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Home My WebLink About202-198MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-114A PRUDHOE BAY UN AURO S-114A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 S-114A 50-029-23116-01-00 202-198-0 W SPT 6579 2021980 1645 983 982 981 980 157 337 334 330 4YRTST P Guy Cook 2/4/2023 Testing done with a Little Red pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S- 114A Inspection Date: Tubing OA Packer Depth 472 2522 2494 2488IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230204053929 BBL Pumped:2.2 BBL Returned:2.2 Friday, March 17, 2023 Page 1 of 1             3%86$ +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. $'/ 1RQH1RQH / %DNHU63HUP3DFNHU 1R6669,QVWDOOHG 1R6669,QVWDOOHG 0RQW\0\HUV 'ULOOLQJ0DQDJHU 7UHYRU+\DWW WUHYRUK\DWW#KLOFRUSFRP 358'+2(%$<$8525$2,/ $XJXVW 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& 6.1.2022 By Meredith Guhl at 10:06 am, Jun 02, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 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N)ODQJH;2WLV%R[ +\GULO $QQXODU 3LSH6OLSV N0XG &URVV 3LSH6OLSV %OLQG6KHDU 0XG &URVV 9%5V MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou LaubenStein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 12, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 5-114A PRUDHOE BAY UN AURO 5-114A Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN AURO S- API Well Number 50-029-23116-01-00 Inspector Name: Lou Laubenstein 114A Insp Num: mitLOL190203160719 Permit Number: 202-198-0 Inspection Date: 2/3/2019 . Rel Insp Num: r 5 -114A 2021980 mped: Notes: Packer Depth Ly pelnj U "TVD 6579 Tubing pe Test S11T Test psi 1645 IA 29 13BL Returned: 2,5 OA 4YRTST P/F P �/ Pretest Initial 15 Min 30 Min 45 Min 60 Min 1412 14121412 1-112 547 2502 - 2198 2405 160 =2l - 3 ?'1 Tuesday, February 12, 2019 Page 1 of I MEMORANDUM State of Alaska Well S-1 14A Alaska Oil and Gas Conservation Commission TO: Jim Regg2 p 3IYI DATE: Tuesday, March 5, 2019 P.I. Supervisor 'C CI r SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION (ALASKA) INC. BBL Pumped: S-1 14A FROM: Lou Laubenstein PRUDHOE BAY UN AURO S-1 14A Petroleum Inspector PIF Notes: Sre: Inspector 323 ' Reviewed By: P.I. Supry r t! NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S- API Well Number 50-029-23116-01-00 Inspector Name: Lou Laubenstein 114A Permit Number: 202-198-0 Inspection Date: 2/22019 � Insp Num: mitLOL190203160719 Rel Insp Num: Depth Pretest Initial Packer Well S-1 14A Type lnj N 'TVD 1412 141'_ PTD 2021980 'Type Testj ser Test psi BBL Pumped: 2.9 BBL Returned: Interval 4YRTST PIF Notes: 1 13 _ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6579 iTubing 1412 141'_ 1412 1412 1645 IA 547 2502 2496 241) z2.5160 OA 1 13 _ 323 ' 321i P Tuesday, March 5, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,February 12,2015 TO: Jim Regg i7 7) P.I.Supervisor \'' 71 "1 ZO/15_ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S-114A FROM: Jeff Jones PRUDHOE BAY UN AURO S-1 14A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 213R— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S- API Well Number 50-029-23116-01-00 Inspector Name: Jeff Jones 114A Permit Number: 202-198-0 Inspection Date: 2/10/2015 Insp Num: mitJJ150210171231 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-114A 1-Type Inj W• ITVD 6579 .TTubing 2338 2338 2338 - 2337 1— PTD 2021980 • Type Test SPT Test psi 1645 - IA 1 520 - 3002 - 2989 • 2986 - Interval 4YRTST P/F P / OA 146 355 349 345 Notes: 3 BBLS methanol pumped 1 well inspected,no exceptions noted. - SCANNED i1-'!1 Thursday,February 12,2015 Page 1 of 1 C~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, • ' ~ , C~ ~s~~ ~--~_ ~--~ f l 1-~ ~uL ~ ~. zoo~ ~~,~~@~°u ~i! ~ ~~: ~~ne~ Ca~rr~~~~~~~ ~~r~r~~;~ f;~ ~D~~~~~ S "` ' ~ ~.. ,~ Enclosed please find a spreadsheet with a list of wells from S-Pad 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, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~~~~~~;~ ~ ~~ << f- 20C~~ Torin Roschinger BPXA, Well Integrity Coordinator . BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad \ ~ I]A}Y 6/95/2009 Well Name PTD a~ Initial rop of cement Vol. of cement um ed Final top of cement Cement top off tlate Cortosion inhibitor COffO510f1 inhibitod sealant date ft bbis ft na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1g57890 0 NA 0 NA 0.9 SYL6/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S•07A 1920980 0 NA 0 NA O.s 5/26/2009 S-08B 2010520 0 NA 0 NA 0.85 5/27/2009 S-o9 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31l2009 S-11B 1990530 025 NA 025 NA 1.7 5/27I2009 S-12A 1851930 025 NA 025 NA 7.7 6/1/2009 S-13 1827350 8 NA 8 NA 55.3 6/1/2009 S•15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19I2009 S-20A 2010450 025 NA 025 NA 1.3 5/19/2009 5-27 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B Y970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26I2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31I2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 7960120 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA 5.1 5/31I2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 /921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 5-35 1921480 0 NA 0 NA .85 in 5/31/2009 S-3s 1921160 0.75 NA 0.75 NA az5 5/27/2009 S-37 1920990 1.25 NA 125 NA 77.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27/2009 S-at 1960240 1.5 NA 1.5 NA 17.7 5/30/2009 S-a2 1960540 0 NA 0 NA O.s 5/30/2009 S-a3 1970530 0.5 NA 0.5 NA 7J 5/28/2009 S-44 1970070 025 NA 025 NA t7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29/2009 S-t02L7 2037560 125 NA L25 NA 7tt 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-106 2070120 1625 NA 1625 NA 174.3 6l2/2009 S-107 2011t30 2.25 NA 225 NA 28.9 5/78/2009 5-708 2017000 3.5 NA 3.5 NA a0 5/30/2009 S40s 2022450 2 NA 2 NA 21.3 5/30/2009 S410 2011290 1175 NA 1175 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2027350 0 NA 0 NA 0.5 5/30/2009 S-713 2021430 1.75 NA 1J5 NA 22.1 5/18/2009 ~ S71aA 2021980~ 125 NA 125 NA 10z 5/30/2009 S-t75 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 1.5 NA t3.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-1~8 2032000 5 NA 5 NA 76.5 5/28/2009 S-t79 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060470 4.5 NA 4.5 NA 53.6 5/28/2009 5-~22 2050810. 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1J5 NA 1.75 NA 11.9 5/26I2009 S-125 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/t/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.&5 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 0.25 NA 025 NA t.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 5~401 2060780 16 NA 16 NA 99.5 6/2/2009 S-SOa 0 NA 0 NA 0.85 5/28/2009 ~ U . . E'TIail to Winton _"ubert@admin.state.ak.us; Bob _Fleckenstein@admin.state akus: Jim_Regg@adminstateak.us; T ûm_Maunder@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska) Inc Prudhoe Bay I PBU I S pad 03/12/07 Andrea Hughes ~ert '3/ /0( 07 J OJ.. -I q~ Packer Depth Pretest Initial 15 Min. 30 Min. We111S-114A I Type Inj. I W TVO I 6,579' Tubing 2,500 2,500 2,500 2,500 InterJal1 4 P.To.12021980 I Type test I P T est psi! 4000 Casi ng 750 4,000 4,000 4,000 P/FI P Notes: AOGCC declined to witness MIT-IA for Regulatory OA 280 550 550 550 Compliance. Weill I Type Inj. I TVO I Tubing Interval! prol I Type test I T est psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing I Interval I PTO.I I Type test I Test psi! Casing I P/FI Notes: OA I Weill I Type tnj.1 TVO I Tubing I I Interval I PTo.1 I Type test I Test psil Casing I I PIFI Notes: OA I I I I Weill I Type Inj.1 TVO I Tubing j I I Interval I p.Tol I Type testl Test psil Casing I I I PIFI Notes: OA I I I TYPE INJ Codes o :::: Drilling 'Waste G = Gas I :: Industria! Wastewater N = Not Injecti n9 W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes Iv1 = Annulus Monitoring p::: Standard Pressure Test R ::: Internal Radioactive Tracer SUIVey A::: Temperature Anomaly Survey 0::: DIfferential Temperature Test INTERVAL Codes I :::: Initial Test 4:::: Four Year Cycle V :::: Required by Variance T = Test during Workover 0::: Other (describe in notes) sCANNED MAR 2 7 2007 MIT PBU S-114A 03-12-07xI5 / STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 0 6 2006 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 L,;J , Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Aß'dl91tQtß Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 202-1980 3. Address: P.O. Box 196612 Stratigraphic 0 Service .(;4 6. API Number: Anchorage, AK 99519-6612 50-029-23116-01-00 7. KB Elevation (ft): 9. Well Name and Number: 70.2 OF S-114A 8. Property Designation: 10. Field/Pool(s): ADL-028258 Prudhoe Bay Field/ Aurora Oil Pool 11. Present Well Condition Summary: Total Depth measured 14890 feet Plugs (measured) None true vertical 7162.22 feet Junk (measured) None Effective Depth measured 14460 feet true vertical 6789.59 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 35 - 115 35 - 115 1490 470 Surface 208760 10-3/4" 45.5# L-80 34 - 6140 34 - 3370.15 5210 2480 Production 480315 7" 26# L-80 33 - 14555 33-6871.19 7240 5410 ..:;.X.... ,i', Perforation depth: Measured depth: 14388 - 14420 - - ,..... "tv ... ._". - True Vertical depth: 6727.82 - 6755.27 - - - - Tubing: (size. grade, and measured depth) 4-1/2" 12.6# L-80 28 - 14270 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 14213 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JUL 11 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 3892 0 1782 Subsequent to operation: 0 0 224 0 3011 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 01 Development Service M Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 Gas 0 WAG MI GINJ 0 WINJ 0 WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Signature Phone 564-4424 Date 6/28/2006 n Form 10-404 Revised 04/2004 n R I h , f\1 ,1 , Submit Original Only 06121/06 Scblumbergep ~ .", Li ,). Od-~lqO 1 C-" 9 NO. 3862 Schlumberger-DCS 2525 Gamboll SI. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well Job# Log Description Date BL Color CD S-111 11216189 MEMORY INJECTION PROFILE 04115/06 1 S-114A 10572082 RST UPFLOW WFL 03/01/03 1 Y-105 10663005 INJECTION PROFILE 03/12/04 1 E-103 10560276 TEMPERATURE WARMBACK 06/22/03 1 Y-214 11162720 UBI 11/24/05 1 Y-213 11076450 INJECTION PROFILE 07/01/05 1 Y-216 11076451 INJECTION PROFILE 07/02/05 1 Y-221 11058523 INJECTION PROFILE 07/03/05 1 L-103 N/A INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08/20/05 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07/19/05 1 e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: r.ft Schlumberger-DC5 2525 Gambel! 51, Suite 400 Anchorage, AK 99503-2838 A TTN: Both BP Exploration (Alaska) Inc. Petrotechnicel Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received by: e RECEIVED JUN 2 3 2006 ~Jaska Oft .& Gas Ccns. Ccmmission AI'IcMrage 'd- . . " .~ >r -, MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ') ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 23, 2003 RE: MWD Formation Evaluation Logs: S-114 & S-114A, AK-MW-22152 8-114 & S-114A: ~ I ~ 3 '-t ~ Digital Log Images: 50-029-23116-00,01 1 CD Rom SCANNED; NO" 0 22D05 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:l) Q~ ~~ Signed: ~oL,' ~\X~ t Cft1 G j~ ~.ç- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Well Name/No. PRUDHOE BAY UN AURO S-114A Permit to Drill 2021980 Operator BP EXPLORATION (ALASKA) INC MD 14890'/ -,---- API No. 50-029-23116-01-00 ~.. .-' TVD 7162./ Completion Date 12/6/2002/ Completion Status 1-01L Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -----~- DATA INFORMATION ----- MWD, GR, RES, DEN, NEU, PWD (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt .:¿~ -l-c5g ~ '1:õg ~' ~D Rpt ~g ~/D ~Pt ~ D Electr Dataset Number Name :A::asing collar locator ...,/ Gamma Ray f.)IVater Flow JCement Evaluation ~; Log Log Run Scale Media No 5 Blu 1 5 Blu Col 5 Blu Interval OH / Start Stop CH Received Comments 1:.f.if'o00 14446 Case 12/20/2002 ~ÒOO 14446 Case 12/20/2002 j.f4204 14434 Case 5/13/2003 4ió00 14446 Case 12/20/2002 Directional Survey 11664 LIS Verification 12142 14890 Open 1 0/17/2002 MWD 59 14843 Open 4/17/2003 12142 14890 Open 1 0/17/2002 5 Blu c..r4000 14446 Case 12/20/2002 5 Blu 4000 14446 Case 12/20/2002 12142 14890 Open 1 0/17/2002 59 14843 Open 4/17/2003 12142 14890 Open 1 0/17/2002 MWD Sample Set Sent Received Number Comments '-~ Directional Survey JTemperature J Pressure Directional Survey LIS Verification Directional Survey Well Cores/Samples Information: Name Interval Start Stop DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021980 Well Name/No. PRUDHOE BAY UN AURO S-114A OperàtorBP EXPLORATION (ALASKA) INC API No. 50-029-23116-01-00 MD 14890 TVD 7162 Completion Date 12/6/2002 Completion Status 1-01L Current Status 1WINJ UIC Y ADDITIONAL INFORMATION v€) Daily Hi~tory Received? ()N Well Cored? Chips Received? <:':TI"N--- Formation Tops ~ (j)/N Analysis Received? ....Y../-N'- . -----~ Comments: '~''''._il/ Compliance Reviewed By: ~ Date: (7 í . Je~^-.L'-ò \.-- _.._---,------------ --------- - z Scblum~erger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well S-114A ,bSna-19 1) S-107 <.10/-1 ) 3 Job# Log Description RST UPFLOW WFL INJECTION PROFILE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED MAY 13 2003 Alaska at: & Gas Cons. Commission Anchorage 03/01/03 04/30/03 NO. 2775 05/08/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Date Sepia BL Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: ~eth ,= ... Receive by: , Color CD ~ (~ --"'/ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Converted to Water Injector 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 662' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 956'FNL,4505'FEL,Sec.28, T12N, R12E, UM At effective depth 954'FNL,4522'FEL,Sec.28,T12N, R12E,UM At total depth 801'FNL,4704'FEL, Sec. 28, T12N, R12E,UM 12. Present well condition summary Total depth: measured true vertical 14890 feet 7162 feet Prudhoe Bay Unit 8. Well number S-114 A 9. Permit number / approval number (asp's 608277, 5985646)~ 202-1981 302- 10. API number Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X (asp's 618929,5980821) (asp's 608260,5985648) (asp's 608075,5985798) Plugging - Perforate _X Repair well - Other _X Conversion 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name ~ 50-029-23116-01 11. Field / Pool Prudhoe Bay Field I Aurora Pool Plugs (measured) Tagged TD @ 14410' (02/25/2003). Effective depth: measured 1441 0 feet Junk (measured) true vertical 6747 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 115' 20" 260 sx AS (approx) 149' 149' Surface 6106' 10-3/4" 942 sx ArcticSet Lite III, 6140' 3370' 726 sx Class 'G' Production 14524' 7" 445 sx Class 'G' 14555' 6871' Perforation depth: measured Open Perfs 14388'-14408' true vertical Open Perfs 6728'-6745'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 14269'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 14213'. 4-1/2" HES 'X' Nipple @ 2323'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Prior to well operation SHUT-IN Subsequent to operation 03/07/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil- Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~J~ Trtle: Technical Asslstan' DeWayne R. Schnorr RBDMS BFl 3D APR 8+ 20U3 Form 10-404 Rev 06/15/88 . RECEIVED APR 1 8 Z003 Alaska Oil & Gas Cons. Commission Anchorage Casing Pressure Tubing Pressure 4810 870 16. Status of well classification as: Suspended - Service Water Iniector Date April 16. 2003 Prepared by DeWayne R. Schnorr 564-5174 ORIG,NA- SUBMIT IN DUPLICATE ~ 01/30/2003 02/09/2003 02/09/2003 02/13/2003 02/14/2003 02/25/2003 03/01/2003 03/07/2003 03/12/2003 03/13/2003 03/13/2003 03/14/2003 04/15/2003 ) ) S-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS NEW WELL POST: HOT OIL TREATMENT NEW WELL POST: PERFORATING NEW WELL POST: HOT OIL TREATMENT; PERFORATING NEW WELL POST: PERFORATING NEW WELL POST: RST / CNL / PNL; STATIC BOTTOM HOLE PRESSURE NEW WELL POST: DRIFT/TAG NEW WELL POST: RST / CNL / PNL; STATIC BOTTOM HOLE PRESSURE SURVEY FIRST DAY OF WATER INJECTION AFTER CONVERSION. ANN-COMM (UIC PROGRAM): AC-BLEED; AC-EVAL; AC-FLUID LEVEL ANN-COMM (UIC PROGRAM): AC-MITIA ANN-COMM (UIC PROGRAM): AC-MITIA ANN-COMM (UIC PROGRAM): AC-MONITOR TESTEVENT --- INJECTION PRESSURE, PSI: 1,966 TYPE: PW, VOLUME: 11,554 BWPD. EVENT SUMMARY 01/30/03 HOT OIL TUBING WITH 455 BBLS OF 190 DEGREE F CRUDE. 02/09/03 ATTEMPT TO PERFORATE UNSUCCESSFUL. PU 3.511 ROLLERS - 20127/811 HSD GUN 6 SPF FULLY LOADED - SAFE FIRING ASSY - CCL - HEAD. OAL: 311. MAX OD: 3.511 ROLLERS. SET DOWN AT 118801, WORK TO 123501 UNABLE TO FALL FURTHER. PUMPED 286 BBL OF HOT CRUDE TO PUSH TOOLS DOWN. COULD NOT GET DOWN WITH GUN. SUSPECT TIGHT FLOWTUBES, WILL CONFIRM IN CABLE SHOP TOMORROW. WEATHERED IN FOR 2 DAYS. 02/09/03 ASSIST E-LlNE. PUMPED 286 BBLS OF CRUDE DOWN THE TUBING @ 180 DEGREES. 02/13/03 PERFORATE INTERVAL: 143881-144081.2-7/811 HSD PJ 2906 GUN - 6 SPF /60 DEG RANDOM. API SPECS IN 4-1/211 : PEN= 27.711 EHD= 0.3611. RIH WITH 201 GUN STRING AND TAG TD AT 104271. UPPER INTERVAL CHANGED TO ACCOMMODATE 201 GUN. PERFORATE INTERVAL 143881-144081 REFERNCED TO MWD GR PLOTTED ON 24-SEPT-2002 AND TIED INTO INTERVAL COLLARS ON SCMT JEWELRY LOG DATED 5-DEC-2002. PAD OPERATOR NOTIFIED WELL TO BE LEFT SHUT IN - WILL BACK IN MORNING TO LOG RST. 02114/03 ATTEMPT RST WATERFLOW LOG WITH PRESSURE / TEMP LOG. COULD NOT GET TOOLSTRING PAST MASTER. TRY AND PUMP DOWN WITH HOT DIESEL (LRS), CAN PUMP INTO WELL BUT TOOLS WILL NOT FALL. BREAK OFF AND INSPECT TOOLS - LOOK OK. STAB ONTO WELL AND PUMP 60/40 (LRS). SAME RESULT. RDMO. PAD OPERATOR NOTIFED WELL LEFT SHUT IN. 02125/03 «< WELL SHUT IN UPON ARRIVAL »> DRIFT & TAG UNABLE TO LOC TTL,TD @ 14,4101 WLM. Page 1 03/01/03 ) ') S-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WFL & SBHTS. LOG BASELINE TEMP FROM TT TO TD. TIE IN TO SWS SCMT LOG DATED 5 DEC 2002. LOG STATIC BOTTOM HOLE PRESSURE/TEMP. DIFFICULTY FALLING BELOW 127001. TAG TD AT144361 WORK TOOLS DOWN. LOG INJECTION PROFILE PASSES & UPFLOW WFL STATIONS (AT 143881, 143501). «< NO UPFLOW DETECTED BEHIND CASING »>. NOTIFY PAD OP OF WELL STATUS: LEFT ON INJECTION. 03/07/2003 FIRST DAY OF WATER INJECTION AFTER CONVERSION. 03/12/03 TIO=1 020/1350/340 PREP FOR AOGCC WITNESSED MITIA. IA FL @ 3001 (6 BBLS). BLEED lAP FROM 1350 PSI TO 140 PSI IN 2.5 HOURS. FINAL WHPs = 1020/140/340. 03/13/03 T/I/O = 1020/300/280. MIT - IA TO 1910 PSI. PASSED. (AOGCC WITNESS, CHUCK SCHEVE). PRESSURED IA TO 1910 PSI WITH 9 BBLS OF METHANOL. STARTED 30 MINUTE TEST. IA LOST 0 PSI IN 30 MINUTES. BLED IA TO 270 PSI. FINAL WHpls = 1020/270/300. 03/13/03 MIT IA TO 1900 PSI WITH 9 BBLS OF METHANOL PASSED. 03/14/03 T/I/O = 1100/270/300. TEMP = HOT. MONITOR WHp.s. (POST MITIA). lAP REMAINED THE SAME SINCE YESTERDAY. 04/15/03 TESTEVENT --- INJECTION PRESSURE, PSI: 1,966 TYPE: PW, VOLUME: 11,554 BWPD. BBLS 3 9 20 25 741 798 FLUIDS PUMPED PRESSURE TEST LUBRICATOR WITH DIESEL, (4 TESTS) METHANOL 60/40 METHANOL WATER DIESEL CRUDE TOTAL ADD PERFS 02/13/2003 THE FOLLOWING INTERVAL WAS PERFORATED WITH THE 2-7/8" PJ 2906, 6 SPF, 60 DEGREE PHASED GUN, RANDOM ORIENTION. 143881 - 144081 Page 2 ) ) Ó(OêJ-/9i / 110"'</ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 01, 2003 RE: MWD Fonnation Evaluation Logs S-114A, AK-MW-22152 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23116-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: \LJ. I I)". - ì Signed: ~ t..tJ&r.!<A.J (:) 1=,". C', ',~ C,: - -., 1\ I" ' 'E';:, ~D"ì>W" . Ü '\~'~!i V'- APR í í' 2003 AJaska 0;'; & Gas ¡)}mmh~ AnClior!"~~ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description S-114A aO~ -¡Cj}t S-215 aOa-J5Lj 22534 SCMT 22525 SCMT 12/05/02 11/16/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. RECE\VED Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Alaska O~¡ & Gas Cons. Commission Anchorage DEC 20 2.002 Date Delivered: Date NO. 2616 12/17/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Aurora Color Sepia 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Receive~ø- BL CD ,--",' LlO~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of Well II Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4617' NSL, 4496' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 43241 NSL, 4505' WEL, SEC. 28, T12N, R12E, UM At total depth 4478' NSL, 4704' WEL, SEC. 28, T12N, R12E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 70.2' ADL 028258 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 9/19/2002 . 9/21/2002 ' 12/612002 .. 17. Total Depth (MD+TVD) 18. Plug Back Depth.(MD+TVD) 19. Directional Survey 14890 - 7162 FT 14460 6790 FT II Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, PWD 23. CASING SIZE 20" 10-3/4" 7" Classification of Service Well Pre-Produced Injector 7. Permit Number 202-198 8. API Number 50-029-23116-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-114A 11. Field and Pool Prudhoe Bay Field / Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2323' MD 1900' (Approx.) 'Y tJ~-w.! 12.ISf' "no, þ ~ zS"2. ' ?'Ý..l) WT. PER FT. 91.5# 45.5# 26# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 115' 30" ,260 sx Arctic Set (Approx.) 34' 6140' 13-1/2" 942 sx Articset Lite III, 726 sx 'G' 31' 14555' 9-7/8" 445 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 14406' . 14420' 6743' - 6755' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 14270' PACKER SET (MD) 14213' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 88 Bbls of Diesel 27. Date First Production December 7, 2002 Date of Test Hours Tested 12/9/2002 4 Flow Tubing Casing Pressure Press. 295 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 306 CALCULATED 24-HoUR RATE OIL-BBL GAs-McF 13,384 GAs-McF WATER-BBL -0- WATER-BBL CHOKE SIZE 900 OIL GRAVITY-API (CORR) GAS-OIL RATIO 43,739 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiR E C E , V E D No core samples were taken. .2 3 28. DEC 1 9 2002 RBDMS 8FL 'j, r: Alaska Oil & Gas Cons. Commislion Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate ') ") 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. HRZ 14152' 6527' Kalubik 14374' 6716' Kuparuk C 14387' 6727' Kuparuk B 14600' 6910' Kuparuk A 14686' 6984' Miluveach 14772' 7059' RECEIVED DEC 1 9 2002 31. List of Attachments: Summ~ry of Daily Drilling Reports and Post Rig Work, Surveys Alaska Oil & Gas Cons. Commission ^nc~101i~aC 32. I ~erebY certify that the fO~Oing_iS true and correct to the best of my knowledge Signed Te"ieHubble /'{~ ~ Title Technical Assistant Date l{).../Ic;/O~ S-114A 202-198 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: 8-114 Common Name: 8-114 Test Date Test Type -.-" - ......_..m. --,--- ---".. .. .....----- .... 9/10/2002 LOT BP EXPLORATION Leak-Off Test Summary I Test Depth (TMD) , Test Depth (TVD) ..... ... ._u_- -- -. -.. ....-.........--. ... ....----.. 6,140.0 (ft) 3,375.0 (ft) AMW 9.40 (ppg) I Surface Pressure! Leak Off Pressure (BHP) .. ... ., -- - .-.. . . ..... 2,748 (psi) 1 ,1 00 (psi) Page 1 of 1 EMW 15.67 (ppg) ~' ""-'< Printed: 9/30/2002 9:17:50 AM ) -) BP EXPLORATION Operations Summary Report Page 1 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/3/2002 12:00 - 12:30 0.50 MOB P PRE Held PJSM. Secured Rig Floor. 12:30 - 13:00 0.50 MOB P PRE Skidded Rig Floor. 13:00 - 17:00 4.00 MOB P PRE Moved off of S-18A. Moved in Rig and Spotted over S-114. 17:00 - 18:00 1.00 MOB P PRE Shimmed and Set Rig. 18:00 - 19:00 1.00 MOB P PRE Skidded Drill Floor into position and connected lines. Spotted Cuttings Tank. 19:00 - 21 :00 2.00 DIVRTR P SURF Held PJSM. Measured RKB's. N / U Diverter and Diverter Line. Took on Spud Mud and Water. Accepted Rig at 1900 hrs 9 I 31 2002. 21 :00 - 00:00 3.00 DIVRTR P SURF Loaded Pipe Shed wI 5" DP. M I U Lines Under Rig Floor. 9/4/2002 00:00 - 02:30 2.50 DRILL P SURF Held PJSM. R I U 5" DP Handling Equipment. P I U Bails and Elevators. 02:30 - 08:30 6.00 DRILL P SURF Held PJSM. M I U and Stood back in Derrick 25 Stands of 5" Drill Pipe and 7 Stands of 5" HWDP. 08:30 - 09:00 0.50 DIVRTR P SURF Function Tested Diverter System, OK. Koomey Test, OK. Witnessing of Diverter Function Test waived by AOGCC Rep Jeff Jones. 09:00 - 10:30 1.50 DRILL P SURF Held PJSM. M I U BHA #1. 13-1/2" Security XL 1 N Bit, Ser# 744995, dressed w/1x14, 3x18 jets, 8" SperryDrill Lobe 6/7 4.0 stg Motor, 12.18" Undergauge Sleeve Stabilizer, XO, Float Sub, Pony Flex Collar, Hang Off Sub, Orienting Sub, Pony Flex Collar, Flex Collar and Drilling Jars. Total BHA Length- 146.87'. 10:30 - 11 :00 0.50 DRILL P SURF Held Pre-Spud Meeting. 11 :00 - 13:00 2.00 DRILL P SURF M / U Top Drive, Circulated Mud System to Shear Gels through Bit Nozzles. R I U Slickline for Gyro Runs. 13:00 - 00:00 11.00 DRILL P SURF Drilled 13-1/2" Directional Hole by Rotating and Sliding from 115' to 744'. WOB 5,000# - 35,000#, RPM 50, Motor RPM 83, Torque Off Bottom 1,000 ft Ilbs - On Bottom 3,000 ft / Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,350 psi, On Bottom 1,450 psi. Took Gyro Surveys every 90'. ART = 2.62 hrs, AST = 2.45 hrs. Total Krevs = 33 9/5/2002 00:00 - 22:30 22.50 DRILL P SURF Drilled 13-1/2" Directional Hole by Rotating and Sliding from 774' to 2,401'. WOB Sliding 35,000# - 50,000#, WOB Rotating 25,000# - 40,000# RPM 50, Motor RPM 83, Torque Off Bottom 3,000 ft Ilbs - On Bottom 8,000 ft Ilbs, Pump Rate 550 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,100 psi. Took Gyro Surveys every 90' to 1,300'. ART = 4.82 hrs, AST = 8.93 hrs. 22:30 - 23:30 1.00 DRILL P SURF Circulated Bottoms Up. Pump Rate 550 gpm, SPP 1,800 psi. Circulated until Returns over Shakers Cleaned Up. Flow Checked Well, Well Static. 23:30 - 00:00 0.50 DRILL P SURF POOH fl Bit Trip from 2,401' to 1,650'. Maximum Overpull 35,000#, Average Drag 3,000#. 9/6/2002 00:00 - 01 :30 1.50 DRILL P SURF Held PJSM. POOH f/ Bit Trip from 1,650' to Surface. Maximum OverpuIl10,000#, Average Drag 3,000#. 01 :30 - 03:00 1.50 DRILL P SURF Held PJSM. M / U BHA #2.13-112" STC MGXi-C Bit, Ser# ML3092, dressed w/ 1x12, 1x14, 2x20 jets, 8" SperryDrill Lobe 6/7 4.0 stg Motor w/ 1.5 deg Bent Housing, 13.125" Undergauge Sleeve Stabilizer, XO, Float Sub, Pony Flex Collar, Hang Off Sub, Orienting Sub, Pony Flex Collar, Flex Collar, Drilling Jars and 21 Jts 5" HWDP. Total BHA Length - 774.74'. Changed Out MWD Pulser. M I U Top Drive and Printed: 9/30/2002 9:18:00 AM ") ) BP EXPLORATION Operations Summary Report Page 2 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/6/2002 01 :30 - 03:00 1.50 DRILL P SURF Surface Tested MWD Tools, OK. 03:00 - 04:00 1.00 DRILL P SURF RIH w/ 13-1/2" Directional BHA on 5" DP to 2,306'. Worked Through Dogleg at 1,685'. Washed Down as a Precaution from 2,306' to 2,401', 04:00 - 00:00 20.00 DRILL P SURF Drilled 13-1/2" Directional Hole by Rotating and Sliding from 2,401' to 4,100'. WOB Sliding 40,000# - 50,000#, WOB Rotating 20,000# - 25,000# RPM 70, Motor RPM 83, Torque Off Bottom 6,000 ft fibs - On Bottom 10,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,550 psi, On Bottom 2,850 psi. String Weight Up 125,000#, String Weight Down 85,000#, String Weight Rotating 105,000#. ART = 6.32 hrs, AST = 5.49 hrs. Krevs 85 9/7/2002 00:00 - 01 :00 1.00 DRILL P SURF Held PJSM. Drilled 13-1/2" Directional Hole by Rotating from 4,100' to 4,220'. WOB 20,000# - 35,000# RPM 70, Motor RPM 83, Torque Off Bottom 6,000 ft / Ibs - On Bottom 11,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,550 psi, On Bottom 2,750 psi. String Weight Up 125,000#, String Weight Down 85,000#, String Weight Rotating 105,000#. 01 :00 - 02:00 1.00 DRILL P SURF Circulated Bottoms Up. Pump Rate 650 gpm, SPP 2,500 psi. Flow Checked Well, Well Static. 02:00 - 03:00 1.00 DRILL P SURF Held PJSM. POOH from 4,220' to 1,635'. Maximum Overpull 50,000# at 2,750', Average Drag 10,000#. 03:00 - 04:00 1.00 DRILL P SURF RIH after Wiper Trip from 1,635' to 4,124'. Set Down at 2,750'. Worked through Tight Spot at 2,750' Several Times. M I U Top Drive, Washed Down as a Precaution from 4,124' to 4,220', No Fill. 04:00 - 00:00 20.00 DRILL P SURF Drilled 13-112" Directional Hole by Rotating and Sliding from 4,220' to 5,850'. WOB Sliding 45,000# - 65,000#, WOB Rotating 20,000# - 35,000#, RPM 70, Motor RPM 83, Torque Off Bottom 10,000 ft IIbs - On Bottom 13,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,700 psi, On Bottom 2,900 psi. String Weight Up 135,000#, String Weight Down 95,000#, String Weight Rotating 110,000#. ART = 13.13 hrs, AST = 1.64 hrs. Krevs 214 9/8/2002 00:00 - 03:00 3.00 DRILL P SURF Held PJSM. Drilled 13-1/2" Directional Hole by Rotating and Sliding from 5,850' to 6,155'. WOB Rotating 20,000# - 45,000#, WOB Sliding 45,000# - 60,000#, RPM 70, Motor RPM 83, Torque Off Bottom 11,000 ft Ilbs - On Bottom 14,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,800 psi, On Bottom 2,950 psi. String Weight Up 135,000#, String Weight Down 95,000#, String Weight Rotating 110,000#. ART = 1.64 hrs, AST = 0.30 hrs. Total Krevs = 231 03:00 - 04:00 1.00 DRILL P SURF Circulated Bottoms Up. Pump Rate 650 gpm, SPP 2,800 psi. Flow Checked Well, Well Static. 04:00 - 06:30 2.50 DRILL P SURF Held PJSM. POOH for Wiper Trip from 6,155' to 618'. Maximum Overpull60,OOO# at 4,300', Average Drag 15,000#. Worked Through Tight Spots at 4,300' - 4,100' and 2,000' - 1,700'. 06:30 - 09:00 2.50 DRILL P SURF RIH after Wiper Trip from 618' to 6,060'. M I U Top Drive, Washed Down as a Precaution from 6,060' to 6,155'. 09:00 - 10:30 1.50 DRILL P SURF Circulated Bottoms Up. Pump Rate 650 gpm, SPP 2,750 psi. Circulated Until Returns over Shaker were Clean. Flow Printed: 9/30/2002 9:18:00 AM ) ') BP EXPLORATION Operations Summary Report Page 3 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/8/2002 9/9/2002 S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 9/3/2002 Start: Rig Release: Rig Number: 14 Spud Date: 9/4/2002 End: From - To Hours Task Code NPT Phase Description of Operations 09:00 - 10:30 1.50 DRILL P SURF Checked Well, Well Static, 10:30 - 12:00 1.50 DRILL P SURF Held PJSM. POOH wI 5" DP from 6,155' to 774'. 12:00 - 14:00 2.00 DRILL P SURF Held PJSM. POOH, Flushed w/ Water, Broke Out and LID Flex D.C., MWD and Mud Motor. 14:00 - 14:30 0.50 CASE P SURF Cleared and Cleaned Rig Floor. 14:30 - 16:00 1.50 CASE P SURF Held PJSM. R / U Equipment to Run 10-3/4" Casing. 16:00 - 16:30 0.50 CASE P SURF M I U Float Shoe Joint, 1 Jt of 10-3/4" Casing and Float Collar Joint. Filled Casing and Checked Float Equipment, OK. 16:30 - 00:00 7.50 CASE P SURF M I U and RIH w/ 10-3/4", 45.5#, L-80, BTC Casing. Average M I U Torque 9,500 ft Ilbs. 105 Jts ran at 2359 hrs. 00:00 - 02:00 2.00 CASE P SURF Held PJSM. Continued to RIH wI Surface Casing. Ran a Total of 146 Joints of 10-3/4",45.5#, L-80, BTC Casing. Average M I U Torque 9,500 ft Ilbs. 02:00 - 02:30 0.50 CASE P SURF M I U 10-3/4" Casing Hanger and Landing Joint. Landed Casing. 10-3/4" Casing Set As Follows: Item Length Depth Float Shoe 1.76' 6,139.30' 2 Jts 10-3/4" 45.5# L-80 BTC Csg 83.71' 6,053.83' Float Collar 1.21' 6,052.62' 12110-3/4"45.5# L-80 BTC Csg 5,020.44' 1,032.18' TAM Port Collar Assembly 42.21' 989,97' 23 10-3/4" 45.5# L-80 BTC Csg 954.22' 35.75' 10-3/4" Casing Hanger 1.79' 33.90' Circulated to Condition Hole, Pump Rate 13 bpm, SPP 1,100 psi. Reciprocated Casing while Circulating, String Weight Up 210,000#, String Weight Down 100,000#, RID Franks Tool, M I U Cement Head wI Plugs to Casing, Continued to Circulate Hole. Pump Rate 13 bpm, SPP 1,050 psi. Held PJSM w/ Dowell Crews, Rig Crews and Peak Truck Drivers. Switched over to Dowell. Pumped 15 bbls of MudPush at 3.0 bpm, 250 psi. Shut in Cement Manifold and Tested Lines to 3,500 psi, OK. Pumped 60 bbls of MudPush at 5.5 bpm, 480 psi. Dropped Bottom Plug, Pumped 745 bbls (943 sx) 10.7 ppg ArcticSet Lite III Lead Cement, Followed by 150 bbls (720 sx) 15.8 ppg Premium Tail Cement wI 0.300% bwoc Dispersant, 0.40% bwoc Fluid Loss, 0.20 gallsk AntiFoam and 1.00 % bwoc Accelerator. Reciprocated Casing While Cementing. Pumped Cement at the Following Rates: Pumped Rate 100.0 bbls 8.00 bpm 200.0 bbls 8.00 bpm 300.0 bbls 8.00 bpm 400.0 bbls 8.00 bpm 500.0 bbls 8.00 bpm 600.0 bbls 8.00 bpm 700.0 bbls 8.00 bpm 745.0 bbls 3.00 bpm Pumping Tail Cement 800.0 bbls 5.50 bpm 02:30 - 03:00 0.50 CASE P SURF 03:00 - 04:00 1.00 CEMT P SURF 04:00 - 08:00 4.00 CEMT P SURF Pressure 800 psi 775 psi 750 psi 750 psi 750 psi 780 psi 830 psi 285 psi 950 psi Printed: 9/30/2002 9:18:00 AM ) ) BP EXPLORATION Operations Summary Report Page 4 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/9/2002 04:00 - 08:00 4.00 CEMT P SURF 850.0 bbls 5,75 bpm 955 psi 895.0 bbls 2.50 bpm 250 psi Dropped Top Plug, Pumped 10 bbls of Water at 6.0 bpm, 300 psi. Switched to Rig Pumps and Displaced wI 575 bbls of Mud at the Following Rates: Pumped Rate Pressure 100.0 bbls 12.00 bpm 675 psi 200.0 bbls 12.00bpm 800 psi 300.0 bbls 12.00 bpm 900 psi 400.0 bbls 9.00 bpm 950 psi 500.0 bbls 9.00 bpm 1 ,150 psi 525.0 bbls 9.00 bpm 900 psi 550.0 bbls 7.00 bpm 1,000 psi 560.0 bbls 7.00 bpm 1 ,100 psi 585.0 bbls 7.00 bpm 1 ,100 psi Wiper Plug Bumped wI 585 bbls Total Displacement Pumped. Pressured up to 1,600 psi, OK. Apx 200 bbls of Lead Cement to Surface. Cement in Place @ 0745 Hrs. Bled off Pressure, Floats Held. 08:00 - 09:00 1.00 CEMT P SURF Flushed Diverter. RID Cement Head and Lines. Broke out and LID Landing Joint. 09:00 - 10:30 1.50 DIVRTR P INT1 Held PJSM. Cleaned and Cleared Rig Floor. N I D Diverter and Surface Stack. 10:30 - 11 :00 0.50 WHSUR P INT1 N I U 13-5/8" x 5,000 psi Split-Speed Wellhead. Tested to 1,000 psi f/1 0 minutes, OK. 11 :00 - 14:30 3.50 BOPSUR P INT1 Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram wI 4-1/2" x 7" Variable Rams, Blind Rams, Mud Cross, Lower Pipe Rams wI 3-1/2" x 6" Variable Rams. 14:30 - 15:30 1.00 BOPSURP INT1 R I U Test Joint and Equipment to Pressure Test BOPE. 15:30 - 19:30 4.00 BOPSUR P INT1 Held PJSM. Tested BOPE, Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 4,000 psi High I 250 psi Low. Tested Annular Preventer to 2,500 psi High 1250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held wI No Leaks or Pressure Loss. Witnessing of BOPE test Waived by AOGCC Rep Chuck Scheve. 19:30 - 20:30 1.00 BOPSUR P INT1 RID BOPE Test Equipment. Ran and Set Wear Bushing. 20:30 - 21 :00 0.50 BOPSUR P INT1 Closed Blind Rams. Tested Casing to 1,000 psi to Ensure TAM Port Collar Closed. OK. Bled Off Pressure, Opened Blind Rams. 21 :00 - 23:30 2.50 DRILL P INT1 M I U 60 Jts of 5" DP, Stood Back in Derrick. 23:30 - 00:00 0.50 DRILL P INT1 Held PJSM. R I U Equipment to M I U BHA #3. 9/10/2002 00:00 - 02:00 2.00 DRILL P INT1 Held PJSM. M I U BHA #3.9-7/8" Hycalog DS-70 PDC Bit, Ser# 200895, dressed w/6x15 jets, 7" SperryDrill Lobe 7/8 6.0 stg Motor wI 1.22 deg Bent Housing, Adjustable Gauge Stabilizer, FEMWD wI Hcim-GR-Res-PWD, FEMWD wI PM, Hang Off Sub, 3 x Flex Collars, 9 Jts 5" HWDP, HE Drilling Jars and 5 Jts 5" HWDP. Total BHA Length - 630.59'. Set Motor Bend and Oriented to MWD. M I U Top Drive and Tested MWD Tools, OK. 02:00 - 03:00 1.00 DRILL P INT1 Held PJSM. Slipped and Cut Drilling Line. 03:00 - 04:00 1.00 DRILL P INT1 RIH wI 9-7/8" Directional BHA on 5" DP to 1,150'. Picked up Printed: 9/30/2002 9:18:00 AM ") ) BP EXPLORATION Operations Summary Report Page 5 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2002 03:00 - 04:00 1.00 DRILL P INT1 Single Joints of DP from Pipe Shed. Slowly Rotated Bit and Stabilizer Through TAM Port Collar at 1,029'. 04:00 - 04:30 0.50 CASE P INT1 Held PJSM. Closed Pipe Rams and Pressure Tested Casing to 1,000 psi to Ensure TAM Port Collar Closed. OK. Bled Off Pressure and Opened Pipe Rams, 04:30 - 08:30 4.00 DRILL P INT1 RIH wI 9-7/8" Directional BHA on 5" DP to 6,047'. Picked up Single Joints of DP from Pipe Shed. Filled Pipe every 30 Joints. Tagged Cement at 6,047'. 08:30 - 09:00 0.50 CASE P INT1 Held PJSM. Closed Upper Pipe Rams. Tested 10-3/4" Surface Casing to 3,500 psi fl 30 minutes, OK. Bled off Pressure, Opened Pipe Rams. 09:00 - 09:30 0.50 DRILL P INT1 Drilled Cement and Float Equipment from 6,047' to 6,141'. WOB 12,000# - 15,000#, RPM 50, Motor RPM 174, Torque 10,000 ft Ilbs, Pump Rate 600 gpm, SPP 2,250 psi. Cleaned out to 6,155'. Displaced Hole to New 9.3 ppg LSND Mud During Drilling Out Operations. 09:30 - 10:00 0.50 DRILL P INT1 Drilled New 9-7/8" Hole 6,155' to 6,175'. WOB 10,000#- 12,000#, RPM 50, Motor RPM 174, Torque 10,000 ft Ilbs, Pump Rate 600 gpm, SPP 2,250 psi. 10:00 - 10:30 0.50 DRILL P INT1 Circulated to Condition Hole and to Complete Mud Displacement. Pump Rate 600 gpm, SPP 2,250 psi. 10:30 - 11 :00 0.50 DRILL P INT1 Held PJSM. Closed Pipe Rams and Performed LOT. Strokes Pmp'd Pressure 5 180 psi 10 430 psi 15 610 psi 20 740 psi 25 860 psi 30 970 psi 35 1,070 psi 39 1 ,1 00 psi 40 1,100 psi 41 1 ,1 00 psi MW 9.4 ppg, Csg Shoe TVD 3,375', Pressure 1,100 psi = 15.67 ppg EMW. Held Pressure f/10 minutes, Pressure Leaked off from 1,100 psi to 640 psi in 5 minutes. Pressure at 10 minutes 640 psi. Bled down Pressure, Opened Pipe Rams. 11 :00 - 00:00 13.00 DRILL P INT1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 6,175' to 8,050'. WOB Sliding 15,000# - 20,000#, WOB Rotating 5,000# - 15,000#, RPM 70, Motor RPM 175, Torque Off Bottom 11,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,300 psi, On Bottom 2,500 psi. String Weight Up 182,000#, String Weight Down 85,000#, String Weight Rotating 125,000#. ART = 5.12 hrs, AST = 1.64 hrs. Pumped 30 bbl Hi-Vis Weighted Barafiber Sweeps every 200'. 9/11/2002 00:00 - 01 :00 1.00 DRILL P INT1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 8,050' to 8,197'. WOB Sliding 15,000# - 20,000#, WOB Rotating 10,000# - 15,000#, RPM 70, Motor RPM 175, Torque Off Bottom 12,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,300 psi, On Bottom 2,500 psi. String Weight Up 185,000#, String Weight Down 85,000#, String Weight Rotating 125,000#. Printed: 9/30/2002 9:18:00 AM ) ) BP EXPLORATION Operations Summary Report Page 6 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/11/2002 01 :00 - 02:00 1,00 DRILL P INT1 Pumped and Circulated Around 35 bbl Hi-Vis Weighted Barafiber Sweep. Pump Rate 650 gpm, SPP 2,300 psi. Circulated until Returns over Shaker Cleaned Up. 02:00 - 04:30 2,50 DRILL P INT1 Held PJSM. Made Wiper Trip from 8,197' to 10-3/4" Casing Shoe at 6,155'. Tight Hole at 7,860', Maximum Overpull 75,000#, Average Drag 25,000#. Hole Tight at 7,770', Pumped out of the Hole from 7,770' to 7,050'. Pump Rate 500 gpm, SPP 2,000 psi. Drag Increased to 50,000# at 7,050'. Back Reamed out ofthe Hole from 7,050' to 6,155'. 04:30 - 05:00 0.50 DRILL P INT1 Circulated Bottoms Up to Clean Hole After Wiper Trip. Pump Rate 650 gpm, SPP 2,300 psi. 05:00 - 07:00 2.00 DRILL P INT1 RIH after Wiper Trip to 8,100'. Hit Bridge at 6,870'. Worked through Bridge with Pump and Slight Rotation. M I U Top Drive, Washed Down as a Precaution from 8,100' to 8,197'. 10' of Fill on Bottom. 07:00 - 16:30 9,50 DRILL P INT1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 8,197' to 9,252'. WOB Sliding 25,000# - 35,000#, WOB Rotating 15,000# - 25,000#, RPM 90, Motor RPM 175, Torque Off Bottom 17,000 ft Ilbs - On Bottom 20,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,750 psi, On Bottom 2,950 psi. String Weight Up 225,000#, String Weight Down 85,000#, String Weight Rotating 125,000#. Pumped 30 bbl Hi-Vis Weighted Barafiber Sweeps every 300'. 16:30 - 17:30 1.00 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Weighted Barafiber Sweep. Pump Rate 650 gpm, SPP 2,750 psi. Circulated until Returns over Shaker Cleaned Up. 17:30 - 19:00 1.50 DRILL P INT1 Held PJSM. Made Wiper Trip from 9,252' to 7,850'. Maximum OverpuIl125,OOO#, Average Drag 75,000#. Hole became Very Tight at 8,400', Pumped and Back Reamed out of the Hole from 8,400' to 8,150'. Pump Rate 600 gpm, SPP 2,300 psi. Straight Pull from 8,150' to 7850'. No Overpull, Drag 30,000#. 19:00 - 20:00 1.00 DRILL P INT1 RIH after Wiper Trip to 9,160', Drag 25,000# - 30,000#. M I U Top Drive, Washed Down as a Precaution from 9,160' to 9,252'. No Fill. 20:00 - 00:00 4.00 DRILL P INT1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 9,252' to 9,720'. WOB Sliding 15,000# - 25,000#, WOB Rotating 10,000# - 20,000#, RPM 90, Motor RPM 175, Torque Off Bottom 15,000 ft I Ibs - On Bottom 18,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,750 psi, On Bottom 2,950 psi. String Weight Up 235,000#, String Weight Down 85,000#, String Weight Rotating 135,000#. ART = 6.68 hrs, AST = 2.03 hrs. Pumped 30 bbl Hi-Vis Weighted Barafiber Sweeps every 300'. 9/12/2002 00:00 - 04:00 4.00 DRILL P INT1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 9,720' to 10,211'. WOB Sliding 20,000# - 25,000#, WOB Rotating 10,000# - 20,000#, RPM 90, Motor RPM 175, Torque Off Bottom 14,000 ft I Ibs - On Bottom 17,000 ft I Ibs, Pump Rate 650 gpm, SPP Off Bottom 2,650 psi, On Bottom 2,950 psi. String Weight Up 215,000#, String Weight Down 85,000#, String Weight Rotating 135,000#. Pumped 30 bbl Hi-Vis Barafiber Sweeps every 300'. 04:00 - 05:00 1.00 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Weighted Barafiber Sweep. Pump Rate 650 gpm, SPP 2,650 psi. Printed: 9/30/2002 9:18:00 AM ') ") BP EXPLORATION Operations Summary Report Page 7 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/12/2002 05:00 - 05:30 0.50 DRILL P INT1 Held PJSM, Made Wiper Trip from 10,210' to 9,150'. No Overpull, Average Drag 20,000#. 05:30 - 06:00 0.50 DRILL P INT1 RIH after Wiper Trip from 9,150' to 10,120'. Average Drag 20,000#. M I U Top Drive and Washed Down as a Precaution from 10,120' to 10,211 '. No Fill On Bottom. 06:00 - 00:00 18.00 DRILL P INT1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 10,211' to 11,845'. WOB Sliding 15,000# - 35,000#, WOB Rotating 8,000# - 20,000#, RPM 90, Motor RPM 175, Torque Off Bottom 12,500 ft Ilbs - On Bottom 17,500 ft I Ibs, Pump Rate 660 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,200 psi. String Wgt Up 200,000#, String Wgt Down 105,000#, String Weight Rotating 145,000#. Pmpd 30 bbl Hi-Vis Sweeps every 250'. AST = 2.65 hrs, ART = 10.42 hrs. 9/13/2002 00:00 - 03:00 3.00 DRILL P INT1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 11,845' to 12,217'. WOB Sliding 40,000#- 45,000#, WOB Rotating 20,000# - 35,000#, RPM 90, Motor RPM 175, Torque Off Bottom 14,000 ft I Ibs - On Bottom 17,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,200 psi. String Weight Up 210,000#, String Weight Down 115,000#, String Weight Rotating 145,000#. Pumped 30 bbl Hi-Vis Weighted Sweeps every 300'. ART = 1.83 hrs, AST = 0.08 hrs. 03:00 - 04:00 1.00 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Weighted Barafiber Sweep. Pump Rate 660 gpm, SPP 2,900 psi. Circulated until Returns over Shaker were Clean. 04:00 - 06:30 2.50 DRILL P INT1 Held PJSM. POOH wI 5" DP from 12,217' to 10-3/4" Casing Shoe at 6,140'. No Overpull, Maximum Drag 45,000#, Average Drag 30,000#. 06:30 - 07:30 1.00 DRILL P INT1 Held PJSM. Slipped and Cut Drilling Line. 07:30 - 08:00 0.50 DRILL P INT1 Serviced Top Drive 08:00 - 09:30 1.50 DRILL P INT1 Pumped and Circulated around 30 bbl1 0% EP Mud Lube Sweep. Parameters Before Lube Pill: String Weight Up 160,000#, String Weight Down 105,000#, RPM 70, Torque 6,000 ft Ilbs; Parameters After Lube Pill: String Weight Up 135,000#, String Weight Down 105,000#, RPM 70, Torque 6,000 ft I Ibs. 09:30 - 11 :30 2.00 DRILL P INT1 POOH wI 5" DP from 6,140' to 600' 11 :30 - 12:30 1.00 DRILL P INT1 POOH wI BHA 12:30 - 13:00 0.50 DRILL P INT1 Downloaded MWD Data. 13:00 - 16:00 3.00 DRILL P PROD1 Held PJSM. M I U BHA #4.9-7/8" Smith S-73HPX PDC Bit, Ser# JS8361, dressed w/8x13 jets, 7" SperryDrill Lobe 7/8 6.0 stg Motor wI 1.22 deg Bent Housing, Adjustable Gauge Stabilizer, FEMWD wI Hcim-GR-Res-PWD, FEMWD wI PM, SFD - CTN, Hang Off Sub, 3 x Flex Collars, 9 Jts 5" HWDP, HE Drilling Jars and 5 Jts 5" HWDP. Total BHA Length - 658.38'. Changed out MWD Pulser. Oriented Motor to MWD. M I U Top Drive and Tested MWD Tools, OK. 16:00 - 16:30 0.50 DRILL P PROD1 Held PJSM. Cleared Rig Floor, Sperry-Sun installed Radioactive Sources, RIH wI MWD Tools below BOP Stack. Sounded the All Clear. M I U and RIH wI 5" HWDP. 16:30 -17:30 1.00 DRILL P PROD1 RIH wI 9-7/8" Directional BHA on 5" DP. PI U Single Joints of 5" DP from Pipe Shed. Printed: 9/30/2002 9:18:00 AM ') ~) BP EXPLORATION Operations Summary Report Page 8 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/13/2002 17:30 - 20:00 2.50 DRILL N RREP PROD1 Worked on Top Drive Electrical Fault. 20:00 - 22:00 2.00 DRILL P PROD1 RIH wI 9-7/8" Directional BHA on 5" DP to 3,630'. PI U Single Joints of 5" DP from Pipe Shed. 22:00 - 00:00 2.00 DRILL P PROD1 RIH wI 9-7/8" Directional BHA on 5" DP to 6,504' 9/14/2002 00:00 - 02:30 2.50 DRILL P PROD1 Held PJSM. RIH wI 9-7/8" Directional BHA on 5" DP to 11,965'. Broke Circulation at 8,200' and 10,200'. Drag 25,000#. 02:30 - 05:30 3.00 DRILL P PROD1 Performed MAD Pass to Log Interval from 11,900' to 11,650'. Rate 180' I hr, RPM 40, Pump Rate 600 gpm, SPP 3,000 psi. 05:30 - 06:00 0.50 DRILL P PROD1 RIH wI Directional BHA on 5" DP to 12,130'. M I U Top Drive, Washed Down as a Precaution from 12,130' to 12,217. 06:00 - 12:30 6.50 DRILL P PROD1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 12,217' to 13,018'. WOB Sliding 15,000# - 20,000#, WOB Rotating 10,000# - 20,000#, RPM 90, Motor RPM 175, Torque Off Bottom 17,500 ft Ilbs - On Bottom 18,000 ft I Ibs, Pump Rate 650 gpm, SPP Off Bottom 3,150 psi, On Bottom 3,300 psi. String Weight Up 225,000#, String Weight Down 115,000#, String Weight Rotating 150,000#. Pumped 30 bbl Hi-Vis Sweeps every 300'. ART = 3.05 hrs, AST = 0.74 hrs. 12:30 - 14:00 1.50 DRILL N DPRB PROD1 Hole Packed off Around Drill String, Lost Circulation, Shut Down Pumps, Hole Static. Losses while Pumping 5 bpm, 140 bph. Pulled out of the Hole from 13,018' to 12,850'. Hole Static. POOH to 12,450', Hole gave Fluid Back. Back Reamed out of Hole from 12,450' to 12,350', Pump Rate 5 bpm, RPM 50, Torque 16,000 ft Ilbs, Established Drilling Rate Parameters, Regained Full Circulation. Mixed LCM Material at 2 sacks I Minute, OM Seal and Barafiber. 14:00 - 15:30 1.50 DRILL N DPRB PROD1 Mixed LCM Material at 1 sack I minute, Began Pump Rate at 175 gpm, SPP 890 psi, After Establishing Full Returns, Slowly Increased Pump Rate to 650 gpm, SPP 3,030 psi. Observed Abundant Cuttings Returned over Shaker. 15:30 - 17:30 2,00 DRILL N DPRB PROD1 Washed and Reamed Back to Bottom to Clean Hole. Full Circulation, Pump Rate 650 gpm, SPP 3,000 psi. 17:30 - 00:00 6.50 DRILL P PROD1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 13,018' to 13,593', WOB Sliding 35,000# - 45,000#, WOB Rotating 10,000# - 25,000#, RPM 90, Motor RPM 175, Torque Off Bottom 17,000 ft I Ibs - On Bottom 20,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,250 psi. String Weight Up 225,000#, String Weight Down 122,000#, String Weight Rotating 150,000#. Pumped 25 bbl Hi-Vis Sweeps every 250', ART = 2.47 hrs, AST = 1.69 hrs. 9/15/2002 00:00 - 05:00 5.00 DRILL P PROD1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 13,593' to 14,168'. WOB Sliding 15,000#- 20,000#, WOB Rotating 5,000# - 10,000#, RPM 90, Motor RPM 175, Torque Off Bottom 16,000 ft Ilbs - On Bottom 17,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 3,050 psi, On Bottom 3,250 psi. String Weight Up 225,000#, String Weight Down 122,000#, String Weight Rotating 160,000#. 05:00 - 06:30 1.50 DRILL P PROD1 Pumped and Circulated Around 25 bbl Hi-Vis Barafiber Sweep, Pump Rate 650 gpm, SPP 3,100 psi. Circulated Until Returns over Shaker were Clean. 06:30 - 07:30 1.00 DRILL P PROD1 Held PJSM. Made Wiper Trip from 14,168' to 12,157'. No Overpull, Average Drag 30,000#. 07:30 - 08:30 1.00 DRILL P PROD1 RIH after Wiper Trip from 12,157' to 14,072', Average Drag Printed: 9/30/2002 9: 18:00 AM ') ) BP EXPLORATION Operations Summary Report Page 9 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/15/2002 07:30 - 08:30 1.00 DRILL P PROD1 20,000#. M I U Top Drive and Washed Down as a Precaution from 14,072' to 14,168'. No Fill On Bottom. 08:30 - 12:00 3,50 DRILL P PROD1 Drilled 9-7/8" Directional Hole by Rotating and Sliding from 14,168' to 14,470'. WOB Sliding 10,000# - 20,000#, WOB Rotating 5,000# - 8,000#, RPM 90, Motor RPM 175, Torque Off Bottom 17,000 ft Ilbs - On Bottom 17,000 ft Ilbs, Pump Rate 660 gpm, SPP Off Bottom 3,000 psi, On Bottom 3,300 psi. String Weight Up 225,000#, String Weight Down 115,000#, String Weight Rotating 165,000#. Pumped 20 bbl Hi-Vis Sweeps every 300'. AST = 2.00 hrs, ART = 3.82 hrs. 12:00 - 00:00 12.00 DRILL P PROD1 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 14,470' to 14,890'. WOB Sliding 15,000#- 35,000#, WOB Rotating 5,000# - 10,000#, RPM 90, Motor RPM 175, Torque Off Bottom 16,000 ft Ilbs - On Bottom 17,500 ftJ Ibs, Pump Rate 650 gpm, SPP Off Bottom 3,150 psi, On Bottom 3,400 psi. String Weight Up 225,000#, String Weight Down 120,000#, String Weight Rotating 175,000#. Pumped 25 bbl Hi-Vis Sweeps every 300'. AST = 6.48 hrs, ART = 0.33 hrs. Note: Increased MW to 10.1 ppg 9/16/2002 00:00 - 12:00 12.00 DRILL P PROD1 Held PJSM. Drilled 9-7/8" Directional Hole by Sliding from 14,890'to 15,185'. WOB 10,000#-20,000#, MotorRPM 175, Pump Rate 650 gpm, SPP Off Bottom 3,200 psi, On Bottom 3,500 psi. String Weight Up 235,000#, String Weight Down 140,000#. Washed and Reamed every 45' to Clean the Hole. Pumped 25 bbl Hi-Vis Sweeps every 2 hrs. AST = 9.59 hrs. 12:00 - 19:00 7.00 DRILL P PROD1 Held PJSM, Drilled 9-7/8" Directional Hole by Rotating and Sliding from 15,185' to 15,603'. WOB Sliding 15,000#- 25,000#, WOB Rotating 5,000# - 15,000#, RPM 90, Motor RPM 175, Torque Off Bottom 17,000 ft Ilbs - On Bottom 18,500 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 3,500 psi, On Bottom 3,750 psi. String Weight Up 260,000#, String Weight Down 140,000#, String Weight Rotating 185,000#. Pumped 25 bbl Hi-Vis Sweeps every 300'. AST = 1.58 hrs, ART = 2.74 hrs. Decision Made to Plug Back and Sidetrack Well Due to Formations coming in High and Possibility of Drilling into Gas Cap. 19:00 - 21 :00 2.00 DRILL C PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Barafiber Sweep. Pump Rate 620 gpm, SPP 3,500 psi. Circulated until Returns over Shaker were Clean. Flow Checked Well, Well Static. 21 :00 - 00:00 3.00 DRILL C PROD1 POOH from 15,503' to 11,300'. Maximum Overpull100,OOO# at 15,440'. Average Drag 25,000#. Tight Spot at 11,300'. M I U Top Drive, Back Reamed Out of the Hole from 11,300' to 11,100'. Pump Rate 585 gpm, SPP 2,800 psi, RPM 55, Torque 13,000 ft Ilbs, String Weight Rotating Up 145,000#. POOH from 11,100' to 11,000', No Overpull, Average Drag 20,000#. 9/17/2002 00:00 - 02:00 2.00 DRILL C PROD1 Held PJSM. POOH from 11,000' to 10-3/4" Casing Shoe at 6,140'. No Overpull, Average Drag 20,000#. 02:00 - 03:00 1.00 DRILL C PROD1 Held PJSM. Slipped and Cut Drilling Line. 03:00 - 04:30 1.50 DRILL C PROD1 Continued to POOH wI 5" DP from 6,140' to 650'. Average Drag 10,000#. 04:30 - 06:30 2.00 DRILL C PROD1 POOH wI 9-7/8" Directional BHA. Broke out and LID 5" Printed: 9/30/2002 9:18:00 AM ') ) BP EXPLORATION Operations Summary Report Page 10 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2002 04:30 - 06:30 2.00 DRILL C PROD1 HWDP and Jars. Remove RA source and LD remaining BHA. 06:30 - 07:00 0,50 DRILL C PROD1 LD tools and clear rig floor. 07:00 - 12:00 5.00 BOPSURC PROD1 Pull Wear bushing and install test plug. Test BOPE to 250 psi low I 5 min & 4000 psi high I 5 min. Test annular to 250 psi low 15 min & 3000 psi high I 5 min. Witness of test waived by AGOCC John Crisp. Pull test plug and install wear bushing, RD test equipment. 12:00 - 20:00 8.00 STKOH C PROD1 MU mule shoe. TIH to casing shoe and break circulation, 420 gpm, 600 psi. Continue TIH break circulation every 20 stands to TD. 20:00 - 23:30 3.50 STKOH C PROD1 Circulate and condition mud for bottom cement plug. Bring cirulation rate up to 600 gpm, losing mud. Circulate@ 550 gpm, 1800 psi. 100 RPM, TO 15 K, PU wt = 260 K, SO wt = 125 K. Condition mud to 10.2 ppg, 47 vis. TO up to 25 K. Stop rotation, circulate and reciprocate pipe. Batch mix 70 bbls 15.8 ppg cement plug. 23:30 - 00:00 0.50 STKOH C PROD1 RU to pump cement. Pump 5 BW, Test lines to 3500 psi. Pump 30 BW. Pump 70 bbls 15.8 ppg cement @ 6.5 bpm, 1000 psi. Displace with 7.5 BW. Switch to rig pump and displace with 246 bbls 10.2 mud. Reciprocate pipe during cement job. TO = 24 K, PU wt = 290 K, SO wt = 125 K. 100% returns. 9/18/2002 00:00 - 00:30 0.50 STKOH C PROD1 Continue cement displacement @ 9 bpm, 1120 psi. PU wt = 300 K, SO wt = 125 K. Cement in place @ 00:30 hrs. 00:30 - 01 :00 0.50 STKOH C PROD1 POOH slow (approx 3.5 min per stand) to 14950'. PU wt = 280 K. 01 :00 - 03:30 2.50 STKOH C PROD1 Circulate out excess cement @ 9 bpm, 1100 psi. Build 11.0 ppg spacer in pits. Returns - PH up, MW up to 10.5 ppg. 03:30 - 05:00 1.50 STKOH C PROD1 Spot 11.0 ppg spacer fl 14950' - 12050' @ 10 bpm, 1140 psi. PU wt = 260 K, SO = 120 K. Rotate & Reciprocate pipe. TO = 25 K. 05:00 - 06:00 1.00 STKOH C PROD1 POOH to 12800'. PU wt = 275 K. 06:00 - 07:30 1.50 STKOH C PROD1 Circulate btms up @ 600 gpm, 1750 psi. 11.0 ppg mud on bottom up. Rotate & reciprocate pipe. 80 rpm. 07:30 - 09:00 1.50 STKOH C PROD1 Pump balanced Form A plug pill with Dowell, Pmp 30 bbls 10.7 ppg viscosified fresh water pill. Pump 30 bbls Form A Plug and follow with 5 bbls 10,7 ppg pill. Displace with 206 bbls 10.2 ppg mud @ 600 gpm, 1750 psi. Rotate and reciprocate pipe. 80 rpm. PU wt = 235 K, SO = 105 K, ROT = 148 K. 09:00 - 09:30 0.50 STKOH C PROD1 POOH slowly (3.5 min I stand) to 12400'. 09:30 - 10:00 0.50 STKOH C PROD1 Pump 50 bbls mud to clear DP and 25 bbl dry job. 10:00 - 12:30 2.50 STKOH C PROD1 POOH to 10.75" casing shoe @ 6140'. 12:30 - 14:30 2.00 STKOH C PROD1 Wait on Form A Plug to set. Perform Rig Maintenance and work on Top Drive. 14:30 - 16:30 2.00 STKOH C PROD1 RIH to 12300'. 16:30 - 17:30 1.00 STKOH C PROD1 Circulate @ 1 bpm, 230 psi while washing down to find top of plug. Tag top of plug @ 12450' 17:30 - 18:30 1.00 STKOH C PROD1 Circulate bottoms up @ 600 gpm, 1450 psi. Rotate and reciprocate pipe. Confirm top of plug with bottoms up. 18:30 - 19:00 0.50 STKOH C PROD1 Wash down to 12600'. 19:00 - 20:30 1.50 STKOH C PROD1 Circulate and condition mud for Kick-off cement plug. @ 600 gpm, 1580 psi. Hold PJSM with rig crew and cementers. Printed: 9/30/2002 9: 18: 00 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ~) Page 11 of 16 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/18/2002 19:00 - 20:30 1.50 STKOH C PROD1 Batch mix cement. 20:30 - 21 :30 1.00 STKOH C PROD1 RU for cement. Pump 5 BW. Test lines to 3500 psi. Pump 30 BW, Pump 51 bbsl (245 sxs) 15.8 ppg Kick-off cement, 1.17 ft^31 sx yeild, 5.085 gall sx. Follow with 5 BW. RD cement head, NU Top Drive. Displace balanced plug with 198 bbls, 10.2 ppg mud @ 550 gpm, 1470 psi. Rotate and reciprocate pipe. PU wt = 300 K, 80 rpm, 25 K TO. Cement plug in place @ 21 :30 Hrs, 09/18/2002. 100% returns. 21 :30 - 22:30 1.00 STKOH C PROD1 POOH slowly (approx 3.5 min per stand) 10 stands to 11650'. 22:30 - 23:00 0.50 STKOH C PROD1 Pump DP volume to clear pipe @ 550 gpm, 1450 psi. Flow check. Pump dry job. 23:00 - 00:00 1.00 STKOH C PROD1 POOH for Kick-Off BHA #5. 9/19/2002 00:00 - 03:00 3.00 STKOH C PROD1 Continue to POOH. 03:00 - 04:30 1.50 STKOH C PROD1 PU BHA #5. Adjust motor to 1.22 Deg. Test AGS. Orient tools. 04:30 - 09:00 4.50 STKOH X DFAL PROD1 Problems uploading MWD data to tools. Failure to communicate with MWD computer. LD tools in pipe shed and trouble shootm MWD tools. 09:00 - 11 :00 2.00 STKOH C PROD1 Continue to PU BHA #5. Upload MWD data to downhole tools. Shallow test. Load RA source. TIH picking up DC's & HWDP from pipe shed. 11 :00 - 13:00 2,00 STKOH C PROD1 TIH to 10,75" casing shoe @ 6140'. 13:00 - 16:30 3,50 STKOH C PROD1 Cut & slip Drill line. Service Top Drive. Change out draw works chain. 16:30 - 19:00 2.50 STKOH C PROD1 TIH. Taking weight @ 11835'. 19:00 - 22:00 3.00 STKOH C PROD1 Circulate and conditon contaminated mud. Returns with High PH, high viscosity (120 +), & abundant Form A Plug. High TO and Drag. TO = 25 K, PU wt = 300 K, SO wt = 95 K. 80 rpm, 648 gpm, 3250 psi off btm. Treating mud with EZ glide, BDF-263. Establish ECD = 10.8 ppg. 22:00 - 23:00 1.00 STKOH C PROD1 Wash I Ream down to hard cement @ 12188' @ 80 rpm, 648 gpm, 3250 psi. 23:00 - 00:00 1.00 DRILL C PROD1 Orient motor. Start side track A @ 12,188' @ 23:00 hrs 09/19/2002. Directionally drill f/12 188' - 12249'. 648 gpm, 3450 psi on btm, 3250 psi off btm. TO = 25 K, PU wt = 275 - 300 K. 20 K WOB. ECD = 10.85 ppg. AST = 0.83 hrs. ART = 0 hrs. 9/20/2002 00:00 - 16:30 16.50 DRILL C PROD1 Directionally drill side track 12249' -13394'. 625 gpm, 3700 psi on btm, 3500 psi off btm wI AGS open, 12-18 K WOB, 90 rpm. PU wt = 265 K, SO wt = 110 K, ROT wt = 165 K. Using Mud swaps for TO & Drag. TO on btm = 25.5 K, off btm = 24.5 K. 16:30 - 18:00 1.50 DRILL C PROD1 Circulate sweep around prior to wiper trip. Survey. Slow pump rates. Flow check. 18:00 - 19:30 1.50 DRILL C PROD1 Wiper trip to 11962'. Hole slick, out & in. No fill. 19:30 - 00:00 4.50 DRILL C PROD1 Directionally drill side track 13394' - 13724'. Swap out 400 bbls mud. TO & Drag down considerably, TO on btm = 18 K, off btm = 16 K. 625 gpm, 3700 psi on btm, 3600 psi off btm wI AGS open, 12-18 K WOB, 90 rpm. PU wt = 255 K, SO wt = 130 K, ROT wt = 175 K. ECD = 11.25 ppg. AST: 6.13 hrs, ART: 7.03 hrs, ADT: 13.16 hrs. Using Mud swaps for TO & Drag. 9/21/2002 00:00 - 12:30 12.50 DRILL C PROD1 Directionally drill side track 13,724' - 14890'. TD. TO on btm = 20 K, off btm = 18 K. 640 gpm, 3700 psi on btm, 3500 psi off Printed: 9/30/2002 9:18:00 AM BP EXPLORATION Operations Summary Report S-114 S-114 DRILL+COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/21/2002 9/22/2002 9/23/2002 ') ) BP EXPLORATION Operations Summary Report S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 00:00 - 12:30 From - To Hours Task Code NPT Phase PROD1 12:30 - 13:00 13:00 - 23:00 23:00 - 23: 15 23:15 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 08:00 08:00 - 14:00 14:00 - 19:00 19:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 06:00 12.50 DRILL C 0.50 DRILL C 10.00 DRILL X 0.25 DRILL X 0.75 DRILL X 1.50 DRILL X 1.00 DRILL X 0.50 DRILL X 1.00 DRILL X 1.00 DRILL X 0.50 DRILL X 2.50 DRILL X 6.00 DRILL X 5.00 DRILL X 2.00 DRILL X 1.50 DRILL X 1.50 DRILL X 2.50 DRILL X 0.50 DRILL X 1.00 DRILL X 0.50 DRILL X 1.50 DRILL X PROD1 DPRB PROD1 DPRB PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 STUC PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 Page 12 of 16 Start: Rig Release: Rig Number: 14 Spud Date: 9/4/2002 End: 9/3/2002 Description of Operations btm wI AGS closed, 20 K WOB, 90 rpm. PU wt = 295 K, SO wt = 155 K, ROT wt = 200 K, ECD = 11.33ppg, Using Mud swaps for TO & Drag. AST: 0.42 hrs, ART: 7.4 hrs, ADT: 7.82 hrs. Lost 100% returns after picking up off bottom on TD. Flow check, loosing mud. Establish sporadic returns. POOH to 14400'. Break circulation. Sporadic returns. Circulate over top of hole while mixing LCM. Spot 30 # I bbl C¡:¡lcium Carbonate ( 10 # each of 25, 150, & 600) LCM pill on bottom @ 2 bpm with no returns. Let pill soak for 15 min. Stage pumps up to 4 bpm with partial returns, losing 162 BPH. Mix and pump pill #2 @ 45 #/bbl Calcium Carbonate (15 # each 25, 150, & 600). Pump pill down @ 4 bpm, 600 psi losing 120 BPH. Let pill soak for 30 min circulation over top of hole, losing 50 BPH. Circulate @ 2 bpm with partial returns, losing 80 BPH. TIH to 14866'. Mix & Pump LCM pill of 10 #/bbl "Steel Seal" + 20 #/bbl Calcium carbonate. Pump down @ 3 bpm, 540 psi, losing 47 BPH & 4 bpm, 630 psi, losing 60 BPH. Continue to circulate "Steel Seal" pill to bottom, Losses @ 45 BPH. POOH to 13186'. Losing 14 BPH up to 13186'. Monitor losses. 6 BPH static losses. POOH to 12284'. Pull into tight hole. Establish Circulation @ 2 BPM, 350 psi. Jar down with Torque. No fluid losses. Stage rate up to 14 bpm jarring down with torque. No fluid losses. Jar free. TIH to 11700'.. Backream through tight hole f/11711' - 10800' @ 90 rpm, 600 gpm, 3000 psi. No fluid losses to hole. POOH for BHA change. LD 14 stands of 5" excess DP. Stand back HWDP. Remove RA source. LD ABS & Neutron tools. Download MWD data. PU BHA #6 & TIH. TIH to casing shoe @ 6140'. Cut & Slip Drill Line. Circulate bottoms up and condition mud @ 336 gpm, 700 psi. TIH @ controlled running speed. Break circulation 120 stands. Continue TIH @ controlled running speed. Break circulation I 20 stands. No losses until last 2 stands in no returns from 14663'. PU last stand. Break circulation. No returns. Rotate and work pipe. No returns @ 4 bpm, 800 psi. No returns @ 2 bpm, 540 psi. Stand back one stand. Attempt circulation rotating and working pipe. No returns. PU wt = 275 K, TO 18 K. POOH to last break circulation point @ 14024'. Circulate @ 4 bpm, 800 psi. 90% losses. TIH to 14860' @ controlled running speed. Pump 120 bbls 60# bbl LCM pill of: 20 ppb "Steel Seal", 10 ppb Baracarb 25,20 ppb Baracard 50,10 ppb Baracarb 150. Chase to bottom with 250 bbls mud. 40% losses. 168 gpm, Printed: 9/30/2002 9:18:00 AM ') ') BP EXPLORATION Operations Summary Report Page 13 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2002 04:30 - 06:00 1.50 DRILL X DPRB PROD1 850 psi. 06:00 - 07:00 1.00 DRILL X DPRB PROD1 POOH 10 stands to 13928'. 07:00 - 08:00 1.00 DRILL X DPRB PROD1 Monitor static losses for 1/2 hr, 48 BPH. Attempt circulation @ 168 gpm, 650 psi. No returns. 08:00 - 14:30 6.50 DRILL X DPRB PROD1 POOH. Break circulation every 5 stands @ 4 bpm. Losses from 50% to 25%. Circulate 4 bpm @ 11100' with 25% losses, Continue TOOH to Casing shoe @ 6140', 14:30 - 17:30 3.00 DRILL X DPRB PROD1 Circulate bottoms up @ 10 3/4" casing shoe, Stage pumps up to 504 gpm, psi. No losses. Getting substantial amount of coal I cutting over shakers. 17:30 - 18:00 0.50 DRILL X DPRB PROD1 TIH 20 stands to 7900' @ controlled running speed. Hole slick. 18:00 - 19:30 1.50 DRILL X DPRB PROD1 Circulate hole clean @ 430 gpm. Getting fair amount of normal cuttings across shakers. No Losses. 19:30 - 20:30 1.00 DRILL X DPRB PROD1 TIH 20 stands to 11800'. Hole slick. 20:30 - 21 :30 1.00 DRILL X DPRB PROD1 Circulate hole clean @ 9800'. Fair amount of normal cutting across shakers. 650 gpm, 2600 psi. No losses. 21 :30 - 22:30 1.00 DRILL X DPRB PROD1 TIH to 11800' @ controlled running speed. Hole slick. 22:30 - 00:00 1.50 DRILL X DPRB PROD1 Circulate hole clean @ 11800'. Substantial amount of LCM. coal, & cuttings across shakers. 650 gpm, 3000 psi. No losses. 9/24/2002 00:00 - 00:30 0.50 DRILL X DPRB PROD1 TIH. Lost returns from pipe displacement @ 12400'. 00:30 - 01 :30 1.00 DRILL X DPRB PROD1 POOH to last circulation point @ 11800'. Establish circulation. Stage pumps up to 13 bpm. 1/2 bpm losses. DP float leaking. 01 :30 - 02:30 1.00 DRILL X DPRB PROD1 TIH 20 stands @ contolled speed to 13736'. Hole slick. 02:30 - 04:00 1.50 DRILL X DPRB PROD1 Circulate & clean hole. Substantial amount of LCM, coal, & cutting over shakers. 650 gpm, 3170 psi. No losses. 04:00 - 07:30 3.50 DRILL X DPRB PROD1 TIH break circulation 12 stands. Stage pumps up to 650 gpm as washing down. 650 gpm, 3180 psi. No losses. Tag up @ 14408', wash through. Continue Wash in hole to 14670'. Start losing partial returns @ 14600', 2 bpm. Wash down @ 640 gpm, 3250 psi. PU wt = 290 K, SO wt = 140 K, ROT wt = 190 K. 07:30 - 08:00 0.50 DRILL X DPRB PROD1 PUH to 14536'. Change out bails while circulating. 08:00 - 09:30 1.50 DRILL X DPRB PROD1 RU circulating equipment. Hold PJSM with rig and pumping crews. Mix polymer pill in pits. Test lines to 3500 psi. Mix Form-A-Plug. 09:30 - 11 :30 2.00 DRILL X DPRB PROD1 Pump LCM of 30 bbls 10.1 ppg Xantham Polymer pill (rig pump), 50 bbls 11.2 ppg Form-A-Plug (Dowell pump), 5 bbls Polymer pill behind (rig pump). Displace with 181 bbls 10.1 ppg mud with rig pumps @ 8 bpm, 1480 psi. Close Annular. Attempt to squeeze into formation. Displace 7 bbls into well, annular pressure maxed out @ 270 psi. RIH to 14678'. Lay plug in well as POOH from 14678' - 14307'. 11 :30 - 12:30 1.00 DRILL X DPRB PROD1 POOH to 13150'. 12:30 - 14:30 2.00 DRILL X DPRB PROD1 Circulate hole clean @ 650 gpm, 3290 psi. Change out bails. Flow check. Well static. 14:30 - 17:30 3.00 DRILL X DPRB PROD1 POOH to 10 3/4" casing shoe. PU and set Storm Packer for BOP test. 17:30 - 18:30 1.00 DRILL X DPRB PROD1 PU and set Storm Packer @ +1- 100' for BOP test. 18:30 - 22:30 4.00 BOPSURX DPRB PROD1 Pull wear bushing. Install test plug. RU for BOP test. Test BOPE to 250 psi low I 5 min & 4000 psi high I 5min; Annular to 250 psi low I 5 min & 3000 psi high I 5 min per AOGCC Printed: 9/30/2002 9:18:00 AM ') ') Page 14 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 9/24/2002 From - To Hours Task Code NPT Phase 18:30 - 22:30 4.00 BOPSURX DPRB PROD1 22:30 - 23:30 1.00 DRILL X DPRB PROD1 23:30 - 00:00 0.50 DRILL X DPRB PROD1 00:00 - 01 :00 1.00 DRILL X DPRB PROD1 01 :00 - 05:00 4,00 DRILL X DPRB PROD1 05:00 - 08:30 3.50 DRILL X DPRB PROD1 08:30 - 09:00 0.50 DRILL X DPRB PROD1 09:00 - 13:00 4.00 DRILL X DPRB PROD1 9/25/2002 13:00 - 18:30 5.50 DRILL X DPRB PROD1 18:00 - 21 :00 3.00 DRILL X DPRB PROD1 21 :00 - 23:00 2,00 DRILL X DPRB PROD1 23:00 - 00:00 1.00 DRILL X DPRB PROD1 9/26/2002 00:00 - 00:30 0.50 DRILL X DPRB PROD1 00:30 - 04:30 4.00 DRILL X DPRB PROD1 04:30 - 05:30 1.00 DRILL X DPRB PROD1 05:30 - 09:00 3.50 DRILL C PROD1 09:00 - 11 :00 2.00 DRILL C PROD1 11 :00 - 13:30 2.50 DRILL C PROD1 13:30 - 15:30 2.00 DRILL C PROD1 15:30 - 19:30 4.00 DRILL C PROD1 19:30 - 21:00 1.50 DRILL C PROD1 21 :00 - 23:30 2.50 CASE C PROD1 23:30 - 00:00 0.50 CASE C PROD1 9/27/2002 00:00 - 18:30 18.50 CASE C PROD1 Start: Rig Release: Rig Number: 14 Spud Date: 9/4/2002 End: 9/3/2002 Description of Operations regulations. Jeff Jones, AOGCC, waived witness of test. RD test equipment. Pull test plug & install wear bushing. TIH and retrieve Storm Packer. Cut & Slip drill line. Continue Cut & Slip Drill line. TIH to 13823'. Fill pipe 120 stands. Break circulation and establish pump rate @ 650 gpm I 40 stands. Wash down to 14405'. After connection could not ream past 14389'. 90 rpm, 650 gpm, 3510 psi. TO 19.5 K. PU wt = 280 K, SO wt = 135 K, ROT wt = 175 K. Back ream up to 14120'. Pump sweep and wash down to 14389'. 630 gpm, 3510 psi. 90 rpm. Unable to ream below 14390'. TO down to 5 K with 50- 120 psi differential pressure. Mix and pump nut plug + citrus acid pill down. Could not ream down past 14390'. Pump sweep to surface. POOH for BHA change. Probable motor failure. Stand back HWDP & DC's. LD Mud motor and PU new motor & Mill tooth bit. Adjust mtr angle and orientate. Function blind rams. TIH with BHA #7. TIH to 10 3/4" casing shoe. Fill pipe I 30 stds. Cut & Slip Drill Line while circulating bottoms up. Test MWD. Circulate bottoms up while cut & slip Drill Line. Continue TIH. Filling DP I 20 stds & breaking circulation. Taking weight @ 13550'. Break circulation and wash down 1 stand to 13641'. Continue TIH to 14312'. Kelly up and wash down from 14312' - 14560'. Intermittent hard spots. Washing down @20 - 25 K WOB, 580 gpm, 2920 psi, 18 K TO, 70 rpm. Start losing fluid @ 14501' +1- 1 bpm. Slow pumps to 450 gpm. Circulate sweep around @ 450 gpm, 1570 psi. Losses from 60 bph down to 30 bph @ bottoms up. Spot 540 bbl "Steel Seal" casing pill from 14560' - 8800' @ 540 gpm, 1570 psi. No losses. Flow check, POOH for 7" casing to 8800'. Break Circulation, Spot 250 bbl "Steel Seal" pill from 8800' - 6140'. Flow check. Pump dry job. Flow check. POOH for 7" casing. LD 102 jts 5" DP. Stand back the rest. No losses. LD HWDP & BHA #7. Clear rig floor. Pull wear bushing. RU casing tools. PJSM. PU shoe track and baker-Iok. Check floats. TIH wI 7", 26 #/ft, L-80, BTC-M casing per running program: Float shoe, 2 jts casing, float collar, 2 jts casing, marker jt, 1 jt casing, marker jt, and 345 jts 7" casing. 80 ftI min running speed in casing. Circulate bottoms up at casing shoe. Minimal losses. CIH @ 60' I min. Wash down @ 6 bpm, 520 psi fl 8700' - 9300' (= bottoms up). CIH @ 60' I min. Wash down @ 6 bpm, 650 psi and 9 bpm, Printed: 9/30/2002 9: 18:00 AM ~) ') BP EXPLORATION Operations Summary Report Page 15 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 9/3/2002 Spud Date: 9/4/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/27/2002 00:00 - 18:30 18.50 CASE C PROD1 980 psi. f/12000' - 13300' (=bottoms up), no losses. CIH to bottom. MU hanger and landing joint. Wash to bottom. Land casing in well head. 18:30 - 19:00 0.50 CASE C PROD1 Circulate OH volume @ 9 bpm, 980 psi. No losses. 19:00 - 19:30 0.50 CASE C PROD1 LD Fill-up tool. MU cement head. 19:30 - 20:00 0.50 CASE C PROD1 PJSM with rig crew & cement crew while circulating OH volume @ 9 bpm, 730 psi. Batch mix cement. 20:00 - 22:30 2.50 CEMT C PROD1 RU to cement. Pump 5 BW. Test lines to 3500 psi. Pump 40 bbls 11.0 ppg MudPush XL @ 4 bpm, 480 psi. Drop bottom plug. Pump 444 sxs "G" cement (95 bbls), 15.8 ppg, 1.2 ft^3/sx yield @ 6 bpm, 780 psi. Shut down. Clear cement lines to pits. Drop Top Plug. Displace with sea water using rig pumps @ 9 - 10 bpm, 600 psi initial pressure & 1200 psi final pressure. Bump plug with 554 bbls to 3000 psi. Casing test for 10 min. Cement in place @ 2200 hrs. Full returns during job. 22:30 - 23:00 0.50 CEMT C PROD1 Check floats. RD cement head. LD landing jt & casing equipment. 23:00 - 23:30 0.50 CASE C PROD1 RIH with 7" casing pack-off. Set pack-off. RILDS. Test to 5000 psi I 10 min. 23:30 - 00:00 0.50 CASE C PROD1 RU slick line for gauge ring I junk basket run. 9/28/2002 00:00 - 09:00 9.00 CASE C PROD1 RU Slick line unit. RIH with 6.125" gauge ring and Junk basket on Slickline. Having difficulty getting down from 3800'. RIH to 6805' making slow hole. POOH for wheels. RIH to 14495'. WLM POOH. RD slick line unit. Rig crew cleaning pits, rig, and working on Mud pumps, 09:00 - 12:00 3.00 CASE C PROD1 RU and LD 5" DP from derrick using mouse hole. Freeze protect outer annulus with 129 bbls crude oil @ 3 bpm with Little Red Services. Max pressure 1100 psi, final pressure 900 psi. 12:00 - 12:30 0.50 CASE C PROD1 Service rig & top drive. 12:30 - 18:00 5.50 CASE C PROD1 Continue to LD 5" DP from Derrick. 18:00 - 19:30 1.50 RUNCOrvc CaMP RU to run 4 1/2" completion string. 19:30 - 00:00 4.50 RUNCOrvc CaMP PJSM. MU & TIH wI completion BHA per competion running order. CIH w/4 1/2", 12.6 #/ft, L-80, TCII tubing as per completion running order. 9/29/2002 00:00 - 16:30 16.50 RUNCOrvc CaMP Continue TIH with 4.5" completion string as per running procedure. Total of 355 jts, 4.5", 12.6 #/ft, L-80, TCII tubing + jewelery ran in well. 16:30 - 17:30 1.00 RUNCOrvc CaMP Pick up Tubing hanger. MU landing jt. RIH and land in well head. RILDS. PU wt = 175 K, SO wt = 92 K. 17:30 - 19:00 1.50 RUNCOrvc CaMP Spot inhibited seawater in IA @ 3 bpm, 390 psi. Change out pipe rams to 2 7/8" x 5". 19:00 - 19:30 0.50 RUNCOrvc CaMP Drop ball and rod wI wheels. RU test equipment. PJSM. 19:30 - 21 :00 1.50 RUNCOrvc CaMP Pressure up on tubing to set packer. Continue pressure to 4000 psi I 30 min for tubing test. Bleed tubing pressure to 2500 psi. Pressure up on IA to 4000 psi I 30 min for packer test. Bleed pressure off tubing and shear RP valve. 21 :00 - 22:00 1.00 RUNCOrvc CaMP RD test equipment & circulating head. LD landing joint. Install TWC & test from below to 3000 psi I 5 min. Printed: 9/30/2002 9:18:00 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) BP EXPLORATION Operations Summary Report Page 16 of 16 S-114 S-114 DRILL +COMPLETE DOYON DOYON 14 Start: Rig Release: Rig Number: 14 Spud Date: 9/4/2002 End: 9/3/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/29/2002 22:00 - 00:00 2.00 BOPSUR C COMP Clear rig floor. ND BOP stack. Change out saver sub to 4" HT. 9/30/2002 00:00 - 05:30 5.50 WHSUR COMP Continue ND BOP Stack. NU tree. RU DSM. Pull TWC. Freeze protect IA wI 88 bbls diesel @ 2.7 bpm, 1800 psi. U-tube freeze protect. Secure Tree. Note: No BPV installed. 05:30 - 06:00 0.50 RIGD COMP RDMO. Release rig for Mob to W-pad @ 06:00 hrs, 09/30/2002. Printed: 9/30/2002 9:18:00 AM ) ) Well: Field: API: Permit: S-114A Prudhoe Bay Unit 50-029-23116-01 202-198 Rig Accept: 09/03/02 Rig Spud: 09/19/02 Rig Release: 09/30/02 Drilling Rig: Doyon 14 POST RIG WORK 11/12/02 PUT HEATER ON SWAB VALVE TO THAW OUT. RUNNING IN HOLE W/2" RS PULLING TOOL W/3.46" BELL GUIDE TO PULL BALL-N-ROD. 11/13/02 PULL B&R @ 14,226' SLM. PULL 1" RPV @ 14,105' SLM (14,115' AMS). ATTEMPT TO PULL STA# 2 @ 7475. SHUT DOWN JOB DUE TO NORCOM COMING OUT TO WORK ON WELLHOUSE @ MIDNIGHT. WELL LEFT SHUT IN. (STA #1 EMPTY). 11/25/02 BALL AND ROD & ST A# 1, 1" RP SHEAR PREVIOUSLY PULLED. START RUNNING IN HOLE WI KOT TO PULL STA# 2 USING ROLLER STEM. 11/26/02 PULL STA# 2 AT 7478',1" DGLV, BK. SET STA# 2 (1" BK DOME - 1706 TRO, 1/4"). ATTEMPTING TO SET ST A# 1 . 11/27/02 SET STA 1 AT 14095',1" OGLV, BK. PULL RHC-M PLUG BODY. DRIFT AND TAG TO WI 33/8" X 10', TEL, SB TO 14478' COR TO DRILLING. NO SAMPLE 58' OF RAT HOLE. GAVE WELL BACK TO PAD OP. LEAVE SHUT IN. 12/05/02 LOGGED TWO SCMT PASSES FROM TD (14460') TO 14000'. TUBING TAIL DETECTED @ 14252'. PRESSURE IN THE MID OF PROPOSED PERFS = 2497 PSI. SCMT LOG SHOWS POOR CEMENT JOB FROM TD TO TT. 12/06/02 PERFORATED INTERVAL 14406'-14420' WITH 3-3/8" HSD GUN. USED PURE DESIGN GUN, POWERJET PJ3406 CHARGES, HMX, 6 SPF, 60 DEG PHASING. TD TAGGED @ 14460'. DSO TO POP AND TEST I PRE ADPERF. ) ) 16-0ct-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-114A II FR Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 12,142.72' MD Window / Kickoff Survey 12,185.00' MD (if applicable) Projected Survey: 14,890.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED OCT 1 7 2002 AIa8U œ & Gas Cons. Comnûaaion Anchor8ge ~cd.-}C¡~ Sperry-Sun Drilling Services North S/opêiAlaska BPXA PBU_WOA'SPad S-114A Job No. AKZZ22152, Surveyed: 21 September, 2002 Survey 1feport 15 October 1 2002 Your Ref: APIS00292311601 Surface Coordinates: 5980820.17 H, 618929.73 E' (70021' 22.S07S- N, 149002' 02.8406" W) Grid Coordinate System: HAD27 Aléska State Planes, Zone 4 Surface Coordinates relative to Project H Reférence: 980820.17 N, 118929.73 E (Grid) Surface Coordinates relative to Structure Reference: 52.14 S, 1012.31 E(True) Kelly Bushing: 70.20ft above Mean Sea Level Elevation relative to Project V Reference: 70.20ft Elevation relative to Structure Reference: 70.20ft sn-.-.....y-su., DAtLLING SÈAVaC&S A Halliburton Company )' EFf!N 'ap'iI 'V-'" t ¡ '¡ ¡ .. . ,., J ¡¡" ' , II t1! i ~ "-" "~' Survey Ref: svy11337 Sperry-Sun Drilling Services Survey Report for PBU_WOA S Pad - $-114A Your Ref: AP/500292311601 Job No. AKZZ22152, Surveyed: 21 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) 12142.72 71.000 292.760 5168.45 5238.65 4170.97 N 9205.58 W 5984844.46 N 609659.09 E 10104.50 Tie On Point - 12185.00 71.060 292.310 5182.19 5252.39 - 4186.29 N 9242.51 W 5984859.20 N 609621.92 E 1.016 10144.43 Window Point 12267.97 69.170 295.540 5210.42 5280.62 4217.91 N 9313.82 W 5984889.68 N 609550.12 E 4.311 1 0222.41 12364.24 66.430 292.150 5246.80 5317.00 4253.96 N 9395.31 W 5984924.43 N 609468.06 E 4.327 10311.48 12460.28 65.980 295.100 5285.56 5355.76 4289.17 N 9475.81 W 5984958:36 N 609387.02 E 2.849 10399.30 '-'" 12555.37 62.950 296.410 5326.54 5396.74 4326.43 N 9553.09 W 5984994.39 N 609309.16 E 3.420 10485.09 12652.38 60.290 296.850 5372.65 5442.85 4364.68 N 9629.38 W 5985031.43 N 609232.27 E. 2.771 10570.41 12748.01 56.440 296.970 5422.80 5493.00 4401.53 N 9701.97 W 5985067.11 N 609159.11 E 4.027 10651.79 12843.95 52.960 296.670 5478.23 5548.43 4436.85 N 9771.83 W 5985101.32 N 609088.69 E 3.636 10730.06 12940.44 50.330 297.180 5538.10 5608:30 4471.11 N 9839.29 W 5985134.50 N 609020.69 E 2.757 10805.70 13034.13 47.670 297.910 5599.56 5669.76 4503.79 N 9901.98 W 5985166.19 N 608957.49 E 2.899 10876.35 13129.91 45.990 299.310 5665.09 5735.29 4537.23 N 9963.31 W 5985198.65 N 608895.64 E 2.052 10946.10 13226.29 43.950 298.750 5733.27 5803.47 4570.29 N 10022.86 W 5985230.76 N 608835.57 E 2.156 11014.08 13318.78 42.200 301.400 5800.84 5871,04 4601.91 N 10077.52 W 5985261.51 N 608780.42 E 2.722 11077.03 13415.58 40.500 306.160 5873.52 5943.72 4637.41 N 10130.67 W 5985296.16 N 608726.71 E 3.692 11140.28 13512.42 40.840 305.820 5946.97 6017.17 4674.50 N 10181.73 W 5985332.43 N 608675.07 E 0.419 11202.33 13607.76 40.250 306.000 6019.42 6089.62 4710.85 N 10231.93 W 5985367.98 N 608624.30 E 0.631 11263.29 13704.63 38.720 306.630 6094.18 6164.38 4747.32 N 10281.56 W 5985403.66 N 608574.09 E 1.633 11323.79 13800.72 37,150 309.340 6169.97 6240.17 4783.65 N 10328.13 W 5985439.25 N 608526.96 E 2.382 11381.45 13894.25 36.310 309.670 6244.93 6315.13 4819.23 N 10371.29 W 5985474.14 N 608483.24 E 0.923 11435.72 13990.25 35.210 309.190 6322.83 6393.03 4854.86 N 10414.62 W 5985509.08 N 608439.35 E 1.182 11490.17 14086,14 33.570 307.4 70 6401.96 6472.16 4888.46 N 10457.09 W 5985542.00 N 608396.35 E 1.988 11542.97 14182.62 32,520 308.360 6482.83 6553.03 4920.79 N 10498.59 W 5985573.66 N 608354.34 E 1.199 11594.34 ~ 14277.99 31.700 308.470 6563.61 6633.81 4952.28 N 10538.31 W 5985604.52 N 608314.12 E 0.862 11643.75 14374.32 30.970 307.730 6645.89 6716.09 4983.20 N 10577.73 W 5985634.80 N 608274.22 E 0.857 11692.64 14471 . 12 30.860 307.430 6728.94 6799.14 5013.53 N 10617.15 W 5985664.51 N 608234.33 E 0.196 11741,27 14567.17 30.720 307.500 6811.45 6881.65 5043.43 N 10656.17W 5985693.79 N 608194.83 E 0.150 11789.36 14663.05 30.030 307.710 6894.17 6964.37 5073.02 N 10694.58 W 5985722.16 N 608155.96 E 0.728 11836.77 14756.61 29,150 307.800 6975.53 7045.73 5101.30 N 10731.11 W 5985750.46 N 608118.99 E 0.942 11881.91 14890.00 29,150 307.800 7092.02 7162.22 5141.13N 10782.45 W 5985789.47 N 608067.02 E 0.000 11945.39 Projected Survey -----..--.--------..-..-----... .----_w_- 15 October, 2002 - 14:35 Page 2 of3 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_WOA S Pad - S-114A Your Ref: API 500292311601 Job No. AKZZ22152, Surveyed: 21 Sèptember, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 295.490° (True). Magnetic Declination at Surface is 25.961°(07-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 14890.00ft., The Bottom Hole Displacement is 11945.39ft., in the Direction of 295.492° (True). y .~ Comments Measured Depth (ft) Station Coordinates rvD Northings Eastings (ft) (ft) (ft) Comment 12142.72 12185.00 14890.00 5238.65 5252.39 7162.22 4170.97 N 4186.29 N 5141.13 N 9205.58 W 9242.51 W 10782.45 W Tie On Point Window Point Projected Survey Survey to%rogram for S-114A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ",-,/ Survey Tool Description 0.00 1364.98 0.00 1327.09 1364.98 14890.00 1327.09 Tolerable Gyro(S-114 Gyro) 7162.22 AK-6 BP JFR-AK(S-114) 15 October, 2002. 14:35 Page 3 of3 DrillQuest 3.03.02.002 ) ) ó(oa-IC¡~ 16-0ct-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-114A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 12,142.72' MD Window / Kickoff Survey 12,185.00 I MD (if applicable) Projected Survey: 14,890.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) OCT 1 7 2002 AJ88ka at: & Gas Cons. CommieIion Anchorage Sperry-Sun Driling Services North Slope Alaska BPXA PBU....WOAS Pad S-114A"WD ~ Job Ho. AKMW22152, Surveyèd: 21 September, 2002 Survey Report 15 October" 2002 Your Ref: API s00292311601 Surface Coordinates: 5980820.17 H, 618929.13 E (10021' 22.5075" H, 149002'02.8406" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 '~ Surface Coordinates relative to Project H Reference: 980820.17 H, 118929.73 E (Grid) Surface Coordinates relative to Structure Reference: 52.14 S, 1012.31 E(True) Kelly Bushing: 70.20ft above Mean Sea Level Elevation relative to Project V Reference: 70.20ft Elevation relative to Structure Reference: 70.20ft !!In""'~\I-.UI! bAILLING 's.Àvtt::es A Halliburton Company Survey Ref:svy11339 Sperry-Sun Drilling Services Survey Report for PBU_WO-4S Pad. S..114A MWD Your Ref: API 500292311601 Job No. AKMW22152, SurveyètJ: 21 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12142,72 71.000 286.190 5169.29 5239.49 4151.57 N 9194.75 W 5984825.24 N 609670.23 E 10086.38 Tie On Point 12185,00 71.060 292.310 5183.05 5253.25 4164.74 N 9232.47 W 5984837.81 N 609632.30 E 13.689 10126.10 Window Point 12267.97 69.170 297.940 5211.29 5281.49 4197.83 N 9303.09 W 5984869.78 N 609561.17 E 6.775 10204.08 12364.24 66.430 292.860 5247.68 5317.88 4236.08 N 9383.55 W 5984906.74 N 609480.11 E 5.653 10293.17 12460.28 65.980 295.770 5286.43 5356.63 4272.25 N 9463.62 W 5984941.64 N 609399.48 E 2.812 10381.01 \....... 12555,37 62.950 297.050 5327.42 5397.62 4310.40 N 9540.46 W 5984978.56 N 609322.04 E 3.410 10466.79 ~/ 12652.38 60.290 297.320 5373.53 5443.73 4349.39 N 9616.38 W 5985016.34 N 609245.52 E 2.753 10552.10 12748.01 56.440 297.490 5423.68 5493.88 4386.86 N 9688.65 W 5985052.66 N 609172.66 E 4.029 10633.46 12843,95 52.960 296.980 5479.11 5549.31 4422.69 N 9758.25 W 5985087.38 N 609102.49 E 3.653 10711.71 12940.44 50.330 297.880 5538.98 5609.18 4457.53 N 9825.41 W 5985121.15 N 609034.79 E 2.822 10787.32 13034.13 47.670 298.760 5600.44 5670.64 4491.06 N 9887.65 W 5985153.69 N 608972.02 E 2.926 10857.94 13129.91 45.990 300.380 5665.97 5736.17 4525.52 N 9948.41 W 5985187.18 N 608910.73 E 2.144 10927.61 13226.29 43.950 299.670 5734.15 5804.35 4559.61 N 10007.38 W 5985220.33 N 608851.23 E 2.180 10995.51 13318,78 42.200 301.610 5801.71 5871.91 4591.78 N 10061.72 W 5985251.63 N 608796.37 E 2.373 11 058.41 13415.58 40.500 305.880 5874.39 5944.59 4627.26 N 10114.90 W 5985286.26 N 608742.65 E 3.402 11121.67 13512.42 40.840 306.530 5947.84 6018.04 4664.53 N 10165.82 W 5985322.72 N 608691.14 E 0.561 11183.68 13607.76 40.250 306.960 6020.29 6090.49 4701.61 N 10215.48 W 5985359.00 N 608640.89 E 0.685 11244.46 13704.63 38.720 306.940 6095.05 6165.25 4738.64 N 10264.71 W 5985395.24 N 608591.09 E 1.579 11304.83 13800.72 37.150 310.150 6170.84 6241.04 4775.41 N 10310.91 W 5985431.28 N 608544.30 E 2.624 11362.37 13894.25 36.310 309.680 6245.80 6316.00 4811.30 N 10353.81 W 5985466.49 N 608500.84 E 0.947 11416.54 13990,25 35.210 309.690 6323.71 6393.91 4847.13 N 10396.98 W 5985501.62 N 608457.10 E 1.146 11470.92 14086.14 33,570 307.990 6402.83 6473.03 4881.10 N 10439.15 W 5985534.92 N 608414.40E 1.982 11523.61 14182.62 32,520 308.490 6483,71 6553.91 4913.66 N 10480.48 W 5985566.82 N 608372.56 E 1.124 11574.92 ~ 14277.99 31.700 309.170 6564.49 6634.69 4945.45 N 10519.97 W 5985597.98 N 608332.57 E 0.940 11624.25 14374.32 30.970 307.980 6646,77 6716.97 4976.68 N 10559.13W 5985628.59 N 608292.92 E 0.993 11673.04 14471 ,12 30.860 306.820 6729.82 6800.02 5006.89 N 10598.63 W 5985658.16 N 608252.94 E 0.626 11721.70 14567.17 30.720 307.740 6812.33 6882.53 5036.67 N 10637.75 W 5985687.32 N 608213.35 E 0.512 11769.83 14663.05 30.030 307.460 6895.05 6965.25 5066.25 N 10676.17 W 5985716.29 N 608174.48 E 0.735 11817.23 14756,61 29.150 307.710 6976.40 7046.60 5094.43 N 10712.18 W 5985743.88 N 608137.42 E 0.950 11862.41 14890.00 29.150 307.710 7092.90 7163.10 5134.17 N 10764.18 W 5985782.80 N 608085.40 E 0.000 11925.91 Projected Survey ------- 15 October, 2002 - 14:39 Page 20f3 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_WOAS Pad. S..114A MWD Your Ref: APISOO292311601 Job No. AKMW22152, Surveyed: 21 Septèmber, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 295.490° (True). Magnetic Declination at Surface is 25.961 °(07 -Sep-02) \- Based upon Minimum Curvature type calculations, at a Measured Depth of 14890.00ft., The Bottom Hole Displacement is 11925.91ft., in the Direction of 295.500° (True). ---I Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12142.72 12185.00 14890.00 5239.49 5253.25 7163.10 4151.57 N 4164.74 N 5134.17 N 9194.75 W 9232.4 7 W 10764.18 W Tie On Point Window Point Projected Survey Survey tool program for S-114A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ~ Survey Tool Description 0.00 1364.98 0.00 1327.09 1364.98 14890.00 1327.09 Tolerable Gyro(S-114 Gyro) 7163.10 MWD Magnetic(S-114 MWD) ._------~------- 15 October, 2002 - 14:39 Page 30f3 DriflQuest 3.03.02.002 bp October 18, 2002 ) ') ... ,\1'.'", -...,~ ~~..- ~~- ~...-- ~.~ ~....... .j'~~i\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 \ J ".,.., '\) "RÞG~\ V ~ -¿. ~-J\.J-(j) OCI ¿; Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for S-114A to Convert to Water Injection Well. BP Exploration Alaska, Inc. proposes the following work to complete new injection well S-114A. This work will commence immediately following completion of wing to tree-top tie-in for temporary flowback of S-114 through S-106 flow-line. Objective of the temporary flowback is to enhance perforation cleanup and allow shorter pre-production times for Satellite injection wells. Surface facility work for tie-in to injection service is targeted for November 1 st, so work should be completed by then if possible. The procedure includes the following major steps: Category Step Description S 0 E 0 E S 0 1 2 3 4 3 7 5 Max Deviation: Perf deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S value: Wellbore Fluids: BHP: PULL RHC, Set LGL Vs, DRI FT FOR PERF (> 14420') Unload/Stackout with Gas-lift (verify tbg FL at GLM1) JewelryLOG/SCMT/ PERF#1 (14' PURE test) Flow 12-hours, obtain 6-hour S-pad well-test AdPERF#2 FLOW FOR 10-DAY CLEANUPITESTING C/O LGL Vs TO DGL Vs obtain SBHPS (min. 2-day SI) MITIA (AOGCC witness) for conversion to injection 74° 3497' MD 31° @ 14420' MD 3.725" XN Nipple @ 14259' (RHC-M plug in place). 14495' WLMD SL tag prior to tubing installation. 9/29/02: Rig ran tubing. Not tested (new well). Nearby well S-101 '8' ppm. Seawater, u-tubed & FP tubing & IA with 88bbls diesel. 3400 psia @ 7600' MD @ 6779' TVDSS PROCEDURE: ') 1. PULL RHC-M plug, DRIFT FOR PERF w/3-3/8" x 30' DG, Install LGLVs. a) 74 deg sail angle, rollers recommended b) If DG can't drift to bottom, leave RP shear in place and pump tools down c) 1" Mandrels at 7496' and 14127', 3/8" 8/0 desired in GLM1, consult GLE for LV design. ") 2. Unload/8tackout with Gas-lift . Goal is to remove liquid from the tubing and allow BHP to be controlled with WHP . Open well to system and pump 5-1 Obbls MeOH down IA prior to 8U . 81 after AL gas reaches surface and leave AL on until max pressure reached . verify tbg FL at GLM1 3. JewelryLOG/8CMTI PERF 14' for PURE (Perforate Underbalanced Reservoir Evalution) test. Separate Perf form attached. a) With a full column of gas (6500' tvd) and 1800psi whp, expected underbalance is 400psi, leave the wing valve open while perforating so the well can be surged to system for a short period prior to retrieving guns. b) If E-line cannot reach desired depths by pumping tools down, contact APE, perforating will be done in 1 rigup with CTU. c) If RP shear is left in place for perforating, replace with 8/0 prior to CT perf or flowback. 4. Flow to system for 12-hours with -4mmcfd GL, obtain 6-hour 8-pad well-test, MeOH may needed to added to IA while WHT is below 50F to prevent hydrates. a) Default NOC=0.865 5. Return for AdPERF#2 6. FLOW a maximum of 10-DAYs FOR CLEANUPITESTING a) Obtain liquid sample and send to PBU lab FOR API gravity and bs&w. Return to GC2 and obtain well-test from 8-pad separator as soon as possible). 7. cIa LGLVs TO DGLVs obtain 8BHP8 (min. 2-day 81) . 8. MITIA (AOGCC witness) for conversion to injection Y 9. Load annulus, pressure test IA to 3500 psi. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. S7:~~ Jim Young Greater Prudhoe Bay Aurora Development Engineer W61r 3/'>/Z.OOš ()F5 J /3;03 ~ t~{vJ APPLICATION FOR SUNDRY APPROVALS ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ') Abandon- Alter casing - CONVERT TO INJECTION WELL 2. Name of Operator " BP Exploration (Alà~ka), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Suspend- Repair well - 1. Type of requèst: 662' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 956' FNL, 4505' FEL, SEC 28, T12N, R12E, UM At effective depth 930' FNL, 4539' FEL, Sec. 28, T12N, R12E, UM At total depth 801' FNL, 4704' FEL, Sec 28 T12N, R12E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- (asp's 618929,5980821) (asp's 608277, 5985646) (asp's 608242, 5985672) (asp's 608075, 5985798) 14890 feet 7162 feet 14470 feet 6798 feet Plugs (measured) Junk (measured) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate _X 6. Datum elevation (DF or KB feet) RKB 70.2 feet 7. Unit or Property name CONVERSION Other _X Prudhoe Bay Unit 8. Well number S-114A 9. Permit number / approval number 202-198 10. API number 50-029-23116-01 11. Field I Pool Prudhoe Bay Field / Aurora Pool Casing Conductor Length 115' 6106' Size Cemented Measured Depth True vertical Depth 20" 260 sx AS (approx) 149' 149' 10-3/4" 942 sx Arcticset Lite III, 6140' 3370' 726 sx 'G" 7" 445 sx Class 'G' 14555' 6871' Surface Production 14524' Perforation depth: measured Not Perforated true vertical Not Perforated Tubing (size, grade, and measured depth 4-1/2" 12.6#, L-80 @ 14269'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 14213'. 4-1/2" HES 'X' Nipple @ 2323'. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: November, 2002 16. If proposal was verbally approved Oil- Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ();... f~ Jim ~ oufg ( Approved by order of the Commission Form 10-403 Rev 06/15/88 . RllltVIÐ OCT 21 2002 &1_01& GasGonS. commission ðI .' Anchorage BOP sketch - Gas- Suspended - WATER INJECTION Questions? Call Jim Young @ 564-5754. Title: Aurora Surveillance Engineer Date October 18. 2002 Prepared by DeWayne R. Schnorr 564-5174 I Approval nO'302.- ~2 g- Date Y7/07 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - .!3j>P Test - Location clearance - ¡ J z J Mechanical Integrity Test Þ. Subsequent form required 10- ....,... 0 T Ii:.- -<¿ £~~ ~ Commissioner 0 R \ G\ NA L RBDMS BFl :v1AR 6 20m SUBMIT IN TRIPLICATE ) PERFORATING PROCEDURE ') Office Ph: 564-5754 ......"..................,-.,.,..,-,.,.,-...-....,-......................... Home Ph: 248-0133 .....",..,.,.,..........,.......,...........,-,...,-........,-".....-,-.... CelVPager: .,...,.,...................~.~~.:~~~!.",.."......"»>.,.,.,,.. CC or AFC: 5M0044 Detail Code: 9335-070-770 Description::Þ.:!3.Ç~Iç,Q:t0.~Q~f:(çf~Tp.:~B~,...,........................:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::..,.....,."",..."""""......""..........,.......""",......."..." WBL Entries Work Desciption SCMT, PURE TEST Well: Date: S-114A ,.,...............,...........,.......,...........,...""""". 7/12/02 API #: 50-029-23116-01 ..,.,<......,.................................. Prod Engr .~~~"y~~.~,~,...",.....",",... -'-'0""""""""""""""""""""""''''-;........." lOR 2000 Type E Var 4,0 06/04/01 H2S Level: _~10'p~~:: Well Obiectives and Loaaina Notes: Jewelry log to tie-in short-jts (below perfs) and TT. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: ,My'y'P.Q.!3.",.... needed Date: ......~"Y?f.?ggg Company: .êp.~E.':Y.,..........., Depths (from-to) ........~,~!,~9.?.".... .....,1.~!.~?.Q..", Schlum Depths (from-to) Feet .....~..~!,~9.§.'...." - ,....}~~,~?.9,'...." 14' SPF 6 ,....>.................,.....,.,.. ......,.><.................... '0.,.....'0''''............., ""...,.,....<>............... "''''''''''''.'''''''''4'''''''''' """'"0''''''''''''''''''' .....n".,...,.........,...... ,.."..",n.........,.,...,... """""""""""'''''''''''''''''' ......"......."................... ,...",.,..........,...,..........,.., """"'''''''''''''''''''''''''''' ...........,...................".. ...."."...................... ,...........,.,.,.,......,....,.. to................,,,.,,........., Gas Jetting Expected? ,....,,,,....~g............ At what Depth? Requested Gun Size: ,........~~~(,~.':........, Charge: ,p.l~4.g,~..........,............. Desired Penetration: >20" to"""""""""""""""""""" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie in to Jewelry @ Minimum ID: Tail Depth: ,.2,1.~.?g,.,.t~!!y,.. M D """;"~;i!(j~8"",,.,,in ...~.1?§,1.:.~~!,I,y'", ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ ,W?~!Q?'''(~~) Perforation Summary Last Tag: ,J,~1.~§),~.I,I)~.., ft MD on Well: Date: S-114A "'...---....""-......--............... API#: 50-029-23116-01 """,.......,..."",."."......... "''''''''''''''''''''..............,...........................,. General Comments: Add 0 to the tie-in lo'g"to"be"öiï""""'''''''''''''' depth with the reference log. feet .....><.."..".........." Orient. NA Phasing 60 Zone Ad/Rellperf .......,ç."......................!.P,~!1......."..,...... "0.'00"'"'''''''''''' 0.............,...,.......,....................... .......0'''''''',>",,,,,, ,.........,."............,....<>................. ..>.................,."..........,.,.....,.>.,.,.,...,...,.,.,...., """"""""""""'" ""'''''''''''''''''''''''''''''''''''0'''''''''' "''''''''''''''''''''''''''''''''.."..".........."............,. .......".......".........., """'...,......,.....,.,.,.,.,.."......,."",..., """""""""""""""'"''''''''''''''''''''''''...,.,...,.... ............................. "''''''''''''''''''''''''''''''''''''''''''''''''''' ""'.,.......,.,.........,.....,....."",.......,.............,." N/A MAX Swell=3.66" in liquid Entry Hole Diam: ,.., ,?'g:~':...... , ,~.!~,~..~,~~!!..9g.I,~.~r.!..9.t.g.?:~..~~~..~,~ggp,~!..;.Y.hf??..~~.p.,~g~~~..,I;!,~9,~r.þ.~!~r.!~~...",.... ...!~.~99p.~!!..f!9;.Y.,f9.U.:?nJ!n.y,~~~..~g..~!!.<?~..f?.~rLg,~.þ'r.i.~)9..9,!~~~L............................. .":?,~.2!1:U,~J!?~.!9.~.p~rf~L~!:,.g..IT:.."......................,,............................,..,,,,,,.,,...................,,......., ."",.............,,~Y~I.I.P..~.~..~~~.!E~P..~.~~................... @ ..1.4.!?§~. 'MD 7 in ::::::HAÞ.Þ.::::: MD is 2800 psi ..,.....,....,............... Summary Dist Town: Prod Engr: Anch Prod Engr ,"'"",,,,,,,,,,,,,,,,,,,,>,,,,,,,,,,,,,,,,.......»».................,,... P. D. Center PBTD ........"......,,,,,....,,.......... ...."..".....................,,,,,..... Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF "r,,"""'"'''''''''''''''''''''''' ......."..............,............... ...~.......",............. ......,....................."........................,........"..."........."...,.....""""'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' "........,,,.,,..,...................,, Zone Aperf/Reperf """"''''''''''''''''''''''''' ''''''''''''''''''''''''''''''..... .,.,............"".........,-.- Phasing "...............""...",,,.,,... 00 00 0 """"'-'-""'.'''''''''''''',-,......",....,.........,.,-,-,.".,....,' """""'"","""''''" ''''''''''''''''''''''''''''''''''''''''''''''''''',-'.'' ....,.................."" ) PERFORATING PROCEDURE ') API #: 50-029-23116-01 ...........<.-.<..........,..................., Prod Engr .~!~"Y~~.~JL."....""".... Office Ph: ,,,,,,,,,,,,,,,,,,,,,,,,,,,.~~.~.:~!.~~,,.,,,,,,,,,,,,,,,,.,,,,,,, Home Ph: 248-0133 """"""""""""'''''''''H'''''''''''''''''''''''"',,.................., Cell/Pager: ,,,,,,.........,,,.......,,,~.~~.:~~Q!'....,,,..,,,,,,,,,,,,..,,,, CC or AFC: 5M0044 Detail Code: 9335-070-770 Description:ÞBÇQ,T9.ÞJ0.p':Çgt:(ÞNTÞ.:sBf...,.......,.......,..........:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::..................,.....,...........,......................................., WBL Entries Work Desciption AFTER WELL-TEST OF PERF#1 (PURE TEST) Well: Date: S-114A ............,...........,.....,...,<...........<.........,..'0" 10/3/02 ..................,..............-................"............., lOR 2000 Type E Var 4,0 06/04/01 ~ ';::""-:::;;::;':=:-.=:-. -- . --- I ¡i H2S Lev~l: JI i¡ <10ppmn l::-::::;:;.;:;-:.....----..:.:.:;.;-.--......-......-::J Well Objectives and LOQQinQ Notes: Jewelry log to tie-in short-jts (below perfs) and TT. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: .~YY.P9.B....".. needed Date: ",,,,~.y?!.?g9.9, Company: .êp.~,~.'Y.........,.... Depths (from-to) ........~,~~,~~ê....... .....,~.~!.~9.?...., Schlum Depths (from-to) Feet .....~..~!,~,~ê.'...... - ......~,~~,~9.?.'...., 14' SPF 6 .....,c,-,.......,.......""'''" .....co....-,................. ,c..,...,...,.,.........,...... "",><,,,,,,,,,,,,,,,,,,,,,,,, ,,,,.,.,........'.................. ....,.....,................... .....,.............'.........,. .....................,.,....... '."...."............."....."" ......,.....................,. ............................... .....'......................... """"""""""""""""" ....".,...,................" ...,........................... ,..'.....'.....................' Gas Jetting Expected? No ,...,...................,.,...., At what Depth? Requested Gun Size: ,.......,~~~(~.':."",,,. Charge: ,p.J.~1.9.~.................",,>... Desired Penetration: >20" ,..............,.,....,.,,................ Is Drawdown Necessary/Desired/Unnecessary During Peñorating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardlíne Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hard/ine) Tie in to Jewelry @ Minimum ID: Tail Depth: "!.1.~,?g.,,.!~!!y,.. MD a~m:a5~' in ::I~?§I:f~!:(y.::: ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ .W?WQ?J~!:J Perforation Summary Last Tag: .,,~.:4~.~,?..!,?.I,!y".. ft MD on Well: Date: S-114A ,,-"''''...,.......,....'''...,....''''''....,...,.... API#: 50-029-23116-01 ....""""""".."".."..." ""'''''''''''''''''''''''''''''''''''''''''''''''''''''' General Comments: Add 0 to the tie-in log'to"be"on'''''''''''''''''''''' depth with the reference log. feet ......",................,. Orient. NA Phasing 60 Zone Ad/ReJlpeñ ."",..ç.............,....".....!.P'.~!1....""".."".., ".......,................. ............,...".........................,.,..... ........,.,......."....... """'0.......................................". "'"'><'''''''''''''''''''''''''''''''''''''''''''0>0''''''''''''' ..,.,...................... ......,.,c>..<>................................... ..,.,.....,...,.................,.................,.,............... ""....................... .......................".,........,."..........., ''''''''''''''''''''''''''''''''''',.,.........,....".."""""" ...."..................... """"'"'''''''''''''''''''''''''''''''''''''''' """"'''''''''''''''''''''''''''........,......,."."""""". N/A MAX Swell=3.66" in liquid Entry Hole Diam: ,.. ...?'9.A'~.....,. .y'y,!~,b..~,f~!Lçg,I,~.~!]'.2!..9.~~..~~~,.~..~g.Q.p',~!..~~,I?I,,~~'p"~g~~9..~.1]9.~r.Þ.~!~!]~~"....... ...!~.1Q9p.~!.'J!~~.f~~"1.~?,nJ!.IJ.~~~~..~9..~!!2~,,I?~!:!,,9.~,Þ.rj.~)Q..ç,I.~~~:".........."................ ...~.~g,Œ~j!~..(Þ.~,!2~.P"~,~~2..~!:I,9"IT:"............................."".."........'"..................."............,,,........... MULTIPLE X-NIPPLES @ 14,259 'MD """"""7'''''''''''''1'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' ................... ::::::EA9.9.::::: MD is ....",......,..?'~Q9., psi Summary Dist Town: Prod Engr: Anch Prod Engr """"""'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' P.D. Center PBTD """"""""""'"'''''''''''''''''''''''''''''''''',...,.....,...,...,.....,.,.,.,.",........."",.,...,.,."..,.,.,..-...,."....,...,......,..,.........,.."""""""""","""""""""""""""""....,.,...",.,...,.,.",.,.,."",......".,.,.,..".,.""""""""""""",,'" Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF "..........."................ "......"""........."...."". Phasing Zone Apeñ/Repeñ .....,........."......". 00 00 0 ."'''''''''''''''''''''''''''''''"'''''''."''''''''''''''''''''....,.... "'''''''''''''''''''''''''''''''''''''''.''''''''''''''''''''''''''. '"''''.'''''.........''''' ') ) - TREE = 4-1/16"5MCIW . WELLHI3AD = 13-5/8" 5M FMC ~ ÄCTUA TOR ;----'--'- I<B. E[ËV";;---"'"----~-'-'7o.5Õ" BF:-ELEV = w_-'-'---------3f KõP;-'-'"--'-'W~-"-"-~fr69' ............~~...............""'...."........~..........~....................... !v1ax ':'!]]~::w,._-"_!?~~~~ Datum MD = 13040' Datum TVD = 6700' SS S-114A I SAFETY NOTES: - - :-i 991' H TAM PORT COLLAR 1 I ~ 2323' H 4-1/2" HES X NIP, ID = 3.813" 1 110-3/4" CSG, 45.5#, L-80, ID = 9.950" 1-1 6140' ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATa; FQRf DATE 2 7496 3784 73 KBG DMY BK 0 09/30102 1 14127 6506 33 KBG RP BK 09/30/02 L Minimum ID = 3.725" @ 14258' 4-112" HES XN NIPPLE ~ I 1 14193' 1-1 4-1/2" HES X NIP, ID = 3.813" 1 :8: 'Z'-l 14213' 1-1 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 1 t . I 14237' H 4-1/2" HES X NIP, ID = 3,813" 1 I I 14258' H 4-1/2" HES XN NP, ID = 3.725" 1 14-1/2" TBG, 12.6#, L-80, ,0153 bpf, ID = 3.958" H 14269' 1 I I 14270' 1--1 4-1/2" WLEG, ID = 3.958" 1 I ELMD NOT LOGGED PERFORATION SUMIV1ARY REF LOG: ANGLEA TTOP ÆRF: f\bte: Refer to Production DB for historical perf data SIZE SPF INfER\! AL Opn/Sqz DA TE -----4 14309' H 7" MARKER JT 1 -----t 14371' H 7" MA RKER JT 1 17" CSG, 26#, L-80, ID = 6.276" H 14555' 1 ~ I 14470' H FBTD I DATE REV BY COMM:NlS 09/30/02 JLIWKK ORIGINAL COIIJPLEfION ()I\ TE REV BY COMM:NfS AURORA LNIT WELL: S-114A PERMIT No: 2021980 A R No: 50-029-21807-60 SEC. 35, T12N, R12E, 4617' NSL, 4496' WEL BP Exploratbn (Alaska) ) ') MECHANICAL INTEGRITY KEl'ORT . '... :. I G ~ E L E ;. S:::: ~ 9 (3/0 '2,-' 1 [ t:Jo(o OPER & FIELD -15 P P í3lA- wt:LL NUMEER S ~t 1 ~, /r. ~?UD DAIZ: : - . Cë.S~Dg: TD: I "--tqo.till.. ~111o 'L TVD; :?BTD: ¡ i-ft/70MI} G?1~ i TVD - /' 7 . Sho e: c.fS'SS HI) ~ -e11 TVD j DV: HD .TVD :~ t;.LL DATA ".:''Joi::g: Shoe: HI) 4 ,..1/1. " Packer J" 113 HI) TVD¡ :GP: HD :"';D :...:"':1e;:: ::ole Size anå Perfs 1'i3fi t t.f1. &~' to I t.i " ¿ 0 .' '. TVD i Set ê. t: :-:ECHANIC;'.L INTEGRITY - PART /1 Annulus Press Test: ~? ; 15 min 30 min Comments: f/tr..T ~tM'¡....tJ ",- ill:CH.ANICÞ..L INTEGRITY - PART f 2 Cement: Volumes :'. .8..mt. Liner i Csg L..J'iS ç; ,I... j DV C¡¡¡t 701 to cover peris q r, <; I(. -to c.ølv t¡¡ . ¡u...J. Theoretical Toe IllJý t ~~ ' ~ Oß P4CR~~Ç"" Cement Bond Log (Yes or No) ¡J ; In AOGCC File' -- CBL Evaluation, =one ê.DOVe perfs Prociuc.tion. Log: -rypeî~,) WFt: Evaluation 1¡.).t.11 k~ ~. . ~ SlAYtJ¡ , ç~~h.W ~j Il1.dJCA t. ~ l" .~fj A£..A t. fÞt ~ d I~~I/~.,{. CONÇLUSIONS :" . ~ , '. ?arf fl: MJ:\ ~htM\0-Å' /\.1 v,M.,lk~j~'^-- MIL. ?arc: ;2: fJtI Ìh~~ b,. Cu.v~ 'tfJlvttIAJ... p~ f p~ d. Loder'"", . \;J4Æ- i-/3/UJV-:;: . - ) WELL 5-114A DATE 3/1/2003 AFE AUD5M0049 ) JOB SCOPE NEW WELL POST DAILY WORK RST I CNL I PNL; STATIC BOTTOM HOLE PRESSURE SURVEY KEY PERSON SWS-REILL Y MIN ID 3.725" DEPTH 14410 FT ) UNIT SWS 2150 DAY SUPV LlDDELOW NIGHT SUPV TTL SIZE 4.5 " DAILY SUMMARY 'WFL & SBHTS. LOG BASE LïN.E' TÈMP FROM TT TO TD. TIE IN TO SWS SCMT LOG DATED 5 DEC'2002. LOG STATIC BOTTOM HOLE PRESSUREITEMP. DIFFICULTY FALLING BELOW 12700'. TAG TD AT14436' WORK TOOLS DOWN. LOG INJECTION PROFILE PASSES & UPFLOW WFL STATIONS (AT 14388',14350'). ****** NO UPFLOW DETECTED BEHIND CASING ******. NOTIFY PAD OP OF WELL STATUS: LEFT ON INJECTION. Init Tbg, lA, OA -> I 380 I 1200 I 0 I TIME COMMENT 08:30 ARRIVE ON LOCATION SWS 2150. SPOT EQUIPMENT. OBTAIN PERMIT TO WORK. WELL SHUT IN, FREEZE PROTECTED. .Ö9:ÕO .'RU ELINE;.'PU'2.5i' FULLBORE SPINNER - RST (UPFLOW WFL MODE) - PRESSITEMP/GRlCCL - 2.5" ROLLER - WEIGHTS - HEAD. OAL: 52.6'. MAX OD: 2.5" 10:00 SAFETY MEETING. . . , 10:20 PT LUBE 300/3000 PSI. 10:48 LOWER HEAT SOCK, OPEN SSV, RIH. 11 :10 CHECK PROPER FUNCTION OF WFL TOOL BY LOGGING WFL STATION WHILE MOVING TOOL DOWNHOLE TEST AT 60 FPM, 30 FP.M, 2.0 FF>.M, 1 OFPM, 5 FPM. .'. ,.." ".,., ."" ." " , 13:00 DIFFICULTY FALLING, WORK TOOLS DOWNHOLE. TOOLS FALLING JERKILY FROM 12700' TO 14436' (TD). 15:00 LOG BASELINE PASS DOWN FROM TUBING TAIL TO TD. TIE IN TO SWS SCMT LOG DATED 5 DEC 2002. . m .... . ..n ... .... .... .... .. 15:30 WA.IT FOR INJECTION.TO STABILI~E. Rf\TE: 7500 BFPD, 90P PSI WHP. , " 15:30 BEGIN INJECTION. INITIAL RATE (ACCORDING TO METER IN WELLHOUSE): 11700 BFPD, 1250 PSI WHP. 16:00 LOG FIRST WATERFLOW STATION AT 14388' (MINITRON DEPTH) CORRESPONDING TO TOP OF PERFS. LOG STATIONS AT FAST, NORMAL, SLOW TOOL SETTINGS. NO FLOW DETECTED. 17:0Ó . TO VE'RIF=YNÖFLOW, LOG ADDITIONAL SLOW STÄTIÒN AT 14350' (rv1lNITRON DEPTH). NO FLOW DETECTED. 17:30 LOG FLOWING PASSES ACROSS PERFS AT 60 FPM. . ..... .... ... .. 19:40 AT SURFACE, RD ELINE. WINDS PICKING UP. 21 :00 MO SWS 2150. NOTIFY PAD OP OF WELL STATUS: LEFT ON INJECTION - NEED FUSIBLE CAP!! """'Finaf"Tb'g, 'lA, OÁ -> T 120"0 I 120Ò r .., ,..." 'o.r."."" ......,...,...,...,.. ....... .. .. , , ...' , ..................,. ., ,.....", FLUID SUMMARY ') ) ,-w"l:l: - N"ttl ~- - - 005-1:1:4- - -. - - n_... - - - - -. _n - n - "_00 00- --- -- -- -- -- -- 00 --..... -- -. -- - - - - - - - - - - n -- _..~ i Date: I-Mar-2003 : :Log File WFL Start Num Flow Signal Velocity i : : :NWft&er- - -- - - De'l;ect-or- -- - - -Depth- -- -Gycl'Ð:J- - - De'l;cct'Ðà- - -'FrUl'loa'l; -- - - -- -- - - -- -- ---- --_: **TEST SHOT - FAST FLUIDS** 8 RST-Far RST-Near 3108.5 8 8 PBMS-GR 3108.5 3108.5 **TEST SHOT SLOW FLUIDS** RST-Near 9 9 RST-Far PBMS-GR 3315 3315 3315 (ft) ** TOP PERF - FAST SETTING ** 25 RST-Near 14388 14388 14388 ** TOP PERF - NORMAL SETTING ** 25 25 RST-Far PBMS-GR 14388 14388 14388 ** TOP PERF - SLOW SETTING ** 26 RST-Near 14388 ** TOP PERF - SLOW SETTING ** 26 RST-Far 14388 14388 14388 (-) 3 Yes 26 PBMS-GR 3 3 Yes Yes 26 PBMS-GR 9 9 Yes Yes 28 28 RST-Near RST-Far 9 Yes 28 PBMS-GR 9 No No No 11 No 11 11 No No 11 No 11 UnkWn 11 11 No No ** 38' ABOVE TOP PERF - SLOW SETTING ** 29 RST-Near 14350 14350 14350 12 UnkWn 12 UnkWn Velocity Error ( ft/min) ( ft/min) 29 RST-Far 12 No AtStart 48.3 28.4 29 PBMS-GR AtStart 60.3 60.5 2.4 4.3 None AtStart 5.3 5.5 0.8 0.7 None AtEnd 10.6 16.4 None None None None AtStart None None None 7.4 0.7 None None None 7.2 0.7 None 17.9 1.5 None RST WFL Station Summary Log File WFL Start Stop Flow Velocity Velocity Number Detector Depth Depth Detected Error (ft) (ft) (ftllnin) (ftllnin) 029 PBMS-GR 14350,0 14335.0 No Data Acquired on: O1-h4ar -2003 16: 10 Detector is above Minilron (sensitive to Up Flow) \oWL Slbcycle Trne: 10.00 see On - 90,67 see O1f to.._Lo..........4\1f.e1 ""._1_."'" 01-Mar-200316:3' DEFAULT FCS_RST_PSP _034L'"""') FN:32 PRODUCER 01-Mar' .')317:24 14453.5 FT Output DllS Files 14197.0 FT DEFAULT FCS_RST_PSP_055PUP FN:48 PRODUCER 01-Mar-200318:10 DEFAULT Flip_FCS_RST _PSP _040LUP Input DllS Files PRODUCER 01-Mar-200317:55 14450.0 FT 14114.5 FT DEFAULT FCS_RST_PSP_047PUP Output DllS Files FN:40 PRODUCER 01-Mar-200318:04 14452.0 FT 14081.5 FT OP System Version: 11CO-305 MCM PFCS-A PSPT -AlB 11 CO-305 11 CO-305 RST -C 11 CO-305 PIP SUMMARY ::JI Time Mark Every 60 S - - - WeB. TeQ:!Peratu.!!! .lWTEP)- - - 40 (DEGF) 240 - -piff!!ential Te1!1l!!rat!:!!~WTG~ - -0.5 (DF/F) 0 0 Gamma Ray (GR) (GAPI) Tension (TENS) . - - - - -- - - - - - - - - - - - - - - - - - - - - - - - ~_~Il_~!~~_~~!~- (~I?~~-- -- - - - -- - - - - -. - -- - - - - - - - - - - -. 100 (LBF) 0 (PSIA) 4 3000 0 OPEN - - - - - - - - - - _We!lTe".!J?eratu!! ~TEf)- - - - - - - - - -- 1 PERFS 140 (DEGF) 1 -19 Computed CCL (CCLC) (V) - - Cable Speed (CVEL) - - Filtered Main Spinner (SPIN) -200 (F/MN) 200 0 (RPS) . . I I I I I I I I I I I 141CO I I I I I I I I i I I I }- ~ I I I l-I I f 1 t? \, J ,. \ ( } ~ 10. - \ > , I 1 : ) t 1 : ~ I ! ~ I' ; : ~ ; I I ,1 i 1...- ~ì '., ¡ ~~ .~ \ ~ . I l-~ -: I-->f ~ c: ! J. : / p~ ~ ~ t ~ ~ J...- T j. ! t ! <-~ i ~, ~ ')--. ¡ ---- ~ ¡ ¡~ I ¡ I I ¡ ! , I I I I I) I J <"'""I I ) I I 1 1 ) 14200 !'o ". ~ . t , ~ i - ~ ~ ¿ ~ t 1430) I I ! I I I I I I I i I I I I f J I -, I V\.TE~ ~ I 1 I I I I I I I \ I I I ~ ~ $ 1. " It ~ 1 t t 1 1 1 ~ . 1 1 , 1 \ , , \0 .. \ \ \ \ \ , ., .. \ \ \ \ , , \ \ \ \ \ \ \ \ - 1 I \ 1 . 1 ! , 1 1 \ 1 , ': I 1 , \ \ \ Ij ,~~ w-rr \ 1 , i ~ , 1 \ I . I . C \ j { t f I . ,; I It I . .. II \ , \ \ I . } ~ I '\ \ } ) ( } I \ , , ~ , I ... . j I . . . I I .- ; j 1 I 1 . It , . It I I ( ~ I I . ,; r I .. . , J ') \ ( I ) ) ) \ ) ( -' f( ~' .~ , . . ) I I I . l I . ; f J . I ., '~ ~ )' ~ t I I{ (, : \ J , W-GR~~'1 - I~~ ~ l, VfP.HE .~..~ ) 1 ~ J : j ~, , " ,. J \ S~~~ 1 \( If " ~ ~ ~1 I' I t J~ i . ~ I C1~: ) It' . I ! c '~ I I I ~ I i C-+l C~ - 1 X -; I/' i ~ IiI f ) f f I ! I ~ '. 1 1 j ¿i/:- : /~ l I: : I: : II I II I I I I: ¡ : II \ I nil - - Cable Speed (CVEq ~ ~ Filtered Main Spinner (SPIN) ~200 (F/M!\!) 200_0 (RPS) Computed CCL (CCLC) OPEN - - - - - - - - - - _Weu..Te"'!peratu!! ~TEf)- - - - - - - - - -- (V) 1 PERFS 140 (DEGF) 1 ) ~ II) ) I 1 1 1 1440: ~' ,"I"'¡ ~." 9 ,,~ j i ¡ I I ~ / 1 , ì : ~ I f : I . I ¡ø ...-.íi' ~ '......, \ t \ \ 1 , . ~ 1 -19 ." ~, ,J t! \~ I I , f : i ~(~ \ ~ I . .;. I, 4 ~' . l ¡ ~ t / ". ~. ~ ""'- ~......... , ',-- 0 Gamma Ray (GR) (GAPI) Tension (TENS) -- n - n n n - n n - n n - -- - n n _.w_t!IJ.~!~~_~Y!~- (~~.R~)-- -- n - - - n - -- -- n - - n -- -- -- ~. 100 (LBF) 0 (PSIA) 4 3000 0 - - - We.!!. Tc'!!})crature .LwTcrL - - 40 (DEGF) 240 - -piff£!ootial Tern~at!!r~WTGr:!l- -O.S (DF/F) 0 PIP SUMMARY ~ Time Mark Every 60 S Parameters DllS Name Description Value PFCS-A: PSP Flow and caliper Tool Spinner Filter Averaging Mode Spinner Depth Constant Filter Main Spinner Flowmeter Sonde System and Miscellaneous DO Depth Offset for Playback PP Playback Processing Format: FULL_PL 1 Vertical Scale: S" per 100' AMOD SDCF SPIN LINEAR AVERAGE - 6 PFCS-A_3.S 2.0 FT NORMAL Graphics File Created: 01-Mar-200318:04 OP System Version: 11 CO-305 MCM PFCS-A PSPT-AIB RST -c 11 CO-30S 11 CO-30S 11 CO-30S ') Input DllS Files ) DEFAULT Flip_FCS_RST _PSP _040LUP PRODUCER 01-Mar-200317:55 14450.0 FT 14114.5 FT DEFAULT FCS_RST_PSP_047PUP Output DllS Files FN:40 PRODUCER 01-Mar-200318:04 PlQl Data Manager Files Pass # 1 Pass # 2 DEFAULT FCS_RST_PSP_065PUP Output DllS Files FN:58 PRODUCER 01-Mar-200319:41 14450.0 FT 14234.0 FT OP System Version: 11CO-305 MCM PFCS-A P~PT -AIR 11 CO-305 11 CO-~05 RST -C 11 CO-305 INJECTING TEMP PASS, 60 FPM DOWN - - - - - - æ02TM~ - - - - -- 60 (DEGF) 160 BASELINE TEMP PASS, 60 FPM DOWN (P01TMP) (DEGF) 60 160 -19 CCl [01] (P01CCL) (V) ~ BASELINE TEMP PASS, 60 FPM DOWN (P01TMP) 100_140 (DEGF) 1 OPEN - - - - - _INJECTIN~TEMP .fASS, 60 £.PM DOWN jf02TMf) - - - - - - 1 PERFS 140 (DEGF) 1 I I I I ! I I I I I I I I I ! l r 0 Gamma-Ray [01] (P01LGR) (GAPI) > I I ! i l I I ¡ ! I I ! I I I I I I I i ~ ! I I I I I i I I I J/ 1 If I I ¡ I I I I I I I CCl [01] (P01CCl) OPEN ~) 1 PERFS Gamma-Ray [01] (P01 lGR) ~ 0 (GAPI) 100_140 BASELINE TEMP PASS, 60 FPM DOWN (P01TMP) (DEGF) > '{ -19 60 -1 ) , I 14300 r:-;"'ç ~ ) ) ~ ! ) t\j~\r , -t~ \~ 1440C 160 INJECTING TEMP PASS, 60 FPM DOWN - - - - - - æ02TM~ - - - - -- 60 (DEGF) 160 \ I ,~ J I, ! I I ¡ , ! \ ! I I i I I 4 t j. I f i i I 1 I I ! ) :1 i t I' I I I r. I I. it 11- J I' I I -_____INJECTIN~TEMPE~S,60FMDOWN~02TMB_____- 140 (DEGF) 1 BASELINE TEMP PASS, 60 FPM DOWN (P01TMP) (DEGF) 1 ') Description ') Parameters DLIS Name CSID CSID CSID CSID CCLS FCHD PCVS PGRS PGS PWHS RHOS SPIS TMPS DO PP Value PFCS-A: PSP Flow and caliper Tool Casing Size I.D. RST -C: Reservoir Saturation Pro Tool C Casing Size I.D. PSPT -AlB: Production Services Logging Platform Casing Size I.D. BORDYN: BorDyn (Well Test Validation) Casing Size I.D. PLQL: Production Logging Quick Look CCL Selector Cased Hole Diameter Selector CVEL Selector GR Selector Pressure Gauge Selector PLQL Water HoldUp Selector Fluid Density Selector Spinner Selector Temperature Selector System and Miscellaneous Depth Offset for Playback Playback ProcessinQ venlcal :icale: ~.. per' uu' 6.5 IN 6.5 IN 6.5 IN 6.5 IN CCLC PFC1 CVEL GR WPRE NONE WFDE SPIN WTEP -1.0 FT NORMAL I"'ormat: I"'tS:)_ut' _UVt:KLAY_' PFCS-A PSPT-AlB DEFAULT \:irapmcs I"'lIe \;reatea: U'-Mar-~uu~ '~:4' OP System Version: 11CO-305 MCM 11 CO-305 11 CO-305 RST -C 11 CO-305 FCS_RST_PSP_065PUP Output DLIS Files FN:58 PRODUCER 01-Mar-200319:41 PLQL Data Manager Files Pass # 1: DUS #31, 60 FPM DOWN, INJECTING 7500 BPD, 900 PSI WHP Pass # 2: DUS #32, 60 FPM UP, INJECTING 7500 BPD, 900 PSI WHP PFCS-A 11 CO-305 PSPT -AlB 11 CO-305 Gamma-Ray [01] (P01 LGR) (GAPI) CCL [01] (P01CCL) DEFAULT 0 FCS_RST_PSP_057PUP Output DLIS Files FN:50 PRODUCER 01-Mar-200318:13 14440.5 FT 14234.5 FT OP System Version: 11CO-305 MCM RST -c 11 CO-305 100 .19 (V) 1- -)... , ~~~!-_~ -~~~gl?- ~~/[~-I;!~~~J~.'!! fïi1liii1.:;¡õ - on. no. - on on.. - _~~l!'!.~.~~. ?.!I.t.fl~fw!'!. i!:'!1 ~~!~L on.. -. -- --.-..on -. -- CA~lE SPEED 80 EPM j¿~(P02CVll. OPEN - -- -- -- -- -- -- -- -- ~PINNER"'?QJ=PI\!. UP jf02SPIN)-- -- -- -- -- -- -- -- -- - 0 (F/MN) -200 PERFS 40 (RPS) I I 1 I r I I i I I '1 I 1 ; 1 1 i I J i j I , I ì i ) I I I , ~ j 1 \ ~ ~ ¡ . t t -r ~ J , I i ! I i ~ ~ I < ~ ~ ... s f; ( ( I \II ~. ~ I III , . t I C ,~ \ \ J t I J . 14300 . i ¡ 1 . ~ q . . , ~ . , r ' i . , \ ~ . ~ l CS ~ è J . . ~ i , I l I i I 1 J , ~L ~ - -,. r \'ð \~)~lß \~ i . ,¡ I I I . 11 " I i I / " , . , ~ .., ",; , " .. '. ~ i I ... to to . \. .. 1440C <) .. , ~ ~ ') ~ -¡ . \ ~ "¡¡ . ) I ,,/" , )J ç ~ i ,;! _CABLE SP§..ED 80 £PM J:!~j~2CVLl. OPEN - - - - - - - - - _SPINNER.JìQ..FP~ UP ,{f02SPIN)- - - - - - - - - - ;~!-.s .~~~~!.>.;~~~ .I?~Y!!~ ![,.C!~~= :Õ"'."'.."''''.. ...I?[,)~t:i.~~. ~9. f..;;~~!H!:q1!>.~!t:iL............. --.~... CCl [01] (P01CCL) (V) -19 0 1 Gamma-Ray [01] (P01LGR) (GAPI) 100 Parameters DLIS Name PFCS-A: PSP Flow and caliper Tool Casing Size I.D. RST-C: Reservoir Saturation Pro Tool C Casing Size I.D. PSPT -AlB: Production Services Logging Platform Casing Size I.D. BORDYN: BorDyn (Well Test Validation) Casing Size I.D. PLQL: Production Logging Quick Look CCL Selector Cased Hole Diameter Selector CVEL Selector GR Selector Pressure Gauge Selector PLQL Water HoldUp Selector Fluid Density Selector Spinner Selector Temperature Selector System and Miscellaneous DO Depth Offset for Playback PP Playback Processing Format: UP _DOWN_80 Vertical Scale: 5" per 100' CSID CSID CSID CSID CCLS FCHD PCVS PGRS PGS PWHS RHOS SPIS TMPS PFCS-A PSPT-AlB DEFAULT Description Value 6.5 IN 6.5 IN 6.5 IN 6.5 IN CCLC PFC1 CVEL GR WPRE NONE WFDE SPIN WTEP -1.0 FT NORMAL Graphics File Created: 01-Mar-2003 18:13 OP System Version: 11CO-305 MCM 11 CO-305 11 CO-305 RST -C 11 CO-305 FCS_RST_PSP_057PUP Output DLIS Files FN:50 PRODUCER 01-Mar-200318:13 RST UPFLOW WATERFLOW LOG with PRESSITEMP/SPINNER 1 March 2003 ) ) ~V~uŒ [ill Æ\ @ WI. ff}\ Lnj cQ) U\.l iFU TONY KNOWLES, GOVERNOR AI,A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. "]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit S-114A BP Exploration (Alaska), Inc. Pennit No: 202-198 Surface Location: 4617' NSL, 4496' WEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 4464' NSL, 4711' WEL, Sec. 28, T12N, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to redrill the above development well. . The pennit does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit 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 witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~()~1v>t' J~Q¡ c~echsli Taylor I}- Chair BY ORDER OF THE COMMISSION DATED thisfl::fh. day of September, 2002 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4617' NSL, 4496' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 4328' NSL, 4533' WEL, SEC. 28, T12N, R12E, UM At total depth 4464' NSL, 4711' WEL, SEC. 28, T12N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028256, 816' MD 5-106 is 14' away at 425' MD 16. To be completed for deviated wells Kick Off Depth 12300' M D Maximum Hole Angle 18. Casin9 Program Specifications Size CasinQ Weight Grade CouDlinQ 7" 26# L-80 BTC-M '\ STATE OF ALASKA "\ ALASKA-_;L AND GAS CONSERVATION COMMI~&ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 70.5' Prudhoe Bay Field I Aurora 6. Property Designation Pool (Undefined) ADL 028258 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / S-114A 9. Approximate spud date 09/18/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14940' MD 17205' TVD 0 17. Anticipated pressure {se;.20 AAC 25.035 (e) (2)} 74 Maximum surface 2925 '"psig, At total depth (TVD) 7000' I 3625 psig Setting Depth Top Botom Quantitv of Cement LenÇlth MD TVD MD TVD (include staae data) 14940' Surface Surface 14940' 7205' 553 sx Class 'G' 1t.J6 A- f-l/I'l/O ~ ~ ~(Ft/~).,.- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 , Hole 9-7/8" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing' 15603 feet 6860 feet NI A feet NI A feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 115' 6105' 20" 10-3/4" 260 sx Arctic Set (Approx.) 951 sx Arcticset Lite III, 720 sx 'G' 115' 6139' 115' 3370' t,~ I£¡~~'Ã'J Perforation depth: measured None Öt true vertical None 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Wa e1 Quay, 564-4178 21. 's~:~:d ~~~;: th~¡~~?~!~~¡:~:J~~~;~:f:7.i¡i=i;:;~;;%I$f#l~~*hf';;H~~t;¡~*%¡~~,f~~,;~l..- Permit Number ~ð API Number Appr.Qval D?te See cover letter ::2-D 2 - II 0 50- 029-23116-01 . L.f II q IÓ~ for other reQuirements Conditions of Approval: Samples Required 0 Yes Ø"No Mud Log Required 0 Yes 6(No Hydrogen Sulfide Measures 0 Yes -I2fNo Directional Survey Required ~Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Oth.er: ,- ~ f: , Bo PEl<> 4~1!)() f~ Ii' . onglOa'I &.gnad by Approved By Cammy OechsJi T aylo1 0" f), ~ ("",~ r~,! , ",ri:~s, i~ner Form 10-401 Rev. 12-01-85 , r\ 1lJ i ¡ \1/=\ L Prepared By NamelNumber: Sondra Stewman, 564-4750 by order of the commission Date qllqlb~ Submit In Triplicate bp ') ) To: Winton Aubert - AOGCC Date: September 17, 2002 From: Walter Quay - BPXA GPB Drilling & Wells Subject: Reference: S-114A - Perm it to Drill Open Hole Sidetrack Operations on Current Well S-114 API # 50-029-23116 Dear Mr. Aubert, As you are aware, Aurora Well S-114 (Permit #202-175) was drilled as planned to the proposed target, however will not be completed due to encountering gas in the reservoir at that location~ The well penetrated the Kuparuk reservoir approximately -90' high and LWD logs showed signs of gas in the- reservoir. Plans are to plug back and sidetrack to a Kuparuk target approximately 1200' to the south west ------ of the current penetration. Below is an outline of the proposed plug back and sidetrack operations. Also enclosed is a schematic of the existing wellbore with proposed plug-back and proposed completion. If you have any questions or require any additional information, please contact me at 564-4178. Scope RiQ ODerations: 1. RIH to TD at 15,603' MD with 5" DP cement stinger. Circulate and condition well for cementing operations. Spot a balanced 15.8 ppg cement P&A plug from TD to +/-14,950' MD (-450' above the ~ Top Kuparuk Reservoir). Plug volume should be based upon an equivalent hole diameter of 10.4" throughout this section (70 bbls total). Pull above cement plug and circulate DP clean. 2. Spot a 11.08 ppg heavy mud spacer from top of cement P&A plug at -14,950' MD to -12,050' MD. Pull DP up to 12,800' MD and circulate out any excess heavy mud spacer above this point. 3. Spot a 10.7 ppg Form-A-Plug pill (cross-linked polymer pill) from 12,800' to -12,600' MD to act as a base for the upcoming cement kick-off plug. Pull DP above top of plug and circulate any excess pill out of DP. Pull to shoe and wait on Form-A-Plug to set (-6 hrs). 4. RIH to -12,300' and wash down looking for top of plug. Once top of plug is verified, condition mud as required for spotting the cement kick-off plug. . ../ 5. Spot a 15.8 ppg cement kick-off plug from 12,600' to 12,200' MD (estimated depths). Plug volume should be based upon an equivalent hole diameter of 11.5" throughout this section (51 bbls total). Pull DP above plug and circulate DP clean. POOH. 6. PU 9-7/8" drilling assembly and RIH. Dress top of cement as required. Planned kick-off point is at , -12,300' MD, however will kick-off soon if plug allows. Kick-off and drill the 9-7/8" hole section as per directional plan to TD @ :1:14,940' MD (7205' TVD). POOH. f" /' 7. Run and cement the 7"/26# production casing as required to cover all significant hydrocarbon intervals (no significant hydrocarbons were seen in the Ugnu or West Sak intervals and therefore, plans are to bring cement -1200' above top Kuparuk formation only). Displace the 7" casing with seawater during cementing operations. Once cement has had adequate time to set, freeze protect the 7" x 10-3/4" annulus as required. 8. RU slick-line and rl¿n gauge ring / junk basket to PBTD. 9. Run a 4-1/2",12.6#, L-80 TC-II completion and space-out tubing tail -50' MD above top Kuparuk. S-114A Permit to Drill ') ) 10. RU slick-line. RIH with standing valve and set in 'XN' nipple below packer. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes:-Shear open RP valve in bottom GLM. - 11. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 12. Freeze protect the well to -2400'. Secure the well. Rig down and move off. Post-Ria Work: 1. RU e-line - Run Cement Evaluation log. 2. Perforate the Kuparuk interval, using bottom most GLM to circulate guns down as required. 3. Fracture stimulate Kuparuk and clean as required. 4. Pull RP shear valve from bottom GLM and install dummy valve. I Well Name: I S-114A Drill and Complete Summary I Type of Redrill (producer or injector): I Pre Produced Injector Surface Location: Target Location: Bottom Hole Location: x = 618,929.73 / Y = 5,980,820.17 6631 FNL 7841 FWL 835 T12N R12E x = 608,249 / Y = 5,985,650 951' FNL 746' FWL 828 T12N R12E x = 608,068 / Y = 5,985,783 816' FNL 568' FWL 828 T12N R12E I AFE Number: 1 AUD5M0045 I l Estimated Start Date: I 09/18/02 1 I MD: 114,940' I I TVD: 17205' 1 Umiat Umiat Umiat I RiQ: I Doyon 14 I OperatinQ days to complete: 19.0 /' I Cellar Elevation: 136.2' I 1 RKB: 170.5' I Well DesiQn (conventional, slimhole, etc.): I 81imhole 1 Objective: I Kuparuk Injection well in the Aurora Development Formation Markers Formation Tops Base Gubik SV6 Base Permafrost SV5 SV4 SV3 SV2 SV1 10-3/4" Csg Point Ugnu - UG4 Ugnu - UG4A Ugnu - UG3 MD 400' 1760' 2148' 2635 3066 4273 4925 5821 6140' 6771 6876 7786' TVD (not ss) 400' 1658' 1929' 2249 2431 2788 2975 3262 3370' 3570 3600 3870 Comments -8.6 ppg EMW -8.6 ppg EMW -8.6 ppg EMW -8.6 ppg EMW -8.6 ppg EMW -8.6 ppg EMW (possible hydrates) -8.6 ppg EMW (possible hydrates) -8.6 ppg EMW (possible hydrates) -8.7 ppg EMW -8.7 ppg EMW -8.7 ppg EMW S-114A Permit to Drill Schrader Ma 10,138' 4627' Schrader N Sands 10,923' 4846' Schrader 0 Sands 11,284' 4955' Colville - CM3 12,017' 5197' Top HRZ 14,214' 6560' TKLB 14,420' 6741 ' TKUP 14,442' 6760' Top Kuparuk A 14,757' 7040' Top Miluveach 14,840' 7115' . TO - 7" Csg Point 14,940' 7205' TD Criteria: Based upon 150' MO of rat-hole beyond Top Miluveach. CasinglTubing Program Hole Size Csgl WtlFt Grade Tbg O.D. 20" 10-3/4" 7" / 4112" ) 30" 13-1/2" 9-7/8" Tubing 91.51 # H-40 45.5# L-80 26# L -80 12.6# L-80 Directional KOP: 112,300 MO Maximum Hole Angle: Close Approach Well: ") -9.0 ppg EMW (possible hydrocarbon bearing) -9.0 ppg EMW (possible hydrocarbon bearing) -9.0 ppg EMW (possible hydrocarbon bearing) -9.9 ppg required for good hole stability ,0 .\ -8.6 ppg EMW (hydrocarbon bearing) -9.8 ppg EMW (hydrocarbon bearing) Conn Length Top MDITVD GL GL GL GL Btm MDITVD -115' / 115' 6152' /3381' 14,940' /7205' 14,4 70' /6690' Welded BTC BTC-M TC-II -80' 6140' -14,940' -14,870' -740 over interval from 3600' All wells pass BP Close Approach guidelines. With respect to allowable deviation, the nearest close approach well is S-106. The well is -14' well-to- well at -425', which allows for only 4.4' of deviation from the proposed directional plan (toward the subject well). IFR & Multi-Shot corrected MWO Surveys KIP to TO. Survey Program: Mud Program 13-1/2" Surface Hole I Extended Bentonite Spud Mud From Surface to -100' TVO below top SV1 Interval Density Viscosity VP Tauo pH API (ppg) (seconds) (lb/1001t2) Fluid Loss Initial 8.5-8.6 >300 50-70 >15 8.5 - 9.5 15-20 Base Perm 9.6 200-250 30-50 >10 8.5 - 9.5 <10 Interval TO 9.6 150 25-40 >10 8.5 - 9.5 <8 9-7/8" Intermediate 1 Production Hole I LSND From Surface Casing Shoe to TO -150' MO into Miluveach Interval Density PV YP MBT pH API (ppg) Fluid Loss Initial 9.3 - 9.4 6-8 22-28 <15 8.5 - 9.5 6-8 Ugnu & Schrader 9.5 8-12 22-28 <15 8.5 - 9.5 6-8 Colville 9.6 8-12 22-28 <15 8.5 - 9.5 6-8 HRZ 10.1 8-14 20-24 <15 8.5 - 9.5 4-6 Kuparuk 10.1 / 8-14 20-24 <15 8.5 - 9.5 4-6 S-114A Permit to Drill ) ) Integrity Testing: Test Point Surface Casing Shoe Depth Test Type 20' of new hole below shoe LOT EMW LOT - Require minimum of 12.1 ppg to achieve -51 bbl kick tolerance Logging Program 9-7/8" Inter / Prod: Drilling: Open Hole: Cased Hole: BHA run - MWD / GR / Res / Den / Neu / PWD - All Real-time None No cased hole logs are planned with the rig on location. Cement Program *See Attached Dowell Cement Program for Details on Cement Formulation* Casing Size 19-7/8" Intermediate / Production I Basis: Lead: None Tail: Based on 1868' of open hole (-1300' MD above top Kuparuk formation) with 300/0 excess + 82' shoe track volume. Tail TOC: -1300' MD above top Kuparuk at 14,168' MD (5898' TVD). Fluid Sequence & Volumes: Pre None Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None 118 bbls / 663 fe / 553 sks of Dowell Premium Latex 'G' with expansive additive at 15.8 ppg and 1.2 cf/sk, BHST 165° / BHCT 125°, TT = 1.5 hrs to Batch Mix + 3.5 hrs *See Attached Dowell Cement Program for Details on Cement Formulation* S-114A Permit to Drill ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOP / equipment will be tested to 4000 psi to accommodate the planned casing test of 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. . Production Section- Maximum anticipated BHP: 2200 psi @ 4600' TVOss - Schrader Bluff Maximum surface pressure: 1740 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . . Maximum anticipated BHP: 3625 psi @ 7000' TVOss -'Kuparuk Maximum surface pressure: 2925 p'si @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . . Planned BOP test pressure: Planned completion fluid: 4000 psi (the casing will be tested to 4000 psi) Estimated 8.5 ppg Seawater /6.8 ppg ~iesel . . Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. ..., . . S-114A Permit to Drill -) ) 8-114 Proposed Plug-Back TREE: 4-1/16" - 5M Carbon WELLHEAD: 13 5/8" - 5M FMC SH Cellar Elevation = 36.20' Doyon 14 RKB = 70.5' 10-3/4",45.5 #/ft, L-80, BTC j 16140' I ~ I Base West Sac/Fault/-Top Colville Shale at -12,017' MD Top of 15.8 ppg Kick-off Plug at I 12,200' I Planned KOP from 12,200' to 12,350' MD , 15.8 ppg Cement : Kick-off Plug' 10.7 ppg Form-A-Plug Cement Base Top of Form-A-Plug pill at I 12,600' I Top of 11.0 ppg Mud Spacer at I 12,800' I ;¡:þ~~Å;,t~~~~t¡'jl ,; 15.8 ppg Cement P&A Plug Top of 15.8 ppg P&A Plug at I 14,950' I / Top Kuparuk Reservoir at I 15,400' I TD of 9-7/8" hole 115,603' 1 '" Date 9/17102 Rev By WDa Comments Aurora WELL: 5-114 API NO: 50-029-23116-01 Proposed Plug Back for Sidetrack Operations BP Alaska Drilling & Wells _°')- °) 5-114 Proposed Completion TREE: 4-1/16" - 5M Carbon WELLHEAD: 13 5/8" - 5M FMC SH 4-1/2" tubing hanger Cellar Elevation = 36.2' Doyon 14 RKB = 70.5' I I I 2350' I 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 12.6# L-80 TC-II Tubing 10-3/4",45.5 #Ift, L-80, BTC j I 6140' I ~ L 4-1/2" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS TVD Size # 2 1 3800' 6500' 1" 1" Valve Type DV RP Shear L /' 4-1/2" X Landing Nipple with 3.813" seal bore, 7" x 4-1/2" Baker '$-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go 10. 4-1/2" WireLine Entry Guide spaced-out -50' MD above the top Kuparuk. Plug Back Depth I 14,850' I 7", 26 #/ft, L80, BTC-Mod 114,940' 1 ~ ~ Date 8/27/02 9/17/02 Rev By WSI WDa Comments Aurora WELL: 5-114 API NO: 50-029-????? Proposed Completion Proposed Completion BP Alaska Drilling & Wells SF3E!J""1r""Y-SUf1 North Slope Alaska Q1i!k.I.d1JLO"""S äF'nil~ BPXA A HOlljb,,(j'm Col1'p."Y ~~~4:~~;1 Pad DrillQuesl" Proposal Data for $-114A WP01 Scale: 1 inch = 500ft -11250 I -10750 I Eastings (Well) -1 0250 I -9750 I -9250 I ~~~~g~t~{igi~g:ln : Measurement Units: North Reference: Well Well It True North Dogleg severity: ~~,~~to per 100 feet (US) Vertical Section Azimuth: Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Northlngs Eastings Vertical Dogleg Depth Depth Section Rate 12300,00 70.976 291.166 5289,66 4226.51 N 9343.59 W 10156.47 13387,13 41.032 307.216 5893,27 4639.08 N 10128.27 W 11040.20 3.000 13483.51 41.032 307.216 5965,97 4677.34 N 10178.66 W III 03.24 0.000 14214,55 29.701 307.195 6561.14 4932.80 N 10515.11 W 11524.13 1.550 14442.17 28.<X)O 307.210 6760.50 4999.20 N 10602.59 W 11633.55 0.747 14790.50 26.258 307.210 7070.50 5095,25 N 10729,09 W 11791.80 0.500 14940.50 25.508 301.210 7205.45 5134.85 N 10781.24 W 11857.04 0.500 Total Depth: 14940.50ftMD,7205.45ftTVD 5500 - '~~ 7" Casing "'( Î;';,'.,g}':~,"i? 14940,50ft MD . '(~;¡ "'-. 7205.45ft TVD ~ """""""""""""~"",,, > ''''', (. """"'~~'" > ~~::..."J ~'7 7." ""~ '4 1J..,o. ""..z:;"'! "07 '~ nd Dir, Start Sail @ 41.032°: 13387.13ftMD,5893.27ftTVD ~"N ~", 500,00 - 5250 .¿::.::::::...~" 200Ð;00-'"'' - ".. .......,..,..."" - "" .-..--... ..,.. - ...-..,-- .... Top Colville SHtstOM, 5270.5fitl TIIO " , ST KOP: Dlr @ 3.0000/lOOft, 160.32 Right TF : 12300.00ft MD, 5289.66ft TVD - - 4750 :p .: "o...,........~ "'~ ST KOP: Dir @ 3.0000/100ft, 160.32 ight TF: 12300.00ft MD, 5289.66ft TVD ..... : ~ C> c: :.c 1:: 0 Z - 4250 .1= 0 0 1.0 II .c () .5 ::: 6000 - End Dir, Start Sail @ 41.0320 : 13387.13ftMD,5893.27ftTVD ~ Begin Dlr @ 1.5500/100ft : 13483.51ft M D, 5965.97ft TVD -- -------------....--- (¡j - 3750 (ij () en .c ..... c. () 0 ~ 6500 :e () > ------------------------------ - - THRZ,¿5.$.()~l.\!P- - - - - - -- --- Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: Current Well Properties S-114A WP01 5980820.17 N, 618929.73 E 52.14 S, 1012.31 E 70° 21' 22,5075" N, 149° 02' 02.8406" W '~ ------------------ Decrease In Dlr Rate @ 0.7500/100ft: 14214.55ft MD, 6561.14ftTVD S.'1'I4A T1 DrìH~r'$ POly @ 8S%MWD+!FR+MS", - oollß~S2fl.lV!L........ - - - - - - - - - - '11WP. S7Gõ.5õ1t~ - - - - - - - - - RKB Elevation: 70.50ft above Mean Sea Level 70.50ft above Structure Reference True North Feet (US) ------------------ - - - - - - ~'~1;À-:;;;;6;5;ft TVO, 4;;1;;;-6;,70 Wd'-''-'-'-W?? - - - ~r~~ ~R~e_@~/!p~t ~.!!~ M~O..:?,!!y£"'" -- .1= 7000 - 0 0 1.0 II J:: () .5 - - LCU, 622~()~ - - - - - - - - - North Reference: ~ 4700,00 Units: --------------------- p -_~¡>.:aru.k.A 7!)4iJ5£ft.lV.£..........._----- ~ - - - - - - - - - -- - - - - -- - - - - ~ __TM.!.Y: ~it..J'{g- - - - - -- }~ ;~~:~~~ft MD 7205.45ft TVD ,iii., Total Depth: 14940.50ftMD,7205.45ftTVD 'J,: "~ :.< I' . /:~; .' (¡j (ij ~ 7500 - " ., ~. I I 10000 10500 Scale: 1 inch = 500ft I 11 000 I 11500 I I 12000 12500 Section Azimuth: 302.290° (True North) ;: , f.~.. t.f' Vertical Section (Well) ""_11''''..__.. "" ^" ",... ,.,,.,,, SPer"i'Y-5UI1 North Slope Alaska ;!B,&,- ...fr\fij~:~:$:m:vœ:Ë:S B P XA A H.mb<lrtl>" Comp."y PBU_WOA S Pad DrillQuest* S-114A WP01 : ~ :"):"~::. . ,"1 ." ~.:.o- .*4 4 " . . f .~ - .' Single Well Target Data for S-114A WP01 Measurement Units: ft Coordinate Target Point TVD Northings Eastings SSTVD Northings Eastings Name Type ASPY ASP X S-114A Tl Entry Point 6760.50 4999.20 N 10602.59 W 6690.00 5985650.41 N 608249.11 E Driller's Poly @ 85% 6760.50 4990.52 N 6690.00 5985642.92 N 608324.09 E MWD+IFR+MS Boundary Point A 10527.74 W B 6760.50 4977.99 N 10515.67 W 6690.00 5985630.58 N 608336.36 E C 6760.50 4961.07 N 10512.08 W 6690.00 5985613.72 N 608340.21 E D 6760.50 4943.38 N 10514.75 W 6690.00 5985595.99 N 608337.83 E E 6760.50 4926.76 N 10520.39 W 6690.00 5985579.28 N 608332.45 E F 6760.50 4912.91 N 10528.40 W 6690.00 5985565.31 N 608324.66 E G 6760.50 4905.30 N 10539.66 W 6690.00 5985557.52 N 608313.52 E H 6760.50 4908.47 N 10554.53 W 6690.00 5985560.45 N 608298.60 E I 6760.50 4971.04 N 10675.29 W 6690.00 5985621.10 N 608176.87 E J 6760.50 4985.85 N 10691.95 W 6690.00 5985635.64 N 608159.97 E K 6760.50 5005.12 N 10692.18 W 6690.00 5985654.91 N 608159.44 E L 6760.50 5025.00 N 10686.40 W 6690.00 5985674.88 N 608164.90 E M 6760.50 5044.23 N 10678.09 W 6690.00 5985694.24 N 608172.90 E N 6760.50 5061.57 N 10668.10 W 6690.00 5985711.73 N 608182.62 E 0 6760.50 5074.04 N 10656.00 W 6690.00 5985724.39 N 608194.52 E P 6760.50 5072.32 N 10639.63 W 6690.00 5985722.93 N 608210.91 E Q 6760.50 5062.34 N 10625.17 W 6690.00 5985713.18 N 608225.53 E S-114A Tl Entry Point 6760.50 4998.77 N 10601.70 W 6690.00 5985650.00 N 608250.00 E Geo Poly Boundary Point A 6760.50 6690.00 5985830.00 N 5179.55 N 10648.84 W 608200.00 E B 6760.50 5048.59 N 10463.90 W 6690.00 5985702.00 N 608387.00 E C 6760.50 4795.64 N 10531.92 W 6690.00 5985448.00 N 608323.00 E D 6760.50 4921.32 N 10762.95 W 6690.00 5985570.00 N 608090.00 E r"\RIIII"'\"R"& t'\....", ",... n"'" ..,,-,1 Target Shape Polygon ,~ Polygon Speri )-Sun Drilling Se.)ices Proposal Data - S-114A WPS - S-114A WP01 001 = 6.3 Draft Copy MD Delta Inclin. Azimuth rvD Delta Northings Eastings Dogleg A. Build A. Tum Toolface VS (c295°) (ft) ,MD (ft) (°) (°) (ft) TVD (ft) (ft) (ft) (0/100ft) (°/1000) (°/1000) (°) (ft) .., .. ......, .., ...,.. ...... ......" ..... .., ................. ""'''''t''''''' """""""'.." '. ..... ,..... .., ,'..... ,.. .' .. """'''''''''''''''''''''''''.'''''Y'.'''''''''''''' ..... ...... '.......... ., , , " "...'" , ,....... ".. , ,.. ... .." "."" ,.,..... ".. .... , , , -1 : 12300.00 70.98; 291.17 5289.66 4226.51 N: 9343.59 W: : .':"! 1 0253.1 '"''~'''''''''''''''''''-'''~~'''''''-'"-'''U'~---~'~b''''''''"''"'''''''''''''''''...,.', ~.,.."..__._-_............,¡.-~-~~~u¥...._............ ........ ....................~.".-"""""" ",......," .-..." ".."........"..................._'¡'_.~..__.~~~~_...~...... ...... .........................,..._._~~.~..~..._.....~~~.~".,~.._....""'¡'.............................""'''''''''¡'''~~--'''''''"' ¡ 2' : 13387.13 1087.13 41.03; 307.22 5893.27 603.61 4639.08 N: 10128.27 W: 3.00: -2.75 1.48: 160.32: 11138.9 :........................".......-,,,,...........,.-....,.,.,.................................+..........._..._-.....;~-~....................................~.".."..,........"......""'....,..' ..........................-........1......,..,..,-......-.. -,..., ........,..............................,...-...,...-..,---............,.....;--,--...,-"-..............-"'-"".." "'.. : 3' i 13483.51 ' 96.381 41.03:307.2215965.97, 72.70 4677.34N: 10178.66W!...__._-~.:Q.0¡ 0.00 0.001 0.00] 11200.8 4' 14214.55 731.05' 29.70 307.20 6561.14 595.17 4932.80 N 10515.11 W 1.55 -1.55 0.00 180.05 11614.5 5T' 14442,17 227.62 28.00 307.21 6760.50 199.36 4999.20 N 10602.59 W 0.75 -0.75 0.01 179.77 11722.0 ,.. 6;"''''''1 1479Ò.50 348.34[ 26.26: 307.21; 7070.50i310~oõ:sã95.25 N 10729.09W¡'''-'-'''-'''-ë)'~5ÕT"" -0.50 0-:-00"'"--'-1'86:ÒO~877.5''' ''''''''' .' ..:... . ..,... moo ",,,,,,,.., . ,'.m..... ......................... . .......... ~_. .~.¡.. .~. V'-'" .- -- -...."..- .' ... ........ u.. '.'" . ............... ...... .............._..__..~ -~.. ~....__. -.... ... ............ ..... ........;... ...~ . ... .~.. u. ..~-.... .-..... .............. ',........................,~... .~.. ...~. ..-.. -........ 7 14940.50 150.00' 25.51' 307.21! 7205.45: 134.95 5134.85N: 10781.24W 0.50 -0.50 0.00, 180.00 11941.6 17 September, 2002 -12:17 -1 - DrillQuest North 510 BPXA ~ 5 Pad, Slot S-114A WPS A WPS - S-114A WP01 -..-l Revised: 17 September, 2002 PROPOSAL REPORT 17 September, 2002 .~ Surface Coordinates: 5980820.17 N, 618929.73 E (70021' 22.5075" N, 149002' 02.8406" W) Surface Coordinates relative to Project H Reference: 980820.17 N, 118929.73 E (Grid) Surface Coordinates relative to Structure Reference: 52.14 S, 1012.31 E (True) Kelly Bushing: 70.50ft above Mean Sea Level 5pE!"I'Y-SUIl D~, ~..L.-"~,,I N~ G seA v I c: e !5 A HalUburton Company Proposal Ref: pro11319 Sperry-Sun Drilling Services Proposal Report for S-114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured 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) (ff C/100ft) 5-114 Reca 0.00 0.000 0.000 -70.50 0.00 0.00 E 5980820.17 N 618929.73 E 0.00 100.00 0.166 20.000 29.50 100.00 0.05 E 5980820.31 N 618929.78 E 0.166 0.03 '~' 200.00 0.330 328.873 129.50 200.00 0.08 E 5980820.70 N 618929.80 E 0.260 0.22 300.00 1.158 300.602 229.49 299.99 0.83W 5980821.37 N 618928.88 E 0.882 1.35 400.00 2.920 285.728 329.43 399.93 3.95W 5980822.59 N 618925.74 E 1.826 4.67 500.00 5.878 274.631 429.14 499.64 11.35 W 5980823.65 N 618918.32 E 3.064 11.55 600.00 9.186 282.973 528.26 598.76 24.25 W 5980825.48 N 618905.39 E 3.476 23.54 700.00 12.244 289.462 626.48 696.98 42.17 W 5980830.58 N 618887.39 E 3.283 41.56 800.00 13.908 293.000 723.92 794.42 63.06 W 5980838.50 N 618866.37 E 1.845 63.64 900.00 16.529 292.144 820.36 890.86 87.39 W 5980848.40 N 618841.88 E 2.630 89.70 1000.00 18.161 289.382 986.~~; 39.85 N 115.34 W 5980858.19 N 618813.77 E 1.828 118.80 1100.00 19.638 290.501 80.86 51.23 N 145.90 W 5980869.07 N 618783.04 E 1.520 150.70 1200.00 20.634 289.101 4.84 62.64 N 178.08 W 5980879.98 N 618750.67 E 1.106 184.01 1300.00 23.024 287.979 1267.73 74.69 N 213.08 W 5980891.47 N 618715.49 E 2.426 220.03 1400.00 26.161 286.478 1358.67 86.54 N 252.91 W 5980902.69 N 618675.48 E 3.199 260.03 1500.00 29.899 287.884 1376.58 1447.08 100.51 N 297.48 W 5980915.94 N 618630.69 E 3.795 305.17 1600.00 35.706 286.454 1460.20 1530.70 116.67 N 349.78 W 5980931.27 N 618578.14 E 5.858 358.01 1700.00 37.546 284.860 1540.91 1611.41 132.44 N 406.67 W 5980946.13 N 618521.00 E 2.072 414.53 1800.00 43.095 284.576 1616.92 1687.42 149.03 N 469.44 W 5980961.73 N 618457.99 E 5.552 476.45 1900.00 46.119 283.413 1687.63 1758.13 166.20 N 538.01 W 5980977.80 N 618389.15 E 3.132 543.59 .~ 2000.00 46.461 282.708 1756.79 1827.29 182.11 N 608.46 W 5980992.60 N 618318.46 E 0.614 611.65 2100.00 46.724 283.184 1825.36 1895.86 198.74 N 679.33 W 5981008.10 N 618247.34 E 0.435 680.44 2200.00 47.185 282.069 1893.93 1964.43 214.72 N 750.33 W 5981022.95 N 618176.08 E 0.936 749.01 2300.00 48.099 283.068 1961.05 2031.55 230.04 N 822.85 W 5981037.12 N 618103.33 E 1.174 818.49 2400.00 48.268 285.868 2027.74 2098.24 248.96 N 894.92 W 5981054.90 N 618030.97 E 2.094 889.52 2500.00 49.482 287.358 2093.80 2164.30 270.53 N 966.83 W 5981075.31 N 617958.73 E 1.653 961.83 2600.00 52.433 288.758 2157.04 2227.54 294.49 N 1040.47 W 5981098.10 N 617884.71 E 3.145 1036.89 2700.00 56.924 290.362 2215.07 2285.57 321.73 N 1117.18W 5981124.12 N 617807.58 E 4.678 1116.28 2800.00 63.222 292.176 2265.24 2335.74 353.06 N 1197.74 W 5981154.17 N 617726.53 E 6.491 1201.12 2900.00 67.776 293.111 2306.17 2376.67 388.36 N 1281.85 W 5981188.13 N 617641.88 E 4.632 1291 .08 17 September, 2002 - 12:31 Page 2 of 12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured 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) (ff CO/100ft) 3000.00 72.072 294.463 2340.62 2411 .12 426.09 N 1367.78 W 5981224.49 N 617555.36 4,479 1383.88 3100.00 71.659 296.833 2370.96 2441.46 467.21 N 1453.73 W 5981264.24 N 617468.77 E 2,289 1478.50 3200.00 70.465 298.422 2403.46 2473.96 511.16N 1537.46 W 5981306.86 N 617384.35 E 1.920 1572.77 3300.00 72.946 298.210 2435.18 2505.68 556.27 N 1620.87 W 5981350.64 N 617300.23 E 2.489 1667.37 3400.00 74.081 298.458 2463.48 2533.98 601.77 N 1705.30 W 5981394.79 N 617215.09 E 1.160 1763.05 \~ 3500.00 74.524 298.051 2490.52 2561.02 5981439.01 N 617129.57 E 0.591 1859.09 3600.00 74.319 297.964 2517.37 2587.87 5981482.97 N 617043.86 E 0.221 1955.15 3700.00 74.009 296.578 2544.64 2615.14 5981525.50 N 616957.56 E 1.369 2050.97 3800.00 73.508 297.286 2572.58 2643.08 5981567.73 N 616871.33 E 0.845 2146.58 3900.00 72.841 296.814 2601 .60 2672.10 5981609.99 N 616785.48 E 0,805 2241 .89 4000.00 72.536 295.948 2631 .29 2701.79 866.02 N 2217.08 W 5981650.88 N 616699.18 E 0.881 2336.85 4100.00 71.762 295.863 2661 .86 2732.36 907.72 N 2302.67 W 5981691.22 N 616612.94 E 0.779 2431.48 4200.00 71.051 295.440 2693.98 2764.48 948.63 N 2388.08 W 5981730.77 N 616526.89 E 0,816 2525.54 4300.00 71 .620 295.419 796;'ì;~, 989.26 N 2473.58 W 5981770.03 N 616440.75 E 0.570 2619.52 4400.00 72.812 294.853 27. fa 1029.99 N 2559.67 W 5981809.39 N 616354.03 E 1.308 2714.06 4500.00 73.454 294.268 2856.02 1069.42 N 2646.93 W 5981847.43 N 616266.16 E 0.852 2808.88 4600.00 74.034 294.755 2 .9 2884.19 1109.23 N 2734.23 W 5981885.85 N 616178.24 E 0.744 2903.95 4700.00 73.776 294.992 2840.91 2911.41 1149.78 N 2821.49 W 5981925.02 N 616090.34 E 0.345 2999.38 4800.00 73.817 294.404 2869.32 2939.82 1190.05 N 2908.51 W 5981963.89 N 616002.70 E 0.567 3094.45 4900.00 73.119 294.169 2897.22 2967.72 1229.31 N 2996.13 W 5982001.76 N 615914.46 E 0.733 3189.50 5000.00 72.158 294.326 2927.28 2997.78 1268.50 N 3083.08 W 5982039.57 N 615826.89 E 0.972 3283.94 5100.00 72.180 294.148 2958.05 3028.55 1307.63 N 3169.82 W 5982077.31 N 615739.55 E 0.171 3378.16 ~' 5200.00 72.312 294.854 2988.51 3059.01 1346.93 N 3256.58 W 5982115.23 N 615652.18 E 0.685 3472.50 5300.00 72.182 294.916 3018.96 3089.46 1387.17 N 3342.91 W 5982154.10 N 615565.22 E 0.142 3566.98 5400.00 71 .658 295.982 3049.95 3120.45 1427.86 N 3428.84 W 5982193.42 N 615478.66 E 1.141 3661.36 5500.00 71 .903 295.558 3081.31 3151.81 1469.32 N 3514.27 W 5982233.51 N 615392.58 E 0.471 3755.72 5600.00 70.509 295.913 3113.38 3183.88 1510.37 N 3599.62 W 5982273.20 N 615306.58 E 1 .434 3849.80 5700.00 69.262 295.820 3147.78 3218.28 1551 .35 N 3684.10 W 5982312.83 N 615221.46 E 1.249 3943.11 5800.00 68.643 296.201 3183.71 3254.21 1592.22 N 3768.00 W 5982352.37 N 615136.93 E 0.714 4035.87 5900.00 68.710 297.976 3220.24 3290.74 1634.84 N 3850.75 W 5982393.66 N 615053.51 E 1.654 4128.59 17 September, 2002 - 12:31 Page 3 of 12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Sw114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured 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 )l¡¡;;I¡¡!, CO/100ft) 6000.00 70.967 296.265 3254.53 3325.03 1677.51 N 3934.43 W 5982435.00 N 614969.17'E 2.770 4222.12 6100.00 71 .364 296.300 3286.64 3357.14 1719.22 N 4019.45 W 5982475.36 N 614883.49 E 0.399 4316.28 6200.00 69.699 296.423 3319.98 3390.48 1761.08 N 4103.92 W 5982515.87 N 614798.37 E 1.669 4410.05 6300.00 69.983 295.086 3354.53 3425.03 1801 .91 N 4188.41 W 5982555.36 N 614713.24 E 1.287 4503.28 6400.00 71 .273 297.202 3387.73 3458.23 1843.47 N 4273.08 W 5982595.56 N 614627.92 E 2.377 4597.06 ~ 6500.00 73.066 297.623 3418.25 3488.75 5982638.07 N 614542.71 E 1.838 4691.94 6600.00 73.004 297.676 3447.31 3517.81 5982681.21 N 614457.30 E 0.080 4787.32 6700.00 71 .977 296.629 3477.69 3548.19 5982723.29 N 614371.83 E 1 .432 4882.20 6800.00 73.181 296.122 3507.51 3578.01 5982764.29 N 614285.64 E 1.298 4977.14 6900.00 73.396 296.167 3536.08 3606.58 5982804.96 N 614198.86 E 0.219 5072.40 7000.00 72.558 297.201 3565.29 3635.79 2102.64 N 4784.19 W 5982846.59 N 614112.76 E 1.296 5167.58 7100.00 71 .894 297.827 3596.07 3666.57 2;146.68 N 4868.53 W 5982889.28 N 614027.73 E 0.893 5262.40 7200.00 72.245 297.082 3626.89 3697.39 2191.01 N 4952.70 W 5982932.28 N 613942.87 E 0.791 5357.24 7300.00 72.733 295.388 27 ;4!,it, 2232.81 N 5038.41 W 5982972.71 N 613856.51 E 1.688 5452.02 7400.00 73.379 294.669 56.69' 2273.35 N 5125.03 W 5983011 .86 N 613769.25 E 0.943 5546.91 7500.00 73.391 294.624 3784.94 2313.00 N 5212.38 W 5983050.13 N 613681 .29 E 0.044 5641.93 7600.00 72.816 294.863 3 3814.10 2353.27 N 5299.14 W 5983089.01 N 613593.89 E 0.618 5736.79 7700.00 72.466 294.117 3773.44 3843.94 2392.96 N 5385.94 W 5983127.32 N 613506.48 E 0.793 5831 .36 7800.00 72.429 292.396 3803.66 3874.16 2430.72 N 5473.47 W 5983163.68 N 613418.36 E 1.641 5925.52 7900.00 72.303 290.520 3833.90 3904.40 2465.58 N 5562.18 W 5983197.13 N 613329.11 E 1.793 6019.14 8000.00 71 .603 290.827 3864.76 3935.26 2498.66 N 5651.36 W 5983228.79 N 613239.42 E 0.759 6112.20 8100.00 70.603 291.045 3897.13 3967.63 2532.66 N 5739.65 W 5983261.38 N 613150.59 E 1.020 6205.00 ~ 8200.00 69.901 291.822 3930.97 4001.47 2566.89 N 5827.30 W 5983294.22 N 613062.41 E 1.014 6297.38 8300.00 70.700 293.487 3964.89 4035.39 2603.04 N 5914.14 W 5983328.99 N 612975.01 E 1.759 6390.11 8400.00 69.515 295.015 3998.63 4069.13 2641.73 N 5999.96 W 5983366.31 N 612888.59 E 1.862 6483.32 8500.00 69.093 295.303 4034.07 4104.57 2681.57 N 6084.55 W 5983404.80 N 612803.37 E 0.501 6576.12 8600.00 70.158 295.547 4068.93 4139.43 2721.81 N 6169.20 W 5983443.69 N 612718.09 E 1.090 6669.17 8700.00 72.560 295.538 4100.87 4171.37 2762.67 N 6254.70 W 5983483.19 N 612631.96 E 2.402 6763.27 8800.00 73.649 295.495 4129.91 4200.41 2803.87 N 6341.06 W 5983523.02 N 612544.96 E 1.090 6858.29 8900.00 74.013 295.694 4157.54 4228.04 2845.43 N 6427.72 W 5983563.19 N 612457.65 E 0.411 6953.74 17 September, 2002 - 12:31 Page 4 of 12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured 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 e/100ft) 9000.00 72.125 295.395 4186.87 4257.37 2886.67 N 6513.96 W 5983603.06 N 612370.76 1.910 7048.68 9100.00 71 .524 294.694 4217.93 4288.43 2927.05 N 6600.01 W 5983642.07 N 612284.08 E 0.897 7143.00 9200.00 70.403 293.512 4250.71 4321.21 2965.38 N 6686.35 W 5983679.02 N 612197.14 E 1.582 7236.46 9300.00 70.163 293.490 4284.50 4355.00 3003.01 N 6772.62 W 5983715.27 N 612110.29E 0.241 7329.49 9400.00 70.118 292.244 4318.45 4388.95 3039.94 N 6859.13 W 5983750.83 N 612023.20 E 1.173 7422.35 "'-'{ 9500.00 69.894 290.990 4352.60 4423.10 5983783.32 N 611935.01 E 1.200 7514.56 9600.00 70.092 292.012 4387.08 4457.58 5983816.46 N 611847.20 E 0.981 7606.79 9700.00 71 .012 293.025 4420.33 4490.83 5983851 .02 N 611759.44 E 1.326 7699.70 9800.00 71 .229 295.303 4452.44 4522.94 5983888.11 N 611672.31 E 2.166 7793.40 9900.00 70.961 297.500 4484.88 4555.38 5983929.14 N 611587.09 E 2.096 7887.52 10000.00 72.088 297.934 4517.04 4587.54 3269.48 N 7376.02 W 5983972.14 N 611502.73 E 1.199 7981.93 10100.00 73.672 298.400 4546.31 4616.81, 3314.41 N 7460.43 W 5984015.72 N 611417.62 E 1.646 8077.28 10200.00 74.395 298.555 4573.66 4644.16 3360.46 N 7544.87 W 5984060.43 N 611332.46 E 0.739 8173.27 10300.00 74.475 297.718 70;9~lt) 3406.03 N 7629.77 W 5984104.64 N 611246.85 E 0.810 8269.38 10400.00 74.831 298.116 97.46 3450.90 N 7715.10 W 5984148.15 N 611160.81 E 0.523 8365.49 10500.00 74.350 297.903 4723.87 3496.36 N 7800.17 W 5984192.25 N 611075.04 E 0.523 8461.68 10600.00 73.868 297.555 4 .8 4751.28 3541.09 N 7885.30 W 5984235.63 N 610989.21 E 0.587 8557.55 10700.00 73.551 297.798 4708.84 4779.34 3585.63 N 7970.32 W 5984278.81 N 610903.49 E 0.393 8653.21 10800.00 72.772 297.742 4737.78 4808.28 3630.24 N 8055.01 W 5984322.07 N 610818.10 E 0.781 8748.64 10900.00 72.058 297.380 4768.00 4838.50 3674.36 N 8139.51 W 5984364.84 N 610732.91 E 0.793 8843.64 11000.00 72.165 296.786 4798.85 4869.35 3717.68 N 8224.19 W 5984406.81 N 610647.55 E 0.575 8938.37 11100.00 72.961 296.148 4828.69 4899.19 3760.18 N 8309.65 W 5984447.95 N 610561.43 E 1.002 9033.31 11200.00 72.137 295.902 4858.67 4929.17 3802.11 N 8395.34 W 5984488.52 N 610475.09 E 0.857 9128.15 ~ 11300.00 71 .408 295.219 4890.06 4960.56 3842.88 N 8481.09 W 5984527.92 N 610388.70 E 0.975 9222.42 11400.00 71 .368 295.958 4921 .96 4992.46 3883.84 N 8566.56 W 5984567.51 N 610302.59 E 0.701 9316.55 11500.00 70.881 295.970 4954.10 5024.60 3925.64 N 8651.53 W 5984607.96 N 610216.97 E 0.487 9410.71 11600.00 69.834 294.760 4987.97 5058.47 3965.62 N 8736.69 W 5984646.59 N 610131.18 E 1.548 9504.06 11700.00 70.038 294.699 5022.39 5092.89 4005.04 N 8821.90 W 5984684.65 N 610045.35 E 0.212 9597.15 11800.00 70.622 293.922 5056.03 5126.53 4043.89 N 8907.69 W 5984722.13 N 609958.96 E 0.936 9690.42 11900.00 71 .044 293.105 5088.82 5159.32 4081.48 N 8994.36 W 5984758.34 N 609871.71 E 0.880 9783.77 17 September, 2002 - 12:31 Page 5 of 12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU- WOA S Pad Measured 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) e/100ft) 12000.00 70.904 292.978 5121.23 5191.73 4118.35 N 9081.48 W 5984793.82 N 609784.01 E 0.185 9877.11 12100.00 70.836 292.920 5154.21 5224.71 4155.29 N 9168.36 W 5984829.38 N 609696.56 E 0.088 9970.29 12200.00 71 .075 292.144 5186.79 5257.29 4191.65N 9255.63 W 5984864.34 N 609608.72 E 0.771 10063.49 12240.80 71 .129 291 .705 5200.00 5270.50 4206.06 N 9291 .44 W 5984878.19 N 609572.69 E 1.026 10101.46 Top Colville Siltstone -- 12300.00 70.976 291.166 5219.16 5289.66 4226.51 N 9343.59 W 5984897.80 N 609520.22 E 0.900 10156.47 ST KOP: Dir @ 3.0000/100ft, 1. .!2 Right TF : 12300.00ft MD, 5289'Mt TVD $-114A WP01 12400.00 68.154 292.254 5324.58 4261 .16 N 9430.64 W 5984931.07 N 609432.63 E 3.000 10248.57 12500.00 65.340 293.385 5364.05 4296.78 N 9515.32 W 5984965.34 N 609347.39 E 3.000 10339.18 12600.00 62.535 294.569 5407,98 4333.27 N 9597.39 W 5985000.52 N 609264.75 E 3.000 10428.06 12700.00 59.741 295.815 5456.25 4370.53 N 9676.64 W 5985036.52 N 609184.93 E /3.000 10514.95 12800.00 56.958 297.134 wiœP508::¡a,., 4408.46 N 9752.83 W 5985073.24 N 609108.14 E 3.000 10599.63 '::::"~' '- 12900.00 54.191 298.538 ü565.25 4446.96 N 9825.77 W 5985110.57 N 609034.60 E 3.000 10681.85 12908.95 53.944 298.669 5570,50 4450.43 N 9832.13 W 5985113.94 N 609028.18 E 3.000 10689.08 CM2 13000.00 51.441 300.044 5625.68 4485.91 N 9895.25 W 5985148.42 N 608964.50 E 3.000 10761.40 13100.00 48.712 301.669 5689.86 4525.22 N 9961.09 W 5985186.68 N 608898.05 E 3.000 10838.05 13200.00 46.008 303.435 5757.59 4564.78 N 10023.10 W 5985225.24 N 608835.42 E 3.000 10911.60 13300.00 43.333 305.369 5758.21 5828.71 4604.47 N 10081.11 W 5985264.01 N 608776.79 E 3.000 10981.85 13387.13 41 .032 307.216 5822.77 5893.27 4639.08 N 10128.27 W 5985297.86 N 608729.08 E 3.000 11040.20 End Dir, Start Sail @ 41.032° : 13387 .13ftMD ,5893.27ftTVD , 13400.00 41 .032 307.216 5832.48 5902.98 4644.19 N 10135.00 W 5985302.87 N 608722.28 E 0.000 11048.62 ~ 13483.51 41 .032 307.216 5895.47 5965.97 4677.34 N 10178.66 W 5985335.33 N 608678.10 E 0.000 11103.24 Begin Dir @ 1.5500/1ooft: 13483.51t MD, 5965.97ft TVD 13500.00 40.776 307.216 5907.93 5978.43 4683.88 N 10187.26 W 5985341.72 N 608669.39 E 1.550 11114.00 13600.00 39.226 307.214 5984.54 6055.04 4722.75 N 10238.45 W 5985379.78 N 608617.59 E 1.550 11178.04 13700.00 37.676 307.211 6062.85 6133.35 4760.36 N 10287.97 W 5985416.59 N 608567.48 E 1.550 11239.99 13800.00 36.126 307.209 6142.81 6213.31 4796.67 N 10335.79 W 5985452.14 N 608519.09 E 1.550 11299.81 13870.32 35.036 307.207 6200.00 6270.50 4821.41 N 10368.38 W 5985476.36 N 608486.12 E 1.550 11340.58 Top Colville Shale (CM1) 13900.00 34.576 307.206 6224.37 6294.87 4831.65 N 10381.87 W 5985486.39 N 608472.46 E 1.550 11357.46 17 September, 2002 - 12:31 Page 6 of 12 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-114A WPS Revised: 17 September, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured 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 e 11 OOft) 14000.00 33.026 307.203 6307.46 6377.96 5985519.32 N 608427.62 1.550 11412.88 14100.00 31 .476 307.200 6392.03 6462.53 5985550.91 N 608384.61 E 1.550 11466.05 14109.33 31.332 307.199 6400.00 6470.50 5985553.78 N 608380.70 E 1.550 11470.89 Fault Crossing 14200.00 29.926 307.196 6478.02 6548.52 5985581.12 N 608343.46 E 1.550 11516.92 14213.81 29.712 307.196 6490.00 6560.50 5985585.19 N 608337.93 E 1.550 11523.76 THRZ ~ 14214.55 29.701 307.195 6490.64 6561.14 5985585.40 N 608337.63 E 1.550 11524.13 Decrease in Dir Rate @ 0.750o/100ft: 14214.55ft MD, 6561.14ft TVD 14300.00 29.062 307.201 6565.10 6635.60 5985610.22 N 608303.84 E 0.747 11565.90 14400.00 28.315 307.207 6652.82 6723.32 5985638.63 N 608265.15 E 0.747 11613.72 14419.50 28.169 307.208 6670.00 6740.50< 5985644.09 N 608257.71 E 0.747 11622.92 TKLB 14442.17 28.000 307.210 6690.00 6760.50 5985650.41 N 608249.11 E 0.747 11633.55 Decrease in Dir Rate @ 0.500o/100ft: 14442.17ft MD, 6760.50ft TVD TKUP Target - S-114A T1 Driller's Poly @ 85% MWD+IFR+MS, Drillers 14500.00 27.711 307.210 5015.54 N 10624.11 W 5985666.41 N 608227.33 E 0.500 11660.47 14600.00 27.211 307.210 5043.43 N 10660.84 W 5985693.71 N 608190.17 E 0.500 11706.42 14600.16 27.210 307.210 5043.47 N 10660.89 W 5985693.75 N 608190.11 E 0.500 11706.49 LCU 14700.00 26.711 307.210 5070.85 N 10696.94 W 5985720.55 N 608153.63 E 0.500 11751.59 14757.03 26.426 307.210 5086.27 N 10717.26 W 5985735.65 N 608133.07 E 0.500 11777.00 Kuparuk A 14790.50 26.258 307.210 7000.00 7070.50 5095.25 N 10729.09 W 5985744.44 N 608121.10 E 0.500 11791.80 14800.00 26.211 307.210 7008.52 7079.02 5097.79 N 10732.43 W 5985746.93 N 608117.72 E 0.500 11795.98 14840.63 26.008 307.210 7045.00 7115.50 5108.60 N 10746.67 W 5985757.51 N 608103.31 E 0.500 11813.80 TMLV 14900.00 25.711 307.210 7098.43 7168.93 5124.26 N 10767.30 W 5985772.85 N 608082.44 E 0.500 11839.60 ~ - 14940.50 25.508 307.210 7134.95 7205.45 - 5134.85 N 10781.24 W 5985783.21 N 608068.33 E 0.500 11857.04 Total Depth: 14940.50ftMD,7205.45ftTVD 7" Casing 17 September, 2002 - 12:31 Page 7 of 12 DritlQuest 2.00.09.006 H DATE CHECK NO. 8/01/02 H207047 VENDOR DISCOUNT NET $100.00 H 207047 DATE INVOICE I CREDIT MEMO GROSS DESCRIPTION 8/01/02 CK073102N Permit To Drill Fee PIs contact Sor.dra stewman X4750 for check pickLp 5 -U4A THE A1TACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, TOTAL ... $100.00 PAY BP EXPLORATION, P.O. BOX 196612 ANCHORAGË, ALASKA 99519..6612 , , , No:H 207047 CONSOLIDATED COMMERCIAL ACCOUNT bATE' AMOUNT **Aug. 1, 2002*** *****$100.00****** NOT VALID AFTER 120 DAYS TO THE ORDER OF Alaska Oil & Gas Conservation Corom 333 W 7th ,Ave, Ste 100 Anchorage, AK 99501 :~.\: ~,' <.:::: ::,::::: ~,\::::~.~'::'~~::"'H " ::~':0~)':~~:: ~.:~.::: ~ :\:::~, \ ':':":':.:::)¡I'- 'Ä~ ....r..,..'¡'",,,,;::,,,,,::,,,..,~:..,,. ':',", "Ì"i~~~~ ',',\", ,~" ',',' ... ".'.:, ~~;;;.ZI.;::,;; ~ ,;!~:~i}~\ ;~:1~;~;?,:;~i(>;S?i II' 20 '70 ~ '711' 1:0 ~ ~ 2038 q 51: 008 ~ ~ ~ '111' ~ ~ ) ") TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~a 5r/lcj/J 71)2- ~/9~ PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 ajody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). - The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKUST COMPANY BPX FIELD & POOL 640120 I Prudhoe Bay, Aurora Undefined WELL NAME PBU S-114A Initial ClasslType DEV 11-01L PROGRAM Exploritory (EXP) _Development (DEV) ~ Redril ~ervlce (SER) _Well bore seg - Annular disposal para req GEOL AREA 890 UNIT No. 11650 ONIOFF SHORE On ADMINISTRATION 1. Permit fee attached. :................................... """""""'"'''''''''''''''''''''''''''''''''''''''' 2. Lease number appropriate ..............,......... ... ................. .......... ... .......,. ..... .......... ... 3. Unique well name and number,. ....... ..... .... ............ ... .................. ,... ,....... ............ .., 4. Well located in a defined pool...... ................. .... .......... ..... ... ... ... ......... ,................... 5. Well located proper distance from drilling unit boundary.............................................. 6. Well located proper distance from other wells ................................................... ........ 7. Sufficient acreage available in drilling unit................................................................ 8. If deviated, is wellbore plat included..................................................................... ... 9. Operator only affected party.................................................................................. 10. Operator has appropriate bond in force ... .............................,........................... ...... 11. Permit can be issued without conservation order..................................................... 12. Permit can be issued without administrative approval............................................... 13 Can permit be approved before 15-day wait ... ............ .......................................... .., 14 Well located within area and strata authorized by Injection Order # 15 All wells witthin 1/4 mile area of review identified ... ..............................,........ ... ........ 16 ACMP Finding of Consistency has been issued for this projec ............... ..................... APPR DATE SFD 9/18/2002 (For Service Well Only) (For Service Well Only) ENGINEERING Conductor string provided........................................................ .'........,...... ........... Surface casing protects all known USDWs ............................................................. CMT vol adequate to circulate on conductor & surf csg ............................................. CMT vol adequate to tie-in long string to surf csg ..................................................... CMT will cover all known productive horizons........................................................., Casing designs adequate for C, T, B & permafrost................................................... Adequate tankage or reserve pit... ......... ... ... ....... ..... ... ... ... ...... ...... ......... ... ...... ...... If a re-drill, has a 10-403 for abandonment been approved........................................ Adequate wellbore separation proposed................................................................ If diverter required, does it meet regulations............................................................ Drilling fluid program schematic & equip list adequate............................................... BOPEs, do they meet regulation ..............................................,............................ BOPE press rating appropriate; test to .................... 4 DOt!) psig ........................... Choke manifold complies w/API RP-53 (May 84) ..................................................... Work will occur without operation shutdown............................................................ Is presence of H2S gas probable.......................................................................... Mechanical condition of wells within AOR verified .................................................... 17 18 19 20 21 22 23 24 25 26 27 DATE 28 4/ t't '0 L ~~ 31 32 (For Service Well Only) 33 APPR fJGIr- GEOLOGY 34 Permit can be issued wlo hydrogen sulfide measures............................................... 35 Data presented on potential overpressure zones ..................................................... 36 Seismic analysis of shallow gas zones.. .... ...... ......... ...... ..... ....... ......... ......... . ... . . .. . . 37 Seabed condition survey (if off-shore) .................................................................... 38 Contact namelphone for weekly progress reports {exploratory only} .......................... APPR DATE SFD 9/18/2002 GEOLOGY: ENGINERING: RES. ENGINERING: COMMISSION: ---- RPC: TEM: JDH:v It- SFD:~GA: \Jlc.k MJW: COT: DTS: of} ¡'lOG Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes H207047 Surface location in AOL 028257; top productive interval and TO in AOL 028258. Not Applicable Not Applicable Not Applicable \- ) "'fA Not Applicable, sidetrack of existing wellbore. SFO AliA- ¡J ~ ~ '1 q 1 l{ t f} ø.¡ tn- I c¡. N/A- Ii1 tW-" ¡II/( W Wt ç,¡ ¿q 2.:5 p <'--r' " 10, I f' PC-¡ , ~. CSCj I ~t- '-!O({)() flL" "'/It Not Applicable Not Applicable Not Applicable Not Applicable ) Comments/Instructions ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically.,.. organize this category of information. ) ) ó?oa-fl8: ) llottJ1 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LìsLib $Revìsion: 4 $ Mon Mar 31 11:05:15 2003 Reel Header Service name.............LISTPE Date.....................03/03/31 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.....................03/03/31 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 Aurora MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA S-114a 500292311601 BP Exploration Alaska, Inc. Sperry-Sun Drilling Services 31-MAR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2215200000 C. EWING L. VAUGHN MWD RUN 2 MW2215200000 C. EWING L. VAUGHN MWD RUN 3 MW2215200000 C.A. DEMOSKI A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW2215200000 C.A. DEMOSKI T. ABBOTT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 4617 4496 MSL 0) 70.20 36.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 115.0 9.875 10.750 6140.0 # REMARKS: ) ') 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SECTION IS A SIDETRACK, KICKED-OFF FROM A CEMENT PLUG IN THE 8-114 WELl.BORE. THE TOP OF THE PLUG 18 AT APPROXI~ffiTELY 12185'MDI 5252'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH NATURAL G~MA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5. ~iD RUN 3 COMPRISED (DGR) UTILIZING GEIGER-MUELLER TUBE RESISTIVITY - PHASE 4 (EWR4); AND DIRECTIONAL WITH DUAL GAMMA RAY DETECTORS; ELECTROMAGNETIC WAVE PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR; EWR4; PWD; COMPENSATED NEUTRON POROSITY (CNP); AND STABILIZED LITHO DENSITY (SLD) . 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNORR (GEOQUEST/BP) TO R. OAKLEY (SSDS), DATED 9/27/01. 8. l'1WD RUNS 1 - 3, 5 REPRESENT WELL S-114A WITH API#: 50-029-23116-01. THIS WELL REACHED A TOTAL DEPTH ('I'D) OF 14890'MD I 7162' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NA,TURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVER~GE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVAL ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 9.875" BIT MUD WEIGHT: 9.4 - 10.1 PPG MUD SALINITY: 300 - 550 PPM CHLORIDES FORMATION WATER SALINITY: 22000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 Glce LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.OOl ) ) Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET FCNT NPHI NCNT RHOB DRHO PEF $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 59.0 116.5 6125.5 6125.5 6125.5 6125.5 6125.5 12088.5 12089.0 12091.5 12097.0 12097.0 12097.0 STOP DEPTH 14843.0 14890.0 14835.5 14835.5 14835.5 14835.5 14835.5 14791.0 14791.0 14791.0 14800.5 14800.5 14800.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD !''lWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 5 MERGED MAIN PASS. $ MERGE TOP 59.0 2401.5 6154.5 12185.0 MERGE BASE 2401. 5 6154.5 12185.0 14890.0 # 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOS MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 ') ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 59 14890 7474.5 29663 59 14890 ROP MWD FT/H 0.22 1308.12 239.414 29517 116.5 14890 GR MWD API 7.66 405.15 79.8427 29569 59 14843 RPX MWD OHMM 0.64 2000 6.86771 17421 6125.5 14835.5 RPS MWD OHMM 0.28 131. 63 5.78285 17421 6125.5 14835.5 RPM MWD O'f-IMM 0.63 1031. 38 6.09302 17421 6125.5 14835.5 RPD MWD OHMM 0.69 2000 8.36498 17 421 6125.5 14835.5 FET MWD HOUR 0.08 165.444 1.87066 17421 6125.5 14835.5 NPHI MWD PU~S 0.23 146.64 33.9161 5405 12089 14791 FCNT MWD CNTS 463 1131 604.286 5406 12088.5 14791 N CNT MV\fD CNTS 2080 3341 2529.69 5400 12091.5 14791 RHOB MWD G/CM 0.032 3.217 2.3136 5408 12097 14800.5 DRHO MWD G/CM -0.103 2.72 0.101906 5408 12097 14800.5 PEF MWD BARN 1. 91 90.15 4.06106 5408 12097 14800.5 First Reading For Entire File..........59 Last Reading For Entire File...........14890 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 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.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 59.0 116.5 STOP DEPTH 2345.0 2401.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 05-SEP-02 Insite 7.75 Memory 2401.0 115.0 2401.0 .3 48.2 # ) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # 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.................. 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER TLG012 13.500 115.0 Spud Mud 9.60 300.0 9.0 400 10.5 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 ) .0 78.4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 59 2401.5 1230.25 4686 59 2401. 5 ROP MWD010 FT/H 0.98 728 152.514 4571 116.5 2401.5 GR MWD010 API 16.66 126.96 67.4714 4573 59 2345 First Reading For Entire File..........59 Last Reading For Entire File...........240l.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 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.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO2 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. 2 .5000 START DEPTH 2345.5 2402.0 STOP DEPTH 6098.5 6154.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # 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.................. 0 Data Specification Block Type.....O Logging Direction.................Down 08-SEP-02 Insite 7.75 Memory 6155.0 2401.0 6155.0 48.4 74.5 TOOL NUMBER TLG013 13.500 115.0 Spud Mud 9.60 82.0 9.4 400 6.2 .000 .000 .000 .000 .0 99.5 .0 .0 -) ') 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 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2345.5 6154.5 4250 7619 2345.5 6154.5 ROP MWD020 FT/H 0.22 1265.39 258.172 7506 2402 6154.5 GR MWD020 API 32.75 152.03 88.0514 7507 2345.5 6098.5 First Reading For Entire File..........2345.5 Last Reading For Entire File...........6154.5 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 Fi 1 e 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.......03/03/31 Maximum Physical Record..65535 File T~:{pe................ 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 RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6099.0 6125.5 6125.5 6125.5 6125.5 6125.5 6155.0 STOP DEPTH 12172.5 12130.5 12130.5 12130.5 12130.5 12130.5 12185.0 # 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): 13-SEP-02 Insite 66.37 Memory 12185.0 6155.0 ') 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 AAY 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 TEMPEAATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTAATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 12185.0 69.4 74.9 TOOL NUMBER 142827 134760 9.875 6140.0 Water 9.50 45.0 9.4 300 6.4 Based 8.000 4.980 7.800 4.750 69.0 115.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6099 12185 9142 12173 6099 12185 ROP MWD030 FT/H 0.43 1308.12 294.49 12030 6155 12185 GR MWD030 API 7.66 134.54 63.6114 12148 6099 12172.5 RPX MWD030 OHMM 0.78 2000 8.25167 12011 6125.5 12130.5 RPS MWD030 OHMM 0.28 131. 63 6.75529 12011 6125.5 12130.5 RPM MWD030 OHMM 1.1 1031. 38 7.17647 12011 6125.5 12130.5 RPD MWD030 OHMM 1.11 2000 10.4115 12011 6125.5 12130.5 FET MWD030 HOUR 0.08 57.4 0.867015 12011 6125.5 12130.5 ~) First Reading For Entire File..........6099 Last Reading For Entire File...........12185 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........1.0.0 Date of Generatlon.......03/03/31 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.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FI LE SUMM.1\RY VENDOR TOOL CODE FCNT NPHI NCNT PEF RHOB DRHO RPM RPS RPD FET RPX GR ROP $ 5 ) header data for each bit run in separate files. 5 .5000 START DEPTH 12088.5 12089.0 12091.5 12097.0 12097.0 12097.0 12131.0 12131.0 12131.0 12131. 0 12131.0 12173.0 12185.5 # LOG HEADER DATA DATE LOGGED: SOFT1/iJARE 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 CNP SLD $ # STOP DEPTH 14791.0 14791.0 14791.0 14800.5 14800.5 14800.5 14835.5 14835.5 14835.5 14835.5 14835.5 14843.0 14890.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA 21-SEP-02 Insite 66.37 Memory 14890.0 12185.0 14890.0 29.2 71.1 TOOL Nm1BER 155790 106927 119007 67985 ,) .,., ) ) OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 6140.0 # 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: Based Water 10.10 43.0 10.0 400 6.0 1.100 .670 1. 650 2.000 78.0 132.8 78.0 78.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REtvIARKS : $ # 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 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX l<1WD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO M\iifD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12088.5 14890 13489.3 5604 12088.5 14890 ROP MWD050 FT/H 0.58 939.98 164.342 5410 12185.5 14890 GR MWD050 API 40.91 405.15 115.815 5341 12173 14843 RPX MWD050 OHMM 0.64 43.25 3.79511 5410 12131 14835.5 RPS MWD050 OHMM 0.65 35.77 3.62389 5410 12131 14835.5 RPM MWD050 OHMM 0.63 36.51 3.6876 5410 12131 14835.5 RPD MWD050 OHMM 0.69 32.14 3.8214 5410 12131 14835.5 FET MWD050 HOUR 0.2357 165.444 4.09891 5410 12131 14835.5 NPHI MWD050 PU-S 0.23 146.64 33.9161 5405 12089 14791 FCNT MWD050 CNTS 463 1131 604.286 5406 12088.5 14791 NCNT HWD050 CNTS 2080 3341 2529.69 5400 12091.5 14791 RHOB MWD050 G/CH 0.032 3.217 2.3136 5408 12097 14800.5 DRHO MWD050 G/CH -0.103 2.72 0.101906 5408 12097 14800.5 PEF MWD050 BARN 1. 91 90.15 4.06106 5408 12097 14800.5 ,\ ~ ') E'irst Reading For Entire File......... .12088.5 Last Reading For Entire File...........14890 File Trailer Service name.............STSLIB.OO5 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/03!31 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.. ...............STS LIS Writing Library. Reel Trailer Service name..... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/31 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................, UNKNOWN Continuation Number......Ol Next Reel Nance........... UNKNOWN Comments. . . . . . . . . . . . .. . . . STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ') Scientific Technical Services Scientific Technical Services