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Home My WebLink About204-234STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other Set CIBP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 204-234 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-22137-02-00 7. Property Designation (Lease Number): ADL 028326 & 028329 8. Well Name and Number: PBU 05-20B 9. Lags (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 11750 feet Plugs measured 10455 feet true vertical 9031 feet Junk measured 11652 feet Effective Depth: measured 10455 feet Packer measured 8424 feet true vertical 9047 feet Packer true vertical 8161 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 3474 13-3/8" 29-3503 29-3503 5020 2260 Intermediate 4679 95/8" 27-4706 27-4706 6870 4760 Liner 4330 T. 4336-8666 4336-8390 7240 5410 Liner 3270 4-1/2" 8480-11750 8214-9031 8430 7500 Perforation Depth: Measured depth: 9540-11650 feet True vertical depth: 9017-9026 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 25-8484 25-8218 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8424 8161 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 371 40419 56 0 1764 Subsequent to operation: 713 5414 422 0 318 14.Attachments: (regmred ar 20 nm 25 07025,071, a 25,210) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Oestgaard, Finn Contact Name: Oestgaartl Finn Authorized Title: Produ p n Engineer Challenger Contact Email: Finn.OestgaardAbp.00m Authorized Signature: ate: t h wil Contact Phone: +1 907 564 5026 Forth 10404 Revised 04/2017 �� m4"Atic-19 BBDMS!!EAjAUG 291019 Submit Original Only Daily Report of Well Operations PBU 05-20B ***WELL S/I ON ARRIVAL*** (Profile Modification) TAGGED BKR ROCKSCREEN IN XN-NIP @ 8,468' MD w/ 4-1/2" BRUSH, 3.80" G -RING. PULLED 4-1/2" BKR ROCKSCREEN FROM XN-NIP @ 8,468' MD. (Pictures of damage taken) 7/30/2019 ***JOB COMPLETE, WELL LEFT S/I*** CTU #8 1.75" CT 0.156WT. Objective: Mill barium scale/Set CIBP MIRU, Weekly bop test. MU & RIH w/ 3.70" mill. Mill from 9526ft to 9667ft. 7/31/2019 **In progress" CTU #8 1.75" CT 0.156WT. Objective: Mill barium scale/Set CIBP Continue to mill from 9667ft. Dry drift to 10600ft. Backreem to 9666ft. Dry driftto 10600ft. POH. MU & RIH w/ HES logging BHA. POOH with memory GR/CCL and correct to reference log. RIH and et 4.5" Baker CIBP at 10,455'. POOH. 8/1/2019 "Complete" ***WELL S/I ON ARRIVAL***(profile mod) SET 4-1/2" x 37' WFD ROCKSCREEN IN XN-NIP @ 8,468' MD. (Check set) 8/9/2019 ***JOB COMPLETE, WELL LEFT S/I*** T/I/O = SSV/80/0. Temp = SI. IA FL (Ops request). Al -disconnected. IA FL @ 1100' (59 bbls). 8/10/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 16:45 T/I/0 = 1560/1560NAC. Temp = SI. T FL (Ops request). Temporary AL online, no companion. T FL @ 5716' (sta # 4 SO). 8/21/2019 SV, WV = C. SSV, MV = O. IA, OA = OTG. 20:30 DATE REV BY COMMENTS DATE REV BY COMMENTS 1991 ORIGINAL COMPLETM 07/21/13 LEC/JMD SET ROCK SCREEN 7/09/13 07/09196 SDETRACKED 02115N7 KDP/JMD TREE CfO 02/12/17) 01/13105 N2ES SDETRACK 08/01h9 JMG/JMD PULLED ROCK SCRN (07/31/191 05/14/12 CJN/JMD SET ROCK SCREEN 05/09/12 09/06119 MR/JMD SETBKRCIBP &01/19 05114/12 JMD SCHEMATIC CLEANUP 09113/19 MTWJMD SET ROCK SCREEN 09/09/19 0625/13 RCT/JMD PULLED ROCK SCRN 0620/13 W=9 DD/JMD ADD OKS, REF, BF ELEVS PRUDHOE BAY UNIT WELL: 05-206 PERMIT NO: 2042340 API No: 50429-22137-02 BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg AUG 1 2-012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 C) _ ra j Subject: Corrosion Inhibitor Treatments of GPB DS -05 0 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, off. Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor - NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A _ N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 - 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -23B 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -288 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -33B 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 STATE OF ALASKA ~~u ~ ~ ?.Q09 ALAS OIL AND GAS CONSERVATION COMM O REPORT OF SUNDRY WELL OP1~,„Q a~Commis;ion ..~z~ s--iso9 1.Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated a Other MILL ~ Pertorrrted: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' Exploratory ~~ 204-2340 3. Address: P.O. Box 196612 Stratigraphic Senrice 6. API Number: Anchorage, AK 99519-6612 50-029-22137-02-00 7. KB Elevation (ft): 9. Well Name and Number: 62.6 KB PBU 05-206 8. Property Designation: 10. Field/Pool(s): ADLO-028329 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11750 feet Plugs (measured) None true vertical 9031.41 feet Junk (measured) 11652' CIBP PUSHED 4/17/09 Effective Depth measured 11663 feet true vertical 9026.48 feet Casing Length Size MD TVD Burst Collapse Conductor 115 20" 91.5# H-40 SURFACE - 115 SURFACE - 115 1490 470 Surface 3512 13-3/8" 68# L-80 SURFACE - 3512 SURFACE - 3512 4930 2270 Production 4706 9-5/8" 47# L-80 SURFACE - 4706 SURFACE - 4706 6870 4760 Liner 4342 7" 26# L-80 4324 - 8666 4324 - 8390 7240 5410 Liner 3270 4-1/2" 12.6# L-80 8480 - 11750 8214 - 9031 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE -8484' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X7" ZXP LNR TOP PKR 4336' 7"X4-1/2" BKR S-3 8424' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,ter ~. ~ s tg ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG r GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature .Phone 564-4944 Date 5/8/2009 Form 10-404 R ised 04/2006 ' ~ ~~~ ~~ E ~~d~ llSubmit Original Only ~' ~~/a`\ .~//~//-P 05-20B 204-234 PFRF eTTe['HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 05-20B 1/5/05 PER 9,540. 9,860. 9,017.49 9,027.55 05-20B 1/5/05 PER 9,920. 10,290. 9,028.3 9,041.38 05-20B 1/5/05 PER 10,980. 11,180. 9,044.01 9,031.21 05-20B 1/5/05 PER 11,230. 11,400. 9,028.03 9,021.67 05-20B 1/5/05 PER 11,580. 11,650. 9,022.89 9,025.81 05-20B 4/17/09 BPP 9,540. 11,652. 9,017.49 9,025.91 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 05-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 4/17/2009~CTU #6 1.75" Coil Mill CIBP /Caliper Log «<InterACT is Publishing»> MIRU i CTU. MU BTT Milling BHA W/ Weatherford Jars. RIH with 3.70" 3-blade flat bottom junk mill. RIH to mill CIBP. sat down at 9629' ctmd. Milled through 9629' ctmd and lost returns. Continue RIH taking no returns. Appear to be pushing debris ahead ~ ;of bit. assed CIBP depth of 10615' without seeing anvthinq. Appears CIBP had 4/18/09 ... POOH with motor and mill. Cont' on WSR 4/18/2009 CTU #6, Mill CIBP/Caliper; Cont' from WSR 4/17/09 ... POOH w/motor and mill. ;Lay down milling assy. Found a few chipped cutting buttons no significant wear. ~ MU and RIH with PDS 40- arm caliper. Log from 11500' up to 8300' ctmd. POOH. ,OOH with good data RD CTU. Pad Op notified of well status M/S/W= O/C/C and casing valves open to gauges. T/I/0= 176/728/40 ...Job Complete... FLUIDS PUMPED BBLS 86 50/50 METH 504 1 % KCL 590 Total • • ~f"~ MICROFILMED 03/01 /2008 DO NOT PLACE r ,,T=~° ,, s '`~ ANY I~EW MATERIAL UNDER THIS PAGE F:\i.aserFiche\CbrPgs_Inserts\Microfilm Marker.doc Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 5C~'iNED SEP 1 8 Z007 Well Job # LOA Description D ate BL 17-14 N/A JEWELRY/SBHP IMt\- J~'-l-Il,(A 08/17/07 1 MPC-10 11767137 MEM INJ PROFILE I )'Tf\' '''Jet;;: -DIK' 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG J'71{,) -05,Ç 08/15/07 1 P2-30 11686776 PRODUCTION PROFILE 19 ~ - ('>O¡,~ 08/25/07 1 L1-31 11865639 LDL ¡OJ''':' ,- r 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE /cr~ -rA-=¡' 08/17/07 1 17-03A N/A JEWELRY/SBHP 'Cl'-/-- /llt_ 08/17/07 1 C-26 11824342 LDL I q-í( - 11..Ç" 08/22/07 1 15-07C 11594517 SBHP SURVEY ~()~- Oqq 08/23/07 1 D-04B 11591451 SBHP SURVEY ;)(')"3. - II () 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE 101 '7( - (V'"> '1< 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE ¡'1~ - ~4 08/19/07 1 09-44 11855501 SBHP/JEWELRY /C>¡I..... - J Q~_ 08/16/07 1 09-23 11824337 SBHP/JEWELRY /~ - e+:2 08/16/07 1 2-52/S-41 11846807 PRODUCTION PROFILE J"6'= - ('\t:\ ~ 08/18/07 1 F-08A 11638646 USIT :)f\~ -0 06/28/07 02-16C 11628790 SCMT dor-()7t5 08/24/07 L2-32 11695060 RST . ,......" '.I,(~ -I~'+- .. 1."'\ /4/,. OS/23/07 1 L5-09 11492259 RST 1C}(')-1:J4 *' '<'(/1'+ 11/11/06 1 02-12B 11767132 MCNL ¡:)t....--:. _~~ .... I~ J.~ 06/21/07 1 18-09B 11366500 MCNL 1'\'1r ~* #- 1:",4 It::) 10/23/06 1 G-14A 11485777 MCNL /t1~ -lì"-'¡; 'it '-<:'-/QA 11/27/06 1 05-20B 10942220 MCNL .:JoLI- !::J:~ (./ it- 1."'..-4 JJ / 06/26/05 1 PLEASE ACKNOWLEDGE RECEIPT BY SI!i'.,.,.~!N.,......~.~.,.A.,. i'.~." ..-..r...... f".T...·~.,.!4.".,.I.!.GìD....'ij NE COpy EACH TO: BP Exploration (Alaska) Inc. ~,~, ~.. p ~=' [1 '\1' ~:_~ ¡,j Petrotechnical Data Center LR2-1 f¡~--- '~<. ~-- . 900 E. Benson Blvd. Anchorage, Alaska 99508 ('íD -:)[.1 II ¡007 Date Delivered: "V 'i'C-'" .'. '{' \.olllilli,,:,J1:-;O /\1i,m1m ¡.)i! .'" \:1,1:· ClliI., ' NO. 4406 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color CD 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATIN Be. W Received by: ' iL--- 09/10/07 . . í, E·:~· ~ &= m\/r: D~·\ . .. ~=:!J b"., n ~, [!"""", '''' Scblumbepger APR 2 U Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;0i~ Oil & Gas Cons. Cornm~ A.'1f~'ìf~ SCANNED APR 2 5 2007 f)û4-t)3(( Well Job# Log Description Date BL 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 OS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 OS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 OS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20107 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 0{ 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 7 r,k DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042340 Well Name/No. PRUDHOE BAY UNIT 05-20B Operator BP EXPLORATION (ALASKA) INC MD 11750 TVD 9031 Completion Date 1/7/2005 Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES / ABI Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name 1-----·· D Asc Directional Survey dY6 ¿jð D Asc Directional Survey ~g Injection Profile , Rpt ,.q.s;~ See-~ L~ ð V~ ..sg C :¡:;¡.p 13940 LIS Verification Log Log Run Scale Media No 2 Blu 1-4 dill C Lis 13940 Induction/Resistivity ¡'Ú> C Pdf 13940 I nd uction/Resistivity i~ C Pdf 13940 Neutron lM'c Pdf 13940 Neutron Wc Lis 14099 Induction/Resistivity i I._- Well Cores/Samples Information: Name 1-4 1-4 1-4 1-4 Interval Start Stop Sent Current Status 1-01L {j;i4d)r-~Y API No. 50-029-22137-02-00 UIC N --~----~---_. Directional Survey Yes -~_._-_.._----".- ----~_.._--_.- (data taken from Logs Portion of Master Well Data Maint Interval Start Stop 4494 11750 4494 11750 . OH/ CH Received Comments 1/27/2005 IIFR 1/27/2005 MWD 9098 11648 Case 8/30/2005 ·-0 4650 5/10/2006 6/8/2006 o -" 11749 4738 11750 Open 6/8/2006 4738 9031 6/8/2006 4738 11750 6/8/2006 4738 9031 6/8/2006 4660 11685 Open 8/30/2006 _.~------- Received Sample Set Number Comments Memory Injection log Memory GR/CCUSTP Pl<J.ytieal cor 1 S-Ju,,-~004 LIS Formation Evaluation 19-Jun-2004 Rap, DGR, EWR, HP 25- Dec-2004 DGR, EWR, 25-Dec-2004 CTN, SLD, DGR 25-Dec- 2004 CTN, SLD, DGR 25-Dec- 2004 GR, ROP, FET, NPHI, RHOB (T"i~ i:; a sendiJãck i of~a~-.¡}~~"J ~ ~r~~ . DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042340 Well Name/No. PRUDHOE BAY UNIT 05-20B API No. 50-029-22137-02-00 Operator BP EXPLORATION (ALASKA) INC MD 11750 TVD 9031 Completion Date 1/7/2005 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? ~ _ Analysis Y / N Received? Daily History Received? ~ &/N Formation Tops --_.._~~-~-~- ~....~- --.~'~---.---~~---'_._--_._--^ ~-_..._------_.._._'-~..."._----.,-_.---- ~~---~. _0' _____'..._______ -~---._-------,_._--- Comments: -~._---~--- r~--- ~=~~--..--=-_--===cc=~=--=---==--===--==D~~::·-=~Æk ~5-~~~~~~= Compliance Reviewed By: -----'-'- . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907 - 793-1005 August 28, 2006 RE: MWD Formation Evaluation Logs: 1E-104, CD3-302 PB1, 05-20B, 15-46 L1 PBI, MPK-09, MPE-31, MPC-43, MPE-25A. 1E-104 'J 04 -. Q';;)~ lQ.o,~L{ CD3-302 PB1 é)ö(o- 010 11..1101 OS-20B v QOI..I-:;34 , 4 oc¡ 0, 15-46 L1 PB1 QoL(-ID3 II..!lvÛ MPK-09 9c>õ- 0 '<'{ 14/104 MPE-31 do5'"- O"é},L./103 MPC-43 804- 03"1 14 10:;) MPE-25A tJ"I.C- GOL(-04S Jg,S-15~ Digital LIS DATA: 1 CD Rom 50-029-23234-00, 50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00,50-029-23200-00,50-029-22980-01. 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 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 1f!-=lo/dÞ Signed: (l<~L . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 15, 2006 RE: MWD Fonnation Evaluation Logs: 05-20B, AK-MW-3454678 OS-20B: Digital Log Images: 50-029- 2213 7 -02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 E>at;CE'VED JUN 0 8 2006 Signed: {\ d}J~------- Alaska Oil & Gas Cons. Commission Anchorage ,,)el/ _;)3(.( $. J 3CJ <fD . . Ðoc./~a3<{ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 April 21, 2006 RE: MWD Formation Evaluation Logs: 05-20B, AJe-MW-3454678 1 LDWG formatted Disc with verification listing. API#: 50-029-22137-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: SitS-IDe.. Signed: (i~R eo (,/- ';)3'{ ÔovY T:Y, tJk ~Lv?lCÅ0tJ S~~ Aø À( ~~ i0G, Scblumbepgep Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Well l-15 I'$'j,- (]f.,? L5-17A lry"í ~^.l3 DS 04-26 /J ~--)I'i S-14A :;t\¡i1- 07' G-27 / g t,- I r ~ DS 06-20B ~ t""j ._).,) I.( E-37A ;.{ (¡ r - \;¡t ^-- D-29 I ~ç- :trJ L2-28 II: r - c »- C-13A i q 7 -/1..1' ~ OWDW-SW/IJ t- J. 3 ð Õ6-08Al<1r-1 q r 12-29 J 31.{- t.3 '.}... ë-19B~G ,,:,- 0'::' r <;-27 i S¡ ~- / çlç F-02A ?. Ò~- - Co c.ì tj 03-33B ).. (!);j- - ¡j I ~ !JIPK.22 .:À (;1-;" 0.:1...2... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11084273 11075898 11072873 10893047 10942221 10942220 10928640 11084274 11076453 11075900 10893096 11062628 11072867 10928632 10942221 10928630 10913011 10893106 )1 Log Description PPROF W/DEFT/GHOST/CALlPER MEM PPROF W/DEFT/GHOST PRODUCTION PROFILE LEAK DETECTION LOG MEM PPROF & IPROF MEM INJECTION LOG MEM PPROF, IPROF & WARMBACK RST RST MCNL RST-BORAX CHANNEL DETECTION LOG RST RST MCNL MCNL MCNL US IT PDC-GR US IT Date 07/08/05 07/03/05 07/30/05 10/17/04 06/29/05 06/26/05 06/14/05 07/09/05 07/27/05 07/05/05 03/24/05 05/17/05 07/07/05 05/12/05 06/29/05 05/08/05 03/19/05 04/20/05 ~ .z.~~ \ -.~ 08/30/05 NO. 3460 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD . 1 i 3;1 J. 3 1 13:0.'1 1 iJ,1.)r 1 iJ).). ~ 1 ) 3 ~¡ 7 1 }.?1.J..8 1 1322'"/ 1 I Lt 3\:¡ 1 13.:Vi 1 1 ,),.). J 'J.. 1 . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 , Anchorage. AK 995g3..-2p38 ..._...., òj¡¡'''''. . ' ATTN: Beth "~~/ i. I .' .f ," I / , i Received by: · . -._- ~ , / . STATE OF ALASKA __ ALASK l AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 2OAAC25.105 20AAC25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2911' SNL, 5033' WEL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 4656' SNL, 4817' WEL, SEC. 32, T11 N, R15E, UM Total Depth: 1070' SNL, 3216' WEL, SEC. 05, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- ~~~.9__ y- _ 59~85~_ Zone-_ AS~__ TPI: x- 697598 y- 5946799 Zone- ASP4 Total Depth: x- 699248 y- 5945149 Zone- ASP4 --------------~- -------------- ---------- 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD DIR / GR / RES / ABI 22. One Other 5. Date Comp., Susp., or Aband. 1/7/2005 6.' Date Spudded 12/25/2004 7. Date T.D. Reached 1/3/2005 8. KB Elevation (ft): 62.6' 9. Plug Back Depth (MD+ TVD) 11663 + 9026 10. Total Depth (MD+ TVD) 11750 + 9031 11. Depth where SSSV set (Nipple) 2198' MD 19. Water depth, if offshore N/ A MSL CAsING Sill!: 20" 13-318" 9-5/8" 7" 4-1/2" GRADI!: H-40 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SeTrING DEPTH MD SernNG DEPTHTVD HOLE lOP BoTTOM I OP BoTTOM Sill!: Surface 115' Surface 115' 30" Surface 3512' Surface 3512' 16" Surface 4706' Surface 4706' 12-1/4" 4324' 8666' 4324' 8390' 8-1/2" 8480' 11750 8214' 9031' 6" WT. PER FT. 91.5# 68# 47# 26# 12.6# 23. Perforations open to Production (MD + TVD of T0.e and Bottom Interval, Size and Number; if none, state none"): 2-7/8" Gun Diameter, 6spf MD TVD MD TVD 9540' - 9860' 9017' - 9028' 9920' - 10290' 9028' - 9041' 10980' - 11180' 9044' . 9031' 11230' - 11400' 9028' - 9022' 11580' - 11650' 9023' - 9026' 26. Date First Production: January 27,2005 Date of Test Hours Tested PRODUCTION FOR 1/22/2005 6 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ....... Press. 936 1,900 24-HoUR RATE7 24. SIZE 4-1/2", 12.6#, L-80 25. 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204·234 13. API Number 50- 029-22137-02-00 14. Well Name and Number: PBU 05-20B 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028329 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMoUNT PULLED 2150 Lbs Poleset 1295 sx CS III, 400 sx Class 'G' 1420 sx Class 'G' 244 sx Class 'G', 179 sx Class 'G' 384 sx Class 'G' DEPTH SET (MD) 8484' PACKER SET (MD) 8423' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl GAs-McF WATER-BBl 645 3345 17 Oll-BBl 2,580 GAs-McF 13,378 WATER-BBl 66 CHOKE SIZE I GAS-Oil RATIO 87.28 5,184 Oil GRAVITY-API (CORR) 27. CORE DATA Brief ~escriptio~ of !ithology, porosity, fractures, apparent dips and pre. S..ence of oil, gas or water (attapb.s.....~. P¡µ,ª..._~.te..§h.,~.e.t,.if.n.~cessary). Submit core chips; If none, state "none". . r< r \. i' t"'~ ~ \ If-:· n rê~1¡ViPi.FrJ6N~ RBDMS 8Ft ~EB 0 8 200S,M ...... ,..... \i".~ .....~.# None ¡~/)}.A. FEB 0 4: 200J ; r.Z ~~ , ¡ . . ~¡E~ ~ Alask~ Oil .& (~ F Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE & 28. GEOLOGIC MARKER. 29. aRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None". NAME MD TVD Sag River 8677' 8401' None Shublik A Shublik B Shublik C 8715' 8736' 8754' 8436' 8456' 8472' Sadlerochit 8801' 8516' 42SB 8937' 8639' Top CGL Base CGL 8995' 9068' 8692' 8759' 23SB I Zone 2B 9140' 8822' 22TS 9180' 8854' 21TS I Zone 2A 9233' 8892' Zone 1 B 9334' 8953' TDF / Zone 1A 9610' 9022' HOT 10290' 9041' 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. /0' ^ ^ ;'A L1 tl~ Terne Hubble .....- O)V ~. ~ PBU 05-20B 204-234 Well Number Title Technical Assistant Date O:z· ()<¡..OS Permit No. I Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Dave Wesley, 564-5153 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 18: 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 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, Other (explain). FEf3 0 ':1: ITEM 27: If no cores taken, indicate 'None". ITEM 29: List all test information. If none, state "None'. Form 1 0-407 Revised 12/2003 Legal Name: 05-20 Common Name: 05-20 12/19/2004 FIT 12/23/2004 FIT 12/24/2004 FIT 12/31/2004 FIT (ft) (ft) (ppg) (psi) (psi) 9.80 (ppg) 4,730.0 (ft) 4,730.0 (ft) 9.40 (ppg) 3,500 (psi) 5,810 (psi) 23.64 (ppg) 4,706.0 (ft) 4,706.0 (ft) 9.80 (ppg) 368 (psi) 2,764 (psi) 11.31 (ppg) 8,687.0 (ft) 8,394.0 (ft) 8.40 (ppg) 720 (psi) 4,383 (psi) 10.05 (ppg) . . Printed: 1/10/2005 9:23:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/1 9/2004 1/7/2005 Spud Date: 3/26/1991 End: 1/7/2005 12/19/2004 00:00 - 13:00 13.00 MOB N WAIT PRE Standby @ J-pad with full crews waiting on weather and road clearing. Phase 2. 13:00 - 00:00 11.00 MOB P PRE PJSM. Move sub from J-pad to DS 5-20B 12/20/2004 00:00 - 08:30 8.50 RIGU P PRE Spot sub over the well. Raise the derrick. RU the rig floor. Spot the pits cuttings tanks and the rig camp. 08:30 - 09:00 0.50 RIGU P PRE Hold Pre-spud meeting with all hands. 09:00 - 10:30 1.50 RIGU P PRE RU DSM and pull BPV with lubricator. 200 psi on tubing and 0 psi on annulus. Install secondary annulus valve and circulation lines. Rig accepted 12/20/04 @ 1030 hrs. 10:30 - 14:00 3.50 WHSUR P DECOMP Open up tubing through choke and blleed diesel to cuttings box. Line up to pump down the annulus - unable to pump. Shut in the well and verify no ice plugs in the surface lines. Line up and open up to the tubing and attempt to circulate to cuttings box throught the choke - no returns. Bullhead tubing volume of 9.8 ppg brine down the tubing - 3 bpm, 300 psi. SI and monitor tubing pressure - 0 psi. RU and pump down annulus. Pressure increased to 3,000 psi with -8 bbls pumped. SI well. Pressure dropped off to 475 psi and held. No returns seen up the tubing or a pressure increase on the OA. Bleed off annulus pressure and RD circulation lines. 14:00 - 18:00 4.00 PULL N WAIT DECOMP Talk to town about plan forward. Wait on Slickline to arrive to pull GLM @ 5,201'. Performed injectivity test @ 0.5 bpm pumping in at 520 psi. Monitored tubing and OA pressures - 0 psi. Note: Surface casing @ 3,512' 18:00 - 23:00 5.00 PULL C DECOMP RU SLB Slickline. Change out SLB tools for rig use. 23:00 - 00:00 1.00 PULL C DECOMP RIH with slickline to pull dummy valve from GLM @ 5,201'. Some difficulty getting through the tree. 12/21/2004 00:00 - 02:30 2.50 PULL C DECOMP RIH with slickline to pull valve from GLM @ 5,201'. Pulled valve from GLM on 2nd try. Valve pulled from the GLM was an orifice valve. 02:30 - 03:00 0.50 PULL C DECOMP Pumped total 30 bbls, 9.8 ppg fluid down tubing at 3 bpm and 400 psi. Attempt to circulate - unsuccessful. 03:00 - 04:00 1.00 PULL C DECOMP RIH and pull valve from GLM @ 3,208'. POH. Valve pulled from 3,208' was a dummy valve. 04:00 - 05:00 1.00 KILL P DECOMP Circulate diesel freeze protect from the well through the GLM @ 3,208' with 9.8 ppg brine - 4 bpm @ 150 psi. 05:00 - 06:00 1.00 PULL C DECOMP RD SLB Slickline. 06:00 - 07:30 1.50 PULL C DECOMP Rig up circulating lines to tubing. Pump 45 bbl soap pill. Displace surface to surface at 12 bpm, 1450 psi. Monitor well - on vacuum. 07:30 - 08:00 0.50 WHSUR C DECOMP Install BPV and attempt to test from below. Pumping fluid away at 3 bpm, 400 psi. 08:00 - 09:00 1.00 WHSUR P DECOMP ND tree and adapter. Hold PJSM. Bleed off chemical injection line to tank. (2,200 psi). 09:00 - 10:30 1.50 WHSUR P DECOMP Wait on CIC to break and plug non-purged chemical injection line. Filling annulus with fresh water using charge pump. Losses at 15 bph. 10:30 - 11 :30 1.00 WHSUR P DECOMP PJSM with CIC. Disconnect chemical injection line. Pull tree and remove from cellar. 11 :30 - 12:00 0.50 WHSUR P DECOMP Measure RKB. Install blanking plug and check hanger threads. 12:00 - 15:30 3.50 BOPSUF P DECOMP NU DSA and BOP's. Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/1 9/2004 1/7/2005 Spud Date: 3/26/1991 End: 1/7/2005 12/21/2004 15:30 - 22:30 7.00 BOPSUF P DECOMP Rig up and test BOP with 4.5" and 3.5" pipe. Test to 250 psi low and 3,500 high. Record on circular chart. Note: Test witnessed by AOGCC Rep., Jeff Jones. 22:30 - 23:30 1.00 WHSUR P DECOMP Rig up DSM lubricator and pull BPV. 23:30 - 00:00 0.50 PULL P DECOMP Pump 20 bbls seawater to fill tubing. MU landing joint. 12/22/2004 00:00 - 01 :00 1.00 PULL P DECOMP Make up landing joint. Back out lock down screws. Pull hanger free. Tubing not free. Max pick up 140K. Rig up to circulate. 01 :00 - 03:30 2.50 PULL P DECOMP Displace well to 9.5 ppg brine at 3 bpm, 110 psi through GLM at 3,208'. Lost 110 bbls during displacement. Well static with pumps off. 03:30 - 04:30 1.00 PULL C DECOMP Rig up Schlumberger e-line. 04:30 - 05:00 0.50 PULL C DECOMP Schlumberger run in hole with 2.68" jet cutter. 05:00 - 06:00 1.00 PULL C DECOMP Cut tubing at 4,785' ELM. POOH. LD sheave, packoff and pump in sub. Install HT-40 XO. 06:00 - 06:30 0.50 PULL C DECOMP Make up TDS and pull tubing free with 150K indicated. Pull hanger to rig floor with 100K up weight. Well on light vacuum. Loss of 9 bbls in one hour. 06:30 - 07:30 1.00 PULL C DECOMP Rig down SWS, break control lines and chemical injection line. Break out and lay down hanger and landing joint. 07:30 - 08:30 1.00 PULL C DECOMP PJSM. Rig up control line spooling unit, power tongs and rig tongs. 08:30 - 18:30 10.00 PULL C DECOMP Lay down 4.5" and 3.5" tubing from 4,794' SLM. Up weight 85K and steady. Recovered: 70 jts 4.5" tubing 57 jts 3.5" tubing 1 - 3.5" tubing cut off joint - 16.63' 1 SSSV 1 GLM 127 clamps (All accounted for) 7 SS bands. Note: Scaly deposit coating tubing from 3,746' to 4,431'. 18:30 - 20:00 1.50 BOPSUPC DECOMP Rig up 4" test joint and test BOP's (upper and lower rams, Annular) to 250 psi low - 3,500 psi high. Pull test plug and install wear bushing. 20:00 - 21 :30 1.50 CLEAN C DECOMP Make up cleanout BHA. 21 :30 - 00:00 2.50 CLEAN C DECOMP Pick up 4" drill pipe to 3,772'. 12/23/2004 00:00 - 01 :30 1.50 CLEAN C DECOMP Continue picking up drill pipe for clean out run to 4,630'. PU weight = 120K, SO weight = 115K. Began taking weight, set down 40K over normal. Made up TDS and washed down single without difficulty. Well back flowing through drill pipe. 01 :30 - 02:30 1.00 CLEAN C DECOMP Circulate hole volume at 4,703'. 9.4 ppg brine, 300 gpm, 500 psi. At bottoms up saw sand and scale. Max fluid weight returned was 10.4 ppg. 02:30 - 03:00 0.50 CLEAN C DECOMP Rack back one stand in derrick and pick up last 3 singles of drill pipe. Wash down stand from derrick and tag tubing stump at 4,799' DPM. 03:00 - 04:00 1.00 CLEAN C DECOMP Circulate hi vis sweep surface to surface at 546 gpm , 1400 psi. Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 3/26/1991 End: 1/7/2005 12/19/2004 1/7/2005 12/23/2004 04:00 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 09:00 09:00 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 23:00 12/24/2004 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 04:00 04:00 - 07:30 07:30 - 11 :30 11 :30 - 12:00 12:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 21 :00 21 :00 - 23:00 Top of window at 4,706 Bottom of window at 4,722' Undergauge hole drilled to 4,738' WEXIT Pump sweep while reciprocating through window. PU 130K SO 135K RT 135K. WEXIT Take SPR's. Perform FIT with 9.8 ppg LSND mud to 369 psi / 11.3 ppg EMW (good test). WEXIT POOH from 4,738' to 982'. WEXIT Stand back HWDP and DC's. Lay down UBHO, bumper sub 1.50 CLEAN C 1.50 CLEAN C 0.50 CLEAN C 1.50 DHB C 3.00 DHB C 0.50 DHB C DECOMP DECOMP DECaMP DECaMP DECOMP DECaMP 2.50 DHB C DECaMP 2.00 DHB C 1.00 DHB C 1.00 DHB C 2.00 DHB C DECaMP DECOMP DECaMP DECOMP 1.00 DHB C DECaMP 1.00 CLEAN C DECOMP 1.00 CLEAN C 1.00 CLEAN C 0.50 CLEAN C 2.50 WHIP C 3.50 WHIP C DECaMP DECOMP DECaMP WEXIT WEXIT 4.00 WHIP C WEXIT 0.50 WHIP C WEXIT 6.00 STWHIP C WEXIT 1.00 STWHIP C 0.50 EV AL C 1.50 STWHIP C 2.00 STWHIP C Slip and cut drilling line. Service TDS. POOH with clean out assy to 316'. Lay down jars, stand back De's, laydown bit, mill, and bit sub. Pick up and make up RTTS BHA assembly to 295' RIH picking up drill pipe from 295' to 4,684'. Tag top of tubing stump at 4,799'. Break circulation. Set RTTS at 4,788'. Test casing to 3,500 psi for 30 minutes (good test). Bleed off pressure and attempt to establish injection rates. Pressured up to 3,000 psi and held, no injection noted. Release RTTS and pick up to 4,730'. Set RTTS and test casing to 3,500 psi for 10 minutes (good test). Attempt to establish injection rates without success, pressure built up to 3,000 psi and held. Release RTTS, pump dry job, blow down surface equipment. POOH with RTTS from 4,730' to 294'. Lay down BHA from 294'. Lay down RTTS. Make up EZSV BHA to 657'. RIH from 657' to 4,730'. PU Weight = 115K SO weight = 118K Set EZSV. Sheared off with 47K overpull. Set down 20K to test set. Tested 9-5/8" casing to 3,500 psi for 30 minutes (good test). Pump 45 bbl hi vis sweep. Displace well to 9.8 ppg LSND milling fluid. 365 gpm, 595 psi. PU weight = 115K - SO weight = 115K. POOH from 4,730' to 2,709'. POOH from 2,709' to 654' Stand back HWDP. Break off and lay down EZSV running tool. Pick up and make up whipstock / milling assembly to 1,006'. RIH with whipstock / milling assembly on 4" drill pipe. 1.5 minutes per stand running time. Tag EZSV at 4,730'. PU 140K SO 140K Rig up Gyro equipment and RIH with same on e-line. Orient tool face at 215 degrees azimuth. POOH with e-line and rig down Gyro equipment. Tag EZSV at 4,730'. Set bottom trip anchor with 25K down weight. Pick up 10K above neutral weight to verify whipstock set. Shear lugs with 45K down weight. Top of window at 4,706'. Mill window in 9-5/8" casing and 24' new hole from 4,706' to 4,738'. WOB7/10 TQ3/10 RPM115 400GPM 750 PSI. Recovered approximately 200 pounds of metal during miling operations. Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/19/2004 1/7/2005 Spud Date: 3/26/1991 End: 1/7/2005 12/24/2004 21 :00 - 23:00 2.00 STWHIP C WEXIT and mills. Note: Upper mill full gauge. 23:00 - 00:00 1.00 STWHIP C WEXIT Clean out under rotary table. Change out elevators. Pick up test joint and pull wear bushing. 12/25/2004 00:00 - 00:30 0.50 STWHIP C WEXIT PJSM. Flush BOP stack. 00:30 . 01 :30 1.00 STWHIP C WEXIT Lay down flush tool. Install wear bushing. 01 :30 - 05:00 3.50 STWHIP C WEXIT Make up 8.5" directional drilling assembly to 1,172'. Orient, initialize and shallow test MWD. 05:00 - 06:30 1.50 STWHIP C WEXIT RIH with drilling assembly from 1,172' to 4,628'. 06:30 - 07:30 1.00 STWHIP C WEXIT Service Drawworks and TDS. 07:30 - 08:30 1.00 STWHIP C WEXIT Rig up Sperry Sun E-line, Gyrodata and side door entry sub 08:30 - 12:00 3.50 STWHIP C WEXIT RIH with Gyro tool made 3 sets. Loss of E-Line power and signal. Wire pinched at side entry sub when tighting pack off. 12:00 - 14:00 2.00 STWHIP X SFAL WEXIT POOH with E-Line and rig down Sperry Sun E-Line unit. 14:00 - 17:00 3.00 STWHIP X SFAL WEXIT PJSM. Rig up SWS E-Line, Gyrodata and side door entry sub. 17:00 - 18:30 1.50 STWHIP X SFAL WEXIT RIH with Gryo. Check shot at 2,500'. Latch in and orient to 240 degrees right and pass through window to 4,726'. 18:30 - 20:30 2.00 DRILL C INT1 Wash undergauge hole from 4,726' to 4,738'. Gyro toolface erratic. Pull back to 4,628' and re-seat tool. RIH to 4,738'. 20:30 - 23:30 3.00 DRILL C INT1 Slide drill from 4,738' to 4,911'. 512 GPM, 1,790 PSI. UP WT = 150K, DN WT = 150K. AST = 2.07 23:30 - 00:00 0.50 DRILL C INT1 Blow down TDS and POOH from 4,911' to 4,628'. POOH with E-Line. 12/26/2004 00:00 - 02:30 2.50 DRILL C INT1 POOH with gyro and rig down same. 02:30 - 03:00 0.50 DRILL C INT1 RIH from 4,628' to 4,814' 03:00 - 03:30 0.50 DRILL C INT1 Ream from 4,814' to 4,911' 03:30 - 12:00 8.50 DRILL C INT1 Directional drill and survey with MWD-GR-DDS-PWD from 4,911' to 5468' w/ 545 gpm , 1850 psi, 70 rpm, 6-10 k wob, ART 3.8 hours, AST 3.8 hours Phase 3 weather conditions 12:00 - 14:30 2.50 DRILL X WAIT INT1 Circ Hole Clean at 210 spm 1550 psi 14:30 . 16:00 1.50 DRILL X WAIT INT1 Monitor well, Slugged pipe, POH inside 9 5/8" window, LD 27 Jts f/ 5468' - 4628' 16:00 - 20:30 4.50 DRILL X WAIT INT1 WOW Phase 3 weather conditions, Monitor well, circ across top of well w/ hole fill 20:30 - 21 :30 1.00 DRILL X WAIT INT1 RIH picking up 27 jts DP from 4,628' to 5,468'. No fill encountered. 21 :30 - 22:00 0.50 DRILL X WAIT INT1 Circulate bottoms up at 550 gpm, 2,300 psi. 22:00 - 00:00 2.00 DRILL C INT1 Directional drill and survey with MWD-GR-DDS-PWD from 5,488' to 5,640' w/ 550 gpm , 2300 psi, 70 rpm, 3-10 k wob, ART .97 hours, AST 0.0 hours Phase 2 weather conditions 12/27/2004 00:00 - 22:30 22.50 DRILL C INT1 Directional drill and survey with MWD-GR-DDS-PWD from 5,640' to 7,550' w/ 569 gpm , 3250 psi, 100 rpm, 10 k wob, ART 11.18 hours, AST 2.54 hours. 22:30 - 00:00 1.50 DRILL C INT1 Pump sweep around at 569 gpm, 3200 psi. Prepare for short trip. 12/28/2004 00:00 - 02:00 2.00 DRILL C INT1 POOH from 7,550' to 5,468'. Max overpull 25K. Hole in good shape. Run back to bottom. Precautionary wash last stand. No fill noted. Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1 2/1 9/2004 1 /7/2005 Spud Date: 3/26/1991 End: 1/7/2005 12/28/2004 02:00 - 12:00 10.00 DRILL C INT1 Directional drill and survey with MWD-GR-DDS-PWD from 7,550' to 8,112'. Weight up mud system to 10.3 ppg. UP Wt 200K, DN Wt 170K, RT Wt 180K, WOB 20, RPM 110, 560 GPM, 3250 PSI, ART 3.41, AST 1.42 12:00 - 20:00 8.00 DRILL C INT1 Directional drill and survey with MWD-GR-DDS-PWD from 8,112'toTDat8,667'. UPWt220K, DNWt170K, RTWt 185K, WOB 20K, RPM 110, 515 GPM, 3,400 PSI, ART 3.62, AST 4.57. 20:00 - 22:00 2.00 DRILL C INT1 Circulate sample for geology. Pump sweep and circulate hole clean. Monitor well. No losses. 22:00 - 23:30 1.50 DRILL C INT1 POOH from 8,667' to 4,814'. UP WT 220K, Max drag 15K. 23:30 - 00:00 0.50 DRILL C INT1 MAD pass from 4,814' to 4,679' 12/29/2004 00:00 - 00:30 0.50 DRILL C INT1 Complete MAD pass. 00:30 - 01 :30 1.00 DRILL C INT1 Slip and cut Drill Line 01 :30 - 02:30 1.00 DRILL C INT1 Service TDS, Dwks, and crown. 02:30 - 04:00 1.50 DRILL C INT1 RIH from 4,628' to 8,647'. No problems and no fill encountered. 04:00 - 04:30 0.50 DRILL C INT1 Wash down from 8,647' to bottom at 8,667'. 04:30 - 06:30 2.00 DRILL C INT1 Pump sweep. Circulate and condition hole for 7" liner run. Spot liner running pill. 06:30 - 10:30 4.00 DRILL C INT1 POOH from 8,667' to BHA. 10:30 - 15:00 4.50 DRILL C INT1 PJSM. Lay down BHA. Flush and download MWD and lay down same. Clean and clear rig floor. 15:00 - 17:30 2.50 CASE C INT1 Change upper pipe rams to 7" and test same to 250 psi low / 3,500 psi high. Good test. 17:30 - 18:30 1.00 CASE C INT1 Rig up casing equipment. 18:30 - 00:00 5.50 CASE C INT1 Make up 7" shoe track and check floats. Run 105 joints 7", 26# L-80, BTC-M liner. Make up packer, XO and space out pups to 4,375' 12/30/2004 00:00 - 00:30 0.50 CASE C INT1 Circulate one liner volume at 4,375'. 00:30 - 03:30 3.00 CASE C INT1 Run 7" liner in hole on 4" drill pipe. Make up cement head. Tag bottom at 8,667'. 03:30 - 04:00 0.50 CEMT C INT1 Circulate and condition while holding PJSM and batching up. UP Wt 215K, DN Wt 155K. 04:00 - 04:30 0.50 CEMT C INT1 Rig up and test lines to 4,500 psi. Good test. 04:30 - 06:30 2.00 CEMT C INT1 Shut Down And Turn Over To Dowell - Pump 27 BBLS 11.0 PPG Mud Push, Followed With 121 BBLS (279 Sacks) 11.5 PPG Class "G" Lead Cement At 5.7 BPM - Pump 37 BBLS of 15.8 PPG Class "G" Tail Cement - Wash Up Lines To Floor- Drop Dart And Displace With 10.3 PPG Mud At 8.0 BPM With 2,060 Psi. - Slow Rate And Latch Liner Wiper Plug With 43 BBLS Pumped Away - Increase Rate To 8 BPM Continue To Displace - Slow Rate To 4.5 BPM With Final Circulating Pressure At 1,524 Psi. - Bump Plug With A Total Of 206 BBLS Pumped. Increase Pressure To 3,000 Psi. To Set Baker Liner Hanger - Increase Pressure to 4,500 PSI to Set Packer. Bleed Off Pressure And Check Floats (Floats Held) 2.5 BBLS Back - Cement In Place At 05:30 Hours - Pressure Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs - As Pressure Decreases Ramp Up Pumps To 515 GPM And Circulate Out Cement With 10.3 PPG Mud. Trace Cement Back To Surface. 06:30 - 10:00 3.50 CEMT C INT1 Rig down cement head. POOH with 7" running tool and lay Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/19/2004 1/7/2005 Spud Date: 3/26/1991 End: 1/7/2005 12/30/2004 06:30 - 10:00 3.50 CEMT C INT1 down same. Clear and clean rig floor. 10:00 - 13:00 3.00 CEMT C INT1 Change top rams to 3X6 variables. Test rams to 250 psi low, 3,500 psi high. Install wear bushing. 13:00 - 15:00 2.00 DRILL C PROD1 Held PJSM - Make Up BHA No.3 - Pick Up Sperry Sun Motor, Set Bend to 1.83Make Up 61/8" Hughes MX18DHX Insert Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools. 15:00 - 16:00 1.00 CASE C INT1 Test 9-5/8" X 7" casing to 3,500 psi for 30 minutes. Good test. 16:00 - 16:30 0.50 DRILL C PROD1 Continue to make up BHA to 399'. Surface test MWD. 16:30 - 18:30 2.00 DRILL C PROD1 RIH picking up drill pipe from 399' to 2,639'. Test MWD. 18:30 - 21 :00 2.50 DRILL C PROD1 RIH from 2,639' to tag landing collar at 8,581'. 21 :00 - 22:30 1.50 DRILL C PROD1 Drill float equipment and cement from 8,581 to 8,665' UP Wt 170K, DN Wt 140K, RT Wt 150K, WOB 10K, RPM 40, GPM 252,1780 PSI, TQ 5K. 22:30 - 00:00 1.50 DRILL C PROD1 Pump 100 BBLS fresh water followed by 45 BBLS hi vis sweep. Displace well to 8.4 PPG Flo-Pro mud. 12/31/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Continue to displace well to 8.4 ppg Flo-Pro mud. Take SPR's. 01 :00 - 01 :30 0.50 DRILL P PROD1 Drill out shoe and rat hole. Drill 20' new hole to 8,687'. 01 :30 - 02:00 0.50 DRILL P PROD1 Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 100 psi 6 275 psi 10 400 psi 14 560 psi 18 720 psi Held Test F/ 10 minutes w/O Psi. Pressure Loss. MW 8.40 ppg, 7" Casing Shoe TVD 8,392' Pressure 720 psi = 10.04 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams 02:00 - 23:00 21.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 8,687' to 9,645' WOB 25K, RPM 40, Motor RPM 176, Torque Off Bottom 2K - On Bottom 5K, Pump Rate 315 gpm, Pressure 2,200 psi. UP Wt 180K, DN Wt 160K, RT Wt 170K- ART = 7.32 hrs. - AST = 8.11 hrs. 23:00 - 00:00 1.00 DRILL P PROD1 Pump hi Vis sweep. Circulate for bit trip. 1/1/2005 00:00 - 00:30 0.50 DRILL P PROD1 Complete circulation prior to bit trip. 00:30 - 04:00 3.50 DRILL P PROD1 POOH with directional BHA #3 from 9,645' To 400'. No overpull encountered. 04:00 - 06:00 2.00 DRILL P PROD1 Handle BHA #3. Download MWD tools and change out bit. Adjust motor. 06:00 - 08:30 2.50 DRILL P PROD1 PJSM. Pick up neutron/density tools, initialize and shallow test MWD. Load sources and lower below rig floor. Pick up remainder of BHA racked in derrick. 08:30 - 11 :30 3.00 DRILL P PROD1 RIH to 8,643'. Fill pipe and function/test MWD every 3,000 feet. 11 :30 - 12:00 0.50 DRILL P PROD1 Service rig and TDS. 12:00 - 12:30 0.50 DRILL P PROD1 RIH from 8,643' to 9,140'. 12:30 - 16:00 3.50 DRILL P PROD1 MAD pass from 9,140' to 9,645' at 200/300 FPH. 16:00 - 00:00 8.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,645' To 10,418'. WOB 25K, RPM 80, Motor RPM 189, Torque Off Bottom 2K - On Bottom 6K, Pump Rate 338 gpm, Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/19/2004 1/7/2005 Spud Date: 3/26/1991 End: 1/7/2005 1/1/2005 16:00 - 00:00 8.00 DRILL P PROD1 Pressure 2,250 psi. UP Wt 175K, DN Wt 155K, RT Wt 165K- ART = 4.10 hrs. - AST = 1.47 hrs. 1/2/2005 00:00 - 15:30 15.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,418' to 11,301'. UP Wt 175K, DN Wt 140K, RT Wt 160K, TO On 6K, TO Off 5K, 313 GPM, 2650 PSI, 7-10 WOB. Note: MWD Failure. 15:30 - 16:00 0.50 DRILL N DFAL PROD1 MWD lost signal. POOH to 9,100'. 16:00 - 16:30 0.50 DRILL N DFAL PROD1 Pump water slug to try to restart MWD. No success. 16:30 - 18:00 1.50 DRILL N DFAL PROD1 Pull up into casing at 8,643'. 18:00 - 19:00 1.00 DRILL N DFAL PROD1 Drop bar and open circulating sub. Circulate bottoms up at max rate. Flow check, well static. 19:00 - 20:00 1.00 DRILL P PROD1 Slip and cut drilling line. 20:00 - 23:00 3.00 DRILL N DFAL PROD1 POOH from 8,643' to BHA at 315'. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Lay down XO and Circ Sub. Flush BHA with water, rack back De's 1/3/2005 00:00 - 03:00 3.00 DRILL N DFAL PROD1 Changed out Pulser TM. Re-ran bit and motor. RIH with BHA to 425'. 03:00 - 07:30 4.50 DRILL N DFAL PROD1 RIH from 425' to 11,301 '. Encountered 3' fill on bottom. 07:30 - 21 :30 14.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,301' to 11,750'. UP Wt 175K, DN Wt 140K, RT Wt 160K, TO On 5-7K, TO Off 4-5K, 318 GPM, 2320 PSI, 7-10 WOB. ART 4.53 AST 3.21 21 :30 - 22:30 1.00 DRILL P PROD1 Circulate bottoms up at 340 gpm, 2,100 psi. 22:30 - 00:00 1.50 DRILL P PROD1 POH from 11,750' to 7" shoe at 8,665'. No difficulties or significant overpull noted. 1/4/2005 00:00 - 00:30 0.50 DRILL P PROD1 Service rig and TDS 00:30 - 02:00 1.50 DRILL P PROD1 RIH f/8,665' to bottom at 11,750'. No problems and no fill encountered. 02:00 - 04:00 2.00 DRILL P PROD1 Pump sweep around at 328 gpm, 2,245 psi. Spot liner running pill. Lay down drill pipe single. Blow down TDS. 04:00 - 05:30 1.50 DRILL P PROD1 POOH for 4.5" liner run f/11, 750' t/8667', no problems, well static. 05:30 - 06:00 0.50 DRILL P PROD1 Drop dart t/open circ sub, slug pipe, B/D TD (dart was used as a 1 7/8" rabitt). 06:00 - 08:30 2.50 DRILL P PROD1 POOH f/8667' t/434'. 08:30 - 11 :00 2.50 DRILL P PROD1 LDI BHA f/434' t/105', flush MWD tools w/FW, PJSM (nukes), remove nukes, LD BHA f/105', clear rig floor. 11 :00 - 14:00 3.00 CASE P PROD1 Test BOP's & related equipment t/250 psi low / 3500 psi high, withness waived by AOGCC (L. Gramaldi). 14:00 - 15:00 1.00 CASE P PROD1 RU liner running tools, PSJM f/liner job. 15:00 - 19:00 4.00 CASE P PROD1 MU fit equip & RIH w/4 1/2" liner to 3269'. 19:00 - 19:30 0.50 CASE P PROD1 MU liner hanger & running tool and RIH t/3280'. 19:30 - 20:00 0.50 CASE P PROD1 Circ liner vol at 3.2 bpm, 250 psi. 20:00 - 22:30 2.50 CASE P PROD1 Con't RIH w/liner to 8667' (7" shoe). 22:30 - 23:00 0.50 CASE P PROD1 Circ DP vol at shoe, 3.2 bpm, 400 psi. 23:00 - 00:00 1.00 CASE P PROD1 Con't RIH w/liner t/1 0,200' - no problems. 1/5/2005 00:00 - 00:30 0.50 CASE P PROD1 RIH w/liner f/1 0,200' t/11 ,750' - no problems. 00:30 - 01 :00 0.50 CASE P PROD1 RU cment rotary head, valves and hoses. 01 :00 - 02:00 1.00 CASE P PROD1 Tag TD @11 ,750', stage pumps to cementing rate of 5 1/2 bpm @ 1150 psi - no losses. 02:00 - 03:00 1.00 CASE P PROD1 Cement liner, pump 5 bbls water, test lines to 4500 psi, pump 20 bbl CW 100, pump 35 bbls 9.5 ppg mud push, pump 80 bbls Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/19/2004 117/2005 Spud Date: 3/26/1991 End: 117/2005 1/5/2005 02:00 - 03:00 1.00 CASE P PROD1 15.8 ppg cmt, wash lines w/perf pill, drop plug, displace plug w/60 bbls perf pill + 69 bbls mud, bumped plug at 129 bbls, CIP @03:00 hrs, pressure to 4000 psi t/set hanger, set dn 20k on hanger, bleed off pressure, floats held. 03:00 - 03:30 0.50 CASE P PROD1 Set liner top packer, rotate 15 RHT, pump to 1000 psi, un-sting f/liner, circ 500 stks to clear cmt, rotate dn 50k to set packer, shear @25k. 03:30 - 05:00 1.50 CASE P PROD1 Circ out excess cmt & displace well to seawater. 05:00 - 05:30 0.50 CASE P PROD1 LD cmt rotary head, valves and hoses. 05:30 - 09:00 3.50 CASE P PROD1 POOH f/8479', LD running tool, clear floor. 09:00 - 11 :30 2.50 CASE P PROD1 woe I load perf assembly in pipe shed. 11 :30 - 12:00 0.50 CASE P PROD1 Test 4 1/2" liner t/3500 psi, chart & hold f/30 min - OK. 12:00 - 16:30 4.50 PERF P OTHCMP PU & RIH w/2 7/8" perf guns to 3231'. 16:30 - 20:00 3.50 PERF P OTHCMP RIH w/DP and tag landing collar @11,661', PU t/11,650'. Perf Depths: 11,650' - 11,580' 11 ,400' - 11 ,230' 11,180' - 10,980' 10,290' - 9920' 9860' - 9540' 20:00 - 20:30 0.50 PERF P OTHCMP Pressure to 3000 psi to fire guns (closed pipe rams), bleed off and open rams, both firing heads fired (lost 9 bbls seawater). 20:30 - 21 :00 0.50 PERF P OTHCMP POOH to 9488' (above top perf), monitor well (3-6 bph loss rate). 21 :00 - 21 :30 0.50 PERF P OTHCMP Pump dry job / blow down all lines. 21 :30 - 00:00 2.50 PERF P OTHCMP POOH t/5751 , (LD DP 1x1). 1/6/2005 00:00 - 02:00 2.00 PERF P OTHCMP POOH f/5751, t/3231 , to top 2 7/8" pipe (LD DP 1x1). 02:00 - 03:00 1.00 PERF P OTHCMP POOH f/3231, t/2146' w/2 7/8" pipe to top of perf guns (LD 2 7/8" pipe 1 x 1). 03:00 - 06:00 3.00 PERF P OTHCMP PJSM - POOH & LD perf guns f/2146' t/1335'. 06:00 - 07:00 1.00 PERF P OTHCMP LD 2 7/8" DP f/1335' t/684'. 07:00 - 10:00 3.00 PERF P OTHCMP LD perf guns f/684' - clear & clean rig floor. 10:00 - 11 :00 1.00 PERF P OTHCMP MU mule shoe, RIH w/DP out of derrick to 5134'. 11 :00 - 12:00 1.00 PERF P OTHCMP Cut drlg line. 12:00 - 15:30 3.50 PERF P OTHCMP POH f/5134' - LD DP 1x1. 15:30 - 16:00 0.50 RUNCOMP RUNCMP Pull wear ring - MU & LD landing jt. 16:00 - 16:30 0.50 RUNCOMP RUNCMP RU to run 41/2" completion. 16:30 - 23:00 6.50 RUNCOMP RUNCMP RIH w/4 1/2" completion to 8490'. 23:00 - 00:00 1.00 RUNCOMP RUNCMP PU & space out w/3 tbg pups (9.78', 9.77', 7.78'), last jt tubing, MU hanger & landing jt to 8488' & land tubing. 1/7/2005 00:00 - 00:30 0.50 RUNCOMP RUNCMP RU to circulate & test lines. 00:30 - 03:00 2.50 RUNCOMP RUNCMP Reverse circ 130 bbls clean SW, 138 bbls inhibited SW, 167 bbls clean SW @ 3 bpm, 200 psi 03:00 - 04:30 1.50 RUNCOMP RUNCMP Drop ball & rod. Increase pressure to 3,500 psi and set the S-3 packer. Hold and chart for 30 minutes - good test. Bleed tubing pressure to 1,500 psi. Pressure up on the annulus to 3,500 psi. Hold and chart for 30 minutes - good test. Bleed off tubing pressure to shear the DCR valve in the upper GLM. Circulation established through upper GLM. 04:30 - 07:30 3.00 BOPSUR P WHDTRE Set BPV / ND BOP. 07:30 - 10:00 2.50 WHSUR P WHDTRE NU adapter flange and tree. Test tree to 5,000 psi - good test. 10:00 - 11 :30 1.50 WHSUR P WHDTRE Pull BPV with lubricator. Install test plug and test tree to 5,000 psi. Pull test plug and RD lubricator. Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/19/2004 Rig Release: 1/7/2005 Rig Number: Spud Date: 3/26/1991 End: 1/7/2005 1/7/2005 11:30-15:00 3.50 RUNCOMP 15:00 - 16:00 1.00 RIGD P WHDTRE RU circulation lines. RU LRHOS. Pressure test lines to 3,500 psi and freeze protect with 155 bbls of diesel and allow to u-tube. Set BPV and test to 1,000 psi from below. RD LRHOS. WHDTRE Remove secondary annulus valve. Secure the tree and the cellar. Rig released to 15-14A @ 1600 -1/7/2005. Printed: 1/10/2005 9:23:36 AM BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA 05-20B Job No. AKZZ3454678, Surveyec!: 3 January, 2005 Survey Report 18 January, 2005 Your Ref: API 500292213702 Surface Coordinates: 5948538.14 N, 697329.93 E (70015'48.8322" N, 148024'16.2860" 1111 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 62. 60ft above Mean Sea Level Spe!f""'f""'Y-SUf1 D. Ft fL.. L.I N SSE: Ft V I eE:S A Halliburton Company DEFI ITIVE . . Survey Ref: svy4474 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B Your Ref: API 500292213702 Job No. AKZZ3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 4494.60 0.400 243.400 4431.85 4494.45 21.59 S 15.36 W 5948516.16 N 697315.14 E 12.26 Tie On Point MWD+IIFR+MS 4706.00 0.280 258.870 4643.25 4705.85 22.02 S 16.53 W 5948515.70 N 697313.98 E 0.071 12.11 Window Point 4746.50 2.770 238.550 4683.73 4746.33 22.54 5 17.46 W 5948515.15 N 697313.06 E 6.196 12.16 4837.50 7.830 146.060 4774.41 4837.01 28.85 S 15.87 W 5948508.89 N 697314.82 E 9.248 18.50 4863.98 9.250 141.070 4800.60 4863.20 32.00 5 13.53 W 5948505.80 N 697317.24 E 6.044 22.37 . 4952.46 11.770 132.200 4887.59 4950.19 43.59 S 2.37W 5948494.50 N 697328.70 E 3.377 37.77 5046.68 14.890 149.470 4979.30 5041.90 60.49 S 10.90 E 5948477.96 N 697342.41 E 5.335 58.85 5140.05 17.750 162.010 5068.93 5131.53 84.37 S 21.40 E 5948454.36 N 697353.53 E 4.844 84.89 5234.65 19.840 170.520 5158.50 5221.10 113.935 28.50 E 5948425.00 N 697361.40 E 3.639 114.45 5328.29 21.630 174.020 5246.07 5308.67 146.77 S 32.91 E 5948392.28 N 697366.68 E 2.324 145.72 5418.58 23.480 178.650 5329.46 5392.06 181.31 S 35.07 E 5948357.81 N 697369.74 E 2.839 177.47 5512.75 23.980 178.550 5415.66 5478.26 219.19 S 36.00 E 5948319.97 N 697371.66 E 0.533 211.65 5608.01 23.580 177.830 5502.84 5565.44 257.58 S 37.21 E 5948281.62 N 697373.88 E 0.519 246.40 5702.50 23.800 178.130 5589.36 5651.96 295.53 S 38.55 E 5948243.73 N 697376.21 E 0.265 280.82 5795.42 24.510 177.850 5674.15 5736.75 333.53 S 39.88 E 5948205.77 N 697378.54 E 0.774 315.28 5889.15 24.000 174.760 5759.61 5822.21 371.94 S 42.35 E 5948167.44 N 697382.02 E 1 .459 350.63 5980.59 24.040 172.930 5843.13 5905.73 408.94 S 46.34 E 5948130.55 N 697386.98 E 0.816 385.41 6073.50 24.210 171.550 5927.93 5990.53 446.56 S 51.47 E 5948093.08 N 697393.09 E 0.634 421.26 6167.88 24.980 170.270 6013.74 6076.34 485.35 S 57.68 E 5948054.47 N 697400.31 E 0.992 458.64 6262.22 23.820 171.580 6099.66 6162.26 523.83 S 63.84 E 5948016.16 N 697407.48 E 1.357 495.72 6354.88 22.610 173.280 6184.81 6247.41 560.03 S 68.66 E 5947980.10 N 697413.25 E 1 .493 530.16 6450.15 22.570 172.800 6272.77 6335.37 596.36 S 73.10 E 5947943.90 N 697418.63 E 0.198 564.54 . 6544.75 22.830 175.320 6360.05 6422.65 632.66 S 76.87 E 5947907.71 N 697423.36 E 1.064 598.60 6639.09 23.460 174.020 6446.79 6509.39 669.58 S 80.32 E 5947870.90 N 697427.77 E 0.860 633.06 6732.57 23.630 173.450 6532.49 6595.09 706.70 S 84.40 E 5947833.90 N 697432.82 E 0.304 667.99 6824.80 23.050 173.490 6617.17 6679.77 743.005 88.55 E 5947797.72 N 697437.93 E 0.629 702.22 6916.20 22.780 173.220 6701.36 6763.96 778.35 S 92.67 E 5947762.49 N 697442.97 E 0.317 735.59 7009.44 23.600 177.890 6787.07 6849.67 814.93 S 95.49 E 5947725.99 N 697446.74 E 2.159 769.46 7103.72 22.870 177.480 6873.71 6936.31 852.09 S 96.99 E 5947688.88 N 697449.22 E 0.793 803.25 7196.82 24.790 177 .840 6958.87 7021.47 889.67 5 98.52 E 5947651.35 N 697451.73 E 2.068 837.43 7289.03 23.530 178.100 7043.00 7105.60 927.39 S 99.86 E 5947613.69 N 697454.06 E 1.371 871.64 7382.26 22.000 177.930 7128.96 7191.56 963.44 S 101.11 E 5947577.68 N 697456.25 E 1.643 904.33 7474.47 21.990 176.620 7214.46 7277.06 997.94 S 102.75 E 5947543.24 N 697458.80 E 0.532 935.81 7568.54 21.350 175.990 7301.88 7364.48 1032.60 S 104.99 E 5947508.65 N 697461.94 E 0.724 967.71 7662.42 21.880 174.310 7389.16 7451.76 1067.05 S 107.91 E 5947474.28 N 697465.77 E 0.868 999.74 18 January, 2005 - 8:01 Page 2 of 6 DrillQuest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B Your Ref: API 500292213702 Job No. AKZZ3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7756.92 23.860 173.320 7476.23 7538.83 1103.56 8 111.88 E 5947437.89 N 697470.70 E 2.134 1034.08 7850.18 23.270 170.770 7561.71 7624.31 1140.488 117.03E 5947401.12 N 697476.81 E 1.263 1069.31 7942.51 21.860 171.440 7646.97 7709.57 1175.488 122.52 E 5947366.27 N 697483.21 E 1.552 1102.98 8036.29 19.940 172.140 7734.58 7797.18 1208.598 127.30 E 5947333.30 N 697488.86 E 2.065 1134.66 8131.51 20.680 170.680 7823.88 7886.48 1241.278 132.25 E 5947300.77 N 697494.66 E 0.942 1166.02 8225.27 20.240 171.580 7911.72 7974.32 1273.65 S 137.30 E 5947268.53 N 697500.57 E 0.577 1197.16 . 8317.74 20.080 176.220 7998.54 8061.14 1305.31 S 140.69 E 5947236.96 N 697504.78 E 1.738 1226.91 8411.21 19.310 177.580 8086.54 8149.14 1336.76 S 142.40 E 5947205.57 N 697507.32 E 0.959 1255.71 8504.97 18.130 175.440 8175.34 8237.94 1366.80 S 144.22 E 5947175.59 N 697509.92 E 1 .456 1283.30 8598.76 18.390 174.530 8264.40 8327.00 1396.07 8 146.79 E 5947146.40 N 697513.25 E 0.411 1310.55 8689.48 20.720 174.170 8349.89 8412.49 1426.28 S 149.78 E 5947116.27 N 697517.04 E 2.572 1338.83 8736.16 22.230 174.020 8393.32 8455.92 1443.28 S 151.54 E 5947099.33 N 697519.24 E 3.237 1354.77 ~766.42 23.450 174.600 8421.21 8483.81 1454.975 152.70 E 5947087.67 N 697520.71 E 4.100 1365.71 8798.57 23.460 174.290 8450.70 8513.30 1467.71 S 153.94 E 5947074.97 N 697522.29 E 0.385 1377.62 8829.56 23.850 173.170 8479.09 8541.69 1480.07 S 155.30 E 5947062.65 N 697523.97 E 1.920 1389.25 8862.31 25.140 171.590 8508.89 8571.49 1493.52 S 157.11 E 5947049.25 N 697526.12 E 4.417 1402.06 8893.58 24.790 171.360 8537.24 8599.84 1506.57 S 159.06 E 5947036.25 N 697528.42 E 1.162 1414.58 8921.74 24.630 171.500 8562.82 8625.42 1518.21 S 160.82 E 5947024.66 N 697530.48 E 0.605 1425.75 8956.22 24.590 170.480 8594.17 8656.77 1532.40 5 163.06 E 5947010.54 N 697533.10 E 1.237 1439.40 8987.83 24.500 170.260 8622.92 8685.52 1545.34 S 165.26 E 5946997.66 N 697535.64 E 0.406 1451.94 9016.02 24.250 169.660 8648.60 8711.20 1556.80 S 167.29 E 5946986.26 N 697537.96 E 1.248 1463.06 9050.54 24.150 168.780 8680.09 8742.69 1570.705 169.94 E 5946972.44 N 697540.97 E 1.084 1476.65 . 9082.37 24.610 167.410 8709.08 8771.68 1583.55 8 172.65 E 5946959.66 N 697544.02 E 2.290 1489.34 9110.84 28.750 164.680 8734.51 8797.11 1595.95 8 175.75 E 5946947.35 N 697547.45 E 15.162 1501.79 9144.29 34.400 163.200 8763.00 8825.60 1612.77 S 180.61 E 5946930.66 N 697552.75 E 17.048 1518.98 9176.09 38.870 162.020 8788.51 8851.11 1630.87 S 186.29 E 5946912.72 N 697558.90 E 14.229 1537.69 9204.57 44.230 162.840 8809.82 8872.42 1648.87 S 191.98E 5946894.87 N 697565.06 E 18.917 1556.31 9234.55 49.490 162.610 8830.31 8892.91 1669.75 S 198.48 E 5946874.16 N 697572.10 E 17.554 1577.87 9266.29 51.740 162.200 8850.45 8913.05 1693.135 205.90 E 5946850.98 N 697580.13 E 7.159 1602.07 9297.86 53.390 163.150 8869.64 8932.24 1717.06 S 213.36 E 5946827.26 N 697588.22 E 5.747 1626.78 9331.09 57.420 163.860 8888.50 8951 .1 0 1743.29 S 221.12 E 5946801.25 N 697596.66 E 12.254 1653.67 9362.48 62.340 165.120 8904.25 8966.85 1769.44 S 228.37 E 5946775.29 N 697604.60 E 16.053 1680.26 9391.45 64.350 165.230 8917.25 8979.85 1794.47S 234.99 E 5946750.44 N 697611.87 E 6.947 1705.57 9423.50 69.900 164.070 8929.70 8992.30 1822.93 8 242.81 E 5946722.20 N 697620.44 E 17.634 1734.48 9454.51 73.680 163.490 8939.39 9001.99 1851.21 S 251.04 E 5946694.14 N 697629.40 E 12.318 1763.41 18 January, 2005·8:01 Page 3 of 6 Dril/Quest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B Your Ref: API 500292213702 Job No. AKZZ3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9485.10 78.200 162.870 8946.82 9009.42 1879.61 8 259.63 E 5946665.98 N 697638.73 E 14.906 1792.61 9516.00 82.200 161.470 8952.08 9014.68 1908.59 S 268.95 E 5946637.26 N 697648.81 E 13.693 1822.67 9548.15 85.060 159.620 8955.64 9018.24 1938.71 S 279.59 E 5946607.42 N 697660.24 E 10.575 1854.34 9578.31 87.650 156.060 8957.56 9020.16 1966.58 S 290.94 E 5946579.86 N 697672.32 E 14.577 1884.32 9605.01 86.980 154.750 8958.81 9021.41 1990.83 S 302.04 E 5946555.91 N 697684.05 E 5.506 1910.97 9638.22 86.610 149.570 8960.67 9023.27 2020.14 S 317.52 E 5946527.02 N 697700.29 E 15.613 1944.11 . 9697.46 85.740 148.690 8964.62 9027.22 2070.87 S 347.85 E 5946477.09 N 697731.94 E 2.087 2003.08 9727.70 87.350 147.110 8966.45 9029.05 2096.44 8 363.89 E 5946451.96 N 697748.64 E 7.453 2033.15 9759.72 91.170 145.410 8966.86 9029.46 2123.068 381.67 E 5946425.81 N 697767.11 E 13.057 2064.93 9791.22 91.850 145.390 8966.03 9028.63 2148.988 399.55 E 5946400.37 N 697785.66 E 2.160 2096.15 9885.10 89.260 145.110 8965.12 9027.72 2226.11 S 453.05 E 5946324.67 N 697841.17 E 2.775 2189.16 9978.19 88.150 144.280 8967.22 9029.82 2302.05 S 506.84 E 5946250.16 N 697896.93 E 1 .489 2281.25 10072.81 88.270 143.860 8970.18 9032.78 2378.63 S 562.33 E 5946175.06 N 697954.41 E 0.461 2374.67 10165.57 87.590 144.540 8973.53 9036.13 2453.82 S 616.56 E 5946101.32 N 698010.59 E 1.036 2466.28 10258.67 87.530 146.400 8977.49 9040.09 2530.44 S 669.28 E 5946026.11 N 698065.30 E 1.997 2558.49 10350.84 88.150 145.390 8980.97 9043.57 2606.71 S 720.92 E 5945951.22 N 698118.92 E 1.285 2649.88 10444.17 88.270 141.240 8983.88 9046.48 2681.50 S 776.64 E 5945877.92 N 698176.58 E 4.446 2741.82 10537.74 89.810 136.830 8985.45 9048.05 2752.12 S 837.96 E 5945808.92 N 698239.73 E 4.991 2832.59 10631.53 90.310 133.210 8985.35 9047.95 2818.45 S 904.25 E 5945744.35 N 698307.73 E 3.896 2921.78 10724.47 90.620 134.670 8984.60 9047.20 2882.94 S 971.17E 5945681.64 N 698376.32 E 1.606 3009.62 10817.44 89.510 133.220 8984.49 9047.09 2947.468 1038.10 E 5945618.90 N 698444.92 E 1.964 3097.49 10883.19 90.490 128.750 8984.49 9047.09 2990.57 S 1087.72 E 5945577.11 N 698495.66 E 6.960 3158.43 10911.02 90.370 125.400 8984.29 9046.89 3007.34 S 1109.92 E 5945560.92 N 698518.29 E 12.045 3183.46 . 10944.83 92.900 122.850 8983.32 9045.92 3026.30 8 1137.89E 5945542.70 N 698546.75 E 10.622 3213.05 10975.10 93.270 122.720 8981.69 9044.29 3042.67 8 1163.31 E 5945527.01 N 698572.58 E 1.295 3239.17 11003.79 93.710 121.200 8979.94 9042.54 3057.828 1187.60 E 5945512.49 N 698597.26 E 5.506 3263.70 11034.95 93.330 121.720 8978.03 9040.63 3074.068 1214.13 E 5945496.96 N 698624.21 E 2.064 3290.21 11097.28 93.950 121.870 8974.07 9036.67 3106.838 1267.00 E 5945465.58 N 698677.92 E 1.023 3343.41 11191.01 93.580 122.430 8967.92 9030.52 3156.608 1346.19 E 5945417.91 N 698758.38 E 0.715 3423.71 11224.61 93.710 122.710 8965.78 9028.38 3174.658 1374.44E 5945400.60 N 698787.10 E 0.917 3452.62 11255.45 93.700 122.510 8963.79 9026.39 3191.248 1400.37 E 5945384.70 N 698813.45 E 0.648 3479.17 11283.39 92.4 70 121.900 8962.29 9024.89 3206.11 8 1423.97 E 5945370.46 N 698837.44 E 4.913 3503.13 11376.89 91.050 120.730 8959.42 9022.02 3254.688 1503.81 E 5945323.99 N 698918.53 E 1.967 3582.65 11411.93 90.430 120.270 8958.96 9021.56 3272.46 S 1534.00 E 5945307.01 N 698949.17 E 2.203 3612.20 11442.00 90.310 120.250 8958.77 9021.37 3287.61 S 1559.97 E 5945292.54 N 698975.53 E 0.405 3637.50 18 January, 2005 - 8:01 Page 40f6 DrillQuest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B Your Ref: API 500292213702 Job No. AKZZ3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11470.30 89.940 119.960 8958.71 9021.31 3301.81 S 1584.46 E 5945278.99 N 699000.38 E 1.661 3661.26 11503.75 89.750 118.780 8958.80 9021.40 3318.21 S 1613.61 E 5945263.36 N 699029.95 E 3.573 3689.11 11564.61 88.330 119.450 8959.82 9022.42 3347.82 S 1666.77 E 5945235.15 N 699083.87 E 2.580 3739.62 11659.58 86.980 119.440 8963.70 9026.30 3394.46 S 1749.40 E 5945190.69 N 699167.69 E 1.422 3818.70 11680.48 86.730 119.230 8964.85 9027.45 3404.69 S 1767.59 E 5945180.95 N 699186.15 E 1.561 3836.07 11750.00 86.730 119.230 8968.81 9031.41 3438.58 S 1828.16 E 5945148.65 N 699247.58 E 0.000 3893.77 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Gk)bal Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 153.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11750.00ft., The Bottom Hole Displacement is 3894.36ft., in the Direction of 152.002° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 4494.60 4706.00 11750.00 4494.45 4705.85 9031.41 21.59 S 22.02 S 3438.58 S 15.36 W 16.53 W 1828.16 E Tie On Point Window Point Projected Survey . 18 January, 2005 - 8:01 Page 5 of6 DrillQuest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B Your Ref: API 500292213702 Job No. AKZZ3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Survey tool program for 05-20B Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 4494.60 0.00 4494.60 4494.45 11750.00 4494.45 MWD Magnetic (05-20PB1) 9031.41 MWD+IIFR+MS (05-20B) . . 18 January, 2005 - 8:01 Page 60f6 DrillQuest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA 05-20B (mwd) . Job No. AKMW3454678, Surveyed: 3 January, 2005 Survey Report 18 January, 2005 Your Ref: API 500292213702 Surface Coordinates: 5948538.14 N, 697329.93 E (70015'48.8322" N, 148024' 16.2860" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 62. 60ft above Mean Sea Level . SpSï'ï')J-SU'" bRILLING Se:RVlc:e:S A Halliburton Company Survey Ref: svy4475 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B (mwd) Your Ref: API 500292213702 Job No. AKMW3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4494.60 0.400 243.400 4431.85 4494.45 21.59 S 15.36 W 5948516.16 N 697315.14 E 12.26 Tie On Point 4706.00 0.280 258.870 4643.25 4705.85 22.02 S 16.53 W 5948515.70 N 697313.98 E 0.071 12.11 Window Point 4746.50 2.770 238.550 4683.73 4746.33 22.54 S 17.46 W 5948515.15 N 697313.06 E 6.196 12.16 4837.50 7.830 146.060 4774.41 4837.01 28.85 S 15.87 W 5948508.89 N 697314.82 E 9.248 18.50 4863.98 9.250 141.070 4800.60 4863.20 32.00 S 13.53 W 5948505.80 N 697317.24 E 6.044 22.37 4952.46 11.770 133.880 4887.59 4950.19 43.79 S 2.55W 5948494.30 N 697328.52 E 3.205 37.86 . 5046.68 14.890 148.240 4979.29 5041.89 60.75 S 10.75 E 5948477.69 N 697342.27 E 4.805 59.01 5140.05 17.750 160.910 5068.91 5131.51 84.41 S 21.73 E 5948454.33 N 697353.86 E 4.874 85.08 5234.65 19.840 169.430 5158.48 5221.08 113.83S 29.39 E 5948425.12 N 697362.29 E 3.642 114.77 5328.29 21.630 172.790 5246.06 5308.66 146.58 S 34.47 E 5948392.52 N 697368.23 E 2.295 146.25 5418.58 23.480 180.020 5329.45 5392.05 181.08 S 36.55 E 5948358.08 N 697371.22 E 3.689 177.94 5512.75 23.980 177. 680 5415.66 5478.26 218.96 S 37.32 E 5948320.23 N 697372.98 E 1.132 212.04 5608.01 23.580 177.470 5502.84 5565.44 257.34 S 38.95 E 5948281.91 N 697375.61 E 0.429 246.97 5702.50 23.800 179.660 5589.36 5651.96 295.29 S 39.89 E 5948244.00 N 697377.55 E 0.960 281.21 5795.42 24.510 179.380 5674.15 5736.75 333.31 S 40.21 E 5948206.00 N 697378.87 E 0.774 315.24 5889.15 24.000 176.720 5759.61 5822.21 371.78 S 41.51 E 5948167.57 N 697381.17 E 1 .286 350.11 5980.59 24.040 174.890 5843.13 5905.73 408.90 S 44.24 E 5948130.54 N 697384.87 E 0.816 384.42 6073.50 24.210 173.370 5927.93 z:::nnn 1:''') 446.67 S 48.12 E 5948092.88 N 697389.74 E 0.693 419.84 vvVV.J.:J 6167.88 24.980 171.630 6013.74 6076.34 485.61 S 53.26 E 5948054.09 N 697395.90 E 1.120 456.86 6262.22 23.820 170.400 6099.66 6162.26 524.10 S 59.34 E 5948015.77 N 697402.98 E 1.342 493.92 6354.88 22.610 172.810 6184.81 6247.41 560.23 S 64.69 E 5947979.80 N 697409.28 E 1.660 528.53 6450.15 22.570 171.240 6272.78 6335.38 596.47 S 69.76 E 5947943.71 N 697415.30 E 0.634 563.13 6544.75 22.830 176.330 6360.06 6422.66 632.73 S 73.70 E 5947907.56 N 697420.19 E 2.094 597.22 . 6639.09 23.460 175.870 6446.80 6509.40 669.72 S 76.23 E 5947870.64 N 697423.68 E 0.695 631.33 6732.57 23.630 172.780 6532.50 6595.10 706.87 S 79.92 E 5947833.61 N 697428.35 E 1.333 666.11 6824.80 23.050 172.300 6617.19 6679.79 743.10 S 84.66 E 5947797.51 N 697434.04 E 0.662 700.54 6916.20 22.780 174.050 6701.37 6763.97 778.43 S 88.89 E 5947762.30 N 697439.20 E 0.802 733.95 7009.44 23.600 176.880 6787.08 6849.68 815.02 S 91.78 E 5947725.80 N 697443.04 E 1 .484 767.86 7103.72 22.870 179.120 6873.72 6936.32 852.19 S 93.09 E 5947688.68 N 697445.32 E 1.216 801.57 7196.82 24.790 176.600 6958.88 7021.48 889.77 S 94.53 E 5947651.16 N 697447.74 E 2.334 835.70 7289.03 23.530 177.380 7043.01 7105.61 927.45 S 96.51 E 5947613.54 N 697450.72 E 1.410 870.18 7382.26 22.000 178.750 7128.97 7191.57 963.50 S 97.75 E 5947577.53 N 697452.89 E 1.737 902.86 7474.47 21.990 175.630 7214.48 7277.08 997.99 S 99.44 E 5947543.10 N 697455.49 E 1.267 934.36 7568.54 21.350 175.150 7301.90 7364.50 1032.61 S 1 02.23 E 5947508.56 N 697459.19 E 0.706 966.47 7662.42 21.880 175.570 7389.18 7451.78 1067.08 S 105.02 E 5947474.18 N 697462.88 E 0.588 998.45 18 January, 2005 - 7:58 Page 2 of 6 Dril/Quest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B (mwd) Your Ref: API 500292213702 Job No. AKMW3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7756.92 23.860 172.680 7476.25 7538.85 1103.60 S 108.82 E 5947437.78 N 697467.64 E 2.408 1032.71 7850.18 23.270 172.000 7561.73 7624.33 1140.558 113.79 E 5947400.97 N 697473.57 E 0.697 1067.89 7942.51 21.860 169.810 7646.99 7709.59 1175.53 8 119.37 E 5947366.14 N 697480.06 E 1.778 1101.59 8036.29 19.940 170.270 7734.59 7797.19 1208.48 S 125.16E 5947333.36 N 697486.72 E 2.055 1133.58 8131.51 20.680 168.910 7823.89 7886.49 1240.98 S 131.14 E 5947301.02 N 697493.55 E 0.922 1165.25 8225.27 20.240 171.360 7911.74 7974.34 1273.26 8 136.76 E 5947268.90 N 697500.01 E 1.027 1196.57 . 8317.74 20.080 175.080 7998.55 8061 .15 1304.89 S 140.52 E 5947237.38 N 697504.60 E 1.397 1226.46 8411.21 19.310 176.210 8086.55 8149.15 1336.30 S 142.92 E 5947206.05 N 697507.82 E 0.919 1255.53 8504.97 18.130 175.760 8175.35 8237.95 1366.32 S 145.02 E 5947176.09 N 697510.71 E 1.268 1283.23 8598.76 18.390 173.140 8264.42 8327.02 1395.56 S 147.87 E 5947146.94 N 697514.32 E 0.918 1310.58 8689.48 20.720 174.170 8349.90 8412.50 1425.73 S 151.21 E 5947116.86 N 697518.45 E 2.596 1338.99 8736.16 22.230 174.440 8393.34 8455.94 1442.74 S 152.90 E 5947099.90 N 697520.59 E 3.242 1354.91 8766.42 23.450 175.040 8421.23 8483.83 1454.44 S 153.98 E 5947088.24 N 697521.97 E 4.104 1365.82 8798.57 23.460 174.710 8450.72 8513.32 1467.188 155.12 E 5947075.53 N 697523.45 E 0.410 1377.69 8829.56 23.850 173.670 8479.10 8541.70 1479.55 S 156.38 E 5947063.20 N 697525.03 E 1.843 1389.28 8862.31 25.140 172.010 8508.91 8571.51 1493.02 S 158.08 E 5947049.77 N 697527.08 E 4.464 1402.06 8893.58 24.790 171.850 8537.26 8599.86 1506.09 S 159.93 E 5947036.76 N 697529.28 E 1.140 1414.54 8921.74 24.630 171.940 8562.84 8625.44 1517.748 161.59 E 5947025.15 N 697531.24 E 0.584 1425.68 8956.22 24.590 170.860 8594.18 8656.78 1531.94 S 163.74 E 5947011.02 N 697533.76 E 1.310 1439.30 8987.83 24.500 170.560 8622.94 8685.54 1544.90 S 165.86 E 5946998.12 N 697536.22 E 0.486 1451.81 9016.02 24.250 170.070 8648.62 8711.22 1556.37 S 167.81 E 5946986.71 N 697538.48 E 1.141 1462.92 9050.54 24.150 169.150 8680.10 8742.70 1570.28 S 170.37 E 5946972.86 N 697541.39 E 1.130 1476.48 9082.37 24.610 167.760 8709.09 8771.69 1583.168 173.00 E 5946960.06 N 697544.36 E 2.310 1489.14 . 9110.84 28.750 165.030 8734.53 8797.13 1595.57 8 176.02 E 5946947.73 N 697547.71 E 15.162 1501.58 9144.29 34.400 163.580 8763.02 8825.62 1612.42S 180.78 E 5946931.01 N 697552.90 E 17.042 1518.75 9176.09 38.870 162.450 8788.53 8851 .13 1630.56 8 186.33 E 5946913.02 N 697558.93 E 14.215 1537.43 9204.57 44.230 163.020 8809.83 8872.43 1648.598 191.93E 5946895.14 N 697565.00 E 18.867 1556.04 9234.55 49.490 163.380 8830.33 8892.93 1669.53 8 198.24 E 5946874.38 N 697571.86 E 17.567 1577.56 9266.29 51.740 162.810 8850.46 8913.06 1693.00 8 205.38 E 5946851.11 N 697579.61 E 7.223 1601.71 9297.86 53.390 163.730 8869.65 8932.25 1717.008 212.59 E 5946827.30 N 697587.45 E 5.716 1626.38 9331.09 57.420 163.980 8888.52 8951.12 1743.278 220.20 E 5946801.24 N 697595.74 E 12.143 1653.24 9362.48 62.340 165.660 8904.27 8966.87 1769.478 227.29 E 5946775.23 N 697603.52 E 16.342 1679.80 9391.45 64.350 165.060 8917.26 8979.86 1794.52 8 233.84 E 5946750.36 N 697610.72 E 7.181 1705.09 9423.50 69.900 164.280 8929.71 8992.31 1822.99 S 241.65 E 5946722.11 N 697619.27 E 17.461 1734.00 9454.51 73.680 163.520 8939.40 9002.00 1851.288 249.82 E 5946694.04 N 697628.18 E 12.410 1762.92 18 January, 2005 - 7:58 Page 3 of6 DrillQuest 3.03.06.008 BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B (mwd) Your Ref: API 500292213702 Job No. AKMW3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9485.10 78.200 162.660 8946.83 9009.43 1879.66 S 258.45 E 5946665.89 N 697637.55 E 15.025 1792.13 9516.00 82.200 161.550 8952.09 9014.69 1908.63 S 267.80 E 5946637.18 N 697647.66 E 13.420 1822.19 9548.15 85.060 159.740 8955.66 9018.26 1938.77 S 278.39 E 5946607.33 N 697659.04 E 10.509 1853.85 9578.31 87.650 157.330 8957.58 9020.18 1966.78 S 289.41 E 5946579.62 N 697670.78 E 11.719 1883.80 9605.01 86.980 154.800 8958.83 9021.43 1991.16 S 300.22 E 5946555.54 N 697682.24 E 9.792 1910.43 9638.22 86.610 149.300 8960.69 9023.29 2020.44 S 315.76 E 5946526.67 N 697698.53 E 16.573 1943.57 . 9697.46 85.740 147.250 8964.64 9027.24 2070.71 S 346.84 E 5946477.23 N 697730.92 E 3.752 2002.48 9727.70 87.350 145.670 8966.46 9029.06 2095.87 S 363.52 E 5946452.52 N 697748.25 E 7.453 2032.46 9759.72 91.170 144.100 8966.87 9029.47 2122.05 S 381.93 E 5946426.83 N 697767.34 E 12.898 2064.15 9791.22 91.850 145.980 8966.04 9028.64 2147.86 S 399.97 E 5946401.50 N 697786.06 E 6.345 2095.34 9885.10 89.260 146.410 8965.13 9027.73 2225.85 S 452.20 E 5946324.90 N 697840.31 E 2.797 2188.54 9978.19 88.150 144.280 8967.24 9029.84 2302.40 S 505.11 E 5946249.76 N 697895.21 E 2.580 2280.77 10072.81 88.270 144.690 8970.19 9032.79 2379.38 S 560.05 E 5946174.25 N 697952.15 E 0.451 2374.30 10165.57 87.590 152.590 8973.55 9036.15 2458.48 S 608.26 E 5946096.45 N 698002.41 E 8.542 2466.66 10258.67 87.530 148.840 8977.51 9040.11 2539.59 S 653.75 E 5946016.56 N 698050.01 E 4.025 2559.59 10350.84 88.150 148.330 8980.99 9043.59 2618.19 S 701.75E 5945939.24 N 698100.06 E 0.871 2651.42 10444.17 88.270 142.600 8983.91 9046.51 2695.01 S 754.62 E 5945863.84 N 698154.92 E 6.138 2743.86 10537.74 89.810 137.840 8985.48 9048.08 2766.88 S 814.46 E 5945793.55 N 698216.63 E 5.346 2835.07 10631.53 90.310 136.360 8985.38 9047.98 2835.59 S 878.30 E 5945726.55 N 698282.25 E 1.666 2925.27 10724.47 90.620 145.340 8984.62 9047.22 2907.58 S 936.92 E 5945656.11 N 698342.73 E 9.668 3016.03 10817.44 89.510 136.290 8984.52 9047.12 2979.57 S 995.60 E 5945585.69 N 698403.27 E 9.807 3106.81 10883.19 90.490 131.250 8984.52 9047.12 3025.04 S 1043.06 E 5945541 .48 N 698451.91 E 7.809 3168.87 10911.02 90.370 125.970 8984.31 9046.91 3042.40 S 1064.80 E 5945524.69 N 698474.10 E 18.977 3194.21 . 10944.83 92.900 125.060 8983.34 9045.94 3062.03 S 1092.31 E 5945505.79 N 698502.11 E 7.952 3224.18 10975.10 93.270 123.800 8981.71 9044.31 3079.12 S 1117.24 E 5945489.36 N 698527.48 E 4.333 3250.73 11003.79 93.710 127.110 8979.97 9042.57 3095.73 S 1140.56E 5945473.37 N 698551.23 E 11.617 3276.12 11034.95 93.330 127.000 8978.05 9040.65 3114.47 S 1165.38 E 5945455.28 N 698576.53 E 1.269 3304.08 11097.28 93.950 127.080 8974.10 9036.70 3151.94 S 1215.03E 5945419.13 N 698627.15 E 1.003 3360.01 11191.01 93.580 126.230 8967.94 9030.54 3207.77 S 1290.06 E 5945365.28 N 698703.62 E 0.987 3443.82 11224.61 93.710 131.760 8965.80 9028.40 3228.86 S 1316.11 E 5945344.88 N 698730.22 E 16.430 3474.44 11255.45 93.700 129.770 8963.81 9026.41 3248.96 S 1339.42 E 5945325.40 N 698754.04 E 6.439 3502.93 11283.39 92.4 70 128.760 8962.31 9024.91 3266.62 S 1361.02 E 5945308.32 N 698776.10 E 5.693 3528.4 7 11376.89 91.050 126.800 8959.43 9022.03 3323.87 S 1434.88 E 5945253.02 N 698851.43 E 2.588 3613.01 11411.93 90.430 125.800 8958.98 9021.58 3344.61 S 1463.12 E 5945233.03 N 698880.20 E 3.358 3644.31 11442.00 90.310 121.670 8958.79 9021.39 3361.30 S 1488.12 E 5945216.99 N 698905.63 E 13.740 3670.53 18 January, 2005 - 7:58 Page 4 0'6 Dril/Quest 3.03.06.008 . BP EXPLORA rlON (ALASKA) INC. Survey Report for 05-20B (mwd) Your Ref: API 500292213702 Job No. AKMW3454678, Surveyed: 3 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11470.30 89.940 121.470 8958.73 9021.33 3376.12 S 1512.23E 5945202.81 N 698930.12 E 1.486 3694.68 11503.75 89.750 115.070 8958.82 9021.42 3391.95 S 1541.68 E 5945187.76 N 698959.97 E 19.141 3722.16 11564.61 88.330 109.920 8959.84 9022.44 3415.23 S 1597.88 E 5945165.96 N 699016.77 E 8.776 3768.41 11659.58 86.980 109.600 8963.72 9026.32 3447.31 S 1687.18 E 5945136.23 N 699106.88 E 1.461 3837.54 11680.48 86.730 120.370 8964.87 9027.47 3456.11 S 1706.07 E 5945127.93 N 699125.99 E 51.467 3853.95 11750.00 86.730 120.370 8968.84 9031.44 3491.20 S 1765.95 E 5945094.42 N 699186.77 E 0.000 3912.41 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 153.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11750.00ft., The Bottom Hole Displacement is 3912.42ft., in the Direction of 153.168° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4494.60 4706.00 11750.00 4494.45 4705.85 9031 .44 21.59 S 22.02 S 3491.20 S 15.36 W 16.53 W 1765.95 E Tie On Point Window Point Projected Survey . 18 January, 2005 - 7:58 Page 50f6 DrillQuest 3.03.06.008 North Slope Alaska BP EXPLORA TION (ALASKA) INC. Survey Report for 05-20B (rowd) Your Ref: API 500292213702 Job No. AKMW3454678, Surveyed: 3 January, 2005 BPXA Survey tool program for 05-208 (mwd) Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 18 January, 2005 - 7:58 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11750.00 9031.44 MWD Magnetic (05-20B (mwd)) . . Page 6 of6 DrillQuest 3.03.06.008 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 5-208 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,494.60' MD 4,706.00' MD 11,750.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 t/1/ A._ r'\ 1J ð. Date ~ 7 JWV\.) ~ ~.r-' Signed ~ lJt~{ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) 18-Jan-05 ;;Lòtf- 2)'-( . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 5-208 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,494.60' MD 4,706.00' MD 11,750.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 c:.1/ J 0 I Date J 7 J "",Wij' Signed ~ .tl) Please call me at 273-3545 if you have any questions or concerns. Regards, Car' Ulrich Survey Manager Attachment(s) 18-Jan-05 )OLf--<)<{ U:hWH (PlO #2042340) Classified as Problem Well All, Well 05-208 (PTO # 2042340) has sustained pressure on the IA and has been classified as a Problem Well. The well was recently sidetracked and a new Gl valve design was installed. The well failed a TIFl on 01/29/05 with the TIO's = 2250/2300/0. The well is currently on-line. Current plans are to: 1. SLCcmfirmGlVs in pocket, eval for Gl V changeout 2. OHO:Re-TIFl . Àttachèd is the wèllbore schematic. Please call if you have anyque$tions. «05-208 DRlG DRAFT.ZIP» .ftnna (Du6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 05-20B DRLG DRAFT.ZIP Content-Type: applicationlx -zip-compressed Content-Encoding: base64 I of 1 2/3/2005 9:03 AM -, TREE :: 13-3/8",68.0#, L-80, 11' 311:12' ID::12.415" ;.J Top of 9-518" Whipstock - 4706' - I 9-5/8" HES EZSV - 4730'____ Tubing lî VIDEO) 7" LNR I· 9-5/8",47.0#, L-80, casing 10 8.681" 8620' Minimum JOINTS of 2 3/8" Liner 131/2", 9.3#, L-80, tubing, 10:: 2.992" 9265' I Top of 4 1/2" liner 17", 29#, L-80, liner. 979 0' ID:: 6.184" 41/2", 12.6#, L-80, 1-1 ID'" 3.953" I 10385' REV BY 1991 ORIGINAL RNITP JMITP COLLAPSED 06/18/02 08/18/03 12/21/04 kwi'! - I 4 1/2" - 'X' 3.813" 10 MD WD TYPE 5 3120 3120 0 4 1/2" X 1 1/2" MMG 4 4716 4716 0 41/2" X 1" MMG OV 3 6057 5976 24 41/2" X 1" MMG DV BK 2 7158 6986 24 41/2" X 1" MMG DV BK 1 8076 20 41/2" X 1" MMG wi / "'" 7",26#, L-80, liner - 8667' "0 Ga, L~ M"d,." "" Chemical Mandrel 1/2" I I REF LOG: MWO GR ON 01/03/05 ANGLE AT to 2· 7/8" 6 9540-9860 0 2-7/8" 6 9920-10290 0 01105/05 2-7/8" 6 10980-11180 0 2-7/8" 6 11230-11400 0 6 11580-11650 0 01/05/05 I 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' I DATE as T1 It Subject: RE: [Fwd: 05-20B Update to the current Sundry and Pennit to DriII] From: "Allen, Kenneth W (SSDS)" <AllenKW@BP.com> Date: Wed, 22 Dec 200415:38:20 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: James Regg <jim_regg@admin.state.ak.us> e Tom, Thanks for the quick review of these changes. Attached is an updated sheet including all the Production information along with the 4-1/2" cementing information you requested. Thanks again guys! Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allenkw@bp.com From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, December 22, 2004 2:48 PM To: Allen, Kenneth W (SSDS) Cc: James Regg Subject: Re: [Fwd: 05"'208 Update to the current Sundry and Permit to Drill] Ken, This acknowledges our conversation of a little while ago. I am reviewing the proposed changes to the abandonment ofDS 5-20A and the sidetrack DS 5-20B. As decompletion work has proceeded according to sundry 304-410, problems have been encountered. It has not been possible to pull the tubing as planned due to fill in the tubing x casing annulus. The tubing was successfully jet cut at about 4800' and the rig is presently laying it down. You are proposing to not attempt further fishing and P&A the DS 5-20A wellbore by setting a retainer at about 4730' and squeezing sufficient cement to effectively plug all the open tubulars. Your proposal to revise the P&A is acceptable. P&Aing the well at the shallower depth has resulting in a modification to the intended drilling plan. You will now be setting a fully cemented drilling liner between the window and the top of the Sag and then setting a fully cemented 4-1/2" production liner to TD. In the information you provided for the revision ofDS 5-20B, you did not include the 4-1/2" liner cementing information. It would be appreciated if you would respond to this message and send that information. Regardless, the plan you have submitted to revise the sidetrack is acceptable and you may proceed as planned. One thing you should note is that the well name and numbering information on the drawing for the "new" well is still listed as 5-20A. That information should be changed to 5-20B, with revision of the permit and API numbers as appropriate. Please call or message with any questions. Tom Maunder, PE AOGCC James Regg wrote: lof2 12/22/20043:57 PM e e I ask him to send changes in lieu of resubmitting a new sundry since work had not yet started and none of objectives change; they are kicking off shallower than was stated in approved sundry. Jim -------- Original Message -------- Subject: 05-20B Update to the current Sundry and Permit to Drill Date: Wed, 22 Dec 2004 12:02:16 -0900 From: Allen, Kenneth W (SSDS) <AllenKW(âjBP.com> To: .iim regg(âjadmin.state.ak.us Jim, Attached is the updated information for the Sundry P&A work and also the new information for a shallow kickoff and running 7" liner. Feel free to give me a shout on my cell phone if you have any questions. Please let me know if you are okay with all the operations. We are currently laying down tubing from ajet cut at 4,785'md. We should finish laying that down this afternoon. If you are OK with the updated P&A procedures we could be into the gauge ring runs and 9-5/8" testing by this evemng. Thanks for the help and sorry to do this to you on such short notice. Although, I guess we are somewhat lucky as we'll get this straightened out before the holidays. /* !Ken Allen/* / //Operations Drilling Engineer// Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allenkw(þ}bp.com<mailto:allenkw(â}bp.com> Updated information for Content-Description: production section of shallow KO plan.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 information for production section of shallow KO 2of2 12/22/20043:57 PM bp e e To: Jim Regg - AOGCC Date: December 21, 2004 From: Ken Allen - BPXA GPB Rotary Drilling Subject: Reference: 05-20A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22137-01 Approval is requested for the proposed P&A of PBU well 05-20A. Nabors 2ES is currently performing the previously approved work outlined in Sundry number 304-410. The decompletion phase has run into some problems. The IA is packed off somewhere between 5201'md and 3208'md. The pack off is mostly likely near the GLM at 5201 'md. The increased risk associated with successfully recovering the completion down to the original kick off point, along with the unknown 9-5/8" integrity, have led to the decision to abandon fishing attempts and sidetrack shallow. The well will be P&A'd as detailed in the outline below. The 05-20A P&A and 05-20B sidetrack will commence once the Sundry approval has been received. Rig Operations: 1. Mil RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to brine. Install TWC. 3. Nipple ?own th~ tree. Nipple up and test BOPE to 3,~00psi. Pull TWC.. IX L\ 'Q \4.ooI5L 4. RlU e-hne and Jet cut 3 %" tublng-4,800'md. RID e-hne. ~\v-:ã ~~..., ,~v ~ ... ~,).. 5. Pull the 4%" X 3 %" tubing from the jet cut at -4,785'md and above. ~ prepared to spool up the Bal-O SSSV control lines and the Chemical Injection line. The CI mandrel is at 8,20Tmd. Determine at what depth the Clline parted. 6. M/U spear assy. Make a spear run (picking up 4" DP) to fish control line if needed. POOH. 7. M/U 8.5" gauge milling assy. RIH picking up 4" DP from pipe shed (if not previously picked up) and drift 9-5/8" 47# casing. POOH. 8. M/U 9-5/8" RTTS. RIH to the top of the tubing stub, set and test 9-5/8" casing to 3500 psi from above. If test passes move on to the next stop of setting a 9-5/8" EZSV. If test fails pull up hole testing to find leak location. 9. M/U a 9-5/8" EZSV and mechanical setting tool. RIH and set -4,730'. Unsting from EZSV and pressure test 9-5/8" casing and EZSV to 3500 psi for 30 minutes. Record the test. Sting into the 9-5/8" EZSV and P&A 05-20A perforations by bull heading with 61 BBLS of 15.8ppg cement. a. Cement Calculations include the following: i. 90' of 9-5/8" casing = -6.6 BBLS 'II ii. 4341' of 3-1/2" TBG = -38 BBLS V iii. 1658' of 2-3/8" TBG = -6.4 BBLS f iv. Squeeze volume = -10 BBLS . v. Total volume to P&A is 61 BBLS 10. M/U a Baker 9-5/8" whip stock assembly with UBHO sub for gyro orientation. RIH to EZSV. RlU e-line <Z-.. and gyro tools. Orient as desired and set the whip stock on the EZSV. ~.~ "V 11. Shear free from the whip stock. Displace the well to 9.8ppg LSND drilling fluid. Verify that the mud (' . weight is at least 9.8ppg prior to cutting the window. '0 ( 12. Mill a window in the 9-5/8" casing at -4,710'md. Drill/mill approximately 20 feet beyond the middle of the window. Circulate the well clean. Pull into the 9-5/8" casing and conduct an FIT to 11.3ppg EMW. /' POOH. 13. MU the 8-1/2" drilling assembly with DIR/GR/DDS/PWD and RIH. Kick off and drill 8-1/2" intermediate interval as per directional plan. t ~ 05-20A Application for Sundry - Version 2.0 e e 14. Drill ahead weighting up to 10.3ppg by the top of the HRZ at -8300'md. Continue drilling to the 7" casing point at Top Sag River to an estimated depth of 8,654'md. 15. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to 4,560' MD. Set hanger 1 liner top packer and displace cement with mud. POOH. 16. M/U a 6-1/8" DIR/GR/RES/ABI drilling assembly. RIH to landing collar. / 17. Pressure test well bore to 3500 psi for 30 minutes. 0/ / 18. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0ppg. 0/' 19. Drill ahead, per directional proposal, to planned TD of -11 ,590'md. 20. Condition the hole for running 41/2", 12.6#, L-80, IBT-M liner. 21. Run and cement the 4 %" production liner, extending the liner lap to -8,504'md. POOH. 22. P/U and RIH with Schlumberger 2 %" DPC perforating guns. Perforate approximately 1,000' of Z1 A/1 B interval, per subsurface team. POOH. 23. R/U and run a 4 1/2", 12.6#, L-80, IBT-M completion, stinging into the 41/2" liner tie back sleeve. 24. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 25. Install a TWC. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 27. Freeze protect the well to -2,200'. Install BPV. Secure the well. 28. Rig down and move off. 0/ v Post-Ria Operations: 1. Mil RU slick line. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: Estimated Spud Date: Completed / Currently on well with Nabors 2ES . ..~. Ken Allen Operations Drilling Engineer 564-4366 05-20A Application for Sundry - Version 2.0 e e Updated information for shallow kick off option of 05-208 Hole Section: 8.5" Intermediate: Cased Hole: Open Hole: Required Sensors I Service Real time MWD Dir/GRlPWD/DDS throughout the interval. Two sample catchers. None planned None planned Mud Program Type LSND Hole Section I operation: I Density (ppg) I Viscosity I PV 9.8-10.0 45-55 12-16 Kick off from cement plug, drill 8-1/2" interval to THRZ YP I Tau 0 I API FL I pH 22 - 28 3 - 7 5 - 7 9.0 Type LSND Hole Section I operation: I Density (ppg) I Viscosity I PV 10.3 45-55 12-16 Drilling 8-1/2" interval from THRZ to section TD YP I Tau 0 I API FL I pH 22 - 28 3 - 7 4 - 5 9.0 Casing I Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size md/tvd md/tvd 8-1/2" 7" 26.0# L-80 BTC-M 4,094' 4,560' 14,559' 8,654' I 8,376' Casing String: Slurry Design Basis: Fluids Sequence I Volume: Test 9-5/8" casing 9-5/8" casing shoe 7" casing 7" casing shoe Cementing Program 7",26#, L-80, BTC-M long string Lead slurry: -3,594' of 7" X 8-1/2" annulus with 40% excess. Tail slurry: 500' of 7" X 8-1/2" annulus with 40% excess, plus -80' of 7", 26.0#, shoe track, plus 150' of 9-5/8" x 7" liner lap, plus 200' of 9-5/8" x 4" drill pipe annulus. Pre-Flush 15.0bbls CW100 Spacer 40.0bbls MudPUSH at 11.3ppg Lead Slurry 114.0bbl I 640 cf 1269 sx Class 'G', 12.0ppg; 2.38 cf/sk. Tail Slurry 35.0bbll 197cf 1170 sx Class 'G', 15.8ppg; 1.16 cf/sk. Casing I Formation Integrity Testing Test Point EZSV to surface 20' new fmn. beyond casing stub Float equipment to surface 20' new formation beyond shoe Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500psi surface 11 .3ppg EMW 3,500psi surface 10.0ppg EMW Hole CasinglTubing Wt. Size Size 6-1/8" 4 Y2" 12.6# Tubing 4W 12.6# Test 9 5/8" X 7" liner 7" window 4 W production liner e e Updated Production section CasinQ I TubinQ ProQram Grade Connection Length Top md I tvd 8,504' I 8,238' Surface L-80 L-80 IBT-M IBT-M 3,086' 8,504' CasinQ I Formation InteQritv TestinQ Test Point Float equipment to surface 20' formation beyond mid-window Float equipment to surface Test Type 30 min recorded FIT 30 min recorded Mud ProQram Type Flo-Pro Hole Section I operation: I Density (ppg) I Viscosity I 8.5 - 8.6 45 - 55 PV 8-12 Drilling 6-1/8" production interval YP I MBT I API FL 25 - 30 <3 4 - 6 MWD I LWD PrOQram Bottom md I tvd 11,590' 19,013' 8,504' I 8,238' Test pressure 3,500psi surface 10.0ppg EMW 3,500psi surface pH 9.0- 9.5 Hole Section: 6-1/8" production: Cased Hole: Open Hole: Required Sensors I Service Real time MWD Dir/GRlRes/ABI throughout interval. Two sample catchers. None planned None planned Casing String: Slurry Design Basis: Fluids Sequence I Volume: Cement PrOQram 41/2", 12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Tail slurry: 2,936' of 4 1/2" X 6-1/8" annulus with 40% excess, plus 80' of 4 1/2",12.6# shoe track, plus 150' of 7",26.0# X 4 W liner lap, plus 200' of 7", 26.0# X 4" drill pipe annulus. Pre-Flush 25bbls CW100 Spacer 35bbls MudPUSH at 9.6ppg Lead Slurry None planned Tail Slurry 71.4bbl 1402 cf 1344 sx Class 'G', 15.8ppg; 1.17 cf/sk. TREE = FMC GEN 4 WELLHEAD = FMC ACTUA TOR = OTIS KB. ELEII = 71' CB. ELEII = 34.1 KOP = 6936' <, ~~'_'M_A_A_ !V1ax Angle = 95 @ 10078' _'___A_A____AA__A_______~_A Datum ",10 = 9244' Datum TVD = 8800' SS 113-3/8",68.0#, L-80, 11 3512' casing 10 = 12.415" Icollapsed Tubing 11 5424' (06/13/02 VIDEO) I TOP OF 7" LNR H 8292' I 19-5/8".47.0#, L-80, 11 8620' casing 10 = 8.681" Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS TOP of 2 3/8" Liner H 9141' 13 1/2", 9.3#, L-80, 11 9265' tubing, 10 = 2.992" ¡Top of 41/2" liner H 9265' 17",29#, L-80, liner, 11 9790' 10 = 6.184" 141/2",12.6#, L-BO, 11 10385' liner, 10 = 3,953" DATE 1991 07/08198 02/27/02 06/18/02 08/18/03 10/27/04 OS-toA P&A e SAFETY NOTES: MAY NEED TO LIMIT INNER ANNULUS TESTING & OP PRESSURES. lNR DIDN'T PT TO 2000# (lOST 500# IN 30 MIN-ON 07/08/98 HO. 3-1/2" OTIS X NIP @ 9156' MlllEDW/2.81" Mill DRl'DTHRU PACK- OFF BUSHING 07/31/93. 700@ 9507' AND 90° @ 9747' - 4730' - 9-5/8" HES EZSV ',:"J, '"-~. - \' \JI a \ \ "ct<.....)\~u CJ...~ 0'\ ð'.)- - ~ GAS LIFT MANDRELS ST MD TVD DElI TYÆ VLV LATCH PORT DATE 1 3208 3208 0 TGPB TG 2 5201 5201 0 TGPB TG 3 6313 6313 0 TGPB TG 4 6902 6900 11 TGPB TG ~ 5 7430 7406 21 TGPB TG 6 7803 7742 27 TGPB TG I 7 8114 8021 26 TGPB TG CHEMJCAL MANDRELS I ST MD I TVDI DElli TYÆ VLV LATCH PORTI DATE I 1 8207 8104 26 MMG-7-LTS RK 9141' H2-3/8" DEPLOYMENT SLY, 10 = 1.969" I 9156' H3-1/2" OTIS XN NIP. 10 = 2.81" (BEHIND LNR) 9244' H 3-1/2" TIW OVERSHOT SEAL ASSY (BEHIND LNR) I 9255' H 7" X 3-1/2" TIW SS HY DRO SET PKR (BEHIND LNR) I ÆRFORA TION SUMMARY REF LOG: MIND GR ON 07/05/98 ANGLE AT TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9673-9805 0 07/07/98 1-11/16" 4 10057 -10760 0 07/07/98 I 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' I 12-3/8" LNR, 4.6#, L-BO, .00387 bpf, ID = 1.995" 11 10799' I REII BY COMMENTS ORIGINAL COMPLETION SIDETRACKED RNtTP CORRECTIONS JM/TP COLLAPSED TBG CMO/TLP ÆRF ANGLE CORRECTION dew Pre rig condition PRUDHOE BA Y UNIT WELL: 05-20A ÆRMIT No: 1971790 API No: 50-029-22137-01 SEe 32, T11N, RiSE, 3938.91' FEL & 5050.68' FNL DATE REV BY COMMENTS BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. ELBI = __.^ ~__. """ m" CB. ELBI = KOP= ~x Ang,le = Datum MD = ,- ~" Datum NO = FMC GEN 4 FMC OTIS 71' 34,1 6936' 95 @ 10078' 9244' 8800' 88 l13-3/8", 68.0#. L-80, 11 3512' casing 10= 12.415" Top of 9-5/8" Whipstock - 4710' - 9-5/8" HES EZSV - 4730'- COllapsed Tubing 11 5424' (06/13/02 VIDEO) TOPOF7" LNR H 8292' .- 19-5/8", 47.0#, L-80, 11 8620' casing ID = 8.681" Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS ¡ToP of 2 3/8" Liner H 9141' 13112".9.3#, l-80, 11 9265' tubing, to = 2.992" !TOP of 4 1/2" liner H 9265' 17",29#, L-80, liner, /1 9790' 10 = 6.184" 14 112", 12.6#, L-80, 11 10385' liner, JD = 3.953" DATE "¡.o' 1991 07/08198 02/27102 06/18/02 08/18/03 12/21/04 05-~X ~ Proposed Completion dO~~if<:'~ --I 2,200' H 4 1/2" - 'X' landing nipple I ST MD NO OBI lYÆ VALVE LA TCH 5 TBD TBO TBO 4112" X 1 1/2" MMG OCR RK -- 41/2" Xi" MMG DV RK --L. 4 TBD TBO TBO 3 TBD TBO TBO 41/2" Xi" MMG DV RK 2 TBO TBD TBD 4112" Xi" MMG OV RK 1 TBD TBD TBO 4 1/2" Xi" Mrv1G DV BK 8,419' H 4 1/2" - 'X' landing nipple 8,439' H 4 1/2" X 7" Baker 8-3 Pkr 8,459' i 4 1/2" - 'X' landing nipple 8,479' H 41/2" - 'XN'landing nipple 8,504' H 4 1/2", 12.6#, L-80, IBT-M 5" X 7" Baker HMC liner 8,504' hanger, ZXP liner top packer w / Tie Back Sleeve. / ~'L_SO' no,,- 8654' ~ ~ Gas Lift Mandrels .. ~ Chemical Mandrel I 11,590' H4 1/Z", 1Z.6#, L-80, IBT-M liner 9141' HZ-3/8" DEPLOYMENT SLV, 10 = 1.969" I 9156' 1-f3-1/2" OTIS XN NIP, 10 = 2.81" (BEHIND LNR) 9244' H 3-1/Z" TIW OVERSHOT SEAL ASSY (BEHIND LNR) I 9255' H 7" X 3-1/2" TIW S8 HYDRO SET PKR (BEHIND LNR) I ÆRFORA TION SUMMARY REF LOG: rv!\ND GR ON 07/05/98 ANGLE AT TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057-10760 0 07/07/98 I 7" X 4-1/2" MIL LOUT WINDOW - 9323' - 9331' I 12-3/8" LNR, 4.6#, L-80, .00387 bpf, ID= 1.995" 11 10799' I REV BY COMMENTS ORIGINAL COM PLETION SIDETRACKED RNlTP CORRECTIONS JMlTP COLLA PSED TBG CMO/TLP ÆRF ANGLE CORRECTION kwa Proposed PM PRUDHOE BAY UNrr WELL: 05-20;( \?:> ÆRMrrNo:~ dOL..\-.;}~ API No: 50-029-22137-09.., SEC 32, T11 N, R15E, 3938.91' FEL & 5050.68' FNL DATE RBI BY COMMENTS BP Exploration (Alaska) COMPANY DETAII.s REFERENCE INFORMA T]ON BPAmoc{\ 62.60 Depth I'm Depth To &Jrveyif'lm\ 47!O.O() I IS9Ü 10 Plannl'Ó: OS·20B wp06 ~hu!l,,\\' K SURVEY PRfXìRAM CAS]NG DETAILS No TVD MD Name Size 8376.60 8654.01 7" 7.000 901261 1]59000 41/2'· 4500 StntD" i21100' 4710· MD. 4709.85'TVD Start D" 00': 4730· MD, 4729. 84'TV _._-~ End if : 525L26'MD, 5236.33'-T D 6300- ., 5 ¢: o o 2:c -" Õ. ~ Q ~ 7200- 13 > " 2 f- 8100- 9000 , 05-20B T4 I ¡ ¡ ¡ I ¡ J I j I ¡ I o ! I ¡ I ¡ I I t Vertical SecÜon al ] 53.02" [900ft/in] \ Sec MD Ine I 4710.00 2 4730.00 3 5251.26 4 9040.88 5 9600.3] 6 9691.55 7 10135.71 8 10161.58 9 ]0201.00 10 ]0478.10 11 10731.17 12 11001.40 13 11590.10 4112" Too! MWDilFRiMS NlUl1e 'E-·W Northing Phm: 05~2üB wpü6 Sh¡:¡!l(JVi K/O (05-2(j/P]ar¡ OJ-2m3) Created Hy: Digital Bu.<;ìnc$s C!ícnlllsl.'T Date: J212¡/2004 Cln;çkeJ Date Reviewed Dull> WEIJ.DETA!J.S !:.ss!ìng Lu!i!ude Longitude Slot 05-20 1335.65 '(,3'J9 5048538.14 697329-93 7()' 15'4~.8J2N !48'24'!6,286W N/A Azi TVD 4709.85 4729.84 TARGET DETAILS Name TVD +N!-S +EJ-W Northing Eastìng Shape 05-20B T4 90]2.60 -33 J3.67 J 686 90 699103.00 Point 05,20B TI rev 9030.60 697672.23 Point 05,20B T2 9039.60 697966.00 Point 05-20B 13 9048.60 5945632.00 698328.00 Point J I I ¡ I ¡ I t 9041. 84 9012.60 SECT]ON DETAILS ,21.99 +N/-S I 1686.90 +EI-W -16.55 -16.87 ,I DLeg TF ace VSec Target 0.00 0.00 12.00 ,47.00 4.00 -48.50 0.00 0.00 12.00 05-20B TI rev 12.00 0.00 6.00 05-20B T2 6.00 0.00 2787.34 6.00 05-20B T3 6.00 -7975 000 0.00 05,20B T4 FORMATION TOP DETAILS No TVDPalh MDPath Formatìon I TSGR 2 TSHA 3 TSHB 4 8450.68 TSHC 5 8485.94 TSAD 6 8603.20 8899.55 42SB 7 8663.65 8965.05 TCGL 8 8724.64 903L14 BCGL 9 8807.60 9]24.41 23SB 10 8833.60 9155.89 22TS II 8894.60 9236.80 2ITS 12 8963.60 9350.58 TZ]B!"]4N" 13 8975.60 "14p·· CP 14 8989.60 13N 15 8997.60 9428.17 "UP" 16 9013.60 9478.99 TDF COMPANY DETAILS BPAmüÇ(1 REFEIŒNCE INFORMATJON 62,60 -600 Start Di 4/100' End Dir 5251.26' MD, 5236.33' 12IJOO' . 9040,88' MD. 733.63'TVD "2 -1200- ;2 o :s :£ ..c t ~ ~ o if) 6/lO0' ]0135.7]'MD,9 9,ITTVD Dir, 10201'MD, 9040.3 'TVD 10 8.1'MD,9046'TVD -300O---.~ 05-20B T4 4 II2" I I ¡ ¡ I I I I I I ! ¡ I ¡ ¡ I I I j ¡ o 600 I I I ]800 I I ! ¡ ..- SURVEY PROGRAM Plan: 05-20B wp06 .shaBo\\' KIn (05·20IPkm 05-2(13) Depth Fm Depth To Survey/Plan 47]0.00 U:59Ü,JO Plal\!1ed:()S--20B\Vp06sha]!owK fooJ Created By: J)jgi¡¡¡j !¡u;-Únegg Chent [iser Date-: !2/21120().j MW[}rlFR~MS Checked Date --'--~--~.- WE! J. DETAILS NaH\<' ·'N,'-$ Northing E"L~ii¡¡g ta.lilud" Longitude Slot 05-2Ü ßJ5.65 --63,')<,) 59485J¡'\'!4 <i97329,9J 70'¡5'48Jß2N 14S''24'!6.236W nA TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape 05-20B T4 9012,60 1686,90 699103,00 Point 05-20B Geo Poly 9030,60 697675,00 Po]ygon 05-20B TI rev 9030,60 697672.23 Point 05-20B T2 9039,60 697966.00 Point 05-20B T3 9048.60 698328,00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TF ace VSec Target I 4710,00 -1655 0,00 0,00 2 4730,00 12,00 -47.00 3 5251.26 4,00 -48,50 4 9040,88 0,00 0,00 5 9600.31 12.00 -14.11 05-20B T I rev 6 9691.55 12,00 -90,58 7 10135.71 000 0,00 8 lO16L58 6,00 -92.81 05-20B T2 9 10201.00 6,00 -94.13 10 10478,10 000 0,00 11 10731I7 6,00 -85,69 05-20B T3 12 11001.40 6.00 -79.75 13 ]]590,10 0,00 0,00 05-20B T4 CASING DETAILS No TVD MD Name Size 7" 41/2" MD, 9012,6' TVD FORMATION TOP DETAILS No, TVDPaih MDPath Formation I 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 I I ' 3600 I I ) ¡ I ¡ ¡ ! West(-)/East(+) [600t1Jìn] e e Sperry-Sun BP Planning Report Company: Field: Site: Well: Wellpatb: BP Amoco Prudhoe Bay PB DS 05 05·20 Plan 05-20B Date: 12/21/2004 Time: 16:41:43 Page: Co-ordinate(NE) Reference: Well: 05-20, True North Vertical (TVD) Reference: 28.5KB+34.1 OGL 62.6 Section (VS) Reference: Well (0.00N,O.OOE,153.02Azi) Survey Calculation Metbod: Minimum Curvature Db: Orade Plan: 05-20B wp06 shallow KIO Date Composed: Version: Tied-to: 9/2312004 32 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: 70 15 Longitude: 148 24 Nortb Reference: Grid Convergence: 35.696 N 14.424 W True 1.50 deg Well: 05-20 Slot Name: Well Position: +N/-S 1335.65 ft Nortbing: 5948538.14 ft Latitude: 70 15 48.832 N +E/-W -63.99 ft Easting : 697329.93 ft Longitude: 148 24 16.286 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 8654.01 8376.60 7.000 8.500 7" 11590.00 9012.61 4.500 6.250 41/2" Formations MD TVD Formations Litbology Dip Angle Dip Direction ft ft deg deg 8653.71 8376.32 TSGR 0.00 0.00 8696.71 8416.01 TSHA 0.00 0.00 8717.20 8434.92 TSHB 0.00 0.00 8734.28 8450.68 TSHC 0.00 0.00 8772.49 8485.94 TSAD 0.00 0.00 8899.55 8603.20 42SB 0.00 0.00 8965.05 8663.65 TCGL 0.00 0.00 9031.14 8724.64 BCGL 0.00 0.00 9124.41 8807.60 23SB 0.00 0.00 9155.89 8833.60 22TS 0.00 0.00 9236.80 8894.60 21TS 0.00 0.00 9350.58 8963.60 TZ1 Bf'14N" 0.00 0.00 9375.20 8975.60 "14P" CP 0.00 0.00 9407.38 8989.60 13N 0.00 0.00 9428.17 8997.60 "13P" 0.00 0.00 9478.99 9013.60 TDF 0.00 0.00 Targets Map Map <-- Latitude -> <-- Longitude --> Name Description TVD +N/-S +E/-W Nortbing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft 05-20B T4 9012.60 -3313.67 1686.90 5945270.00 699103.00 70 15 16.240 N 148 23 27.216 W 05-20B Geo Poly 9030.60 -1868.65 296.22 5946678.00 697675.00 70 15 30.454 N 148 24 7.668 W -Polygon 1 9030.60 -1868.65 296.22 5946678.00 697675.00 70 15 30.454 N 148 24 7.668 W -Polygon 2 9030.60 -1944.65 371.26 5946604.00 697752.00 70 15 29.707 N 148 24 5.485 W -Polygon 3 9030.60 -2693.20 838.82 5945868.00 698239.00 70 15 22.344 N 148 23 51.884 W -Polygon 4 9030.60 -2843.25 990.95 5945722.00 698395.00 70 15 20.868 N 148 23 47.459 W -Polygon 5 9030.60 -3228.43 1755.16 5945357.00 699169.00 70 15 17.079 N 148 23 25.230 W -Polygon 6 9030.60 -3414.64 1684.26 5945169.00 699103.00 70 15 15.247 N 148 23 27.294 W -Polygon 7 9030.60 -3061.45 919.21 5945502.00 698329.00 70 15 18.722 N 148 23 49.547 W Company: Field: Site: Well: Wellpatb: Targets Name -Polygon 8 -Polygon 9 -Po1Y90n 10 -Polygon 11 05-20B T1 rev 05-20B T2 05-20B T3 BP Amoco Prudhoe Bay PB DS 05 05-20 Plan 05-20B Plan Section Information MD ft 4710.00 4730.00 5251.26 9040.88 9600.31 9691.55 10135.71 10161.58 10201.00 10478.10 10731.17 11001.40 11590.10 Survey MD ft 4710.00 4730.00 4800.00 4900.00 5000.00 5100.00 5200.00 5251.26 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 Incl de¡¡ 0.28 2.60 22.65 22.65 89.17 89.08 89.08 89.00 88.83 88.83 90.00 92.85 92.85 Incl deg 0.28 2.60 4.92 8.74 12.67 16.63 20.61 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 22.65 Description Dip. Dir. Azim deg 259.29 216.79 172.98 172.98 160.00 149.05 149.05 147.50 145.14 145.14 130.00 114.03 114.03 Azim deg 259.29 216.79 191.54 181.08 177.00 22.65 22.65 22.65 22.65 22.65 174.84 173.49 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 172.98 TVD ft 9030.60 9030.60 9030.60 9030.60 e Sperry-Sun BP Planning Report +N/-S ft -2886.84 -2057.92 -1963.10 -1868.68 9030.60 -2000.00 9039.60 -2485.10 9048.60 -2931.46 TVD ft 4709.85 4729.84 5236.33 8733.63 9030.60 9032.00 9039.17 9039.60 9040.35 9046.00 9048.60 9041.84 9012.60 TVD ft 4709.85 4729.84 4799.69 4898.96 4997.20 5093.93 5188.68 5236.33 5281.31 5373.59 5465.88 5558.17 5650.45 5742.74 5835.03 5927.31 6019.60 6111.89 6204.17 6296.46 6388.74 6481.03 6573.32 6665.60 6757.89 +N/-S ft -21.99 -22.37 -132.67 -1581.22 -2000.00 -2082.23 -2463.10 -2485.10 -2517.90 -2745.23 -2931.46 -3074.22 -3313.67 Sys TVD ft 4647.25 4667.24 4737.09 4836.36 4934.60 5031.33 5126.08 5173.73 5218.71 5310.99 5403.28 5495.57 5587.85 5680.14 5772.43 5864.71 5957.00 6049.29 6141.57 6233.86 6326.14 6418.43 6510.72 6603.00 6695.29 e Date: 12/21/2004 Time: 16:41 :43 Page: 2 Co-ordinate(NE) Reference: Well: 05-20, True North Vertical (TVD) Reference: 28.5KB+34.10GL 62.6 Section (VS) Reference: Well (0.00N,0.00E,153.02Azi) Survey Calculation Metbod: Minimum Curvature Db: Orade +E/-W ft 707.70 227.23 197.70 297.22 Map Nortbing ft 5945671.00 5946487.00 5946581.00 5946678.00 Map Easting ft 698113.00 697611.00 697579.00 697676.00 <--- Latitude --> Deg Min Sec 70 15 20.440 N 70 15 28.593 N 70 15 29.525 N 70 15 30.454 N <..- Longitude --> Deg Min Sec 148 23 55.699 W 148 24 9.675 W 148 24 10.534 W 148 24 7.639 W 290.00 5946546.54 697672.23 70 15 29.162 N 148 24 7.849 W 571.17 5946069.00 697966.00 70 15 24.391 N 148 23 59.670 W 921.61 5945632.00 698328.00 70 15 20.001 N 148 23 49.476 W +EI-W ft -16.55 -16.87 -11.62 166.74 290.00 329.18 557.57 571.17 593.03 751.38 921.61 1149.89 1686.90 NIS ft -21.99 -22.37 -26.58 -38.38 -56.94 -82.15 -113.91 -132.67 -151.30 -189.53 -227.75 -265.97 -304.20 -342.42 -380.65 -418.87 -457.09 -495.32 -533.54 -571.77 -609.99 -648.21 -686.44 -724.66 -762.89 DLS Build Turn deg/10OO deg/100ft deg/10OO 0.00 0.00 0.00 12.00 11.60 -212.53 4.00 3.85 -8.40 0.00 0.00 0.00 12.00 11.89 -2.32 12.00 -0.10 -12.00 0.00 0.00 0.00 6.00 -0.29 -5.99 6.00 -0.43 -5.98 0.00 0.00 0.00 6.00 0.46 -5.98 6.00 1.05 -5.91 0.00 0.00 0.00 EIW ft -16.55 -16.87 -18.42 -19.42 -18.99 -17.13 -13.84 -11.62 -9.32 -4.62 0.09 4.80 9.50 14.21 18.92 23.62 28.33 33.04 37.74 42.45 47.16 51.86 56.57 61.28 65.98 DLS deg/10OO 0.00 12.00 4.00 4.00 4.00 TFO Target deg 0.00 -47.00 -48.50 0.00 -14.11 05-20BT1 rev -90.58 0.00 -92.81 05-20B T2 -94.13 0.00 -85.69 05-20B T3 -79.75 0.00 05-20B T4 MapN ft 5948515.72 5948515.34 5948511.09 5948499.26 5948480.73 4.00 4.00 4.00 0.00 0.00 5948455.57 5948423.91 5948405.22 5948386.65 5948348.57 5948310.48 5948272.40 5948234.31 5948196.23 5948158.14 5948120.06 5948081.97 5948043.89 5948005.80 5947967.71 5947929.63 5947891.54 5947853.46 5947815.37 5947777.29 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MapE ft 697313.97 697313.66 697312.22 697311.52 697312.44 697314.96 697319.08 697321.80 697324.58 697330.28 697335.99 697341.70 697347.40 697353.11 697358.82 697364.52 697370.23 697375.93 697381.64 697387.35 697393.05 697398.76 697404.47 697410.17 697415.88 Tool/Comment Start Dir 12/10 Start Dir 4/1 00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS End Dir : 5251 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS e e Sperry-SuD BP Planning Report Company: BP Amoco Date: 12/21/2004 Time: 16:41:43 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Rèference: Well: 05-20, True North Site: PB OS 05 Vertical (TVD) Reference: 28.5KB+34.10GL 62.6 Well: 05-20 Section (VS) Reference: Well (0.OON,O.00E,153.02Azi) Wellpath: Plan 05-20B Survey Calculation Method: Minimum Curvature Db: Orade Su rvey MD Incl Azim TVD Sys TVD NIS EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/100ft ft ft 7000.00 22.65 172.98 6850.18 6787.58 -801.11 70.69 0.00 5947739.20 697421.59 MWD+IFR+MS 7100.00 22.65 172.98 6942.46 6879.86 -839.34 75.40 0.00 5947701.12 697427.29 MWD+IFR+MS 7200.00 22.65 172.98 7034.75 6972.15 -877.56 80.10 0.00 5947663.03 697433.00 MWD+IFR+MS 7300.00 22.65 172.98 7127.04 7064.44 -915.78 84.81 0.00 5947624.94 697438.71 MWD+IFR+MS 7400.00 22.65 172.98 7219.32 7156.72 -954.01 89.52 0.00 5947586.86 697444.41 MWD+IFR+MS 7500.00 22.65 172.98 7311.61 7249.01 -992.23 94.22 0.00 5947548.77 697450.12 MWD+IFR+MS 7600.00 22.65 172.98 7403.89 7341.29 -1030.46 98.93 0.00 5947510.69 697455.82 MWD+IFR+MS 7700.00 22.65 172.98 7496.18 7433.58 -1068.68 103.63 0.00 5947472.60 697461.53 MWD+IFR+MS 7800.00 22.65 172.98 7588.47 7525.87 -1106.90 108.34 0.00 5947434.52 697467.24 MWD+IFR+MS 7900.00 22.65 172.98 7680.75 7618.15 -1145.13 113.05 0.00 5947396.43 697472.94 MWD+IFR+MS 8000.00 22.65 172.98 7773.04 7710.44 -1183.35 117.75 0.00 5947358.35 697478.65 MWD+IFR+MS 8100.00 22.65 172.98 7865.33 7802.73 -1221.58 122.46 0.00 5947320.26 697484.36 MWD+IFR+MS 8200.00 22.65 172.98 7957.61 7895.01 -1259.80 127.17 0.00 5947282.18 697490.06 MWD+IFR+MS 8300.00 22.65 172.98 8049.90 7987.30 -1298.02 131.87 0.00 5947244.09 697495.77 MWD+IFR+MS 8400.00 22.65 172.98 8142.18 8079.58 -1336.25 136.58 0.00 5947206.00 697501.48 MWD+IFR+MS 8500.00 22.65 172.98 8234.47 8171.87 -1374.47 141.29 0.00 5947167.92 697507.18 MWD+IFR+MS 8600.00 22.65 172.98 8326.76 8264.16 -1412.70 145.99 0.00 5947129.83 697512.89 MWD+IFR+MS 8653.71 22.65 172.98 8376.32 8313.72 -1433.23 148.52 0.00 5947109.38 697515.95 TSGR 8654.01 22.65 172.98 8376.60 8314.00 -1433.34 148.54 0.00 5947109.26 697515.97 7" 8696.71 22.65 172.98 8416.01 8353.41 -1449.66 150.55 0.00 5947093.00 697518.41 TSHA 8700.00 22.65 172.98 8419.04 8356.44 -1450.92 150.70 0.00 5947091.75 697518.59 MWD+IFR+MS 8717.20 22.65 172.98 8434.92 8372.32 -1457.50 151.51 0.00 5947085.20 697519.58 TSHB 8734.28 22.65 172.98 8450.68 8388.08 -1464.02 152.31 0.00 5947078.69 697520.55 TSHC 8772.49 22.65 172.98 8485.94 8423.34 -1478.63 154.11 0.00 5947064.14 697522.73 TSAO 8800.00 22.65 172.98 8511.33 8448.73 -1489.15 155.41 0.00 5947053.66 697524.30 MWD+IFR+MS 8899.55 22.65 172.98 8603.20 8540.60 -1527.20 160.09 0.00 5947015.75 697529.98 42SB 8900.00 22.65 172.98 8603.62 8541.02 -1527.37 160.11 0.00 5947015.58 697530.01 MWD+IFR+MS 8965.05 22.65 172.98 8663.65 8601.05 -1552.23 163.17 0.00 5946990.80 697533.72 TCGL 9000.00 22.65 172.98 8695.90 8633.30 -1565.59 164.82 0.00 5946977.49 697535.71 MWD+IFR+MS 9031.14 22.65 172.98 8724.64 8662.04 -1577.50 166.29 0.00 5946965.63 697537.49 BCGL 9040.88 22.65 172.98 8733.63 8671.03 -1581.22 166.74 0.00 5946961.92 697538.05 Start Dir 12/1 0 9100.00 29.58 169.48 8786.68 8724.08 -1606.90 170.80 12.00 5946936.36 697542.78 MWD+IFR+MS 9124.41 32.46 168.45 8807.60 8745.00 -1619.24 173.22 12.00 5946924.09 697545.51 23SB 9155.89 36.18 167.33 8833.60 8771.00 -1636.59 176.95 12.00 5946906.84 697549.70 22TS 9200.00 41.42 166.06 8867.96 8805.36 -1663.47 183.32 12.00 5946880.13 697556.78 MWD+IFR+MS 9236.80 45.79 165.18 8894.60 8832.00 -1688.05 189.63 12.00 5946855.73 697563.72 21TS 9300.00 53.32 163.95 8935.57 8872.97 -1734.37 202.45 12.00 5946809.77 697577.75 MWD+IFR+MS 9350.58 59.35 163.12 8963.60 8901.00 -1774.72 214.38 12.00 5946769.74 697590.74 TZ1Bf'14N" 9375.20 62.26 162.76 8975.60 8913.00 -1795.26 220.69 11.90 5946749.38 697597.58 "14P" CP 9400.00 65.25 162.41 8986.56 8923.96 -1816.49 227.35 12.09 5946728.33 697604.79 MWD+IFR+MS 9407.38 66.13 162.31 8989.60 8927.00 -1822.90 229.38 12.00 5946721.98 697606.99 13N 9428.17 68.61 162.04 8997.60 8935.00 -1841.16 235.26 12.00 5946703.88 697613.34 "13P" 9478.99 74.68 161.40 9013.60 8951.00 -1886.95 250.38 12.00 5946658.51 697629.67 TOF 9500.00 77.19 161.15 9018.71 8956.11 -1906.24 256.93 12.00 5946639.39 697636.71 MWD+IFR+MS 9600.00 89.13 160.00 9030.60 8968.00 -1999.71 289.89 12.00 5946546.83 697672.12 MWD+IFR+MS 9691.55 89.08 149.05 9032.00 8969.40 -2082.23 329.18 11.96 5946465.37 697713.55 End Oir : 9691 9700.00 89.08 149.05 9032.14 8969.54 -2089.48 333.52 0.00 5946458.24 697718.08 MWD+IFR+MS 9800.00 89.08 149.05 9033.75 8971.15 -2175.23 384.95 0.00 5946373.87 697771.73 MWD+IFR+MS 9900.00 89.08 149.05 9035.36 8972.76 -2260.98 436.37 0.00 5946289.50 697825.38 MWD+IFR+MS 10000.00 89.08 149.05 9036.98 8974.38 -2346.73 487.79 0.00 5946205.13 697879.02 MWD+IFR+MS 10100.00 89.08 149.05 9038.59 8975.99 -2432.48 539.21 0.00 5946120.76 697932.67 MWD+IFR+MS 10135.71 89.08 149.05 9039.17 8976.57 -2463.10 557.57 0.00 5946090.64 697951.83 Start Dir 6/100 e e Sperry-Sun BP Planning Report Company: BP Amoco Date: 12/21/2004 Time: 16:41 :43 Page: 4 Field: Prudhoe Bay Co-onlinate(NE) Reference: Well: 05-20, True North Site: PB DS 05 Vertical (TVD) Reference: 28.5KB+34.1OGL 62.6 Well: 05-20 Section (VS) Reference: Well (0.00N,O.00E,153.02Azi) Wellpatb: Plan 05-20B Survey Calculation Metbod: Minimum Curvature Db: Orade Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/1 000 ft ft 10161.58 89.00 147.50 9039.60 8977.00 -2485.10 571.17 6.00 5946069.00 697966.00 05-20B T2 10200.00 88.83 145.20 9040.33 8977. 73 -2517.08 592.46 6.00 5946037.59 697988.12 MWD+IFR+MS 10201.00 88.83 145.14 9040.35 8977.75 -2517.90 593.03 6.00 5946036.79 697988.71 End Dir : 1020 10300.00 88.83 145.14 9042.37 8979.77 -2599.12 649.60 0.00 5945957.09 698047.39 MWD+IFR+MS 10400.00 88.83 145.14 9044.41 8981.81 -2681.16 706.75 0.00 5945876.58 698106.66 MWD+IFR+MS 10478.10 88.83 145.14 9046.00 8983.40 -2745.23 751.38 0.00 5945813.70 698152.95 Start Dir 6/100 10500.00 88.93 143.83 9046.43 8983.83 -2763.05 764.10 6.00 5945796.22 698166.13 MWD+IFR+MS 10600.00 89.39 137.85 9047.90 8985.30 -2840.54 827.21 6.00 5945720.41 698231.25 MWD+IFR+MS 10700.00 89.85 131.87 9048.56 8985.96 -2911.04 898.06 6.00 5945651.80 698303.93 MWD+IFR+MS 10731.17 90.00 130.00 9048.60 8986.00 -2931.46 921.61 6.00 5945632.00 698328.00 05-20B T3 10800.00 90.73 125.94 9048.16 8985.56 -2973.80 975.86 6.00 5945591.10 698383.34 MWD+IFR+MS 10900.00 91.79 120.03 9045.95 8983.35 -3028.20 1059.69 6.00 5945538.92 698468.55 MWD+IFR+MS 11000.00 92.83 114.11 9041.91 8979.31 -3073.65 1148.62 6.00 5945495.82 698558.64 MWD+IFR+MS 11001.40 92.85 114.03 9041.84 8979.24 -3074.22 1149.89 6.00 5945495.28 698559.93 End Dir : 1100 11100.00 92.85 114.03 9036.95 8974.35 -3114.33 1239.84 0.00 5945457.55 698650.89 MWD+IFR+MS 11200.00 92.85 114.03 9031.98 8969.38 -3155.00 1331.05 0.00 5945419.28 698743.14 MWD+IFR+MS 11300.00 92.85 114.03 9027.01 8964.41 -3195.67 1422.27 0.00 5945381.02 698835.39 MWD+IFR+MS 11400.00 92.85 114.03 9022.04 8959.44 -3236.35 1513.49 0.00 5945342.75 698927.63 MWD+IFR+MS 11500.00 92.85 114.03 9017.08 8954.48 -3277. 02 1604.71 0.00 5945304.48 699019.88 MWD+IFR+MS 11590.00 92.85 114.03 9012.61 8950.01 -3313.63 1686.81 0.00 5945270.04 699102.91 4112" 11590.10 92.85 114.03 9012.60 8950.00 -3313.67 1686.90 0.00 5945270.00 699103.00 05-20B T4 . ~~!Æ~E (ffi} !Æ~!Æ~~~!Æ . AI#ASIiA OIL AlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 05-20B BP Exploration (Alaska) Inc. Permit No: 204-234 Surface Location: 2911' SNL, 5033' WEL, SEC. 32, TI1N, RI5E, UM Bottomhole Location: 945' SNL, 3358' WEL, SEC. 05, TlON, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you fÌ"om 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 . ne s any required test. Contact the Commission's petroleum field inspector at (907) 659-3 7 ag r). BY ORDER <}!!HE COMMISSION DATED this~ay of November, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. iu61\- H¡lolz.oo1 o Drill iii Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2911' SNL, 5033' WEL, SEC. 32, T11N, R15E, UM / Top of Productive Horizon: 4859' SNL, 4776' WEL, SEC. 32, T11N, R15E, UM Total Depth: 945' SNL, 3358' WEL, SEC. 05, T10N, R15E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 697330 y- 5948538 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 9050 feet Maximum Hole Angle: 93 degrees . STATE OF ALASKA . AL~ OIL AND GAS CONSERVATIOm;OMMISSION PERMIT TO DRILL 20 MC 25.005 11b. Current Well Class 0 Exploratory iii Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: Da Blanket 0 Single Well 11. Well Name and Number: .r/ 'l{ 04-- Bond No. 2S100302630-277 PBU 05-20B /' 6. Proposed Depth: 12. Field I Pool(s): MD 12073 TVD 9013 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028329 8. Land Use Permit: 9. Acres in Property: 2560 13. Approximate Spud Date: December 10, 2004 14. Distance to Nearest Property: 28,300' 6" WeiQht 12.6# Spètifiça~joo~ Grade CouplinQ Length L-80 IBT-M ~ '!>ITS 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 62.6 feet 05-10 is 631' away at 9516' MD / 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2370 SI3UiogÐèpth Tóp ..' .' . ........\ .... .. Bottom MD TVD MD TVD (including staQe data) .Q25~~' 12073' 9013' 342 sx Class 'G' / ~'ìc,? jJ;bSh \;-t·GA- 18. Casing Program: Size CasinQ 4-1/2" Hole 19, PRESENIWELLCONDITION' SQMMARY (To be oolTlptetedfOfRedrill.ANQR~oVY.C>pefåticjn$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 10800 9027 None 10765 9028 Structural Conductor 115' 20" 2150# Poleset 115' 115' Surface 3512' 13-3/8" 1295 sx CS III, 400 sx Class 'G' 3512' 3512' Intermediate 8621' 9-5/8" 1420 sx Class 'G' 8621' 8454' Production Liner 1032' 7" 100 sx RAMP Cmt, 234 sx Class 'G' 8291' - 9323: 8179' - 8909' Liner 57' 4-1/2" Uncemented 9265' - 9322' 8881' - 8908' Liner 1659' 2-3/8" 8 Bbls LARC 9141' - 10800' 8817' - 9027' 20. Attachments Da Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 9021' - 9028' Da Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report Da Drilling Fluid Program Da 20 AAC 25.050 Requirem.ents Perforation Depth MD (ft): 9673' - 10760' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Billlsaacson Title Senior Drilling Engineer Date: Contact Dave Wesley, 564-5153 Phone 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Number: 2..09'- -Z.:< 4' 50- 029-22137-02-00 Conditions of Approval: ~mple equired 0 Yes ßNo Hydr en ulfide Measures ftYes 0 No Bop - 1-;. ' Permit Appr<7val / c.L Date: II/It, If!) I Mud Log Required Directional Survey Required See cover letter for other requirements o Yes ~No ;J8Yes tj No APPROVED BY THE COMMISSION Date /J.1b~t/ ;c~~n "r:þPlicate r l " \".! ~ ,., , A . . I Well Name: I 5-208 Planned Well Summary Well 05-20B Well Type Horizontal Sidetrack / Producer Target Objective Zone 1 A/1 B I AFE Number: I PBD 4P2308 I I API Number: I 50-029-22137-02 Surface I Northing I Easting I Offsets I TRS I Location 5,948,538.14 697,329.93 2,369' FSL / 247' FWL 11 N, 15 E, 32 Target I Northing I Easting I Offsets I TRS I Location 5,946,597.00 697,645.00 420' FSL / 504' FWL 11 N, 15 E, 32 Bottom I Northing I Easting I Offsets I TRS I Location 5,945,270.00 699,103.00 945' FNL / 1,922' FWL 10N,15E,5 I Planned KOP: I 9,050' md / 8,760' tvd I Planned TD: 112,073' md / 9,013' tvd I Rig: I Nabors 2ES I / I CBE: 134.10' I RTE: 162.60' Approved Well plan: Maximum Hole Inclination: Proximity Issues: Survey Program: Nearest Well within pool: Nearest Property Line Directional Proqram Wp04 I Exit point: I 9,050' md /8,760' sstvd -93.0° from -11,350' to TD at -12,073' in the planned 6" production section. There are no close approach issues in drilling 5-20B. All surrounding wells / pass major risk criteria. Standard MWD with "FR / Cassandra. Well 05-10, with center-to-center distance of -631' at 9,516' md. 28,300' to the nearest PBU property line. 05-20B Sidetrack Page 1 . . Loqqinq Proqram Hole Section: 6" production: Cased Hole: Open Hole: Required Sensors I Service Real time MWD Dir/GR/Res/ABI throughout the interval. Two sample catchers. None planned None planned Mud Proqram Type Flo-Pro Hole Section I operation: I Density ~.. ) I Viscosity I 8.5 -~~ 45 - 55 PV 8-12 Drilling 6" production interval VP I MBT I 25 - 30 <3 Casinq I Tubinq PrOqram Hole CasinglTubing Wt. Grade Connection Length Top Size Size md I tvd 6" 4 Y2" 12.6# L-80 IBT-M / 3,173' 8,900' I 8,656' Tubing 4 Y2" 12.6# L-80 IBT-M 8,900' Surface Casing String: Slurry Design Basis: Fluids Sequence I Volume: Casing String: Slurry Design Basis: Fluids Sequence I Volume: Test 9 5/8" X 7" liner 7" window 4 %" production liner 05-20B Sidetrack Cementinq PrOqram APIFL 4-6 pH 9.0-9.5 Bottom md I tvd 12,073' I 9,013' 8,900' 18,656' /" 7",26.0#, L-80, BTC-M Scab liner (Contingency) / Lead slurry: -3,642' of 7", 26.0# X 9 5/8", 47.0# annulus. Tail slurry: 1,000' of 7", 26.0# X 9 5/8", 47.0# annulus, plus -86' of 7", 26.0#, shoe track. Pre-Flush Spacer Lead Slurry Tail Slurry None planned 45bbls MudPUSH at 9.5ppg 93.2bbl I 523 cf I 219 sx Class 'G', 12.0ppg; 2.39 cf/sk. 28.9bbl I 162cf I 140 sx Class 'G', 15.8ppg; 1.16 cf/sk. 41/2",12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Tail slurry: 3,023' of 41/2" X 6" annulus with 40% excess, plus 85' of 4 1/2", 12.6# shoe track, plus 150' of 7", 29.0# X 4 %" liner lap, plus 200' of 7",29.0# X 4" drill pipe annulus. Pre-Flush 25bbls CW100 Spacer 35bbls MudPUSH at 9.6ppg Lead Slurry None planned ~) /'" ~ Tail Slurry 73.0bbl 1410 cf ~£Sx Class 'G', 15.8ppg; ~f/Sk. Casinq I Formation Inteqritv Testinq Test Point Bridge plug to surface 20' formation beyond mid-window Float equipment to surface Test Type 30 min recorded FIT 30 min recorded Test pressure 3,500psi surface 10.0ppg EMW 3,500psi surface Page 2 . . Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: BOPE configuration during de- completion Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned completion fluid: Annular Injection: Cuttings Handling: Fluid Handling: 9 5/8" X 7" de-completion phase 3,250psi at 8,800' sstvd. 2,370psi (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Infinite r% 250psi low /, psi high - 7 day test cycle (Pre drilling phase) Variable Bor ams will remain installed. This configuration provides two sets of employable rams, rather than one. 6" production interval 3,250psi at 8,800' sstvd. 2,370psi (based upo HP and a full column of gas from TD @ 0.10 psi/ft) Infinite with 10.0 EMW FIT. 250psi low /3, psi high - 14 day test cycle (Drilling operations) 8.4ppg seaw .1 ppg Diesel /' Disposal No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. Any metal cuttings should be sent to the North Slope Borough. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for injection. All Class I wastes are to be hauled to Pad 3 for disposal. 05-20B Sidetrack Page 3 Formation TSGR TSHA TSAD 42SB TCGL BCGL 23SB 22TS 21TS TZ1B 1 14N 14P 13N 13P TDF (TZ1 A) THOT I TD Criteria: Pre-Riq Operations: . . Geoloqic Proqnosis MD TVDbkb TVDss Comments 8,314 8,353 8,423 8,541 8,601 8,662 8,745 8,771 8,832 -3,250psi (7.1 ppg EMW) 8,901 8,913 8,927 8,935 8,951 8,986 TD Criteria I TD with sufficient rat hole to allow perforating a minimum of 200' of Z1 B. Operations SUmmary 1. The 3 W', 9.2#, L-80 tubing is collapsed/parted at 5,424'md, based upon a video log run 8/21/2002. 2. Currently, it is not possible to conduct an MIT-IA with the parted tubing and with open perforations. 3. MIT-OA passed to 2,000psi on 10/25/2004. 4. A PPPOT-IC passed to 3,100psi, and a PPPOT-T passed to 5,000psi on 10108/2004. All LDS functioned and were re-torqued to 450 ft-Ibs. 5. Circulate the well to brine, as necessary to balance, by bull heading down the tubing to the open perforations. Attempt to circulate through the tubing part, taking returns up the IA. Reverse-circulate from the IA to the tubing to confirm the IA is clear. Freeze protect to -2,200' MD with diesel. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV. Secure the well. Level the pad as necessary. RiQ Operations: 1. Mil RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. R/U. Pull the 4·W' X 3 W' tubing from the collapse 1 part at -5,424'md and above. Be prepared to spool up the Bal-O SSSV control lines and the Chemical Injection line. The CI mandrel is at 8,20Tmd. Determine at what depth the Clline parted. 5. M/U a Baker overshot 1 dressing assembly, with -100 feet of wash over pipe. RIH, wash over down to the tubing stub. Dress the tubing stub in preparation for the outside cutter. POOH. 6. M/U Baker overshot 1 outside cutter assembly. RIH to 3 W' tubing stub. Make an outside cut on the 3 W' tubing below the point of collapse/part. POOH with fish. 05-20B Sidetrack Page 4 . . \( 7. M/U an overshot, with a grapple dressed for the 3 W' tubing. RIH and overshot I engage the tubing stub. 8. R/U SWS E-line. RIH with the 2 3/8" chemical cutter or jet cutter. Confirm all drill pipe and assembly components will allow passage of the tubing cutter. Cut the 3 W' tubing at -9,125'md. POH and RID E-line. 9. POOH and UD the remaining 3 W' tubing. Spool up the remaining chemical injection line. 10. R/U E-line. RIH with a full gauge GR/JB for the 7", 29.0#, L-80 liner. Tag the tubing stub at 9,125'. POOH. 11. Alternatively, M/U a milling assembly and RIH while P/U 4" drill pipe. Tag the tubing stub. POOH. 12. M/U a HES 7" EZSV bridge plug. RIH with the EZSV, on E-line, and set at -9,070'md. POOH and RID E-line. 13. Attempt to pressure test the 7" liner X 9 5/8" casing to 3,500psi for 30 minutes. Record the test. 14. If the pressure test fails, prepare to P/U a 9 5/8" RTTS to locate the leak point. A contingency plan to run a 7" scab liner is in place, should the casinß fail the pressure test. Otherwise, continue with the plan to RIH with the whip stock. T ~ <" I D ~ (/0 ( Ovf f H·"~..",{ , 15. M/U a Baker 7" whip stock assembly. RIH to EZSV retainer. OrierH as desired and set the whip stock on the EZSV.· ~ 16. Shear free from the whip stock. Displace the well to 8.5ppg Flo-Pro drilling fluid. 17. Mill a window in the 7" liner at -9,050'md. Drilllmill approximately 20 feet beyond the middle of the window. 18. Circulate the well clean. Pull into the 7" liner and conduct an FIT to 10.0ppg EMW. POOH. /" 19. M/U a 6" Dir/GR/Res/ABI drilling assembly. RIH to the window. 20. Drill ahead, per directional proposal, to planned TD of -12,075'md. /' 21. Condition hole for running 41/2",12.6#, L-80, IBT-M liner. / 22. Run and cement the 4 W' production liner, extending the liner lap to -8,900'md. POOH. 23. P/U and RIH with Schlumberger 2 W' DPC perforating guns. Perforate approximately 1,000' of Z1A/1B interval, per subsurface team. POOH. 24. R/U and run a 41/2", 12.6#, L-80, IBT-M completion, stinging into the 41/2" liner tie back sleeve. 25. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each / test. /' 26. Install a TWC. 27. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 28. Freeze protect the well to -2,200'. Install BPV. Secure the well. 29. Rig down and move off. Post-Riq Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 11/15/04 Estimated Spud Date: 12/10104 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 05-20B Sidetrack Page 5 . . Phase 1: Move In I Riq Up I Test BOPE Planned Phase Time 23 hours Planned Phase Cost $57,670 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards }> No wells will require shut-in for the rig move onto 05-20A. However, 05-08 is 60.0' to the North, and 05-07 is 60.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. }> The 3 %" tubing is parted at -5,425'md, as confirmed with a video run on 6/13/2002. }> During MI/RU operations, the 5-20A well bore will be secured with the following barriers: o Tubing: kill weight fluid and a BPV. The tubing is parted at -5,425'md. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 10/25/2004 passed. }> Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. » During ND/NU BOPE operations, the 5-20A well bore will be secured with the following barriers: o Tubing: kill weight fluid and a TWC. The tubing is parted at -5,425'md. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 10/25/2004 passed. }> DS 05 is .!]S!t.designated as an HzS site.-However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 05-08 5ppm 05-10 10ppm 05-07 5ppm 05-21A 15ppm The maximum level recorded of H2S on the pad was 21ppm, in 11/1990. }> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 05-20B Sidetrack Page 6 . . Phase 2: De-complete Well Planned Phase Time 112 hours Planned Phase Cost $350,382 Reference RP .:. "De-completions" RP Issues and Potential Hazards }> Monitor the well to ensure the fluid column remains static, prior to pulling the completion. }> Have all wellhead and completion equipment NORM-tested, following retrieval. }> Note that this wellhead is an FMC Gen IV. The tubing hanger is 11" X 4 W' FMC hanger, with 9" LH Acme lifting thread. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. }> There is a 4112" Cameo Bal-O SSSV with dual 14" control lines, and a chemical injection mandrel with a single 3/8" injection line. There were 70 - 4 112" clamps, 156 - 3 W clamps, 15 - 3 %" Mod clamps, and 21 stainless steel bands used in securing the control lines and chemical injection line. }> It is suspected that the 3 112",9.2#, L-80 tubing is parted at -5,425'md. }> Due to the parted 3 112" tubing at -5,425'md, a pre rig coil tubing cement P&A was not possible. The well bore will be abandoned with an EZSV bridge plug following de-completion. }> The 9 5/8" X 7" will be pressure-tested to 3,500psi, to confirm integrity. If the test fails, the leak point will be located and isolated with a 7" scab liner. Phase 3: Run Whip Stock Planned Phase Time 52 hours Planned Phase Cost $354,144 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards }> A 7" whip stock will be run and set in the existing intermediate casing. }> There may be no cement behind the 7" casing at the sidetrack point. }> Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. 05-20B Sidetrack Page 7 . . Phase 7: Drill 6" Production Hole Interval Planned Phase Time 128 hours Planned Phase Cost $715,300 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards > The parent well, 5-20, experienced no lost circulation events during drilling operations. ~ There were no significant lost circulation events in any of the near surrounding wells. > The planned well, 5-20B, is expected to cross no faults while drilling the production interval. Phase 9: Run 4%" Production Liner Planned Phase Time 28 hours Planned Phase Cost $236,722 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards > The completion design is to run a 4 W', 12.6#, L-80 solid liner throughout the production interval. > Differential sticking is possible. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 1 formation. Minimize the time the pipe is left stationary while running the liner. > Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner shoe. > Ensure the 4 W' liner top packer is set prior to POOH. Phase 10: DPC Perforate Planned Phase Time 30 hours Planned Phase Cost $282,006 Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards > The well will be DPC perforated, -600psi overbalanced, after running the 4 W 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. 05-20B Sidetrack Page 8 . . Phase 12: Run 4 %" L-80 Completion Planned Phase Time 28 hours Planned Phase Cost $337,782 Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. ~ The completion, as designed, will be to run a 4%,',12.6#, L-80, IST-M production tubing string, stinging into the 4 %" liner tieback sleeve. Phase 13: ND/NU/Release RiQ Planned Phase Time 15 hours Planned Phase Cost $49,111 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards Þ> No wells will require shut-in for the rig move onto 05-20A. However, 05-08 is 60.0' to the North, and 05-07 is 60.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ During ND/NU tree operations, the 5-20A well bore will be secured with the following barriers: o Tubing: kill weight fluid and a TWC. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 10/25/2004 passed. ~ During RD/MO operations, the 5-20A well bore will be secured with the following barriers: o Tubing: kill weight fluid and a SPY. o IA: Annulus valve and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 10/25/2004 passed. 05-208 Sidetrack Page 9 Plan: 05-20B wp04 (05-2ü/PJan 05~20B) Created By: Troy Jakabosky Checked: Too! MWD SURVEY PROGRAM Surve)'iT'hm P1mmed; OHDa ..vp04 V2 Depth Pm I)¢pth To 9050.00 1207257 REfERENCE lNFORMA rrON COMPANY m:r A!l.S BP Am<>oo - Shape Date: Date: Slot NlA Basting Latitude L{}flgitt.1de 10~15'4K832N 148"24'lô286W Northing TARGET DETAILS +N!·S +EI-W WELL DETAILS Easring 697329.93 Northing 5948538.14 +£I-W -63.99 TVD ,6! ,6( ,61 +N!.s !335.65 """" !)5,2ù ~o Poly Name FORMA nON TOP DETAILS No, TVDPath MDPath Fonnation I 2 3 4 5 6 " Size 4.500 CASING DETAILS MD 12072.00 Name 4 II2' TVD 9012.63 Target VSee 05-2013 T2 TFace SECTION DETAILS +N!-S +E!-W DLeg TVD Azi Inc MD 9039,: I' t~ 11 II 05-20B T4 , I( It See I 2 3 4 5 6 7 8 9 10 11 12 13 7200 No, I 7600 8400-- " :¡¡ ~ 1 -¡;¡ " t " > 1ì Þ 7 , , 4400 , , , , 4000 , 3600 , , , , 3200 , 2000 , 600 , , 1200 , , 800 8800 9200 " . BP BP Planning Report . COlDpany: Field: Site: WeD: WeUpath: BP Amoco Prudhoe Bay PB DS 05 05-20 Plan 05-208 Date: 10/1812004 TUDe: 17:26:24 . ~age: Co-ordinate(NE) Reference: Wen: 05-20. True North . Vertical (TVD) Referenee: 28.5 + 34.1 62.6 .. . Seetion (VS) RefereJlee: Well (0.ooN.O.OOI;.153;02AZI1 Survey Calculation Method: Minimum Cúrvature .. Db: Plan: 05-208 wp04 Date Composed: Version: Tied-to: 9/23/2004 22 From; Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 wen Centre bggm2004 Site: PB DS 05 TR-11-15 UNITED STATES; North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: 70 15 Longitude: 148 24 North Reference: Grid Convergence: 35.696 N 14.424 W True 1.50 deg Well: 05-20 Slot Name: 05-20 Well Position: +N/-S 1335.65 ft Northing: 5948538.14 ft Latitude: +EI-W -63.99 ft Easting: 697329.93 ft Longitude: Position Uncertainty: 0.00 ft 70 15 48.832 N 148 24 16.286 W Casing Points MD TVD Diameter Hole Size Name ft ft in in 12072.00 9012.63 4.500 6.125 4 1/2" Formations MD TVD Formations UthoIogy ft ft 0.00 TSAD 0.00 0.00 TZ3 0.00 0.00 TZ2C 0.00 9138.20 8807.60 TZ28 0.00 9208.38 8837.60 22TS 0.00 9375.36 8886.60 21TS 0.00 9636.16 8958.60 TZ1b (none) 0.00 9719.47 8981.60 13N 0.00 9857.34 9014.60 TZ1A 0.00 Targets Map Map ~ Latitude --> Name Description TVD +N/oS +EI-W Northing Easting Deg Min See Dip. Dir. ft ft ft ft ft 05-208 T4 9012.60 -3313.67 1686.90 5945270.00 699103.00 70 15 16.240 N 148 23 27.216 W 05-20B T1 9030.60 -1948.84 264.10 5946597.00 697645.00 70 15 29.665 N 148 24 8.602 W 05-208 Geo Poly 9030.60 -1868.65 296.22 5946678.00 697675.00 70 15 30.454 N 148 24 7.668 W -Polygon 1 9030.60 -1868.65 296.22 5946678.00 697675.00 70 15 30.454 N 148 24 7.668 W -Polygon 2 9030.60 -1944.65 371.26 5946604.00 697752.00 70 15 29.707 N 148 24 5.485 W -Polygon 3 9030.60 -2665.21 839.56 5945896.00 698239.00 70 15 22.619 N 148 23 51.862 W -Polygon 4 9030.60 -2843.25 990.95 5945722.00 698395.00 70 15 20.868 N 148 23 47.459 W -Polygon 5 9030.60 -3228.43 1755.16 5945357.00 699169.00 70 15 17.079 N 148 23 25.230 W -Polygon 6 9030.60 -3414.64 1684.26 5945169.00 699103.00 70 15 15.247 N 148 23 27.294 W -Polygon 7 9030.60 -3061.45 919.21 5945502.00 698329.00 70 15 18.722 N 148 23 49.547 W -Polygon 8 9030.60 -2886.84 707.70 5945671.00 698113.00 70 15 20.440 N 148 23 55.699 W -Polygon 9 9030.60 -2057.92 227.23 5946487.00 697611.00 70 15 28.593 N 148 24 9.675 W 05-20B T2 9039.60 -2485.10 571.17 5946069.00 697966.00 70 15 24.391 N 148 23 59.670 W 05-208 T3 9048.60 -2931.46 921.61 5945632.00 698328.00 70 15 20.001 N 148 23 49.476 W . Company: Field: Site: WeD: WelIpath: Targets Name . BP BP Planning Report BP Amoèo Prudhoe Bay PB DS 05 05-20 Plan 05-2OB Date: 1011812004 Timei17:26:Z4 Co-ordinate(NE) Reference: VertiéaI. (TVD) Refereoce: Sedioo (VS) Reference: . Survey Calculation Method: Plan Section Information MD ft 9050.00 9070.00 9268.07 9754.21 10023.66 10216.79 10627.25 10642.69 10671.42 10869.67 11215.83 11352.33 12072.57 Survey MD ft 9050.00 9070.00 9100.00 9138.20 9200.00 9208.38 9268.07 9300.00 9375.36 9400.00 9500.00 9600.00 9636.16 9700.00 9719.47 9754.21 9800.00 9857.34 9900.00 10000.00 10023.66 10100.00 10200.00 10216.79 10300.00 10400.00 10500.00 10600.00 10627.25 10642.69 10671.42 10700.00 10800.00 Inel (\eg 52.24 54.58 73.97 73.97 89.17 89.17 89.17 89.00 88.71 88.71 90.00 92.62 92.62 lad (\eg 52.24 54.58 57.51 61.24 67.30 68.12 73.97 73.97 73.97 73.97 73.97 73.97 73.97 73.97 73.97 73.97 76.55 79.78 82.19 87.83 89.17 89.17 89.17 89.17 89.17 89.17 89.17 89.17 89.17 89.00 88.71 88.71 88.71 Description Dip. Dir. Azim .Øeg 170.79 170.12 165.60 165.60 160.00 148.41 148.41 147.50 149.20 149.20 125.00 115.81 115.81 Azim deg 170.79 170.12 169.33 168.38 166.99 166.81 165.60 165.60 165.60 165.60 165.60 165.60 165.60 165.60 165.60 165.60 164.61 163.40 162.51 160.48 160.00 155.42 149.42 148.41 148.41 148.41 148.41 148.41 148.41 147.50 TVD ft 8759.47 8771.39 8856.98 8991.19 9030.60 9033.41 9039.35 9039.60 9040.17 9044.64 9048.60 9045.48 9012.60 TVD ft 8759.47 8771.39 8788.15 8807.60 8834.42 8837.60 8856.98 8865.79 8886.60 8893.40 8921.01 8948.62 8958.60 8976.23 8981.60 8991.19 9002.84 9014.60 9021.29 9029.98 9030.60 9031.71 9033.16 9033.41 9034.61 9036.06 9037.51 9038.96 9039.35 9039.60 TVD ft +N/.,8 ft -1053.32 -1069.15 -1242.59 -1695.15 -1948.84 -2122.41 -2472.01 -2485.10 -2509.55 -2679.79 -2931.46 -3000.45 -3313.67 Sys TVD ft 8696.87 8708.79 8725.55 8745.00 8771.82 8775.00 8794.38 8803.19 8824.00 8830.80 8858.41 8886.02 8896.00 8913.63 8919.00 8928.59 8940.24 8952.00 8958.69 8967.38 8968.00 8969.11 8970.56 8970.81 8972.01 8973.46 8974.91 8976.36 8976.75 8977.00 149.20 9040.17 8977.57 149.20 9040.82 8978.22 149.20 9043.07 8980.47 +N/.,8 ft +FJ-W ft 28.49 31.15 69.06 185.29 264.10 347.99 562.98 571.17 586.24 687.73 921.61 1039.17 1686.90 NIS ft -1053.32 -1069.15 -1093.64 -1125.88 -1180.24 -1187.80 -1242.59 -1272.32 -1342.47 -1365.41 -1458.50 -1551.59 -1585.25 -1644.68 -1662.81 -1695.15 -1737.94 -1791.88 -1832.16 -1926.58 -1948.84 -2019.45 -2108.03 -2122.41 -2193.28 -2278.46 -2363.63 -2448.80 -2472.01 -2485.10 -2509.55 -2534.09 -2619.97 +FJ-W ft Map Northing ft . Map Easting ft <-- Latitude --> Beg MiD. See. . DLS BniId Tu,ro deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 12.00 11.70 -3.31 10.00 9.79 -2.29 0.00 0.00 0.00 6.00 5.64 -2.08 6.00 0.00 -6.00 0.00 0.00 0.00 6.00 -1.10 -5.90 6.00 -1.01 5.92 0.00 0.00 0.00 7.00 0.37 -6.99 7.00 1.92 -6.73 0.00 0.00 0.00 FJW ft 28.49 31.15 35.59 41.95 53.83 55.59 69.06 76.69 94.71 100.60 124.51 148.42 157.07 172.33 176.99 185.29 196.68 212.15 224.50 256.11 264.10 293.05 339.32 347.99 391.57 443.95 496.33 548.71 562.98 571.17 586.24 600.87 652.07 DLS deg/100ft 0.00 12.00 10.00 10.00 10.00 10.00 10.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 6.00 MapN ft 5947485.99 5947470.23 5947445.87 5947413.81 5947359.78 5947352.27 5947297.85 5947268.34 5947198.69 5947175.91 5947083.49 5946991.06 5946957.64 5946898.63 5946880.64 5946848.52 5946806.05 5946752.54 5946712.60 5946619.04 5946597.00 5946527.18 5946439.84 5946425.70 5946355.99 5946272.23 5946188.46 5946104.69 5946081.87 5946069.00 6.00 0.00 0.00 5946044.96 5946020.81 5945936.31 'J'FO deg 0.00 -13.00 -12.94 0.00 -20.50 -90.08 0.00 -100.58 99.74 0.00 -87.13 -74.04 0.00 Target . 05-208 T1 05-20B T2 05-20B T3 05-208 T4 MapE .... ft . 697386.01 697389.09 697394.17 697401.37 697414.67 697416.63 697431.52 697439.93 697459.78 697466.27 697492.61 697518.95 697528.48 697545.29 697550.42 697559.57 697572.08 697588.95 697602.35 697636.42 697645.00 697675.79 697724.36 697733.40 697778.83 697833.42 697888.01 697942.59 697957.47 697966.00 ToolICo,.unent Start Dir 12/1 0 Start Dir 10/10 MWD TZ2B MWD 22TS End Dir : 9268 MWD 21TS MWD MWD MWD TZ1b MWD 13N Start Dir 611 00 MWD TZ1A MWD MWD 05-208 T1 MWD MWD End Dir : 1021 MWD MWD MWD MWD Start Dir 6/100 05-20B T2 697981.71 End Dir : 1067 697996.98 MWD 698050.40 MWD .. . BP BP Planning Report . Survey 10869.67 88.71 149.20 9044.64 8982.04 -2679.79 687.73 0.00 5945877.44 698087.62 Start Dir 711 00 10900.00 88.82 147.08 9045.30 8982.70 -2705.55 703.74 7.00 5945852.12 698104.29 MWD 11000.00 89.18 140.09 9047.05 8984.45 -2785.96 763.06 7.00 5945773.29 698165.70 MWD 11100.00 89.56 133.10 9048.15 8985.55 -2858.55 831.73 7.00 5945702.53 698236.24 MWD 11200.00 89.94 126.11 9048.59 8985.99 -2922.26 908.73 7.00 5945640.87 698314.88 MWD 11215.83 90.00 125.00 9048.60 8986.00 -2931.46 921.61 7.00 5945632.00 698328.00 05-20B T3 11300.00 91.62 119.33 9047.41 8984.81 -2976.25 992.82 7.00 5945589.10 698400.36 MWD 11352.33 92.62 115.81 9045.48 8982.88 -3000.45 1039.17 7.00 5945566.12 698447.32 End Dir : 1135 11400.00 92.62 115.81 9043.30 8980.70 -3021.18 1082.04 0.00 5945546.52 698490.72 MWD 11500.00 92.62 115.81 9038.74 8976.14 -3064.67 1171.97 0.00 5945505.41 698581.75 MWD 11600.00 92.62 115.81 9034.17 8971.57 -3108.16 1261.91 0.00 5945464.30 698672.79 MWD 11700.00 92.62 115.81 9029.61 8967.01 -3151.65 1351.84 0.00 5945423.18 698763.83 MWD 11800.00 92.62 115.81 9025.04 8962.44 -3195.13 1441.77 0.00 5945382.07 698854.86 MWD 11900.00 92.62 115.81 9020.48 8957.88 -3238.62 1531.71 0.00 5945340.95 698945.90 MWD 12000.00 92.62 115.81 9015.91 8953.31 -3282.11 1621.64 0.00 5945299.84 699036.94 MWD 12072.00 92.62 115.81 9012.63 8950.03 -3313.42 1686.39 0.00 5945270.24 699102.48 4 1/2" 12072.57 92.62 115.81 9012.60 8950.00 -3313.67 1686.90 0.00 5945270.00 699103.00 05-20B T4 ; 05-2.A Pre Rig . TREE = WELLHEAD = .m~..",. .. '^ ~mn~_ ACTUA TOR = KB. ELEV = ,~, ~,.,~ CB. ELEV = RbÞ"" ~~:ÄngI~~~'~ Datum MD = "" ........~uw________...~.., Datum lVD = FMC GEN 4 FMC OTIS 71' 34.1 6936' """'~ W~~ ...., 95~@ 100~~' 9244' ......."'~.._,-~..~ 8800' SS 14-1/2", 12.6#, L-80, 11 tubing, ID = 3.958" 2978' I TOP OF 3-1/2" TBG H 2978' 113-3/8",68.0#, L-80,11 3512' casing ID = 12.415" COllapsed Tubing 11 5424' (06/13/02 VIDEO) I TOP OF 7" LNR H 8292' 19-5/8",47.0#, L-80, 11 8620' casing ID = 8.681" Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS I Top of 2 3/8" Liner H 9141' 13 1/2", 9.3#, L-80, 11 9265' tubing, ID = 2.992" I Top of 4 1/2" liner H 9265' 17",29#, L-80, liner, Ii 9790' ID = 6.184" 14 1/2", 12.6#, L-BO, 11 10385' liner, ID = 3.953" DATE 1991 07/08/98 02/27/02 06/18/02 08/18/03 10/27/04 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACKED RNITP CORRECTIONS JMlTP COLLAPSED TBG CMOITLP PERF ANGLE CORRECTION dew Pre rig condition .:iii: , L ~ 0[----- I I /' H/1 4~ 9141' 9156' 9244' 9255' 1976' H4 1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" H4-1/2" X 3-1/2" XO I 2978' GAS LIFT MANDRELS DEV TYPE VLV LATCH PORT DATE o TGPB TG o TGPB TG o TGPB TG 11 . TGPB TG 21 TGPB TG 27 TGPB TG 26 TGPB TG CHEMICAL MANDRELS IST MD IlVDI DEVI TYPE IVLVLATCH PORT DATE I 1 8207 8104 26 MMG-7-LTS RK ST MD lVD 1 3208 3208 2 5201 5201 3 6313 6313 4 6902 6900 5 7430 7406 6 7803 7742 7 8114 8021 SAFETY NOTES: MAY NEED TO LIMIT INNER ANNULUS TESTING & OP PRESSURES. LNR DIDN'T PT TO 2000# (LOST 500# IN 30 MIN-ON 07/08/98 HO. 3-1/2" OTIS X NIP @ 9156' MILLED W/2.81" MILL DRL'D THRU PACK- OFF BUSHING 07/31/93. 700 @ 9507' AND 900 @ 9747' H2-3/8" DEPLOYMENTSLV,ID= 1.969" I H3-1/2" OTIS XN NIP, ID = 2.81" (BEHIND LNR) H3-1/2" TrN OVERSHOT SEAL ASSY (B8-IIND LNR) I H 7" X 3-1/2" TrN SS HYDRO SET PKR (BEHIND LNR) I PERFORA TION SUMMARY REF LOG: MIND GR ON 07/05/98 ANGLE AT TOP PERF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 -10760 0 07/07/98 I 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' I DATE REV BY 12-3/8" LNR, 4.6#, L-80, .00387 bpf, ID = 1.995" 11 10799' 1 COMMENTS PRUDHOE BA Y UNIT WELL: 05-20A PERMIT No: 1971790 API No: 50-029-22137-01 SEe 32, T11N, R15E, 3938.91' FEL & 5050.68' FNL BP Exploration (Alaska) .; . 05-208 P~posed completion / FMC GEN 4 FMC OTIS 113-3/8",68.0#, L-8°'li L casing ID= 12.415" 3512' ---¡ ---¡ ~ ---¡ I TOP OF 7" LNR H 8292' I" I :8 :8 19-518",47.0#, L-80, 11 8620' casing ID = 8.681" l . 14-1/2", 12.6#, L-80, 11 2978' tubing, ID = 3.958" I HES 7" EZSV I Top of 2 3/8" Liner 1-1 9,070' H 9141' 13 1/2", 9.3#, L-80, tubing, ID = 2.992" TOp of 4 1/2" liner 11 9265' H 9265' 17", 29#, L-80, liner, 11 9790' 10=6.184" 14 1/2", 12.6#, L-80, 11 10385' liner, 10 = 3.953" I 2,200' 1-1 41/2" - 'X'landing nipple I TREE = WELLHEAD = ."~"'-'<"^"~~ ACTUATOR = KB. ELEV = CB. ELEV = 34.1 KOP = 6936' m.. .......mm.uuuM.·____..m^^.mmm..________ ....~·______"m~ " ~x A~9.!~ = ~5 @ ~E078~ Datum MD = 9244' öäÎumiV5::::~~ 8800' 58 GAS LIFT MANDRELS ST MO rvD DEV TYÆ VALVE LATCH 5 TBD TBD TBD 4 1/2" X 1 1/2" MMG OCR RK 4 TBD TBD TBO 4 1/2" X 1 1/2" MMG DV RK 3 TBD TBO TBO 4 1/2" X 1 1/2" MMG DV RK 2 TBD TBO TBD 4 1/2" X 1 1/2" MMG DV RK 1 TBD TBD TBO 4 1/2" X 1 1/2" MMG DV RK 8,830' H 41/2" - 'X'landing nipple 8,850' H 4 1/2" X 7" Baker 8-3 A<r 8,870' 1-1 4 1/2" - 'X' landing nipple 8,890' H 41/2" - 'XN' landing nipple 8,897' H 4 1/2", 12.6#, L-80, IBT-M I 5" X 7" Baker HMC liner / 8,900' hanger, ZXP liner top packer w / Tie Back Sleeve. Jì I 12,073' 1;141/2", 12.6#, L-80, IBT-M liner / DATE REV BY PRUDHOE BAY UNIT WELL: 05-20B PERMIT No: API No: 50-029-22137-02 SEC 32, T11 N, R15E. 3938.91' FEL & 5050.68' FNL COMMENTS DATE 1991 07/08/98 02/27/02 06/18/02 08/18/03 10/27/04 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACKED RNlTP CORRECTIONS JMiTP COLLAPSED TBG CMOfTLP PERF ANGLE CORRECTION dew 5-20B Proposed completion BP Exploration (Alaska) " . POST THIS NOTICE IN THE DOG.USE . .¡. 5-208 Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 27 ppm, measured in November 1990. ------- ./ NORM test all retrieved well head and completion equipment. ./ All surrounding wells pass major risk criteria. ./ The closest neighboring wells, at surface, are 05-08 and 05-07. Well 05-08 is approximately 60' to the North, Well 05-07 is approximately 60' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ The 3~" tubing is parted at -5,425'md. De-completion may be problematic, especially with the 3 /8" chemical injection line extending to the mandrel at 8,207' md. ./ The integrity of the 9 5/8" intermediate casing will not be tested until the well has been de-completed. A scab liner contingency is in place. ./ There are no planned fault crossings in drilling the production interval. However, there are known faults to the SW and NE of the planned horizontal trajectory. ./ Differential sticking may be encountered. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE OS 05 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 05-20B TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 1 ~-;-'''l ¡ DATE t )-ID-Ol(1 6AY:?!J~1E .~ .&~J.406CG$ ¡CD.OD : è)t-Q _~~~ CO/ÍOO LJULLÁRS First National Bank Alaska :::'r;5~ ~'{,v(.~. . . 89-6/1262 "Mastercard Check" I: ¡. 25 2000 bOI: 11 q J. ....., b 2 27"' ¡. 55 bU- 0 ¡. b ¡. . . D D Well bore seg Annular Disposal - Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name PRUDHOE BAY UNIT 05-20B Program DEV .J. - PTD#: 2042340 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration 1 P_e(lnitfee attache_d_ . _ _ _ _ ~ - - - - - - - - - - ~ Y_es 2 ~Leas.enumber _appropri<lte _ _ . ~ ~ _ . ~ . ~ - - - - _ Yes 3 _U~nique well.n.arn~_aod [1l!/1JQer _ ~ ~ _ _ ~ _ _ ~ ~ _ _ ~ _ _ _ ~ _ _ _ ~ . ~ - - ~ - - - ~ _y~s ~ - - - - - - - - ~ - - - - - - - - ~ - - - - 4 WeJUOC<lted ina. d.efjlJe.dpool. . ~ ~ . ~ _ - - - - - ~ Y.es - - - - 5 WellJOC<lted proper_distance_ from driJIing \,IlJitb.o\,llJd_ary_ . Yes - - - -- 6 WelUoC<lted proper _distance. from otber welJs_ ~ · y~s 7 .S_uffjcieIJLacreag.e_aYail<lble in.dJilli[1g.lInjL . Yes ~ - - - 8 Jf.d~viated, js_ weJlbore plç¡tilJcJu.ded . . . - - -- - - - - - - - - · Y_es - - - - - 9 _OPerator olJly affected party _ _ . - - - - - Yes - - - - - 10 _Operator bas~a.ppropriate_ bond inJorce. ~ _ _ ~ ~ _ _ ~ _ _ _ _ _ _ ~ _ _ ~__~__~_Yes - - ~ - - - - - - - - - - - . - - - - - - ~ - 11 P~[/1Jil can be iSSl!ed wjtbout çonservation order_ - - - - _ Yes - - - - Appr Date 12 P~r/1Jit can be iSSl!ed wjtbout ad.lTJilJistrative_ appr.ovaJ . . . Yes RPC 11/15/2004 13 Can permit be approved before 15-day wait Yes 14 Well Jocaled within area and_strç¡ta _authorized by~ Injection Order # (pullO# in_ c.omrn.ents). (For_ .NA - - - - - - - - 15 AJlwelJs~withi.n.1l4_mile~area~ofreYi~wjd~ntified(Forserv.i~.we[lonlYL _ _ _ ~ _ _ ~ _ _ _ ~ _ _ ~ _NA ~ - - - - - - - ~ - - - - - - - - - - - - . - 16 PJe-produ_ced. injector; _duration~of pre-pr~uction J.es& than. 3 mOlJths. (For_service well onJy) . _ _NA 17 ACMP_ finding .of Con_sistency h_as bee_n .issued_ for_ this pr_oiect _ . . - - - .NA Engineering 18 _C_ondu_ctor strin.g.pJovided _ . . _ .NA 119 S_urfa~.cç¡&ing.protect& altknown. USDWs . . _ _ _NA 20 _c.MT v_oJ. adequate_ to çirc.uJ.ate_o_ncond_uctor & Sl!rf. C$g _ . - - - - · _NA - - - - - 21 _CMT v.ol adequate_ to tie-inJong _string to.surf Ç$g _ _ .NA 22 _CMT will çoyeraJI ]<oown.productiye borizon.s _ - - - - - Yes 23 _Casing designs ad.ec¡ua.te tor C,.T, B _& permafr_ost - - - - .. _' Yes 24 Adequ<ltetan.kç¡ge_ or reserve pit . - - - - - . - y~s lIIab_ors~2_ES. . 25 Jf.aJe-drilL has_a 1~03 fQr <lbandonme.nt be_en apPJoved . · Y_es 11J8/2QO.<k 26 _Mequ<lte.we!lbore sepi;lralio_n_proposed _ _ _ _ _ ~ _ _ _ ~ _ _ ~ ~ _ _ ~ _ _ _ _ _ _ _ _ ~ _ _ Yes - - ~ - - - - - - - - - - - - - - - - * - - - 27 Jf.dNerter Jeq.uiJed, does jLlTJeet reguJations_ .. _ .NA. Sidetrack. . - - - - - Appr Date 28 .DJilli[1g fJujd.prog.ram schemç¡tic_& eq.uipJista.dequate. ..' Yes Max MW.8.6 ppg. WGA 11/16/2004 29 _BO_PEs,.d.o.they meet regu.latiol) . - - - - _ Yes 30 BQP.Epress rati[1g appropriate;.test to.(pu_t PSig incomOlents) - - - Y~s Test to .3500_ psi. . MS¡:> 23.70 psi. 31 C.hoke_manifold complie& w/API. ßf>-53 (May ß4) _ . _ _. Yes 32 Work will occ.ur withoytoperatio.n_shlltdown_ _ . - - - - - Y.es - - - - 33 J& pre&eoce of H2S ga& probable _ _ _ - - - - - - - - - - No_ lIIota[1 H2S pad.. 34 Meçbanical.cO[1d.itlo!1.of wells within 80R yerjfied (For. service welJ ol1ly) ~ .NA. Geology 35 Permit ca[1 be issued wlo. hydrogen sulfide measures. - - - No 36 _Qata. PJeseoted on. potential ove_rpre$.surezOl1es _ _ . - - - - - - - -- · .NA Appr Date 37 .Seismicanalysjs_ o.f sballow gas~z.o[1es _ . .NA RPC 11/15/2004 38 _Seabed .conditi.o[1 slIrve-y _(if off-Shore) . . .NA - - - - - 39 . Conta_ct nam.elphOl1eJorweekly progress reports [exploratory.onlyl . . _ . _ _NA Geologic Engineering ~ Commissioner: Date: Commissioner: Date om . er Date DT·S 1/116/1-- -:0~y . . Well History File APPENDIX Information of detailed nature ttlat is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, 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. fJOt.¡-8-3'f Sperry-Sun Dr~ng Services LIS Scan Utility . $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 19 14:52:56 2006 #1<{ð~1 Reel Header Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ............ . UNKNOWN Continuation Number.. ....01 Previous Reel Name. .... ..UNKNOWN Comments. .............. ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments............... ..STS LIS writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 5-20B 500292213702 BP Exploration Sperry Drilling Services 19-APR-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003454678 D. RICHARDSO R. BORDES MWD RUN 2 MW0003454678 J. BOBBITT J. RALL MWD RUN 3 MW0003454678 J. BOBBITT J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 MW0003454678 J. BOBBITT J. RALL MWD RUN 4 MW0003454678 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 32 11N 15E 2911 5033 MSL 0) 62.60 34.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS Qo4-:J3<{ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 8.500 6.125 SIZE (IN) DEPTH (FT) 9.625 4706.0 7.000 8667.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 4706' MD/4706'TVD IN THE 5-20 WELLBORE. THE WHIPSTOCK WAS POSITIONED PRIOR TO THE ADDITION OF MWD TOOLS TO THE BHA. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2-4 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4) AND AT-BIT INCLINATION (ABI). MWD RUNS 3 & 4 ALSO INCLUDED STABILIZED LITHO-DENSITY (SLD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD PASS POROSITY DATA ACQUIRED OVER THE INTERVAL 9140'MD-9645'MD (BIT DEPTHS), WHILE RIH FOR MWD RUN 3, WERE MERGED WITH RUN 3 MWD DATA. MAD DGR AND EWR4 DATA ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER/ TELECO COMPOSITE GAMMA RAY LOG RUN IN 5-20 ON 22 APRIL 1991. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 24 MARCH 2006, AS AUTHORIZED BY PRIYA MARAJ (BP). 6. MWD RUNS 1-4 REPRESENT WELL 5-20B WITH API# 50-029-22137-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11750'MD/9031'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION .OR . (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.5 PPG MUD SALINITY: 3000 - 4000 FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ PPM CHLORIDES 10,994 PPM CHLORIDES File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPS RPD RPX RPM FET NPHI NCNT FCNT PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4660.0 4748.0 8647.0 8647.0 8647.0 8647.0 8647.0 9061. 5 9061. 5 9061. 5 9076.0 9076.0 9076.0 STOP DEPTH 11706.5 11758.5 11713.5 11713.5 11713.5 11713.5 11 713 .5 11670.5 11670.5 11670.5 11685.0 11685.0 11685.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 4668.0 4673.0 4680.0 4685.0 4691.0 4696.0 4705.0 4717.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD GR 4658.5 4663.0 4670.0 4674.5 4681.0 4684.5 4695.0 4708.0 BIT RUN NO 1 2 MERGE TOP 4650.5 8667.0 MERGE BASE 8667.0 9645.0 MWD MWD $ 3 4 . 9645.0 11301. 0 11301.0 11749.5 . # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value................. .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4660 11758.5 8209.25 14198 4660 11758.5 FCNT MWD CNTS 229.1 1396.08 623.479 5219 9061. 5 11670.5 NCNT MWD CNTS 16148.4 42267.7 28526.5 5219 9061.5 11670.5 RHOB MWD G/CM 2.048 3.199 2.33988 5219 9076 11685 DRHO MWD G/CM -0.253 0.823 0.0628881 5219 9076 11685 RPD MWD OHMM 0.56 2000 55.4091 6134 8647 11 713 .5 RPM MWD OHMM 0.59 2000 45.6497 6134 8647 11 713 .5 RPS MWD OHMM 0.57 1294.76 36.3885 6134 8647 11 713 .5 RPX MWD OHMM 0.54 1033.46 32.9213 6134 8647 11713.5 FET MWD HOUR 0.17 54.32 1. 91164 6134 8647 11 713.5 GR MWD API 5.13 528.4 86.317 14094 4660 11706.5 PEF MWD BARN 0.28 7.48 2.14675 5219 9076 11685 ROP MWD FT/H 0.11 417.62 122.845 14022 4748 11758.5 NPHI MWD PU-S 14.84 37.04 23.5552 5219 9061.5 11670.5 First Reading For Entire File......... .4660 Last Reading For Entire File.......... .11758.5 File Trailer Service name.......... ...STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .06/04/19 Maximum Physical Record..65535 File Type.. ............. .LO Next File Name.......... .STSLIB.002 . . Physical EOF File Header Service name... ....... ...STSLIB.002 Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation.... ...06/04/19 Maximum Physical Record. .65535 File Type.. .... ......... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS RPD RPX FET RPM RAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 9098.5 9106.5 9106.5 9106.5 9106.5 9106.5 9149.0 STOP DEPTH 9600.5 9607.0 9607.0 9607.0 9607.0 9607.0 9653.5 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 9089.0 MERGE BASE 9645.0 # 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 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MAD OHMM 4 1 68 4 2 RPM MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPX MAD OHMM 4 1 68 16 5 FET MAD HOUR 4 1 68 20 6 GR MAD API 4 1 68 24 7 RAT MAD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9098.5 9653.5 9376 1111 9098.5 9653.5 RPD MAD OHMM 5.7 152.22 37.3184 1002 9106.5 9607 RPM MAD OHMM 4.83 118.49 30.5877 1002 9106.5 9607 RPS MAD OHMM 4.8. 115.16 27.1116 1002 .106.5 9607 RPX MAD OHMM 5.13 85.22 23.7814 1002 9106.5 9607 FET MAD HOUR 17.42 27.65 23.009 1002 9106.5 9607 GR MAD API 8.47 151.92 46.5587 1005 9098.5 9600.5 RAT MAD FT/H -311.18 292.21 198.575 1010 9149 9653.5 First Reading For Entire File. ..... ... .9098.5 Last Reading For Entire File........ ...9653.5 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation.......06/04/19 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...... .06/04/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 4650.5 4739.0 STOP DEPTH 8637.5 8667.0 # 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: 28-DEC-04 Insite 66.37 Memory 8667.0 4738.0 8667.0 9.3 24.8 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 61497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPT~T) : 4325.0 . # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.30 72.0 9.4 3500 5.4 .000 .000 .000 .000 .0 140.0 .0 .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 .1IN Max frames per record............ . Undefined Absent value..... ...... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD010 ROP MWD010 Units FT API FT/H Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4650.5 8667 6658.75 8034 4650.5 8667 GR MWD010 API 5.13 397.11 102.874 7975 4650.5 8637.5 ROP MWD010 FT/H 0.37 362.81 130.661 7857 4739 8667 First Reading For Entire File......... .4650.5 Last Reading For Entire File....... ....8667 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF . File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPS RPM RPX RPD ROP $ 4 . header data for each bit run in separate files. 2 .5000 START DEPTH 8638.0 8638.0 8638.0 8638.0 8638.0 8638.0 8667.5 STOP DEPTH 9592.5 9599.5 9599.5 9599.5 9599.5 9599.5 9645.0 # 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 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 31-DEC-04 Insite 66.37 Memory 9645.0 8667.0 9645.0 20.7 87.7 TOOL NUMBER 160788 156404 6.125 8667.0 FLO-PRO SF 8.50 68.0 9.2 2750 10.0 1. 700 1.070 2.000 1.500 69.0 114.0 69.0 69.0 MATRIX DENSITY: HOLE CORRECTION (IN): . . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .... ... ......0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8638 9645 9141. 5 2015 8638 9645 RPD MWD020 OHMM 0.56 2000 127.373 1924 8638 9599.5 RPM MWD020 OHMM 0.59 2000 101. 782 1924 8638 9599.5 RPS MWD020 OHMM 0.57 1294.76 73.6597 1924 8638 9599.5 RPX MWD020 OHMM 0.54 1033.46 64.7514 1924 8638 9599.5 FET MWD020 HOUR 0.31 54.32 2.75812 1924 8638 9599.5 GR MWD020 API 12.7 528.4 56.7105 1910 8638 9592.5 ROP MWD020 FT/H 0.62 281. 92 81.5052 1956 8667.5 9645 First Reading For Entire File. .........8638 Last Reading For Entire File. ...... ....9645 File Trailer Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name..... ......STSLIB.005 Physical EOF File Header Service name... ......... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record. .65535 File Type............... ~ Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF DRHO RHOB GR RPX FET RPS RPM RPD ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 9052.5 9052.5 9052.5 9067.0 9571.0 9571.0 9593.0 9600.0 9600.0 9600.0 9600.0 9600.0 9645.5 STOP DEPTH 11213.0 11213.0 11213.0 11227.5 11227.5 11227.5 11249.0 11256.5 11256.5 11256.5 11256.5 11256.5 11301.0 # 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 SLD CTN EWR4 $ # BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB!G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 02-JAN-05 Insite 66.37 Memory 11301.0 9645.0 11301.0 85.7 94.0 TOOL NUMBER 160788 154267 10603684 156404 6.125 8667.0 FLO PRO SF 8.40 47.0 9.7 3350 8.6 1. 300 .720 1. 400 2.000 70.0 132.8 70.0 70.0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): . . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point......... .... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9052.5 11301 10176.8 4498 9052.5 11301 FCNT MWD030 CNTS 229.1 1396.08 622.751 4322 9052.5 11213 NCNT MWD030 CNTS 16148.4 42267.7 28466.2 4322 9052.5 11213 RHOB MWD030 G/CM 2.089 3.067 2.31842 3314 9571 11227.5 DRHO MWD030 G/CM -0.253 0.406 0.0570244 3314 9571 11227.5 RPD MWD030 OHMM 9.94 44.02 21. 518 3314 9600 11256.5 RPM MWD030 OHMM 8.88 39.42 19.2078 3314 9600 11256.5 RPS MWD030 OHMM 8.12 39.69 18.7296 3314 9600 11256.5 RPX MWD030 OHMM 7.63 44.56 17.783 3314 9600 11256.5 FET MWD030 HOUR 0.17 17.4 1.10213 3314 9600 11256.5 GR MWD030 API 24.57 172 . 12 63.4838 3313 9593 11249 PEF MWD030 BARN 0.28 7.48 2.10427 4322 9067 11227.5 ROP MWD030 FT/H 0.45 417.62 139.307 3312 9645.5 11301 NPHI MWD030 PU-S 14.84 37.04 23.5441 4322 9052.5 11213 First Reading For Entire File......... .9052.5 Last Reading For Entire File.......... .11301 File Trailer Service name.... ........ .STSLIB.005 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .06/04/19 Maximum Physical Record. .65535 File Type.... ........... ~ Next File Name.......... .STSLIB.006 Physical EOF File Header Service name...... ...... .STSLIB.006 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......06/04/19 Maximum Physical Record..65535 File Type... ..... ..... ...LO Previous File Name.... ...STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI NCNT FCNT PEF DRHO RHOB GR RPX RPD RPS RPM FET ROP $ 6 . header data for each bit run in separate files. 4 .5000 START DEPTH 11213.5 11213.5 11213.5 11228.0 11228.0 11228.0 11249.5 11257.0 11257.0 11257.0 11257.0 11257.0 11301.5 # 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 SLD CTN EWR4 $ # STOP DEPTH 11661.5 11661.5 11661. 5 11676.0 11676.0 11676.0 11697.5 11704.5 11704.5 11704.5 11704.5 11704.5 11749.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 03-JAN-05 Insite 66.37 Memory 11750.0 11301.0 11750.0 86.7 93.7 TOOL NUMBER 160788 154267 10603684 156404 6.125 8667.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . Flo-pro 8.50 46.0 9.4 2800 7.8 . 1. 300 .680 1. 400 2.000 70.0 140.0 70.0 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 .1IN Max frames per record. ......... ...Undefined Absent value....... ....... ...... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11213.5 11749.5 11481. 5 1073 11213.5 11749.5 FCNT MWD040 CNTS 373.41 1074.14 626.986 897 11213.5 11661.5 NCNT MWD040 CNTS 23555.9 37560.8 28817.1 897 11213.5 11661.5 RHOB MWD040 G/CM 2.099 3.12 2.44733 897 11228 11676 DRHO MWD040 G/CM - 0.114 0.823 0.069903 897 11228 11676 RPD MWD040 OHMM 13.57 73.75 26.232 896 11257 11704.5 RPM MWD040 OHMM 11.23 61.78 22.9147 896 11257 11704.5 RPS MWD040 OHMM 11.31 53.61 21.6695 896 11257 11704.5 RPX MWD040 OHMM 10.93 53.32 20.5629 896 11257 11704.5 FET MWD040 HOUR 0.47 18.01 3.08808 896 11257 11704.5 GR MWD040 API 17.56 178.1 86.3476 897 11249.5 11697.5 PEF MWD040 BARN 1. 31 6.32 2.35143 897 11228 11676 ROP MWD040 FT/H 0.11 243.21 83.7371 897 11301.5 11749.5 NPHI MWD040 PU-S 17.3. 31.54 23.6089 897 First Reading For Entire File... ..... ..11213.5 Last Reading For Entire File.. ....... ..11749.5 File Trailer Service name....... ......STSLIB.006 Service Sub Level Name... Version Number... ..... ...1.0.0 Date of Generation.......06/04/19 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...... .06/04/19 Maximum Physical Record. .65535 File Type......... .... ...LO Previous File Name.... ...STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPS RPM RPX FET RAT $ 7 .213.5 11661. 5 for each pass of each run in separate files. header data .5000 3 1 START DEPTH 9089.5 9097.5 9097.5 9097.5 9097.5 9097.5 9140.0 # 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 $ STOP DEPTH 9591.5 9598.0 9598.0 9598.0 9598.0 9598.0 9644.5 02-JAN-05 Insite 66.37 Memory 9645.0 9089.0 9645.0 85.7 94.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 160788 156404 # . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point......... .... . Undefined Frame Spacing................ .... .60 .1IN Max frames per record....... ..... . Undefined Absent value......... ...... .......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.125 8667.0 FLO PRO SF 8.40 47.0 9.7 3350 8.6 1. 300 .720 1. 400 2.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MAD031 OHMM 4 1 68 4 2 RPM MAD031 OHMM 4 1 68 8 3 RPS MAD031 OHMM 4 1 68 12 4 RPX MAD031 OHMM 4 1 68 16 5 FET MAD031 HOUR 4 1 68 20 6 GR MAD031 API 4 1 68 24 7 RAT MAD031 FT/H 4 1 68 28 8 Name DEPT RPD RPM RPS RPX FET GR RAT Service Unit FT MAD031 OHMM MAD031 OHMM MAD031 OHMM MAD031 OHMM MAD031 HOUR MAD031 API MAD031 FT/H Max 9644.5 152.22 118.49 115.16 85.22 27.65 151. 92 292.21 Min 9089.5 5.7 4.83 4.83 5.13 17.42 8.47 -311.18 First Reading For Entire File......... .9089.5 Last Reading For Entire File.......... .9644.5 Mean 9367 37.3184 30.5877 27.1116 23.7814 23.009 46.5587 198.135 Nsam 1111 1002 1002 1002 1002 1002 1005 1010 . 70.0 132.8 70.0 70.0 First Reading 9089.5 9097.5 9097.5 9097.5 9097.5 9097.5 9089.5 9140 Last Reading 9644.5 9598 9598 9598 9598 9598 9591. 5 9644.5 . File Trailer Service name.... .........STSLIB.007 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation.. .... .06/04/19 Maximum Physical Record..65535 File Type............ ... .LO Next File Name.......... .STSLIB.008 Physical EOF . Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... .....UNKNOWN Continuation Number. .... .01 Next Reel Name..... ..... . UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File