dart. Launch & chase with 2% KCL. Dart hit Q 48.4bbls. Press test inner reel valve & CTC to 3500psi - OK. PT MP#1 valve seat to 3700psi. PJSM. M/U slick cementing BHA #1 with big hole (0.90" ID) nozzle & 6' CSH tbg pup. Strip into well & M/U injector. Open up well & observe 2400psi WHP. IAP = Opsi, OAP = 12psi. Fix leak in flow tee wing valve. Snub in hole with cementing BHA #1 taking gassy returns to tiger tank. Wt check @ 9100' _> Up - 40k, Down - 18.5k. Continue RIH & tag WS Q 9346'. Correct CTD to 9335' (ELMD). PUH to 8890' while bullheading 50bbls of wellbore fluids. Flag CT. Meanwhile RU LRS pump to IA & bump up IAP to 500psi. RU SLB Cementers. Circ out wellbore fluids with 150bb1s of 2% KCL 3bpm/900psi & reduce WHP to 50psi. PJSM with all personnel concerning cementing operations. Meanwhile continue circulating wellbore C~ 2.42bpm/180psi & 50psi WHP to liquid pack wellbore. Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Spud Date: 4/23/1979 Event Name: REENTER+COMPLETE Start: 2/9/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/28/2006 Rig Name: NORDIC 1 Rig Number: Date ~I From - To Hours Task 'Code ~~ NPT ' Phase Description of Operations - i' --- __ 2!13/2006 101:30 - 02:45 1.251 ZONISO P ~ (WEXIT 02:45 - 03:00 0.25 ZONISO P 03:00 - 03:30 0.50 ZONISO P 03:30 - 05:00 1.50 ZONISO P 05:00 - 05:30 0.50 ZONISO P 05:30 - 07:30 2.00 ZONISO P 07:30 - 08:30 08:30 - 09:15 09:15 - 11:45 1.00 ZONISO P 0.75 STWHIP P 2.50 STWHIP P 11:45 - 12:45 12:45 - 14:45 14:45 - 18:00 18:00 - 19:15 19:15 - 21:00 21:00 - 22:00 22:00 - 23:00 23:00 - 00:00 1.00 STWHIP P 2.00 STWHIP P 3.251 STWHIPI P 1.251 STWHIPI P 1.75 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 2/14/2006 100:00 - 00:30 I 0.50 I STWHIPI P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Prime up. Flush/PT lines to 4k. Pump 5bbls of water ahead. Mix & pump 39bbls 15.Sppg class 'G' cmt slurry & 5bbls of water behind @ 2.4bpm/550psi & 35psi WHP. Shut-in choke. Chase/bulhead cement with KCL water C~3 2.94bpm/240psi & 50psi WHP. Bullhead 34bbls of cmt away C~3 2.94bpm from 50psi WHP to squeeze pressure of 125psi. Open up choke. Lay-in remaining 5bbls cmt 1:1 to TOC @ 8562'. POOH replacing voidage to safety C~ 8000'. Shut-in choke. Squeeze in additional 5bbls of cmt C~ min rate with 150psi WHP. RBIH contaminating any cmt stringers to 9300' with 2.45/2.45bpm & 1110psi. Circ btms up from 9300'. Getting 1:1 with not gas in returns. R/D cementers & LRS. Swap well to bio-KCL milling fluid. Jet OOH while displacing well to 2 ppb bio-KCL water. Jet thoroughly across jewelries & GLMs. Pump 3.1 bpm, full returns. UO cementing BHA. Jet stack. M/U Weatherford 3.80" window milling BHA #2. OAL = 82.60'. RIH with WFD 3.80" window milling BHA #2. Circ a min rate while RIH. sat down 2 times at SWS nipple at 8052 ft CTD. Lightly ream down thru nipple with slight motor work. Went thru easily. RIH to 9335' with no wt loss. POH slow while WOC. WOC. Tag whipstock at 9348'. Correct depth to 9335'. [-13']. Start milling, 2.5 bpm, free spin = 1180 psi, 17.5K down wt, 8 stalls trying to get started. Strong stalls as soon as mill touches whipstock. No WOB. Increase pump to 2.6 bpm, 1250 psi free spin. Still stalled at 9335', after RIH very slowly. Strong motor stalls. Hard to establish a wear patern. The top of whipstock was set just below a 4-1/2" collar, to place the window exit point above a 7" collar, If the whipstock was set 2' high we may have been stalling at the 4-1/2" connection. Total of 12 stalls to get started. 2.6 bpm, 1250 psi, 1 K. Milling Window OK after 4 hours. 2.6 bpm, 1250-1350 psi, 1 FPH, 2K WOB. Milling 3.80" window thru 4-1/2" and 7" Liners. 2.6 bpm, 1250-1400 psi, 3K WOB. Mill to 9337'. PVT = 222bb1s. Mill window to 9339' with 2.6/2.6bpm, 1250/1500psi, ifph ave ROP & 2k WOB. Mill window to 9340' with 2.6/2.6bpm, 1250/1350psi, ifph ave ROP & 2k WOB. Mill window to 9341' with 2.6/2.6bpm, 1250/1550psi, ifph ave ROP & 3k WOB. Mill window to 9341.7' with 2.6/2.6bpm, 1250/1650psi, 0.7fph ave ROP & 3k WOB. Mill window to 9342' with 2.6/2.6bpm, 1250/1650psi, 0.7fph ave ROP & 3k WOB. Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Spud Date: 4/23/1979 Event Name: REENTER+COMPLETE Start: 2/9/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2!28/2006 Rig Name: NORDIC 1 Rig Number: Date i From - To ~,i Hours ',~ Task ;Code NPT Phase I Description of Operations 2/14/2006... 00:30 - 01:30 1.00 _ ~ - ' -- _ _ - _ - ---- STWHIP P WEXIT Mill window to 9343' with 2.6/2.6bpm, 1250/1650psi, ifph ave i ROP & 4k WOB. 01:30 - 02:30 1.00 STWHIP P WEXIT i Mill window to 9344' with 2.6/2.6bpm, 1250/1650psi, ifph ave I ~ ROP & 4k WOB. 02:30 - 03:30 1.001 STWHIP P WEXIT Mill window to 9345' with 2.6/2.6bpm, 1250/1650psi, !fph ave ROP & 4k WOB. 03:30 - 04:30 1.00 STWHIP P WEXIT Mill window to 9346' with 2.6/2.6bpm, 1250/1550psi, ifph ave ROP & 3k WOB. 04:30 - 05:30 1.00 STWHIP P WEXIT Control mill window to 9347' with 2.6/2.6bpm, 1250/1650psi, 05:30 - 06:00 I 0.501 STW HI P I P 06:00 - 09:30 I 3.501 STWHIPI P 09:30-11:00 1.50 STWHIP P 11:00-11:30 0.50 STWHIP P 11:30 - 12:00 0.50 DRILL P 12:00 - 12:15 0.25 DRILL P 12:15 - 14:00 I 1.751 DRILL I P 14:00 - 16:00 2.00 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 17:10 0.17 DRILL P 17:10 - 18:00 0.83 DRILL P 18:00 - 00:00 6.00 DRILL P 2/15/2006 100:00 - 01:00 ( 1.001 DRILL I P 01:00 - 02:00 I 1.001 DRILL I P ifph ave ROP & 2k WOB. See CTP bump to 2150psi & WOB fall off to 1 k C~ 9346.4'. Exit into formation C~ 9347'. Tentative window depths are: TOWS/TOW = 9335', BOW = 9347', RA Pip tag = 9343.87'. WEXIT Mill formation to 9350' with 2.6/2.6bpm, 1250/1750psi, 8fph ave ROP & 5k WOB. Stall motor. Backream clean to above window C~3 9320'. Ream back in hole clean & ease back into milling. PVT = 222bb1s. WEXIT Mill formation to 9357'. Ream window while swapping to reconditioned FloPro. 2.7 bpm, 2000 psi, Ream window up/down total of 3 times. Stop Pump and Run thru window clean. Back ream up thru window clean. WEXIT POH. 2.6 bpm, 2200 psi. WEXIT Lay out milling BHA. Window mill was 3.80" No-Go, string mill was 3.79" No-Go. PRODi M/U SWS CTC. Pull /Press test, OK. PRODi HELD PRE-SPUD MEETING with all personnel. Review well hazards and plan. Reviewed MWD/RES BHA M/U procedure, hazards and mitigation. PROD1 M/U drilling BHA #3 with 1.5deg X-treme motor, MWD/GR-RES, orienter & rebuilt Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #2. Scribe tools. Initialize RES tool & M/U injector. PROD1 RIH drilling BHA#3. SHT MWD &orienter _ OK. Continue RIH to 9035'. PROD1 Log down GR & tie-into Geology PDC log. Subtract 13' from CTD. PROD1 RIH clean thru window with pumps down. Tag btm without pumps ~ 9355'. Bring on pumps & establish freespin C~ 2.5bpm/2800psi. TF = 70R. Up wt = 32k, Run-in wt = 22k. PVT = 314bb1s. PROD1 PUH above window. Orient TF around to HS. RBIH to btm. Stall several times on btm & ease into drilling. PROD1 Driling build/turn with TF 10-20 L, 2.58 bpm, 3300 psi, FS 2900 psi, PV 310 bbls, Lithology 60 percent chert w/ pyrite, ROP 15 - 30 fph. Log GR pip tag C~ 9341'. Corrected window depths are: TOWS/TOW = 9332' & BOW = 9344'. PROD1 Driling build/turn with TF 10-30 L, 2.58 bpm, 3300 psi, FS 2900 psi, PV 309 bbls, Lithology 50 percent chert w/ pyrite, ROP 15 - 30 fph PROD1 Orient TF around to 70 L, difficult getting clicks on btm, POH, Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Operations Summary Report Page 4 of 12 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To G-06 G-06 REENTE NORDIC NORDIC Hours ' R+COM CALIST 1 Task PLET A Code ! E NPT i Start Rig Rig Phase Spud Date: 4/23/1979 : 2/9/2006 End: Release: 2/28/2006 Number: ~~ Description of Operations 2/15/2006 _ 01:00 - 02:00 1.00, DRILL P PROD1 performed wiper trip to 9360', orient TF around, RIH to btm. 02:00 - 03:30 1.50 DRILL P PROD1 Driling build/turn with TF 60 L, 2.58 bpm, 3300 psi, ROP 30 - i ( 70 fph 03:30 - 04:10 0.67 ~ DRILL P PROD1 ' Unable to Orient TF on btm, POH to 9360', Orient TF to 47 R 04:10 - 06:30 2.33 ~ DRILL P PRODi ~ Drill build/turn to 9646' with TF 18 - 50 L, 2.7 bpm, 3800 psi, ROP 30 - 60 fph. 06:30 - 07:15 0.75 DRILL P PROD1 Wiper to window & orient TF to 45R. RBIH to btm. Up wt = 32k. S/O wt = 17k. PVT = 304bb1s. 07:15 - 08:25 1.17 DRILL P PROD1 Drill to 9700' with 20-30R TF, 2.6/2.6bpm, 2950/3250psi, 8k WOB & 50fph ave ROP. 08:25 - 08:30 0.08 DRILL P PROD1 Short 100' wiper. 08:30 - 09:15 0.75 DRILL P PROD1 Drill with 15-25R TF, 2.5/2.5bpm, 2850/3250psi, 9k WOB & 50fph ave ROP. Land build/turn section ~ 9740' in lower Z-1 B Ci3 revised target of +/-8955ftvdss. 09:15 - 11:15 2.00 DRILL P PRODi POOH for lateral BHA. Paint EOP flag C~ 8900'. Chase solids to surface, jog back in hole C~ 100fpm & chase back up to surface. Meanwhile bleed down the IAP from 950psi to 100psi. 11:15 -.12:15 1.00 DRILL P PROD1 OOH. PJSM. S/B injector. Check bit -grade 5/4/I with 2 plugged jets & slight ring on the pilot. C/O orienter, motor & bit. Download resistivity tool. 12:15 - 13:00 0.75 DRILL P PROD1 M/U lateral BHA #4 with 1.Odeg X-treme motor, MWD/GR-RES, orienter & new Bit #3 [Smith ODM 3-3/4" x 4-1/8" bicenter]. Scribe tools & initialize resistivity tool. M/U injector. 13:00 - 15:10 2.17 DRILL P PROD1 RIH drilling BHA#4. SHT MWD &orienter - OK. Continue RIH. Correct -14' (~ the flag. Check Up wt = 31 k, Run-in wt = 19k. RIH clean thru window with pumps down. 15:10 - 15:20 0.17 DRILL P PROD1 Log up & tie-into RA pip tag. Add 0.5' to CTD. 15:20 - 15:30 0.17 DRILL P PROD1 RIH to btm tagged (~ 9738'. 15:30 - 15:45 0.25 DRILL P PROD1 Orient TF to 90R. Up wt = 28k. S/O wt = 17k. PVT = 293bb1s. Meanwhile bleed down the IAP from 950psi to 100psi. 15:45 - 16:45 1.00 DRILL P PROD1 Drill to 9766' with 90-110R TF, 2.6/2.6bpm, 2950/3350psi, 9k WOB & 30fph ave ROP. Drilling very ratty. 16:45 - 17:00 0.25 DRILL P PROD1 Orient TF to 110L. 17:00 - 20:15 3.25 DRILL P PROD1 Drill with 90L TF, 2.6/2.6bpm, 2950/3350psi, 15k WOB & 10fph ave ROP. Wt stacking, sticky & drilling very ratty. 20:15 - 21:15 1.00 DRILL P PROD1 Wiper trip to 9360', 2.3 bpm, FS 3000 psi 21:15 - 23:10 1.92 DRILL P PROD1 Drill with 68 - 56 L TF, 2.4 bpm, 3400 psi, 5 - 10 k WOB, ROP 15 - 46 fph, Pit Vol 286 bbls, Wt stacking, sticky & drilling very ratty. Mixed and pumped Lub-Tex pill, hole slicked up while pill was pumped thru bit then resorted back to sticky and ratty. 23:10 - 00:00 0.83 DRILL P PROD1 Drill with 77- 90 L TF, 2.4 bpm, 3650 psi, 4 k WOB, ROP 50 fph, displacing well to new Flo-Pro system, returned used mud to MI for reconditioning. ROP at 60 fph 2/16/2006 00:00 - 03:30 3.50 DRILL P PROD1 Drill with 90 - 68 L TF, 2.4 bpm, 3650 psi, 4 k WOB, displacing well to new Flo-Pro system, returned used mud to MI for reconditioning, after new mud in system, pump pressure at 3050 psi w/ 2.3 bpm, 4 K WOB, ROP 20 fph, still stacking WT on bit, ratty and sticky, PVT 324 bbls 03:30 - 05:30 2.00 DRILL P PROD1 POH to inspect BHA 05:30 - 06:00 0.50 DRILL P PROD1 OOH. PJSM. S/B injector. Check bit -grade 1/1/t with 2 plugged jets & slight ring on the pilot. C/O bit. 06:00 - 06:45 0.75 DRILL P PRODi M/U lateral BHA #5 with 1.Odeg X-treme motor, Printed: 3/6!2006 12:52:22 PM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ! Name: ell Name: e: Name: From - To ', G-06 G-06 REENTE NORDIC NORDIC Hours R+COM CALIS 1 Task PLET TA Code E I NPT Start Rig Rig Phase Spud Date: 4/23/1979 : 2/9/2006 End: Release: 2/28/2006 Number: ~ Description of Operations 2/16/2006 -- -- - 06:00 - 06:45 ~ 0.75 DRILL P - ' PROD1 _- - --- - - _ -- -- MWD/GR-RES, orienter & new Bit #4 [Hughes 3-3/4" x 4-1/8" RWD2ST bicenter]. Inspect CTC & found some loose set screws. 06:45 - 07:30 0.75 DRILL P PROD1 Behead & install new SLB CTC. Pull test to 35k & PT to 3500psi. 07:30 - 09:20 1.83 DRILL P PROD1 RIH drilling BHA#5. SHT MWD &orienter - OK. Continue RIH. Correct -14' C~3 the flag. Check TF - 70R. RIH clean thru window with pumps down. 09:20 - 09:30 0.17 DRILL P PROD1 Log up & tie-into RA pip tag. Subtract 3' from CTD. 09:30 - 09:50 0.33 DRILL P PROD1 RIH to btm tagged @ 9915'. 09:50 - 10:20 0.50 DRILL P PROD1 Orient TF to around to 90L. Up wt = 28k. S/O wt = 17k. PVT = 320bb1s. 10:20 - 11:30 1.17 DRILL P PRODi Drill to 9969' with 80-100L TF, 2.6/2.6bpm, 2650/3100psi, 5k WOB & 50fph ave BOP. Drilling invert in search of reservoir quality sand. Still drilling ratty but lot better than the previous run. 11:30 - 12:55 1.42 DRILL P PROD1 Orient & drill to 10050' with 80-100L TF, 2.7/2.7bpm, 2750/3200psi, 12k WOB & 50fph ave BOP. Stacking wt. 12:55 - 13:45 0.83 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 13:45 - 14:20 0.58 DRILL P PROD1 Drill to 10071' with 70L TF, 2.6/2.6bpm, 2700/3200psi, 4k WOB & 50fph ave BOP. 14:20 - 15:15 0.92 DRILL P PROD1 Orient & drill to 10100' with 50-60L TF, 2.6/2.6bpm, 2700/3200psi, 4k WOB & 30fph ave BOP. 15:15 - 15:35 0.33 DRILL P PRODi Orient TF around to 65R. Up wt = 27k. S/O wt = 15k. PVT = 317bb1s. 15:35 - 17:i5 1.67 DRILL P PROD1 Continue drilling invert to 10130' with 80-100R TF, 2.6/2.6bpm, 2700/3200psi, 6k WOB & 30fph ave BOP. Meanwhile bleed down the OAP from 300psi to 10psi &IAP from 780psi to 680psi. Getting liquid back from the IAP. Could only get the IAP down to 680psi after 2hrs of bleeding. BHCT observed from MWD = 132degsF. 17:15 - 18:15 1.00 DRILL P PROD1 Orient & drill to 10170' with 110R TF, 2.6/2.6bpm, 2700/3200psi, 4k WOB & 95fph ave BOP. Observe drilling break C~3 10140', PVT 311 bbls 18:15 - 18:55 0.67 DRILL P PROD1 Drill with 117 - 131 R TF, 2.6/2.6 bpm, 2700!3200 psi, 4 - 6 k WOB, 95 - 125 fph ROP 18:55 - 19:55 1.00 DRILL P PROD1 Wiper trip to 9360', no hole problems 19:55 - 23:00 3.08 DRILL P PROD1 Drill with 117 - 131 R TF, 2.6/2.6 bpm, 2700/3200 psi, 4 - 6 k WOB, 50 - 100 fph ROP 23:00 - 00:00 1.00 DRILL P PROD1 Orient and Drill with 153 - 173 L TF, 2.55/2.55 bpm, 2700/3800 psi, 4 - 6 k WOB, 50 - 100 fph ROP 2/17/2006 00:00 - 01:45 1.75 DRILL P PROD1 Drill with 153 - 173 L TF, 2.55/2.55 bpm, 2700/3800 psi, 4 - 6 k WOB, 50 - 100 fph ROP 01:45 - 03:15 1.50 DRILL P PROD1 Wiper trip, tie-in to RA tag 0' correction, no hole problems 03:15 - 03:50 0.58 DRILL P PROD1 Orient TF around to 70 R, PVT 301 bbls 03:50 - 04:00 0.17 DRILL P PROD1 Drill with 58 - 78 R TF, 2.7/2.7 bpm, 3175/3600 psi, 3 - 6 k WOB, ROP 100 fph 04:00 - 04:30 0.50 DRILL P PROD1 Orient TF around to 109 L 04:30 - 04:55 0.42 DRILL P PROD1 Drill with 153 - 135 L TF, 2.65 bpm, 3600 psi, 3 - 6 k WOB, ROP 100 fph 04:55 - 06:30 1.58 DRILL P PRODi Orient and Drill to 10500' w/ TF at 103 L, 2.6 bpm, 3525 psi, 2 - 4 k WOB, ROP 110 fph 06:30 - 07:50 1.33 DRILL P PROD1 Wiper trip to window. Observe slight wt bobble ~ 10080' shale Printed: 3!6/2006 12:52:22 PM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Spud Date: 4/23/1979 Event Name: REENTER+COMPLETE Start: 2/9/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/28/2006 Rig Name: NORDIC 1 Rig Number: Date '~, From - To , Hours ~ Task '~, Code NPT ~~ Phase ~! Description of Operations I 2/17/2006 06:30 - 07:50 1.33 DRILL P PROD1 while PUH 8~ RIH .RBIH to btm. Up wt = 30k. S/O wt = 13k. PVT = 297bb1s. IAP = 780psi. OAP = 475psi. 07:50 - 08:15 0.42 DRILL P PROD1 Orient & drill to 10548' with 70L TF, 2.6/2.6bpm, 2800/3350psi, 7k WOB & 70fph ave ROP. 08:15 - 08:35 0.33 DRILL P PRODi ~ Orient TF around to 150L. 08:35 - 09:05 0.50 DRILL P PROD1 Drill to 10578' with 130-150L TF, 2.6/2.6bpm, 2800/3350psi, 4k ~ WOB & 80fph ave ROP. 09:05 - 09:10 0.08 DRILL P PROD1 Orient TF to 60L. 09:10 - 10:00 0.83 DRILL P PROD1 Drill to 10650' with 85L TF, 2.6/2.6bpm, 2800/3200psi, 5k WOB & 95fph ave ROP. 10:00 - 11:20 1.33 DRILL P PRODi Wiper trip to window. Observe slight wt bobble C~? 10120' shale while PUH. RBIH to btm. Up wt = 30k. S/O wt = 13k. PVT = 290bb1s. IAP = 850psi. OAP = 570psi. 11:20 - 12:45 1.42 DRILL P PRODi Orient & drill to 10755' with 120R TF, 2.6/2.6bpm, 3000/3550psi, 5k WOB & 120fph ave ROP. 12:45 - 13:20 0.58 DRILL P PROD1 Orient & drill to 10800' with 130R TF, 2.6l2.6bpm, 3000/3550psi, 4k WOB & 130fph ave ROP. 13:20 - 14:10 0.83 DRILL P PRODi Wiper trip to window. Observe slight wt bobble @ 10700' & 10080' shales. Up wt = 30k. 14:10 - 14:30 0.33 DRILL P PROD1 Log up & tie-into RA pip tag. Add 4' to CTD. 14:30 - 15:20 0.83 DRILL P PROD1 RIH to btm tagged @ 10804'. S/O wt = 13k. PVT = 282bb1s. IAP = 910psi. OAP = 620psi. 15:20 - 17:45 2.42 DRILL P PROD1 Orient & drill to 10950' with 80-100L TF, 2.6/2.6bpm, 3000/3550psi, 4k WOB & 100fph ave ROP. 17:45 - 19:25 1.67 DRILL P PROD1 Wiper trip to window. 19:25 - 19:45 0.33 DRILL P PROD1 Drill with 35 L - HS TF, 2.4 bpm, 2950/3350psi, 4k WOB, ROP 75 - 100 fph 19:45 - 20:05 0.33 DRILL P PROD1 Orient TF around to 83 L 20:05 - 22:45 2.67 DRILL P PROD1 Drill with TF at 88 L, 2.65 bpm, 3800psi, 4 - 6 k WOB, ROP 90 - 120 fph, displace well with new Flo-Pro Mud system 22:45 - 00:00 .1.25 DRILL P PROD1 Wiper trip to window. 2/18/2006 00:00 - 00:15 0.25 DRILL P PROD1 Wiper Trip to window 00:15 - 00:35 0.33 DRILL P PROD1 Orient TF around to 118L, PVT 289 bbls 00:35 - 00:50 0.25 DRILL P PROD1 Drill with TF at 141 L, 2.6 bpm, 3300psi, 2 k WOB, ROP 120 fph 00:50 - 02:30 1.67 DRILL P PRODi Orient TF to 100L, Drill with TF at 121 - 83L, 2.7 bpm, 3400psi, 2 - 4 k WOB, ROP 120 fph 02:30 - 04:40 2.17 DRILL P PROD1 Wiper trip to window, tie-in w/ RA tag, no correction, PVT 286 bbls 04:40 - 04:50 0.17 DRILL P PROD1 Drill with TF at 108 - 99R, 2.7 bpm, 3700psi, 2 - 6 k WOB, ROP 120 - 140 fph 04:50 - 05:10 0.33 DRILL P PROD1 Orient TF around to 55R 05:10 - 06:25 1.25 DRILL P PROD1 Drill to 11400' with TF at 46 - 96R, 2.6 bpm, 3500psi, 2 - 6 k WOB, ROP 135 - 100 fph 06:25 - 08:00 1.58 DRILL P PROD1 Wiper trip to window. Observe CTP bump @ 9660' -suspect plug in BHA. Still getting 1:1 circ, MWD still pulsing &orienter still indexing. PUH above window & troubleshoot hi-pressures without luck. IAP = 750psi & OAP = 465psi. 08:00 - 09:20 1.33 DRILL N DFAL PROD1 POOH to inspect BHA. Observe IAP & OAP gradually reduce to 80psi & 9psi respectively with BHA C~3 surface. 09:20 - 10:30 1.17 DRILL N DFAL PROD1 OOH. PJSM. S/B injector. Check bit -grade 1/1/I with 1 plugged jet. Check motor, MW D pulser, orienter &MHA - nothing amiss. C/O motor & scribe tools. Download resistivity tool. C/O MWD pulser &MHA. Inspect CTC - OK. Circ Printed: 3!6/2006 12:52:22 PM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 4/23/1979 Start: 2/9/2006 End: Rig Release: 2/28/2006 Rig Number: Date ', From - To Hours Task '~ Code', NPT 2/18/2006 09:20 - 10:30 1.171 DRILL ~ N DFAL 10:30 - 12:15 I 1.751 DRILL I N I DFAL 12:15 - 14:30 I 2.251 DRILL I N I DFAL 14:30 - 16:00 I 1.501 DRILL I N I DFAL 16:00 - 17:15 I 1.251 DRILL I P 17:15 - 18:45 I 1.501 DRILL I P 18:45 - 19:00 0.25 DRILL P 19:00 - 19:20 0.33 DRILL P 19:20 - 20:15 0.92 DRILL P 20:15 - 20:45 0.50 DRILL P 20:45 - 23:00 2.25 DRILL P 23:00 - 00:00 1.00 DRILL P 2/19/2006 100:00 - 01:50 I 1.831 DRILL I P 01:50 - 04:35 I 2.75) DRILL I P 04:35 - 06:15 1.67 DRILL N SFAL 06:15 - 07:45 1.50 DRILL N SFAL 07:45 - 08:00 0.25 DRILL N SFAL 08:00 - 08:10 0.17 DRILL N SFAL 08:10 - 08:15 0.08 DRILL N SFAL 08:15 - 09:00 0.75 DRILL N SFAL 09:00 - 09:15 0.25 DRILL N SFAL 09:15 - 11:00 1.75 DRILL N SFAL 11:00 - 11:30 0.50 BOPSUF~ P 11:30 - 00:00 12.50 DRILL I N WAIT Phase ~ Description of Operations PROD1 surface thru OECT & record normal pressure of 1230psi C~ 2.6bpm. PROD1 M/U lateral BHA #6 with 1.Odeg X-treme motor, MWD/GR-RES, orienter & same Bit #5 [Hughes 3-3/4" x 4-1/8" RWD2ST bicenterj. Initialize resistivity tool. M/U injector. Circ ~ surface thru BHA & record hi-pressure of 3800psi C~ 2.4bpm. PROD1 Unstab & S/B injector. C/O orienter & M/U injector. SI bag & circ @ surface thru BHA & still record hi-pressure of 3800psi @ 2.4bpm. B!O MWD/RES & observe broken centralizer blade (3" long x 1/2" wide) from MWD probe on equalizer internal jet. C/O centralizer blades & insert back MW D probe. M/U BHA & scribe tools. Re-initialize resistivity tool. M/U injector. Circ @ surface thru BHA & record normal pressure of 2200psi C 2.4bpm. PRODi RIH drilling BHA#6. SHT MWD &orienter - OK. Continue RIH. RIH clean thru window with pumps down. PROD1 RIH to btm tagged C~3 114.13'. Correct CTD to 11400'. P!U wt = 28k. S/O wt = 12k. PVT = 297bb1s. IAP = 880psi. OAP = 49psi. Freespin C~3 2.6bpm = 2580psi. PROD1 Drill with 130-170L TF, 2.6/2.6bpm, 2600/3070psi, 6k WOB & 135fph ave ROP. MWD pulsing intermittently. PROD1 Orient TF to 117L, PVT 292 bbls PROD1 Drill with TF at 98 - 58 L, 2.6/2.6bpm, 2600/2900psi, 6k WOB & 100fph ave ROP. MWD working fine on either side of 11480'. TF rolled around to 105R PROD1 Orient TF around to 3L PROD1 Drill with TF at 59 - 109 L, 2.7/2.7bpm, 3025/3450psi, 2 - 4k WOB & 65fph ave ROP. PROD1 Wlper Trip to window PROD1 Drill with TF at 50 - 68 L, 2.7/2.7bpm, 3025/3450psi, 2 - 4k WOB & 65fph ave ROP. PROD1 Drill with TF at 47 - 71 L, 2.6/2.6bpm, 2800/3150psi, 2 - 4k WOB & 45fph ave ROP. PROD1 MAD Pass f/ TD to window, Pin Hole CT while logging at 9950', ton miles 697,340 PROD1 POH to BHA PROD1 OOH. PJSM. S/B injector. Download resistivity. L/D BHA. Bit grade - 1/2/1. SI swab valve. Stab injector on well. PROD1 PJSM for B/D CT with N2. PRODi Pump 5bbls of fresh water ahead.. PRODi P/T N2 lines to 2500psi - OK. PROD1 Blow down CT with N2 & bleed off. PROD1 PJSM for stripping off & pulling back CT to the reel PRODi P/U injector. Slip grapple connector into CT & pull test. Strip-off CT from injector & spool back to reel. Secure CT & prep reel for shipment. S/B injector. PRODi Conduct weekly ROPE function test. PROD1 W. O. Wind to subside for CT reel swap. Winds currently blowing C«1 30mph steady with 40mph gusts. Performing general housekeeping and preventive maintenance Meanwhile cut & slip 45' of drilling line. Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT Start: 2/9/2006 Rig Release: 2/28/2006 Rig Number: Page 8 of 12 Spud Date: 4/23/1979 End: Phase ! Description of Operations 2/20/2006 00:00 - 06:00 6.00 DRILL N WAIT ~ PRODi 06:00 - 12:00 I 6.001 DRILL I N I WAIT I PROD1 W.O. Wind to subside for CT reel swap. Winds currently blowing @30mph steady with 40mph gusts ,performing general housekeeping and preventive maintenance W.O. Wind to subside for CT reel swap. Winds currently blowing @30mph steady with 40mph gusts. Meanwhile conduct rig evacuation drill & review Hand Safety presentation. Review various forward plan options with ANC & decide to cut +/-10500' of CT & run liner with +/-6700' of 2-3/8" PH6 tbg. 12:00 - 13:00 1.00 DRILL N SFAL PRODi Nordic Crew change. Held HA/HM &PJSM for forward plan operations. Mobilize 2 metal dumpsters for cut CT & ask for 300jts of 2-3/8" PH6 Tbg to be rattled. Meanwhile fill hole with 13bbls of mud. 13:00 - 13:15 0.25 DRILL N SFAL PROD1 PJSM for stabbing CT back into the injector & for cutting CT. 13:15 - 15:00 1.75 DRILL N SFAL PROD1 M/U reel motor. Slip grapple connector into CT & pull test. Pull CT across pipeshed & stab CT thru injector. 15:00 - 19:30 4.50 DRILL N SFAL PRODi R/U hydraulic cutter & cut 3500' of CT. 19:30 - 20:00 0.50 DRILL N SFAL PROD1 Held PJSM on cutting and LD CT with new crew rotation from days off, also, reviewed Hand Safety power point presentation. 20:00 - 00:00 4.00 DRILL N SFAL PROD1 Cut 3500' of 2 3/8" CT for a total of 7000' 2/21/2006 00:00 - 05:15 5.25 DRILL N SFAL PRODi Cut total of - 10500' of 2 3/8" CT, leaving - 1840' left on reel, R/D hydraulic cutter 05:15 - 06:15 1.00 CASE P RUNPRD M/U Baker CTC. Pull test to 60k - OK. 06:15 - 07:00 0.75 CASE P RUNPRD R/U to run liner. 07:00 - 07:15 0.25 CASE P RUNPRD Held PJSM for M/U completion liner & accessories. GPB is now in Level-2 driving conditions on the main roads, all access roads & Pads. Winds currently blowing @ 30mph steady with 40mph gusts. 07:15 - 10:30 3.25 CASE P RUNPRD M/U 2-7/8" STL rotating guide shoe, float collar, 1 shoe jt, float collar & landing collar. M/U 59jts of 2-7/8" STL 6.16# L-80 liner & LSL sub. M/U 4jts of 3-3/16" 6.2# L-80 TCII liner. Suspend operations due to Phase-3 weather conditions. 10:30 - 00:00 13.50 CASE N WAIT RUNPRD W. O. Wind to subside. Winds currently blowing C~3 75mph. 2/22/2006 00:00 - 07:00 7.00 CASE N WAIT RUNPRD W. O. Wind to subside. Winds currently blowing ~ 25mph with 35mph gusts. GPB currently on Phase 2 on all main roads & Level 3 on Well Pads & access roads. 07:00 - 07:15 0.25 CASE P RUNPRD Held PJSM for resuming operations & for M/U completion liner & accessories. 07:15 - 09:30 2.25 CASE P RUNPRD M/U total 34jts of 3-3/16" 6.2# L-80 TCII, XO, 1 jt of 3-1/2" 8.81# L80 STL, X nipple & 3-1/2" pups. 09:30 - 09:45 0.25 CASE C RUNPRD Held PJSM for loading & prepping 2-3/8" PH6 tbg. 09:45 - 13:00 3.25 CASE C RUNPRD R/U to run 2-3/8" PH6 tbg. Load into pipe shed, prep & tally 1st batch of 100jts of 2-3/8" PH6 tbg. 13:00 - 13:30 0.50 CASE P RUNPRD M/U BKR deploy sleeve. OAL of Inr - 3041.11'. M/U BKR CTLRT, disconnect, X/Overs. 13:30 - 13:45 0.25 CASE C RUNPRD Held PJSM for M/U 2-3/8" PH6 tbg. 13:45 - 18:00 4.25 CASE C RUNPRD M/U 100jts of 2-3/8" PH6 tbg. String wt on the Martin-Decker = 34k. Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Operations Summary Report Page 9 of 12 Legal Well Name: G-06 Common Well Name: G-06 Spud Date: 4/23/1979 Event Name: REENTER+COMPLETE Start: 2/9/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/28/2006 Rig Name: NORDIC 1 Rig Number: Date ', From - To ~ Hours Task ,Code NPT - - -~ 2/22/2006 18:00 - 20:00 ~ 2.00 CASE ~ C 20:00 - 23:00 23:00 - 00:00 2/23/2006 00:00 - 03:00 03:00 -04:00 04:00 - 05:30 05:30 - 07:15 3.00 CASE ~ C i 1.00 CASE C 3.00 CASE C i 1.00 CASE ~ C 1.50 CASE I C i 1.75 CASE ~ C 07:15 - 08:00 108:00 - 08:30 08:30 - 10:30 10:30 - 11:30 11:30 - 11:45 11:45 - 12:15 12:15 - 13:00 13:00 - 13:40 0.751 CASE I P 0.501 CASE I P 2.00 CASE ~ P 1.001 CASE I P 0.25 CASE P 0.50 CEMT P 0.75 CEMT P Phase Description of Operations RUNPRD Waiting on 121 jts - 2 3/8" PH6 rental string to arrive on location RUNPRD Load into pipe shed, prep & tally 2nd batch of 121 jts - 2-3/8" PH6 tbg. RUNPRD PU 2 3/8" PH6 tbg, RIH w/ liner to 3854', MU torque 2200 ftlbs RUNPRD PU 2 3/8" PH6 tbg, RIH w/ liner above window to 9000', MU torque 2200 ftlbs, 33 k Up Wt, 28 Dn Wt RUNPRD RU head pin, Circ water out of liner w/ Flo-Pro RUNPRD RU hardline, Pull test CTC to 80 K, pump volume dart, actual displacement 8 bbls, PT inner reel valve and CTC RUNPRD PU a total of 221jts of 2-3/8" PH6 tbg, RIH w/ liner, MU torque 2200 ftlbs. M/U X/Os & swivel. M/U CTC & stab injector. Liner shoe currently @ 10154'. Meanwhile R/U SLB cementers. RUNPRD Wt check: Up = 42k. Run-in wt = 22k. Establish Circ C 0.45bpm/1070psi. Continue RIH smoothly ~ 45fpm thru OH. Set down @ 11503'. P/U & run thru. Continue RIH Inr to TD tagged 2x ~ 11650'. Up wt = 42k. PUH to ball drop position Cam? 11643'. RUNPRD Establish Circ. Load 5/8" AL ball &circ with mud C 2.35/2.29bpm & 2450psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down ~ 25bbls away. Ball on seat ~ 26.9bbls. Pressure up to 3400psi & release CTLRT. P/U @ 35k & confirm release. RUNPRD Circ well to 2% KCL water with double friction reducer C~3 2.89/2.86bpm & 2715psi. Send used FloPro to MI for reconditioning. Observe IAP climb up to 1925psi. Reduce pumps to 1.88/1.77bpm & 870psi and reduce IAP to 1890psi. RUNPRD Load balance KCL into pits & mix KCL-bio displacement pill. Meanwhile continue circulating KCI @ 1.88/1.77bpm & 870psi. RUNPRD PJSM with all personnel concerning cementing operations. RUNPRD Batch mix 40 bbls of 15.8ppg 'G' latex cmt with additives. RUNPRD P/T cement lines to 4000 psi, Pumped 35 bbls of CL "G" at 2.6 bpm, 1550 - 1100 psi, 2.55 bpm returns. Clean cement line. Insert Dart. Displace dart with 30 bbls Biozan water ~ 3.75 bpm at 200 psi, caught up to cement after pumping 18 bbls, slow rate to 2.75 bpm at 1820psi, slowed rate to 2 bpm w/ 1100 psi, dart engaged liner wiper at 32.4 bbls pumped, sheared at 2600 psi, bumped plug w/ 51.8 bbl at 2 bpm, pressured up f/ 2500 psi to 3500 psi ,held for 2 minutes, bled of floats held, CIP at 13:00 hrs on 2/23/06. No fluid loss to formation during cement job. Top of FS at 11648' ist(Btm) FC at 11647' 2nd(Top) FC at 11615' LC at 11614' BOT Liner Deployment Sleeve at 8608' 2 7/8" tbg and accessories was drifted to 2.347", Pin Bore 2.377" ID; 3 3/16" tbg was drifted to 2.75" OD, 3 1/2" tbg and accessories was drifted to 2.867", Pin Bore 2.972" ID 0.67 CEMT ~ P RUNPRD Pressured up to 500 psi, unsting f/ deployment sleeve, POH Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: G-06 Common W ell Name: G-06 Spud Date: 4!23/1979 Event Nam e: REENTE R+COM PLET E Start : 2/9/2006 End: Contractor Name: NORDIC CALIS TA Rig Release: 2/28/2006 Rig Name: NORDIC 1 Rig Number: ~ Date '~ From - To Hours Task ; Code ~ NPT '; Phase Description of Operations , ~ _ '-_ I _ _ - _ - - - - --- 2/23/2006 13:00 - 13:40 0.67 CEMT P RUNPRD while filling voidage, std back inj. 13:40 - 00:00 10.33 CEMT C RUNPRD PJSM, POH, LD 2 3!8" PH6 pipe 2/24/2006 00:00 - 00:45 0.75 CEMT P RUNPRD LD baker liner running tools. 00:45 - 01:00 0.25 CEMT N DFAL RUNPRD PJSM N2 blowdown. 01:00 - 01:30 0.50 CEMT N DFAL RUNPRD N2 blowdown 1840' of coil. 01:30 - 04:00 2.50 CEMT N DFAL RUNPRD Pull back coil to reel. 04:00 - 10:00 6.00 BOPSU P RUNPRD BOP test. Witnessing waived by Lou Grimaldi AOGCC.Witnessed by R Laule & R Bordes BP Welt Site Supervisors. 10:00 - 15:30 5.50 BOPSU N WAIT RUNPRD Waiting on crane, performing preventive maintenance on equipment and general house keeping. DSM installed secondary annulus valve on IA. UCA Lab Test at 15:00 hrs showed 1698 psi compressive strength 15:30 - 19:00 3.50 EVAL N DFAL RUNPRD Crane arrived on location, PJSM w/crews involved in operations -Overhead Lifts, RU. Swap out CT reel 19:00 - 21:30 2.50 EVAL N DFAL RUNPRD Prep to pull coil to injector 21:30 - 00:00 2.50 EVAL N DFAL RUNPRD Replace stripper brass. Pull coil to injector. 2/25/2006 00:00 - 04:00 4.00 EVAL N DFAL RUNPRD Behead coil. Pull Test to 35K. Attempt to fill coil. Froze up line. Thaw line. Fill coil and pump volume dart (2 rubbers).NO Go didn't launch. Relaunch and pump 10 bbl over no dart .Launch second (4 rubbers) dart. At 59.5bb1 recovered 4 rubber dart. Continue to pump. At 62 bbl recovered the first dart launched. I never saw that before. 04:00 - 04:15 0.25 BOPSU P RUNPRD PT inner reel valve. 04:15 - 07:00 2.75 EVAL P RUNPRD MU cleanouUmemory logging BHA, RIH w/ 50 stds of 1 1/4" CSH, BHA length 3133', stab inj 07:00 - 07:55 0.92 EVAL P RUNPRD RIH w/ Cleanout Assy, tagged up at 7439' 07:55 - 09:45 1.83 EVAL P RUNPRD Drill cmt f/ 7439' to 7517' w/ 1.4 bpm at 2200 psi, FS at 2000 psi, WOB 2 K, progress very slow 09:45 - 10:30 0.75 EVAL P RUNPRD POH to BHA 10:30 - 12:30 2.00 EVAL P RUNPRD POH w/ BHA, Std back 50 stds of CSH 12:30 - 13:00 0.50 EVAL P RUNPRD PJSM -handling CNL tools, LD memory CNL tools 13:00 - 14:10 1.17 EVAL P RUNPRD MU BHA # 9, Baker MHA 14:10 - 15:00 0.83 EVAL P RUNPRD Change out CTC f/ SLB to Baker, pull and pressure test, OK, MU, Stab Inj 15:00 - 16:30 1.50 EVAL P RUNPRD RIH w/ BHA, taking weight at 7488', FS at 1600 psi w/ 2.64 bpm, PVT 265 bbls 16:30 - 20:45 4.25 EVAL P RUNPRD Wash Dn f/ 7488' to 7515', Drill cmt f/ 7515' - 8619 w/ 2.60 bpm, 1635 psi, 1 - 2 K WOB. ROP 150 - 370. Pumping 5 bbl Hi vis sweeps every 150-200'. Having continuous beads of cement cutting over shaker. Sweeps being extra cement cutting periodically blinding the screens. Pump sweep prior to POH. Seem less motor work and 20:45 - 23:15 2.50 EVAL N RUNPRD POH to surface pumping at max rate. 23:15 - 00:00 0.75 EVAL N RUNPRD LD 3.75 ceanout accy and PU 2.3 mill motor and memory log. 2/26/2006 00:00 - 03:15 3.25 EVAL N LOWERi PU Cleanout /memory logging BHA and 50 stands 1-1/4" CSH. 03:15 - 04:45 1.50 EVAL N LOWERi PU injector. RIH. to liner top. Begin fluid swap. 04:45 - 06:45 2.00 EVAL P LOWERi Log down at 30 fpm.at 1.4 bpm 1570 psi. 06:45 - 07:40 0.92 EVAL P LOWERI Log Up at 60 fpm f/ 11619' to 8600' at .50 bpm 500 psi while laying in pert pill, Up Wt 29.5 K 07:40 - 08:40 1.00 EVAL P LOWERi POH to BHA, pumping at full rate, std back inj 08:40 - 10:40 2.00 EVAL P LOW ER1 PJSM, Open circ sub, POH w/ BHA, Std Back 50 Stds of 1 1!4" Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: G-06 G-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/9/2006 Rig Release: 2!28/2006 Rig Number: Date ~li From - To Hours ~~ Task ~~, Code G NPT ~I ' ' Phase 2/26/2006 08:40 - 10:40 2.00 EVAL P ___ __ LOWERI 10:40 - 11:30 0.83 EVAL P LOWERI 11:30 - 12:00 I 0.501 PERFOBI P I I LOWERI 12:00 - 13:30 I 1.50) CEMT P RUNPRD 13:30 - 15:25 ~ 1.92 ~ PERFOB~ P i ~ LOW ER1 15:25 - 17:30 I 2.081 PERFOBI P I I LOWERI 17:30 - 19:00 1.50 PERFO~ P LOWERI 19:00 - 20:40 1.67 PERFO P LOWERI 20:40 - 21:30 0.83 PERFO P LOWERI 21:30 - 23:00 1.50 PERFO P LOW ER1 23:00 - 00:00 1.00 PERFO P LOW ER1 2/27/2006 00:00 - 00:30 0.50 PERFO P LOWERi 00:30 - 01:00 0.50 PERFO P LOWERI 01:00 - 06:50 5.83 PERFO P LOWERI 06:50 - 07:30 0.67 CASE P RUNPRD 07:30 - 09:30 2.00 CASE P RUNPRD 09:30 - 10:45 1.25 CASE P RUNPRD 10:45 - 11:00 0.25 CASE P RUNPRD 11:00 - 12:00 1.00 CASE P RUNPRD 12:00 - 14:00 2.00 CASE P RUNPRD 14:00 - 15:00 I 1.001 CASE I P I I RUNPRD Page 11 of 12 Spud Date: 4/23/1979 End: Description of Operations CSH PJSM, POH, remove source, LD Memory CNL tool, mtr and mill, confirm download info is good. Corrected PBTD 16011' and corrected liner top 8602'. Load pert guns into pipe shed. R/U safety jt & prep to M/U perf guns. Meanwhile download CNL data. From log data, PBTD = 11614' & 8600'. RU pump trk, P!f surface lines to 3500 psi, Pressure up IA to 1000 psi, pressured up on liner lap to 2000 psi, IA and tbg pressure equalized to -1380 psi, bled do tbg pressure to 1000 psi, pressured up on IA to -2850 psi when tbg pressure started to equalize w/ IA f/ 1215 psi to 2400 psi, pumped 4.9 bbls diesel do the iA, pressure equalized At -2450 psi on IA and Tbg. PJSM on perforation job. Fax CNL log to ANC Geo. ANC Geo OKs preliminary pert picks. M/U 65 jts of 2" HSD 6spf 2006PJ guns & blanks with CBF firing system. M/U 27 stds of CSH workstring. M/U MHA. Stab onto well. RIH to PBTD correct -12'. PU to ball drop position. Pump 10 bbl pill. Launch bail. displace ball with 5bbl pill and KCL at 1.7 bpm at 2500 psi. After 45 bbl reduce rate to .88 bpm C~ 440 psi. PT = 304 bbls. Ball on seat with 57.2 bbl fired at 59.2 bbl at 2680 psi. with pipe in motion. Bottom shot at 11520'. Well took 6 bbl before regaining returns. POH to CSH. Lost 5 bbl while POH for a total loss of 11 bbls. Set back injector and stand back 27 Stands CSH. Continue standing back CSH tubing. PJSM for laying down the perforating guns and their blanks. LD spent perforating guns, all shots fired, offload f/ pipeshed MU Baker polish mill assy RIH tagged liner top, worked polish mill inside depolyment sleeve, had slight pressure increase when no-go out, PU above sleeve, shut do pumps, RIH, dry tagged w/ No-Go on polish mill. POH to BHA LD Baker mtr, polish mill, taletail was rubbed down PU, strap LTP and seal unit, MU LTP Assy RIH w/ LTP Assy w/ .50 bpm at 125 psi, tag and sting into deployment sleeve w/ pumps on f/ 8608' to 8618' w/ 10K, pressure increased to 300 psi, bled off to 0 psi, S/O WT 10 K, P/U to 8615', brk circ Sting into deployment sleeve w/ seal assy, RU, PT 2 3/8" CT annulus (backside) to 2050 psi and IA to 2100 psi, pressure tracked f/ between 2 3/8" CT x 4 1/2" tbg to IA, held for 30 min, Bled off backside to 0 psi and IA to 70 psi, IA would not bleed off with CT annulus, had to bled off separately. Pressure Readings on Backside and IA and SI to Pump ISIP 2050 psi 2100 psi 2050 psi Printed: 3/6/2006 12:52:22 PM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: G-06 Common Well Name: G-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Hours Task Code NPT Date From - To I } 2/27/2006 14:00 - 15:00 1.00 CASE ~ P 15:00 - 15:45 0.75 CASE P 15:45 - 16:45 I 1.001 CASE I P 16:45 - 19:00 2.25 CASE P 19:00 - 20:45 1.75 WHSUR P 20:45 - 21:15 0.50 WHSUR N WAIT 21:15 - 21:50 0.58 WHSUR P 21:50 - 22:10 0.33 WHSUR P 22:10 - 00:00 1.83 WHSUR P 2/28/2006 00:00 - 02:00 2.00 WHSUR P Spud Date: 4/23/1979 Start: 2/9/2006 End: Rig Release: 2/28/2006 Rig Number: Phase Description of Operations RUNPRD 10 min 1989 psi 2090 psi 1987 psi 15 min 1967 psi 2062 psi 1965 psi 20 min 1952 psi 2046 psi 1948 psi 25 min 1941 psi 2036 psi 1941 psi 30 min 1930 psi 2028 psi 1937 psi RUNPRD Unsting f/ deployment sleeve, PU to 8605', Drop/launch 5/8" steel ball w/ 400 psi. Chase ball pass gooseneck C~ 2.4 bpm/1065psi. Slow down to 0.5bpml115psi ~ 44 bbls away. Ball on seat at 49.6 bbls. Bleed off CTP. RBIH & set down 10k @ 8616'. P/U & space out locator @ 1' from deploy sleeve 8594'. Set slips with 2050psi. Stack 10k' -seal locator is 1' above landing profile. RUNPRD RU pump trk, P/T surface lines to 3500 psi, Pressure up IA to 1000 psi, bled do pressure on CT to 650 psi inadvertently, pressured up on liner top packer between the 2 3/8" x 4 1/2" tbg to 2000 psi, IA and CT annulus communicating, pressure equalized to -1380 psi, pressured up do CT to 2000 psi, pressure fell off rapidly, ball has sheared, unable to retain pressure on CT, Consult w/ Anch, advised to POH w/ packer assy. RUNPRD PU to 30 K with no overpull, POH POST RIH with nozzel and freeze protect with 50/50 methanol. POST Wait on N2 30 min POST RU N2 unit POST PJSM for the N2 blowdown. POST Blow down reel with N2. Jet BOP. Set back injector. POST ND BOP. install and test tree cap. Clean pits. Released Rig at 0200 hrs. 02/28/2006. All further rig information wilt be on well P2-37A DIMS. Printed: 3/6/2006 12:52:22 PM Halliburton Company Survey Report Company: BP Amoco Date: 3/1 412 0 06 Time: 10:49:43 Page: ] ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: WeII: G-06,'7 rue North Site: PB G Pad VertieaL('I'VD) Reference: 9:06 4/23/1979 00:00 64.4 Well: G-06 Section (VS) Reference: Well (O.OON,O.OOE,109.36Azi) Wellpath: G-06A -- Survey Calculation Method: Minimum Curvature Db: Oracle -- - Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: G-06 Slot Name: 06 G-06 Well Position: +N/-S 2122.16 ft Northing: 5968996.00 ft Latitude: 70 19 19.080 N +E/-W 1997.37 ft Easting : 658254.00 ft Longitude: 148 43 0.721 W Position Uncertainty: 0.00 ft Wellpath: G-06A Drilled From: G-06 500292035801 Tie-on Depth: 9332.00 ft Current Datum: 9: 06 4!23/1979 00:00 Height 64.38 ft Above System Datum: Mean Sea Leve l Magnetic Data: 2/9/2006 Declination : 24.62 deg Field Strength: 57605 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 29.38 0.00 0.00 109.36 Survey Program for Definitive Wellpath Date: 3!3/2006 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 9300.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 9332.00 11627.86 MWD (9332.00-11 627.86) MWD MWD -Standard Survey ___ _ ~1D Inc! Azim TVD Sys TVD V/S E/W - MapN MapE Tool.. ft deg deg ft ft ft ft ft ft 29.38 0.00 0.00 29.38 -35.00 0.00 0.00 5968996.00 658254.00 TIE LINE 100.00 0.40 235.79 100.00 35.62 -0.14 -0.20 5968995.86 658253.80 BOSS-GYRO 200.00 0.28 235.60 200.00 135.62 -0.47 -0.69 5968995.51 658253.32 BOSS-GYRO 300.00 0.62 229.69 299.99 235.61 -0.96 -1.31 5968995.01 658252.71 BOSS-GYRO 400.00 0.52 216.60 399.99 335.61 -1.68 -1.99 5968994.28 658252:04 BOSS-GYRO 500.00 0.52 192.89 499.99 435.61 -2.48 -2.36 5968993.47 658251.69 BOSS-GYRO 600.00 0.93 199.69 599.98 535.60 -3.69 -2.74 5968992.26 658251.34 BOSS-GYRO 700.00 0.93 200.60 699.96 635.58 -5.21 -3.30 5968990.72 658250.81 BOSS-GYRO 800.00 0.45 197.69 799.96 735.58 -6.35 -3.70 5968989.58 658250.43 BOSS-GYRO 900.00 0.42 195.79 899.95 835.57 -7.07 -3.92 5968988.85 658250.23 BOSS-GYRO 1000.00 0.10 229.69 999.95 935.57 -7.48 -4.09 5968988.44 658250.07 BOSS-GYRO 1100.00 0.10 206.79 1099.95 1035.57 -7.62 -4.19 5968988.30 658249.97 BOSS-GYRO 1200.00 0.15 181.60 1199.95 1135.57 -7.82 -4.24 5968988.09 658249.93 BOSS-GYRO 1300.00 0.25 162.50 1299.95 1235.57 -8.16 -4.17 5968987.75 658250.00 BOSS-GYRO 1400.00 0.55 162.40 1399.95 1335.57 -8.83 -3.96 5968987.09 658250.22 BOSS-GYRO 1500.00 0.63 161.81 1499.94 1435.56 -9.81 -3.65 5968986.12 658250.56 BOSS-GYRO 1600.00 0.72 162.70 1599.94 1535.56 -10.93 -3.29 5968985.00 658250.94 BOSS-GYRO 1700.00 0.52 167.90 1699.93 1635.55 -11.97 -3.01 5968983.97 658251.25 BOSS-GYRO 1800.00 0.55 205.39 1799.93 1735.55 -12.85 -3.12 5968983.09 658251.15 BOSS-GYRO 1900.00 0.67 208.50 1899.92 1835.54 -13.80 -3.60 5968982.13 658250.69 BOSS-GYRO 2000.00 0.48 209.39 1999.92 1935.54 -14.68 -4.09 5968981.24 658250.22 BOSS-GYRO 2100.00 0.33 237.29 2099.91 2035.53 -15.20 -4.53 5968980.71 658249.79 BOSS-GYRO 2200.00 0.40 228.10 2199.91 2135.53 -15.59 -5.04 5968980.31 658249.29 BOSS-GYRO 2300.00 0.50 229.39 2299.91 2235.53 -16.10 -5.63 5968979.78 658248.71 BOSS-GYRO 2400.00 0.37 217.69 2399.91 2335.53 -16.64 -6.16 5968979.23 658248.20 BOSS-GYRO 2500.00 0.32 225.79 2499.90 2435.52 -17.09 -6.55 5968978.77 658247.81 BOSS-GYRO 2600.00 0.40 335.30 2599.90 2535.52 -16.97 -6.90 5968978.89 658247.46 BOSS-GYRO 2700.00 0.33 13.39 2699.90 2635.52 -16.37 -6.98 5968979.48 658247.37 BOSS-GYRO 2800.00 0.93 101.00 2799.90 2735.52 -16.25 -6.12 5968979.63 658248.23 BOSS-GYRO Halliburton Company Survey Report __ Company: BP Amoco Date: 3/1 412 0 06 Time: 10:49:43 Page: 2 Nield: Prudhoe Bay Co-ordinate(NE) Reference: Weit'G-06, True North Site: PB G Pad Vertical (TVU) Reference: 9:06 4/23/1979 00:00 64.4 I Well: G-06 Section (VS) Reference: Weil (O.OON,O.OOE,109.36Azi) Wellpath: G-06A Survey Calculation Method: Minimum Curvature Ub: Oracle Survey ftll IttdCl~g Azdi 9 fftU SysftVll NftS Eft Mft N Mft E "foul 2900.00 3.47 99.50 2899.81 2835.43 -16.90 -2.33 5968979.05 658252.02 BOSS-GYRO 3000.00 6.30 121.11 2999.45 2935.07 -20.24 5.35 5968975.88 658259.78 BOSS-GYRO 3100.00 9.12 115.81 3098.54 3034.16 -26.53 17.19 5968969.84 658271.74 BOSS-GYRO 3200.00 10.63 121.20 3197.05 3132.67 -34.76 32.21 5968961.93 658286.93 BOSS-GYRO 3300.00 11.90 123.10 3295.12 3230.74 -45.16 48.74 5968951.88 658303.68 BOSS-GYRO 3400.00 13.38 124.81 3392.70 3328.32 -57.40 66.88 5968940.03 658322.07 BOSS-GYRO 3500.00 15.68 126.00 3489.49 3425.11 -71.95 87.31 5968925.91 658342.80 BOSS-GYRO 3600.00 17.78 125.61 3585.26 3520.88 -88.79 110.66 5968909.58 658366.50 BOSS-GYRO 3700.00 18.95 128.20 3680.16 3615.78 -107.72 135.83 5968891.18 658392.06 BOSS-GYRO 3800.00 19.68 122.31 3774.54 3710.16 -126.76 162.83 5968872.71 658419.45 BOSS-GYRO 3900.00 21.38 120.11 3868.19 3803.81 -144.91 192.83 5968855.20 658449.83 BOSS-GYRO 4000.00 22.98 121.20 3960.79 3896.41 -164.16 225.30 5968836.64 658482.69 BOSS-GYRO 4100.00 24.00 120.50 4052.50 3988.12 -184.60 259.52 5968816.93 658517.33 BOSS-GYRO 4200.00 25.03 121.00 4143.48 4079.10 -205.82 295.18 5968796.47 658553.43 BOSS-GYRO 4300.00 25.12 121.50 4234.06 4169.68 -227.80 331.41 5968775.25 658590.11 BOSS-GYRO 4400.00 25.03 120.10 4324.64 4260.26 -249.50 367.81 5968754.33 658626.96 BOSS-GYRO 4500.00 24.85 121.50 4415.31 4350.93 -271.09 404.02 5968733.51 658663.62 BOSS-GYRO 4600.00 24.85 121.61 4506.05 4441.67 -293.08 439.84 596871228 658699.88 BOSS-GYRO 4700.00 24.77 121.70 4596.82 4532.44 -315.10 475.55 5968691.02 658736.06 BOSS-GYRO 4800.00 24.37 122.61 4687.77 4623.39 -337.23 510.76 5968669.64 658771.72 BOSS-GYRO 4900.00 24.32 122.31 4778.88 4714.50 -359.36 545.54 5968648.25 658806.95 BOSS-GYRO 5000.00 24.67 122.11 4869.88 4805.50 -381.45 580.62 5968626.90 658842.49 BOSS-GYRO 5100.00 24.77 122.70 4960.71 4896.33 -403.87 615.93 5968605.24 658878.26 BOSS-GYRO 5200.00 25.20 123.11 5051.35 4986.97 -426.81 651.39 5968583.05 658914.19 BOSS-GYRO 5300.00 25.80 123.70 5141.61 5077.23 -450.52 687.32 5968560.11 658950.62 BOSS-GYRO 5400.00 25.85 124.31 5231.62 5167.24 -474.88 723.44 5968536.52 658987.23 BOSS-GYRO 5500.00 26.07 124.70 5321.53 5257.15 -499.68 759.51 5968512.49 659023.82 BOSS-GYRO 5600.00 2622 124.50 5411.30 5346.92 -524.70 795.78 5968488.24 659060.61 BOSS-GYRO 5700.00 26.52 124.50 5500.90 5436.52 -549.86 832.38 5968463.86 659097.73 BOSS-GYRO 5800.00 26.55 124.70 5590.36 5525.98 -575.22 869.16 5968439.27 659135.03 BOSS-GYRO 5900.00 26.70 124.81 5679.76 5615.38 -600.77 905.98 5968414.51 659172.38 BOSS-GYRO 6000.00 26.75 124.81 5769.08 5704.70 -626.44 942.90 5968389.62 659209.83 BOSS-GYRO 6100.00 26.78 125.61 5858.36 5793.98 -652.41 979.69 5968364.44 659247.16 BOSS-GYRO 6200.00 27.08 124.50 5947.52 5883.14 -678.42 1016.77 5968339.22 659284.77 BOSS-GYRO 6300.00 27.13 123.81 6036.54 5972.16 -704.00 1054.47 5968314.44 659323.00 BOSS-GYRO 6400.00 26.95 124.61 6125.61 6061.23 -729.56 1092.07 5968289.69 659361.13 BOSS-GYRO 6500.00 26.77 124.00 6214.82 6150.44 -755.02 1129.39 5968265.02 659398.97 BOSS-GYRO 6600.00 26.25 124.11 6304.30 6239.92 -780.01 1166.37 5968240.81 659436.47 BOSS-GYRO 6700.00 25.87 124.31 6394.14 6329.76 -804.71 1202.70 5968216.88 659473.31 BOSS-GYRO 6800.00 25.52 124.70 6484.25 6419.87 -829.27 1238.43 5968193.08 659509.55 BOSS-GYRO 6900.00 25.20 124.31 6574.61 6510.23 -853.54 1273.72 5968169.57 659545.35 BOSS-GYRO 7000.00 24.75 123.70 6665.26 6600.88 -877.15 1308.72 5968146.70 659580.83 BOSS-GYRO 7100.00 24.10 124.70 6756.31 6691.93 -900.39 1342.93 5968124.19 659615.51 BOSS-GYRO 7200.00 23.45 124.81 6847.82 6783.44 -923.37 1376.05 5968101.92 659649.11 BOSS-GYRO 7300.00 22.85 125.50 6939.77 6875.39 -946.00 1408.19 5968079.97 659681.72 BOSS-GYRO 7400.00 22.22 125.50 7032.14 6967.76 -968.26 1439.39 5968058.37 659713.38 BOSS-GYRO 7500.00 21.82 125.10 7124.84 7060.46 -989.93 1469.99 5968037.36 659744.43 BOSS-GYRO 7600.00 21.35 124.81 7217.83 7153.45 -1011.00 1500.14 5968016.92 659775.02 BOSS-GYRO 7700.00 20.68 125.20 7311.18 7246.80 -1031.57 1529.52 5967996.98 659804.82 BOSS-GYRO 7800.00 20.10 125.11 7404.91 7340.53 -1051.64 1558.00 5967977.52 659833.72 BOSS-GYRO 7900.00 19.47 125.41 7499.01 7434.63 -1071.17 1585.64 5967958.57 659861.76 BOSS-GYRO 8000.00 19.05 127.41 7593.41 7529.03 -1090.75 1612.19 5967939.57 659888.71 BOSS-GYRO Halliburton Company Survey Report Company:. BP Amoco Date: 3/14/2006 Time: 10:49:43 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G-06, True North Site: PB G Pad Vertical (TVD) Reference: 9:06 4/23/1979 00:00 64.4 Well: G-06 Section (VS) Reference: Well (O.OON,O.OOE,109.36Azi) i Wellpath: G-06A Survey Calculation Method:. Minimum Curvature Db: Oracle Survev MD Incl Azim TVD Sys TVD N/S E/W' MapN MapE Tool ft deg deg ft ft ft ft ft ft 8100.00 20.07 128.11 7687.64 7623.26 -1111.25 1638.65 5967919.63 659915.60 BOSS-GYRO 8200.00 20.82 130.70 7781.34 7716.96 -1133.43 1665.63 5967898.02 659943.04 BOSS-GYRO 8300.00 20.92 133.50 7874.78 7810.40 -1157.31 1692.05 5967874.71 659969.95 BOSS-GYRO 8400.00 22.47 136.90 7967.70 7903.32 -1183.55 1718.06 5967849.02 659996.51 BOSS-GYRO 8500.00 24.00 140.81 8059.59 7995.21 -1213.27 1743.97 5967819.86 660023.04 BOSS-GYRO 8600.00 24.25 142.61 8150.86 8086.48 -1245.35 1769.29 5967788.32 660049.03 BOSS-GYRO 8700.00 24.35 144.81 8242.00 8177.62 -1278.52 1793.65 5967755.68 660074.07 BOSS-GYRO 8800.00 26.17 147.20 8332.44 8268.06 -1313.90 1817.47 5967720.80 660098.64 BOSS-GYRO 8900.00 26.87 149.61 8421.92 8357.54 -1351.94 1840.85 5967683.28 660122.82 BOSS-GYRO 9000.00 26.62 149.90 8511.22 8446.84 -1390.81 1863.52 5967644.89 660146.30 BOSS-GYRO 9100.00 26.15 149.50 8600.80 8536.42 -1429.18 1885.94 5967607.00 660169.52 BOSS-GYRO 9200.00 25.82 149.81 8690.69 8626.31 -1466.99 1908.08 5967569.67 660192.45 BOSS-GYRO 9300.00 24.88 149.61 8781.06 8716.68 -1503.96 1929.67 5967533.17 660214.81 BOSS-GYRO 9332.00 24.60 149.73 8810.13 8745.75 -1515.52 1936.43 5967521.75 660221.82 MWD 9369.81 31.45 149.64 8843.48 8779.10 -1530.85 1945.40 5967506.62 660231.10 MWD 9400.05 37.00 149.59 8868.48 8804.10 -1545.51 1954.00 5967492.14 .660240.01 MWD 9446.00 45.13 149.54 8903.09 8838.71 -1571.52 1969.27 5967466.47 660255.83 MWD 9486.94 51.37 138.29 8930.39 8866.01 -1596.03 1987.32 5967442.34 660274.39 MWD 9514.78 53.83 131.06 8947.31 8882.93 -1611.54 2003.04 5967427.17 660290.43 MWD 9547.11 57.36 124.36 8965.59 8901.21 -1627.81 2024.14 5967411.34 660311.87 MWD 9589.43 64.93 118.73 8986.01 8921.63 -1647.12 2055.72 5967392.71 660343.85 MWD 9628.60 70.13 112.91 9000.99 8936.61 -1662.84 2088.29 5967377.68 660376.74 MWD 9662.54 75.33 114.50 9011.06 8946.68 -1675.87 2117.95 5967365.28 660406.67 MWD 9702.02 84.14 118.55 9018.09 8953.71 -1693.22 2152.66 5967348.67 660441.73 MWD 9733.00 91.63 124.01 9019.23 8954.85 -1709.28 2179.09 5967333.17 660468.49 MWD 9766.47 94.18 127.36 9017.54 8953.16 -1728.77 2206.23 5967314.25 660496.04 MWD 9802.53 91.01 122.07 9015.90 8951.52 -1749.28 2235.83 5967294.38 660526.06 MWD 9838.75 92.95 119.25 9014.65 8950.27 -1767.73 2266.97 5967276.59 660557.57 MWD 9870.38 93.30 116.79 9012.93 8948.55 -1782.57 2294.84 5967262.34 660585.75 MWD 9903.60 92.60 112.38 9011.22 8946.84 -1796.37 2325.01 5967249.18 660616.20 MWD 9943.70 91.63 109.39 9009.74 8945.36 -1810.65 2362.44 5967235.69 660653.92 MWD 9977.00 92.07 104.81 9008.66 8944.28 -1820.43 2394.24 5967226.58 660685.92 MWD 10010.52 92.69 99.52 9007.27 8942.89 -1827.49 2426.97 5967220.22 660718.79 MWD 10040.30 92.51 95.99 9005.92 8941.54 -1831.50 2456.44 5967216.83 660748.34 MWD 10071.96 93.30 91.77 9004.31 8939.93 -1833.64 2487.98 5967215.36 660779.91 MWD 10101.28 95.86 88.77 9001.97 8937.59 -1833.78 2517.20 5967215.83 660809.13 MWD 10131.73 97.00 92.82 8998.56 8934.18 -1834.20 2547.45 5967216.05 660839.38 MWD 10162.68 96.74 97.76 8994.85 8930.47 -1837.03 2578.04 5967213.87 660870.01 MWD 10192.13 95.33 101.28 8991.76 8927.38 -1841.88 2606.92 5967209.63 660898.98 MWD 10224.81 92.86 106.04 8989.42 8925.04 -1849.57 2638.58 5967202.60 660930.80 MWD 10261.99 92.51 101.63 8987.68 8923.30 -1858.45 2674.63 5967194.49 660967.03 MWD 10294.97 91.89 99.70 8986.41 8922.03 -1864.55 2707.02 5967189.07 660999.53 MWD 10320.94 90.48 98.64 8985.88 8921.50 -1868.69 2732.65 5967185.48 661025.24 MWD 10350.51 90.31 98.99 8985.67 8921.29 -1873.22 2761.87 5967181.56 661054.55 MWD 10382.63 89.60 97.05 8985.70 8921.32 -1877.70 2793.67 5967177.76 661086.44 MWD 10425.70 87.58 94.58 8986.76 8922.38 -1882.06 2836.50 5967174.30 661129.35 MWD 10455.69 88.99 89.83 8987.66 8923.28 -1883.22 2866.45 5967173.78 661159.31 MWD 10490.30 88.99 85.60 8988.27 8923.89 -1881.84 2901.02 5967175.88 661193.84 MWD 10525.84 91.45 82.95 8988.13 8923.75 -1878.29 2936.37 5967180.17 661229.11 MWD 10555.32 91.01 81.55 8987.50 8923.12 -1874.32 2965.58 5967184.76 661258.22 MWD 10587.11 89.52 75.91 8987.35 8922.97 -1868.11 2996.74 5967191.63 661289.25 MWD 10621.28 89.96 72.02 8987.51 8923.13 -1858.67 3029.57 5967201.75 661321.87 MWD 10659.98 90.48 69.03 8987.36 8922.98 -1845.77 3066.05 5967215.42 661358.07 MWD Halliburton Company Survey Report i Company: BP Amoco Field: Prudhoe Bay Site: PB G Pad Well: G-06 WeIlpath: G-06A Date: 3/14/2006 't'ime: 10:49:43 Page: 4 Co-ordinate(NE)'Reference: Well: G-06, True North Vertical (TVD) Reference: 9:06 4!23/1979 00:00 64.4 Section (VS) Reference: Well (O.OON,O.OOE,109.36Azi) Survev Calculation Method: Minimum Curvature Db: Oracle ~~ ~ Sw•oe~ - -- -_ - - - - - - _ MD Inc! Azim TVD Sys TVD N/S J F/W __ _ MapN --- - - _ MapE _. Tool ft deg deg ft ft ft ft ft ft 10689. 56 91. 37 70. 97 8986. 88 8922. 50 -1835 .65 3093 .84 5967226. 12 661385. 64 MWD 10726. 21 91. 10 78. 90 8986. 09 8921. 71 -1826 .14 3129 .20 5967236. 38 661420. 78 MWD 10757. 71 89. 78 83. 84 8985. 85 8921. 47 -1821 .41 3160 .33 5967241. 76 661451. 81 MWD 10792. 37 87. 22 87. 89 8986. 75 8922. 37 -1818 .92 3194 .88 5967244. 98 661486. 29 MWD 10830. 25 86. 87 87. 54 8988. 71 8924. 33 -1817 .41 3232 .68 5967247. 29 661524. 05 MWD 10862. 50 87. 75 81. 90 8990. 22 8925. 84 -1814 .44 3264 .74 5967250. 93 661556. 04 MWD 10905. 40 87. 67 77. 14 8991. 94 8927. 56 -1806 .65 3306 .88 5967259. 61 661598. 00 MWD 10938 .62 88. 02 73. 44 8993. 19 8928. 81 -1798 .22 3338 .98 5967268. 71 661629. 92 MWD 10969 .48 90. 75 72. 03 8993. 52 8929. 14 -1789 .06 3368 .45 5967278. 49 661659. 18 MWD 11001. 47 90. 84 68. 86 8993. 07 8928. 69 -1778 .36 3398 .59 5967289. 82 661689. 08 MWD 11032 .78 87. 75 66. 21 8993. 46 8929. 08 -1766 .40 3427 .51 5967302. 39 661717. 75 MWD 11061 .18 89. 87 60. 58 8994. 05 8929. 67 -1753 .69 3452 .89 5967315. 63 661742. 85 MWD 11094 .18 90. 93 60. 75 8993. 82 8929. 44 -1737 .52 3481 .65 5967332. 40 661771. 27 MWD 11129 .34 88. 02 57. 40 8994. 14 8929. 76 -1719 .46 3511 .81 5967351. 09 661801. 03 MWD 11175 .12 88. 19 51. 06 8995. 66 8931. 28 -1692 .73 3548 .91 5967378. 60 661837. 56 MWD 11205 .37 88. 02 46. 66 8996. 66 8932. 28 -1672 .84 3571 .68 5967398. 96 661859. 90 MWD 11240 .18 90. 57 39. 96 8997. 09 8932. 71 -1647 .53 3595 .54 5967424. 77 661883. 22 MWD 11280 .18 93. 22 46. 30 8995. 76 8931. 38 -1618 .37 3622 .85 5967454. 49 661909. 91 MWD 11310 .53 91. 28 47. 89 8994. 57 8930. 19 -1597 .72 3645 .06 5967475. 60 661931. 68 MWD 11351 .85 91. 98 51. 24 8993. 39 8929. 01 -1570 .94 3676 .49 5967503. 04 661962. 54 MWD 11381. 91 93. 04 55. 11 8992. 08 8927. 70 -1552 .94 3700 .53 5967521. 54 661986. 18 MWD 11436 .45 91. 98 49. 30 8989. 69 8925. 31 -1519 .56 3743 .57 5967555. 81 662028. 50 MWD 11478 .55 89. 25 50. 88 8989. 23 8924. 85 -1492 .56 3775 .85 5967583. 49 662060. 21 MWD 11513 .15 86. 08 49. 12 8990. 64 8926. 26 -1470 .34 3802 .33 5967606. 26 662086. 22 MWD 11547 .18 85. 20 46. 48 8993. 23 8928. 85 -1447 .55 3827 .47 5967629. 58 662110. 86 MWD 11574 .91 87. 84 39. 96 8994. 92 8930. 54 -1427 .39 3846 .41 5967650. 13 662129. 37 MWD 11601 .28 90. 04 38. 37 8995. 40 8931. 02 -1406 .95 3863 .06 5967670. 91 662145. 59 MWD 11627 .86 93. 13 34. 14 8994. 67 8930. 29 -1385 .53 3878 .76 5967692. 66 662160. 84 MWD 11650 .00 93. 13 34. 14 8993. 46 8929. 08 -1367 .24 3891 .17 5967711. 2.1 662172. 85 PROJECTED ,TREE _ WELLHEAD= 13-5/8" -5M-F ACTUATOR = r, KB. ELEV = 64.38' BF ELEV = 36.1' KOP = Max Angle = 3200' 97 @ 10132' _. Datum MD = __ 9395' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 2.36" @ 8607' LOGATOR SUB w/BKR SEAL ASSY TOP OF 7" LNR 3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.992" ~ 8658' 9-5i8" CSG, 47#, L-80, ID = 8.681" 8754' TOP OF WHIPSTOCK (02147106) 9335' RA TAG 9344' CIBP (02/47/06) 9400' I S OTE: SLOW I~t=A€~ IN 9-518" CAS[i~G S 8068-8'! 34~', 70° @ 9629' 2092' 4-1/2" SSSV OTIS LANDING NIP, ID = 3.813" GAS LIFT MA NDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3071 3005 9 OTIS DMY RA 01/13/95 4 4322 4189 25 OTIS DMY RA 01/13/95 3 5885 5602 27 OTIS DMY RA 09/90 2 7764 7306 20 OTIS DMY RA 09/90 1 8030 7557 19 OTIS DMY RR 09!90 3356' -+ 9-5/8" DV PKR $05$' 4-1/2" PARKER SWS NIP, ID = 3.813" $061' 9-5/8" x 4-1/2" TIW HBBP-R RET PKR, ID = 4.00" 8562' I~TOP OF CEMEM (7" LNR X 4-1/2" TBG} (02!16/06} $596' 3.625" BKR DEPLOY SLV, ID = 3.00" 8602' 4-1/2" BKR KB LNR TOP PKR, ID = 2.441" 8607' 6" BKR SEAL ASSY w / LOC SUB, ID = 2.360" 8609' 3.70" BKR BOT LNR DEPLOY SLV, ID = 3.00" $62$' 3-112" HES X NIP, ID = 2.81 $65$' 1 3-1(2" X 3-3(16" XO, ID = 2.992" MILLOUT WINDOW {G-06A) 9335' - 9347' 3-3116" X 2-7/8" XO, ID = 2.441" I~ I4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-~ 9520' PBTD 9647' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9700' PERFORATION SUMMARY REF LOG: SWS MCNL/GR/CCL ON 02/25/06 ANGLE AT TOP PERF: 97 @ 10140' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPI~USOZ DATE 2" 6 10140 - 10340 O 02/26/06 2" 6 10370 - 10540 O 02!26!06 2" 6 10580 - 10640 O 02/26106 2" 6 10830 - 11250 O 02/26/06 2" 6 11480 - 11520 O 02/26/06 3-3/16" LNR 6.2#, L-80 TCII, ( 9716' .0076 bpf, ID = 2.80" PBTD ~ 11614' ~- 2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11650' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/21!79 ORIGINAL COMPLEfION 09/29190 RIG WORKOVER 02/28106. NORDICI CTD SIDETRACK (G-06A) 03/18!06 ???%TLI-I DRLGDRAFTCORRECTION PRUDHOE BAY UNff WELL: G-06A PERMff No: ®2060120 API No: 50-029-20358-01 SEC 12, T11 N, R13E, 2627' FSL & 1975' FEl BP Exploration (Ataska) 6" CIW MC SSH G -0 6A OTIS ~ " • 01-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well G-06A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,332.00' MD Window /Kickoff Survey: 11,627.86' MD (if applicable) Projected Survey: 11,650.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~~ ~ ~j Date ~ Signed /'' Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • ~;~~~~ "°~ ~ ~~~~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~ OIL ~ t7[a~7 333 W. 7TM AVENUE, SUITE 100 CO1~T5ERQA'1`IO1Q COrIIrII551O1~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Robert Caughlin FAx (so7> 27sasa2 CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay, PBU G-06A BP Exploration (Alaska), Inc. Permit No: 206-012 Surface Location: 2653' FNL, 1974' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 4131' FNL, 1842' FWL, SEC. 07, T11N, R14E, UM Dear Mr. Caughlin: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, .- ,~°' Daniel T. Seamount Jr. Commissioner DATED this27~ay of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~VGI`'V G~ STATE OF ALASKA ALASKA AND GAS CONSERVATION CO SSION JAN 2 4 2006 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-06A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11525 TVD 8932ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2653' FNL 1974' FEL SEC 12 T11 N R13E UM 7. Property Designation:. ADL 028304 Pool , , , , . , Top of Productive Horizon: 4050' FNL, 108' FEL, SEC. 12, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud te: February 9 06 Total Depth: 4131' FNL, 1842' FWL, SEC. 07, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,800' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 658254 - 5968996 Zone- ASP4 10. KB Elevation (Height above GL): 64.3g~ feet 15. Distance to Nearest Well Within Pool 571' 16. Deviated Wells: Kickoff Depth: 9330 feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3100 Surface: 2220 r 18. asing rogram: Size S lions pacifies Setting :Depth To Bottom uantity o ement cf. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-3/16' x 2-7/8° 6.2# / 6.4# L-80 CII / ST 2325' 9200' 8626' 11525' 8932' 157 cu ft Class 'G' i g, PRESENT-WELL. CONDITION SUMM ARY (To be completed for Aedrill AND Re-entry Operations) Total Depth MD (ft): 9701 Total Depth TVD (ft): 9149 Plugs (measured): None Effective Depth MD (ft): 9647 Effective Depth TVD (ft): 9099 Junk (measured): None Casing Len h Size Cement Volume MD TVD r on r 110' 20" x 30" 79 cu ft Permafrost 110' 110' 2698' 13-3/8" 241 cu ft Arcticset 2698' 2698' 1 8754' 9-5/8" 1250 cu ft Class 'G', 140 cu ft Arcticset 8754' 8291' Pr i in 1472' 7" 12 cu ft Class 'G' 8228' - 9700' 7808' - 9148' Perforation Depth MD (ft): 9478' - 9595' Perforation Depth TVD (ft): 8944' - 9051' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Laughlin, a4o-0684 Printed Name Robert C ughlin Title CT Drilling Engineer Ted tagg, 56a-4694 Prepared By Name/NUmber: Si nat e- :;~:.;"-~ Phone 440-0684 Date 2Lr- ,,,,,_o~ Terrie Hubble, 564-4628 . __ _ Commission Use Only Permit To Drill Number: 2 - 2 API Number: 50- 029-20358-01-00 Permit Approval Date: ..~ ~~° See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~_ o Mud Log Required ~ ! Yes~No Hydrogen Sulfide Measures Yes ~ No Directional Survey Required Yes ^ No other: T,P.St` ~o I~ C f -0 3So o ~ 5,~; . APPROVED BY / ~~ "7~~ A roved B ~ `~" THE COMMISSION Date Form 10-401 Revised 06/2004 'k,~ '. ~ ~.,~ ~ - Submit In Duplicate BP Prudhoe Bay G-06A CTD Sidetrack CTD Sidetrack Summary Rig Work: / 1) MIRU Nordic 1 and test BOPE to 250 psi low and 3500 psi high. 2) Mill 3.8" window through two strings in Zone 2 at 9330' MD (8744ss). 3) Drill 4-1/8" open hole, 2,195' sidetrack into Zone 1B target with TD at 11,525'MD (8932ss). ~ 4) Run solid 3-3/16"x2-7/8" liner, cement and test to 2000 psi. ~ 5) Cleanout liner and perforate for production (800 ft of perfs). 6) Freeze protect well and RDMO. Mud Program: • Well kill: 8.5 ppg m • Milling/drilling: .6 pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3-3/l6", 6.2#, L-80, TCII to 10,000' x 2-7/8", 6.4#, L-80, STL to 11,525' fully cemented liner. Top of liner to be at 9, ' MD (8,626'ss). • A minimum f 28 is 15.8 ppg cement will be used for liner cementing. Note: The very short liner lap is designe provide room for a future sidetrack. A retrievable liner top packer will be installed to seal the liner lap and cover squeeze hole in the 4'h" tubing. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 92 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 13,800 ft. • Distance to nearest well within pool - 571 ft. (G-26B) Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. MCNL log will be run across the cemented liner. Hazards • The maximum recorded H2S level on G Pad is 20 ppm (G-29 on 9/3/05).. • Lost circulation risk is below average. Reservoir Pressure • Res. press. is estimated to be 3100 psi at 8800'ss (6.8 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2220 psi. / TREE _ 6" CMJ - --- WELLHEAD - 13-5/8" - -5M -FMC SSH ACTUATOR = OTIS KB. ELEV = 64.38' BF. ELEV..- _ - 36.1' _. w, ~,.m.m KOP = __ ._r~.__...~~. 3200' Max Angle = 27 @ 6300' Datum MD = 9392' Datum ND = 8800' SS -O ~ S SOTE: SLOW LEAK IN 9-5/8" CASING B N 8068-8130'. TAG TD @ 9583' ELMD, GR/CGL 01 /27/91. 2092' 4-1/2" SSSV OTIS LANDING NIP, ID = 3.813" 3356' 1 9-5/8" DV PKR GAS LIFT MANDRELS 13-318" CSG, 72#, N-80, ID = 12.347" ~-j 2698' Minimum ID = 3.725" @ 9516' 4-1/2" OTIS XN NIPPLE ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3071 3005 9 OTIS OMY RA 01!13/95 4 4322 4189 25 OTIS DMY RA 01/13/95 3 5885 5602 27 OTIS DMY RA 09/90 2 7764 7306 20 OTIS DMY RA 09!90 1 8030 7557 19 OTIS DMY RA 09/90 8058' 4-1l2" PARKER SWS NIP, ID = 3.813" 806 9-5/8" x 4-1/2" TNV HBBP-R REf PKR, ID = 4.00" TOP OF 7" LNR ~-j 8228' 9-5/8" CSG, 47#, L-80, ID = 8.681" $754' ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-j 9520' PERFORATION SUMMARY REF LOG: SWS BRCS ON 05/10/79 A NGLE AT TOP PERF: 24 @ 9446' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPWSOZ DATE 3-1/8" 4 9446 - 9454 S 10114/89 3-1/8" 4 9464 - 9478 S 10/14/89 4" 4 9478 - 9482 O 09/27/90 3-3/8" 4 9490 - 9496 O 10/21/89 3-3/8" 4 9518 - 9532 O 10/21!89 3-3/8" 4 9543 - 9548 O 10/17/89 3-3/8" 4 9558 - 9563 O 10!17/89 3-3l8" 4 9570 - 9595 O 10/17/89 PBTD 9647' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9700' 9455' 9467' 9471' 9504' 9508' 9516' 9~20~ DATE REV BY COMMENTS DATE REV BY COMMENTS 05/21/79 ORIGINAL COMPLETION 11/05!05 MOR/TLH TTP PULLED (04104/04) 09/29/90 RIG WORKOV ER 11/04/01 RN/TP CORRECTIONS 03/04/03 DCR/KK PERF CORRECTIONS 11/16/03 TWC/TLH PLUG CORRECTION 01123/04 BJMcL/TLH SLIDING SLV CORRECTION 7" x 4-1/2" TMJ HBB-R RET PKR, ID = 3.875" 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" TOP OF BLAST JOINTS BTM OF BLAST JOINTS 7" x 4-112" TM/ HBBP PERM PKR, ID = 3.875" 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2" TT WLEG ELMD TT LOGGED 12/17/96 PRUDHOE BAY UNff WELL: G-06 PERMIT No: 1790120 API No: 50-029-20358-00 SEC 12, T11N, R13E, 2627' FSL & 1975' FEL BP 6cploration (Alaska) TREE = 6" ViIELLHEAD= 3-5/8"-SM-FMC ACTUATOR = KB. ELEV = 8 BF. ELEV = - -- Max Angle = _ - __- 27-~-E Datum MD = c ~~ s A SA TE SLOW LEAK IN 918" CASING BETWEEN 8068130'. TAGTD ~ 9583' ELM D, ~rcpc:=,~:~~ C~:~ ~~:'~~:~tr~ck GwccLO1rz7~91. 2082' 4-1/2' SSSV OTIS LANDING NIP, ID= 3.813' I 9-5/8" DV PKR I I 13-3/8" CSG, 72*, N-80, ID = 12.347" I TOP OF 7" LNR ~~ 8228' 9-5/8" CSG, 47t, L-80, ID = 8.681' H 8764' Tba Flinch 8~'i"6-°.`'': PERFORATION SUMMARY REF LOG: SWS BRCS ON 05/10/79 ANGLE AT TOP PERF: 24 ~ 9448' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OPWSOZ DATE 3-1/8" 4 9446 -9454 ,,, >~cc~osed 3-1/8" 4 9464 -9478 isolated proposed 4" 4 9478 -9482 isolated proposed 3-3/8" 4 9490 -9496 isolated proposed 3-3/8" 4 9518 -9532 isolated proposed 3-3/8" 4 9543 -9548 isolated proposed 3-3/8" 4 9558 -9563 sclated proposed 3-3/8" 4 9570 -9595 solated proposed ~4-1/2" TBG, 12.6*, L-80, .0152 bpf, ID= 3.958" ~ ~ PBTD N 8847' 7" LNR, 29ie, L-80, .0371 bpf, ID = 8.184' 8700' ST NID TVD DEV TYPE VLV LATCH PORT DATE 5 3071 3005 9 OTIS DMY RA 01 /13/95 4 4322 4189 25 OTIS DAILY RA 01 /13/95 5885 5602 27 OTIS DRAY RA 09/90 2 7764 7306 20 OTIS DAAY RA 09/90 1 8030 7557 19 OTIS DMY RA 09/90 806~~4-1/2" PARKERSWS NIP, ID= 8081' 9-5/8' x 4-1/2" TNV HBBRR R 8890'Liner Top Fkr 9200' lop of 3-3116" Liner 9200' -Lop of cement 9210' 3-1!2" X NIP I~ - 2.613" 10000' H3-3116 x 2-7/8 X-over ~w~{I~STCx:i~ ~- ar~P 9604' 8608' 9616' 8620' 9620' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/21/79 ORIGINAL COMPLETION 11/05/05 MOR/TLH TTP PULLED (04/04/04) 09/29/90 RIG WORKOVF32 11/04/01 RN/TP CORRECTIONS 03/04/03 DCR/KK PERF CORRECTIONS 11/16/03 TWCITLH PLUG CORRECTION 01/23/04 BJMcLlTLH SLIDING SLV OORRECTION 9400' ' I i ID = 4.00' 7" x 4-1/2' TNV HBB-R RET PKR, ID = 3.875" 4-112" OTIS XA SLIDING SLV, ID = 3.813" TOP OF BLAST JOINTS BTM OF BLAST JOINTS 7" x 4-1/2" TNV HBBPPERM PKR, ID= 3.875' 4-1/2' OTIS XN NP, ID= 3.725' 4-1/2" TT WLE3G ELMD TT LOGGED 12/17!98 PRUDHOE BAY UNlT WELL: G-O6 PERMIT No: 1790120 API No: 50-029-20358-00 SEC 12, T11 N, R13E, 262T FSL 8 1975' FEL E9P Exploration (Alaska) • • a -T----,-----~-~-- - _ ~ =a::=:_~;_: §§e C P eA O 7 o e e ~ ~ ., } 4 ~ A g~~8a ~ ~~~~~E~iE'E 4 i!! ~ ~ ~ ~ ° €~~i~R~ ~~ ~ ~~5avporqa~t .~ Eiif~~bx i ! i I ~ E ! ~ ~ ~ $ ~ ~ _...., • • a ~ ~ ~e~ 5 ~ ~i ~ ~ s ~ ~~s ~ }x$g n i 9 y m m Z ~a ~~g~ ~ ~~ ~~ ~ ~~~ g Q~ m N ~"~" .. ~` . 8 _: .- ~ ` $ f-a= _~.... i .- } ~ .... _ N a `. ~ ~ +• r ~ m .. ,_ m ~ ~- f V ~- ~ ~ ~-----'.--~-~-ti a _~ ~- c ;i ~ ~ ~ ,. +_ ~: - ~ t: . F $ ~ ~ __:.. t - - r- :r: - N . a ._ '~- f: t::: n I :,95If ~~-_ - 8 2$~- __ r '- (Q~ ~ f 01 ~ t' ~ g ~ ~. r + , r r ~ ~ ~ ~~~ ~ C 7 S ~lCL g Xi r ~_` ~ - 1 1 1 f ~ ~ ~~~~t~i~~G~~i N m ~ O ~o § _: m~ G (9a a2 I ^ ~ _ 0 ~ ~ g~~~d g to gg}} :} q; 8 ~ ~~` F t 1 - d_ „~ cc a ucs ~ f f ~ a ------- - ~ ~ ~ ~ pap ~ ~~s ! ! €~~I~~~~il~i~ i ~ ~--;--- -~-:~--:-t--~--~- --- ~'~ ~~ ~ > ~ ~~~ ~ ~~~~ii~is~~l~~ ---- ._._ _ _ -.8 i snyyogaaaoooa f .i:~^ ' I~iM00L1 (+)4i~g1~-14i~oS I { f _ ~-- ~ ~# + ~~ ..... - ~ ' ...._ ~ ~: c .. ~ h C ~ i . t V $ 1•--F•--- 1 V ~ F f f i' t f f f t~ f ~ ~ 1 i __J '/ _: V ~ ~. t __7____ ~. ~ . .- ~ ...E ~ ..:_ ~ r ~ a r _ -: - -~ #--,-- , :.~ .~ l -t ~ - .. -. 1 l t + ~ ~.. __.. .._ fy 1 - 1 C .. ~ f .. ~ ._ ~ - S - + ' - l + -: k _. :: ~ ~ . - -_~ j f ::, t.:; :~ , BP Alaska by Baker Hughes INTEQ Planning Report yes INTEQ Compsnyc BP Amoco Date: 1/17/2006 Time: 15:48;10 Pager 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeII: G-06, True North Site: PB G Pad Vertieal,(TVD) Reference: 9 : O6 4/23/1979 00:00 64.4 Well: - G-O6 Sectloa (VS) Reference: WeU (O.OON,O.OOE,111. 19Azi) Wellpath: ,Plana, G-06A Sarvey Caknlatlon Method:. Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Msp Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: WeII Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Positlou: Northing: 5966832. 87 ft Latltnde: 70 18 58.211 N Froro: Map Eastlng: 656301. 39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-06 Slot Name: O6 G-06 Wetl Position: +N/-S 2122.16 ft Northing: 59&8996. 00 ft Latitude: 70 19 19.080 N +E/-W 1997.37 ft Eastiug : 658254. 00 ft Longitude: 148 43 0.721 W Positlou Uncertainty: 0.00 ft Wellpath: PIan3, G-O6A Drilled From: G-O6 Tie-0u Depth: 9330.00 ft Current Datum: 9:06 4/23/1979 00:00 Height 64. 38 ft Above System Datnm: Mean Sea Level Maguetlc Data: 1/17/2006 Decliustlon: 24.64 deg Field Strength: 57605 aT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.38 0.00 0.00 111.19 Plan: Plan #3 Date Composed: 1/17/2006 Versfou: 3 Principal: Yes Tied-to: From: Definitive Path Targets .:Map Map <- Latttnde -> <-- Lou ~ -->e Name Descrlptlon TVD +NlS +E/-W Nortbiug Fasting Deg Mio Sec Deg Mln Soc D[p. Dir. ft ft ft ft ft G-O6A Polygon 64.38 -1691,64 2140.96 5967350.00 660430.00 70 19 2.440 N 148 41 58.253 W -Polygon 1 64.38 -1691,64 2140.96 5967350.00 660430.00 70 19 2.440 N 148 41 58.253 W -Polygon 2 64.38 -1777.66 2899.37 5967280.00 661190.00 70 19 1.592 N 148 41 36.125 W -Polygon 3 64.38 -1697,69 3376.20 5967370.00 661665.00 70 19 2.376 N 148 41 22.212 W -Polygon 4 64.38 -1317.87 3864.35 5967760.00 662145.00 70 19 6.109 N 148 41 7.963 W -Polygon 5 64.38 -1414.54 3942.34 5967665.00 662225.00 70 19 5.158 N 148 41 5.689 W -Polygon 6 64.38 -1568.67 3899.07 5967510.00 662185.00 70 19 3.642 N 148 41 6.953 W -Polygon 7 64.38 -1983.85 3190.11 5967080.00 661485.00 70 18 59.562 N 148 41 27.645 W -Polygon 8 64.38 -2005.73 2804.54 5967050.00 661100.00 70 18 59.349 N 148 41 38.895 W -Polygon 9 64.38 -1845.88 2102.70 5967195.00 660395.00 70 19 0.923 N 148 41 59.370 W G-O6A Fault1 64.38 -1825.01 2773.34 5967230.00 661065.00 70 19 1.126 N 148 41 39.803 W -Polygon 1 64.38 -1825.01 2773.34 5967230.00 661065.00 70 19 1.126 N 148 41 39.803 W -Polygon 2 64.38 -1626.84 2862.54 5967430.00 661150.00 70 19 3.075 N 148 41 37.198 W G-O6A Fauk3 64.38 -2039.29 2498.74 5967010.00 660795.00 70 18 59.020 N 148 41 47.817 W -Polygon 1 64.38 -2039.29 2498.74 5967010.00 660795.00 70 18 59.020 N 148 41 47.817 W -Polygon 2 64.38 -2329.03 2482.62 5966720.00 660785.00 70 18 56.170 N 748 41 48.290 W G-O6A Fault2 64.38 -1560.71 2098.71 5967480.00 660385.00 70 19 3.728 N 148 41 59.484 W -Polygon 1 64.38 -1560.71 2098.71 5967480.00 660385.00 70 19 3.728 N 148 41 59.484 W -Polygon 2 64.38 -1652.61 2661.94 5967400.00 660950.00 70 19 2.822 N 148 41 43.052 W G-O6A Fault4 64.38 -1573.02 3393.83 5967495.00 661680.00 70 19 3.602 N 148 41 21.695 W -Polygon 1 64.38 -1573.02 3393.83 5967495.00 661680.00 70 19 3.602 N 148 41 21.695 W -Polygon 2 64.38 -1411.63 3567.29 5967660.00 661850.00 70 19 5.189 N 148 41 16.632 W G-O6A Fauft6 64.38 -1150.43 3987.92 5967930.00 662265.00 70 19 7.755 N 148 41 4.355 W -Polygon 1 64.38 -1150.43 3987.92 5967930.00 662265.00 70 19 7.755 N 148 41 4.355 W -Polygon 2 64.38 -778.63 3670.66 5968295.00 661940.00 70 19 11.414 N 148 41 13.607 W G-06A FauftS 64.38 -1934.13 3441.23 5967135.00 661735.00 70 19 0.050 N 148 41 20.317 W -Polygon 1 64.38 -1934.13 3447.23 5967135.00 661735.00 70 19 0.050 N 148 41 20.317 W -Polygon 2 64.38 -1867.20 3587.69 5967205.00 661880.00 70 19 0.708 N 148 41 16.043 W BP Alaska by Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: '1/17/2006 Time: 15:48:10 Page: 2 Field: Prudhoe Bay Co-0rdinate(NE)Reference: Well: G-06, Tnie North Site: PB G Pad Vertlcai (1'VD) Reference: 9 :06 4/23/1979 Ol):00 64.4 WeU; G-06 Sectbn (VS) Reference: Well (0.00N,0.00E,111. 19Azi) Wellpath: PIan3, G-06A Servey CalcalaHon Method: .Minimum Curvature Db: Oracle Targets Map Map. ~ Latitude -> <-- Longitude -> Name Description TVD +N1S +EL-W Northing Eaating Deg Min Sec Deg Min Sec Dip. ~.. ft ft ft ft ft i G-06A Target3 8990.38 -1479.94 3817.92 5967597.00 662102.00 70 19 4.516 N 148 41 9.320 W G-O6A Target2 8999.38 -1842.21 2829.99 5967214.00 661122.00 70 19 0.957 N 148 41 38.150 W G-06A Targetl 9019.38 -1778.78 2145.13 5967263.00 660436.00 70 19 1.583 N 148 41 58.132 W Annotation MD .LVD ft ft 9300.00 8781.06 TIP 9330.00 8808.31 KOP 9350.00 8826.35 End of 9 Deg/100' DLS 9400.47 8869.71 4 9757.83 9024.97 End of 17 Deg/100' DLS 10057.83 9015.67 6 10207.83 9011.71 7 10457.83 9005.62 8 10632.83 9001.07 9 10947.83 8996.31 10 11047.83 8996.34 11 11272.83 8996.41 12 11525.00 0.00 TD Plan Section Information MD Iael Aim' TVD +N!-S +EI-W DLS $nild Tarn TFO Target ft deg deg R ft ft deg/100ft deg/100ft dsg/100ft .deg 9300.00 24.88 149.61 8781.06 -1503.96 1929.67 0.00 0.00 0.00 0.00 9330.00 24.62 149.72 8808.31 -1514.80 1936.01 0.88 -0.87 0.37 170.01 9350.00 26.42 149.72 8826.35 -1522.24 1940.36 9.00 9.00 0.00 0.00 9400.47 35.00 149.72 8869.71 -1544.48 1953.34 17.00 17.00 0.00 0.00 9757.83 91.90 123.84 9024.97 -1752.27 2174.46 17.00 15.92 -7.24 330.00 10057.83 91.54 87.82 9015.67 -1832.73 2458.22 12.00 -0.12 -12.00 270.00 10207.83 91.46 105.83 9011.71 -1850.49 2606.49 12.00 -0.05 12.00 90.00 10457.83 91.27 75.82 9005.62 -1854.05 2853.54 12.00 -0.08 -12.00 270.00 10632.83 91.68 96.83 9001.07 -1842.89 3027.15 12.00 0.24 12.00 88.60 10947.83 89.98 59.06 8996.31 -1778.26 3329.60 12.00 -0.54 -11.99 267.80 11047.83 89.98 47.06 8996.34 -1718.27 3409.38 12.00 0.00 -12.00 270.00 11272.83 89.98 74.06 8996.41 -1608.70 3603.52 12.00 0.00 12.00 90.00 11525.00 89.99 43.80 8996.47 -1480.05 3817.00 12.00 0.00 -12.00 270.00 Survey MD Inel ; ' Azim `Sys TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft tfeg/100ft ft deg 9300.00 24.88 149.61 8716.68 -1503.96 1929.67 5967533.17 660214.81 0.00 2342.87 0.00 MWD 9330.00 24.62 149.72 8743.93 -1514.80 1936.01 5967522.46 660221.38 0.88 2352.71 170.01 MWD 9350.00 26.42 149.72 8761.97 -1522.24 1940.36 5967515.12 660225.88 9.00 2359.45 0.00 MWD 9375.00 30.67 149.72 8783.93 -1532.56 1946.38 5967504.93 660232.12 17.00 2368.79 0.00 MWD 9400.47 35.00 149.72 8805.33 -1544.48 1953.34 5967493.16 660239.33 17.00 2379.59 0.00 MWD 9425.00 38.66 146.38 8824,96 -1556.94 1961.13 5967480.87 660247.38 17.00 2391.36 330.00 MWD 9450.00 42.47 143.50 8843,95 -1570.23 1970.48 5967467.77 660257.01 17.00 2404.88 332.67 MWO 9475.00 46.35 141.00 8861.80 -1584.06 1981.20 5967454.18 660268.02 17.00 2419.87 334.87 MWD 9500.00 50.27 138.81 8878.43 -1598.33 1993.23 5967440.17 660280.34 17.00 2436.25 336.65 MWD 9525.00 54.23 136.86 8893.73 -1612.97 2006.50 5967425.81 660293.92 17.00 2453.92 338.11 MWD 9550.00 58.22 135.10 8907.63 -1627.90 2020.94 5967411.19 660308.67 17.00 2472.78 339.30 MWD 9575.00 62.23 133.48 8920.04 -1643.05 2036.48 5967396.38 660324.52 17.00 2492.74 340.28 MWD 9588.27 64.37 132.67 8926.00 -1651.14 2045.14 5967388.47 660333.35 17.00 2503.74 341.09 G-06A T 9600.00 66.26 131.97 8930.90 -1658.32 2053.02 5967381.46 660341.38 17.00 2513.68 341.45 MWD 9610.55 67.97 131.37 8935.00 -1664.78 2060.28 5967375.15 660348.77 17.00 2522.78 341.74 G-O6A T 9625.00 70.30 130.56 8940.15 -1673.63 2070.47 5967366.52 660359.15 17.00 2535.49. 341.98 MWD 9650.00 74.36 129.22 8947.73 -1688.90 2088.75 5967351.64 660377.74 17.00 2558.05 342.27 MWD BP Alaska by Baker Hughes INTEQ Planning Report BAI~R ^ ~s INTEQ Company: BP ArrloCO Date: 1/17/2006 Tlme: 15:48110 Page: 3 Field: Pnidhoe Bay Go-ordioate(NE) Reference: WeU: G-O6. True North Site: PB G Pad Vertlcal (7'VD) Reference: 9 : O6 4/23H979 00:00 64.4 Well: G-06 Seetlo®(VS)Refereace; Weli(O.OON,OOOE,111.19Azi) Wellpatb: PIan3, G-06A Sarvey Calculatlon Meffiod: Minimum Curvature Db: Orade Survey M!D Intl Azim Sys TVD N/S ElVN 1NiipN M#pE DLS V& TFO Tool ft deg deg ft" ft ft ft ft deg/100ft ft deg 9675.00 78.42 127.93 8953.62 -1704.04 2107.74 5967336.90 660397.05 17.00 2581.24 342.67 MWD 9700.00 82.48 126.67 8957.76 -1718.98 2127.35 5967322.38 660416.97 17.00 2604.92 342.98 MWD 9725.00 86.55 125.44 8960.15 -1733.62 2147.47 5967308.17 660437.39 17.00 2628.96 343.19 MWD 9750.00 90.63 124.22 8960.77 -1747.89 2167.98 5967294.33 660458.19 17.00 2653.25 343.30 MWD 9757.83 91.90 123.84 8960.59 -1752.27 2174.46 5967290.09 660464.77 17.00 2660.88 343.33 MWD 9775.00 91.90 121.78 8960.03 -1761.57 2188.89 5967281.10 660479.38 12.00 2677.69 270.00 MWD 9800.00 91.89 118.78 8959.20 -1774.17 2210.46 5967268.96 660501.22 12.00 2702.36 269.93 MWD 9825.00 91.88 115.77 8958.37 -1785.62 2232.67 5967257.98 660523.66 12.00 2727.20 269.83 MWD 9850.00 91.86 112.77 8957.56 -1795.89 2255.44 5967248.20 660546.64 12.00 2752.15 269.73 MWD 9875.00 91.84 109.77 8956.75 -1804.95 2278.72 5967239.63 660570.11 12.00 2777.13 269.64 MWD 9900.00 91.82 106.77 8955.95 -1812.79 2302.45 5967232.29 660593.99 12.00 2802.08 269.54 MWD 9925.00 91.78 103.77 8955.16 -1819.37 2326.55 5967226.22 660618.23 12.00 2826.94 269.44 MWD 9950.00 91.75 100.77 8954.39 -1824.67 2350.97 5967221.43 660642.75 12.00 2851.62 269.35 MWD 9975.00 91.71 97.77 8953.64 -1828.70 2375.63 5967217.93 660667.48 12.00 2876.06 269.26 MWD 10000.00 91.66 94.77 8952.91 -1831.43 2400.46 5967215.73 660692.37 12.00 2900.21 269.17 MWD 10025.00 91.61 91.76 8952.19 -1832.85 2425.41 5967214.83 660717.34 12.00 2923.98 269.08 MWD 10050.00 91.56 88.76 8951.50 -1832.96 2450.40 5967215.24 660742.32 12.00 2947.32 268.99 MWD 10057.83 91.54 87.82 8951.29 -1832.73 2458.22 5967215.64 660750.14 12.00 2954.53 268.91 MWD 10075.00 91.54 89.89 8950.83 -1832.39 2475.38 5967216.34 660767.29 12.00 2970.41 90.00 MWD 10100.00 91.53 92.89 8950.16 -1832.99 2500.36 5967216.27 660792.27 12.00 2993.92 90.06 MWD 10125.00 91.52 95.89 8949.49 -1834.90 2525.27 5967214.88 660817.22 12.00 3017.84 90.14 MWD 10150.00 91.51 98.89 8948.83 -1838.12 2550.06 5967212.19 660842.06 12.00 3042.10 90.22 MWD 10175.00 91.49 101.89 8948.18 -1842.62 2574.63 5967208.20 660866.73 12.00 3066.65 90.29 MWD 10200.00 91.47 104.89 8947.53 -1848.41 2598.94 5967202.93 660891.15 12.00 3091.41 90.37 MWD 10207.83 91.46 105.83 8947.33 -1850.49 2606.49 5967201.02 660898.74 12.00 3099.19 90.45 MWD 10225.00 91.46 103.77 8946.89 -1854.87 2623.09 5967196.98 660915.42 12.00 3116.25 270.00 MWD 10250.00 91.46 100.77 8946.26 -1860.18 2647.50 5967192.19 660939.95 12.00 3140.94 269.95 MWD 10275.00 91.45 97.77 8945.62 -1864.20 2672.17 5967188.69 660964.69 12.00 3165.39 269.87 MWD 10300.00 91.43 94.77 8945.00 -1866.93 2697.01 5967186.48 660989.58 12.00 3189.53 269.79 MWD 10325.00 91.42 91.77 8944.37 -1868.36 2721.96 5967185.59 661014.55 12.00 3213.31 269.72 MWD 10350.00 91.40 88.77 8943.76 -1868.47 2746.95 5967186.00 661039.53 12.00 3236.65 269.64 MWD 10375.00 91.37 85.76 8943.15 -1867.28 2771.91 5967187.71 661064.46 12.00 3259.49 269.57 MWD 10400.00 91.34 82.76 8942.56 -1864.78 2796.77 5967190.74 661089.27 12.00 3281.77 269.50 MWD 10425.00 91.31 79.76 8941.98 -1860.99 2821.47 5967195.05 667113.88 12.00 3303.43 269.43 MWD 10450.00 91.28 76.76 8941.42 -1855.90 2845.94 5967200.65 661138.23 12.00 3324.40 269.36 MWD 10457.83 91.27 75.82 8941.24 -1854.05 2853.54 5967202.66 661145.80 12.00 3330.82 269.29 MWD 10475.00 91.32 77.88 8940.86 -1850.14 2870.26 5967206.92 661162.43 12.00 3345.00 88.60 MWD 10500.00 91.36 80.88 8940.27 -1845.54 2894.82 5967212.04 661186.88 12.00 3366.23 88.65 MWD 10525.00 91.45 83.88 8939.65 -1842.23 2919.59 5967215.87 661211.58 12.00 3388.13 88.72 MWD 10550.00 91.51 86.88 8939.00 -1840.22 2944.50 5967218.41 661236.43 12.00 3410.63 88.79 MWD 10575.00 91.57 89.88 8938.33 -1839.51 2969.48 5967219.64 661261.39 12.00 3433.66 88.87 MWD 10600.00 91.62 92.89 8937.63 -1840.11 2994.46 5967219.56 661286.37 12.00 3457.17 88.95 MWD 10625.00 91.67 95.89 8936.92 -1842.03 3019.37 5967218.18 661311.32 12.00 3481.09 89.03 MWD 10632.83 91.68 96.83 8936.69 -1842.89 3027.15 5967217.48 661319.11 12.00 3488.65 89.12 MWD 10650.00 91.60 94.77 8936.19 -1844.63 3044.22 5967216.10 661336.22 12.00 3505.20 267.80 MWD 10675.00 91.48 91.77 8935.52 -1846.05 3069.17 5967215.21 661361.19 12.00 3528.97 267.74 MWD 10700.00 91.36 88.77 8934.90 -1846.17 3094.16 5967215.62 661386.18 12.00 3552.31 267.66 MWD 10725.00 91.23 85.77 8934.34 -1844.98 3119.12 5967217.33 661411.11 12.00 3575.16 267.59 MWD 10750.00 91.10 82.77 8933.83 -1842.48 3143.99 5967220.35 661435.91 12.00 3597.44 267.52 MWD 10775.00 90.96 79.78 8933.38 -1838.69 3168.69 5967224.66 661460.53 12.00 3619.10 267.46 MWD 10800.00 90.83 76.78 8932.99 -1833.61 3193.17 5967230.26 661484.89 12.00 3640.09 267.40 MWD 10825.00 90.69 73.78 8932.66 -1827.26 3217.34 5967237.11 661508.92 12.00 3660.33 267.36 MWD 10850.00 90.55 70.78 8932.39 -1819.65 3241.15 5967245.22 661532.56 12.00 3679.78 267.32 MWD 10875.00 90.40 67.79 8932.18 -1810.81 3264.53 5967254.55 661555.75 12.00 3698.38 267.28 MWD 10900.00 90.26 64.79 8932.04 -1800.76 3287.42 5967265.08 661578.42 12.00 3716.09 267.26 MWD 10925.00 90.11 61.79 8931.95 -1789.53 3309.75 5967276.79 661600.51 12.00 3732.84 267.24 MWD 10947.83 89.98 59.06 8931.93 -1778.26 3329.60 5967288.47 661620.12 12.00 3747.28 267.23 MWD 10950.00 89.98 58.80 8931.93 -1777.14 3331.46 5967289.63 661621.95 12.00 3748.61 270.00 MWD BP Alaska by Baker Hughes INTEQ Planning Report fBAl~i••^ INTEQ Company: BP Amoco `Date: i/17/2006 Time: 15:48:10 - Page: 4 Field: Prudhoe Bay Co-0rdiuate(NE) Reference: WeIL' G-06, True No~tlt Site: PB G Pad Yertlcal (1'VD) Retereuce: 9:06 4/23/197900:00 64.4 Weil: G-06 Section (VS) Reference: Well (O.OON,O.OOE,111.19Azi) Wellpath: PIen3, G-06A Survey Calwlation Method: Minimum Curvature Db: Orade Survey MD Incl Azim Syt TVD " N!S E/W MapN MapE DLS YS TFO Tool ', ft deg deg ft ft ft ft ft deg/100ft ft deg 10975.00 89.98 55.80 8931.94 -1763.63 3352.50 5967303.57 661642.70 12.00 3763.34 270.00 MWD 11000.00 89.98 52.80 8931.95 -1749.05 3372.80 5967318.58 661662.68 12.00 3776.99 270.00 MWD 11025.00 89.98 49.80 8931.96 -1733.42 3392.30 5967334.62 661681.85 12.00 3789.53 270.00 MWD 11047.83 89.98 47.06 8931.96 -1718.27 3409.38 5967350.12 661698.61 12.00 3799.98 270.00 MWD 11050.00 89.98 47.32 8931.97 -1716.79 3410.97 5967351.63 661700.17 12.00 3800.93 90.00 MWD 11075.00 89.98 50.32 8931.97 -1700.34 3429.79 5967368.48 661718.63 12.00 3812.52 90.00 MWD 11100.00 89.98 53.32 8931.98 -1684.88 3449.44 5967384.34 661737.95 12.00 3825.25 90.00 MWD 11125.00 89.98 56.32 8931.99 -1670.48 3469.87 5967399.17 661758.07 12.00 3839.09 90.00 MWD 11150.00 89.98 59.32 8931.99 -1657.17 3491.02 5967412.93 661778.94 12.00 3854.01 90.00 MWD 11175.00 89.98 62.32 8932.00 -1644.98 3512.85 5967425.57 661800.50 12.00 3869.95 90.00 MWD 11200.00 89.98 65.32 8932.01 -1633.95 3535.28 5967437.07 661822.69 12.00 3886.88 90.00 MWD 11225.00 89.98 68.32 8932.02 -1624.11 3558.26 5967447.39 661845.46 12.00 3904.75 89.99 MWD 11250.00 89.98 71.32 8932.02 -1615.49 3581.72 5967456.51 661868.73 12.00 3923.50 89.99 MWD 11272.83 89.98 74.06 8932.03 -1608.70 3603.52 5967463.76 661890.37 12.00 3941.37 89.99 MWD 11275.00 89.98 73.80 8932.03 -1608.09 3605.60 5967464.40 661892.45 12.00 3943.09 270.00 MWO 11300.00 89.98 70.80 8932.04 -1600.49 3629.42 5967472.50 661916.09 12.00 3962.55 270.00 MWD 11325.00 89.98 67.80 8932.04 -1591.66 3652.80 5967481.83 661939.28 12.00 3981.16 270.00 MWD 11350.00 89.99 64.80 8932.05 -1581.61 3675.69 5967492.36 661961.95 12.00 3998.86 270.00 MWD 11375.00 89.99 61.80 8932.06 -1570.38 3698.02 5967504.06 661984.04 12.00 4015.62 270.00 MWD 11400.00 89.99 58.80 8932.06 -1557.99 3719.73 5967516.90 662005.49 12.00 4031.39 270.00 MWD 11425.00 89.99 55.80 8932.07 -1544.48 3740.77 5967530.84 662026.23 12.00 4046.12 270.00 MWD 11450.00 89.99 52.80 8932.07 -1529.90 3761.07 5967545.85 662046.22 12.00 4059.77 270.00 MWD 11475.00 89.99 49.80 8932.08 -1514.27 3780.57 5967561.89 662065.39 12.00 4072.31 270.01 MWD 11500.00 89.99 46.80 8932.09 -1497.64 3799.24 5967578.91 662083.70 12.00 4083.70 270.01 MWD 11525.00 89.99 43.80 8932.09 -1480.05 3817.00 5967596.86 662101.09 12.00 4093.91 270.01 3.5" • are i. N (_~ of bag Dowell of bag of slips Blind/Shears 2 3/8" combi ram/slips 1 BAG TOTs ~ Mud Cross I I Mud Cross cross of blind/shears variable bore Cipe 31/2"-2 7/13" 2 3/8" combi ram/slips Flow Tee TOTs ~ • TERRIE L RUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 "Mastercard Check" ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF rir~t National-Bank Alaska v Anchorage, AK 99501 MEMO~,~~ ~: 1 2 5 200060~:9914~~~6 2 27~~~ 15561' 0 25 1 89-6/7252 251 DATE ~~"{'V~J S 1(~ , c`b s t TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ -~,%~ Development Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In 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 acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 ___Well Name: PRUDHOE BAY UNIT G-06A _ Program _____ .Well bore seg PTD#:2060120 Company BP EXPLORATtQN_(ALASKA~ INC _ InitiatClass/Type _ -_ l 1_OIL GeoArea $90_ ____~_ Unit 11&50 On1Off Shore On Annular Disposal [] Administration 1 Petmitfeeattached------------------------- ---------------_ Ye~-- ---.--° 2 Lease number appropriate_ - - . _ , _ - . - . Yes - 3 Unique well-name andnumber__-_--.- -------- ------- -------- Yes_- -- - ---- 4 Well located in a_definedpool-__._----_------------- Yes-- --..._ 5 Weil located p[dper distancefro_m-drilling unit_boundary- - _ _ ___ _ _ _ _ _ _ _ _ : < - Yes - _ _ 6 Well located pr_operdistance-from other wells_ - - . _ - _ _ _ : _ - Yes - . - _ _ _ _ _ - 7 Sufficient acreage available in drilling unit _ _ _'- : - _ Yes : - - 8 If deviated, is_wellbore plat_included - _ _ :. - - - Yes - , - - .: _ - - . _ _ - . I 9 Operator only affected party- - - - . - - Yes - - - - - 1 10 Operator has appropriate_bond in force. - - - - _ - - Yes , - _ - _ 11 Pe[mitcan be issued without conseryationorder- - - - - - - - - - - - - - - - - - - - Yee - - - - - - - - - - - ° - Appr Date ' 12 Permit can be issued without administ[ative approval - - - - - - - - - -- - - - - - ; . ; - _ _ _ Yes - - . - _ _ RPC 112512006 13 Can permit be approvedbefgre15-day-wait-------------------- ---------- Yes-- --=----..------------------------.- -- - ------.-.-----...-------.---- .. ! 14 Well located within area and strata authorized by_Injection Order# (put_1O# in-comments)_(F9r_ NA- _ - - - _ - - - : . 15 All wells within,U4_mile area of review identified (For service well only) - _ _ _ _ - - . _ NA_ _ - - - _ _ - . 16 Pre-producedinject9r; duration of prep[oductionl_essthan3months_(ForserviceWellonly),_ NA__- --,---______ __---.--_-_____________ ___ _________________--. AC_MP.finding of Consistency_has been issued_for_this project _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ NA_ - - _ - . - - __ ~ Engineering, i ~- 18 - - Conductor string.P-ravided - - - - - - - - - NA - - - - - - - ~ 19 Surface casing_protects aII knowgUSDWS • - - - - - - - NA - 20 CMT.vo(adequate_tocirculateonconductor_&surf-csg---------_----.-------- NA--- :-------- -.----.-- --------------- ---__,-.-------- - i 21 CMT_vol adequate_t4 tie-in long string to surf csg- - - - - - - ---- - - - - - - -- - - - - - - - - - NA... :.. - - _ : _ ----------------------------------------------------------------- ~1 22 CMT.wlll coyer all knownproductive harizQns- - _ - _ - -- Yes : _ , Adequate excess.. - _ _ _ , _ - 1 23 Casing designs adequate for C, T, B &-permafrost - - - _ - - Yes - - - - - - - - 24 Adequate tankage-or tesenre pit - - - - - - Yes - - - CTDU. - - - - - - - - - - 25 If a re-drill, has a 10-403 for abandonment been epproved Yes . _ '_ X26 _Adequate wellbore separation.proposed - - Yes - 27 If diverter regwred, does d meet_ regulations _ _ - _ _ NA. - - Sidetrack. _ _ _ _ Appr Date 28 Dnlhng fluid_program schematic & equip list adequate_ _ - - _ _ _ - Yes . _ Max MW 8;6 ppg. - _ - . _ WGA U2612006 29 BOPEs, do they meetregulation - Yes _ _ _ _ _ _ _ _ 30 BOPS-press rating appropriate; test to-(put prig in cAmments)- - - - - - - - - - - - - - - - - - Yes .. - - - . - Test to 3500_ psi. _MSP 2220 psi.- - - - - j31 Choke manifold complieswlAPI-RP-53(M_ayZ34)--------------------------- Yes-- .--------. ----- -- --------- ~32 Workvnlloccurwithoutoperationshutdow-n_________________:_-_-:_.__-__ Yes-_ -.-__.. ________ -_ -- __--..-__._ -_. 33 Is presence-of H2S gas probable - - - - - - - - N0• - - - - ---- ~34 Mechanical condition of wells within AOR verified (Forservice well only) - - . - _ _ _ ' _ _ - - _ - - NA - _ . _ _ _ - - _- - Geology ~I35 Pe[rnit-can be issued wlo_ hydrogenaulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ . . - - _ - : - 36 Data_presentedon.potentialoverpressurezones__-______-_-.--------- NA_ _ __--- _ ------:----------- --------,---- Appr Date X137 Seismic analysis of shallow gas zones_ - _ - _ - - - - - - - - - - - - - - NA_ _ RPC 112512006 38 Seabed condition survey_(ifoff-shore) - - NA - - - ~i39 Contact namelphone for weekly_progress reports [exploratory only[ _ - - _ _ NA- _ - - - _ - - Geologic Engineering Public Commissioner: Date Date: Commissioner Date issioner: Com m 77 y~/ / ~J l C~(7~i~ ~ C,7' Ub • • • Well f-fistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. F g-06a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 14 07:45:45 2008 Reel Header Service name .............LISTPE Date . ...................08/03/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comment5 .................STS LIS Writing Library. scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/03/14 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical services Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: G-06A API NUMBER: 50029203580100 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-MAR-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: W-0004214919 W-0004214919 W-0004214919 LOGGING ENGINEER: S. LATZ S. LATZ 5. LATZ OPERATOR WITNESS: J. EGBEJIMBA J. EGBEJIMBA J. EGBEJIMBA MWD RUN 4 JOB NUMBER: W-0004214919 LOGGING ENGINEER: S. LATZ OPERATOR WITNESS: J. EGBEJIMBA SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: 13E FNL: 2653 FSL: FEL: 1974 FWL: Page 1 ~a~-oca ~ ~~~~ r . g-06a.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: 64.38 DERRICK FLOOR: GROUND LEVEL: 36.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.125 4.500 9332.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE G-06 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9332'MO/8746'TVDSS. THE WHIPSTOCK WAS POSITIONED PRIOR TO THE COIL UNIT RIGGING UP. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). UPHOLE TIE-IN SGRC DATA ACQUIRED WHILE RIH FOR MWD RUN 1 WERE MERGED WITH RUN 1 MWD DATA. DUE TO A TOOL MEMORY PROBLEM, MWD RUN 4 RECORDED DATA WERE UNUSABLE. THEREFORE, REAL-TIME DATA ARE PRESENTED FOR RUN 4 (SROP,SGRC,SEDP, SESP,SFXE ONLY). MAD PASS DATA ACQUIRED WHILE POOH AFTER REACHING FINAL TD WERE ALSO UNUSABLE. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN G-06A ON 25 FEBRUARY 2006. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 4 JANUARY 2008, AS AUTHORIZED BY MIKE MCTEAGUE (BP). ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-4 REPRESENT WELL G-06A WITH API#: 50-029-20358-01-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11650'MD/8929'TVDSS. 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 Page 2 LJ SPACING). SEDP = SMOOTHED SPACING). SFXE = SMOOTHED g-06a.tapx PHASE SHIFT-DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPD RPM ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 8975.0 9324.5 9324.5 9324.5 9324.5 9324.5 9362.5 STOP DEPTH 11603.5 11616.5 11369.0 11616.5 11616.5 11369.0 11650.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT BASELINE DEPTH GR 8975.0 8977.0 8976.0 8978.0 8980.5 8982.5 8984.5 8984.5 8988.0 8988.5 8989.5 8989.5 8996.0 8997.0 9010.0 9010.0 9015.5 9015.0 9018.0 9017.5 9324.0 9322.0 9334.5 9334.0 9342.5 9341.0 9345.0 9344.0 9350.0 9348.5 9357.0 9355.0 9362.5 9359.0 9365.0 9361.0 9379.5 9375.5 9397.0 9395.5 9399.5 9397.5 9445.5 9442.0 9455.5 9453.0 9484.5 9482.5 9505.0 9502.0 9543.0 9541.5 UNSHIFTED DEPTH --------- Page 3 g-06a.tapx 9546.5 9546.5 9559.5 9557.5 9565.0 9563.0 9567.5 9566.0 9575.0 9573.5 9599.0 9598.0 9616.5 9615.0 9630.5 9631.0 9643.0 9643.0 9660.0 9661.0 9667.0 9667.5 9725.0 9724.5 9746.5 9745.5 9784.0 9784.0 9825.0 9824.5 9832.0 9832.0 9851.5 9850.5 9871.0 9869.5 9892.0 9890.0 9914.0 9915.5 9917.0 9919.5 9921.0 9922.5 9935.5 9936.5 9963.5 9963.0 9967.0 9967.0 9995.0 9993.0 10008.5 10004.0 10018.0 10014.0 10036.5 10036.0 10046.5 10048.0 10052.0 10054.0 10062.5 10062.5 10070.5 10068.5 10083.5 10079.0 10096.0 10090.5 10101.0 10096.5 10110.5 10107.5 10114.0 10111.0 10116,0 10112.5 10133.0 10130.0 10140.0 10137.0 10158.0 10153.5 10217.5 10213.0 10236.5 10234.0 10250.0 10246.5 10291.5 10287.0 10317.5 10315.0 10336.5 10332.0 10353.0 10346.0 10361.5 10356.0 10395.0 10391.0 10440.5 10435.5 10468.0 10464.0 10494.5 10492.0 10498.5 10495.0 10508.5 10504.5 10531.5 10527.0 10545.5 10541.5 10552.0 10547.5 10558.0 10556.5 10579.5 10576.5 10583.5 10582.0 10586.0 10585.0 Page 4 U 9-06a.tapx 10595.0 10595.5 10637.5 10634.5 10648.0 10646.0 10655.0 10653.0 10673.0 10671.0 10682.0 10683.0 10685.0 10686.0 10689.0 10690.0 10743.0 10746.5 10753.5 10756.0 10759.5 10762.5 10770.5 10773.0 10793.5 10794.5 10850.5 10852.0 10864.0 10865.0 10870.0 10869.5 10881.5 10882.0 10893.5 10893.0 10905.0 10905.0 10943.0 10942.5 10960.5 10959.5 10970.0 10969.0 11002.0 11000.5 11004.0 11002.5 11009.5 11009.5 11025.0 11026.0 11034.5 11036.0 11037.0 11038.0 11045.5 11046.5 11111.0 11111.5 11131.5 11133.5 11144.0 11145.0 11157.0 11156.5 11179.5 11179.0 11189.5 11191.5 11194.0 11196.0 11200.0 11202.0 11216.5 11215.5 11238.0 11236.5 11253.0 11251.5 11427.0 11426.0 11436.0 11433.0 11462.0 11459.5 11464.0 11461.5 11477.0 11474.5 11491.0 11488.5 11501.5 11500.5 11515.5 11515.5 11650.0 11650.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 8977.0 9740.0 MwD 2 9740.0 9915.0 MwD 3 9915.0 11400.0 MWD 4 11400.0 11650.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Page 5 Data Record Type... ., g0-06a.tapx Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 8975 11650 10312.5 5351 8975 11650 RPD MWD OHMM 0.27 2000 47.0952 4564 9324.5 11616.5 RPM MWD OHMM 0.6 2000 33.8184 4090 9324.5 11369 RPS MWD OHMM 0.24 2000 34.6401 4585 9324.5 11616.5 RPX MWD OHMM 0.21 1984.59 30.5882 4090 9324.5 11369 FET MWD HOUR 0.18 11.24 1.45617 4564 9324.5 11616.5 GR MwD API 14.24 390.03 71.2538 4690 8975 11603.5 ROP MWD FT/H 0.49 726.26 83.6341 4576 9362.5 11650 First Reading For Entire File..........8975 Last Reading For Entire File...........11650 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER Page 6 g-06a.tapx FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8977.0 9694.5 RPM 9322.5 9708.0 RPS 9322.5 9708.0 RPD 9322.5 9708.0 RPX 9322.5 9708.0 FET 9322.5 9708.0 ROP 9359.0 9740.0 LOG HEADER DATA DATE LOGGED: 15-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9740.0 TOP LOG INTERVAL (FT): 9359.0 BOTTOM LOG INTERVAL (FT): 9740.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.6 MAXIMUM ANGLE: $4.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9332.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .120 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 126.0 MUD FILTRATE AT MT: .140 68.0 MUD CAKE AT MT: .130 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 7 $ g-06a.tapx Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 l 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8977 9740 9358.5 1527 8977 . 9740 RPD MwD010 OHMM 0.27 2000 96.6294 772 9322.5 9708 RPM MWDO10 OHMM 0.6 2000 58.1143 772 9322.5 9708 RPS MWDO10 OHMM 0.16 2000 65.3375 772 9322.5 9708 RPX MWDO10 OHMM 0.19 1984.59 41.5444 772 9322.5 9708 FET MwD010 HOUR 0.18 3.6 1.299 772 9322.5 9708 GR MWDO10 API 14.24 390.03 57.6591 871 8977 9694.5 ROP MWDO10 FT/H 1.29 298.54 52.0319 763 9359 9740 First Reading For Entire. File..........8977 Last Reading For Entire File...........9740 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLiB.003 Phy51Ca1 EOF File Header Service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLIB.002 Page 8 g-06a.tapx comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9695.0 9868.5 RPX 9708.5 9883.0 FET 9708.5 9883.0 RPD 9708.5 9883.0 RPM 9708.5 9883.0 RPS 9708.5 9883.0 ROP 9740.5 9915.0 LOG HEADER DATA DATE LOGGED: 16-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9915.0 TOP LOG INTERVAL (FT): 9740.0 BOTTOM LOG INTERVAL (FT): 9915.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.0 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9332.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .120 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 129.4 MUD FILTRATE AT MT: .140 68.0 MUD CAKE AT MT: .130 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 9 g-06a.tapx 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9695 9915 9805 441 9695 9915 RPD MWD020 OHMM 18.85 31.11 22.5161 350 9708.5 9883 RPM MWD020 OHMM 14.28 25.14 18.315 350 9708.5 9883 RPS MWD020 OHMM 14.12 26.79 18.483 350 9708.5 9883 RPX MWD020 OHMM 13.18 29.3 18.3346 350 9708.5 9883 FET MWD020 HOUR 1.13 7.82 3.27477 350 9708.5 9883 GR MWD020 API 50.55 134.83 83.2746 348 9695 9868.5 ROP MWD020 FT/H 0.49 726.26 53.2124 350 9740.5 9915 First Reading For Entire File..........9695 Last Reading For Entire File...........9915 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Page 10 Maximum Physical Record..65535 g-06a.tapx File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9869.0 FET 9883.5 RP5 9883.5 RPM 9883.5 RPx 9883.5 RPD 9883.5 $OP 9915.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11354.5 11368.0 11368.0 11368.0 11368.0 11368.0 11400.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RE5I5. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (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: header data for each bit run in separate files. 3 .5000 4 18-FEB-06 Insite 4.3 Memory 11400.0 9915.0 11400.0 86.9 97.0 TOOL NUMBER 78005 178424 4.125 9332.0 Flo Pro 8.60 65.0 9.4 24000 6.2 .100 68.0 .050 150.0 .140 68.0 .080 68.0 Page 11 g-06a.tapx 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 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9869 11400 10634.5 3063 9869 11400 RPD MwD030 OHMM 18.79 60.37 40.0724 2970 9883.5 11368 RPM MwD030 OHMM 14.88 49.55 29.6081 2970 9883.5 11368 RPS MWD030 OHMM 14.57 55.99 30.0132 2970 9883.5 11368 RPX MWD030 OHMM 12.36 65.34 29.431 2970 9883.5 11368 FET MWD030 HOUR 0.21 8.73 1.11187 2970 9883.5 11368 GR MWD030 API 30.94 182.86 72.0296 2972 9869 11354.5 RoP MwD030 FT/H 0.66 229.35 93.5414 2970 9915.5 11400 First Reading For Entire File..........9869 Last Reading For Entire File...........11400 File Trailer Service name... .......STSL2B.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Page 12 g-06a.tapx Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11355.0 RPD 11368.5 RPS 11368.5 FET 11368.5 ROP 11400.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 19-FEB-06 Insite 4.3 Memory 11650.0 11400.0 11650.0 85.2 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178424 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: header data for each bit run in separate files. 4 .5000 5 STOP DEPTH 11603.5 11616.5 11616.5 11616.5 11650.0 4.125 9332.0 Flo Pro 8.60 65.0 9.5 23000 6.4 .100 68.0 .050 156.0 .140 68.0 .080 68.0 Page 13 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: g-06a.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPS MWD040 OHMM 4 1 68 8 3 FET MWD040 HOUR 4 1 68 12 4 GR MwD040 API 4 1 68 16 5 ROP MWD040 FT/H 4 1 68 20 6 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11355 11650 11502.5 591 11355 11650 RPD MWD040 OHMM 26.41 43.27 33.8425 476 11368.5 11616.5 RPS MWD040 OHMM 19.02 33.54 25.1277 497 11368.5 11616.5 FET MWD040 HOUR 0.22 11.24 2.49089 497 11368.5 11616.5 GR MWD040 API 38.88 141.26 80.182 498 11355 11603.5 ROP MWD040 FT/H 1.47 260 92.7279 500 11400.5 11650 First Reading For Entire File..........11355 Last Reading For Entire File...........11650 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/14 Origin ...................STs Tape Name ................UNKNOWN Page 14 h ~ ~ • g-06a.tapx Continuation Number......01 N2xt Tape Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE gate . ...................08/03/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. 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