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Home My WebLink About205-195CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-08A (PTD #2051950) will lapse on AOGCC 4-year MIT-IA Date:Monday, March 7, 2022 11:01:33 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, March 6, 2022 11:08 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; John Conrad <John.Conrad@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 01-08A (PTD #2051950) will lapse on AOGCC 4-year MIT-IA Mr. Wallace, Injector 01-08A (PTD # 2051950) is due for its 4-year AOGCC MIT-IA by the end of March. Currently, there are no plans to put the well on Injection. The well is now classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. r • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,March 19,2018 TO: Regg Jim P.I.Supervisor ken 4z0(1 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 01-08A FROM: Brian Bixby PRUDHOE BAY UNIT 01-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 01-08A API Well Number 50-029-20160-01-00 Inspector Name: Brian Bixby Permit Number: 205-195-0 Inspection Date: 3/11/2018 Insp Num: mitBDB180311153422 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 01-08A Type Inj W TVD 8256 TTubing 1989 1987 - 1988 1987' PTD± 2051950 Type Test SPT ;Test psi 2064 IA 144 2800 2770 2759 BBL Pumped: 4.7 f BBL Returned: I 3.5 OA 0 0 12 • 13 IntervalP/ ! F P — -__ -- --_-__-- --__- ---__ 4YRTST PI �� Notes: SCANNED . MondaY, PaMarch 19,2018 Page MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I I ~ i ~ DATE: Friday, May 07, 2010 Toy Jim Regg h~j ~ l P.I. Supervisor 11 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 0 ] -08A FROM: John Crisp PRUDHOE BAY UNIT 01-08A Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `-f ~,K-~ Comm Well Name: PRUDHOE BAY UNIT 01-08A Insp Num: mitJCr100504075033 Rel Insp Num: API Well Number: 50-029-20160-01-0o Permit Number: 205-195-0 Inspector Name: John Crisp Inspection Date: 4/29/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well col-osA T_YPe Inj. ~' ~ TVD P.T.D zosl9so TypeT set SPT r~Test psi azs6 zo6a IA 30 ~ 2soo ~ Op o ~ 2a3o i 2a2o z ~-- z Interval 4YRTST per, P ~ Tubing i 1830 1840 1840 1840 Notes: 3.9 bbls pumped for test S{ {~ Friday, May 07, 2010 Page I of 1 • • WELL LOG TRANSMITTAL To: Alaska DNR, Division of Oil & Gas Attn: Kristen Dirks 550 West 7~' Ave., Suite 800 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: O 1-08A+PB 1 August 27, 2008 AK-MW-4110204 O1-08A+PB1: Z" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-029-20160-01,70 2" x 5" TVD RESISTNITY & GAMMA RAY Logs: 1 Color Logs 50-029-20160-01,70 Digital Log Images: 1 CD Rom 50-029-20160-01,70 ~` ~'~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: ~~,G Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska-995:18 Anchorage, Alaska 99508 Date: Signed: ~ aos =~ ~ I~~~ ~u :~~ _~ _ • • WELL LOG TRANSMITTAL To: State of Alaska August 12, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 01-08A AK-MW-4110204 01-08A: 1 LDWG formatted CD rom with verification listing. API#: 50-029-20160-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Da~~: ~ ~ Signed: v~~ ~t~s-i~-5 ~~~c~~ • • WELL LOG TRANSMITTAL To: State of Alaska August 12, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data:. 01-08A PB1 AK-MW-4110204 Ol-08A PB1: 1 LDWG formatted CD rom with verification listing. API#: 50-029-20160-70 ~~~,~~ ~,~~ ~ r , `> 205 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: l~2~ 2a5=1Q15 Ito ?f (o ~ 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: O 1-08A+PB 1 August 27, 2008 AK-MW-4110204 01-08A+PB1: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20160-01,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20160-01,70 Digital Log Images: ~,,, , ~ ~o :b `, ~~~~ 1 CD Rom 50-029-20160-01,70 °~~~~' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: . I~ Date: V ~ ~ Signed: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 I ~ ~f (1ZC= ao5=! `~5 ~ lCo`zs c`S ~~- DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051950 Well Name/No. PRUDHOE BAY UNIT 01-OSA Operator BP EXPLORATION (ALASKA} INC API No. 50-029-20160-01-00 MD 14800 TVD 8331 Completion Date 2/7/2006 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, MWD DIR / GR / RES f PWD, DIR / GR /RES /DEN Welt Log Information: Log/ Electr (data taken from Logs Portion of Master Well Data Maint Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments C Lis 13773 Temperature 1 11000 14700 Case 311!2006 Base Temperature Log GRlCCL/Temp 23-Feb-06 'I plus .LAS .pds files / Y1QQ _ Cement Evaluation 5 Blu 3000 14200 Case 1/31/2006 ULTRASONIC CEMENT ~ ('~ EVALUATION USIT-GR- Temperature 5 Blu 1 11000 14700 Case 3!1/2006 CCL 30-Jan-2006 Base Temperature Log II GR/CCL/Temp 23-Feb-O6 /~~ED v D Asc Directional Survey 29 14800 Open 411 712 0 0 6 it ~ D Asc Directional Survey 29 2616 Open 4/17!2006 PB 1 ~- C Las 15539 Induction/Resistivity 0 14799 Open 10/12/2007 DRHO, FCNL, GR, NPHI, RHOB RPD RPS w/EMF graphics Field Data C Las 15540 Induction/Resistivity 2093 2616 Open 10!12(2007 PB1 EWR, GR, ROP, RPS Ili w/EMF graphics Field Data ~, Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / 1QIU\ Daily History Received? N Chips Received? "Y"T~~ Formation Tops QN Analysis Y7'I~"! Received? Directional Survey DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051950 Well Name/No. PRUDHOE BAY UNIT 01-08A Operator BP EXPLORATION (ALASKA) INC MD 14800 TVD 8331 Completion Date 217!2006 Completion Status 1 WINJ Current Status 1 WINJ Comments: API No. 50-029-20160-01-00 UIC Y __ __ --- - ,` ----- Compliance Reviewed By: Date: { !~ ~~`~ by ~ Date 10-12-2007 Transmittal Number:92907 BP~A WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) t you have an uestions, lease contact llouglas llortch at the YllC at 564-4y%3 Delive Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-08A u z,~ g~_I~ 5 ~~.__ _ ----- 03-14A wlo Oaf i ~S~! (_ ~ _ ___ ___ 03-36A (~a b ~ ~ fbP.~- -~- _ _- _ 05-36A 05-36APB1 ~p~ _d-3.n tSS~i 06-13APB1-. ~Q.~ -to~Y __L5~`~5 _ ~ ~_~.~__.... 12-05A aQ~-..Q~~ ~_l5i~Ll~ _.___ 12-05APB1 c2Q~.-CG3 ",1.~5~/'~_ ~. ___.._.._. C-22A uc~C~Co_.--'-~-.±a~S~I.SI~_. __._._ ..~...:~, E-15C ai,r _,.~ .. t ~ ~.-ri.a __. -02 ~b(o Ito '~ t.sssl.___..__..~--- K-02DPB1 _a.Qr'o.._-D~~.'"lS'SSa.r..__...__ W-213 . 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 19b612 Anchorage, AK 99519-6612 ~ s MEMORANDUM Toy Jim Regg ` ]f P.1.Supervisor ~ \~~(G~ y ~~~~~t I`~~`" FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 17, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-08A PRUDHOE BAY UNIT 01-08A Src: Inspector NON-CONFIDENTIAL .~ ~~~ ~~ Reviewed By: P.I. Suprv, Comm Well Name PRUDHOE BAY UNIT 01-08A API Well Number 50-029-20160-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS060516062534 Permit Number: 205-195-0 Inspection Date: 5/15/2006 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~--~-_ Well ~ 01-08A TYPe IRj. I N ~~ 'I'~JD ~, 8255 IA ~~ 360 ~ 2500 2470 ~ 2460 P.T. 20519 0 TYPeTest I sPT Tes p 2obs.~ A o ! o ! o ~ o ~ I Interval ~IT~- P/F P` Tubing ! o o I o E o Notes Wednesday, May 17, 2006 Page 1 of I `r OI-08A MIT • • Subject: PBU 01-O8A MIT From: James Regg <jiln_regg c~adrnin.state.ak.us> Date: Mon,-0l May 2006 ~4:ST:O4 -0$00 To: "I~~SU, AD~~' ~~~cll [r~te~,rit~~ En~;inecr,~ ~NSUAD~G%~~"e~Ill~itc~;ritvErr~sineerr~uBP.cor~> C'C: Bob Flc?ckenst~:in <:hoh (leckenstein~cr?a~lmin.state.ak.us=- Well was put on injection 4/24/06 according to revised well completion rpt. We do not have a record of MIT done prior to injection (this was probably done when rig was still on the well in January). Please forward a copy of the MIT; also make arrangements for an AOGCC-witnessed MIT. Thank you. Jim Regg AOGCC 1 of 1 5/1/2006 2:51 PM .~ ~~~~~ f STATE OF ALASKA _ ~' ALASV~IL AND GAS CONSE~t~l,~t~NN;~SION ~ ' WELL COMPLETION OR RES CO9,, MPLEQTION REPORT AND LOS ~;; : ~. J, v, .~i3a>~`ia~ y+ r :a~. !. ~ 1 , l~ '~ ~ . 1 is fit: i7:i s Revised: 0+4/2r~j~a#~on ~a~ ~ ~: 1 a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 zoAAC Zs.i ~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 Aband. 2/7/2006 12. Permit to Drill Number 205-195 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/3/2006 13. API Number 50-029-20160-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/3/2006 14. Well Name and Number: PBU 01-08A 4204 FSL, 3758 FEL, SEC. 08, T10N, R15E, UM Top of Productive Horizon: 3246' FSL, 2224' FEL, SEC. 01, T10N, R14E, UM g, KB Elevation (ft): 66.4' 15. Field /Pool(s): Prudhoe Bay Field /Put River Po Total Depth: 3576' FSL, 2721' FEL, SEG. 01, T10N, R14E, UM 9. Plug Back Depth {MD+TVD) 14715 + 8335 Ft 4b. Location of Welt (State Base Plane Coordinates): Surface: x- 698864 y- 5939851 Zone- ASP4 10. Total Depth (MD+TVD) 14800 + 8331 Ft 16. Property Designation: ADL 028329 _ TPI: x- 689969 y- 5943946_ Zone- ASP4 Total Depth: x- 689463 Y- 5944262 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness o erma rost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, MWD DIR / GR /RES / PWD, DIR / GR /RES /DEN / NEU, USIT ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MD` ETTING EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 100' Surface 100' 32" 13-3/8" 72# MN-80 Surface 2350' Surface 2350' 17-1/2" 6400 sx Permafrost II 9-5/8" 40# L-80 27' 5465' 27' 4471' 12-1/4" 224 sx ASL, 523 sx 'G', 184 sx ASL 7" 26# L-80 25' 14212' 25' 8339' 8-3/4" 2so 5x'G', Asa sx •c•, azs sx •~•, ass s«'c• 4-1/2" 12.6# L-80 14066' 14800' 8279' 8331 6-1/8" 106 sx Class 'G' 23. Pertorations open to Production (MD +TVD of Top and " " 24. TuefNC RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET {MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 14067' 14011' MD TVD MD TVD 14570' - 14700' 8342' - 8336' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 2424' Set Kick Off Plug: 63 Bbfs Class 'G' Freeze Protect with 75 Bbts of Diesel 26• PRODUCTION TEST Date First Production: March 24, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water injection 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 O{L GRAV{TY-APl {CORK) 27. GORE 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 ~~~F q'~'} `~ 20D1 Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~NUEp ON REVERSE $IDE wr .~ GEOLOGIC MARKS 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'. Ugnu 4 6042' 4698' None Ugnu 3 6484' 4890' Ugnu 1 7890' 5548' West Sak 2 8830' 6052' West Sak 1 9332' 6302' CM3 9878' 6537' CM2 11032' 7004' CM1 12835' 7761' Top HRZ 13542' 8060' Base HRZ 13993' 8248' Put River 14195' 8332' 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. Signed Terrie Hubble ' t Title Technical Assistant Date ~l ~~ (~p PBU 01-08A 205-195 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Dr/wing Engneer: Ken Allen, 564-4366 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Aiaska. ITeM 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. ITeM 4b: TPI (Top of Producing Interval). ITeM 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). ITEM 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. ITeM 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). ITeM 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". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • s 22-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1-08A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,350.00' MD Window /Kickoff Survey 14,758.40' MD (if applicable) Projected Survey: 14,800.00' 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 , / . Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) X05 =(Q4 ~~~ • • 22-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1-08A PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,350.00' MD Window /Kickoff Survey 2,573.00' MD (if applicable) Projected Survey: 2,616.00' 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 Date ~O b Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~r: ~cf,l,~D STATE OF ALASKA ALAS IL AND GAS CONSERVATION COM .~SION '~'~+~' 1 7 2000 WELL COMPLETION OR RECOMPLETION REPORT AND LOG. ~iaska G~i! ~ Gas Cons. Commission l~tlC.finr~.,,. ia. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ®WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) inc. 5. Date Comp., Susp., or Aband. 2/7/2006 12. Permit to Drill Number 205-195 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1 /3/2006 13. API Number 50- 029-20160-01-00 4a. Location of Well (Governmental Section): Surtace: 4204' FSL 3758' FEL SEC 7. Date T.D. Reached 2/3/2006 14. Well Name and Number: PBU 01-08A , , . 08, T10N, R15E, UM Top of Productive Horizon: 3246' FSL, 2224' FEL, SEC. 01, T10N, R14E, UM g, KB Elevation (ft): 66.4' 15. Field /Pool(s): Prudhoe Bay Field /Put River Pool Total Depth: 3576' FSL, 2721' FEL, SEC. 01, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 14715 + 8335 Ft 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 698864 y- 5939851 Zone- ASP4 10. Total Depth (MD+TVD) 14800 + 8331 Ft 16. Property Designation: ADL 028329 TPI: x- 689969 y- 5943946 Zone-Y ASP4 Total Depth: x- 689463 y- 5944262 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: ----~------"- ----"----------- --~-----~---- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, MWDDIR / GR /RES / PWD, DIR / GR /RES /DEN / NEU, USIT 2. ASING, LINER AND CEMENTING ECORD CASINO ~ EPTH Mo INti EPTH TVA Hod ouNT $IZE WT, PER Ft. GRADE OP TTOM' OP TTOM $IZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 100' Surface 100' 32" 13-3/8" 72# MN-80 Surface 2350' Surface 2350' 17-1/2" 00 sx Permafrost II 9-5/8" 40# L-80 27' 5465' 27' 4471' 12-1/4" 24 sx ASL 523 sx 'G' 184 sx ASL 7" 26# L-80 25' 14212' 25' 8339' 8-3/4" 3o sx'G', 154 sx'G', azs sx'G', t65 sx'c~' 4-112" 12.6# L-80 14066' 14800' 8279' 8331 6-1/8" 106 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 14067' 14011' MD TVD MD TVD 14570' - 14700' 8342' - 8336' 25.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2424' et Kick Off Plug: 63 Bbls Class 'G' Freeze Protect with 75 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): NIA Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submik,core chips; if none, state "none". 4 None ~o~ d csJdNG~o~/ Z,3,Sa 2 3 Sa ~y,~ ~.~..~.$ ~~ ~ a zoos Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE y ~^ 28 GEOLOGIC MARKERS 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". Ugnu 4 6042' 4698' None Ugnu 3 6484' 4890' Ugnu 1 7890' 5548' West Sak 2 8830' 6052' West Sak 1 9332' 6302' CM3 9878' 6537' CM2 11032' 7004' CM 1 12835' 7761' Top HRZ 13542' 8060' Base HRZ 13993' 8248' Put River 14195' 8332' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. f hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~/~ ~/t~tO T l A ~ Titl h i i t D e n ec ca ss ant ate s Terrie Hubble PBU 01-OSA 205-195 Prepared By Navne/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: Ken Alen, 564-4366 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 Submit Original Only Printed: 2(13!2006 12:00:32 PM BP EXPLORATION Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALAS KA DRILLING Rig Name: NABORS 2ES Date f From - To i Hours ~, Task j Code ~~ NPT ~ 12/25/2005 09:00 - 11:00 2.00 MOB P 11:00 - 12:00 1.00 MOB N WAIT 12:00 - 00:00 12.00 MOB P 12/26!2005 00:00 - 07:00 7.00 MOB P 07:00 - 12:00 5.00 RIGU P 12:00 - 13:00 1.00 RIGU P 13:00 - 20:00 7.00 RIGU P 20:00 - 20:30 I 0.501 WHSUR I P 20:30 - 22:30 I 2.001 WHSUR I P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 WHSUR P 12/27/2005 100:00 - 01:30 I 1.501 PULL I P 01:30 - 02:30 1.00 WHSUR P 02:30 - 05:00 2.50 WHSUR P 06:30 - 07:30 1.00 BOPSU~P 07:30-17:30 { 10.OO~WHSURIP 17:30 - 18:30 1.00 {WHSUR P 18:30 - 19:30 1.004 WHSUR P 19:30 - 21:30 2.00 WHSUR P 21:30 - 00:00 I 2.501 WHSUR I P 12/28/2005 ~ 00:00 - 01:00 1.00 WHSUR P 01:00 - 05:30 4.50 PULL P 05:30 - 06:00 ~ 0.50 BOPSU~ P 06:00 - 09:00 3.00 BOPSU P 09:00 - 09:30 0.50 BOPSUF~ P 09:30 - 11:30 2.00 CLEAN I P Start: 12/26/2005 Rig Release: 2/7/2006 Rig Number: Page 1 of 16 Spud Date: 6!4/1975 End: 2/7/2006 Phase I Description of Operations PRE Lay down derrick. Pull shop and pits away from sub base. PRE Wait on Security for escort. PRE Move sub base off of well Y-11Ci and to D.S. 1 well # 8. PRE Move sub base from Y-11 Ci to D.S. 1 well # 8. PRE Spot rig over well. Double mat under sub base and set rig. PRE Close cellar doors and cover cellar. PRE PJSM. Raise and pin derrick. Set pipe shed chute. Spot pits, shops and shacks. Bridle down derrick. R/U floor. Spot and berm cuttings tank. Complete pre-spud check list. Take on seawater. DECOMP Hold pre-spud meeting with drill crew, Tool Pusher & WSL. Rig accepted for operations C~ 20:00 hrs 12/26/2005. DECOMP Install secondary annulus valve. R/U circ lines in cellar and to cuttings tank. DECOMP R/U DSM lubricator & pull TWC valve. DECOMP Pump Safe Surf pill and circ out diesel freeze protect through cut tubing ~ 2950'. Displace well to clean seawater. Pump 260 bb{s down tubing to annulus through choke to slop tank. DECOMP Circ out freeze protect and displace well to clean seawater @ 5 bpm ~ 1100 psi. DECOMP Set BPV and test from below to 1000 psi. DECOMP N/D tree and adaptor flange, remove from cellar. Dress wellhead. Install blanking plug. DECOMP N/U 13 5!8" x 5000 psi BOPE. DECOMP M/U test joint. Blow through choke manifold, kill and choke fines. DECOMP Test BOPE to 250 low & 4000 psi high test. Test annular preventor to 250/2500 psi. Test top, bottom & blind rams. HCRs, manuals and choke manifold and valves on top drive. Pertorm Koomey test. R!D test equipment and blow down all lines. Test witnessed by AOGCC Rep. John Crisp, Co. Rep. John Rall and Tool pusher Cleve Coyne. DECOMP PIU tools and retreive FMC blanking plug, UD tools & plug. DECOMP P/U DSM lubricator and extension. Pull BPV. R/D DSM. DECOMP P/U single of drill pipe and double spear. Attempt to spear weld neck tubing hanger. Grapples would not enter hanger. Change to smaller grapples and spear hanger. DECOMP BOLDS. Pull hanger free with i90K, UWT = 75K. Pull hanger to floor. Flow check. Release spears, break out hanger. Clear rig floor. R/U power tongs and casing tools. Bring Control line spooling unit to rig floor. DECOMP R/U and reverse circ out seawater contaminated with diesel. DECOMP POH UD 5 1/2" 17# tubing from cut @ 2950'. Recovered 93 joints of tubing, 1 SSSVLN, 1 cut joint 13.15' long and 64 SS bands. R!D casing tools. Clear and clean rig floor. DECOMP P/U 5" test joint and R/U to test BOPE. DECOMP Test BOPE with 5" test joint. Test top rams, bottom rams & top drive valves to 250 low test and 4000 psi high. Test annular preventor to 250/2500. Test witnessed by Rig Rep. John Rall & Tool Pusher Cleve Coyne. DECOMP Pull test plug, UD test joint. Blow down top drive and all {fines. DECOMP P1U 9 5/8" casing scraper, 8 i/2" bit, bumper sub, 9 drill collars & 18 HWDP. RIH to 856'. Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Operations Summary Report Page 2 of 16 Legal Well Name: 01-08 Common Well Name: 01-08 Spud Date: 6/4/1975 Event Name: REENTER+COMPLETE Start: 12/26!2005 End: 2/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2Rl2006 Rig Name: NABOBS 2ES Rig Number: Date From - To I Hours Task ~, Code ~~I NPT Phase ------!-------~ --~---_ ~ ---1 ---~ ---- 12/28/2005 11:30 - 13:30 2.00 CLEAN P DECOMP 13:30 - 14:30 1.00 CLEAN P DECOMP 14:30 - 15:30 1.00 CLEAN P DECOMP 15:30 - 16:30 1.00 CLEAN P DECOMP 16:30 - 17:00 0.50 DHB P 17:00 - 20:00 3.00 DHB P 20:00 - 20:30 0.50 DHB P 20:30 - 21:00 0.50 DHB P 21:00 - 22:00 1.00 DHB P 22:00 - 00:00 2.00 BOPSU P 12/2912005 00:00 - 00:30 0.50 BOPSU P 00:30 - 01:00 0.50 BOPSU P 01:00 - 01:30 0.50 DHB P 01:30 - 02:30 1.00 DHB P 02:30 - 04:00 1.50 STCTPL P 04:00 - 05:30 1.50 STCTPL P 05:30 - 07:00 1.50 STCTPL P 07:00 - 08:30 1.50 STCTPL P 08:30 - 09:00 0.50 STCTPL P 09:00 - 10:00 1.00 STCTPL P 10:00 - 12:00 2.00 STCTPL P 12:00 - 13:30 1.50 STCTPL P 13:30 - 15:30 I 2.001 STCTPL I P 15:30 - 19:00 3.50 STCTPL N 19:00 - 21:00 2.00 STCTPL P 21:00 - 21:30 0.50 STCTPL P 21:30 - 00:00 2.50 STCTPL P i 2/30/2005 100:00 - 17:00 I 17.001 STCTPL I P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP HMAN DECOMP DECOMP DECOMP DECOMP DECOMP Description of Operations RIH PIU drill pipe to 275i'. Pump Safe Surf pill & CBU ~ 625 gpm @ 950 psi. POH from 2751' to 856'. Stand back HWDP & D.C.s. Break & UD bit, casing scraper, float sub, bumper sub & jars. M/U 9 5/8" CIBP to drill pipe. RIH ~ 90 fpm P/U drill pipe. Wash down from 2495' to 2505'. Set CIBP @ 2500' and shear off. Pull 1 stand of drill pipe. M/U 9 5/8' RTTS and set (~ 29'. Test 9 5!8" casing &CIBP below RTTS to 3000 psi. Unsung & pull running tool. Close blind rams & test above RTTS to 3000 psi. Drain BOP stack & install test plug. PJSM. Change lower set of rams to 9 5/8" casing rams. Test lower BOP door seals to 250 low, 4000 psi high test. BOLDS & pull test plug. RIH with RTTS running tool to 29' and sting in to RTTS. Pull to rig floor. POH from 2400' & UD CIBP running tool. M/U Baker 8 1/4" MultiString casing cutter on drill pipe. RIH with casing cutter to 2390'. Cut 9 5/8" casing at 2390'. Pump C~ 134 gpm ~ 575 psi, 60 rpm. POH with casing cutter. (wet) UD casing cutter tools and clear rig floor. M/U 9 5/8" casing spear assy. Spear casing (~ 2390'. BOLDS. Heat wellhead with steam. Disengage spear & UD. M/U packoff running tool. Engage top of hanger and rotate packoff seal assy 1/4 turn counter clockwise. UD packoff tool and M/U spear. Change out grapple on spear and M/U to top drive. Engage hanger with spear. Pull 190K to unseat hanger, P!U 3' and close annular preventor. Line up through choke to take returns to cuttings tank. Attempt to break circ. Pressure up slowly to 1270 psi, pressure dropped to 1100 psi ~ 1.5 bpm. No returns. Bleed off, open annular preventor and attempt to circ. Work pipe and stage up to 1000 psi. Pull hanger to rig floor. Packoff on spear not holding. Land hanger, break out spear and change packoff cup. Blow down top drive and kill fine. M1U spear to top drive, monitor well. Thaw hard lines to cuttings tank. Engage casing hanger with spear and pull hanger to rig floor, UWT = 175K. Attempt to break circ while working pipe. No returns, injecting @ 3 bpm C~3 1000 psi. Mix and pump dry job. PJSM. Install false bowl & slips, disengage spear & UD. R1U tongs, break & UD casing hanger. R/U power tongs, change elevators. POH UD 9 518" casing from 2390'. Pipe connections tight and hard to break. R/U double line on break out tongs. Steam casing collars before breaking. Fill hole through 9 518" casing as hole will not take fluid down the backside due to Arctic Pack sheath between the 13 3/8" and 9 5/8" casing. POH UD 9 5/8" casing from 2270'. Connections tight and hard Printed: 2/13/2006 72:00:39 PM BP EXPLORATION Operations Summary Report Page 3 of 16 Legal Well Name: 01-08 Common Wetl Name: 01-08 Spud Date: 6/4/1975 Event Name: REENTER+COMPLETE Start: 12!2612005 End: 2/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~~i From - To I Hours I Task ~j Code I, NPT ! Phase --_ --i ---- ' - -- --i --~ -! -- ---- - - -~ 12/30/2005 ~ 00:00 - 17:00 ~ 17.00 ~ STCTPL ~ P ~ ~ DECOMP 17:00 - 17:30 0.50 STCTPL P DECOMP 17:30 - 18:30 1.00 CLEAN P DECOMP 18:30 - 21:00 I 2.501 CLEAN I P I I DECOMP 21:00 - 22:30 I 1.501 CLEAN I P I I DECOMP 22:30 - 23:00 0.50 CLEAN P DECOMP 23:00 - 23:30 0.50 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 12/31(2005 00:00 - 01:00 1.00 CLEAN P DECOMP 01:00 - 01:30 0.50 BOPSU P DECOMP 01:30 - 02:00 0.50 EVAL P DECOMP 02:00 - 04:30 2.50 EVAL P DECOMP 04:30 - 06:30 I 2.001 DHB I P I I DECOMP 06:30 - 08:00 I 1.501 DHB I P I I DECOMP 09:30 - 100:30 I 1.00 DHB P I DECOMP DECOMP 110:00 - 14:00 3.00 DHB P ~ DECOMP DECOMP 14:00 - 15:30 1.50 DHB P DECOMP 15:30 - 17:00 1.50 DHB P DECOMP 17:00 - 17:30 0.50 DHB P DECOMP 17:30 - 18:30 1.00 DHB P DECOMP 18:30 - 19:00 0.50 DHB ~ P DECOMP 19:00 - 19:30 0.50 DHB P DEGOMP 19:30 - 22:30 3.00 DHB P DECOMP 22:30 - 23:30 1.00 DHB P DECOMP 23:30 - 00:00 0.50 DHB P DECOMP 1/1!2006 00:00 - 00:30 0.50 DHB P DECOMP 00:30 - 01:30 1.00 STWHIP P WEXIT 01:30 - 06:00 4.50 STWHIP P WEXIT 06:00 - 07:00 1 1.001 STWHIPI P I I WEXIT Description of Operations to break. Using double line on break out tongs. Steam casing collars before breaking. Fill hole through 9 5/8" casing as hole will not take fluid down backside due to Arctic Pack sheath between 13 3/8" x 9 5/8" casing. Recovered 60 joints, 1 cut joint 27.25' long and 13 bow spring centralizers. R/D casing tools, clear & clean rig floor. P/U 9 5/8" casing spear (from previous run) break & UD. P/U 13 3/8" casing scraper BHA to 517'. CBU, Arctic pack returns. RIH Break circ ~ 880' & 1350'. RIH to 9 5/8" casing stump ~ 2390'. Pump Safe Surf pill and circulate out Arctic Pack with i 10 degree seawater, CBU. Rotate & reciprocate. Pump Safe Surf pill #2 and CBU, returns clean. POH to BHA ~ 880'. Rack back HWDP & drill collars. UD drilling jars & casing scraper. VD 13 3/8" casing scraper assy. Clear rig floor. Set wear bushing, RILDS. PJSM. R/U SWS and GyroData. RIH with GyroData gyro and take surveys ~ 100' intervals to 2350'. POH with wire line, UD gyro Re-head SWS rope socket and prepare to run CCL & 13 3/8" EZSV plug. RIH with 13 3/8" EZSV & GCL to 2350'. CCL not locating. POH with wire line, UD EZSV. Re-run CCL to 2350', POH. P/U 13 318" EZSV and RIH. Set the top of the plug G 2370'. POH with wire line. R/D SWS. Clear rig floor. MIU 5" mule shoe on HWDP &RIH to 572'. P/U 13 3/8" RTTS. Set RTTS below wellhead. Test 13 318" casing, pressure up to 1650 psi below RTTS, no test. Pressure up above RTTS to 2000 psi, OK. Leave RTTS set & POH, UD running tool. Change bottom rams from 9 5/8" to 2 7/8" X 5" variable. Pull wear ring, set test plug. Test bottom rams to 250 low, 4000 psi high test. Pull test plug, set wear ring, UD test joint. M/U RTTS running tool. RIH and engage RTTS, release and pull to rig floor. UD RTTS. POH with HWDP from 572'. P/U RTTS &circ valve. RIH with RTTS to 571'. Test 13 3/8" casing to 2000 psi, OK. R{H, test casing @ 1141' and 1711'. Tag EZSV C~ 2370'. POH to 2280'. Test below RTTS, pressure up to 2000 psi, test bled off rapidly to 875 psi. Test above RTTS to 2000 psi, OK. POH with RTTS from 2280'. Break & UD RTTS. Clear rig floor. UD 13 318" RTTS, clear rig floor. Bring subs and tools for whipstock BHA to rig floor. P/U whipstock BHA &GyroData gyro tool to 15S'. Orient tools and UBHO sub. Upload MWD tools. Diffaculty reading GyroData. Printed: 2/13!2006 12:Q0:39 PM BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: 0 1-08 Common W ell Name: 0 1-08 Spud Date: 6/4/1975 Event Nam e: REENTE R+COM PLET E Start : 12/2612005 End: 2/712006 Contractor Name: NABOB S ALASK A DRI LLING i Rig Release: 2/7/2006 Rig Name: NABOB S 2ES Rig Number: r Date ~ From - To ~ Hours I i Task i Codej I NP7 ~ Phase ! Description of Operations 1/1/2006 07:00 - 08:00 1.00 STWHIP P WEXIT - Shallow test MWD and GyroData tools, pump C~ 600 gpm @ 700 psi. Blow down top drive. 08:00 - 09:00 1.00 STWHIP P WEXIT P/U BHA to 168', bumper sub will not close, P1U new bumper sub. 09:00 - 10:30 1.50 STWHIP P WEXIT RIH with BHA, 215K drag from 168' to 997'. 10:30 - 13:00 2.50 STWHIP P WEXIT RIH from 997' to 2139', 2/5K intermittent drag to 2115'. Work through tight spot Q 2115'. UWT &DWT = 115K. Wash down from 2115' to 2325'. Orient whipstock 80 degrees left. 13:00 - 14:30 1.50 STWHIP P WEXIT R/U Sperry Sun E-line truck. RIH with gyro for check shot. R/D gyro and E-line. 14:30 - 15:30 1.00 STWHIP P WEXIT Orient whipstock 80 degrees left and set ~ 2383'. (Halliburton EZSV was set @ 2370' and slipped down hole to top of 9 518" cut off @ 2390'.} 15:30 - 16:00 0.50 STWHIP P WEXIT Displace seawater from well to 8.8 ppg LSND milling fluid. Pump @ 600 gpm C~ 760 psi. 16:00 - 00:00 8.00 STWHIP P WEXIT Mill window in 13 3/8" 72 # casing from 2350' to 2356'. UWT = 120K, DWT = 120K, RWT = 115K. Pump ~ 600 gpm @ 820 psi. RPM = 90 to 100, torque off bottom = 1250, on = 5/7000. Recovered 180 pounds of metal cuttings. 1!212006 00:00 - 18:00 18.00 STWHIP P WEXIT Mill window in 13 3/8" 72 # casing to 2377'. Pump @ 600 gpm 850 psi. RPM = 90. Torque = 15l25K. WOB = 12l26K. Drill 20' of new formation to 2405'. UWT = 120K, DWT = 120K, RWT = 115K. TOW Q 2353', BOW ~ 2377', TD of 12.25" hole @ 2387', TD of 11.625" hole ~ 2405'. Recovered 950 # of metal cuttings. 18:00 - 19:00 1.00 STWHIP P WEXIT Pump Super Sweep and ream window clean, CBU X 2 Ca? 650 gpm. 19:00 - 19:30 0.50 STW HIP P WEXIT Take gyro 4 point survey. 19:30 - 20:00 0.50 STWHIP P WEXIT Perform FIT test to 10.8 ppg mud weight. TVD = 2405', Mud weight = $.8 ppg, Pressure = 250 psi. 20:00 - 21:00 1.00 STWHIP P WEXIT Pull 1 stand drill pipe. Slip & cut drill line. 21:00 - 21:30 0.50 STWHIP P WEXIT Service top drive. 21:30 - 22:00 0.50 STWHIP P WEXIT POH to 965'. 22:00 - 00:00 2.00 STWHIP P WEXIT POH, stand back 6 stands of HWDP, UD 9, 6 1/4" drill collars. Down load MWD. 1/3/2006 00:00 - 01:30 1.50 STWHIP P WEXIT Stand back MWD & gyro tools. L/D mills. Full gage. Clear & clean rig floor. 01:30 - 02:00 0.50 STWHIP P WEXIT Service wear ring. 02:00 - 04:00 2.00 STWHIP P WEXIT Flush BOP stack & surface equipment. Remove rotary table cover and clean out with super sucker. 04:00 - 09:00 5.00 STWHIP P WEXIT PJSM. P/U 12 1/4" drilling BHA - 1.83 deg motor, gyro tools, LWD, MWD. Orient. Shallow test. RIH wf BHA. 09:00 - 10:30 1.50 STWHIP P WEXIT RIH picking up DP from 850' to 2,266'. 10:30 - 11:30 1.00 STWHIP P WEXIT Install blower hose. SPR's. Orient 80 LHS. Slide thru window. No problems. 11:30 - 14:00 2.50 DRILL P INTi Drill from 2,405' to 2,552'. Stopped drilling to validate gyro 1 surreys. Will cross hard on traveling cylinder map if surveys are correct. 14:00 - 14:30 0.50 {DRILL N DPRB INT1 Pull up to 2,350' to run Gyro on E-Line 14:30 - 19:30 5.00 {DRILL N DPRB INT1 RU Sperry Sun E-line. Ran eight check shots with Gyro on E-Line from 2,333 to 2,429'. GWD surveys were good. MW in 8.8 ppg, MW out 8.7 Ppg. 19:30 - 20:00 0.50 DRILL N DPRB INTi Slug DP. POOH to check tool orientation. Printed: 2(13/2006 12:00:39 PM BP EXPLORATION Operations Summary Report Page 5 of 16 Legal Welt Name: 0 1-OS Common W ell Name: 0 1-08 Spud Date: 6/A~/1975 Event Nam e: REENTE R+COM PLET E Start : 12!2612005 End: 2/7/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/7/2006 Rig Name: NABOB S 2ES Rig Number: Date ~ From - To Hours i Task Code ~~ ~ NPT ~ ~ Phase ; Description of Operations 1!3!2006 20:00 - 22:30 2.50 DRILL N DPRB INTi Stand back BHA to UBHO sub. Check tool orientation - o.k. Down load. L.D DM HOC and GR/ RES. 22:30 - 00:00 1.50 DRILL N DPRB INTt PU DM HOC on top ofi GWD, GR/ RES -orient tools. P.U. TM HOC and UBHO. Upload. i!4/2006 00:00 - 02:00 2.00 DRILL N DPRB INT1 Upload MWD,orient UBHO sub. Shallow test. RIH w! BHA. 02:00 - 02:30 0.50 DRILL N DPRB INTi RIH to 2,271'. 02:30 - 03:00 0.50 DRILL N DPRB INT1 Connect blower hose. Orient 85 deg LHS. Slide thru window to 2,400'. No problems. 03:00 - 06:00 3.00 DRILL N DPRB INT1 Orient low side and slide 200 fph from 2,400' to 2,458' to drop angle.595 gpm @ 1,500 psi., WOB 5-7K, Diff pressure 70 - 80 psi. Survey @ 2,414' - 1.94 deg, azmuith 359 deg. Slide fl 2,458' to 2,550' @ 200 - 250 deg TF to drop and turn left. Survey C~3 2,509' - 5.2 deg azmuith 346 deg. 06:00 - 06:30 0.50 DRILL P INT1 Drill from 2,552' to 2,598'. AST =.35 hrs, ART = 0 hrs. 06:30 - 09:30 3.00 DRILL N DPRB INT1 Pull up to 2,457'. Slide /trench out hole f12,457' to 2,598' with 160? TF. 09:30 - 10:00 0.50 DRILL P INT1 Drill from 2,598' to 2,616'. AST = .15 hrs, ART = 0 hrs. 10:00 - 11:00 1.00 DRILL N DPRB INT1 Circ at 2,616'. Monitor well. Static. MW in & out 8.9 ppg. Slug DP. 11:00 - 12:00 1.00 DRILL N DPRB INT1 POOH to check whipstock orientation. 12:00 - 15:30 3.50 DRILL N DPRB INT1 Pulled BHA -Down load - L.D. MWD, GWD, Stab, Motor. Clear floor. 15:30 - 16:30 1.00 DRILL N DPRB INT1 PU Whipstock hook, float, BS, Jars, UBHO, and 6 - 6 1/4" DC's. 16:30 - 17:00 0.50 DRILL N DPRB INTi RIH with DP to 2,365'. 17:00 - 20:00 3.00 DRILL N DPRB INT1 Attempt to hook whipstock - no success. 20:00 - 23:00 3.00 DRILL N DPRB INT1 RU Sperry Sun E-Line and RIH w/ Gyro. Orient hook to 282 deg and attempt of hook whipstock. Hooked whipstock - whipstock slide ~ 336 deg. POOH w/ wire line and rig down wire line. MW in 9.0 ppg, MW out 8.9+ ppg 23:00 - 00:00 1.00 DRILL N DPRB INTi Flow check. Slug DP. POOH to BHA. 1/5/2006 00:00 - 01:30 1.50 DRILL N DPRB INT1 LD BHA. Clear rig floor. 01:30 - 02:30 1.00 DRILL N DPRB INT1 MU mule shoe sub and RIH with DP open ended to bottom at 2,616' to spot cement kick off plug. 02:30 - 03:30 1.00 DRILL N DPRB INT1 Cic and cond mud - MW 9.0 +ppg. 03:30 - 04:30 1.00 REMCM N DPRB INT1 PJSM. Dowell spotted balance cement kick off plug in open hole from 2,616' to 2,350'. Pumped 20 bbls water, 63 bbls Class "G" ~ 16.0 ppg and displace w12.8 bbls water and 33 bbls mud. CIP @ 0420 hrs. -Cement Calcs =Open hole volume + 35% excess + 50' inside 13-3/8" csg above the Top of the whipstock. 04:30 - 05:00 0.50 CEMT N DPRB INT1 Pulled out off hole slow to 1,989`. Circ @ 650 gpm to clean up DP. 05:00 - 05:30 0.50 DRILL N DPRB INTi RIH to 2,200'_ Wash down to BOW @ 2,377'. 05:30 - 06:00 0.50 DRILL N DPRB INTi Circ bottoms up 600 gpm 300 psi. No cement to surface. Monitor well. Static. BD top drive. MW in & out 9.0+. 06:00 - 06:30 0.50 DRILL N DPRB INTi POOH from 2,377' to 2,088'. 06:30 - 07:30 1.00 DRILL N DPRB INT1 Lubricate rig and top drive. 07:30 - 08:30 1.00 DRILL N RREP INT1 Repair leak on TD end valve. Replace o-ring. 08:30 - 11:00 2.50 DRILL N DPRB INTi RIH from 2,088' to 2,377'. Wash down from 2,377' and tag top cement plug ~ 2,424'.. CBU. 600 gpm @ 350 psi. Cement to surface. Monitor well. Static. Slug DP. BD top drive. MW in & out9.1 ppg. Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page 6 of 16 operations Summary Report Lego{ Well Name: 0 1-08 Common W ell Name: 0 1-08 Spud Date: 6/4/1975 Event Nam e: REENTE R+COM PLET E Start : 12/26!2005 End: 2!7/2006 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 2/712006 Rig Name: NABOR S 2ES Rig Number: Date ! From - To i Hours ~I Task ~ Code j i NPT ~ Phase ~ Description of Operations 1/5/2006 11:00 - 12:00 i.00 DRILL N DPRB INT1 POOH and LD mule shoe sub. 12:00 - 13:30 1.50 DRILL N DPRB INT1 MU BHA -Bit, 8" motor - 2.12 deg, UBHO -RIH w/ flex collars, jars, and HWDP. 13:30 - 14:00 0.50 DRILL N DPRB INTi RU E-line in derrick. 14:00 - 15:00 1.00 DRILL N DPRB INT1 RIH to 2,380'. 15:00 - 18:00 3.00 DRILL N DPRB INT1 RIH w/ gyro on wireline -orient motor to 270 deg. POOH w! wire line. RIH to 2,414' -Gyro survey. 18:00 - 00:00 6.00 DRILL N DPRB INT1 Drill f( 2,424' to 2,604'. AST = .98 hrs, ART = 0 hrs. Wire line Gyro survey / TF every 30'. 450 gpm C~ 850 psi. UP 110K, DN 110K, RT 110k. 1(6(2006 00:00 - 05:00 5.00 DRILL P INT1 Drill from 2,604' to 2,699'. Wire! line gyro survey 1 TF every 30'. AST = .64 hrs. ART = 0 hrs. UP 110K, DN 110k, 600 gpm @ 1,200 psi off 1 1,250 psi on. 05:00 - 05:30 0.50 DRILL P INT1 Circ 10 min. MW in & out 9.1 ppg. Monitor well. POOH to 2,287'. 05:30 - 06:30 1.00 DRILL P INT1 CBU. String in 8.9 ppg pre- mixed mud into system. MW in & out 9.1 ppg.Monitor well. Slug DP. Blow down TD 06:30 - 07:00 0.50 DRILL P INT1 POOH with DP for BHA change. 07:00 - 09:30 2.50 DRILL P INT1 Pull BHA -stand back HWDP, jars, NMDC's. Set motor to 1.5 deg. Break bit and LD motor. 09:30 - 13:00 3.50 DRILL P INT1 MU bit, 8" motor - 1.5 deg, stabilizer. PU MWD J LWD's / UBHO sub. Upload MWD.RIH w/ BHA. Surface test. 13:00 - 14:30 1.50 DRILL P INT1 RIH to 2,699'. 14:30 - 00:00 9.50 DRILL P INT1 Drill from 2,699' to 3,571' '. AST = 4.85 hrs, ART = 2.18 hrs. UP 125K, DN110k, RT 115k,T0 off 4K,T0 on 5K. 599 gpm ~ 1,500 psi off btm, 1,640 psi on btm. 1/7/2006 00:00 - 23:30 23.50 DRILL P INTi Drill from 3,571' to 5,467' TD. UP 145k, DN 115K, RT 130K, TO on 7K, TO off 6K. 600 gpm ~ 1,650 psi. 23:30 - 00:00 0.50 DRILL P INTi Circ -pump 50 bbl hi-vis sweep - 650 gpm C~ i,950 psi., 80 rpm, recpicate. 1/8/2006 00:00 - 01:30 1.50 DRILL P INT1 Girc hole clean. Pump 50 bbl hi-vis sweep around and CBU 2X. 650 gpm @ 1,950 psi. Rotate 80 rpm (recipicate. Monitor we{I. MW in 9.2 ppg, MW out 9.2+ ppg. 01:30 - 09:30 8.00 DRILL P INTi Wiper trip -POOH to 4,990'. Ho{e tight - 40 -50K over pull / swabbing - wipe hole. Back ream out f/ 4,990' - 4,885', 4,426' - 4,333', 4,240' - 2,431' - pumping 480 gpm @ 975 psi, 75 RPM. 09:30 - 10:30 1.00 DRILL P INT1 Cut drilling line. Service and inspect drawworks. 10:30 - 1 i:00 0.50 DRILL P INTi Service top drive. 11:00 - 13:00 2.00 DRILL P INT1 RIH from 2,336' to 5,467'. Ream from 4,670' to 4,713'. 13:00 - 15:00 2.00 DRILL P INT1 Pump hi-vis sweep around and circ hole clean - 550 gpm C~3 1,580 psi., 100 RPM. Monitor well. Static. Slug pipe blow down TD. MW in & out 9.1 ppg. 15:00 - 17:00 2.00 DRILL P INT1 POOH to 2,710'. No problems. 17:00 - 19:00 2.00 DRILL P 1NT1 Mad pass from 2,710' to 2,100'.250 FPH Remove blower hose. 19:00 - 20:30 1.50 DRILL P INT1 POOH to run 9 518° csg. Stand back HWDP and jars. 20:30 - 23:00 2.50 DRILL P INT1 Download MWD. Flush too{s. LD BHA. Clear rig floor. 23:00 - 00:00 1.00 BOPSU P LNR1 PJSM. Change top rams to 9 5/8". Pull wear ring. Set test plug. 1/9/2006 00:00 - 01:30 i,50 BOPSU P LNR1 RU test door seals to 250 psi low and 4,000 psi high. RD test equipment. Blow down. Oi:30 - 03:30 2.00 CASE P LNR1 RU to run 9 518" csg. Insta{I long bans. PJSM. 03:30 - 05:00 1.50 CASE P LNR1 M.U. Shoe track. Clear floats. P.U. Franks fill up tool. Printed: 211312006 12:00:39 PM BP EXPLORATION Operations Summary Report Lega{ Wefl Name: 01-08 Common Well Name: 01-08 Event Name: REENTER+COMPLETE Start: 12/26/2005 Contractor Name; NABOBS ALASKA DRILLING 1 Rig Release: 2Rl2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To i Hours i Task I~~ Code I NPT ~ Phase 1/9/2006 105:00-10:00 S.OO~CASE P LNRi 10:00 - 11:00 1.00 CASE P LNR1 11:00 - 15:00 4.00 CASE P LNR1 15:00 - 16:00 1.00 CEMT P LNR1 16:00 - 17:00 1.00 CEMT P LNR1 17:00 - 18:00 { 1.00 I CEMT I P I I LNR1 18:00-21:00 ~ 3.00{CEMT {P { {LNR1 21:00 - 22:00 I 1.001 CEMT I P I I LNR1 22:00 - 00:00 2.00 CEMT P LNR1 1/1012006 00:00 - 02:30 2.50 CEMT P LNR1 02:30 - 04:30 2.00 CEMT P LNR1 04:30 - 06:00 I 1.501 CEMT ! P I I LNR1 06:00 - 08:00 2.00 BOPSUF{ P LNR1 08:00 - 12:00 4.00 WHSUR P LNR1 12:00 - 15:00 I 3.001 WHSUR I P I I LNRi 15:00 - 17:30 2.50 BOPSU P LNRi 17:30 - 18:30 1.00 BOPSU P LNR1 18:30 - 19:00 0.50 BOPSU P LNR1 19:00 - 23:30 4.50 BOPSU P LNR1 23:30 - 00:00 I 0.501 BOPSUR P I I LNRi 1!i 112006 { 00:00 - 02:00 { 2.00 CASE I P I {INT2 02:00 - 03:00 1.00 WHSUR N I HMAN INT2 03:00 - 05:00 2.00 W HSUR N ~ HMAN INT2 Page 7 of 16 Spud Date: 6/4/1975 End: 2/7/2006 Description of Operations Run 9 518"' 40# L80 BTC csg to 2,275'. Circ -pump 9 518" csg volume, stage pump up to 6 BPM C~ 350 psi. UP wt145K, DN wt 85k. Run 9 5/8" csg from 2,275' to 5,465'. No problems. CBU - 7.8 BPM 630 psi. L.D Franks fill up tool. M.U. cementing head. Blow down top drive. Circ and recipicate pipe - 7.8 BPM @ 600 psi. PJSM. UP 250K, DN 150k. Dowell pumped first stage as follows - 5 bbls water ahead. Test lines to 4,100 psi. Pumped 20 bbls CW-100 ~ 8.3 ppg, 80bbls Mud push !I @ 10.6 ppg. Dropped btm plug. Pumped 179 bbls ASL @ 10.7 ppg, 78 bbl Class "G" @ 15.8 ppg, 30 bbls Class "G" Durastone @ 16.0 ppg. Dropped top plug. Dowell displaced w/ 414 bbls mud @ 7.25 BPM .Stopped recipicating w/ cement out shoe -dragging. Plug down and job complete C~ 20:45 hrs. Full returns throughout job. Plug did not bump. Checked floats - holding. Drop opening plug. Pressure to 1,300 psi and openned ES cementer @ 2,117'. CBU 7 BPM @ 450 psi -recovered 40 bbls cement. Full returns. Circ. Clean surface equipment. Flush out stack. Wait on cement -Circ 7.3 BPM @ 430 psi. PJSM. Dowell cemented second stage thru ES cementer ~ 2,117' as follows -Pumped 5 bbls water. Test lines to 4,000 psi. Pumped 10 bbls CW-100 @ 8.33 ppg, 20 bbls mud push II ~ 10.6 ppg, 148 bbls ASL ~ 10.7 ppg. Dropped closing plug. Dowell displaced w/ 165 bbls mud ~ 7 BPM. Pressure up to 1,400 psi to close ES cementer. Released pressure. Held. CIP @ 0415 hrs. Circ 25 bbls good cement to surface. Flush out stack and clean surface equipment. Suck out 9 5/8" csg. RD cementing head. ND bop's and csg head. PU stack. Set slips on 9 5/8" csg. Landed 9 5!8" with 100K on slips. Cut off 9 5/8" csg. Removed csg spool and set back BOP's. PJSM. Install 9 5!8" pack off w! running toot. Install csg spool. Test pack off to 3,500 psi. OK. Install secondary annulus valve. PJSM. Clean out drip pan. NU BOPE. Install mousehole. PJSM. Change top rams to 3.5" x 6" VBR. RU to test BOP's. Set test plug and RU test joint. Test BOPE as per BP policy to 250 psi low and 4,000 psi high. Hydril to 250 psi low and 2,500 psi high. Test witness waived by Lou Grimaldi w/ AOGCC. Test witnessed by Mike Whiteley - Fairweather, Ronnie Dalton -Nabors. RD test Equipment. Set wear ring. Blow down surface equipment. Start making up drill out BHA -unable to get 8.75" od stabilizer thru well head. Pulled wear ring - o.k. Stabilizer stopping on top of 9 5!8" pack-off bushing. Wait on FMC and pack-off running tool. Part well head at bottom of 7" csg spool and pick up w/ stack. Grind out 9 5/8" pack-off bit guide I.D. to 8.750". Ran 8 314" O.D. stabilizer thru pack-off &csg - o.k. Printed: 2713/2006 12:00:39 PM BP EXPLORATION Operations Summary Report Legal Well Name: 01-08 Common Well Name: Oi-08 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To j Hours Task I Code ~ NPT li Start: 12/26/2005 Rig Release: 2/7/2006 Rig Number: Phase 1!11/2006 105:00 - 06:30 I 1.50 WHSUR N HMAN L 06:30- 08:00 1.50 DRILL ~P C INT2 {NT2 08:00 - 09:00 1.00 DRILL P INT2 09:00 - 10:00 1.00 DRILL P INT2 10:00 - 14:00 4.00 DRILL P INT2 14:00 - 15:00 1.00 CASE P INT2 15:00 - 17:00 2.00 DRILL P INT2 i7:00 - 17:30 0.50 DRILL P INT2 17:30 - 18:30 1.00 DRILL P INT2 18:30 - 19:00 I 0.501 DRILL I P I I INT2 19:00 - 19:30 0.50 DRILL P INT2 19:30 - 22:30 3.00 DRILL P INT2 22:30 - 00:00 1.50 DRILL P INT2 1/12/2006 00:00 - 02:30 2.50 DRILL P INT2 02:30 - 03:30 1.00 DRILL P INT2 03:30 -04:00 0.50 DRILL N RREP INT2 04:00 - 06:30 2.50 DRILL P INT2 06:30 - 00:00 17,50 DRILL P INT2 i/13/2006 100:00 - 01:30 I 1.501 DRILL I P I I INT2 01:30 - 02:00 0.50 DRILL P INT2 02:00 - 04:30 2.50 DRILL P INT2 04:30 - 05:30 1.00 DRILL P INT2 05:30 - 07:00 1.50 DRILL P INT2 07:00 - 10:30 3.50 DRILL P INT2 10:30 - 12:00 1.50 DRILL P INT2 12:00 - 13:00 1.00 DRILL P INT2 13:00 - 14:00 1.00 DRILL P INT2 14:00 - 00:00 10.00 DRILL N HMAN INT2 1/14/2006 100:00 - 01:45 I 1.751 DRILL I N I HMAN I INT2 01:45 - 02:30 0.75 DRILL P INT2 02:30 - 03:00 0.50 DRILL P INT2 03:00-04:001 i.00~DRILL IP I (INT2 04:00 - 00:00 I 20.001 DRILL I P I INT2 Page 8 of 16 Spud Date: 6/4/1975 End: 2/7/2006 Description of Operations N.U. csg spool and test pack-off to 3,500 psi. PJSM. M.U. drill out BHA - 8 314" mill tooth bit, B.S., Stablizer, Fllex collars, HWDP, jars, HWDP. RIH picking up DP to 2,113'. Connect blower hose. Drill out plugs and ES cementer C~ 2,116'. Wash down to 2,132'. RIH picking up 5" DP. Tagged cement C~3 5,346'. Test 9 5/8" csg to 3,500 psi for 30 min. Final pressure 3,440 psi. Drill cement and float equipment from 5,364' to shoe C~3 5,465'. Drill new formation from 5,467' to 5,487'. Displace well with 10.2 ppg LSND mud -pumped 49 bbls hi-vis EP mud lub spacer ahead - 12 BPM @ 650 psi. Performed FIT to 11.6 ppg EMW - 325 psi w/ 10.2 ppg mud @ 4,472' TVD. Blow down surface equipment. Monitor well. Slug DP. BD top drive. MW in & out 10.2 ppg. POOH. Stand back BHA. LD bit / stablizer. PJSM. P.U. Rotary steerable drilling BHA. Upload MWD. PU BHA. Pressure test Geo Pilot manifold. Surface test Geo Pilot and MWD. Service Top drive and Drawworks. Repair Iron Roughneck. RIH to 5,467 '. Fill DP every 3,000'. Install blower hose. SPR's. Base line ECD's. Directional drill 8 3/4" hole from 5,487' to 6,339'. ART 12.8 hrs. ROP decreased to 1 FPH @ 6,336' - 6,339'. Vary WOB, RPM, Pump rate. Unable to get bit to drill. UP 175K, DN 105k, RT 130K, RPM 70 - 120, TO off 10K, TO on 11 K. 596 gpm @ 2,000 psi. ECD 10. 85 ppg. Attempt to get bit to drill @ 6,339'. Vary WOB / RPM. Unable to get bit to drill. Build slug. MW in & out 10.2 ppg. Monitor well. Static. Slug DP. Blow down surface equipment POOH to BHA. POOH w/ BHA. Bit not damaged -full gage. Two chipped cutters. Break off bit. Down load MWD. L.D. Geo Pilot. MU BHA - 8 3/4" mill tooth bit ! 7" motor - 1.22 deg. Orient. Upload MWD. Shallow test. Finish RIH w! BHA RIH to 5,465'. Cut drilling line. Adjust brakes. Lubricate rig. Service top drive. Wait @ shoe for close approach well DS 01-20 to have plug set in tubing tail pipe and tested. General rig housekeeping and equipment maintenance. Continue wait C«? shoe for close approach well DS 01-20 to have plug set in tubing tail pipe and tested. TIH to 6,300' /Wash to bottom. Drill from 6,339' to 6,396'. Hard stringer from 6,339' to 6,343', then broke through. Lost pump pressure -Change shaker screen and clean screens on both mud pumps. Drill from 6,396' to 7534'. Up 185K, DN 110K, RT 135K, Rotary 90 rpm, TQ off 10.5K, TQ on 10K, 596 gpm C~ 2,590 psi. ECD = 11. 12 ppg. Gal ECD = 11.11. Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 0 1-08 Common W ell Name: 0 1-08 Spud Date: 6/4/1975 Event Nam e: REENTE R+COM PLET E Start : 12/26/2005 End: 2!7/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/7/2006 Rig Name: NABOB S 2ES Rig Number: Date i From - To Hours I Task i , Code I , ' NPT i Phase II Descri tion of O erations p P - - i 1fi5l2006 00:00 - 01:30 1.50 DRILL P INT2 Drill from 7534' to 7630'. Up 185K, DN i10K, RT 135K, Rotary 90 rpm, TQ off 10.5K, TO on 1 OK, 596 gpm @ 2,590 psi. ECD = 11. 12 ppg. Cal ECD = 11.11. ROP 60-70 FPH. 01:30 - 02:30 1.00 DRILL P INT2 Pump hi-vis sweep around to c{ean hole/ Flow check well/ Pump Dry Job I Blow Down Top Drive. Mud Wt in & out 10.2 pp9~ 02:30 - 05:00 2.50 DRILL P INT2 POOH to Shoe. No problems !Flow check at shoe. Finish POOH with DP. 05:00 - 08:30 3.50 DRILL P INT2 POOH with BHA. Stand back HWDP1Jars Service float and download MWD. Lay down Motor, MWD and clear floor. 08:30 - 11;00 2.50 DRILL P INT2 P/U Geo pilot, MW D and remaider of BHA#12 /Run BHA in hole to 835' 11:00 - 13:30 2.50 DRILL P INT2 TIH 835' to 5464' (MU Ghost reamer on std#10xx) fill pipe every 3000' 13:30 - 14:30 1.00 DRILL P INT2 Cut 160' of Drilling line and service drawworks 14:30 - 15:30 1.00 DRILL P INT2 Service Top Drive and install blower hose 15:30 - 16:30 1.00 DRILL P INT2 RIH 5464' to 7450' 16:30 - 17:30 1.00 DRILL P INT2 Ream from 7450 - 7630 f Circulate to reduce ECD's 17:30 - 00:00 6.50 DRILL P INT2 Drill from 7630' to 7982'. Up 210K, DN 110K, RT 140K, Rotary 140 rpm, TO off 13-15K, TQ on 15-18K, 600 gpm C~ 2,400 psi. ECD = 1 i ppg. Cal ECD = 11.07. ROP 100-130 FPH. MW=10.2ppg In and Out 111612006 00:00 - 15:30 15.50 DRILL P INT2 Drill from 7682' to 9164'. Up 225K, DN i20K, RT 160K, Rotary 110 rpm, TO off 14-17K, TO on 17-19K,600 gpm Geo Pilot tool having difficulty hooking up to hole causing angle to drop below porposed tangent angle 15:30 - 16:30 1.00 DRILL P INT2 Pump HV sweep - CBU 2 times /Observe well Pump dry job MW in 10.2 MW out 10.2 16:30 - 19:00 2.50 DRILL P INT2 Trip out to casing shoe /monitor well 19:00 - 21:00 2.00 DRILL P INT2 POH 5465' to BHA 0835' 21:00 - 23:30 2.50 DRILL P INT2 POH with BHA /Break bit / DN load MWD f LD MWD &Geo Pilot 1 Clear Floor 23:30 - 00:00 0.50 DRILL P INT2 M/U BHA #13 Adjust Motor setting to 1.5 1!1712006 00:00 - 02:00 2.00 DRILL P INT2 UP-Load MWD& Surface test -Pick up remaining BHA -Ghost reamer 10xx stands up 02:00 -04:00 2.00 DRILL P INT2 TIH 835' to 5355' fill pipe every 3000' 04:00 - 05:00 1.00 DRILL P INT2 Cut Drilling line and service drawworks 05:00 - 05:30 0.50 DRILL P INT2 Service Top Drive, crown & Tube Elmago coupling 05:30 - 07:30 2.00 DRILL P INT2 TIH 5355' to 9065' Fill pipe every 3000' No problems running in Dn 115K 07:30 - 00:00 16.50 DRILL P INT2 Wash 99' to 9164' Drill from 9164' to 10293'. Up 210K, DN 135K, RT 160K, Rotary 80 rpm, TQ off 13K, TO on i7K,575 gpm Torque increased to approximately 20K on bottom, so lubricate °!° raised from 1.5 to 3.5 reducing torque by 3k. mud wt 10.2 in 10.2 out 1118!2006 00:00 -04:30 4.50 DRILL P INT2 Drill from 9164' to 10573'. Up 220K, DN 130K, RT 165K, ~ Rotary 80 rpm, TQ off 16/19K, TO on 16(17K,575 gpm 2880 psi on bottom 2670off mud wt 10.3 in 10.3 out 04:30 - 06:00 1.50 DRILL N RREP INT2 Work on #1 mud pump Liner /Crack in Mud end 06:00 -06:30 0.50 DRILL N RREP INT2 Mix and pump dry job /observe well 06:30 - 12:00 5.50 DRILL N RREP INT2 POH to 5366' Max up 250K no problems (NPT time due to pump repair) j 12:00 - 13:00 1.00 DRILL N RREP INT2 Work on #1 mud pump Liner !Service Top drive (NPT time due Printed: 2/13/2006 72:00:39 PM BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Spud Date: 6!4/1975 Event Name: REENTER+COMPLETE Start: 12/2612005 End: 217/2006 Contractor Name: NABOBS ALAS KA DRILLING f Rig Release: 2/7!2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~ Hours I Task ~ ' 1 Code j NPT I Phase I Description of Operations ! i _-----_ 1/18/2006 --_ - 12:00 - 13:00 --- 1.00 --- DRILL - N - RREP - - INT2 - _ _- to pump repair) 13:00 - 15:30 2.50 DRILL N RREP INT2 POH with BHA#11 5366' to 831'(NPT time due to pump repair) 15:30 - 18:00 2.50 DRILL P INT2 Rack back HWDP & Jars DN load MWD - LD MWD and Motor, Clear floor 18:00 - 21:00 3.00 DRILL P INT2 MU BHA#12 T/825' upload & surface test MWD 590gpm C«~ 1170psi 21:00 - 00:00 3.00 DRILL P INT2 Trip in picking up singles from pipe shed 825' - 3942' Fill pipe and circulate 1 i/2 drill pipe volume 575gpm @1900psi 1/19/2006 00:00 - 03:00 3.00 DRILL P INT2 TlH 3942' - 10463' Fili pipe every 3000' 03:00 - 00:00 21.00 DRILL P INT2 Wash and ream F/10463' T/10577' Drill from 10573' to11668 '. Up 220K, DN 135 K,RT165 K, Rotary 90-125 rpm, TO off13 K, TQ on 16K,555 gpm 2560 psi mud wt 10.1 in 10.2 out Lubricant pill added at 11,000' reduced torque by 4-5K 1120!2006 00:00 - 00:00 24.00 DRILL P INT2 Drill from 11668' to 13025 '. Up 245 K, DN 135 K,RT 175 K, Rotary 120 rpm, TO off 20-21 K, TO on 22-23 K,550 gpm 2950 psi off 3050 psi on mud wt 10.8 in 10.9 out Wt up to 10.8ppg at 12450 W/12.9ppg spike fluid /Torque increase of 4-6 K after wt at 10.8ppg 1!2112006 00:00 - 00:00 24.00 DRILL P INT2 Drill from 13025' to 14003 '. Up 265 K, DN 140 K,RT 182 K, Rotary 90 rpm, TO off 18 K, TO on 19-20 K,550 gpm 3260 psi on mud wt 10.8 in 10.8+ out 1/22/2006 00:00 - 08:00 8.00 DRILL P INT2 Drill from 14003' to TD @ 14212 ', Up 270 K, DN 140 K,RT 182 K, Rotary 90 rpm, TO off 18 K, TO on 19-20 K,550 gpm 3260 psi on mud wt i0.8 in 10.9 out 08:00 - 12:30 4.50 DRILL P INT2 Circulate bottoms up sample for geo /Pump hi vis sweep / Rotate and reciprocate pipe /Blow down Geo-Span manifold / Pump dry job !Blow down top drive 12:30 - 17:00 4.50 DRILL P INT2 POH F114,163' - To 5358' !Max up 330K No problems 17:00 - 18:00 1.00 DRILL P INT2 C/O elevatorsfM/U storm packer and single set at 38' / UD single & stinger /test to 1000psi 18:00 - 00:00 6.00 BOPSU P INT2 PJSM /Drain Stack and pull wear ring ! M/U and install test plug /Blow through lines and attempt to test -test plug leaking / R.I.L.D.S. -Still leaking /Pull and inspect test plug- install and test against blind rams -still leaking !Pull and run plug upside down as per FMC /Pull out lock down screw and view port & confirm seat. R.I.L.D.S. /Test BOP 250 low/4000psi high annular 250 low 2500 high/ Witness of test waived by John Spalding A.O.G.C.C. Test witnessed by Well site leaders Blair Neufeld/Jim Willingham 1/23/2006 00:00 - 04:30 4.50 BOPSU P INT2 Test BOP 250 low/4000psi high annular 250 low 2500psi high/ Witness of test waived by John Spaulding A.O.G.C.C.Test witnessed by Well site leaders Blair Neufeld /Jim Willingham. Phase 2 weather restrictions in effect. 04:30 - 07:00 2.50 BOPSU P INT2 Blow down lines & pull test plug. Install wear ring. Unseat storm packer and pull to floor. LD same. 07:00 - 08:30 1.50 DRILL P INT2 ; Slip & cut drilling line. 08:30 - 11:00 2.50 DRILL P INT2 ~ RIH to 10800 ft. Phase 3 weather conditions announced -travel with heavy equipment escort only. Do risk assessment with Toolpusher. Agree that POH to 9 5/8" shoe is safest course of action. 11:00 - 13:30 2.50 DRILL N WAIT INT2 POH to 9 5/8" casing shoe & secure well. Wait on weather conditions to improve. Crew change was accomplished at y 13:00 hrs with heavy equipment escort. Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page i 1 of 16 Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Spud Date: 6/4/1975 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: 2!7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~~ From - To ~ Hours ~ Task~~~ Code ~ NPT ~ Phase Description of Operations 1/23/2006 13:30 - 00:00 10.50 DRILL N WAIT INT2 Wait on weather to subside. Cleaning rig & minor repairs -low risk work. Midnight crew change completed with heavy equipment escort. 1!24!2006 00:00 - 05:00 5.00 DRILL N WAIT INT2 Waiting on weather. Bit ~ 9 5!8" casing shoe. Phase 3 weather conditions. Monitor well. Filling across top of the hole, well stable. Work on housekeeping and minor low risk projects. 05:00 - 10:00 5.00 DRILL P INT2 Weather improved. No longer phase 3. Trip in hole from 5383' to 13687'. Fill pipe at 3000' intervals. 10:00 - 14:30 4.50 DRILL P . INT2 Wash and ream from 13687' to bottom C~ 14212'. Pump C~ 450 gpm C 2100 psi. Torque = 19/23K ~ 75 rpm. UWT = 300K, DWT = 120K, RWT = 195K. 14:30 - 18:30 4.00 DRILL P INT2 Pump high vis sweep and circulate until clean. Pump Cam? 500 gpm ~ 2700 psi. Take slow pump rates. Monitor well, pump dry job. Blow down top drive. Drop 2 7/8" drift down drill pipe. MWT in and out = 10.8 ppg. 18:30 - 20:00 1.50 DRILL P INT2 POH trom 14212' to 131 i 9'. UWT = 310K, max pull = 380K. DWT = 135K. Hole tight and ratty. Working through tight spots. Run back to bottom. 20:00 - 22:00 2.00 DRILL P INT2 Mix and pump sweep, circ until clean. Rotate and reciprocate pipe. 22:00 - 00:00 2.00 DRILL P INT2 POH from 14212' to 13308' wet. Hole in good shape. UWT = 310K, max UWT = 320K. Monitor well, pump dry job. POH from 11308' to 11793'. 1/25/2006 00:00 -04:00 4.00 DRILL P INT2 POH for 7" liner from 11793' to 9 5/8" shoe ~ 5465' & observe well, stable. Remove top drive blower hose. 04:00 - 09:00 5.00 DRILL P INT2 PJSM. POH LD 5" DP. 09:00 - 13:00 4.00 DRILL P INT2 Monitor well at BHA, stable. POH L/D BHA. Flush tools with water. Down load MWD. L/D HWDP, flex collars, Stabs and Geo Pilot. 13:00 - 14:00 1.00 CASE P LNR2 R/U 7" casing equipment. 14:00 - 22:30 8.50 CASE P LNR2 PJSM. M/U shoe track and check floats are holding. RIH with 7" 26# L-80 BTC-M liner with ES cementer. RIH to 9 5/8" shoe ~ 5465'. 22:30 - 00:00 1.50 CASE P LNR2 Circulate liner volume, pump at 230 gpm @ 500 psi. 1/26/2006 00:00 - 01:30 1.50 CASE N SFAL LNR2 Thaw frozen mud line. 01:30 - 09:00 7.50 CASE P LNR2 RIH into open hole with 7" 26# L-80 BTC-M liner. Record up and down weights every 10 joints. 09:00 - 09:30 0.50 CASE P LNR2 P/U 7" x 9 5/8" liner hanger. Fill void at top of packer with polymer fluid (for cement barrier). 09:30 - 13:30 4.00 CASE P LNR2 RIH with liner on 5" drill pipe. Fill pipe at 10 stand intervals and record up and down weights. RIH to 14197'. P/U cement head and single of drill pipe. Tag bottom @ 14212'. Down weight = 130K, Up weight = 375K. 13:30 - 14:30 1.00 CEMT P LNR2 Break circ, pump C~3 3 bpm @ 950 psi. Stage pump up to 6 bpm Ca? 1330 psi. PJSM. Mix lead cement on the fly. 14:30 - 17:00 2.50 CEMT P LNR2 Line up Schlumberger, pump 5 bbl of water & test lines to 4500 psi. Pump 20 bbl 10.9 ppg Mud Push spacer followed by 120 bbl of 11.0 ppg Lite Crete cement. Pump 32 bbl of 15.8 ppg gas Block tail cement (batch mixed). Drop plug and displace with mud @ 6 bpm. Observe Patch up of liner wiper and bump plug. Pressure up to 1000 psi. Bleed off pressure and check floats. Pressure up to 2800 psi and slack off 60K weight to set Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Spud Date: 6!411975 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: 2!7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2006 Rig Name: NABOBS 2ES Rig Number: Date I From - To i Hours it Task Code ~ NPT II Phase II 1/26/2006 ~ 14:30 - 17:00 ~ 2.50 CEMT ~ P I ~ LNR2 17:00 - 00:00 I 7.001 CEMT I P I I LNR2 1/27/2006 100:00 - 04:00 I 4.001 CEMT I P I I LNR2 04:00 - 07:00 I 3.001 CEMT I P I I LNR2 07:00 - 07:30 I 0.501 CEMT I P I I LNR2 07:30 - 12:00 ~ 4.50 ~ CEMT ~ P ~ ~ LNR2 12:00 - 14:30 I 2.501 CEMT I P I I LNR2 14:30 - 15:30 1.00 CEMT P LNR2 15:30 - 17:00 1.50 CEMT P LNR2 17:00 - 22:30 I 5.501 CEMT I P I I LNR2 22:30 - 00:00 1.50 CEMT P LNR2 iJ28J2006 00:00 - 00:30 0.50 CEMT P LNR2 00:30 - 01:30 1.00 CEMT P LNR2 01:30 - 04:30 3.00 CEMT P LNR2 04:30 - 05:00 0.50 CEMT P LNR2 05:00 - 05:30 0.50 CEMT P LNR2 05:30 - 06:00 0.50 CASE P LNR2 06:00 - 08:00 2.00 CASE P LNR2 08:00 - 09:30 1.50 CASE P LNR2 09:30 - 18:00 8.50 CASE P LNR2 18:30 - 19:30 10.00 CEMT P ~ LNR2 19:30 - 20:30 1.00 CEMT P 20:30 - 22:30 I 2.001 CEMT I P I l LNR2 Description of Operations liner hanger. Increase pressure to 3300 psi and open HOWCO ES cementer. CIP @ 17:00 hrs. CBU @ 8 bpm @ 1800 psi. Trace of cement in returns. WOC, circ @ 3 bpm @ 475 psi. WOC to reach 500 psi compressive strength before cementing 2nd stage on 7" liner. Circ @ 3 bpm @ 475 psi. PJSM. Cement job, stage # 2. Pump 10 bbls of CW 100 pre-flush @ 8.3 ppg. Pump 20 bbls of 11.5 ppg Mud Push II spacer. Mix and pump 170 bbls of 12.5 ppg Lite Crete cement. Drop wiper plug and displace with 268.2 bbls of 10.8 ppg mud @ 5.5 bpm, observe liner wiper plug latch up @ 91.9 bbl away. Bump plug with 2700 psi and close ES cementer. Check floats held. CIP @ 07:00 hrs. Rotate 20 turns to the right and release from liner hanger. Pressure up to 1000 psi and unsting. Pump cement up hole 30 bbl (550 ft). Attempt to set packer with 60K down weight, no indication of shear. CBU & condition mud, +-4 bbl cement in returns. Attempt to reset packer by setting 70K weight down while rotating, no indication of shear. Circ and condition mud while rotating & reciprocating. Pump @ 9 bpm @ 750 psi. UWT = 130K, DWT = 105K. Mix & pump dry job. Blow down top drive. Unable to break top connection with top drive gripper. Break down cement head with tongs. UD cement head and clear rig floor. Cut & slip 102' of drill line. Adjust brakes. Service top drive. Service clutches on desks. Service spline on dynamatic brake. Check gripper, clean and function test. Monitor well. POH UD 5" drill pipe. UD Baker liner running tool. Clear rig floor. M/U 5" mule shoe &RIH with drill pipe from derrick to 3421'. PJSM. RIH with 5" drill pipe from 3421' to 4183'. CBU @ 12 bpm @ 420 psi. Pump dry job, blow down top drive. PJSM. POH LDDP from 4183'. Test 7 "liner/packer to 2000 psi, OK. Blow down top drive. Pull wear ring. Clean rotary table and drip pan with super sucker. PJSM. R/U long bails and 7" casing equipment. R/U torque turn equipment and casing tongs. PJSM with all personell. P/U 7" 26# L-80 BTC-M liner to 439'. RIH with 7" 26# L-80 TC It tieback string to 5306'. UWT = 170K, DWT = 95K. M/U 15' pup joint & XO, space out & locate seal assembly on 7" liner top. R/D casing equipment. M/U cement head and cement hose, verify space out. Break circ @ 2 bpm, stage pump up to 5 bpm @ 300 psi. PJSM with all personell. Pump 40 bbl of high vis spacer with rig pumps. Line up on cementers, pump 5 bbl water & test lines to 4500 psi. Pump 112 bbl of 6.8 ppg diesel & release bottom plug. Pump 34 bbl of 15.8 ppg class "G" cement. Release top plug. Pump 5 bbl water and displace with 203 bbl of 9.5 ppg mud. Bump plug with 1000 psi. Check floats held. Steed off Printed: 2!13!2006 12:00:39 PM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 0 1-08 Common W ell Name: 0 1-08 Spud Date: 6/4/1975 Event Nam e: REENTE R+COM PLET E Start : 1212612005 End: 2/7/2006. Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/7/2006 Rig Name: NABOB S 2ES Rig Number: Date From - To I Hours j Task ~ Code ~~ NPT j Phase ~~ Description of Operations -----i -- i -__; __-- I i 1!2812006 20:30 - 22:30 2.00 CEMT P LNR2 pressure. Slack off on string & stab seal assy into SBR. Check for flow. CIP C~3 22:30 hrs. 22:30 - 23:30 1.00 CEMT P LNR2 Blow down surface equipment. R/D cement head and circ lines. Vacuum mud from 7" landing joint with super sucker. Drain BOP stack. 23:30 - 00:00 0.50 CASE P LNR2 Nipple down BOP. 1/29/2006 00:00 - 00:30 0.50 CASE P LNR2 PJSM. N!D BOP. 00:30 - 02:30 2.00 CASE P LNR2 PJSM. Set 7" casing on emergency slips with 100 K weight. RIU Wachs tool and cut casing. Remove cut joint. Set BOP back. 02:30 - 05:30 3.00 CASE P LNR2 PJSM. N/U 13 5/8" x 5000# tubing spool. Install secondary annulus valve. Test pack-off to 4000 psi. OK. 05:30 - 08:00 2.50 CASE P LNR2 N/U BOP. 08:00 - 09:00 1.00 CASE P LNR2 Change top drive saver sub from 4 1/2" IF to 4" HT40. Change die blocks and stabbing guide. 09:00 - 09:30 0.50 CASE P LNR2 R/U test joint. Set test plug. 09:30 - 11;00 1.50 CASE P LNR2 Test top and bottom rams to 250 low & 4000 high psi. Test annular to 2501ow & 2500 high. Test break between stack & tubing spool 11:00 - 11:30 0.50 CASE P LNR2 RID test joint. Set wear ring. Blow down surface equipment. 11:30 - 14:00 2.50 DRILL P PROD1 Bring tools to rig floor. Change out elevators and handling equipment. M/U clean out BHA, P/U 6 1/8" ATJ4 bit, 4.75" mud motor, 3 flex collars, circ sub & jars: Shallow test mud motor C~3 5 bpm ~ 360 psi. 14:00 - 18:00 4.00 DRILL P PROD1 RIH P/U 4" HT40 drill pipe. Fill pipe C«~ 3128'. R{H to 4993. Install top drive blower hose. Break circ. RIH to 5230', wash down to orifice float collar @ 5293'. 18:00 - 19:00 1.00 DRILL P PRODi Dri{I cement plugs and float collar. Pump ~ 225 gpm ~ 900 psi. Torque off bottom = 3 to 4K @ 30 rpm. WOB = 2/5K. CBU. 19:00 - 23:30 4.50 DRILL P PROD1 Blow down top drive. RIH P/U 4" HT40 drill pipe to 9879'. Wash & ream to 9910'. 23:30 - 00:00 0.50 DRILL P PROD1 Drill cement from 9910' to 9942'. UWT = 185K, DWT = 95K, RWT = 125K. Pump C~3 225 gpm @ 1700 psi. Torque on bottom = 8K, off = 4K. Mud weight in & out = 9.5 ppg. 1/30/2006 00:00 - 02:30 2.50 DRILL P PROD1 Drill cement from 9942'. Grill ES cementer C 9955'. UWT = 185K, DWT = 90K, RWT = 125K. WOB = 15K. Torque = 12K @ 30 rpm. Pump C~3 200 gpm ~ 1300 psi. 02:30 - 06:00 3.50 DRILL P PRODi RIH P1U drill pipe to 14035'. Wash/drill cement to 7" landing collar @ 14125'. 06:00 - 07:00 1.00 CASE P PROD1 Test 7 "casing to 4000 psi. Stage pump up, chart & hold for 30 min, OK. Blow down surface equipment. 07:00 - 10:00 3.00 DRILL P PROD1 Drill float equipment & shoe track to 14212'. F.C. @ 14125', L.C. @ 14167', shoe @ 14212'. 10:00 - 12:00 2.00 DRILL P PROD1 Pump 75 bbl water & 40 bbl high vis spacer. Displace with 8.4 ppg FloPro mud. Pump C~ 275 gpm ~ 1380 psi, reciprocate & rotate. UWT = 175K, DWT = 125K, RWT = 145K. Torque = 516K C~ 30 rpm. 12:00 - 13:30 1.50 DRILL P PROD1 Remove top drive blower hose. Service rig, top drive & crown. Clean shaker beds & mud troughs. 13:30 - 20:00 6.50 DRILL P PROD1 Monitor well, POH from 14135' to 308'. Monitor well @ BHA. POH, stand back HWDP & flex collars. L/D mud motor, clear rig floor. 20:00 - 00:00 4.00 EVAL P PRODi PJSM with SWS & rig crew. R/U & run USIT log. Mud weight in Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: 0 1-08 Common W ell Name: 0 1-08 Spud Date: 6/4/1975 Event Nam e: REENTE R+COM PLET E Start : 12/26/2005 End: 2/7/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/7/2006 Rig Name: NABOB S 2ES Rig Number: Date ~ From - To ~ Hours I Task , Code I NPT ! Phase ~ Description of Operations -- L--J ---1 - ~- -- '----~ --_---- ______ __--------- 1/30/2006 20:00 - 00:00 4.00 EVAL P PROD1 & out = 8.4 ppg. 1/31/2006 00:00 - 05:30 5.50 EVAL P INT2 Run USIT log from bottom @ 14,212' to 1000'. 05:30- 06:30 1.00 EVAL P PROD1 Rig down wireline and clear floor f PJSM bring BHA equipment to floor, 06:30 - 09:00 2.50 DRILL P PROD1 Make up BHA#16 to 382'/ orient,upload MWD, shallow test 09:00 - 09:30 0.50 DRILL P PROD1 PJSM P/U drillpipe 382' to 1005' 09:30 - 16:00 6.50 DRILL P PROD1 RIH F/1005' - 14,181' Fill pipe every 3000' Test MWD @6902' Up wt 220K DN wt 130K 16:00 - 17:00 1.00 DRILL P PROD1 PJSM Slip & Cut Drill line (cut 89') 17:00 - 18:00 1.00 DRILL P PROD1 Service Top drive and Rig 18:00 - 20:30 2.50 DRILL P PROD1 BRK. Circulation Wash F/14,181'- T/14,212' Orient toolface to highside Slide drill from 14,212' - 14,232' 20:30 - 21:00 0.50 DRILL P PROD1 POOH to 14,181' Perform F.I.T. T/825 psiF/10min on chart recorder. Blow down kill line BRK circulation and wash to 14,232' 21:00 - 00:00 3.00 DRILL P PROD1 Slide Drill 14,232' - 14,274' AST=3.22hrs Up wt 195K, DN wt 120K, RT wt 150k, Mud wt in 8.4ppg, Mud wt out 8.4ppg 2!112006 00:00- 05:00 5.00 DRILL P PROD1 Slide Drill 14,232' - 14,274' AST=3.22hrs Up wt 195K, DN wt 120K, RT wt 150k, Mud wt in 8.4ppg, Mud wt out 8.4ppg Pump tube pill @ 14295 due to poor weight transfer to bit. Pill did not have a large effect on sliding. 05:00 - 06:00 1.00 DRILL P PROD1 Circulate bottoms up sample / Monitor well,static 06:00 - 06:30 0.50 DRILL P PROD1 POOH F/14,340' - T/14,212' 06:30 - 07:00 0.50 DRILL P PROD1 Drop dart to open circulating sub, Remove Blower hose, Pump dry job, Blow down Topdrive 07:00 - 14:30 7.50 DRILL P PRODi POOH F/14,212' - T/351' Moniter well @ BHA, Rack back HWDP & Collars,Download and laydown MWD, Lay down Motor 14:30 - 15:30 1.00 DRILL P PROD1 Clear Floor -Service Top Drive 15:30 - 16:30 1.00 DRILL N RREP PROD1 Tighten chain in Draworks /Remove link -add half link 16:30 - 19:00 2.50 DRILL N RREP PROD1 PJSM Thaw frozen Ki11 and Choke lines Between HCR valves and wellbore on BOP stack 19:00 - 21:30 2.50 DRILL P PROD1 Make up BHA #17 21:30 - 23:00 1.50 DRILL P PRODi Shallow pulse test MWD, PJSM, Load nuclear sources, RIH with Collars and HWDP T/386' 23:00 - 00:00 1.00 DRILL P PROD1 RIH F1386' - T/3203' Filf pipe, Mud wt 8.4ppg in I out Up wt 85K Down wt 75K 2/2/2006 00:00 - 05:00 5.00 DRILL P PRODi RIH F13203' - T/14,2i2' Fifl pipe every 3000' 05:00 - 05:30 0.50 DRILL P PROD1 Circulate orient motor highside /Blow down topdrive /install Blower hose 05:30 - 06:00 0.50 DRILL P PRODi Log formation with MWD (recorded} 14,260' - 14,340' 06:00 - 07:00 1.00 DRILL P PROD1 Log formation with MWD (rea{time) 14,260' - 14,340' 220gpm @ 2000psi 90ftfhr 07:00 - 00:00 17.00 DRILL P PROD1 Drill 14,340' - 14,690' AST=6.09 hrs ART=5.78 hrs. Up wt 190K, DN wt 120K, RT wt 150k, Mud wt in 8.5ppg, Mud wt out 8.5PP9 2/3/2006 00:00 - 04:00 4.00 DRILL P PROD1 Drill 14,690' - 14,800' AST=.69 hrs ART=3.13 hrs. Up wt 190K, DN wt 115K, RT wt 150k, Mud wt in 8.5ppg, Mud wt out 8.5ppg 04:00 - 05:00 1.00 DRILL P PROD1 Pump His vis sweep ! CBU @275gpm 2300psi /Monitor well - Static 05:00 - 06:00 1.00 DRILL P PROD1 POOH 14,800' - 14,212' Surveys @ 14,368',14,346', 14,313' - f Monitor well /Static. Blow down Topdrive, Clean floor Printed: 2/13/2006 12:00:39 PM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Spud Date: 6/4/1975 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: 2/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~~ From - To ~I Hours ~~ Task II Code I NPT ! Phase --- ,____-~---- --I---I- --~---- 2/3/2006 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 08:30 1.50 DRILL P PROD1 08:30 - 09:30 1.00 DRILL P PROD1 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 11:00 0.50 DRILL P PROD1 11:00 - 11:30 0.50 DRILL N RREP PROD1 11:30 - 16:30 5.00 DRILL P PROD1 16:30 - 20:00 3.50 DRILL P PRODi 20:00 - 21:00 1.00 CASE P RUNPRD 21:00 - 21:30 0.50 CASE P RUNPRD 21:30 - 22:30 1.00 CASE P RUNPRD 22:30 - 23:00 0.50 CASE P RUNPRD 23:00 - 00:00 1.00 CASE P RUNPRD 2/4!2006 00:00 - 06:00 6.00 CASE P RUNPRD 06:00 - 06:30 0.50 CASE P RUNPRD 06:30 - 07:30 1.00 CASE P RUNPRD 07:30 - 08:30 1.00 CEMT P RUNPRD 08:30 - 09:30 1.00 CEMT P RUNPRD 09:30 - 11:00 1.50 CEMT P RUNPRD 11:00 - 12:00 1.001 CEMT I P I {RUNPRD 12:00 - 12:30 0.50 CEMT P RUNPRD 12:30 - 14:00 1.50 CEMT P RUNPRD 14:00 - 15:00 1.00 CEMT P RUNPRD 15:00 - 15:30 0.50 CEMT P RUNPRD 15:30 - 21:30 6.00 CEMT P RUNPRD 21:30 - 22:00 0.50 CEMT P RUNPRD 22:00 - 22:30 0.50 PERFO P OTHCMP 22:30 - 23:00 0.50 PERFO P OTHCMP 23:00 - 00:00 1.00 PERFO P OTHCMP 2/5/2006 00:00 - 01:30 y 1.50 PERFO P OTHCMP 01:30 - 07:30 I 6.00 PERFO P OTHCMP 07:30 - 08:30 I 1.001 PERFOD P I I OTHCMP 08:30 - 18:30 I 10.00 PERFO P OTHCMP 18:30 - 20:00 I 1.50 PERFO P OTHCMP Description of Operations Lubricate Rig -service top drive RIH 14,212' to 14,800' No problems CBU 275gpm @2550psi Rotate and recipricate pipe. Spot Liner runninng pill. Moniter well /Static POOH wet 14,800' - 14,122' Moniter well !Static. Clean Floor Drop dart to open Circ. sub. Pump dry job. Blow down topdrive POOH 14,122' - 12,727' Repair air leak on low drum clutch POOH 12,727' - 386' PJSM. lay down BHA 386'-135'. Remove nuclear sources. Flush BHA with water. Blow down top drive. Dowload MWD then layout with motor and bit. Clear and clean floor PJSM Rig up 4 1/2" liner equipment Pick up float equipment & check floats Pick up and run in 4 1/2" 12.6# L80 IBT-M Liner to 733' Torque to 3900 ft/Ibs. Make up hanger and RIH one stand. Circulate Liner volume Q856' 5 BPM ~170psi Run liner 856' to 2646' break circulation every 10 stands. Run liner 2646' to 14,212' break circulation every 10 stands. Circulate Liner volume 5bpm (~ 1250psi 200K up 125K do Run liner into open hole from 14,212' to 14780'. Make up cement head and wash to bottom @ 14,800' Stage pump up and circulate liner ~5bpm ~1490psi PJSM Batch mix cement Pump 5 bbl H2O -Test lines to 4500psi,Pump 10bbICW100-10bb1 mud push 11 spacerG 10.Sppg & 22bb1 class G cement C~315.8ppg. Wash lines through T with pert pill. Drop wiper plug & pump remaining pert pill. Finish displacing with mud. 149bb1 to bump. Set liner on bottom -pick up to pick up weight. Pressure up to 3500psi to set hanger. Bleed off & check floats then release from hanger Pressure string to 1000psi. Pick up to verity release. Circulate 220SPM for 500stks. Weight set packer with 55K down then rotate 55K down to verify. CBU 126PM C~3450psi 7bbl cement returns to surface. PJSM Lay down cement head .Clear rig floor Displace well to 8.5ppg seawater @14,066' - i0 BPM ~2500psiPump dry job. Blow down top drive Cut Drill fine Lubricate rig Service top drive POOH 14,066' to surface Lay down liner running tool Test Liner and Packer to 4000psi for 30 minutes PJSM Bring perforating tools to the rig floor Make up perforating guns to 161' Rig up 2 7!8" handling equipment Make up 2 7/8" Drillpipe 161' to 693' RIH with 4" drillpipe 693' to 14,714 Pick up to shot depth C~314,700" PJSM Fire pert guns -Good indication -POOH 50' above top shot @ 14,539' Monitor well -Pump dry job -Blow down surface equipment Lay down drill pipe 14,500' to 688' Rig up to and lay down 2 7/8" drill pipe 688' to 161' Printed: 2/13!2006 12:00:39 PM BP EXPLORATfON Operations Summary Report Legal Well Name: 01-08 Common Well Name: 01-08 Event Name: REENTER+COMPLETE Start: 12/26/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2006 Rig Name: NABOBS 2ES Rig Number: Date 2/5/2006 2/6/2006 2/7/2006 Page 16 of 16 Spud Date: 6!4/1975 End: 2/7/2006 From - To Hours Task ~~ Code I NPT i Phase j Description of Operations I ~ I 20:00 - 22:30 2.50 PERFO P OTHCMP 22:30 - 23:00 0.50 WHSUR P RUNCMP 23:00 - 00:00 1.00 BUNCO RUNCMP 00:00 - 01:00 1.00 BUNCO RUNCMP 01:00 - 11:30 10.50 BUNCO RUNCMP 11:30 - 12:00 0.50 BUNCO RUNCMP 12:00 - 12:30 0.50 BUNCO RUNCMP 12:30 - 13:30 1.00 BUNCO RUNCMP 13:30 - 14:00 0.50 RUNGO RUNCMP 14:00 - 16:30 2.50 BUNCO RUNCMP 16:30 - 18:00 1.50 BUNCO RUNCMP 18:00 - 19:00 1.00 BUNCO RUNCMP 19:00 - 21:00 2.00 BUNCO DPRB RUNCMP 21:00 - 23:30 2.50 BUNCO DPRB RUNCMP 23:30 - 00:00 0.50 RUNCOI~P RUNCMP 00:00 - 01:30 1.50 BUNCO~p RUNCMP 01:30 - 02:00 0.50 BUNCO RUNCMP 02:00 - 02:30 0.50 BUNCO RUNCMP 02:30 - 04:00 1.50 BOPSU P RUNCMP 04:00 - 06:00 2.00 WHSUR P RUNCMP 06:00 - 07:30 1.50 WHSUR P RUNCMP 07:30 - 08:30 1.00 WHSUR P RUNCMP 08:30 - 10:00 1.50 WHSUR P RUNCMP 10:00 - 11:00 1.00 WHSUR P RUNCMP 11:00 - 11:30 0.50 WHSUR P RUNCMP 11:30 - 12:00 0.50 WHSUR P RUNCMP 12:00 - 13:00 1.00 WHSUR P RUNCMP 13:00 - 00:00 11.00 WHSUR P RUNCMP PJSM Lay down guns /All guns fired -Clear floor Pull wear ring and make up landing joint Rig up 4 112" tubing handling equipment Make up Packer and tail pipe assembly Run 4 112" 12.6# L-80 Tubing -Make up torque 3600 fT/Ibs Space out tubing, tag no go ~ 14,070' 95Kdn 165K up PJSM Make up Hanger PJSM Land Hanger Rig up circulating lines Test lines to 4000psi Reverse circulate corrision inhibitor 3 bbm @300psi Drop 1 7/8" rod and ball Attempt to seat ball Blow down surface equipment Lubricate rig Service topdrive Rig up slick fine unit Run in hole with 3.65°bell guide and 3.474" Lead impression block Run in hole to 14,075'(SLM) Tap on rod with impression block POOH with slick line Good impression on block Pressure up tubing to 600 psi OK Rig down slickline Pressure test Tubing and annulus 4000 psi 30min -Shear DCK valve Install 2 way check and test from below 1000 psi Blow down surface equipment Nipple Down BOP Nipple Up tree & adaptor Test tree and adaptor to 5000psi Rig up DSM Lubricator - Pul! Two way check PJSM Rig up hot oil & circulating hoses pressure test lines to 3000psi Rev circulate 75bb1 diesel 2 1/2 BPM @ 1400psi U-Tube annulus to tubing Dry Rod back pressure valve -lest from below to 1000psi Rig down Oil hot truck & cellar Remove 2nd Annular valve Secure tree and cellar Rig release 13:00 Move rig Printed: 7113!2006 12:00:39 PM Halliburton Global _---- I Company: BP Amoco Date: 2/20/2006 Time: 16:23:09 Page: 1 f ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True North ~ Site: PB DS 01 Vertical (TVD) Refer ence: 66.90'RKB 66.9 j Well: 01-08 Section (VS) Referen ce: Well (O.OON,O.OOE,31.47Azi) ~ Wellpath: 1-08AP81 Sm~vev Calculation M ethod: 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 (C{arke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea level Geomagnetic Mo del: bggm2005 Well: 01-08 Slot Name:! 01-08 Well Position: +N/-S -2122.67 ft Northing: 5939851.43 ft Latitude: 70 14 23.027 N +E/-W 1571.02 ft Easting : 698863.54 ft Longitude: 148 23 38.338 W Position Uncertainty: 0.00 ft Wellpath: 1-08APB1 Drilled From: 01-08 500292016070 Tie-on Depth: 2350.00 ft Current Datum: 66.90'RKB Height 66.90 ft Above System Datum: Mean Sea Level Magnetic Data: 1 212 812 0 0 5 Declination: 24.80 deg Field Strength: 57616 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N!-S +E/-W Direction ft ft ft deg 29.00 0.00 0.00 31.47 Survey Program for Definitive Wellpath Date: 1(9!2006 Validated: Yes Version: 14 Actual From To Survey Toolcode Tool Name ft ft 100.00 2350.00 GYD_CT_CMS (100.00-2350.00) (0) GYD-CT-CMS Gyrodata cont.casing m/s 2413.00 2573.00 01-08AP61 GyroData(Evader) (2413.00-25Xi`CID)GC-SS Gyrodata gyro single shots Survey MD Inel Azim CVD Sys TVD N/S E/W MapN MapE '1'001. ft deg deg ft ft ft ft ft ft 29.00 0.00 0.00 29.00 -37.90 0.00 0.00 5939851.43 698863.54 TIE LINE 100.00 0.24 161.39 100.00 33.10 -0.14 0.05 5939851.29 698863.59 GYD-CT-CMS 200.00 0.11 155.53 200.00 133.10 -0.43 0.15 5939851.01 698863.71 GYD-CT-CMS 300.00 0.19 213.05 300.00 233.10 -0.65 0.10 5939850.78 698863.66 GYD-CT-CMS 400.00 0.31 158.43 400.00 333.10 -1,04 0.11 5939850.39 698863.68 GYD-CT-CMS 500.00 0.54 178.96 500.00 433.10 -1.77 0.22 5939849.67 698863.81 GYD-CT-CMS 600.00 0.45 185.25 599.99 533.09 -2.63 0.19 5939848.81 698863.80 GYD-CT-CMS 700.00 0.28 209.66 699.99 633.09 -3.23 0.04 5939848.20 698863.66 GYD-CT-CMS 800.00 0.18 187.32 799.99 733.09 -3.60 -0.10 5939847.83 698863.53 GYD-CT-CMS 900.00 0.19 186.19 899.99 833.09 -3.92 -0.14 5939847.51 698863.50 GYD-CT-CMS 1000.00 0.05 194.63 999.99 933.09 -4.13 -0.17 5939847.30 698863.48 GYD-CT-CMS 1100.00 0.33 24.74 1099.99 1033.09 -3.91 -0.06 5939847.52 698863.58 GYD-CT-CMS 1200.00 0.12 356.80 1199.99 1133.09 -3.54 0.05 5939847.89 698863.69 GYD-CT-CMS 1300.00 0.16 86.50 1299.99 1233.09 -3.43 0.19 5939848.01 698863.82 GYD-CT-CMS 1400.00 0.19 88.21 1399.99 1333.09 -3.42 0.49 5939848.03 698864.12 GYD-CT-CMS 1500.00 0.38 104.37 1499.98 1433.08 -3.49 0.98 5939847.96 698864.61 GYD-CT-CMS 1600.00 0.42 113.90 1599.98 1533.08 -3.72 1.63 5939847.75 698865.27 GYD-CT-CMS 1700.00 0.43 110.23 1699.98 1633.08 -4.00 2.32 5939847.49 698865.97 GYD-CT-CMS 1800.00 0.40 84.93 1799.98 1733.08 -4.10 3.02 5939847.41 698866.67 GYD-CT-CMS 1900.00 0.60 116.66 1899.97 1833.07 -4.30 3.84 5939847.23 698867.49 GYD-CT-CMS 2000.00 0.39 102.71 1999.97 1933.07 -4.61 4.64 5939846.94 698868.30 GYD-CT-CMS 2100.00 0.38 82.06 2099.97 2033.07 -4.64 5.30 5939846.93 698868.96 GYD-CT-CMS 2150.00 0.73 99.49 2149.97 2083.07 -4.67 5.78 5939846.91 698869.44 GYD-CT-CMS 2200.00 1,33 112.57 2199.96 2133.06 -4.95 6.63 5939846.66 698870.29 GYD-CT-CMS 2225.00 1.45 113.97 2224.95 2158.05 -5.19 7.18 5939846.43 698870.86 GYD-CT-CMS 2250.00 1.51 119.23 2249.94 2183.04 -5.48 7.76 5939846.16 698871.44 GYD-CT-CMS 2300.00 1.41 117.70 2299.92 2233.02 -6.09 8.88 5939845.58 698872.58 GYD-CT-CMS 2350.00 1.69 124.21 2349.91 2283.01 -6.79 10.03 5939844.91 698873.75 GYD-CT-CMS 2413.00 3.52 356.78 2412.87 2345.97 -5.38 10.69 5939846.34 698874.37 GYD-GC-SS Halliburton Global ~ Company: BP Amoco ~ Field: Prudhoe Bay Site: PB DS 01 Well: 01-08 Wellpath: 1-08APB 1 Survey ~~ MD Inct ~ ~ _ .4zim ft deg ~ deg - _ - 2417.00 3.70 355.02 2457.00 5.46 353.79 2509.00 6.87 352.55 2556.71 4.23 352.55 2573.00 5.64 353.26 2616.00 5.64 353.26 Date: 2/20/2006 ---- Time: 16:23:09 Page: 2 j Co-ordinate(NE) Reference: Well: 01-08, True North Vertical (TVll) Reference: 66.90'RKB 66.9 j Section (VS) Reference: Well (O.OON,O.OOE,31.47Azi) ~ Survey Calculation Method: Minimum Curvature Db: Oracie I TVD Sys TVll N/S E/W MapN MapE Tool ft ft ft ft ft ft 2416.86 2349.96 -5.13 10.68 5939846.59 698874.35 GYD-GC-SS 2456.73 2389.83 -1.95 10.36 5939849.76 698873.94 GYD-GC-SS 2508.43 2441.53 3.60 9.69 5939855.28 698873.13 GYD-GC-SS 2555.91 2489.01 8.17 9.09 5939859.84 698872.41 GYD-GC-SS 2572.14 2505.24 9.56 8.92 5939861.22 698872.20 GYD-GC-SS 2614.93 2548.03 13.76 8.42 5939865.41 698871.59 BLIND Halliburton Global j Company: BP Amoco `` Date: 2!20/2006 Time: 16:42:19 Page: 1 Ftield: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True N orth Site: PB DS 01 Vertical (TVD) Refer ence: 66.90'RKB 66.9 I Well: 01-08 Section (VS) Referen ce: NJeil (O.OON.QOOE,296.40Azi) ~ Wellpath: 01-08A 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 Mo del: bggm2005 Well: 01-08 Slot Name: 01-08 Well Position: +N/-S -2122.67 ft Northing: 5939851.43 ft Latitude: 70 14 23.027 N +E/-W 1571.02 ft Fasting ; 698863.54 ft Longitude: 148 23 38.338 W Position Uncertainty: 0.00 ft Wellpath: 01-O8A Drilled From: 1-0$AP61 500292016001 Tie-on Depth: 2350.00 ft Current Datum: 66.90'RKB Height 66.90 ft Above System Datum: Mean Sea Level Magnetic Data: 12/28/2005 Declinafion: 24.80 deg Field Strength: 57616 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N!-S +El-W Direction ft ft ft deg 29.00 0.00 0.00 296.40 Survey Program for Definitive Wellpath Date: 2/20/2006 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 2350.00 GYD_CT_CMS (100.00-2350.00) (0) GYD-CT-CMS Gyrodata cont.casing m/s 2428.81 2650.00 1-08A Gyro (2428.81-2650.00) GYD-GC-SS Gyrodata gyro single shots 2720.45 14758.40 1-08A IIFR+MS (2720.45-14758.40) MWD+IFR+MS MWD +IFR + Multi Station Survey MD Inc! Azim fVD Sys TVD CIS E/W NIapN MapE Tool j ft deg deg ft ft ft ft ft ft 29.00 0.00 0.00 29.00 -37.90 0.00 0.00 5939851.43 698863.54 TIE LINE 100.00 0.24 161.39 100.00 33.10 -0.14 0.05 5939851.29 698863.59 GYD-CT-CMS 200.00 0.11 155.53 200.00 133.10 -0.43 0.15 5939851.01 698863.71 GYD-CT-CMS 300.00 0.19 213.05 300.00 233.10 -0.65 .0.10 5939850.78 698863.66 GYD-CT-CMS 400.00 0.31 158.43 400.00 333.10 -1.04 0.11 5939850.39 698863.68 GYD-CT-CMS 500.00 0.54 178.96 500.00 433.10 -1.77 0.22 5939849.67 698863.81 GYD-CT-CMS 600.00 0.45 185.25 599.99 533.09 -2.63 0.19 5939848.81 698863.80 GYD-CT-CMS 700.00 0.28 209.66 699.99 633.09 -3.23 0.04 5939848.20 698863.66 GYD-CT-CMS 800.00 0.18 187.32 799.99 733.09 -3.60 -0.10 5939847.83 698863.53 GYD-CT-CMS 900.00 0.19 186.19 899.99 833.09 -3.92 -0.14 5939847.51 698863.50 GYD-CT-CMS 1000.00 0.05 194.63 999.99 933.09 -4.13 -0.17 5939847.30 698863.48 GYD-CT-CMS 1100.00 0.33 24.74 1099.99 1033.09 -3.91 -0.06 5939847.52 698863.58 GYD-CT-CMS 1200.00 0.12 356.80 1199.99 1133.09 -3.54 0.05 5939847.89 698863.69 GYD-CT-CMS 1300.00 0.16 86.50 1299.99 1233.09 -3.43 0.19 5939848.01 698863.82 GYD-CT-CMS 1400.00 0.19 88.21 1399.99 1333.09 -3.42 0.49 5939848.03 698864.12 GYD-CT-CMS 1500.00 0.38 104.37 1499.98 1433.08 -3.49 0.98 5939847.96 698864.61 GYD-CT-CM5 1600.00 0.42 113.90 1599.98 1533.08 -3.72 1.63 5939847.75 698865.27 GYD-CT-CMS 1700.00 0.43 110.23 1699.98 1633.08 -4.00 2.32 5939847.49 698865.97 GYD-CT-CMS 1800.00 0.40 84.93 1799.98 1733.08 -4.10 3.02 5939847.41 698866.fi7 GYD-CT-CMS 1900.00 0.60 116.66 1899.97 1833.07 -4.30 3.84 5939847.23 698867.49 GYD-CT-CMS 2000.00 0.39 .102.71 1999.97 1933.07 -4.61 4.64 5939846.94 698868.30 GYD-CT-CMS 2100.00 0.38 82.06 2099.97 2033.07 -4.64 5.30 5939846.93 698868.96 GYD-CT-CMS 2150.00 0.73 99.49 2149.97 2083.07 -4.67 5.78 5939846.91 698869.44 GYD-CT-CMS 2200.00 1.33 112.57 2199.96 2133.06 -4.95 6.63 5939846.66 698870.29 GYD-CT-CMS 2225.00 1.45 113.97 2224.95 2158.05 -5.19 7.18 5939846.43 698870.86 GYD-CT-CMS 2250.00 1.51 119.23 2249.94 2183.04 -5.48 7.76 5939846.16 698871.44 GYD-CT-CMS 2300.00 1.41 117.70 2299.92 2233.02 -6.09 8.88 5939845.58 698872.58 GYD-CT-CMS 2350.00 1.69 124.21 2349.91 2283.01 -6.79 10.03 5939844.91 698873.75 GYD-CT-CMS C7 Halliburton Global Company: BP Amoco Field: Pru dhoe Bay Site: PB DS 01 Well: 01- 08 Wellpath: 01- 08A Survev MD Inc1 Azim TVD ft deg cSeg ft 2428. 81 1. 22 353 .00 2428. 70 2460. 00 1. 88 271 .00 2459. 89 2493. 00 3. 85 250 .00 2492. 84 2524. 00 6. 66 239 .00 2523. 71 2554. 00 9. 51 235 .84 2553. 41 2587. 00 11. 95 238 .61 2585. 83 2618. 00 13. 48 246 .96 2616. 07 2650. 00 14. 25 258 .61 2647. 15 2720. 45 17. 93 264 .51 2714. 83 2764. 45 20. 74 267 .51 2756. 34 2859. 76 22. 78 275 .75 2844. 88 2955. 23 26. 09 277 .71 2939. 79 3050. 99 29. 76 281 .10 3016. 39 3145. 34 35. 04 280 .56 3096. 02 3240. 85 39. 82 285 .03 3171. 86 3335. 65 40. 79 286 .00 3244. 15 3429. 51 41. 06 291 .41 3315. 09 3524. 85 38. 27 296 .59 3388. 50 3619. 61 38. 00 302 .94 3463. 06 3714. 33 37. 84 308 .74 3537. 81 3809. 70 38. 98 313 .12 3612. 55 3905. 60 43. 38 313 .38 3684. 71 4000. 88 47. 24 312 .92 3751. 71 4096. 03 51. 41 311 .96 3813. 71 4192. 03 56. 00 311 .82 3870. 52 4286. 88 57. 83 308 .31 3922. 31 4382. 26 58. 43 303 .57 3972. 69 4478. 19 57. 54 298 .27 4023. 57 4571. 90 60. 80 296 .55 4071. 59 4666. 56 65. 01 295 .69 4114. 70 4763. 00 64. 65 296 .32 4155. 71 4857. 06 64. 93 295 .76 4195. 78 4951. 73 63. 55 297 .05 4236. 92 5045. 74 61. 87 296 .03 4280. 03 5138. 41 62. 32 295 .70 4323. 40 5232. 06 62. 86 295 .92 4366. 51 5326. 16 62. 74 295 .40 4409. 52 5420. 04 63. 77 294 .60 4451. 77 5525. 64 66. 13 293 .74 4496. 48 5619. 37 66. 91 294 .51 4533. 82 5712. 93 67. 72 294 .63 4569. 91 5808. 36 67. 65 294 .32 4606. 14 5903. 89 66. 51 292 .80 4643. 35 5998. 75 66. 99 292 .48 4680. 79 6092. 65 65. 77 296 .30 4718. 42 6187. 09 64. 46 294 .80 4758. 17 6279. 86 62. 66 294 .28 4799. 47 6362. 32 64. 29 29d .52 4836. 30 6457. 44 63. 65 297 .25 4878. 04 6551. 14 62. 40 297 .57 4920. 55 6644. 52 62. 80 297 .88 4963. 52 6739. 95 60. 85 297 .44 5008. 58 Date: 2/20/2006 Time: 16:42:19 Page: 2 Co-ordinate(NE) Reference: We11: 01-08, True North Vertical (TVD) Reference: 66.90'RKB 66.9 Section (VS) Reference:. Well (O.OON,O.OOE,296.40Azi) Sur.°ey Calculation Method: Minimum Curvature Db: Oracle S~sTVD N/S E/W' - ft ft ft - 2361. - _ 80 - _ -6 - - .61 10. 89 2392. 99 -6 .27 10. 34 2425. 94 -6 .64 5. 76 2456. 81 -7 .92 6. 24 2486. 51 -10 .21 2. 70 2518. 93 -13 .52 -2. 48 2549. 17 -16 .60 -8. 54 2580. 25 -18 .84 -15. 84 2647. 93 -21 .59 -35. 14 2689. 44 -22 .58 -49. 67 2777. 98 -21 :46 -84. 90 2864. 89 -16 .79 -124. 10 2949. 49 -9 .39 -168. 31 3029. 12 0 .09 -217. 95 3104. 96 13 .05 -274. 48 3177. 25 29 .46 -333. 57 3248. 19 49 ,17 -391. 75 3321. 60 73 .83 -447. 33 3396. 16 102 .84 -498. 08 3470. 91 136 .88 -545. 22 3545. 65 175 .70 -589. 95 3617. 81 218 .96 -635. 92 3684. 81 265 .27 -685. 34 3746. 81 313 .94 -738. 59 3803. 62 365 .59 -796. 18 3855. 41 416 .71 -857. 00 3905. 79 464 .22 -922. 56 3956. 67 506 .01 -992. 29 4004. 69 543 .02 -1063. 72 4047. 80 580 .11 -1139. 37 4088. 81 618 .37 -1217. 81 4128. 88 655 .73 -1294. 28 4170. 02 693 .64 -1370. 64 4213. 13 730 .98 -1445. 38 4256. 50 766 .70 -1519. 07 4299. 61 802 .90 -1593. 91 4342. 62 839 .14 -1669. 35 4384. 87 874 .57 -1745. 33 4429. 58 913 .73 -1832. 61 4466. 92 948 .87 -1911. 07 4503. 01 984 .76 -1989. 57 4539. 24 1021 .34 -2069. 92 4576. 45 1056 .51 -2150. 57 4613. 89 1090 .06 -2231. 01 4651. 52 1125 .56 -2309. 35 4691. 27 1162 .52 -2386. 63 4732. 57 1197 .02 -2462. 19 4769. 40 1227 .50 -2529. 38 4811. 14 1264 .80 -2606. 27 4853. 65 1303 .24 -2680. 40 4896. 62 1341 .81 -2753. 78 4941. 68 1380 .86 -2828. 29 MapN Mapl': _ - - Too! ft ft 5939845.11 698874.60 GYD-GC-SS 5939845.44 698874.04 GYD-GC-SS 5939845.03 698872.47 GYD-GC-SS 5939843.68 698869.98 GYD-GC-SS 5939841.30 698866.50 GYD-GC-SS 5939837.85 698861.42 GYD-GC-SS 5939834.61 698855.44 GYD-GC-SS 5939832.18 698848.21 GYD-GC-SS 5939828.92 698828.98 MWD+IFR+MS 5939827.55 698814.49 MWD+iFR+MS 5939827.74 698779.24 MWD+IFR+MS 5939831.37 698739.93 MWD+IFR+MS 5939837.60 698695.55 MWD+IFR+MS 5939845.77 698645.68 MWD+IFR+MS 5939857.24 698588.82 MWD+IFR+MS 5939872.08 698529.33 MWD+IFR+MS 5939890.25 698470.65 MWD+IFR+MS 5939913.43 698414.44 MWD+IFR+MS 5939941.09 698362.95 MWD+-FR+MS 5939973.88 698314.93 MWD+IFR+MS 5940011.50 698269.20 MWD+IFR+MS 5940053.53 698222.10 MWD+IFR+MS 5940098.52 698171.48 MWD+IFR+MS 5940145.76 698116.96 MWD+IFR+MS 5940195.87 698058.04 MWD+IFR+MS 5940245.36 697995.90 MWD+IFR+MS 5940291.13 697929.11 MWD+IFR+MS 5940331.06 697858.31 MWD+IFR+MS 5940366.18 697785.93 MWD+IFR+MS 594040125 697709.33 MWD+IFR+MS 5940437.43 697629.91 MWD+IFR+MS 5940472.76 697552.49 MWD+IFR+MS 5940508.64 697475.15 MWD+IFR+MS 5940543.99 697399.46 MWD+IFR+MS 5940577.75 697324.86 MWD+IFR+MS 5940611.96 697249.09 MWD+IFR+MS 594064620 697172.73 MWD+IFR+MS 5940679.61 697095.84 MWD+IFR+MS 5940716.45 697007.57 MWD+IFR+MS 5940749.51 696928.22 MWD+IFR+MS 5940783.32 696848.80 MWD+IFR+MS 5940817.76 696767.51 MWD+IFR+MS 5940850.79 696655.97 MWD+IFR+MS 5940882.20 696604.68 MWD+IFR+MS 5940915.63 696525.43 MWD+IFR+MS 5940950.53 696447.20 MWD+IFR+MS 5940983.02 696370.77 MWD+IFR+MS 5941011.72 696302.80 MWD+IFR+MS 5941046.98 696224.96 MWD+IFR+MS 5941083.45 696149.85 MWD+IFR+MS 5941120.06 696075.47 MWD+IFR+MS 5941157.14 695999.97 MWD+IFR+MS Halliburton Global j Company: BP Amoco Date: 212012006 Time: 16:42:19 -- Page: 3 ~ Field: Pru dhoe Bay Co-ord inate(NE) Reference: WeVI: 01-08, True North ~ Site: PB DS 01 Vertical ('I'VD) Reference: 66.90RKB 66.9 ~~ Well: 01- 08 Section (VS) Reference: Well (O.OON,O.OOE,296.40Azi} ~ ~ Wellpath: 01- 08A Survey Calculation Method: Mini mum Curvatu re Db: Oracle ~~ Sur~~ev r _ - MD - - Incl - __--_- Azim - _ - TVD - _ -- Sys TVD -- N/S - _ _ E/W - - blapN - --- MapE --- - - - - "fool ~ a deg deg ft ft ft ft ft ft 6833.38 60.49 296.80 5054.34 _ - 4987.44 --- --- 1417.99 .-_ _ _ -2900.79 _ 5941192.34 695926.52 MWD+{FR+MS 6927.21 60.44 298.92 5100.60 5033.70 1456.14 -2972.95 5941228.57 695853.38 MWD+IFR+MS 7023.73 61.53 299.39 5147.42 5080.52 1497.26 -3046.66 5941267.73 695778.61 MWD+IFR+MS 7119.91 62.17 298.41 5192.79 5125.89 1538.24 -3120.91 5941306.73 695703.32 MWD+IFR+MS 7218.42 62.36 299.47 5238.64 5171.74 1580.43 -3197.21 5941346.90 695625.93 MWD+IFR+MS 7310.09 62.68 297.37 5280.94 5214.04 1619.14 -3268.73 5941383.69 695553.42 MWD+IFR+MS 7404.70 63.98 295.44 5323.41 5256.51 1656.72 -3344.45 5941419.27 695476.74 MWD+IFR+MS 7500.36 63.04 295.36 5366.08 5299.18 1693.45 -3421.79 5941453.94 695398.46 MWD+IFR+MS 7597.66 63.19 294.23 5410.08 5343.18 1729.84 -3500.57 5941488.24 695318.75 MWD+IFR+MS 7703.69 62.63 294.83 5458.36 5391.46 1769.03 -3586.45 5941.525.15 695231.88 MWD+IFR+MS 7798.34 61.28 296.48 5502.87 5435.97 1805.19 -3661.75 5941559.31 695155.65 MWD+IFR+MS 7892.29 59.20 297.31 5549.50 5482.60 1842.07 -3734.48 5941594.26 695081.98 MWD+IFR+MS 7987.97 57.82 298.53 5599.48 5532.58 1880.27 -3806.57 5941630.54 695008.91 MWD+iFR+MS 8084.14 57.36 299.41 5651.02 5584.12 1919.59 -3877.60 5941667.97 694936.87 MWD+IFR+~r1S 8178.19 56.89 299.86 5702.07 5635.17 1958.65 -3946.26 5941705.20 694867.21 MWD+IFR+MS 8273.85 55.24 301.07 5755.47 5688.57 1998.88 -4014.67 5941743.61 694797.77 MWD+IFR+MS 8369.77 56.17 302.15 5809.52 5742.62 2040.41 -4082.15 5941783.35 694729.21 MWD+IFR+MS 8463.56 57.11 303.67 5861.10 5794.20 2082.98 -4147.91 5941824.16 694662.36 MWD+IFR+MS 8558.60 57.69 305.90 5912.31 5845.41 2128.66 -4213.66 5941868.09 694595.43 MWD+IFR+MS 8654.39 58.37 304.41 5963.03 5896.13 2175.44 -4280.10 5941913.10 694527.79 MWD+IFR+MS 8701.66 59.07 305.77 5987.57 5920.67 2198.66 -4313.15 5941935.44 694494.13 MWD+IFR+MS 8750.53 59.72 303.49 6012.45 5945.55 2222.56 -4347.76 5941958.42 694458.91 MWD+IFR+MS 8846.39 59.94 304.38 6060.63 5993.73 2268.83 -4416.52 5942002.85 694388.96 MWD+IFR+MS 8940.24 59.82 303.64 6107.73 6040.83 2314.23 -4483.81 5942046.46 694320.50 MWD+IFR+MS 9035.59 59.73 304.06 6155.73 6088.83 2360.12 -4552.23 5942090.53 694250.89 MWD+IFR+MS 9130.21 60.23 304.08 6203.06 6136.16 2406.02 -4620.09 5942134.62 694181.85 MWD+IFR+MS 9218.99 60.68 304.93 6246.84 6179.94 2449,77 -4683.74 5942176.67 694117.07 MWD+IFR+MS 9313.62 61.11 302.84 6292.88 6225.98 2495,86 -4752.38 5942220.94 694047.25 MWD+IFR+MS 9409.81 62.53 300.85 6338.30 6271.40 2540.59 -4824.40 5942263.74 693974.07 MWD+IFR+MS 9503.91 63.67 298.78 6380.88 6313.98 2582.30 -4897.21 5942303.52 693900.19 MWD+IFR+MS 9597.67 64.82 296.73 6421.62 6354.72 2621.62 -4971.93 5942340.85 693824.46 MWD+IFR+MS 9692.07 65.73 294.82 6461.11 6394.21 2658.89 -5049.15 5942376.07 693746.30 MWD+IFR+MS 9786.75 66.00 294.40 6499.82 6432.92 2694.87 -5127.70 5942409.97 693666.83 MWD+IFR+MS 9880.15 66.12 292.49 6537.73 6470.83 2728.84 -5206.01 5942441.85 693587.65 MWD+IFR+MS 9974.28 65.44 291.83 6576.34 6509.44 2761.22 -5285.51 5942472.12 693507.32 MWD+IFR+MS 10067.57 65.20 291.44 6615.30 6548.40 2792.47 -5364.31 5942501.28 693427.74 MWD+IFR+MS 10162.65 65.52 290.89 6654.94 6588.04 2823.67 -5444.90 5942530.35 693346.35 MWD+IFR+MS 10257.36 65.70 292.45 6694.05 6627.15 2855.52 -5525.06 5942560.07 693265.39 MWD+IFR+MS 10352.10 64.86 290.52 6733.67 6666.77 2887.05 -5605.13 5942589.47 693184.52 MWD+IFR+MS 10447.58 65.11 291.68 6774.05 6707.15 2918.19 -5685.85 5942618.48 693103.01 MWD+IFR+MS 10542.32 66.52 293.58 6812.86 6745.96 2951.45 -5765.61 5942649.62 fi93022.40 MWD+IFR+MS 10619.09 68.21 292.73 6842.41 6775.51 2979.31 -5830.76 5942675.75 692956.55 MWD+IFR+MS 10714.64 68.77 294.24 6877.44 6810.54 3014.74 -5912.29 5942709.01 692874.12 MWD+IFR+MS 10808.30 67.63 295.51 6912.23 6845.33 3051.31 -5991.18 5942743.49 692794.29 MWD+IFR+MS 10904.63 65.35 293.56 6950.65 6883.75 3088.00 -6071.52 5942778.04 692713.01 MWD+IFR+MS 10998.90 64.87 293.44 6990.33 6923.43 3122.10 -6149.94 5942810.06 692633.73 MWD+IFR+MS 11095.38 65.09 294.13 7031.13 6964.23 3157.36 -6229.94 5942843.19 692552.83 MWD+IFR+MS 11189.98 64.75 295.00 7071.23 7004.33 3192.98 -6307.87 5942876.74 692473.99 MWD+IFR+MS 11284.26 64.91 296.16 7111.33 7044.43 3229.82 -6384.83 5942911.54 692396.09 MWD+-FR+MS 11379.41 65.51 296.23 7151.23 7084.33 3267.95 -6462.34 5942947.61 692317.61 MWD+IFR+MS 11475.11 65.11 294.85 7191.21 7124.31 3305.44 -6540.79 5942983.01 692238.20 MWD+IFR+MS 11570.24 65.22 294.14 7231.16 7164.26 3341.23 -6619.35 5943016.72 692158.72 MWD+IFR+MS 11664.84 65.37 294.51 7270.70 7203.80 3376.63 -6697.66 5943050.04 692079.51 MWD+IFR+MS Halliburton Global ~~ Company: BP Amoco Date: 2/20/2006 Cime: 16:42:19 Page: 4 Field: Pru dhoe Bay Co-ord inate('NE) Re ference: Well: 01-08, True North ~ Site: PB DS 01 Vertical (1'Vll) Refe rence: 66,90'RKB 66.9 Wcll: 01- 08 Section (VS) Referen ce: Well (O.OON,O.OOE,296.40Azi) Weltpath: 01- O8A Survey Calculation Method: Minimum Curvatu re Db: Oracle Survey _ - _ - _ i Mll _ -- lncl ----- Azim -- - TVD __ _ _ Sys TVD NlS E!W MapN MapE _ - "Cool I ft deg deg ft ft ft ft ft ft _ _ _ _ _ - 11759.99 _ _ -- 64.80 --- - - . 293.76 - _- - - 7310.78 -- _ _ _ 7243.88 _ _ - _ 3411.92 - _ .- - -6776.41 __ - _ - - __ 5943083.23 __ _------ 691999.86 - __ __- - -_ _ -_ MWD+IFR+MS ~ 11855.24 64.97 294.99 7351.21 7284.31 3447.51 -6854.97 5943116.74 691920.40 MWD+IFR+MS 11951.01 65.38 295.20 7391.42 7324.52 3484.38 -6933.68 5943151.52 691840.74 MWD+{FR+MS 12046.13 65.93 294.83 7430.63 7363.73 3521.02 -7012.22 5943186.07 691761.28 MWD+IFR+MS ~ 12141.83 65.49 293.65 7470.00 7403.10 3556.83 -7091.75 5943219.77 691680.83 MWD+IFR+MS ~ 12237.31 65.71 293.17 7509.44 7442.54 3591.38 -7171.55 5943252.20 691600.16 MWD+IFR+MS 12333.25 65.48 292.82 7549.08 7482.18 3625.51 -7251.97 5943284.20 691518.86 MWD+IFR+MS 12427.71 65.03 293.94 7588.62 7521.72 3659.55 -7330.71 5943316.15 691439.26 MWD+IFR+MS 12522.62 64.98 294.07 7628.73 7561.83 3694.55 -7409.29 5943349.05 691359.78 MWD+IFR+MS 12616.28 64.94 293.52 7668.37 7601.47 3728.78 -7486.94 5943381.23 691281.27 MWD+IFR+MS 12710.49 64.70 292.83 7708.45 7641.55 3762.33 -7565.31 5943412.70 691202.04 MWD+IFR+MS 12804.75 64.83 293.50 7748.64 7681.74 3795.88 -7643.70 5943444.16 691122.79 MWD+IFR+p,,}S 12899.00 65.23 294.10 7788.43 7721.53 3830.36 -7721.88 5943476.57 691043.74 MWD+IFR+MS 12993.11 64.59 293.78 7828.33 7761.43 3864.94 -7799.77 5943509.08 690964.97 MWD+IFR+MS 13087.08 64.61 295.51 7868.64 7801.74 3900.34 -7876.92 5943542.43 690886.91 MWD+IFR+MS 13180.19 65.31 295.34 7908.05 7841.15 3936.55 -7953.11 5943576.62 690809.80 MWD+IFR+MS 13274.68 65.49 295.61 7947.39 7880.49 3973.51 -8030.67 5943611.51 690731.30 MWD+IFR+MS 13369.49 65.15 295.36 7986.97 7920.07 4010.57 -8108.44 5943646.52 690652.58 MWD+IFR+MS 13464.13 65.09 295.77 8026.79 7959.89 4047.62 -8185.89 5943681.51 690574.19 MWD+IFR+MS 13559.09 64.89 294.89 8066.94 8000.04 4084.44 -8263.67 5943716.26 690495.47 MWD+IFR+MS 13654.75 65.12 294.66 8107.36 8040.46 4120.77 -8342.39 5943750.50 690415.82 MWD+IFR+MS 13748.58 65.43 295.07 8146.60 8079.70 4156.61 -8419.72 5943784.28 690337.58 MWD+IFR+MS 13844.48 65.63 294.62 8186.33 8119.43 4193.28 -8498.93 5943818.85 690257.43 MWD+IFR+MS 13939.84 65.43 294.17 8225.83 8158.93 4229.13 -8577.97 5943852.60 690177.48 MWD+IFR+MS 14034.76 65.09 293.94 8265.55 8198.65 4264.27 -8656.69 5943885.65 690097.86 MWD+IFR+MS 14129.51 65.57 294.02 8305.10 8238.20 4299.27 -8735.36 5943918.56 690018.30 MWD+IFR+MS 14179.23 65.12 293.73 8325.84 8258.94 4317.56 -8776.68 5943935.75 689976.51 MWD+IFR+MS 14212.50 67.38. 291.98 8339.24 8272.34 4329.38 -8804.74 5943946.83 689948.15 MWD+IFR+MS 14240.80 73.55 290.84 8348.70 8281.80 4339.10 -8829.56 5943955.89 689923.08 MWD+IFR+MS 14273.80 81.95 290.77 8355.69 8288.79 4350.55 -8859.68 5943966.54 689892.68 MWD+IFR+MS 14306.59 90.57 293.45 8357.83 8290.93 4362.85 -8889.96 5943978.04 689862.08 MWD+IFR+MS 14329.49 91.62 299.89 8357.39 8290.49 4373.13 -8910.41 5943987.77 689841.37 MWD+IFR+MS 14359.34 93.44 303.06 8356.07 8289.17 4388.69 -8935.84 5944002.66 689815.54 MWD+IFR+MS 14392.39 94.11 307.12 8353.90 8287.00 4407.65 -8962.82 5944020.89 689788.07 MWD+IFR+MS 14420.16 92.54 310.28 8352.29 8285.39 4424.98 -8984.45 5944037.65 689765.99 MWD+-FR+MS 14452.02 93.33 311.16 8350.66 8283.76 4445.73 -9008.57 5944057.76 689741.34 MWD+IFR+MS 14504.18 94.12 310.31 8347.27 8280.37 4479.70 -9048.01 5944090.67 689701.02 MWD+IFR+MS 14545.29 95.00 308.18 8344.00 8277.10 4505.62 -9079.74 5944115.75 689668.62 MWD+IFR+MS 14596.58 95.36 306.05 8339.37 8272.47 4536.44 -9120.47 5944145.48 689627.09 MWD+IFR+MS 14637.49 91.05 305.39 8337.08 8270.18 4560.29 -9153.63 5944168.44 689593.32 MWD+IFR+MS 14684.58 91.20 304.30 8336.16 8269.26 4587.19 -9192.26 5944194.31 689553.99 MWD+IFR+MS 14729.40 93.13 304.45 8334.46 8267.56 4612.47 -9229.23 5944218.61 689516.37 MWD+IFR+MS 14758.40 93.08 304.39 8332.89 8265.99 4628.84 -9253.12 5944234.34 689492.06 MWD+IFR+MS 14800.00 93.08 304.39 8330.66 8263.76 4652.30 -9287.40 5944256.89 689457.18 PROJECTED to TD TREE= 4-1/1fi" C:M/ WELLHEAD =• FMC ACTUATOR = AXELSON KB. ELEV = 66.9' BF. ELEV = 42.0' KOP = 2351' Max Angfe = 95 @ 14597' Datum MD = 13796' Datum ND = 8100' SS { 20" CSG, 94#, H-40, ID = 19.124" {-{ 100' Minimum ID = 3.725" @ 14055° 4-1f2°' HES XN NiPPLE WHIPSTOCK (41!01106) ~--~ 2350' r 13-318" EZSV (12!31!05) ^2370' 9-5/8" CSG STUB (12129!05) 2390' 9-5(8"CIBP(12128/05} 2500' 13-318" CSG, 72#, MN-80, 2674' ID =12.347" SEE PREVIOUS SCHEMATIC FOR WELL 01-08 TBG, LNR, &CSG DETAILS ~1-O8A 7" TIEBACK, 26#, L-80 TCIi, ID = 6.276" 7" TIEBACK, 26#, L-80 BTGM, ID = 6.276" 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 4886' 5325' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 12/07/05-02/04/06 ANGLE AT TOP PERF: 95 @ 14570' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 14570 - 14700 O 02/05/06 4-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 7" LNR, 26#, L-80 BTGM, ID = 6.276" {-{ 1 Pero 14715' 4-1/2" LNR 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 14800' 5315, I--, 9-518" X 7" BKR C2 ZXP LNR TOP PKR ~w/TIEBACK SLV, ID = 7.50" 5315' 7" BKR PORTED TIEBACK SEAL ASSY, tD = 6.160" 5333' 9-518" X 7" BKR FLEXLOCK LNR HNGR, ID = 6.30" 99$6, I--~ 7" HES ES CEMENTER2, ID = 6.230" 13990' 4-1/2" HES X NIP, fD = 3.813" 14011• ~-'j 7" X 4-1/2" BKR PKR, ID = 3.875" 14034' 4-112" HES X NIP, ID = 3.813" 14055' 4-112" HES XN NIP, ID = 3.725" 14066' 7" x 5" BKR ZXP LNR TOP PKR w i TIEBACK SLV, ID = 4.440" 14067' 4-1/2" WLEG, ID = 3.958" 14084' 7" X 5" FLEXLOCK LNR HNGR, ID = 4.420" 14094' 5" X 4-112" XO, ID = 3.990" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/75 ORIGINAL COMPLETION 09/23/97 LAST WORKOVER 02/09/06 N2ES SIDETRACK(01-08A) 02119/06 RCC/TLH DRLGDRAFTCORRECTIONS 02/27!06 DAV/PJC GLV C/O PRUDHOE BAY UNIT WELL: 01-08A PERMIT No: 1051950 API No: 50-029-20160-01 SEC 8, T10N, R15E, 4024' ESL, 3375.8' FEL BP F~tploration (Alaska} SATES: 70° @ 14241' ***C E NIPPLES IN 4-112" L-80 TBC~`** 211T --+9-518" HES ES CEMENTER, ID = 8.875" f 2222' 4-112" HES X NIP, 4D = 3.813" MILLOUTWINDOW (d1-08A) 13-318" CSG: 2353` - 2377' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3951 9604 3717 6424 45 65 KG62 KG62 DOME SO BK BK 16 20 02127/06 02127!06 4387' {-{ EST. TOP OF CEMENT ~~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houton, Texas 77043 713/461-3146 Fax: 7 1 31461-0920 January 18, 2006 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Petrotechnicai Data Center, LR2-1 Anchorage, Alaska 99508 Re: DS-01, Weti #1-08A Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~~ Rob Shoup North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyroda a Gyrodata incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP DS-01 #1-08A NABORS #2ES PRUDHOE BAY, AK AK1205G_577 JANUARY 6, 2006 1~,.~~ cJ 11 Serving the Wor{dwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directi onal Survey for BP EXPLORATION (ALASKA) INC. Lease: DS-O1 Well: 1-08A, 13-5/8" Casing Location: Nabors #2E5, Prudhoe Bay, Alaska Job Number: AK1205G 577 Run Date: 06 Jan 2006 Surveyor: Henry Drew; Jeff Smith Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.239730 deg. N Longitude: 148.393983 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location • • Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directi onal Survey BP Exploration (Alaska) Inc. Lease: DS-O1 Well: 1-08A, 13-5/8" Casing Location: Nabors #2ES, Prudhoe Bay, Alaska Job Number: AK1205G 577 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. - 0 QO - - 0.00 0.00 N 0 0 E - - - 0.00 0.00 0.0 0.0 - 0.00 N 0.00 E ------------------------------------- ------------------------------------------ 0 - 2350 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 13-3/8" CASING ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #2ES R.K.B. OF 6b.9 FT. TO M.S.L. 100.00 0.24 161.39 S 18 37 E 0.24 100.00 0.2 161.4 0.20 S 0.07 E 200.00 0.11 155.53 S 24 28 E 0.13 200.00 0.5 160.3 0.48 S 0.17 E 300.00 0.19 213.05 S 33 3 W 0.16 300.00 0.7 170.2 0.70 S 0.12 E 400.00 0.31 158.43 S 21 34 E 0.25 400.00 1.1 173.1 1.09 S 0.13 E 500.00 0.54 178.96 5 1 2 E 0.27 500.00 1.8 172.4 1.81 S 0.24 E 600.00 0.45 185.25 S 5 15 W 0.10 599.99 2.7 175.5 2.68 S 0.21 E 700.00 0.28 209.66 S 29 40 W 0.23 699.99 3.3 179.0 3.29 S 0.06 E 800.00 0.18 187.32 S 7 19 W 0.13 799.99 3.7 181.3 3:66 S 0.08 W 900.00 0.19 186.19 S 6 11 W 0.01 899.99 4.0 181.8 3.98 S 0.12 W 1000.00 0.05 194.63 S 14 38 W 0.14 999.99 4.2 182.1 4.19 S 0.15 W 1100.00 0.33 24.74 N 24 45 E 0.38 1099.99 4.0 180.6 3.97 S 0.04 W 1200.00 0.12 356.80 N 3 12 W 0.23 1199.99 3.6 178.8 3.60 S 0.07 E 1300.00 0.16 86.50 N 86 30 E 0.20 1299.99 3.5 176.6 3.49 S 0.21 E 1400.00 0.19 88.21 N 88 13 E 0.03 1399.99 3.5 171.6 3.48 S 0.51 E 1500.00 0.38 104.37 S 75 38 E 0.20 1499.98 3.7 164.2 3.55 S 1.00 E 1600.04 0.42 113.90 S 66 6 E 0.08 1599.98 4.1 156.3 3.79 S 1.66 E 1700.00 0.43 110.23 S 69 46 E 0.03 1699.98 4.7 150.0 4.06 S 2.35 E 1800.00 0.40 84.93 N 84 56 E 0.18 1794.98 5.2 143.8 4.16 S 3.05 E 1900.00 0.60 116.66 S 63 20 E 0.33 1899.97 5.8 138.4 4.37 S 3.87 E 2000.00 0.39 102.71 S 77 17 E 0.24 1999.97 6.6 135.0 4.68 S 4.68 E 2 • • BP Exploration (Alaska) Inc. Lease: DS-O1 Well: 1-08A, 13-S/8" Casing Location: Nabors #2ES, Prudhoe Bay, Alaska Job Number: AK1205G 577 A Gyrodata Directi onal Survey MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. 2100.00 0.38 82.06 N 82 3 E 2150.00 0.73 99.49 S 80 31 E 2200.00 1.33 112.57 S 67 26 E 2225.00 1.45 113.97 S 66 2 E 2250.00 1.S 1 119.23 S 60 46 E 2300.00 1.41 117.70 S 62 18 E 2350.00 1.69 124.21 S 55 48 E Final Station Closure: Distance: 12.18 ft Az: 124.20 deg. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 100 ft. 0.14 2099.97 7.1 131.4 0.76 2149.96 7.5 129.1 1.28 2199.96 8.3 126.9 0.49 2224.95 8.9 126.0 O.S9 2249.94 9.6 125.4 0.21 2299.92 10.8 124.6 0.67 2349.91 12.2 124.2 HORIZONTAL COORDINATES feet 4.71 S 5.34E 4.74 S 5.82 E 5.01 S 6.67 E 5.25 S 7.23 E 5.54 S 7.80 E 6.15 S 8.92 E 6.85 S 10.08 E • 3 BP Exploration (Alaska) Inc. Well: DS-O1 1-08A 13-5/8" Casing Location: Nabors #2ES, Prudhoe Bay, Alaska 0 -1 - -2 - -3 C~ z ~ -4 - O z -5 - -6 -7 Inrun Gyrodata AK1205G 577 DEFINITIVE I -- ---- - --- - ------- ___ 1~ - j ~ - i I I - -- ---- ------ ------ • -- • --. __ _ - _ ~~_ - _~ _ ,_ i, ~_. ~~ - ------f---~__~!,_ I ~.. ~. BOTTOM OLE LOCATED -- - ~ MD: 235 .00 • i i ~ ~ 0 1 2 3 4 5 6 7 8 9 10 FASTING (ft) BP Exploration (Alaska) Inc. Well: DS-O1 1-08A 13-5/8" Casing Location: Nabors #2ES, Prudhoe Bay, Alaska 3.0 2.5 • 2.0 0 0 rn a~ .~ 1.5 w w w J 0 1.0 0.5 ~ Inrun Gyrodata AK1205G 577 DEFINITIVE BOTTOM HOLE LOCATE MD: 235 .00 ',s ~,. ~~ _ ~ ~~, ~ _ _ ~ ~,_ 0.0 ~ I 0 500 1000 1.500 MEASURED DEPTH (ft) 2000 2500 • ___ _ Re: 1-08Ai Cement Isolation " "~0 '~a " ~ ~~ Subject: Re: 1-08Ai Cement Isolation From: Winton Aubert <Winton_aubert@admin.state.ak.us> Date: Wed, 01 Feb 2006 13:41:04-0900 To: "Dean, James A" <James.Dean@bp.com> ~I CC: James B Re <~im re admin.state.ak.us> 95 J _ 99@ James, This confirms AOGCC's approval to inject water in welt 01-08A (PTD 205-195), contingent upon BPXA performing follow-up logging within 30 days of first injection, and as described below. Winton Aubert AOGCC 793-1231 Dean, James A wrote: W+nton, As per our review of the 1-08Ai USIT log and our discussion this afternoon, BP understands that the AOGCC requires a follow-up fog after commencing water injection to verify no fluid movement behind the 7" intermediate casing. The ~ logging method will be determined by BP. j --.fames 1 of 1 2/1/2006 1:41 PM ~ ~ sag s j l t ~ ~ } 1 ~ /.s..,._VSA OIL A1QI)GA5 CO1~T5ERQA~`IO1~T COl-I1rII5SI01~ Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 !/. FRANK H. MURKOWSKl, GOVERNOR ;i~ ~ya ~ 333 W. 7`" AVENUE, SUITE 100 a~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe O l -08A BP Exploration (Alaska) Inc. Permit No: 205-195 Surface Location: 4024' FSL, 3758' FEL, SEC. 08, TlON, R15E, ITM Bottomhole Location: 3460' FSL, 2587' FEL, SEC. Ol, TlON, R14E, LTM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced service 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to fitness any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 (pager). N DATED this ~ ~ of December, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~~ ALASKH~IL AND GAS CONSERVATION COfC!~VIISSION PERMIT TO DRILL 20 AAC 25.005 "~t~C~`~~'1~d SEC 0 ~ z~~ A(esk~ ail ~ Gaa Con:Z. Coittfnssifr r.~_L....."r.c 1a. Type of work ~ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil u ip one ^ 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 01-08A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14590 ND 8337 12. Field /Pool(s): Prudhoe Bay Field /Put River 4a. Location of Well (Goverf mepial Section): Surface: ~ !~/7lQS 3758' FEL 4AI?~' FSL SEC T10N O8 R15E UM ° 7. Property Designation: ADL 028329 Pool , , . , , , Top of Productive Horizon: 3236' FSL, 2227' FEL, SEC. 01, T10N, R14E, UM g, Land Use Permit: 13. Approximate Spud December 0 005 Total Depth: 3460' FSL, 2587 FEL, SEC. 01, T10N, R14E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,120' 4b. Location of Well (State Base Plane Coordinates): Surface: x-698864 - 5939851 Zone- ASP4 10. KB Elevation Plan (Height above GL): 66.4 feet 15. Distance to Nearest Well Within Pool Ot-29 is offset by ~59' at 5349' 16. Deviated Wells: Kickoff Depth: 2350 feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 035) Downhole: 3684 Surface: 85 18. asing rogram: Size Specifications Setting D>~pth To Bottom u o >ement c:f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD ND 3 includin sta a data qo 12-1/4" 9-5l8" 40# L-80 BTC-M 5637' Surface Surface 5537' 4506' x AS Lite 3,-85~`sx Class 'G' ' N/A 7" Tieback 26# L-80 BTC-M 5387' Surface Surface 5387' 4440' 145 sx Class 'G' ~ 7o v L: t<e 8-3/4" 7" 26# L-80 BTC-M 8774' 5387' 4440' 14161' 8331' 90 sx Class 'G',-8~4g'sx Class 'G' ~ 6-1/8" 4-1/2" 12.6# L-80 lBT-M 530' 1406i' 8288' 14590' 8337' 7 sx Class 'G` ~ 19. PRESENT WELL CONDITION SUMM ARY (To b®'~mpleted for Redrill AND Re-entry Operations) Total Depth MD (ft): 13550 Total Depth TVD (ft): 9139 Plugs (measured): 11468 Effective Depth MD (f~: 13314 Effective Depth TVD (ft): 9003 Junk (measured): None Casin Len h Size Cement Volume MD TVD r I n c or 100' 20" 100' 100' 2674' 13-318" 00 sx Permafrost II 2674' 2674' 11960' 9-5/8" 1500 sx Class 'G', 125 sx PF II 11960' 8188' P i 1903' 7" 00 sx Class 'G' 11647' - 13550` 8809' - 9139' Pertoration Depth MD (ft): None (Squeezed) Perforation Depth ND (ft): None 20. Attachments ®Filing Fee, $100 ^ 80P Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis-- ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name ve Wes1e Title Senior Drilling Engineer Preparetl 8y Nama(Number. Si nature Phone 564-5153 Date /~'~~~~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number:~,~7 1 API Number: 50- 029-20160-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sample equired ^ Yes ~No Mud log Required ^ Yes „~No _t,. Hydr a Sulfide Measures ^ Yes ~No Directional Survey Required ,,~Y s ^ No Other: ~~S l ~ r~ v 4 [~O D S~ti . ~l=T t_¢.. w~'.r.~. tC~.~t 1 D r~ ~-t f~¢ c~. Per c z~ o s (. k.~ LI ~, a,l t ~ v~,.t e t3 0~ ~ t ~ f~ r~ e.e eau. ~,...c t' s ~..~ ~'-~a ~~ ~c,~. . APPROVED BY A ro THE COMMISSION Date ! ~ ~ ~ ysGk' Form 10-401 Re a 200 Submit In Duplicate r Exhibit III-1 Affidavit STATE OF ALASKA THIRD JUDICIAL DISTRICT 1, Tim Verseput, declare and affirm as follows: • 1. I am the Greater Prudhoe Bay Gravity Drainage Manager for BP Exploration (Alaska) 1nc., the designated operator of the Prudhoe Bay Unit Initial Participating Area, and as such have responsibility for Put River Sandstone Interval Formation operations. 2. On November 28, 2005, I caused copies of the August 19, 2005 Application for Amendment of Conservation Order No. 341 D for the Prudhoe Oil Pool and Area Injection Order No. 4C to include the Put River Sandstone Interval Formation to be provided to the below referenced surface owner and operators of all land within aone-quarter mile radius of the proposed injection areas. Prudhoe Bay Unit Operator: Maureen Johnson, GPB Performance Unit Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Surface Owner: Dick Mylius, Acting Director Division of Mining, Land & Water Department of Natural Resources 550 West 7th Avenue, Suite 1070 Anchorage, AK 99501 • i Subsurface Owner and Operator: Bill Van Dyke, Acting Director Division of Oil & Gas Department of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 Signed: a v Tim Verseput Date GPB Gravity Drainage Manager BP Exploration (Alaska) Inc. Declared and affirmed before me this 2~~ day of l~1 c~ u~evv~,b-ems , 2005. ~1 ~~,OI~Lt.~c~ ~ ~~ Notary Public in and for Alaska My commission expires: l t :` NOTARY .~ ~F'OF • P~-PS`s i • Planned Well Summary Sidetrack ! Well 01-08A Type Horizontal / Object ve Put River Water In'ector AFE Number: PBD 4P2448 API Number: 50-029-20160-01 Surface Northin Eastin Offsets TRS Location 5,939,851.43 698,863.54 4024' FSL / 3758' FEL 10 N, ~ E,~ i5 Target Northin Eastin Offsets TRS Location 5,943,935 689,966 3236' FSL / 2227' FEL 10 N, 14 E, 1 Bottom Northin Eastin Offsets TRS Location 5,944,150 689,600 3460' FSL / 2587' FEL 10 N, 14 E, 1 Planned KOP: 2,350' and Planned Spud: 12/10/05 Ri Nabors 2ES Planned Lateral TD: 14,590' and Planned Lateral TVD: 8,337' tvd GL: 37.9' RTE: 66.4' Directional Program A roved Well Ian: WP07 Exit oint: X50' and / 2,284' sstvd Maximum Hole Inclination: --1° at 2,350' in the original well bore, 9 _ at 14,438' in the planned 6-1/8' horizontal. A Gyro survey will be run over the vertical hole before drilling. This will improve our positional uncertainty for the entire wellbore. Proximity Issues: Well 01-20 will need to be risked base to 1:200 to pass BP's A/C criteria. Well 01-29 passes major risk criteria, but will have a close tolerance line. Details are listed in the attached Anti-Collision re ort. Surve Pro ram: Standard MWD+IIFR+MS Nearest Well: Well 01-29, with acenter-to-center distance of ~59' at --5,349' md. Nearest Property Line 24,120' 1n~4d' 01-08A P Sermit to Dri{I2i Page 1 ~ • Logging Program Hole Section: Required Sensors /Service 12-114" intermediate 1 MWD DIR/GR (G/MWD used for whipstock & initial drill out until clear of ma netic interference throu h the interval all in real-time mode. 8-3/4" intermediate 2 MWD DIR/GR/RES/PWD throughout the interval all in real-time mode. The RSS tool is re uested to have GR and Inc at bit. DIR/GR/RES/DEN/NEU throughout the interval all in real-time mode. Neutron 6-1 /8" production: and Density tools will be picked up after finishing the build section and a MAD performed over the build section BEFORE drilling the lateral. Two sample catchers will be re uired at com an man call out. Cased Hole: USIT Lo tanned from 7" drillin liner shoe to ~ 3,000' O en Hole: None tanned Mud Program Fresh water LSND Hole Section / o eration: 12-1/4" Intermediate .Hole 1 Depth ft Density Gra ty PV (cP) YP 2 API FL l pH MBT ) ( (ppg) Solids % (Ib/100ft) (m /30min) ~2, 350 window 8.8 < 6.0 15 - 22 30 - 40 NC 9.0 - 9.5 < 20.0 millin 2,370' - 8.8-9.2 <6.0 18-25 22-28 <9.0 9.0-9.5 <20.0 5,537' Fresh water LSND Hole Section ! o eration: 8-3/4" Intermediate Hote 2 Depth (ft) Density ) ( Gra ty PV (cP) YP 2 Ibl100ft API FL ll30 i pH MBT ppg Solids % ( ) (m m n) 5,53T - 9.0-9.6 <6.0 15-22 22-30 <8.0 9.0-9.5 <20.0 13,385' 13,385' - .8 <6.0 18-28 22-28 <5.0 9.0-9.5 <20.0 14,161' FloPro SF Hole Secti on / o eration: 6-1/8" Production Hole Depth Density LSRV PV YP 2 API FL H p Chlorides MBT (ft) (ppg) (cP) (Ib/100ft) (mV30min) (mg/I) 14,161' - 8.4 >20,000 8-15 24-30 <7.0-9.0 9.0-9.5 <600 <20.0 14, 590' 01-08A Permit to Drill Page 2 s • Casing /Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size ~ and / tvd and / tvd 12-1/4" 9-5/8" 40 L-80 BTC-M 5,537' Surface 5,537' / 4,506' 9-5/8 CSG 7" Tieback 26.0# L-80 BTC-M 5,387' Surface 5,387' / 4,440' 8-3/4" 7" 26.0# L-80 BTC-M 774' 8 5 387' / 4 440' 14'161' / ' , , , 8,331 6-1/8" 4-1/2" 12.6# L-80 IBT-M 530' 14,061'/ 8,288' 14,590'/ 8,337' Tubin 4-1/2" 12.6# L-80 IBT-M 14,06i' Surface 14,061'/ 8,288' Cementing Program Casin Strin 9-5/8", 40#, L-80, BTC-M 9-5/8" Slurry Design Basis: Lead slurry: 2,350' of 13-318" x 9-5/8" annulus with 10% excess, plus ~_ ~~ Tail slurry: 3,187' of 12.25" x 9-5/8" annulus with 40% excess, plus 100' of 9- 5/8" 47# shoe track. Pre-Flush None Planned '3x38 S acer 40bbls MudPUSH II Fluids Sequence /Volume: Lead Slurry ~56bbls / ~ ,1 ArcticSet Lite 3 (with freeze protect), 10.7 .4 /s ,¢o Tail Slur a-73bbls ft / x Class `G', 15.8 • 1.16 /sk. BHST: 92° ill b Ce i d h fl BHCT: 79° ment w e m xe on t e y Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner 1 s Sta e Slurry Design Basis: Lead slurry: None Planned. Tail slurry: 1,500 of 8-3/4" x 7" annulus with 40% excess, plus 100' of 7", 26# shoe track Pre-Flush None Planned Fluids S e /V l S acer 25bbls MudPUSH II at 11.8 equ nce o ume: Lead Slur Z Li z , 5 Tail Slur 60bbls / 337 ft 294`sx Class 'G', 15.8 .16 ft /sk. BHST: 180° ill b C i d hemfil BHCT: 119° ement w e m xe on t y Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner (2" Sta e) Slurry Design Basis: Lead slurry: None Planned. Tail slurry: 4,148 of 8-3/4" x 7" annulus with 40% excess, plus 100' of 7", 26# shoe track, plus 150' of 9-5/8" X 7" liner lap, plus 200' of 9-5/8" X 5" drill pipe annulus. Pre-Flush None Planned Fl id S /V l S acer 40bbls MudPUSH II at 11.8 u s equence o ume: Lead Slur None tanned L i c f 2. Tail Slur ~bbls 1-9~6•ft / ,.1.5:8 t /sk. BHST: 135° ill b i Cem t d th fl BHCT: 100° w e m on en xe e y k~Gok-- ~~~" I~~'" 01-08A Permit to Drill Page 3 • • Casin Strin 7", 26#, L-80, BTC-M Tieback Slurry Design Basis: Lead slurry: None Planned. ~ ~~~~ Tail slur :1,000 of 9-5/8" x 7" annulus, lus 40' of 7" 26# shoe track Pre-Flush None Planned Fluids Se uence /V l m S acer 15bbls MudPUSH II at 11.8 q e: o u Lead Slur None lanned Tail Slur 30bbls / 168 ft / 4 x Class `G', 15.8 .1 t /sk. BHST: 90° ill b C i d h fl BHCT: 79° ement w e m xe on t e y Casin Strin 4-1/2", 12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Slurry Design Basis: Tail slurry: 429' of 4-i/2" X 6-1/8" annulus with 40% excess, plus 100' of 4~ 1/2 , 12.6# shoe track, plus 100 of 7 X 4-1/2 liner lap, plus 200 of 7 X 4 drill i e annulus. Pre-Flush 10bbls CW 100 Fl id S /V l S acer 15bbls MudPUSH II at 11.0 u s equence o ume: Lead Slur None lanned Tail Slur 18bbls / 101 ft / 8 x Class `G', 15.8 ; 1 16 /sk. BHST: 180° C ill b b h i d b f i ° ement w ore pump e atc m xe e ng BHCT: 119 Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 13-3/8" Casin to surface Bride lu to surface 30 min recorded 3,000 si 13-3/8" Casin window 20' be and middle of window FIT 10.8 EMW 9-5/8" Casin to surface Landin collar to surface 30 min recorded 3,500 si surface 9-5/8" Casin shoe 20' be and middle of window FIT 11.5 EMW 7" Casin to surface Liner Landin collar to surface 30 min recorded 4,000 si surface 7" shoe 20' be and shoe FIT 10.3 EMW 4-1/2 liner to surface Liner Landin collar to surface 30 min recorded 4,000 si surface 01-08A Permit to Drill Page 4 • • Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. ROPE and drilling fluid system schematics are currently on file with the AOGCC. Well lnterval: 12-114" intermediate 1 interval Maximum antici ated BHP: 1,994 psi at 4,512' TVD. Maximum surface ressure: 1,495 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 28.5 BBLS with 10.3 ppg EMW FIT (FIT TO 10.8 PPG EMW - ~46 BBLS WITH A 10.8 PPG EMW FIT Planned ROPE test pressure: 250 psi low / 4,000 psi high - 7 day test cycle until the whipstock is icked u .Once whi stock is icked u a 14 da test c cle be ins. BOPE configuration for 9-5/8" C/O to 9-5/8" pipe rams while running the 9-5/8" liner. Casin BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except Planned BOPE function test when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Well Interval: 8-314" intermediate 2 interval Maximum antici ated BHP: 3,684 psi at 8,337' TVD. Maximum surface ressure: 2,850 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 239 BBLS with 11.3 EMW FIT FIT TO 11.5 PPG EMW Planned BOPE test ressure: 250 si low / 4,000 si hi h -14 da test c cle. ' ROPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Well Interval: 6-1/8" production section Maximum antici ated BHP: 2,700 psi at 8,338' TVD. Maximum surface ressure: 1,866pS1 (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.8 EMW FIT FIT to 10.3 EMW Planned BOPE test ressure: 250 si low / 4,000 si hi h ~ Planned com letion fluid: 8.4 seawater J 7.Op Diesel ¢ODO ~,~, (nl Planned BOPE test ressure: 250 si low / si hi h -14 da test c cle. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. 01-08A Permit to Drill Page 5 s • Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation ssTVD ft MD ft Est. Pressure PSI SV5 -2500 2567 SV4 -2845 2929 SV3 -3445 3659 SV2 -3635 3915 SV1 -4058 4676 UG4 -4630 5965 2537 UG3 -4815 6382 2619 UG1 -5450 7814 2898 WS2 -6010 9076 3144 WS1 -6235 9583 3243 CM3 -6473 10120 CM2 -6940 11173 CM1 -7627 12722 THRZ -8010 13585 BHRZ -8170 13946 To Put River SS -8265 14161 2700 LCU -8290 Below TD n/a TD Criteria TD Criteria: Intermediate 1 Drill ~40' into the last 100' TVD thick shall in the SV1, above the Ugnu formation. TD Criteria: Drill to the Top of the Put River Formation. Intermediate 2 TD Criteria: Production Drill to TD of plan. There is room to the Northwest of the polygon in needed. 01-08A Permit to Drill Page 6 s • Fault Prognosis Formation where encounter the Fault Est. MD Intersect SSTVD Intersect Est. Throw Throw Direction Uncertainty Fault #1 -above 12800 0 at this D to W THRZ 0 throw? level Fault #2 - in THRZ 0 at this 13600 D to E 0 throw? level The propose 01-BAi well will cross the trend of one NE-SW trending down to the W fault at about 12,800 ft md. However the well has been planned to cross the fault trend above the THRZ where there is no observable offset on the seismic. The well will also cross the tip point of a second small N-S trending down to fhe E fault at about 13,600 ft md, in the HRZ, where there is no detectable offset. Because the well will cross above both faults, in a shale section, where there is no observable offset, there should be minimal risk of lost circulation. Examination of the uphole well path on seismic shows no obvious faulting or other drilling hazards. The well is located in an area of moderate LC Risk according to the WORD Lost Circulation risk study. Lost circulation risk is considered low for the faults in fhe area, particularly on the east-west to northeast-southwest striking faults. No significant lost circulation has occurred in the surface or intermediate hole in the area. The nearest significant LC incident was approximately 3500 feet north in well 02-12. Well rig/coil Barrels MD TVDSS Zone X Y Comments 02-12 rig 150 10531 9142 Below BS 690394 5947278 casing 02-12A coil 3 11094 8963 ZONE 1 690516 5946566 Operations Summary Pre-Rig Work: 1. Rig up slickline. Pull PXN plug from TP. Drift 5-1/2" x 4-1/2" tubing through WLEG. Tag and record PBTD below W LEG. 2. Fluid pack the tubing and inner annulus. 3. P&A perfs in 7" liner from the 10' of cement on top of the IBP set at 13,314' MD. RIH with coil to PBTD (13,314' MD). Lay in 74 bbls of cement to 11,320' MD (Above top of production packer). Wash down to confirm TOC @ 11,320'. POH with coil. a. Cement Calculations: • 7" liner = 13,314' - 11,647' or 1,667' (~62 BBLS) • 9-5/8" casing = 11,647' - 11,534 or 113' (~8 BBLS) • 4-1/2" tubing = 11,534' - 11,406' or 128' (~2 BBLS) • 5-1/2" tubing = 11,406' -11,320' or 86' (~2 BBLS) • Total cement volume of 74 BBLS 4. Rig up slickline, drift 5-1/2". Tag TOC. 5. Jet cut the 5-1/2" tubing at ~ 2,950' MD. 6. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 7. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to 2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. 01-08A Permit to Drill Page 7 • s Rig Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 5-1/2" tubing from the pre-rig cut 2,950'. Spool up SSSV control lines. 5. MU 9-5/8" casing scraper assembly. RIH picking up 5" DP to 2,700' & circulate wellbore. 6. MU a 9-5l8" CIBP on DP & set 2,500'. POOH. 7. C/O to 9-5/8" Rams. 8. MU a Baker 9-5/8" casing cutting assembly. RIH picking up 5" drill pipe to ~2,390'md. Cut the 9-5/8" casing per Baker representative instructions. POOH and VD assembly. 9. MU a 9-5/8" casing spear assembly and unseat the casing. Circulate the Arctic Pack from the annulus with warm diesel followed by sea water and detergent sweeps. Pull the 9-5l8" casing from the cut at 2,390'. 10. RU a-line. Run Gauge Ring /Junk basket and Gamma Ray tool for 13-3/8", 72# casing with CCL to casing stub ~ 2,390'. 11. RIH with 13-3/8" EZSV on a-line. Set EZSV at 2,370 to avoid cutting a casing collar during window milling operations. RD a-line. 12. CIO to variable Rams. 13. Close rams and pressure test the 13-318" casing and bridge plug to 3,000 psi for 30 minutes. 3- whipstock and bottom trip anchor with a 12-114" window milling assembly. BHA will contain a UBHO sub and G/MWD tool for whipstock orientation. RIH on 5" DP to EZSV. Orient and set the / whipstock. Swap well over to 8.8 ppg milling fluid. E-line will be utilized to ensure G/MWD tools match up to Gyrodata's a-line Gyro orientation. -r{ r _ ~o .,~0~15. Mill a window in the 13-3/8" casing at ±2,350' MD plus 20' from mid window. Perform FIT to 10.8 ppg. ~ ~ I POOH for Drilling BHA. Note: Verify that the mud weight is 8.8 ppg prior to cutting the window. ~P-'~ ~ °~' 16. MU the 12-1/4" drilling assembly with DIR(G/MWD)/GR/RES/PWD and RIH. Kick off and drill 12-1/4"---, interval to 9-5/8" casing point at the shale interval just before the Top Ugnu 4 (4,440' ssTVD / ~ 3~'~ "r MD). Short trip and condition wellbore for 9-5/8" casing. POOH. The G/MW D surreys will be used°until clear of magnetic interference. 17. Run a 9-5/8" BTC-M casing throughout the 12-1/4" hole and back into the 13-3/8" casing to surface. Cement will be brought up to surface. 18. MU the 8-3/4" RSS drilling se bly with DIR/GR/RES/PWD and RIH to the landing collar. 19. Pressure test wellbore to ,50 psi for 30 minutes. 20. Drill shoe track. Ensure 9.0 ppg mud throughout system and drill 20' of new formation. Perform FIT to 11.5 ppg. 21. Continue drilling 8-314".,interval ho~ng inclination ~65° to the THRZ Formation at 13,585' MD. Mud weight will be inc ased to 10.8 ppg before drilling into the THRZ. Drill ahead holding angle until 7" casing point ~1 ,161"Short trip and condition hole for 7" liner run. POOH racking back as much 5" drill pipe as pose to limit the amount of time before running 7" liner. 22. Run and cement a 7" drilling liner throughout the 8-3/4" hole and back into the 9-5/8" casing 150' to 5,387' MD. Cement will be pumped in two stages. Set hanger /liner top packer and displace cement with mud. POOH laying down the 5" DP. LD all 5" DP from Derrick. 23. RU and run 7" Tie-back liner to surface. Cement will be brought up to ~ ,5$'!' MD. The top 2,200' of 9- 5!8" by 7" annulus will be freeze protected to surface. 24. MU 6-1/8" clean out BHA wi u ed bit. RIH picking up 4" DP to the 7" tieback landing collar. ~ 25. Pressure test wellbore to 4 0 psi for 30 minutes. 26. Drill out 7" tieback float eq ent. 27. Continue to RIH picking up 4" DP to the 7" ES cementer. Drill out 7" ES Cementer equipment. 28. Continue to RIH picking up ~P to the 7" drilling liner landing collar. 29. Pressure test wellbore to 4~bOQ'psi for 30 minutes. 30. Drill out shoe track. Swap ~r to 8.4ppg FloPro mud. POOH for USIT logging tools ~ 31. RU a-line. RIH w/USIT to 7" shoe. Log USIT from 7" shoe to 3,000'. POOH RD a-line. 32. MU 6-1/8" BHA with DIRlGR/RES and RIH to the 7" shoe. Drill at least 20' (not more than 50') of ~ formation sliding for build. 33. Perform FIT to 10.3 ppg. 34. Drill the 6-118" build interval as per directional plan building to --93° (estimated 14,438' MD). POOH for horizontal assembly. 01-08A Permit to Drill Page 8 • • ,=_~ 35. MU,•~-1/ ~' BHA with DIR/GR/RES/NEU/DEN and RIH. Drill horizontal interval to an estimated TD of ~ 14;5 ' md. Condition well bore for the 4-1l2" solid, cement liner. POOH racking back DP. LD drilling as bly. 36. Run and cement a 4-Y2" solid production liner extending the liner lap 100' into the drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. Note: A perf pill will be left in the 4-1/2"liner. 37. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 38. Run the 4-1 /2", 12.6#, L-80 completion tying m ~h~ 4-1 /2" liner top. ~ 39. Set packer and individually test the tubing to . ,00~"psi and annulus to ,O,Q~ psi for 30 minutes each. 40. Set and test TWC. ~'" 41. ND BOPE. NU and test the tree to 5,000 psi. 42. Freeze protect the IA and Tubing to 2,200' and secure the well. 43. RDMO. Post-Rip Work: 1. Install wellhouse and flowlines. New "S" Riser will be manufactured. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 3. Install gas lift valves. Job 1: Move In / Rig Up /Test BOPE Reference RP • "Drilling/Vt/orkover Close Proximity Surface and Subsurface Wells" SOP. • "Hydrogen Sulfide"SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto 01-08. However, 01-29 is about 60' to the North and 01-30 is about 60' to the South of 01-08. 01-29 and 01-30 are the closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - The 01-08 well bore will be secured with the following barriers: • Note on barriers during MIRU procedures: Tubing -Tested Cement plug (P&A perfs), Kill weight fluid and a BPV. IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. OA -Kill weight fluid, tested annulus and annular valve. • Note on barriers during ND Tree / NU BOP Procedures Tubing -Tested Cement plug (P&A perts), Kill weight fluid and a TWC. IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. OA -Kill weight fluid, tested annulus and annular valve. - Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. 01-08A Permit to Drill Page 9 • • Drill Site 07 is not considered as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL with H2S Readin 01-29 5 m 06/25/05 #2 Closest SHL with H2S Readin 01-30 N/A #1 Closest BHL with H2S Readin 03-09 4 m 09105/05 #2 Closest BHL with H2S Readin 03-25 50 m 11/04/05 Max Recorded H2S Readin on the Pad 01-24A 40 m 12/22/04 - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: De-complete Well Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static prior to pulling the completion. - Note and record required PU weight to pull tubing from cut point (2,950'). - Have all wellhead and completion equipment NORM-tested, following retrieval. - The existing wellhead is a FMC Gen 1 (McEvoy) completed in 1975. tt has 9-5/8" casing set on a mandrel hanger and packoff. The current completion is a 5-1l2" crossed over to 4-1/2" just below the packer. Top lift threads of the hanger are listed as 5-1/2" Hydril running threads. Have a spear on location as a contingency to pull the Hanger to the floor. Ensure Baker has contingency grapples on location for different weight tubing pups. - There is a 5-112" Otis ROM SSSV Landing Nipple at 2,223'. There should be 2, '/a" encapsulated control lines run to surface. The historic records are unclear, but there should be 2 control lines with an unknown number of protectors or SS bands. - Ensure a 9-5/8" casing scraper has been run across the planned CIBP setting depth and the 9- 5/8" cut point. This covers both RP's for these operations. 01-08A Permit to Drill Page 10 Job 3: Run Whip Stock Reference RP • "Whipstock Sidetrack' RP. • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards • - BOP test interval during this phase is 7 days until the whipstock is picked up. Once the whipstock is picked up the 14 day test cycle starts and continues until the rig moves off the well. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. - A 13-3/8" whip stock will be run and set in the existing 13-3/8" 72# casing. A 12-1/4" window will then be milled in the 13-3/8" 72# casing. Ensure entire wellbore has been circulated to 8.8 ppg mud before milling commences. - Expect cement behind the 13-3/8" casing at the sidetrack point. - Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. - Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. 01-08A Permit to Drill Page 11 • s Job 5: Drill Intermediate 1 (12-1/4") Hole Reference RP • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "Shale Drilling- Kingak & HRZ" Issues and Potential Hazards - 01-08A is not expected to cross any mapped faults in the 12-1/4" intermediate hole section. If losses/breathing are encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. - KICK TOLERANCE: In the worst case scenario of 8.5 ppg pore pressure at the 9-5/8" casing depth, gauge hole, a fracture gradient of 10.3 ppg at the 12-1/4" casing window, 8.8 ppg mud in the hole, the kick tolerance is 28.5 BBLS. FIT will be to 10.8 ppg. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Phase 6: Run and Cement Intermediate Liner 1 Reference RP • "Surface Casing and Cementing Guidelines" RP Hazards and Contingencies - Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab !surge pressures could initiate instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the liner is left stationary across permeable formations. Proper casing centralization and keeping the liner moving will facilitate minimizing the potential for differential sticking. - 01-08A is not planned to cross any faults in the 12-1/4" interval. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. 01-08A Permit to Drill Page 12 • r Job 5: Drill Intermediate 2 (8-3/4") Hole Reference RP • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "Shale Drilling- Kingak &HRZ" Issues and Potential Hazards - 01-08A is expected to cross two mapped faults in the 8-3/4" intermediate hole section. Although, both fault have no appreciable offset so losses or well bore stability is not expected. If losses/breathing are encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. - KICK TOLERANCE: In the worst case scenario of 8.5 ppg pore pressure at the 7" TD depth, gauge hole, a fracture gradient of 11.3 ppg at the 12-1/4" casing window, 10.8 ppg mud in the hole, the kick tolerance is 239 BBLS. FIT will be to 11.5 ppg. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Phase 6: Run and Cement Intermediate Liner 2 & Tieback Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Hazards and Contingencies - Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the liner is left stationary across permeable formations. Proper casing centralization and keeping the liner moving will facilitate minimizing the potential for differential sticking. - 01-08A has the possibility of crossing two faults in the 8-3/4" interval. Detailed depth listed on page 6. - 7" 26# drilling liner will be cemented in 2 stages. 15t stage will cover the bottom 1,500' from the 7" shoe. The 2" stage will be performed through an HES ES Cementer set -100' below the deepest West Sak formation. Cement will be brought up to the top of the liner. - The 7" 26# tieback will have 1,000' of cement place in the 9-5/8" x 7" just above the seal assembly. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. 01-08A Permit to Drill Page 13 • • Job 7: Drill Production Hole Interval Reference RP • "Leak-off and Formation Integrity Tests" SOP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management' RP Issues and Potential Hazards - The 01-08A wellbore does not cross any mapped faults in the production interval. - Differential sticking is a concern. The 8.4 ppg mud will be 953 psi over balanced to the Put River formation when static. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). - An EMI-920 sweep will be pumped just ahead of the new Flo-Pro mud during displacement after drilling the shoe track due to the tortuosity of this wellbore. - A liner running pill will be left in the open hole on the final trip out of the hole to run the solid liner. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Job 9: Run Production Liner Reference RP • "Modified Conventional Liner Cementing' RP • Schlumberger Cement Program. Issues and Potential Hazards - The completion design is to run a 4-1 /2", 12.6#, L-80 IBT-M solid liner throughout the production interval - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 953 psi over balanced to the Put River formation when static. Minimize the time the pipe is left stationary while running the liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will be run to extend 100' above the bottom of the 7" liner shoe. - A Hi-Vis perforation pill will be spotted in the 4-1/2" liner as per MIDF recommendations. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. 01-08A Permit to Drill Page 14 • • Phase 10: DPC Perforate Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - The well will be DPC perforated overbalanced, after running and cementing the 4-1/2 liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. - Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Job 12: Run Completion Reference RP • "Completion Design and Running" RP • "Casing and Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well to 2,200'. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4-1/2", 12.6#, L-80, IBT-M production tubing string, stinging into the 4-1/2" production liner tieback sleeve. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. 01-08A Permit to Drill Page 15 • Job 13: ND/NU/Release Rig Reference RP • "ADW Rig Move" RP. • "Freeze Protecting an lnnerAnnulus" RP. Issues and Potential Hazards - No wells will require shut-in for the rig move off 01-08A. However, 01-29 is about 60' to the North and 01-30 is about 60' to the South of 01-08. 01-29 and 01-30 are the closest surface neighboring wells. Care should be taken white moving off the well. Spotters should be employed at all times. - Note on Barriers during the ND BOP / NU Tree procedures: ^ Tubing -Kill weight fluid an a RHC plug with ball & rod and a TWC. ^ IA -Kill weight fluid, tested annulus and annular valve. • OA -Kill weight fluid, tested annulus and annular valve • OOA -Fully Cement Annulus. - Note on Barriers during the RDMO procedures: ^ Tubing -Kill weight fluid on a RHC plug with ball & rod and a BPV. ^ IA -Kill weight fluid, tested annulus and annular valve. ^ OA -Kill weight fluid, tested annulus and annular valve ^ OOA -Fully Cement Annulus. 01-08A Permit to Drill Page 16 TREE _ ? •WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 72' BF. ELEV = ? KOP = 3000' Max Angle = 63 @ 7600' Datum MD = 13095' Datum TV D = 8800' SS 20" CSG, 94#, H-40, ID = 19.124" 13-3/8" CSG, 72#, MN-80, ID = 12.347" ~ 01-08 ~ Current 0 2223' --' 5-1/2" OTIS ROM SSSV NIP, ID = 4.562" 100' 2402` & 2628' - 9-5/8" FO Cementers Cement was pumped between FO Cementers Minimum 1D = 3.813" @ 11468' 4-1/2" OTIS X NIPPLE Ij 5-1/2" TBG-NPC, 17#, L-80, .0232 bpf, ID = 4.892" ~--~ 11406_ III TOP OF 4-1/2" TBG-NPC 11406' 4-1/2" TBG-NPC, 12.6#, ~ 11534' MN-80, .0152 bpfi, ID = 3.958" TOP O~ F 7" L~-r 11647' 9-5/8" CSG, 47#, MN-80/SOO-95, ID = 8.681" ~-( 11 PERFORATION SUMMARY REF LOG: BHCS ON 07/07/75 ANGLEATTOPPERF: 52 @ 12776' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12776 - 12786 S 04/03/88 3-3/8" 6 12954 - 12964 S 04/03/88 3-1/8" 4 12970 - 12980 S 10/11/84 3-3/8" 4 13000 - 13030 thief zone 10/11/84 3-318" 1 13050 - 13068 S 10/27/86 3-3/8" 1 13072 - 13092 S 10/27/86 3-318" 1 13096 - 13116 S 10/27/86 3-3/8" 1 13120 - 13140 S 10/27/86 2-7/8" 4 13160 - 13185 S 02/10/77 7" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" 13550' TD 13550' DATE REV BY COMMENTS DATE REV BY CONNvIENTS 07/22/75 ORIGINAL COMPLETION 09/22105 KSB/TLH TTP SET (05/05105) 09/23197 LAST WORKOVER 02/15/01 TP CORRECTIONS 06/05/03 CMO/TLP MAX ANGLE 08/17/03 CMO/TLP DATUM MD CORRECTION 11/29/04 DFR/TLP 20" CSG, CORRECT 9-5/8" CSG 13314' (-~ IBP W/10' CMT ON TOP (08/29/90 PRUDHOE BAY UNff WELL: 01-08 PERMIT No: 1750260 API No: 50-029-20160-00 SEC 4, T10N, R15E, 1095.37' Flt 8 3694.26' FNL BP Exploration (Alaska) ' ~ 11310' -~ 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 11347' 5-112" OTIS XN NIP, ID = 4.455" 11354' 5-1/2"BOTPBRASSY~ 11395' 9-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.75" 11406' ~5-1/2" X 4-1/2" XO 11468' 4-1/2" OTIS X NIP, ID = 3.813" 'e " ' 4-1/2 PXN TTP (05/05/05) 11468 11531' 4-1/2" BOT SHEAROUT SUB 11534' --~ 4-1/2" TUBING TAIL 11521' ELMD TT LOGGED 10/22/76 TREE _ ? WELLHEAD FMC ACTUATOR = AXELSON KB. ELEV = 72' BF. ELEV = ? KOP = 3000' Max Angle = 63 @ 7600' Datum MD = 13095' Datum TV D = 8800' SS ~ 01-0 8 Pre-Rig 20" CSG, 94#, H-40, ID = 19.124" (-i 100' 5-1/2" OTIS ROM SSSV NIP, ID = 4.562" I 2402` & 2628' - 9-5/8" FO Cementers Cement was pumped between FO Cementers 13-3/8" CSG, 72#, MN-80, ID = 12.347" I-~ 2674' --2950' -Jet Cut Minimum ID = 3.813" @ 11468' 4-1 /2" OTIS X NIPPLE 5-1/2" TBG-NPC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 11406' TOP OF 4-1/2" TBG-NPC 11406' 4-1/2" TBG-NPC, 12.6#, 11534' MN-80, .0152 bpf, ID = 3.958" TOP OF 7" LNR 11647' 9-5/8" CSG, 47#, MN-80/SOO-95, ID = 8.681" 11960' PERFORATION SUMMARY REF LOG: BHCS ON 07/07/75 ANGLE AT TOP PERF: 52 @ 12776' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12776 - 12786 S 04/03/88 3-3/8" 6 12954 - 12964 S 04/03/88 3-1/8" 4 12970 - 12980 S 10/11/84 3-3/8" 4 13000 - 13030 thief zone 10/11/84 3-3/8" 1 13050 - 13068 S 10/27/86 3-3/8" 1 13072 - 13092 S 10/27/86 3-3/8" 1 13096 - 13116 S 10/27/86 3-3/8" 1 13120 - 13140 S 10/27/86 2-7/8" 4 13160 - 13185 S 02/10/77 7" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" ~ 13550' TD 13550' 11310' -i 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" I I 11320` -Top of Cement P&A Plug 1134T S-1/2" OTIS XN NIP, ID = 4.455" 11354' S-1/2" BOT PBRASSY 11395' 9-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.75" 11406' 5-1/2" X 4-1/2" XO 11468' 4-1/2" OTIS X NIP, ID = 3.813" 11531' 4-1/2" BOT SHEAROUT SUB \ ' " 11534 TUBING TAIL 4-1/2 ' 11521' ELMD TT LOGGED 10/22/76 m 'x~ b . ;- • ' m s 13314' IBP W/10' CMT ON TOP (08/29/90) DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/75 ORIGINAL COMPLETION 09/22(05 KSB/TLH TTP SET (05/05/05) 09/23/97 LAST WORKOVER 02/15/01 TP CORRECTIONS 06/05/03 CMO/TLP MAX ANGLE 08!17/03 CMO/TLP DATUM MD CORRECTION 11/29;04 CI=R/TLP c0" ~U. -.;RR~~ ~- r8" ~SGj j PRUDHOE BAY UNIT WELL: 01-08 PERMIT' No: 1750260 API No: 50-029-20160-00 SEC 4, T10N, R15E, 1095.37' FEL & 3694.26' FNL BP Exploration (Alaska) TREE _ ? WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 72' BF. ELEV = ? KOP = 3000' Max Angle Datum MD Datum TV i = 63 @ 7600' = 13095' = 8800' SS 20" CSG, 94#, H-40, ID = 19.124" D '~ ~~' 13-3/8" HES EZSV --"2370' Mechanical Cut --"2390' 2402` & 2628' - 9-5/8" FO Cementers Cement was pumped between FO Cementers 13-3/8" CSG, 72#, MN-80, ID = 12.347" 2674' Jet Cut - -2950' PERFORATION SUMMARY REF LOG: BRCS ON 07/07/75 ANGLE AT TOP PERF: 52 @ 12776' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12776 - 12786 S 04/03/88 3-3/8" 6 12954 - 12964 S 04/03/88 3-1/8" 4 12970 - 12980 S 10/11/84 3-3/8" 4 13000 - 13030 thief zone 10/11/84 3-3/8" 1 13050 - 13068 S 10/27/86 3-3/8" 1 13072 - 13092 S 10/27/86 3-3/8" 1 13096 - 13116 S 10/27/86 3-3/8" 1 13120 - 13140 S 10/27/86 2-7/8" 4 13160 - 13185 S 02/10/77 M in im u m ID = 3.81 3" @ 11 468' 4 -1 12 " O T IS X N IP P L E LTOP OF 4-1 /2" TBG-NPC 4-1 /2" T8G-NPC, 12.6#, MN-80, .0152 bpf, ID = 3.958" TOP OF 7" LNR 9-5/8" CS G. 47 tt. MN-80/SOO-95. ID = 8.681" 01-0 8 Decomplete r ~ ~_ ,~, Y `~ -2500' - 9-5/8" HES CIBP Pull & LD 5-1 /2" TBG Set 9-5/8" CIBP Cut & Pull 9-5/8" CSG just above FO CMTR Set 13-3/8" EZSV '~ ~ ~ 310• 1--1 5-1/2" OTIS XA SLIDING SLV ID = 4.562" 11 320" -Top of Cement P8.A Plug 17347' S-1/2" OTIS XN NIP, ID = 4.455" 11354' S-1/2" BOT PBR ASSV 11395' 1-1 9-5 /8" X 5-1 /2" BAKER SA B PK R, ID = 4.7 11~ 40~ 5-1l2" X 4-112" XO ~- e~ 4-1/2" OTIS X NIP, ID = 3.813" IBP W/1 = 6 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/75 ORIGINAL COMPLETION 09/22/05 KSB/TLH TTP SET (05/05/05) 09/23/97 LAST WORKOVER 11/10/05 KWA Proposed Completion 02/15/01 TP CORRECTIONS 06/05/03 CMO/TLP MAX ANGLE 08/17/03 CMO/TLP DATUM MD CORRECTION 11/29/04 DFR/TLP 20" CSG, CORRECT 9-5/8" CSG PRUDHOE BAY UNIT WELL: 01-08A PERMIT No: API No: 50-029-20160-01 BP Exploration (Alaska) ~1-08A ~ Proposed Completion ~ 20" CSG, 94#, -2,200' HES 4-1/2" X Nipple ID = 3.813" H-40, ^' 100` - ~ 2350' -Top of Whipstock / 7", 26#, L-80, BTC-M Tieback 4-1/2", 12.6#, L-80, IBT-M TBG WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = BF. ELEV = KOP = Max Angle = Datum MD = Datum TV D = GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 TBD TBD TBD TBD 13-3/8" HES EZSV - -2370' Mechanical Cut - -2390' 2402` & 2628' - 9-5/8" FO Cementers CMT between FO Cementers 13-3/8" CSG, 72#, _ _2674' L-80, MN-80 9-5/8" HES CIBP - --2500' Jet Cut - -2950' 5-1/2" TBG-NPC, 17#, L-80 I I 9 I • -453T - TOC -5537' - 7" Seal assy ' , / -5387 -BKR HGR &LTP w/TB sleave / -5537' - 9-5/8", 40#, L-80, BTC-M -9685' - BOC &7" HES EZ CMTR -12661 ` - TOC -14,080' HES 4-1/2" X Nipple ID = 3.813" -14,000 BKR 7" x 4-1/2" BKR PKR -14,020' HES 4-1/2" X Nipple ID = 3.813" / -14,040' HES 4-1/2" XN Nipple ID = 3.725" -14,061` 4-1/2" WLEG / -14061' -BKR HGR &LTP w/TB sleave -14161' - 7", 26#, L-80, BTC-M r \ -14490 - PBTD / -14590'-4-1/2", 12.6#, L-80, IBT-M 11~ 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 1320' -Top o f Cement PS.A Plug 11347' S-1 /2" OTIS XN NIP, ID = 4.455" 11354' S-1 /2" BOT PBR ASSY 11~ 9-5 /8" X 5-1 /2" BAKER SA B PKR, ID = 4.75" 11~ 5-1 l2" X 4-112" XO 4-1 /2" OTIS X NIP_ ID = 3.813" 1 11531• 11 4-1 /2 BOT SHEA ROU7 SUB 11$34' 4-1/2"TUBING TAIL 11521' ELMD TT LOGGED 10/22/76 11960' - 9-5/8" CSG, 47#, MN-80/SOO-95 I 13314' I~ ier wnu cMi uN lur ~uaizaiau/ 1 7" LNR, 29#, MN-80, .0371bpf, ID = 6.184" 13 5 ' ~~ 7D 13550' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/75 ORIGINAL COMPLETION 09/22/05 KSB/TLH TTP SET (05105!05) 09/23/97 LAST WORKOVER 11/10/05 KWA Proposed Completion 02/15/01 TP CORRECTIONS 06/05/03 CMO/TLP MAX ANGLE 08/17/03 CMO/TLP DATUM MD CORRECTION j '. 1 ~'Od s ~~ ? P ~ ~0" CS':. CORR`CT 9 5'8" CSv PRUDHOE BAY UNfT WELL: 01-08A PERMIT No: API No: 50-029-20160-01 BP Exploration (Alaska) ` lit' Anx,m n awn L'P (akublxxl A1.~IIxx1: AI u I m (Im._ xun Alu,lxxl: Jnr. t'~~luxlur N..n11 I nor xurW.u: I _IIIryw:J - (':nine 0.'arnlnp Mctlxxl: ILII.. Ii~.ol ~.~ ~ ~_TI 0 0 c 6001 E= ItI~.II:RI N('I_ INIi)ItA1n I It)N NIItV 1~.1' I•Rt ltfltAA1 I'Iml 111-(IxA „'nll7 ((II-(Ix: I'I:m nl-11xA1 lu+,nt N1:1N I )\ II< I x.l rx, \'.n ~ 1 I\I) k 1 ~ x. t J J N -III Il.~lxh lln Ik~rlll Ju ~uni•,'I 'I I foul l'rt:nxJ ll ' ) InIy l:Ikuhlnk li:llwlllal _ _ )_ IryuuU%,u. I I'~'/I~111)S 4 I\ Iltl x I!I%N Ix I nl.:nunxl 11.1,1 H. .r.ln. _%.• +~? ,d,.Jll :I~.xI IJ>SVI JI I'1 uvw.l' nlaw.A ury ,'VJ' AIN'l)I I~IL~AIx t h.. kx~J I)aw" ('aku6lx,n Al.tlx,J: Alnnnnnn ('an-vuve Ki~. ic.. i•J I )ul~• 0.'M I. nf:l All. CASING DETAILS Nmnc N -~ I:' -N' NxlLnlx IEmng l alnnk Iungnuk xlal No. TVD MD Name Sizr Iran: ar ea 1s7ue sal'niSI JJ rvwuasJ nl-Irz uemJ IJ%"_t'i%_It%0.' NA I 4506.10 5516 9U 9 5%8" 9.625 TARGET DETAILS 2 83 31.29 1416 L00 7" 7.000 3 8337.42 11590AU 41/2" 4.SOD N;une TVD +N/-S +E/-W Northing Fasting Shape UI-08A TI Rev 3 8331.10 3317.11 -8787.21 5943931.02 689')66.00 Point I ! I ~ I ~ i i 1 ~~ 01-08A T2 Rev 3 8337.40 4;41.70 -9147.43 5944150.02 689600.00 Point - --- - - - - ---- ---- -- -- - - - - - - - - ' -_ - ' - - - -- - i SECTION DETAILS - - - - - -- -- - - -- -- --- Sec MD hJC Az i TVD +N!-S +[;/.W DLrg TFace VSec Target - --- - V _... _ _ __ _. __ __.._ --~ - - _ _ _ I 2390.00 0.96 127.19 234295 -4.22 8.78 0.00 0.00 A.74 - - - - - - - - -- - - 2 2370.00 L52 276.34 2369.94 -4.29 8b5 12.011 IGI.00 -9.GG 3 32A1.00 3(,.72 276.34 3188.37 27.03 -273.39 4.00 0.00 256.8') -_ --. - - -. _ --. __.. _- - 4 3830.00 42.5$ 311.97 3640.66 179.38 _S, )5.96 4.0(1 90.00 G13.SG 5 4200 00 57.35 31 L97 3878A9 368.25 -805.95 4.00 0.00 R85.G4 I - - ~ ~ ~ ',~ G g5~;.00 ;828 296.63 405L94 5,2,37 -1032?I 1.00 00.00 1156.83 ~ j ~ '~ ~~ - -- - - -- _-. -- j ~ 7 4660.15 G3.G7 296.07 4117.48 574.80 -I 138.08 4.(10 -5.38 1274.96 I ~ ~ ~ ~. ~ ~ - - - - -- - - ~ ~ i 8 1411;.45 G3.G7 296.07 8311.73 4298.92 -8750.03 O.UO 0.00 9748.95 JISSMU.-t11b.~1B'TVb - - - --- ~ 9 14161.27 65,50 2')6.07 8331.40 4317.11 -8787?I 4.00 0.00 9790.34 OI-08AT1 Rev3 - _ _ _ _ 10 14270.;0 90.00 296.07 8354.40 1363.66 -8882.36 ~ 22.43 0.00 9896.27 ' '. - - _ II 11310.38 93 ?5 304.41 835327 4383.71 -8916.77 22.43 GS.G3 9936.00 _ I -- _ _ ~ 12 14590.11 2,.25 304.11 8337.40 4541.70 -9147.13 0.00 0.00 10212-86 01-08A T2 Rev 3 ' I I I ~ FORMATION TOP DETAILS -_ ~~ - _- - - - - - --- - __~_ --_-- '. ~ Nu. 'iVDPath MDPaIh Formation _ - -__~ _. __ _ - ,. _ - __ _ ~. I 2566.40 2;67.;1 SV5 ~ I - __--_ _. - ) _ - - - - - - - - - I ~ _. - -- - - ~ - ~ 2 2911.40 928.55 SV4 ~ ~ - ~-'- -- - - - - - . - -- -- - - --- - i 3 1;1 140 658-53 SV3 0 ~ ~ I ~ - - -- - - - - - - -- - - - ~ ! ~ ~ ~ 4 3701.40 3911.80 SVZ 15 - -- - --- ---- ~ - --- - I 5 4121.40 4675.74 SVI ' - -- -_ __ _ _-. .._. G 4G 9G A0 5965.22 UG4 ~0 7 4881.40 6382.28 UG3 ! I I ~ 8 5516.40 7813J9 UGI ~ ' ' 0 - - - - --- - --- -- - 10 6301.40 9;834; WSI I ` i~ ' ~, ~ .. _ _ ._ _ ) ~~ 51940 1011' C'M1 I~ G . j ~ I I ~ i - - ' - ~ - -- I ~ I _ 7006.40 I 1172.7 ('M Z - I I ~ „ 0 .. ~~ I3 7693.40 12721.51 CM I - - -- .... i ~ 0.'I ~ '',. -. - --- - -- - _. __ -. _ - 14 8076.40 13581.9? THRZ --. _- - -. 050 _ 15 8216.40 13)45.62 BHRZ I -_ -- - - 3 __ - - IG 8331.40 14161.27 Tup Put River SS - - - -.._ T , ~ 17 0.00 0.00 TJB ~ , ~ IS 0 - _ 18 0.00 O.OU TSGR I ! ~ ~ - ~ ~ ~ -- -s „t o 1 100 lain 7 Mo u)zl n o - -- 0 1500 3000 4>W 6000 7500 9000 10500 12000 Venical Srction at 296.40' [ I;OOft%in] l tlhll•AN1 nl:l All. ~ IU II~ItIIN 1 INIY1lthinll(IN In \ minu IN 1 k I N II t ,I n% Itu~ N~xIL I \.~ni.. 111\nl li 1 f..Jll t'nI.W hl1 I: hl rally,-al,u. w~.l \ II<I I ILLIUIN 01x11'1 I: .,~: tun: lu'N'.~n %f.amm~l l).~II H.~lerc nv: l%.~~i]v (s JII ~~~rhl.+lxxl: Inr l)luxkr Nunll t':~hul~lnni %i.llu.l. hiinumm~ ("un~l,u~• I~:m wla.c' I~.ILMtivl t'.suh W'aminp Mctluxl: Ituks Ilaa.l II ^•'."^,^"„^' rlJ,rul o%nt,pa7pn us:Pl.v,ol usnl Ihp 11~ t nptl f 4 ,~ I L I I ..,.I l rvl ul Its. I'n rv l:JevMnl.y IIJA•IIINe/h~cur/fi,,~ 112v 'llll; _i IJb%.JI IlmuwJ:aM%A wpl-\J? hlq'l) II'I< M. (Lcc keJ: U.nc \\'I:I I. I)I :I All N:~,lu• N-~ I~..1\' N.ihlult} I~aiiii~ I:ilil~xl.• I,.iivil~el.~ .~I.,1 I ~ I I ~ I illal% -`I"I.] I <7111_' "11YI:<I ~i M1~JXWr ty ]11"IJ'_`i,I~7N IJL; ^_4:iK.it%N' NA SEC'"rION DETAILS Stc MD Inc Azi T\'D +N--S +E;-W DLrg TFace VSec Target I 2350.00 0.96 127.19 ?349.95 -4.22 8.78 OAU 0.00 -9.74 2 2370.00 152 276.34 2369.94 -4.29 8.65 12A0 IGI.UO ~).6G 3 32>OAO 36.72 276.34 3188.37 27.03 -273.39 4.00 UAU 256.89 4 3830.00 42.55 31 L97 3640.66 179.38 -59,.96 4.00 90.00 G13.SG 5 42UUA0 57.35 31 L97 3878.09 36825 -805.95 4.00 0.00 885.64 6 4>25.(IU 5818 296.63 4051.94 522.37 -1032.21 4.00 -90.00 1156.83 7 -166(1.15 G3.G7 296.07 4117A8 574.80 -1138.08 4.00 -538 1274.96 8 14115.45 63.67 296.07 8311.73 4298.92 -8750.03 11.00 0.00 9748.95 9 1416127 65.50 29GA7 8331.40 4317.11 -878711 4.00 0.00 9790.34 OI-O8 A'1'I Rev 3 10 14270.50 90.(10 296.07 8354.40 4363.66 -8882.36 22.43 0.00 989617 II 14310.38 9315 304.41 8353.27 4383.71 -8916.77 22.43 G8.G3 9936.00 12 1459UA I 93.25 304.41 8337.40 4541.70 -9147.43 O.OU 0.00 10212.86 01-U8 A T2 Rev 3 I ~ I I I FORMATION TOP DETAILS -- - -. . I o. "rVDI'ath MDPath Formation - - - - - - --- - - ~-~ -- --- ' 1 2566.40 2567.91 SV5 2911.40 2928.55 SV4 - - - ~ - - - --... .. - - - - -.. - - '. 3 351 1.40 3658.53 SV3 ._. .- -- -. _ .. - - - - - -- -- _ _-. _. ._ _. ', '• 3701.40 3914.80 SV2 I 5 4124.40 4675,74 SVI ' 4G9G.4p 596522 UG4 _ _ 4881.40 638218 UG3 - - _ _ _ 5516.40 7813.79 UGI - - -- _- - -- -- -- - . - ..- --_ -. ~ ) 607GA0 9076.23 N'SZ -- -_ - _ -- _ _- 10 6301.40 9583.45 WSI _ -- - - - - - ~. '. I1 6539.40 10119.99 CM3 - - - - ~ R 7000.40 I 1172.77 ('M2 I3 7693.40 12721.51 CMI -- _ - _ _ I - I I 14 8076.40 13584.92 THRZ - _ - - i ~ IS 8236.90 13945.62 DHRZ ~ - - - - _ ~ I ~. I G 8331.40 141 G 1.27 Top Put River SS _ _. .. - - - - 17 0.00 o.ou ne I _ _ -- -. -. _. _. _ . I '~. 18 0.00 QUO TSGR - - - -- -- - --i - . - ,. , -- - - ~ -- - . : i .. -- 1 -~-'-- -~- - .- - -- -- - _ I ~ ,I _ \ _- - - - - - - -- - - -- -I - -- - -}- 10(Ip - L..I - i ~ - - .- _ - -_- _. _ -_ _ ~ _ ... - - - - __ - - _ I T I 9 57 _ - ~ S U _.~ - I i I - - - ~ ILS ASINC- a - - - - - -- -- ~ _ _ _ t 1 ~nd Dir ~ 4GG - b.l -' [Jj, 1 - 7.48 II"r ~ -- "I i ~ - - ~ i No. TVD MD N mt Sizr - - . _. _ _ - - _ -- __ i ~ , I i I ~ 1 . _ ~ 0. 0 \ , 7 9 8331.9 14161.00 7" 7.00(1 - -- - - ~ - -- ~ - -- - - - - -- ~ lal ir4/ 00:2 OIIv~D,2 6t 9 'T - ~ ~ \\ ~ .. '. 3 8337.42 14590.00 4 1/2" 4.500 I ~ I ~ ~ ' ~ ', i , I 3 0 3p 1 U. l U TARGET DETAILS ~ St rl Dir l2; lUU': 23-C,U' MD. 3~9.p5'(~jD ~ Na7nr TVD +W-S +E/-W Noshing Fasting Shape 01-08A Fault I 77$7.40 4212.61 -8125.70 $943848A2 690630.00 Polygon OI-08AT1 Rev3 833L40 4317.11 -878711 5943935A2 689966.00 Point ,000 -511) _ ~ - l(I -4000 3000 -_000 -1000 0 West(-).%Eas0+I[100UO:inJ 01-08A Geo Poly 8331.40 3945.03 ~)U93.15 59;3555.02 689670.00 Polygon UI-U8A'1'Z Rev 3 8337.40 4541.7(1 -9147A3 594415QU2 G8960(IAU Point Sperry-Sun BP Planning Report Company: BP Amoco Date: 11/29!2005 Time: 13:32:58 Page: i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True North Site: PB DS 01 Vertical (TVD) Reference: 28.5 + 37.9 66.4 Well: 01-08 -- Section (VS) Reference: Well (O.OON,O.OOE,296.40Azi) Wellpath: Plan 01-08A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 01-08A wp07 Date Composed: 11!3/2005 Version: 42 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 01 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Gronnd Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01-08 Slot Name: 01-08 Well Position: +N/-S -2122.67 ft Northing: 5939851.43 ft Latitude: 70 14 23.027 N +E/-W 1571.02 ft Easting : 698863.54 ft Longitude: 148 23 38.338 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 5536.90 4506.40 9.625 12.250 9 5/8" 14161.00 8331.29 7.000 8.750 7" 14590.00 8337.42 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 2567.51 2566.40 SV5 0.00 0.00 2928.55 2911.40 SV4 0.00 0.00 3658.53 3511.40 SV3 0.00 0.00 3914.80 3701.40 SV2 0.00 0.00 4675.74 4124.40 SV1 0.00 0.00 5965.22 4696.40 UG4 0.00 0.00 6382.28 4881.40 UG3 0.00 0.00 7813.79 5516.40 UG1 0.00 0.00 9076.23 6076.40 WS2 0.00 0.00 9583.45 6301.40 WS1 0.00 0.00 10119.99 6539.40 CM3 0.00 0.00 11172.77 7006.40 CM2 0.00 0.00 12721.51 7693.40 CM1 0.00 0.00 13584.92 8076.40 THRZ 0.00 0.00 13945.62 8236.40 BHRZ 0.00 0.00 14161.27 8331.40 Top Put River SS 0.00 0.00 0.00 LCU 0.00 0.00 0.00 0.00 TJB 0.00 0.00 0.00 0.00 TSGR 0.00 0.00 Targets Map Map <---- Latitude ---> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 01-08A Fauit 1 7757.40 4212.61 -8125.70 5943848.02 690630.00 70 15 4.415 N 148 27 34.665 W -Polygon 1 7757.40 4212.61 -8125.70 5943848.02 690630. 00 70 15 4.415 N 148 27 34.665 W -Polygon 2 7757.40 5151.75 -8002.88 5944790.02 690728. 00 70 15 13.653 N 148 27 31.122 W 01-08A T1 Rev 3 8331.40 4317.11 -8787.21 5943935.02 689966. 00 70 15 5.435 N 148 27 53.908 W ! S err -S n p y u BP Planning Report Company: BP Amoco Date: 11!29/2005 Time: 13:32:58 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True North Site: PB DS 01 Vertical (TVD) Reference: 28.5 + 37.9 66.4 Well: 01-08 Section (VS) Reference: Well (O.OON,O.OOE,296.40Azi) Wellpath: Plan 01-08A Survey Calculation Method: Minimum Curvature Db: Oracle. Targets Name Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Map Northing ft Map Easting ft <-- Latitude ---> Deg Min Sec <--- Longitude --> Deg Min Sec 01-08A Geo Poly 8331 .40 3945.03 -9093.15 5943555.02 689670.00 70 15 1.772 N 148 28 2.793 W -Polygon 1 8331 .40 3945.03 -9093.15 5943555.02 689670.00 70 15 1.772 N 148 28 2.793 W -Polygon 2 8331 .40 3945.24 -8342.84 5943575.02 690420.00 70 15 1.783 N 148 27 40.972 W -Polygon 3 8331 .40 4745.79 -8351.73 5944375.02 690390.00 70 15 9.656 N 148 27 41.256 W -Polygon 4 8331 .40 4740.97 -8927.09 5944355.02 689815.00 70 15 9.602 N 148 27 57.991 W -Polygon 5 8331 .40 4513.03 -9198.21 5944120.02 689550.00 70 15 7.357 N 148 28 5.869 W 01-08A T2 Rev 3 8337 .40 4541.70 -9147.43 5944150.02 689600.00 70 15 7.640 N 148 28 4.393 W Plan Section Information MD ft Inc! deg Azim deg TVD ft +N/-S ft +E/-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft TFO Target deg 2350.00 0.96 127 .19 2349.95 -4.22 8.78 0.00 0.00 0.00 0.00 2370.00 1.52 276 .34 2369.94 -4.29 8.65 12.00 2.81 745.73 161.00 3250.00 36.72 276 .34 3188.37 27.03 -273.39 4.00 4.00 0.00 0.00 3830.00 42.55 311 .97 3640.66 179.38 -595.96 4.00 1.00 6.14 90.00 4200.00 57.35 311 .97 3878.09 368.25 -805.95 4.00 4.00 0.00 0.00 4525.00 58.28 296 .63 4051.94 522.37 -1032.21 4.00 0.29 -4.72 -90.00 4660.15 63.67 296 .07 4117.48 574.80 -1138.08 4.00 3.98 -0.42 -5.38 14115.45 63.67 296 .07 8311.73 4298.92 -8750.03 0.00 0.00 0.00 0.00 14161.27 65.50 296 .07 8331.40 4317.11 -8787.21 4.00 4.00 0.00 0.00 01-08A T1 Rev 3 14270.50 90.00 296 .07 8354.40 4363.66 -8882.36 22.43 22.43 0.00 0.00 14310.38 93.25 304 .41 8353.27 4383.71 -8916.77 22.43 8.15 20.91 68.63 14590.41 93.25 304. 41 8337.40 4541.70 -9147.43 0.00 0.00 0.00 0.00 01-08A T2 Rev 3 Survey MD Inc! Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft ft deg/100ft ft ft 0.00 0.00 0.00 0.00 -66.40 0.00 0. 00 0.00 0.00 5939851.43 698863.54 TSGR 2350.00 0.96 127.19 2349.95 2283.55 -9.74 -4. 22 8.78 0.04 5939847.45 698872.43 Start Dir 12!10 2370.00 1.52 276.34 2369.94 2303.54 -9.66 -4 .29 8.65 12.00 5939847.37 698872.30 Start Dir 4/100 2400.00 2.72 276.34 2399.92 2333.52 -8.61 -4 .17 7.55 4.00 5939847.46 698871.20 MWD+IFR+MS 2500.00 6.72 276.34 2499.56 2433.16 -0.88 -3 .26 -0.63 4.00 5939848.16 698862.99 MWD+IFR+MS 2567.51 9.42 276.34 2566.40 2500.00 8.02 -2 .21 -10.06 4.00 5939848.95 698853.55 SV5 2600.00 10.72 276.34 2598.39 2531.99 13.36 -1 .59 -15.70 4.00 5939849.43 698847.88 MWD+IFR+MS 2700.00 14.72 276.34 2695.91 2629.51 34.04 0. 84 -37.59 4.00 5939851.28 698825.94 MWD+IFR+MS 2800.00 18.72 276.34 2791.66 2725.26 61.07 4. 02 -66.18 4.00 5939853.70 698797.28 MWD+IFR+MS 2900.00 22.72 276.34 2885.17 2818.77 94.30 7. 92 -101.35 4.00 5939856.68 698762.03 MWD+IFR+MS 2928.55 23.87 276.34 2911.40 2845.00 104.90 9. 17 -112.57 4.00 5939857.63 698750.77 SV4 3000.00 26.72 276.34 2975.99 2909.59 133.57 12. 54 -142.91 4.00 5939860.19 698720.36 MWD+IFR+MS 3100.00 30.72 276.34 3063.67 2997.27 178.70 17. 84 -190.66 4.00 5939864.23 698672.49 MWD+IFR+MS 3200.00 34.72 276.34 3147.78 3081.38 229.47 23. 80 -244.38 4.00 5939868.78 698618.63 MWD+IFR+MS 3250.00 36.72 276.34 3188.37 3121.97 256.89 27. 03 -273.39 4.00 5939871.23 698589.55 MWD+IFR+MS 3300.00 36.77 279.68 3228.44 3162.04 285.27 31. 19 -303.00 4.00 5939874.62 698559.84 MWD+IFR+MS 3400.00 37.14 286.31 3308.38 3241.98 343.67 44. 71 -361.51 4.00 5939886.58 698501.00 MWD+IFR+MS 3500.00 37.87 292.77 3387.74 3321.34 404.06 65. 07 -418.81 4.00 5939905.42 698443.18 MWD+IFR+MS 3600.00 38.95 298.97 3466.12 3399.72 466.11 92. 18 -474.64 4.00 5939931.05 698386.66 MWD+IFR+MS 3658.53 39.72 302.46 3511.40 3445.00 503.10 111. 13 -506.52 4.00 5939949.16 698354.29 SV3 3700.00 40.33 304.85 3543.15 3476.75 529.55 125. 91 -528.71 4.00 5939963.35 698331.72 MWD+IFR+MS 3800.00 42.00 310.38 3618.46 3552.06 594.05 166. 10 -580.77 4.00 5940002.14 698278.62 MWD+IFR+MS 3830.00 42.55 311.97 3640.66 3574.26 613.56 179. 38 -595.96 4.00 5940015.02 698263.09 MWD+IFR+MS 3900.00 45.35 311.97 3691.05 3624.65 660.35 211. 87 -632.08 4.00 5940046.54 698226.13 MWD+IFR+MS 3914.80 45.94 311.97 3701.40 3635.00 670.55 218. 95 -639.95 4.00 5940053.41 698218.08 SV2 4000.00 49.35 311.97 3758.79 3692.39 731.19 261. 04 -686.75 4.00 5940094.25 698170.18 MWD+IFR+MS 4100.00 53.35 311.97 3821.24 3754.84 806.41 313. 25 -744.80 4.00 5940144.91 698110.78 MWD+IFR+MS • S rr - n pe y Su BP Planning Report Company: BP Amoco Date: 11/29/2005 Time: 13:32:58 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True North Site: PB DS 01 Vertical (TVD) Reference: 28.5 + 37.9 66.4 Well: 01-08 Section (VS) Reference: Well (O.OON,O.OOE,296.40Azi) Wellpath: Plan 01-08A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Iucl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 4200.00 57.35 311.97 3878.09 3811.69 885.64 368.25 -805.95 4.00 5940198.27 698048.20 MWD+IFR+MS 4300.00 57.44 307.22 3932.00 3865.60 967.62 421.91 -870.84 4.00 5940250.20 697981.93 MWD+IFR+MS 4400.00 57.70 302.49 3985.64 3919.24 1051.07 470.13 -940.07 4.00 5940296.57 697911.45 MWD+IFR+MS 4500.00 58.15 297.80 4038.77 3972.37 1135.59 512.66 -1013.32 4.00 5940337.15 697837.11 MWD+IFR+MS 4525.00 58.28 296.63 4051.94 3985.54 1156.83 522.37 -1032.21 4.00 5940346.37 697817.96 MWD+IFR+MS 4600.00 61.27 296.31 4089.69 4023.29 1221.63 551.26 -1090.22 4.00 5940373.71 697759.22 MWD+IFR+MS 4660.15 63.67 296.07 4117.48 4051.08 1274.96 574.80 -1138.08 4.00 5940395.98 697710.76 End Dir :4660 4675.74 63.67 296.07 4124.40 4058.00 1288.93 580.94 -1150.63 0.00 5940401.78 697698.05 SV1 4700.00 63.67 296.07 4135.16 4068.76 1310.68 590.49 -1170.16 0.00 5940410.82 697678.28 MWD+IFR+MS 4800.00 63.67 296.07 4179.52 4113.12 1400.30 629.88 -1250.66 0.00 5940448.07 697596.77 MWD+IFR+MS 4900.00 63.67 296.07 4223.88 4157.48 1489.92 669.27 -1331.17 0.00 5940485.32 697515.25 MWD+IFR+MS 5000.00 63.67 296.07 4268.24 4201.84 1579.55 708.65 -1411.67 0.00 5940522.56 697433.74 MWD+IFR+MS 5100.00 63.67 296.07 4312.60 4246.20 1669.17 748.04 -1492.18 0.00 5940559.81 .697352.23 MWD+IFR+MS 5200.00 63.67 296.07 4356.96 4290.56 1758.79 787.43 -1572.68 0.00 5940597.06 697270.72 MWD+IFR+MS 5300.00 63.67 296.07 4401.32 4334.92 1848.41 826.81 -1653.19 0.00 5940634.30 697189.21 MWD+IFR+MS 5400.00 63.67 296.07 4445.67 4379.27 1938.03 866.20 -1733.69 0.00 5940671.55 697107.70 MWD+IFR+MS 5500.00 63.67 296.07 4490.03 4423.63 2027.65 905.59 -1814.20 0.00 5940708.80 ' 697026.19 MWD+IFR+MS 5536.90 63.67 296.07 4506.40 4440.00 2060.72 920.12 -1843.90 0.00 5940722.54 696996.11 9 5/8" 5600.00 63.67 296.07 4534.39 4467.99 2117.27 944.97 -1894.70 0.00 5940746.05 696944.68 MWD+IFR+MS 5700.00 63.67 296.07 4578.75 4512.35 2206.90 984.36 -1975.21 0.00 5940783.29 696863.17 MWD+IFR+MS 5800.00 63.67 296.07 4623.11 4556.71 2296.52 1023.75 -2055.71 0.00 5940820.54 696781.65 MWD+IFR+MS 5900.00 63.67 296.07 4667.47 4601.07 2386.14 1063.13 -2136.22 0.00 5940857.79 696700.14 MWD+IFR+MS 5965.22 63.67 296.07 4696.40 4630.00 2444.59 1088.82 -2188.72 0.00 5940882.08 696646.98 UG4 6000.00 63.67 296.07 4711.83 4645.43 2475.76 1102.52 -2216.72 0.00 5940895.04 696618.63 MWD+IFR+MS 6100.00 63.67 296.07 4756.18 4689.78 2565.38 1141.91 -2297.22 0.00 5940932.28 696537.12 MWD+IFR+MS 6200.00 63.67 296.07 4800.54 4734.14 2655.00 1181.29 -2377.73 0.00 5940969.53 696455.61 MWD+IFR+MS 6300.00 63.67 296.07 4844.90 4778.50 2744.63 1220.68 -2458.23 0.00 5941006.78 696374.10 MWD+IFR+MS 6382.28 63.67 296.07 4881.40 4815.00 2818.37 1253.09 -2524.47 0.00 5941037.42 696307.03 UG3 6400.00 63.67 296.07 4889.26 4822.86 2834.25 1260.07 -2538.74 0.00 5941044.03 696292.59 MWD+IFR+MS 6500.00 63.67 296.07 4933.62 4867.22 2923.87 1299.45 -2619.24 0.00 5941081.27 696211.08 MWD+IFR+MS 6600.00 63.67 296.07 4977.98 4911.58 3013.49 1338.84 -2699.75 0.00 5941118.52 696129.57 MWD+IFR+MS 6700.00 63.67 296.07 5022.34 4955.94 3103.11 1378.23 -2780.25 0.00 5941155.77 696048.06 MWD+IFR+MS 6800.00 63.67 296.07 5066.70 5000.30 3192.73 1417.61 -2860.76 0.00 5941193.01 695966.54 MWD+IFR+MS 6900.00 63.67 296.07 5111.05 5044.65 3282.36 1457.00 -2941.26 0.00 5941230.26 695885.03 MWD+IFR+MS 7000.00 63.67 296.07 5155.41 5089.01 3371.98 1496.39 -3021.77 0.00 5941267.51 695803.52 MWD+IFR+MS 7100.00 63.67 296.07 5199.77 5133.37 3461.60 1535.77 -3102.27 0.00 5941304.76 695722.01 MWD+IFR+MS 7200.00 63.67 296.07 5244.13 5177.73 3551.22 1575.16 -3182.78 0.00 5941342.00 695640.50 MWD+IFR+MS 7300.00 63.67 296.07 5288.49 5222.09 3640.84 1614.55 -3263.28 0.00 5941379.25 695558.99 MWD+IFR+MS 7400.00 63.67 296.07 5332.85 5266.45 3730.46 1653.93 -3343.79 0.00 5941416.50 695477.48 MWD+IFR+MS 7500.00 63.67 296.07 5377.21 5310.81 3820.09 1693.32 -3424.29 0.00 5941453.75 695395:97 MWD+IFR+MS 7600.00 63.67 296.07 5421.57 5355.17 3909.71 1732.71 -3504.79 0.00 5941490.99 695314.46 MWD+IFR+MS 7700.00 63.67 296.07 5465.92 5399.52 3999.33 1772.09 -3585.30 0.00 5941528.24 695232.94 MWD+IFR+MS 7800.00 63.67 296.07 5510.28 5443.88 4088.95 1811.48 -3665.80 0.00 5941565.49 695151.43 MWD+IFR+MS 7813.79 63.67 296.07 5516.40 5450.00 4101.31 1816.91 -3676.91 0.00 5941570.62 695140.19 UG1 7900.00 63.67 296.07 5554.64 5488.24 4178.57 1850.87 -3746.31 0.00 5941602.73 695069.92 MWD+IFR+MS 8000.00 63.67 296.07 5599.00 5532.60 4268.19 1890.25 -3826.81 0.00 5941639.98 694988.41 MWD+IFR+MS 8100.00 63.67 296.07 5643.36 5576.96 4357.82 1929.64 -3907.32 0.00 5941677.23 694906.90 MWD+IFR+MS 8200.00 63.67 296.07 5687.72 5621.32 4447.44 1969.02 -3987.82 0.00 5941714.48 694825.39 MWD+IFR+MS 8300.00 63.67 296.07 5732.08 5665.68 4537.06 2008.41 -4068.33 0.00 5941751.72 694743.88 MWD+IFR+MS 8400.00 63.67 296.07 5776.44 5710.04 4626.68 2047.80 -4148.83 0.00 5941788.97 694662.37 MWD+IFR+MS 8500.00 63.67 296.07 5820.79 5754.39 4716.30 2087.18 -4229.34 0.00 5941826.22 694580.86 MWD+IFR+MS 8600.00 63.67 296.07 5865.15 5798.75 4805.92 2126.57 -4309.84 0.00 5941863.47 694499.34 MWD+IFR+MS 8700.00 63.67 296.07 5909.51 5843.11 4895.54 2165.96 -4390.35 0.00 5941900.71 694417.83 MWD+IFR+MS S err -Sun • P Y BP Planning Report Company: BP Amoco Date: 11/29/2005 Time: 13:32:58 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True North Site: PB DS 01 Vertical (TVD) Reference: 28.5 + 37.9 66.4 Well: 01-08 Section (VS) Referen ce: Well (O.OON,O. OOE,296.40Azi) Wellpath: Plan 01-08A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft Incl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DLS deg/100ft MapN ft MapE ft TooUComme t 8800.00 63.67 296 .07 5953. 87 5887 .47 4985.17 2205.34 -4470.85 0.00 5941937.96 694336.32 MWD+IFR+MS 8900.00 63.67 296 .07 5998. 23 5931 .83 5074.79 2244.73 -4551.36 0.00 5941975.21 694254.81 MWD+IFR+MS 9000.00 63.67 296 .07 6042. 59 5976 .19 5164.41 2284.12 -4631.86 0.00 5942012.45 694173.30 MWD+IFR+MS 9076.23 63.67 296 .07 6076. 40 6010 .00 5232.72 2314.14 -4693.23 0.00 5942040.85 694111.17 WS2 9100.00 63.67 296 .07 6086. 95 6020 .55 5254.03 2323.50 -4712.36 0.00 5942049.70 694091.79 MWD+IFR+MS 9200.00 63.67 296 .07 6131. 30 6064 .90 5343.65 2362.89 -4792.87 0.00 5942086.95 694010.28 MWD+IFR+MS 9300.00 63.67 296 .07 6175. 66 6109 .26 5433.27 2402.28 -4873.37 0.00 5942124.20 693928.77 MWD+IFR+MS 9400.00 63.67 296 .07 6220. 02 6153 .62 5522.90 2441.66 -4953.88 0.00 5942161.44 693847.26 MWD+IFR+MS 9500.00 63.67 296 .07 6264. 38 6197 .98 5612.52 2481.05 -5034.38 0.00 5942198.69 693765.74 MWD+IFR+MS 9583.45 63.67 296 .07 6301. 40 6235 .00 5687.31 2513.92 -5101.57 0.00 5942229.78 693697.72 WS1 9600.00 63.67 296 .07 6308. 74 6242 .34 5702.14 2520.44 -5114.89 0.00 5942235.94 693684.23 MWD+IFR+MS 9700.00 63.67 296 .07 6353. 10 6286 .70 5791.76 2559.82 -5195.39 0.00 5942273.19 693602.72 MWD+IFR+MS 9800.00 63.67 296 .07 6397. 46 6331 .06 5881.38 2599.21 -5275.90 0.00 5942310.43 693521.21 MWD+IFR+MS 9900.00 63.67 296 .07 6441. 82 6375 .42 5971.00 2638.60 -5356.40 0.00 5942347.68 693439.70 MWD+IFR+MS 10000.00 63.67 296 .07 6486. 17 6419 .77 6060.63 2677.98 -5436.91 0.00 5942384.93 693358.19 MWD+IFR+MS 10100.00 63.67 296. 07 6530. 53 6464 .13 6150.25 2717.37 -5517.41 0.00 5942422.18 ' 693276.68 MWD+IFR+MS 10119.99 63.67 296. 07 6539. 40 6473 .00 6168.16 2725.24 -5533.50 0.00 5942429.62 693260.38 CM3 10200.00 63.67 296. 07 6574. 89 6508 .49 6239.87 2756.76 -5597.92 0.00 5942459.42 693195.17 MWD+IFR+MS 10300.00 63.67 296. 07 6619. 25 6552 .85 6329.49 2796.14 -5678.42 0.00 5942496.67 693113.66 MWD+IFR+MS 10400.00 63.67 296. 07 6663. 61 6597 .21 6419.11 2835.53 -5758.93 0.00 5942533.92 693032.14 MWD+IFR+MS 10500.00 63.67 296. 07 6707. 97 6641 .57 6508.73 2874.92 -5839.43 0.00 5942571.16 692950.63 MWD+IFR+MS 10600.00 63.67 296. 07 6752. 33 6685 .93 6598.36 2914.30 -5919.93 0.00 5942608.41 692869.12 MWD+IFR+MS 10700.00 63.67 296. 07 6796. 69 6730 .29 6687.98 2953.69 -6000.44 0.00 5942645.66 692787.61 MWD+IFR+MS 10800.00 63.67 296. 07 6841. 04 6774 .64 6777.60 2993.08 -6080.94 0.00 5942682.91 692706.10 MWD+IFR+MS 10900.00 63.67 296. 07 6885. 40 6819 .00 6867.22 3032.46 -6161.45 0.00 5942720.15 692624.59 MWD+IFR+MS 11000.00 63.67 296. 07 6929. 76 6863. 36 6956.84 3071.85 -6241.95 0.00 5942757.40 692543.08 MWD+IFR+MS 11100.00 63.67 296. 07 6974. 12 6907. 72 7046.46 3111.24 -6322.46 0.00 5942794.65 692461.57 MWD+IFR+MS 11172.77 63.67 296. 07 7006. 40 6940. 00 7111.68 3139.90 -6381.04 0.00 5942821.75 692402.25 CM2 11200.00 63.67 296. 07 7018. 48 6952 .08 7136.08 3150.62 -6402.96 0.00 5942831.90 692380.06 MWD+IFR+MS 11300.00 63.67 296. 07 7062. 84 6996 .44 7225.71 3190.01 -6483.47 0.00 5942869.14 692298.54 MWD+IFR+MS 11400.00 63.67 296. 07 7107. 20 7040 .80 7315.33 3229.40 -6563.97 0.00 5942906.39 692217.03 MWD+IFR+MS 11500.00 63.67 296. 07 7151. 55 7085 .15 7404.95 3268.78 -6644.48 0.00 5942943.64 692135.52 MWD+IFR+MS 11600.00 63.67 296. 07 7195. 91 7129 .51 7494.57 3308.17 -6724.98 0.00 5942980.88 692054.01 MWD+IFR+MS 11700.00 63.67 296. 07 7240. 27 7173 .87 7584.19 3347.56 -6805.49 0.00 5943018.13 691972.50 MWD+IFR+MS 11800.00 63.67 296. 07 7284. 63 7218 .23 7673.81 3386.94 -6885.99 0.00 5943055.38 691890.99 MWD+IFR+MS 11900.00 63.67 296. 07 7328. 99 7262 .59 7763.44 3426.33 -6966.50 0.00 5943092.63 691809.48 MWD+IFR+MS 12000.00 63.67 296. 07 7373. 35 7306. 95 7853.06 3465.72 -7047.00 0.00 5943129.87 691727.97 MWD+IFR+MS 12100.00 63.67 296. 07 7417. 71 7351. 31 7942.68 3505.10 -7127.50 0.00 5943167.12 691646.46 MWD+IFR+MS 12200.00 63.67 296. 07 7462. 07 7395. 67 8032.30 3544.49 -7208.01 0.00 5943204.37 691564.94 MWD+IFR+MS 12300.00 63.67 296. 07 7506. 42 7440. 02 8121.92 3583.88 -7288.51 0.00 5943241.62 691483.43 MWD+IFR+MS 12400.00 63.67 296. 07 7550. 78 7484. 38 8211.54 3623.26 -7369.02 0.00 5943278.86 691401.92 MWD+IFR+MS 12500.00 63.67 296. 07 7595. 14 7528. 74 8301.17 3662.65 -7449.52 0.00 5943316.11 691320.41 MWD+IFR+MS 12600.00 63.67 296. 07 7639. 50 7573. 10 8390.79 3702.04 -7530.03 0.00 5943353.36 691238.90 MWD+IFR+MS 12700.00 63.67 296. 07 7683. 86 7617. 46 8480.41 3741.42 -7610.53 0.00 5943390.60 691157.39 MWD+IFR+MS 12721.51 63.67 296. 07 7693. 40 7627. 00 8499.68 3749.89 -7627.85 0.00 5943398.62 691139.86 CM1 12800.00 63.67 296. 07 7728. 22 7661. 82 8570.03 3780.81 -7691.04 0.00 5943427.85 691075.88 MWD+IFR+MS 12865.79 63.67 296. 07 7757. 40 7691. 00 8628.99 3806.72 -7744.00 0.00 5943452.36 691022.26 01-08A Fault 1 12900.00 63.67 296. 07 7772. 58 7706. 18 8659.65 3820.19 -7771.54 0.00 5943465.10 690994.37 MWD+IFR+MS 13000.00 63.67 296. 07 7816. 94 7750. 54 8749.27 3859.58 -7852.05 0.00 5943502.35 690912.86 MWD+IFR+MS 13100.00 63.67 296. 07 7861. 29 7794. 89 8838.90 3898.97 -7932.55 0.00 5943539.59 690831.34 MWD+IFR+MS 13200.00 63.67 296. 07 7905. 65 7839. 25 8928.52 3938.35 -8013.06 0.00 5943576.84 690749.83 MWD+IFR+MS 13300.00 63.67 296. 07 7950. 01 7883. 61 9018.14 3977.74 -8093.56 0.00 5943614.09 690668.32 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: 11/29/2005 Time: 13:32:58 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-08, True Nordl Site: PB DS 01 Vertical (TVD) Reference: 28.5 + 37.9 66.4 Well: 01-08 Section (VS) Reference: Well (O.OON,O.OOE,296.40Azi) Wellpath: Plan 01-08A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 13400. 00 63 .67 296. 07 7994.37 7927 .97 9107.76 4017.13 -8174. 07 0.00 5943651.34 690586.81 MWD+IFR+MS 13500. 00 63 .67 296. 07 8038.73 7972 .33 9197.38 4056.51 -8254. 57 0.00 5943688. 58 690505.30 MWD+IFR+MS 13584. 92 63 .67 296. 07 8076.40 8010 .00 9273.49 4089.96 -8322. 94 0.00 5943720. 21 690436.08 THRZ 13600. 00 63 .67 296. 07 8083.09 8016 .69 9287.00 4095.90 -8335. 07 0.00 5943725. 83 690423.79 MWD+IFR+MS 13700. 00 63 .67 296. 07 8127.45 8061 .05 9376.62 4135.29 -8415. 58 0.00 5943763. 08 690342.28 MWD+IFR+MS 13800. 00 63 .67 296. 07 8171.81 8105 .41 9466.25 4174.67 -8496. 08 0.00 5943800. 32 690260.77 MWD+IFR+MS 13900. 00 63 .67 296. 07 8216.16 8149 .76 9555.87 4214.06 -8576. 59 0.00 5943837. 57 690179.26 MWD+IFR+MS 13945. 62 63 .67 296. 07 8236.40 8170 .00 9596.75 4232.03 -8613. 31 0.00 5943854. 56 690142.07 BHRZ 14000. 00 63 .67 296. 07 8260.52 8194 .12 9645.49 4253.45 -8657. 09 0.00 5943874. 82 690097.74 MWD+IFR+MS 14100. 00 63 .67 296. 07 8304.88 8238 .48 9735.11 4292.83 -8737. 60 0.00 5943912. 07 690016.23 MWD+IFR+MS 14115.45 63 .67 296. 07 8311.73 8245 .33 9748.95 4298.92 -8750. 03 0.00 5943917. 82 690003.64 Start Dir 4/100 14161. 00 65 .49 296. 07 8331.29 8264 .89 9790.09 4317.00 -8786. 99 4.00 5943934. 92 689966.23 7" 14161. 27 65 .50 296. 07 8331.40 8265 .00 9790.34 4317.11 -8787. 21 4.00 5943935. 02 .689966.00 01-O8A T1 Rev 14200. 00 74 .19 296. 07 8344.73 8278 .33 9826.66 4333.07 -8819. 84 22.43 5943950. 12 689932.97 MWD+IFR+MS 14270. 50 90 .00 296. 07 8354.40 8288 .00 9896.27 4363.66 -8882. 36 22.43 5943979. 05 689869.66 MWD+IFR+MS 14300. 00 92 .41 302. 24 8353.78 8287 .38 9925.71 4378.02 -8908. 11 22.43 5943992. 72 689843.55 MWD+IFR+MS 14310. 38 93 .25 304. 41 8353.27 8286 .87 9936.00 4383.71 -8916. 77 22.43 5943998. 18 '689834.74 End Dir :1431 14400. 00 93 .25 304. 41 8348.19 8281 .79 1.OOe04 4434.27 -8990. 59 0.00 5944046. 78 689759.61 MWD+IFR+MS 14500. 00 93 .25 304. 41 8342.52 8276 .12 1.01e04 4490.69 -9072. 96 0.00 5944101. 00 689675.79 MWD+IFR+MS 14590. 00 93 .25 304. 41 8337.42 8271 .02 1.02e04 4541.47 -9147. 09 0.00 5944149. 80 689600.35 41/2" 14590. 41 93 .25 304. 41 8337.40 8271 .00 1.02e04 4541.70 -9147. 43 0.00 5944150. 02 689600.00 01-08A T2 Rev 33 - ",~,. N 1 14 N 13 w THIS ST1 SURVEY ~ ~ O Z IXtILL 97E Q ~ a ~ 12 N - - . 11 II 'I i 18 I J~ •F ,~ ,~ 0 w ~x OF °°°°°° '9 ~ °°°°° °° P °° I ~ °49 ~ ~ °°o ~ I % °°°°°°°°°°°°°°°°°°°°°°°°°°°°° °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° - ~ ~ ~ ° ° ~~, ~° Richard F. Allison ~~° ,~ ' 10608 °° °°°° \ SSIONA~ I SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT I THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE ~ CORRECT AS OF NOVEMBER 14, 2005. -- DRT~ TITS 1 'I NOTES: EL GEND i. DATE OF SURVEY: NOVEMBER 14, 2005. 2. REFERENCE FIELD BOOK: PB05-06 PG's 71-75 AS-BUILT WELL AND PB05-07 PG's 57-59. ^ EXISTING WELL 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. DRILL SITE 1 AVERAGE SCALE FACTOR IS: 0.9999443. 6. HORIZONTAL CONTROL IS BASED ON DS-1 OPERATOR MONUMENTS. 7. VERTICAL CONTROL IS BASED DS-1 TBM's. ELEVATIONS ARE ARCO MLLW SEA LEVEL DATUM. 8. TOP OF BASE FLANGE ELEVATION IS 38.33. t OCATFn W1THiN PRnTRACTFn SFG OfR_ T 101 N__ R 15 F . IIMTAT MFRT~TAN_ AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC APPROX. SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) GND. ELEV. OFFSETS 1-08 Y=5,939,851.43 N=-2,377.24 70'14'23.027" 70.2397297' 37 9 4204' FSL ' X= 698,863.54 E= 1150.02 148'23'38.338" 148.3939828' ' FEL 3758 i•. iw u ci~ KWH ~ CHECKED: ~ `r' ` SPM DATE: N O J ~ a T 11/14/05 II I~ ll~l(J DRAWING: FRB05 DS1 01-01 SHEET: MoD No, EOA DRILL SITE 1 1 11 21 05 CORRECT E SECTION OFFSET SPM K`Mi ~ ~~~0~ ® o AS-BUILT WELL LOCATION 0 11 14 05 ISSUED FOR INFORMATION KNH SPM SCALE: WELL 1-08 1 OF 1 N0. DATE REVISION BY CHK 1' = ze0' • • Casing /Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size and / tvd and / tvd 12-1/4" 9-5l8" 40 L-80 BTC-M 5,537' Surface 5,537' / 4,506' 9-5/8 7" Tieback 26.0# L-80 BTC-M 5,387' Surface 5,387' / 4,440' CSG 8-3/4" 7" 26.0# L-80 BTC-M 8,774' 5,387' / 4,440' 14,161' / 8,331' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 530' 14,061'/ 8,288' 14,590'/ 8,337' Tubin 4-1/2" 12.6# L-80 IBT-M 14,061' Surface 14,061'/ 8,288' Cementing Program Casin String: 9-5/8", 40#, L-80, BTC-M 9-5/8" Lead slurry: 2,350' of 13-3/8" x 9-5/8" annulus, plus 2,187' of 12-1/4 x 9-5/8" annulus with 40% excess Slurry Design Basis: Tail slurry: 1,000' of 12-1/4" x 9-5/8" annulus with 40% excess, plus 80' of 9- 5/8" 40# shoe track. Pre-Flush None Planned S acer 80bbls MudPUSH II a Fluids Sequence /Volume: i„y Lead Slur 307bb1s / 1,723 ft / ArcticSet Lite 3 (with freeze s /sk. protect), 10.7pp Tail Slur 84bbls / 469 ft / 0 sx Class `G', 15.8p ; 1.16gft /sk. BHST: 92° Cement will be mixed on the fly BHCT: 79° Casing String: 7", 26#, L-80, BTC-M Intermediate Liner 1S Sta e Slurry Design Basis: Lead slurry: 3,191' of 8-3/4" x 7" annulus with 40% excess. Tail slurry: 750' of 8-3/4" x 7" annulus with 40% excess, plus 100' of 7", 26# shoe track Pre-Flush None Planned S acer 20bbls MudPUSH IJ~f 10.9 !1 Fluids Sequence /Volume: Lead Slur 120bb1s / 671 ft / ~~;;'sx Lite Crete, 11.0 g; 3: ~ /sk. Tail Slur 60bbls / 337 ft / 9 sx Class `G', 15.8 .1 ft /sk. BHST: 180° Cement will be mixed on the fly BHCT: 119° Casing String: 7", 26#, L-80, BTC-M Intermediate Liner (2" Sta e Slurry Design Basis: Lead slurry: None Planned. Tail slurry: 4,683' of 8-3/4" x 7" annulus with 30% excess, plus 150' of 9-5/8" X 7" liner fa lus 200' of 9-5/8" X 5" drill i e annulus. Pre-Flush 10bbls CW 100 Spacer 20bbls MudPUSH Il at 11.5p Fluids Sequence /Volume: Lead Slurr None planned ,,~., ~~~~ Tail Slur 178bb1s / 995 ft /,-513 sx Crete, 12.5pp ; ~.g4~ft /sk. BHST: 135° Cement will be mixed on the fly BHCT: 100° 01-08A Permit to Drill • • Casin String: 7", 26#, L-80, BTC-M Tieback Slurry Design Basis: Lead slurry: None Planned. Tail slur :1,000' of 9-5/8" x 7" annulus, lus 40' of 7" 26# shoe track Pre-Flush None Planned S acer 15bbls MudPUSH II at 11.8 Fluids Sequence /Volume: Lead Slurr None tanned Tail Slurr 30bbls / 168 ft / 145 sx Class `G', 15.8p ; 1.16 ft /sk. BHST: 90° Cement will be mixed on the fly BHCT: 79° Casing String: 4-1/2", 12.6#, L-80, IBT-M solid roduction liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 429' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 100' of 4- 1/2", 12.6# shoe track, plus 100' of 7" X 4-1/2" liner lap, plus 200 of 7" X 4" drill i e annulus. Pre-Flush 10bbls CW 100 S acer 10bbls MudPUSH II at 10.5 Fluids Sequence /Volume: Lead Slurr None tanned Tail Slur 18bbls / 101 ft / 87 sx Class 'G', 15.8 ; 1.16 ft /sk. BHST: 180° Cement will be batch mixed before pumping BHCT: 119° Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 13-3l8" Casin to surface Bride lug to surface 30 min recorded 3,000 si 13-3/8" Casin window 20' be and middle of window FIT 10.8 EMW 9-5/8" Casin to surface Landin collar to surface 30 min recorded 3,500 si surface 9-5/8" Casin shoe 20' be and middle of window FIT 11.5 EMW 7" Casin to surface Liner Landin collar to surface 30 min recorded 4,000 si surface 7" shoe 20' be and shoe FIT 10.3 EMW 4-1/2 liner to surface Liner Landing collar to surface 30 min recorded 4,000psi surface 01-08A Permit to Drill * • 01-08A P ro posed Completion 20"CSG, 94#, H-40, ~ 100' - ~~' ~ '2,200' HES 4-1/2" X Nipple ID = 3.813" ` 2350' -Top of Whipstock ~/ 7", 26#, L-80, BTC-M Tieback • 4-12", 12.6#, L-80, IBT-M TBG TREE WEiLHEAD = FML' ACTUATC'R= AXELSGN h'B. ELEV = BF. EL2/ _ KOP= Max A ng le = Daiu m MD = Data m TVD = `="~ GAS LIFT MANDRELS ST MD ND DEV T(PE VLV LATCH PUR.T DATE 1 2 TBD TBD TBD TBD 13-3/8" HES EZSV -2370' Mechanica I Cut - -2390' 2402' & 2628' - 9-5/8" FO Cementers CMT between FO Cementers 13-3/8" CSG, 72#, _ _2674' L-80, MN-80 9-5/8" HES CIBP - 2500' Jet Cut - 2950' 5-1/2" TBG-NPC, 17#, L-80 ~ -4537' - TOC -5537' - 7" Seal assy / -5387' -BKR HGR &LTP w/TB sleaee / -5537' - 9-5/8", 40#, L-80, BTC-M -10220' - T' HES EZ CMTR r -14,080' HES 4-1/7' X Nipple ID = 3.813" -14,000 BKR 7" x 41/2" BKR PKR -14,020' HES 4-1/2" X Nipple ID =3.813" -14,040' HES 4-1/2" XN Nipple ID =3.725" -14,061' 41/2" WLEG -14061' -BKR HGR & LTP w/TB sleave ~ , -14161' - T', 26#, L-80, BTC-M -14490' - PBTD " / -14590' - 41/2", 12.6#, L-80, IBT-M 113 19' - 0-1: XA SLUI~: -V ID .30i' '1320' -Top of Cement P&A Plug 114 47' i'0-1.'•XN VIF. ID-'.10:' 11864' a-' -c:ii •n1 F3ur 114 Bf' '-g ~• %s-1/:~ zn~crl: ::n r. :<1=, m - ~ Ts f tans' ~- x ~~tra xn 1 16 1-' - I: :; I ::n a 11594' T,.r h!? - 116:1' t-1._ 1 LJ`-... s ~ , 4n nl ~ ~ 11960'-9-5/8"CSG, 47#, MN-80/SOO-95 loa la' H m' u~- ~cxi JN r:e :•=~•:~ I i.z :RY,.ne.-0?..,-T1-pl,m-c nt• lasso' ~ T- 18560' DATE REV F31' COMNENT5 DATE REV B`( L`UNMENTS 072285 [ift1~31NAL CGMPLErIGN 09CZ2/05 KSB/TLH TTPSET(05/05l0~/ 0523197 LAST WDRKGVER 11/14!05 IMIA Proposrd Complrtion U215/01 TP CORRECIIUNS 0605813 CIvh7/TLP MAnANGLE 0817,03 CP7kl/TLP DATUMt`~D CURRECTION 11 29k14 DFR/TLP 20" CSO, CORRECT9.5/8" CSG PRUDHOE 6A'(UNIT WELL 01-08A PERMIT No: API No: 50-029-2d 160-01 BP E.~lorati~n (Alas kaj • • From: "A11en, Kenneth W" <Kenneth.Allen(clbp.com> Date: Mon, OS Dec 2005 14:13:37 -0900 To: F~cib Grandall~ci~ldmin.statc.a}~_us C(,: "HuEihlc, 1~crrie. I_." ~1 luhblr fl "~i'bh.c~m-= Bob, This is the 2"d send as the 1St was returned with an undeliverable message? The wells below are the only wells within %4 mile of the planned 01-08A well at the Put River formation interval. 02-11 Distance = 830' (Closest point at put interval) I~ 7 G!~ ~ ~ Status of well = P&A'd for 02-11A CTD sidetrack 02-11 A Distance = 830' (Closest point at put interval) ! ~ ~' 1 Z to ~ Status of well =Flowing well (waivered for IA x OA leak) 06-22 Distance = 860' (Closest point at put interval) I gZ 13l ~ Status of well = P&A'd for 06-22A CTD sidetrack 06-22A Distance = 860' (Closest point at put interval) I ~ 3 or ~ ~ Status of well =Shut in for suspected tubing leak & production casing leak (secured with tubing tail plug} Terrie Hubble asked if I could provide you with the closest Put River Producer distances also... The closest Put River producer is well 02-23A. It is ~5~' from the planned 01-08A injector. If you have any questions or need more information please let me know. Thanks, Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allenl~~r~(rzb~.com 1 of 1 12/5/2005 2:21 PM r1 ~J C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re THE APPLICATION OF BP ) EXPLORATION (ALASKA) INC. ) for an order to modify Area Injection ) Order 4C to include the Put River ) Sandstone Member of the Kalubik ~ Formation in the authorized injection ~ strata for enhanced recovery; and Area Injection Order 4D Prudhoe Bay Field Prudhoe Oil Pool Put River Oil Pool December 2, 2005 THE PROPOSAL initialed by the Commission to amend underground injection orders to incorporate consistent language addressing the mechanical integrity of wells IT APPEARING THAT: 1. By letter dated August 19, 2005 BP Exploration (Alaska), Inc. ("BPXA"), Operator of the Prudhoe Bay Unit, applied for a modification of Conservation Order 341 D and Area Injection Order 4C to include the Put River Sandstone Member of the Kalubik Formation ("PRS") within the Prudhoe Oil Pool definition and to authorize injection for enhanced recovery purposes within the interval. 2. The Alaska Oil and Gas Conservation Commission ("Commission") published notice of opportunity for public hearing in the Anchorage Daily News on September 1, 2005. 3. On September 13 and September 30, 2005 BPXA submitted addenda addressing questions by the Commission staff concerning its application. 4. The Commission held a public hearing October 6, 2005 at the Alaska Oil and Gas Conservation Commission at 333 West 7`h Avenue, Suite 100, Anchorage, Alaska 99501. 5. The Commission received no protests to or comments on BPXA's application. 6. BPXA supplied additional information as requested by the Commission on November 3, 2005. 7. On its own motion the Commission proposed to amend the rules addressing mechanical integrity in all existing orders authorizing underground injection. The Commission published notice of opportunity for public hearing on the proposal in the Anchorage Daily News on October 3, 2004 to consider amendment of underground injection orders to incorporate consistent language addressing the mechanical integrity of injection wells. A hearing was tentatively scheduled for November 4, 2004. Area Injection Order 4D December 2, 2005 • Page 2 8. By e-mail dated October 15, 2004, BPXA suggested edits to the Commission's proposed language addressing the mechanical integrity of injection wells. 9. No protests to the Commission's proposal or requests for hearing were received, and the scheduled hearing was vacated. FINDINGS: 1. CO 559 and CO 341E: The findings of Conservation Orders No. 559 and 341E are incorporated by reference. 2. Operator: BPXA is Operator of the property in the area in which injection is proposed. 3 . Infection Strata BPXA requested that the PRS be added as an allowable injection stratum. The PRS is the sandstone interval that correlates with the interval 9,638 to 9,719 measured feet on the Borehole Compensated Sonic Log, Run 2, dated September 28, 1975,. in the Atlantic Richfield-Exxon NGI No. 1 well. BPXA requested the addition of this sandstone interval within the definition of the Prudhoe Oil Pool. 4. Proposed Injection Area: The hydrocarbon-bearing interval of the PRS lies entirely within the area of the approved affected area of AIO 4C. No changes have been requested for the affected area of AIO 4C. 5. Operators/Surface Owners Notification: At the time of the application BPXA had not proposed a well for injection service. BPXA will provide an affidavit showing that the Operators and Surface Owners within one-quarter mile radius of each proposed injector have been notified upon application for a Permit to Drill or Application for Sundry Approval for any injection wells. 6. Description of Operation: The PRS is located within the Prudhoe Bay Unit and overlies the Prudhoe Oil Pool in the vicinity of Drill Sites 1, 2, 5, 6, 15, 18, NGI, and WGI. A reservoir model is currently being constructed to evaluate development options. Four vertically significant and laterally extensive sandstone lobes have been correlated within the PRS interval. There is no pressure communication between the four locally deposited sandstone lobes. Each of the lobes are laterally interbedded with shales of the Kalubik Formation. They are termed the Southern, Central, Western, Northern Lobes. The Southern and Central Lobes are saturated with black oil and the Western and Northern Lobes contain gas condensate. Development of the largest black oil accumulation, the Southern Lobe, is anticipated to include one to five production wells and one to five injection wells. Development plans for this accumulation are being evaluated. The Northern Lobe is in pressure communication with the gas cap of the Prudhoe Oil Pool, and the definition of the Prudhoe Oil Pool has been expanded to include the Area Injection Order 4D • • Page 3 December 2, 2005 Northern Lobe. 7. Hydrocarbons In Place and Hydrocarbon Recovery: There are no indications of a free gas column in the Southern or Central Lobes. Estimated hydrocarbons in place are as follows: Lobe Estimated Oil in Place, MMSTB Estimated Gas in Place, BCF Southern 12.6-19.2 6.9-10.5 Central 1.1-2.7 .5-1.3 Western n/a 69.6-104.4 Northern n/a 108.4-160.4 Using material balance calculations for the Southern and Central Lobes, primary depletion is estimated to recover approximately 10% of the STOIP. Early screening of analog reservoirs suggests incremental recovery of 10-25% with waterflood. No discussion was provided concerning the benefits of enriched gas injection. 8. Geologic Information: The Northern Lobe of the PRS is in depositional contact, and pressure communication with the Sag River Formation portion of the Prudhoe Oil Pool. The Commission has expanded the Prudhoe Oil Pool to include the Northern Lobe of the PRS with the issuance of CO 341E. The remaining lobes of the PRS, including the targeted waterflood development area of the Southern Lobe, are hydraulically isolated from the Prudhoe Oil Pool and each other. The Southern, Central and Western Lobes of the PRS comprise the Put River Oil Pool as defined in CO 559. BPXA's application and Conservation Order 559 provide a discussion of the Put River Oil Pool development. 9. Well Logs: The logs of existing injection wells are on file with the Commission. 10. Mechanical Integrity and Well Design of Injection Wells: The casing programs for injectors will be permitted and completed in accordance with 20 AAC 25.030. Cement bond logs will be run on all injection wells to demonstrate isolation of injected fluids to the PRS. 11. Type of Fluid /Source: Fluids requested for injection for the purposes of pressure maintenance and enhanced recovery are: a) produced water from Prudhoe Bay Unit production facilities; b) source water from the Seawater Treatment Plant; c) fluids injected for purposes of stimulation per 20 AAC 25.280(a)(2), consistent with other North Slope field practices; d) tracer survey fluid to monitor reservoir performance, consistent with other North Slope field practices; and Area Injection Order 4D December 2, 2005 e) miscible injectant. 12. Water Composition and Compatibility with Formation: ,. Page 4 The main fluid source will be source water from the Seawater Treatment Plant. No significant compatibility issues are anticipated between the formation and injected fluid. Analyses of core samples from Put River Formation sandstone in Prudhoe Bay Unit Well 2-14 demonstrate similar clay mineral types and proportions as those in Kuparuk River Formation reservoirs in adjacent North Slope fields. Each of the analog fields has a successful history of waterflooding and based on these comparisons the Put River Formation is not anticipated to have compatibility issues related to seawater injection. 13. Infection Rates and Pressures, Fracture Information: The expected average surface water injection pressure for the PRS is 1800 psig. The maximum water injection pressure is 2600 psig, or 5950 psig bottom hole. The sandstone in the Southern Lobe where injection is being evaluated has 80-100 feet of Kalubik Formation above and 150-200 feet of Kingak Shale below. With the bounding shale thicknesses, the expected maximum injection pressure would not initiate or propagate fractures through the confining strata. 14. Underground Sources of Drinking Water: No underground sources of drinking water are known to exist beneath the area covered by this order, the Eastern Operating Area of the Prudhoe Bay Unit and the Pt. McIntyre Oil Field. 15. Mechanical Integrity of Injection Wells and Wells within'/a mile of infector: A report on the mechanical condition of each well that has penetrated the PRS within one-quarter mile radius of a proposed injection well will be provided to the Commission with each application for a Permit to Dill or Application for Sundry Approval for an injection well. Changes proposed by the Commission in the rules governing demonstration of mechanical integrity, well integrity failure and confinement, and administrative actions will improve clarity, reduce the potential for confusion, and better protect mechanical integrity of injection wells. CONCLUSIONS: 1. The conclusions of CO 559 and CO 341 E are incorporated by reference. 2. The application requirements of 20 AAC 25.402 have been met. 3. Initial development will target oil reserves in the Southern Lobe of the Put River Oil Pool. 4. Water injection will significantly improve recovery within the Southern Lobe of the Put River Oil Pool. Area Injection Order 4D December 2, 2005 • Page 5 5. Further rules on depletion plans and appropriate enhanced recovery operations are incorporated within CO 559. 6. There are no known or anticipated compatibility problems between the PRS and the requested injectants. 7. The proposed injection operations will be conducted in permeable strata, which can reasonably be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata. S. Injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the wellbore and appropriate operating conditions. 9. Reservoir and well surveillance, coupled with regularly scheduled mechanical integrity tests, will demonstrate appropriate performance of the enhanced oil recovery project or disclose possible abnormalities. 10. Revisions as proposed by the Commission are appropriate concerning the rules governing demonstration of mechanical integrity, well integrity failure and confinement, and administrative actions. NOW, THEREFORE, IT IS ORDERED 1. Rule 1 of Area Injection Order No. 4C (corrected) is amended to include the following in the authorized injection strata for the injection of fluids described in Finding 9 of this order for purposes of pressure maintenance and enhanced recovery: a. the Prudhoe Oil Pool as defined in Conservation Order No. 341 E; b. the Put River Oil Pool as defined in Conservation Order No. 559. 2. Rule 4 of Area Injection Order No. 4C (corrected) is amended to read: Rule 4 Monitoring the Tubing-Casing Annulus Pressure Variations The tubing and casing annuli pressures of each injection well must be monitored at least daily, except if prevented by extreme weather condition, emergency situations, or similar unavoidable circumstances. Monitoring results shall be documented and made available for Commission inspection. 3. Rule 5 of Area Injection Order No. 4C (corrected) is revoked. 4. Rule 6 of Area Injection Order NO. 4C (corrected) is hereby amended to read: Area Injection Order 4D ~ • Page 6 December 2, 2005 Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in a well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter (except at least once every two years in the case of a slurry injection well). The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30-minute period. Results of mechanical integrity tests must be readily available for Commission inspection. 5. Rule 7 of Area Injection Order No. 4C (corrected) is amended to read: Rule 7 Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the Operator shall notify the Commission by the next business day and submit a plan of corrective action on a Form 10-403 for Commission approval. The Operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection. Area Injection Order 4D • December 2, 2005 Page 7 6. Rule 9 of Area Injection Order No. 4C (corrected) is amended to read: Rule 9 Administrative Action Unless notice and public hearing are otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. DONE at Anchorage, Alaska and dated December 2, 2005. ''€: - - '`~. ~,~ ~ ,-. i~ ~ ~~ ;~~ `°~. ''~ ,; a ~_ . `~ ~v ./`v AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). ~ • TERRIE L RUBBLE ss-sirz5z 242 ', BP EXPLORATION AK tNC ~~Mastercard Check" PO BOX 196.612 1VI6 7-5 ANCHORAGE, AK 99519-6612 ~aTE '~ PAY TO THE ~ ~~ $ 'O~ •~O ORDER OF _ O LLAR First National Bank Alaska Anchorage, AK 99501 ~~ ~~~ ` MEMO isL25200060~:99L4~~~6227~~~L556~~' 0242 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO SE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~/~ O ~ -Q ~ 5~~ CHECK WHAT i ADD-ONS APPLIES ; (OPTIONS MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" ~re-f ~ . The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function of .the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (per records, data and logs acquired for the pilot ~ hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACIlVG j The permit is approved subject to full EXCEPTION I compliance with 20 AAC 25.055. Approval to ~ perforate and groduce/infect is contingent ; upon issuance of a conservation order approving a spacing exception. (Company Name) assumes ~ the liability of any protest to the spacing j exception that may occur. DRY DITCH Alt dry ditch sample sets submitted to the SAMPLE ~ Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ~ LO' sample intervals through target zones. Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT C CKLIST Field & Pool PRUDHOE BAY, PUT RIVER OIL -640182 WeII Name: PRUDHOE BAY UNIT 01-08A Program SER Well bore seg ^ PTD#:2051950 Company BP EXPLORATION (ALASKA) INC _ Initial Classffype _ SER 11 WINJ GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permitfee attached_ _ - _ _ _ _ - - - . - _ - _ _ _ _ _ _ _ Yes _ _ _ 2 Lease number appropriate- - - - - - - - - - - Yes - 3 Uniquewell_nameandnumbe[_..______________________ ____________Yes__- -_._-__._ -- 4 Well located in.a.defined_pool - - Yes -. - 5 Well located proper distance from drillingunitboundary__________ ___________Yes___ ____-.---_______-_-.--_____--__---____--_--_-._ 6 WeII located proper distance from other wells_ _ _ - _ _ _ Yes - - _ _ Nearest Put River completion is 5440 feet away-RPC - - - - _ - - - - - ------------------ 7 Sufficient acreageayail_ablein_drillingunit__-______----- ------------Yes___ --.--_-- 8 If deviated,is.wellboreplat-included__._________ ___----- --------__-Yes-__ ___-_---___-______,--________-__- -----_ 9 Operatorgnlyaffectedparty____________________________ ____________Yes__ _-._ -- - - 10 Operator has-appropriate.bopdin force - ----- -- ---- -- -- -----Yes --- ---- - ------ - ------- - -- ----- ------ - ------ - -- 11 Permit_can be issued without conservation order_ _ _ _ - - - - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . - - - - - _ _ _ _ _ -- - Appr Date 12 Pe[mitcan be issued without administrative_approval - - , _ - - Yes . - - RPC 121512005 13 Can permit be approved before 15-day wait Yes 14 WeII located within area and-strata authorized by_Injection Order # (put_IO# in_comments)_(For- Yes - .. - AIO.4D_ - - _ _ - - - _ - - _ - _ - - _ - _ - - - - _ - 15 All wells within 1!4-mile area.of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _PBU 02-11, PBU 02-11A, PBU 06-22~PB11 Q6-22A.. _ _ _ _ - _ _ _ _ _ . , _ _ _ --------------------- 16 Pre-produced injector; duration of pre production less than-3 months_(For service well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ACMP-Finding oft;onsistency-h_asbeenissued-for_thisproject------ ------------ NA____ -_--.-_-_______-_-_-__ __---_---_- - - Engineering 18 _C_onduckorst[ing_provided_______________________-.--_ _____-----.-NA__ _--.-_--______--.-__ -- - 19 Su_rface-casing-protectsallknownUSDWS_---------------- ------------Yes--- ----------------------.-------------------------------- --------- --- 20 CMT-voladequate_tocirculate-onconducto[&surf_csg------------ ------- ----Yes--- -___Adequateexcess,-____---.--_____-__--__--_-__,-_---_--__.__--____-.-_-- 21 CMT-vol-adeguate_to tie-in long string to surf csg_ _ - - - - - - _ _ _ - - Yes - - - _ - . - - - - 22 CMT_willcoverallknown-p(oductivehorizons_-_--___________ ____________ Yes-__ _____----_-_____--,-______-----__ 23 Casingdesign5adequateforC,_T,B&-peCmafrost_-----.------ ------------Yes--- ----------------------,------------------------.------------- 24 Adequatetankage_orreseryepit__________ ______________ _______----Yes-_. ____Nabor-s-2ES,____,___-___--__---___----_-____------ --------------- 25 Ifa_re-drill,has_a_1.0-403 forabandon_mentbeenapproved--_______ ____________Yes- _ __11l2312005._--____-------_______-__. 26 Adequateweliboreseparationproposed___-_________________ ___________Yes___ -.._-______________ 27 Ifdiverterregraired,doesitmeetregulalions--__-_-.---._--__ --,_--_--___ NA_-_ -__Sidetrack--------------------------------------------- Appr Date 28 Dnllingfluid-programschematic-&eui listadeuate-----_ 4p q - __.-_____Yes._ __ _MaxMW-10,8-ppg_________________-__-----___--_-_--____--_---_____-----_- WGA 12/6!2005 29 BOPEs,dotheymeetregu_lotion------------- ----------- -----------Yes--- ------ ------------ ---,-----------------------.------------ -- --- 30 BOPS-press rating appropriate; test t_o_(put prig in comments)_ _ - - - - Yes . - _ - -Test to 4000 psi. _M$P 2850 si, p - - 31 Choke-manifold complieswlAPI-RP-53~May 84)--________-____ ____________Yes-__ __-_----_______-_---_______---_-__ 32 Workwilioccurw~houtoperationshutdown-__--____------- ------------Yes__ --..--._- - - 33 Is presence-of H25 gas-probable - - N0 - Not an H2S pad• - - - - - - 34 Mechanical_condition ofwells within AOR verified- (Forservice well only) - - - - - Yes - Cementing reviewed for all AORwells- - - - - - - - - - - - - - - - Geology 35 Permit_can be issued w!o hydrogen_sulfide measures Yes 36 _D_ata_presented qn pote_ntial overpressure zones - _ - - - _ NA_ - - _ - - - - Appr Date 37 Seismic analysis-of shallow gas-zones- NA - - - RPC .12/512005 38 Seabed condition sunrey_(ifoff-shore) . - - - NA- - - - - - - - - - 39 Contact namelphone for weekly_progress reports_ [exploratory only] NA- - . - - _ _ _ _ - _ - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Co r Date • • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part ofi 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. • 01-08apbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Aug 11 16:39:14 2008 Reel Header Service name .............LISTPE Date . ...................08/08/11 Ori in ...................STS Ree~ Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/08/11 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA ~~N~€~ 5 ~ ~ ~. 2008 01-08A PB1 500292016070 BP Exploration (Alaska) Sperry Drilling Services 11-AUG-08 MWD RUN 1 MWD RUN 2 JOB NUMBER: W-0004110204 W-0004110204 LOGGING ENGINEER: C. COCHRAN C. COCHRAN OPERATOR WITNESS: J. RALLS J. RAUL SURFACE LOCATION SECTION: $ TOWNSHIP: lON RANGE: 15E FNL: FSL: 4204 FEL: 3758 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 66.90 GROUND LEVEL: 37.90 WELL CASING RECORD Page 1 • Library. Scientific Technical Services Library. scientific Technical services MWD RUN 3 W-0004110204 C. COCHRAN J. RAUL /~'~~~ ~ c av~ -r~5 • • 01-08apbl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.500 13.375 2350.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIP- STOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. UPHOLE MAD TIE-IN SGRC WERE MERGED WITH RUN 1 MWD DATA. EWR TOOLS DID NOT EXIT THE CASING ON MWD RUN 3. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 4 AUGUST 2008, QUOTING AUTHORIZATION FROM PRIYA MARAJ (BP). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL 1-08A PB1 WITH API# 50-029-20160-70. THIS WELL REACHED A TOTAL DEPTH OF 2616'MD/2614'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................LO Page 2 • Ol-08apbl.tapx 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 RPD RPX RPS RPM FET ROP 1 • clipped curves; all bit runs merged. .5000 START DEPTH 2093.5 2345.0 2345.0 2345.0 2345.0 2345.0 2350.5 STOP DEPTH 2539.0 2531.5 2531.5 2531.5 2531.5 2531.5 2616.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2093.5 2402.0 2402.0 2552.0 2552.0 2616.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2093.5 2616 2354.75 1046 2093.5 2616 Page 3 • Ol-08apbl.tapx RPD MWD OHMM 0.34 2000 65.8766 374 2345 2531.5 RPM MWD OHMM 0.76 1758.7 12.769 374 2345 2531.5 RPS MWD OHMM 0.91 1389.38 7.10794 374 2345 2531.5 RPX MWD OHMM 0.99 1380.77 6.85283 374 2345 2531.5 FET MWD HOUR 0.71 45.25 17.5022 374 2345 2531.5 GR MWD API 19.48 92.24 47.782 892 2093.5 2539 ROP MWD FT/H 0.04 278.12 126.947 532 2350.5 2616 First Reading For Entire File..........2093.5 Last Reading For Entire File...........2616 File Trailer service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2093.5 2315.0 ROP 2350.5 2402.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 70.08 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2402.0 TOP LOG INTERVAL (FT): 2350.0 BOTTOM LOG INTERVAL (FT): 2402.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: ,Q Page 4 • Ol-08apbl.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 11.625 DRILLERS CASING DEPTH (FT): 2350.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): $,$Q MUD VISCOSITY (S): 65.0 MUD PH: g,3 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): g,0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.390 109.4 MUD FILTRATE AT MT: 1.600 74.0 MUD CAKE AT MT: 2.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 GR MwD010 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2093.5 2402 2247.75 618 2093.5 2402 GR MWDO10 API 19.48 54.72 38.0445 444 2093.5 2315 ROP MWDO10 FT/H 0.04 43 10.9651 104 2350.5 2402 First Reading For Entire File..........2093.5 Last Reading For Entire File...........2402 Page 5 • • O1-08apbl.tapx File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File TypPe. .LO Next File Name...........STSLIB.003 Physical EOF File Header service name... .....STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2315.5 FET 2345.0 RPx 2345.0 RPS 2345.0 RPM 2345.0 RPD 2345.0 ROP 2402.5 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: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 2484.5 2477.0 2477.0 2477.0 2477.0 2477.0 2552.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA 03-JAN-06 Incite 70.08 Memory 2552.0 2402.0 2552.0 3.5 6.9 TOOL NUMBER 120558 116184 Page 6 • • 01-08apbl.tapx OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2350.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): $,80 MUD VISCOSITY (S): 65.0 MUD PH: 9,3 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 9,0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.860 80.3 MUD FILTRATE AT MT: 1.600 74.0 MUD CAKE AT MT: 2.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type...,.0 Logging Direction .................DOwn Optical log depth units.........,.Feet Data Reference Point ..............undefined Frame Spacing....... ..........,.60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ...,. Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 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 Name Service unit Min Max Mean Nsam First Reading Last Reading DEPT FT 2315.5 2552 2433.75 474 2315.5 2552 RPD MWD020 OHMM 0.34 2000 92.2329 265 2345 2477 RPM MwD020 OHMM 1.17 1758.7 17.3015 265 2345 2477 RPS MWD020 OHMM 1.2 1389.38 9.3089 265 2345 2477 RPX MWD020 OHMM 0.99 1380.77 8.93615 265 2345 2477 FET MwD020 HOUR 0.71 45.25 17.0674 265 2345 2477 GR MWD020 API 28.16 92.24 53.7558 339 2315.5 2484.5 ROP MWD020 FT/H 17.19 278.12 164.365 300 2402.5 2552 Page 7 • O1-08apbl.tapx First Reading For Entire File..........2315.5 Last Reading For Entire File...........2552 File Trailer service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/08/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.... .08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 2477.5 RPD 2477.5 RPM 2477.5 FET 2477.5 RPS 2477.5 GR 2485.0 ROP 2552.5 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: 04-JAN-06 Insite 70.08 Memory 2616.0 2552.0 2616.0 4.2 5.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 116184 Page 8 • header data for each bit run in separate files. 3 .5000 STOP DEPTH 2531.5 2531.5 2531.5 2531.5 2531.5 2539.0 2616.0 ~ • 01-08apbl.tapx $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2350.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): $,$Q MUD VISCOSITY (S): 65.0 MUD PH: Q,3 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.100 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.950 80.3 MUD FILTRATE AT MT: 1.800 74.0 MUD CAKE AT MT: 2.800 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Dat a 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 ........ .....undefine d Absent value ................. .....-999 Depth Units. .. .. ..... Datum specification Block sub -type...0 Nam e service order units size N sam 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 Nam e Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2477.5 2616 2546.75 278 2477.5 2616 RPD MWD030 OHMM 0.82 2.14 1.79927 109 2477.5 2531.5 RPM MwD030 OHMM 0.76 2.08 1.74945 109 2477.5 2531.5 RPS MWD030 OHMM 0.91 2.08 1.75697 109 2477.5 2531.5 RPX MWD030 OHMM 1.11 2.06 1.78789 109 2477.5 2531.5 FET MWD030 HOUR 17.36 20.75 18.5594 109 2477.5 2531.5 GR MWD030 API 23.07 88.49 68.8678 109 2485 2539 Page 9 O1-08apbl.tapx RoP Mw~030 FT/H 1 176.73 133.481 First Reading For Entire File..........2477.5 Last Reading For Entire File...........2616 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 gate of Generation.... .08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/O8/11 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/08/11 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN comments .................sTS LIS Writing Library. Physical EOF Physical EOF End Of LIS File 128 2552.5 2616 Scientific Technical services scientific Technical Services Page 10 4 • Ol-08a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Aug 11 15:27:46 2008 Reel Header Service name .............LISTPE Date . ...................08/08/11 Ori 9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................08/08/11 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: MW0004110204 LOGGING ENGINEER: C. COCHRAN OPERATOR WITNESS: J. BALL MWD RUN 5 JOB NUMBER: Mw0004110204 LOGGING ENGINEER: M. HANIK OPERATOR WITNESS: D. MASKELL MWD RUN 8 JOB NUMBER: Mw0004110204 LOGGING ENGINEER: M. HANIK OPERATOR WITNESS: D. MASKELL MWD RUN 11 • Scientific Technical Services scientific Technical services Sf~ Yr'i~ V4/ .. V C~~~ O1-08A 500292016001 BP Exploration (Alaska) Sperry Drilling Services 11-AUG-08 MWD RUN 2 Mw0004110204 C. COCHRAN J. RALL MWD RUN 6 Mw0004110204 M. HANIK D. MASKELL MWD RUN 9 Mw0004110204 A. SHANAHAN D. MASKELL MAD RUN 11 Page 1 MWD RUN 4 Mw0004110204 C. COCHRAN J. RALL MWD RUN 7 Mw0004110204 M. HANIK D. MASKELL MWD RUN 10 Mw0004110204 C. COCHRAN J. RALL v ~~ ~~ /9 ~~ ~~ ~~~ • • JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MW0004110204 C. COCHRAN J. RALL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.750 3RD STRING 6.125 PRODUCTION STRING REMARKS: O1-08a.tapx MW0004110204 C. COCHRAN J. RALL 8 lON 15E 4204 3758 66.90 37.90 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 2350.0 9.625 5465.0 7.000 14208.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED OFF OF A CEMENT PLUG IN 1-08 PB1. THE TOP OF THE CEMENT (KOP) WAS AT 2425'MD/2425'TVD, WITHIN THE MWD RUN 2 INTERVAL. 4. MWD RUNS 1-11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 5-9 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 5,7,9 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (G P). MWD RUN 11 ALSO INCLUDED COMPENSATED THERMAL NEUTRON(CTN) AND AZIMUTHAL LITHO-DENSITY (ALD). TWO MAD PASSES ACQUIRED DATA OVER THE MWD RUN 10 INTERVAL PRIOR TO MWD RUN 11. THE FIRST PASS (RIH) WAS MERGED WITH RUN 11 MWD DATA. THE SECOND (POOH) IS PRESENTED SEPARATELY. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 4 AUGUST 2008, QUOTING AUTHORIZATION FROM PRIYA MARAJ (BP). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,4-11 REPRESENT WELL 1-08A WITH API# Page 2 • • O1-08a.tapx 50-029-20160-01. THIS WELL REACHED A TOTAL DEPTH OF 14800'MD/8331'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED-HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4-8.5 PPG MUD SALINITY: 3300-3400 PPM CHLORIDES FORMATION WATER SALINITY: 20000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE .HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 3 Ol-08a.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2093.5 14740.0 RPX 2345.0 14747.0 FET 2345.0 14747.0 RPS 2345.0 14747.0 RPD 2345.0 14747.0 RPM 2345.0 14747.0 RoP 2350.5 14800.0 NCNT 14194.0 14712.5 FCNT 14194.0 14712.5 NPHI 14194.0 14712.5 RHOB 14205.5 14727.0 PEF 14205.5 14727.0 RHO 14205.5 14727.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 2093.5 2402.0 MwD 2 2402.0 2425.0 MWD 4 2425.5 5467.0 MWD 5 5467.0 6339.0 MwD 6 6339.0 7630.0 MWD 7 7630.0 9164.0 MWD 8 9164.0 10576.0 MWD 9 10576.0 14212.0 MWD 10 14212.0 14340.0 WD 11 14340.0 14800.0 $ REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 Page 4 01-08a.tapx GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD Pu-S 4 1 68 52 14 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 2093.5 14800 8446.75 25414 2093.5 14800 FCNT MWD CNTS 185.5 722.9 451.678 1038 14194 14712.5 NCNT MWD CNTS 15100.5 34553.8 25834.4 1038 14194 14712.5 RHOB MWD G/CM 1.487 3.734 2.48321 1044 14205.5 14727 DRHO MWD G/CM -0.341 1.426 0.111769 1044 14205.5 14727 RPD MWD OHMM 0.24 2000 19.469 24805 2345 14747 RPM MWD OHMM 0.28 2000 13.2717 24805 2345 14747 RPS MWD OHMM 0.39 2000 5.20789 24805 2345 14747 RPX MWD OHMM 0.39 2000 5.37939 24805 2345 14747 FET MWD HOUR 0.19 230.54 3.7113 24805 2345 14747 GR MWD API 6.01 398.38 90.8723 25294 2093.5 14740 PEF MWD BARN 0.11 8.11 2.47072 1044 14205.5 14727 RoP MwD FT/H 0.01 623.86 103.797 24860 2350.5 14800 NPHI MWD PU-S 19.46 51.67 28.7564 1038 14194 14712.5 First Reading For Entire File..........2093.5 Last Reading For Entire File...........14800 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RHOB DRHO and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 14197.5 14200.5 14200.5 STOP DEPTH 14278.0 14265.0 14265.0 Page 5 • 01-08a.tapx PEF 14200.5 14265.0 NCNT 14200.5 14250.5 FCNT 14200.5 14250.5 NPHI 14200.5 14250.5 FET 14204.5 14285.0 RPS 14204.5 14285.0 RPM 14204.5 14285.0 RPD 14204.5 14285.0 RPX 14204.5 14285.0 T 14257.0 14338.0 $ MERGED PBU MWD REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 MERGE TOP MERGE BASE 14194.0 14340.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14197.5 14338 14267.8 282 14197.5 14338 FCNT MAD CNTS 215.8 515.1 413.412 101 14200.5 14250.5 NCNT MAD CNTS 16801 28138 23794.8 101 14200.5 14250.5 RHOB MAD G/CM 2.105 3.577 2.42916 130 14200.5 14265 DRHO MAD G/CM -0.102 1.281 0.274238 130 14200.5 14265 RPD MAD OHMM 8.69 42.86 18.8245 162 14204.5 14285 RPM MAD OHMM 6.88 36.5 16.6517 162 14204.5 14285 RPS MAD OHMM 6.1 33.19 15.4713 162 14204.5 14285 RPX MAD OHMM 4.81 37.4 14.3149 162 14204.5 14285 FET MAD HOUR 28.7 263.29 57.7731 162 14204.5 14285 GR MAD API 41.94 110.37 66.6477 162 14197.5 14278 Page 6 DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO 11 1 • • O1-08a.tapx PEF MAD BARN 0.77 6.38 1.69962 130 14200.5 14265 RAT MAD FT/H 2 620 95.2515 163 14257 14338 NPHI MAD PU-S 23.31 42.51 29.0507 101 14200.5 14250.5 First Reading For Entire File..........14197.5 Last Reading For Entire File...........14338 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2093.5 2315.0 $OP 2350.5 2402.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 70.08 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2402.0 TOP LOG INTERVAL (FT): 2350.0 BOTTOM LOG INTERVAL (FT): 2402.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 116184 Page 7 • • O1-08a.tapx 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: 12.250 2350.0 water Based 8.80 65.0 9.3 1800 9.0 2.000 74.0 1.390 109.4 1.600 74.0 2.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MwD010 API 4 1 68 4 2 ROP MwD010 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2093.5 2402 2247.75 618 2093.5 2402 GR MwD010 API 19.48 54.72 38.0445 444 2093.5 2315 ROP MWDO10 FT/H 0.04 43 10.9651 104 2350.5 2402 First Reading For Entire File..........2093.5 Last Reading For Entire File...........2402 File Trailer service name... .......STSLIB.003 service Sub Level Name... Page 8 • O1-08a.tapx version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................L0 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.......08/08/11 Maximum Physical Record..65535 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 2315.5 RPX 2345.0 RPM 2345.0 FET 2345.0 RPS 2345.0 RPD 2345.0 ROP 2402.5 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: header data for each bit run in separate files. 2 .5000 STOP DEPTH 2425.0 2425.0 2425.0 2425.0 2425.0 2425.0 2425.0 03-7AN-06 Insite 70.08 Memory 2425.0 2402.0 2425.0 3.5 6.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2350.0 BOREHOLE CONDITIONS Page 9 4 • • 01-08a.tapx MUD TYPE: water Based MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 65.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.860 80.3 MUD FILTRATE AT MT: 1.600 74.0 MUD CAKE AT MT: 2.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Log~iny 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 N sam 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 2315.5 2425 2370.25 220 2315.5 2425 RPD MWD020 OHMM 0.34 2000 150.685 161 2345 2425 RPM MwD020 OHMM 1.28 1758.7 27.3727 161 2345 2425 RPS MWD020 OHMM 1.31 1389.38 14.2231 161 2345 2425 RPX MWD020 OHMM 0.99 1380.77 13.6044 161 2345 2425 FET MWD020 HOUR 0.94 45.25 27.4439 161 2345 2425 GR MWD020 API 28.16 80.34 50.1308 220 2315.5 2425 ROP MWD020 FT/H 28.11 278.12 161.452 46 2402.5 2425 First Reading For Entire File..........2315.5 Last Reading For Entire File...........2425 Page 10 • • 01-08a.tapx File Trailer Service name... .......STSLI6.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 2425.5 FET 2425.5 RPM 2425.5 RPS 2425.5 RPX 2425.5 ROP 2425.5 GR 2425.5 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 5409.0 5409.0 5409.0 5409.0 5409.0 5467.0 5416.5 Page 11 08-JAN-06 Insite 70.08 Memory 5467.0 2425.0 5467.0 17.9 65.0 TOOL NUMBER 120558 116184 12.250 • • Ol-08a.tapx DRILLER'S CASING DEPTH (FT): 2350.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 48.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 750 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.930 86.0 MUD FILTRATE AT MT: 1.950 65.0 MUD CAKE AT MT: 3.000 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2425.5 5467 3946.25 6084 2425.5 5467 RPD MWD040 OHMM 0.41 19.83 4.2619 5968 2425.5 5409 RPM MWD040 OHMM 0.39 9.6 4.06057 5968 2425.5 5409 RPS MWD040 OHMM 0.48 7.39 3.96474 5968 2425.5 5409 RPX MWD040 OHMM 0.52 7.09 3.82965 5968 2425.5 5409 FET MWD040 HOUR 0.19 125.95 4.37616 5968 2425.5 5409 GR MWD040 API 16.86 118.43 73.3147 5983 2425.5 5416.5 ROP MWD040 FT/H 19.03 623.86 137.722 6084 2425.5 5467 First Reading For Entire File..........2425.5 Page 12 ~ • 01-08a.tapx Last Reading For Entire File...........5467 File Trailer Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLI6.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS 5409.5 RPD 5409.5 FET 5409.5 RPM 5409.5 RPx 5409.5 GR 5417.0 ROP 5487.5 STOP DEPTH 6293.5 6293.5 6293.5 6293.5 6293.5 6301.5 6339.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 Page 13 13-JAN-06 Insite 66.37 Memory 6339.0 5487.0 6339.0 62.7 67.7 TOOL NUMBER 119546 145654 r ~ ~J BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 01-08a.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 • 8.750 5466.0 water Based 10.20 53.0 9.4 250 8.4 6.000 68.0 3.990 105.8 9.500 68.0 2.130 68.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5409.5 6339 5874.25 1860 5409.5 6339 RPD MwD050 OHMM 1.28 2000 128.056 1769 5409.5 6293.5 RPM MWD050 OHMM 1.03 1809.23 52.9221 1769 5409.5 6293.5 RPS MWD050 OHMM 0.85 2000 17.1116 1769 5409.5 6293.5 RPX MWD050 OHMM 1.07 2000 21.772 1769 5409.5 6293.5 FET MWD050 HOUR 0.31 104.6 7.7422 1769 5409.5 6293.5 GR MwD050 API 6.01 124.66 50.2986 1770 5417 6301.5 ROP MWD050 FT/H 0.45 193.3 100.028 1704 5487.5 6339 Page 14 01-08a.tapx First Reading For Entire File..........5409 Last Reading For Entire File...........6339 File Trailer Service name... .......STSLI6.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER v FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6294.0 7583.0 RPX 6294.0 7583.0 FET 6294.0 7583.0 RPD 6294.0 7583.0 RPM 6294.0 7583.0 GR 6302.0 7591.0 ROP 6339.5 7630.0 LOG HEADER DATA DATE LOGGED: 15-7AN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7630.0 TOP LOG INTERVAL (FT): 6339.0 BOTTOM LOG INTERVAL (FT): 7630.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.4 MAXIMUM ANGLE: 64.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 15 • • Ol-08a.tapx DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 5466.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 53.0 MUD PH: $.$ MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.630 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.040 113.0 MUD FILTRATE AT MT: 5.100 70.0 MUD CAKE AT MT: 2.710 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6294 7630 6962 2673 6294 7630 RPD MWD060 OHMM 0.24 240.62 4.6294 2579 6294 7583 RPM MWD060 OHMM 0.28 186.09 4.41742 2579 6294 7583 RPS MWD060 OHMM 0.39 34.93 3.93076 2579 6294 7583 RPX MWD060 OHMM 0.91 29.38 3.86929 2579 6294 7583 Page 16 • O1-08a.tapx FET MWD060 HOUR 0.28 30.72 1.89914 2579 6294 7583 GR MWD060 API 13.22 129.77 69.1163 2579 6302 7591 ROP MWD060 FT/H 0.32 352.3 115.753 2582 6339.5 7630 First Reading For Entire File..........6294 Last Reading For Entire File...........7630 File Trailer Service name... .......STSLiB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.008 Physical EOF File Header service name... .......5T5LI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 7583.5 9118.0 RPx 7583.5 9118.0 RPS 7583.5 9118.0 RPD 7583.5 9118.0 FET 7583.5 9118.0 GR 7591.5 9126.0 ROP 7630.5 9164.0 LOG HEADER DATA DATE LOGGED: 16-7AN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9164.0 TOP LOG INTERVAL (FT): 7630.0 BOTTOM LOG INTERVAL (FT): 9164.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 55.2 MAXIMUM ANGLE: 62.6 Page 17 header data for each bit run in separate files. 7 • 01-08a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT; NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 C. TOOL NUMBER 134745 10505932 8.750 5466.0 water Based 10.20 49.0 8.8 600 5.8 3.100 70.0 1.990 113.0 5.300 70.0 2.200 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 7583.5 9164 8373.75 3162 7583.5 RPD MWD070 OHMM 0.84 15.66 3.05469 3070 7583.5 Page 18 Last Reading 9164 9118 • C~ O1-08a.tapx RPM MWD070 OHMM 0.83 372.88 3.23976 3070 7583.5 9118 RPS MWD070 OHMM 0.84 24.72 2.90226 3070 7583.5 9118 RPX MWD070 OHMM 0.83 34.13 2.90951 3070 7583.5 9118 FET MwD070 HOUR 0.21 18.48 1.16284 3070 7583.5 9118 GR MWD070 API 23.88 113.46 64.5502 3070 7591.5 9126 ROP MWD070 FT/H 2.13 325.92 128.104 3068 7630.5 9164 First Reading For Entire File..........7583.5 Last Reading For Entire File...........9164 File Trailer Service name... .......STSLI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.009 Physical EOF File Header service name... .......STSLIB.009 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9118.5 10529.5 RPS 9118.5 10529.5 FET 9118.5 10529.5 RPx 9118.5 10529.5 RPM 9118.5 10529.5 GR 9126.5 10537.5 ROP 9164.5 10576.0 LOG HEADER DATA DATE LOGGED: 18-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10576.0 TOP LOG INTERVAL (FT): 9164.0 BOTTOM LOG INTERVAL (FT): 10576.0 BIT ROTATING SPEED (RPM): Page 19 • • O1-08a.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 60.2 MAXIMUM ANGLE: 66.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 5466.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 51.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.750 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.610 124.0 MUD FILTRATE AT MT: 3.300 70.0 MUD CAKE AT MT: 2.600 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MwD080 OHMM 4 1 68 16 5 FET MwD080 HOUR 4 1 68 20 6 GR MwD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Page 20 O1-08a.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9118.5 10576 9847.25 2916 9118.5 10576 RPD MWD080 OHMM 1.27 22.53 3.73809 2823 9118.5 10529.5 RPM MWD080 OHMM 1.21 30.09 3.58524 2823 9118.5 10529.5 RPS MWD080 OHMM 1.23 16.13 3.48038 2823 9118.5 10529.5 RPX MWDO80 OHMM 1.26 15.4 3.4788 2823 9118.5 10529.5 FET MWD080 HOUR 0.3 17.88 1.26948 2823 9118.5 10529.5 GR MwD080 API 36.42 145.44 90.0786 2823 9126.5 10537.5 ROP MWD080 FT/H 1.76 250.94 113.39 2824 9164.5 10576 First Reading For Entire File..........9118.5 Last Reading For Entire File...........10576 File Trailer Service name... .......STSLIB.009 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.009 comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10530.0 14166.0 RPx 10530.0 14166.0 RPD 10530.0 14166.0 RPS 10530.0 14166.0 FET 10530.0 14166.0 GR 10538.0 14173.5 ROP 10576.5 14212.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): header data for each bit run in separate files. 9 .5000 22-7AN-06 Insite 66.37 Memory 14212.0 Page 21 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 Ol-08a.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 10576.0 14212.0 64.5 68.8 TOOL NUMBER 134745 10505932 8.750 5466.0 water Based 10.80 52.0 9.5 800 4.9 .990 70.0 .480 150.0 2.110 70.0 2.170 70.0 Name Service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 Page 22 • O1-08a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10530 14212 12371 7365 10530 14212 RPD MWD090 OHMM 0.9 33.36 4.45128 7273 10530 14166 RPM MWD090 OHMM 0.97 23.73 4.31877 7273 10530 14166 RPS MWD090 OHMM 1.16 13.86 3.7138 7273 10530 14166 RPX MWD090 OHMM 1.16 14.55 3.53876 7273 10530 14166 FET MWD090 HOUR 0.45 24.4 1.25556 7273 10530 14166 GR MWD090 API 30.49 398.38 142.066 7272 10538 14173.5 ROP MWD090 FT/H 0.01 170.21 70.9781 7272 10576.5 14212 First Reading For Entire File..........10530 Last Reading For Entire File...........14212 File Trailer Service name... .......STSLIB.O10 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.011 Physical EOF File Header Service name... .......STSLIB.O11 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 14166.5 14296.5 RPx 14166.5 14296.5 RPS 14166.5 14296.5 RPM 14166.5 14296.5 RPD 14166.5 14296.5 GR 14174.0 14289.5 ROP 14212.5 14340.0 LOG HEADER DATA DATE LOGGED: O1-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite Page 23 • • 01-08a.tapx DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14340.0 TOP LOG INTERVAL (FT): 14212.0 BOTTOM LOG INTERVAL (FT): 14340.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.4 MAXIMUM ANGLE: $9,9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 14208.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 56.0 MUD PH: 10.5 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.320 115.0 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: .750 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order Units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MwD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 Page 24 • • O1-08a .tapx GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14166.5 14340 14253.3 348 14166.5 14340 RPD MWD100 OHMM 0.39 2000 473.332 261 14166.5 14296.5 RPM MWD100 OHMM 3.15 2000 490.392 261 14166.5 14296.5 RPS MWD100 OHMM 0.51 65.67 12.2423 261 14166.5 14296.5 RPX MWD100 OHMM 0.39 35.51 10.8296 261 14166.5 14296.5 FET MWD100 HOUR 2.75 230.54 84.4295 261 14166.5 14296.5 GR MWD100 API 28.54 171.63 74.9873 232 14174 14289.5 ROP MWD100 FT/H 1.19 55 19.492 256 14212.5 14340 First Reading For Entire File..........14166.5 Last Reading For Entire File...........14340 File Trailer Service name... .......STSLIB.O11 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.012 Physical EOF File Header Service name... .......STSLIB.012 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.011 comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 14194.0 14712.5 NPHI 14194.0 14712.5 FCNT 14194.0 14712.5 RHOB 14205.5 14727.0 DRHO 14205.5 14727.0 PEF 14205.5 14727.0 GR 14290.0 14740.0 RPM 14297.0 14747.0 RPS 14297.0 14747.0 RPD 14297.0 14747.0 Page 25 • O1-08a.tapx FET 14297.0 14747.0 RPX 14297.0 14747.0 ROP 14340.5 14800.0 LOG HEADER DATA DATE LOGGED: 03-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14800.0 TOP LOG INTERVAL (FT): 14340.0 BOTTOM LOG INTERVAL (FT): 14800.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.1 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 SLD STABILIZED LITHO DEN 188894 CTN COMP THERMAL NEUTRON 100547 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 14208.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 54.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 3400 FLUID LOSS (C3): 8.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .290 122.7 MUD FILTRATE AT MT: 2.800 65.0 MUD CAKE AT MT: .700 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Page 26 O1-08a.tapx Absent value .... ..................-999 Depth units. .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD110 CNTS 4 1 68 4 2 NCNT MWD110 CNTS 4 1 68 8 3 RHOB MWD110 G/CM 4 1 68 12 4 DRHO MWD110 G/CM 4 1 68 16 5 RPD MWD110 OHMM 4 1 68 20 6 RPM MwD110 OHMM 4 1 68 24 7 RPS MWD110 OHMM 4 1 68 28 8 RPX MWD110 OHMM 4 1 68 32 9 FET MWD110 HOUR 4 1 68 36 10 GR MWD110 API 4 1 68 40 11 PEF MWD110 BARN 4 1 68 44 12 ROP MWD110 FT/H 4 1 68 48 13 NPHI MWD110 PU-5 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 14194 14800 14497 1213 14194 14800 FCNT MWD110 CNTS 185.5 722.9 451.678 1038 14194 14712.5 NCNT MWD110 CNTS 15100.5 34553.8 25834.4 1038 14194 14712.5 RHOB MWD110 G/CM 1.487 3.734 2.48321 1044 14205.5 14727 DRHO MWD110 G/CM -0.341 1.426 0.111769 1044 14205.5 14727 RPD MWD110 OHMM 6.09 76.17 20.9959 901 14297 14747 RPM MWD110 OHMM 4.76 54.77 17.8482 901 14297 14747 RPS MWD110 OHMM 3.97 34.71 15.4069 901 14297 14747 RPX MWD110 OHMM 3.7 38.47 13.9621 901 14297 14747 FET MwD110 HOUR 1.6 29.9 5.11453 901 14297 14747 GR MWD110 API 40.75 120.12 68.5012 901 14290 14740 PEF MWD110 BARN 0.11 8.11 2.47072 1044 14205.5 14727 ROP MWD110 FT/H 3.18 281.21 32.8626 920 14340.5 14800 NPHI MWD110 PU-S 19.46 51.67 28.7564 1038 14194 14712.5 First Reading For Entire File..........14194 Last Reading For Entire File...........14800 File Trailer Service name... .......STSLIB.012 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.013 Physical EOF File Header Service name... .......STSLI6.013 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/11 Maximum Physical Record..65535 Page 27 • • O1-08a.tapx File Type. ............LO Previous File Name.......STSLIB. 012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 11 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14197.5 14278.0 PEF 14200.5 14265.0 FONT 14200.5 14250.5 NPHI 14200.5 14250.5 DRHO 14200.5 14265.0 RHOB 14200.5 14265.0 NCNT 14200.5 14250.5 RPD 14204.5 14285.0 RPM 14204.5 14285.0 RPS 14204.5 14285.0 RPX 14204.5 14285.0 FET 14204.5 14285.0 RAT 14257.0 14338.0 LOG HEADER DATA DATE LOGGED: 03-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14338.0 TOP LOG INTERVAL (FT): 14257.0 BOTTOM LOG INTERVAL (FT): 14338.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.1 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 SLD STABILIZED LITHO DEN 188894 CTN COMP THERMAL NEUTRON 100547 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 14208.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 54.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 3400 FLUID LOSS (C3): 8.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) Page 28 O1-08a.tapx MUD AT MEASURED TEMPERATURE (MT): .500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .290 122.7 MUD FILTRATE AT MT: 2.800 65.0 MUD CAKE AT MT: .700 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MAD111 CNTS 4 1 68 4 2 NCNT MAD111 CNTS 4 1 68 8 3 RHOB MAD111 G/CM 4 1 68 12 4 DRHO MAD111 G/CM 4 1 68 16 5 RPD MAD111 OHMM 4 1 68 20 6 RPM MAD111 OHMM 4 1 68 24 7 RPS MAD111 OHMM 4 1 68 28 8 RPX MAD111 OHMM 4 1 68 32 9 FET MAD111 HOUR 4 1 68 36 10 GR MAD111 API 4 1 68 40 11 PEF MAD111 BARN 4 1 68 44 12 RAT MAD111 FT/H 4 1 68 48 13 NPHI MAD111 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14197.5 14338 14267.8 282 14197.5 14338 FCNT MAD111 CNTS 215.8 515.1 413.412 101 14200.5 14250.5 NCNT MAD111 CNTS 16801 28138 23794.8 101 14200.5 14250.5 RHOB MAD111 G/CM 2.105 3.577 2.42916 130 14200.5 14265 DRHO MAD111 G/CM -0.102 1.281 0.274238 130 14200.5 14265 RPD MAD111 OHMM 8.69 42.86 18.8245 162 14204.5 14285 RPM MAD111 OHMM 6.88 36.5 16.6517 162 14204.5 14285 RPS MAD111 OHMM 6.1 33.19 15.4713 162 14204.5 14285 RPX MAD111 OHMM 4.81 37.4 14.3149 162 14204.5 14285 FET MAD111 HOUR 28.7 263.29 57.7731 162 14204.5 14285 GR MAD111 API 41.94 110.37 66.6477 162 14197.5 14278 PEF MAD111 BARN 0.77 6.38 1.69962 130 14200.5 14265 RAT MAD111 FT/H 2 620 95.2515 163 14257 14338 NPHI MAD111 PU-S 23.31 42.51 29.0507 101 14200.5 14250.5 Page 29 • O1-08a.tapx First Reading For Entire File..........14197.5 Last Reading For Entire File...........14338 File Trailer Service name... .......STSLI6.013 Service sub Level Name... version Number. ........1.0.0 gate of Generation.......08/08/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.014 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/08/11 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/08/11 Ori9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 30