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Home My WebLink About201-059MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-100 PRUDHOE BAY UN BORE V-100 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/10/2023 V-100 50-029-23008-00-00 201-059-0 W SPT 6392 2010590 1598 2121 2121 2120 2120 749 753 754 755 4YRTST P Austin McLeod 7/9/2023 MITIA 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 BORE V-100 Inspection Date: Tubing OA Packer Depth 277 2943 2881 2872IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230710203452 BBL Pumped:2.1 BBL Returned:2.1 Thursday, August 10, 2023 Page 1 of 1             6HW:KLSVWRFNIRU/DWHUDO By Samantha Carlisle at 8:18 am, Sep 23, 2022 'LJLWDOO\VLJQHGE\7UHYRU+\DWW '1FQ 7UHYRU+\DWW RX 8VHUV 'DWH 7UHYRU+\DWW '6U %23(WHVWWRSVL 0*56(36)' -/& Gregory Wilson Digitally signed by Gregory Wilson Date: 2022.09.26 15:30:56 -08'00' RBDMS JSB 092922 7R $ODVND2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ )URP 7UHYRU+\DWW 'ULOOLQJ(QJLQHHU 'DWH 6HSWHPEHU 5H 3%896XQGU\5HTXHVW 6XQGU\DSSURYDOLVUHTXHVWHGWRVHWDZKLSVWRFNDQGPLOOWKHZLQGRZLQ9DVSDUWRIWKH SUHULJIRUGULOOLQJDQGFRPSOHWLQJRIWKHSURSRVHG9/&7'ODWHUDO 3URSRVHGSODQIRU9/3URGXFHU 3ULRUWRGULOOLQJDFWLYLWLHVVFUHHQLQJZLOOEHFRQGXFWHGWR0,7DQGGULIWIRUZKLSVWRFN(OLQHRU6HUYLFH&RLOZLOOPLOO WKH;1QLSSOH(OLQHZLOOVHWD[ZKLSVWRFNULJZLOOVHWLIQHHGHG 6HH9/37'UHTXHVWIRUFRPSOHWHGULOOLQJGHWDLOV$FRLOWXELQJGULOOLQJVLGHWUDFNZLOOEHGULOOHGZLWKWKH 1DERUV&'5ULJ7KHULJZLOOPRYHLQWHVW%23(DQGNLOOWKHZHOO7KHULJZLOOPLOODVLQJOHVWULQJZLQGRZ RIIRUPDWLRQRXWRIWKHFDVLQJ7KHZHOOZLOONLFNRIIGULOOLQJDQGODQGLQWKH.XSDUXN&7KHODWHUDOZLOO FRQWLQXHLQWKH.XSDUXN&WR7'7KHSURSRVHGVLGHWUDFNZLOOEHFRPSOHWHGZLWKD[´/VROLGVORWWHG OLQHU7KLVFRPSOHWLRQ:,//127DEDQGRQWKHSDUHQW.XSDUXNSHUIV 3UH5LJ:RUN(VWLPDWHGWRVWDUWHQGRI1RYHPEHU 6OLFNOLQH'XPP\:6GULIW D 'ULIWSDVWZKLSVWRFNVHWWLQJORFDWLRQ )XOOERUH0,7,$DQG0,77WRSVL (OLQH6HW´[´ZKLSVWRFNZLOOVHWRQULJLIQHHGHG D 7RSRIZKLSVWRFNVHWDW¶0'WRSRIZLQGRZDW¶0'SLQFKSRLQW E 2ULHQWHG52+6KLJKVLGH 6HUYLFH&RLORU(OLQH0LOO;11LSSOH D 0LOOWKH;1QLSSOHWR´DWa¶0' 9DOYH6KRS3UH&7'7UHH:RUNDVQHFHVVDU\ 5LJ:RUN x 5HIHUHQFH3%89/37'VXEPLWWHGLQFRQFHUWZLWKWKLVUHTXHVWIRUIXOOGHWDLOV x *HQHUDOZRUNVFRSHRI5LJZRUN 0,58DQG7HVW%23(0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL D *LYH$2*&&KUQRWLFHSULRUWR%23(WHVW 6HW:KLSVWRFNRQO\LIQRWGRQHSUHULJ 0LOO:LQGRZRQO\LIQRWGRQHSUHULJ 'ULOO%XLOGDQG/DWHUDO 5XQ6ROLG6ORWWHG/LQHU )UHH]H3URWHFWDQG5'02 7UHYRU+\DWW && :HOO)LOH 'ULOOLQJ(QJLQHHU -RVHSK/DVWXIND SSS 7KLVFRPSOHWLRQ:,//127DEDQGRQWKHSDUHQW.XSDUXNSHUIV 6XQGU\ 37' %23(WHVWWRSVL :HOO 'DWH 4XLFN7HVW6XEWR2WLV IW 7RSRI2WLV IW 'LVWDQFHVIURPWRSRIULVHU ([FOXGLQJTXLFNWHVWVXE 7RSRI$QQXODU IW C L Annular IW %RWWRP$QQXODU IW &/%OLQG6KHDUV IW &/3LSH6OLSV IW % % % % Kill Line Choke Line &/3LSH6OLS IW &/3LSH6OLSV IW 79 79 7 7 )ORZ7HH 0DVWHU 0DVWHU /'6 ,$ 2$ /'6 *URXQG/HYHO /3KRVHRSHQHQGHGWR)ORZOLQH CDR2-AC BOP Schematic &'55LJ V'ULS3DQ )LOO/LQHIURP+) 1RUPDOO\'LVFRQQHFWHG +3KRVHWR0LFURPRWLRQ +\GULO $QQXODU %OLQG6KHDU 3LSH6OLSV 3LSH6OLSV 3LSH6OLSV N0XG &URVV 3LSH6OLSV 3LSH6OLS +) QQHFHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHH I1 ZOI o�'7 by Date: 11/18/2019 32 0 0 y Transmittal Number: 93714 BPXA WELL DATA TRANSMITTAL Enclosed is a disc with the requested core photos and analysis. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall&bp com. RPI_WeIINo WI_Rermit Well Nm Core Photos Core Analysis, Description, etc 50029229780000 2001620 PRUDHOE BAY UN BORE Z-101 50029229880000 2001960 PRUDHOE BAY UN AURO S-104 J 50029229950000 2002080 PRUDHOE BAY UNIT Z-39 50029230080000 2010590 PRUDHOE BAY UN BORE V-100 50029231610000 2031030 PRUDHOE BAY UN BORE V-111 J 50029233880000 2080530 PRUDHOE BAY UN ORIN L-205 L-205PB1* *Plug -back analysis located in BP archive database. Please sign and email a copy of this transmittal to. GANCPDC@bp365.onmicrosoft.com Thank you, Mer .Merion Xendaff SIM Specialist SIM BP Exploration AlaskaJ900 E. Benson Blvd.lRoom: 716BIAnchorage, AK Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 17pA4 °AVor7— ti L- 14.0 L— 9 " ]AN 3 0 2€620 1 AOGCC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (I p �'�I �l DATE: Monday, July 29, 2019 P.1. Supervisor IIeY SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. V-100 FROM: Lou Laubenstein PRUDHOE BAY UN BORE V-100 Petroleum Inspector Sre; Inspector Reviewed By:� P.1. Supry -bp-- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-100 API Well Number 50-029-23008-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL190721171800 Permit Number: 201-059-0 Inspection Date: 7/21/2019 Rel Insp Num: Packer Depth Pretest Well V-100 Type Inj W 'TVD x392 - 'Tubing 2039 PTD 2010590 -',Type Test, SPT Test pd, 1598 IA 21 BBL Pumped. 24 iBBL Returned: j I OA 709 Interval 4YRTST PT P Notes: Good test ' Initial 15 Min 30 Min 15 Min 60 Min 2041- 2040 - 2040 ' 2750 - 2212 - 2709 713 - 714 _ 713 - Monday, July 29, 2019 Page 1 of I • • Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, September 04, 2015 8:59 PM To: Regg,James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay . 'fq 91916 Cc: AK, D&C Well Integrity Coordinator Subject: August 2015 AOGCC MIT Forms Attachments: August 2015 MIT Forms.zip All, Please find the attached MIT forms for August 2015: Well: PTD#: L-103 2021390 P-10A 2150660 1981270 ►/v-1oo 2010590 goo W 207 2030490 W-219 2101050 W-220 2101260 W-221 2110290 W-223 2110060 Thank you, Whitney Pettus (4//0 nute: A c:'ir Par lo) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinatorPBP.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoo@alaska.gov AOGCC.Inspectors(d).alaska.00v, phoebe.brooks@alaska.00v chris.wallaceaalaska.gov OPERATOR: BP Exploration(Alaska),Inc. y 1 �(I(r S FIELD/UNIT/PAD: Prudhoe Bay/GPB/V l DATE: 08/03/15 OPERATOR REP: Kevin Parks AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-100 ' Type Inj. W ', TVD 6,392' Tubing "1,855 '1,857 - 1,856 "1,858 Interval 4 P.T.D. 2010590 ' Type test P Test psi 1598 Casing 400 2,505 2,467 2,462 P/F P ' Notes: 4yr MIT-IA to 2500 psi OA 774 777 777 - 777• Pumped 1.7 bbls ambient diesel.Bled back IA to 100 psi Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval, P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi CasingP/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU V-100 08-03-2015.xls Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, July 12, 2015 2:26 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV;Wallace, Chris D (DOA); Shrider, James Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA); Pettus, Whitney Subject: UNDER EVALUATION:Injector V-100 (PTD #2010590) Place on Injection for Compiance Testing Attachments: image001.png; image002.png All, Injector V-100(PTD#2010590)was due for its AOGCC witnessed MIT-IA in April of 2015 and is now ready to be placed on injection. At this time the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus (.Illrrii(//c: h rin Po/As) BP Alaska-Well Integrity Coordinator SCANNED JUL 1 3 2015 G\ I WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: &C Well Integrity Coordinator Sent: Thursday, 09, 2015 2:34 PM To: AK, OPS GC2 OSM; S GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C W?tine OEerations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East-Wells Opt Engr; AK, OPS Well Pad LV; Shrider, James; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD WelII rity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alas . v' Subject: NOT OPERABLE: Injector V-100 (PTD #2010590) Due For AOGC T-IA All, 1 �\ Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, April 09, 2015 2:34 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV; Shrider,James;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: NOT OPERABLE:Injector V-100 (PTD#2010590) Due For AOGCC MIT-IA Attachments: image001.png;Injector V-100 (PTD#2010590) TIO plot.docx All, Injector V-100(PTD#2010590) is due for an AOGCC MIT-IA on April 25, 2015. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection, and will be added to the Quarterly Not Operable Injector Report. A copy of the TIO plot is included for reference. Kevin Parks (Alternate:Laurie Climer) BP Alaska-Well Integrity Coordinator si p APR 1 0 2015 GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 Injector V-100(PTD#2010590)TIO plot .11 V-110 4.030 • 1.000 t r —a—a 0014 —.-01 -a Oo11 MI5 0,.1415 111,21/15 O1%15 OVA1IS O.1115 @,20'S :22,5 03005 0111,5 030115 012715 010315 Imó ~. roject Well History File Cover.e XHVZE r This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. & 0 L - D 5C¡ Well History File Identifier Organizing (done) RES CAN Two-Sided 111111111111I111111 DIGITAL DATA ~ Diskettes, No. ~ 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: o Other, NofType NOTES: BY: BEVERLY ROBIN VINCENT SHERYLBvINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY o Rescan Needed 1/11/1111I1111/1111 OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner Logs of various kinds o Other ~ 1111111111I1//11111 t/l.1P Scanning Preparation .:3 x 30 = ~ + L = TOTAL PAGES '1~ BY: BEVERLY ROBIN VINCENT SHERy(0~ WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: -C¡r PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: L YES NO BY: BEVER,~OB~ ~CENT SHERYL MARIA WINDY DATE::¡-:3-Q3Sl';::::;b Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLySINCENT SHERYL MARIA WINDY DATE: 't-j-Q,3lSl ~ (;~~~I~~~~I~~~~~~~~~~ ~~RUI~:;~SS)ECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS 1/11/1 111111111111 ReScanned (inr/Í\tidual page [special <1Irenlion) .,canning complnted) 1/1111/111111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: lsl General Notes or Comments about this file: Quality Checked (done) 11/ "1111I1111111/1 12/1 OI02Rev3NOTScanned. wpd MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, April 26, 2011 Jim Regg ' P.I. Supervisor f ) 7 1 l'i' SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -100 FROM: John Crisp PRUDHOE BAY UN BORE V -100 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry . NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE V - 100 API Well Number: 50 029 - 23008 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110426123135 Permit Number: 201 - 059 - Inspection Date: 4/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 'Well v -loo ' Type Inj. W 'TVD 6392 ' IA 730 2530 ' 2500 2500 - P. T.D1 2010590' TypeTest SPT 1 Test psi 1598 ' OA 700 700 700 700 Interval 4YRTST per` P - Tubing 2650 2650 2650 2650 Notes: 1.2 bbls pumped for test i Siitin AA 4 201 s Tuesday, April 26, 2011 Page 1 of 1 ~ ~ bp BP Exploration (Alaska) Ina Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~;; ~~y ~~~E~~~~ A~'aa~~~~t1:~ ~~f1,! ~ ~ ~~~~~ ' OCT 4 ~ 20Q9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ 4il ~ Gas Cons. Cammia~einn 333 West 7t" Avenue Anchcrap~ Anchorage, Alaska 99501 ~ S Subject: Corrosion Inhibitor Treatments of GPB V-Pad ~b ~ ~ ~ ~~ ~d~ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- 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, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, 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) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 v-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-10t 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA t0.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233~00000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 5002923178ot00 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2o1 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29l2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-2t7 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7J12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "r'~^ 2080200 50029233830000 NA 1.75 NA ~b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 . . MEMORANDU~I State of Alaska Alaska Oil and Gas Conservation Commission TO: ,--, 1/ ., I Jim Regg J ",¿fef &(:;¡C7 P.I. Supervisor L ¿ DATE: :v1onday, "'fay 21,2007 SLBJECT: Mechanical Integnty Tests BP EXPLORA TIO"i (ALASKA) INC V-I00 PRUDHOE BAY UN BORE V-lOO ~\' OsC FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P,l. Suprv 58.2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-IOO API Well Number: 50-029-23008-00-00 Insp Num: rnitJCr070518101523 Rei Insp N um: Permit Number: 201-059-0 Inspector Name: John Crisp Inspection Date: 5/13/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~.~ ..._...._-~._--,-._.~._-~-~.._,-----._- ~l V-I00. ¡Type Inj. !~¡ TV~ _~=~_~~..~ 3020 ¡ 296~,:-_=960 i P.T.DI 2010590 jTypeTest : SPT, Test psi I 3000 ¡ OA I 480 ' 500 I 500 I' 500-1---- ---~---' _ ' -__._____._.._...,...--_.__~______.__.__.._.._.___L_-_._.._____~_~_.._~__~~_.,,__.__._ _____ _--Ì-__.___~ Interval OTHER PIF P ,/' Tubing ¡ 1550 1550 1550 1600 ____ '::.L.. __~._~~__. -.---.--~._- Notes: MIT IA for evaluation. 5~ JUN () 6 ZODi' Monday, May 21, 2007 Page I of I 12-19 (PTD#1821980), S-123 (PTD#20413,S-111 (PTD#20505... Jim, Tom and Bob - Please see the attached MIT forms for the following wells: 12-19 (PTD#1821980): CMIT TxlA and MITOA for variance compliance 8-123 (PTD#2041370): MITIA pre-MI swap 8-111 (PTD#2050510): MITIA for AA request V-100 (PTD#2010590): MITIA and MITOA for AA request /have also included the results from the V-100 OA gas sample. «MIT PBU 12-19 05-13-07.xls» «MIT PBU 8-123 05-13-07.xls» «MIT PBU 8-111 05-13-07.xls» «MIT PBU V-100 05-13-07.xls» «OAV100.doc» Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager-659-5100, 1154 sCANNED MAY 1 8 2007 Content-Description: MIT PBU 12-19 05-13-07.xls MIT PBU 12-19 OS-13-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 8-123 05-13-07.xls MIT PBU 8-123 OS-13-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 8-111 05-13-07.xls MIT PBU 8-111 OS-13-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 10f2 5/16/200710:30 AM 12-19 (PTD#1821980), S-123 (PTD#204137W-111 (PTD#20505... . Content-Description: MIT PBU V-lOO 05-13,.07.xls PBU V-I00 Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: OA VI00.doc OA VI00.doc Content-Type: application/msword Content-Encoding: base64 20f2 5/16/2007 10:30 AM . . ~~tt s/,þüÎ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well P.T.D. Notes: Well P.T.D. Notes: Well PTD. Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / V pad 05/13/07 Jack Winslow John Crisp Tubing Casing Pretest 1550 o o P o F TYPE TEST Codes M = Annulus Monitoring p:= Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU V-100 05-13-07-1.xls .. .. 'k . 907-659-5654 GPB LABORATORY ANALYTICAL REPORT Email: GPBLab@bp.com . Sample ID Collection Date Facility Location Analysis Name LINE PRES METHANE-MOL % ETHANE-MOL % PROPANE-MOL% I-BUTANE-MOL% N-BUTANE-MOL% I-PENTANE-MOL% N-PENTANE-MOL% C6P-MOL% C02-MOL% NITROGEN-MOL % MOL WEIGHT BTU GRSDRY IDEAL BTU GRSDRY REAL BTU GRSSAT IDEAL BTU NET SPG REAL 02CONTAM DISTRIBUTION: Ron Wilson Reported by: Analysis Unit PSIG MOL% MOL 0/0 MOL 0/0 MOL% MOL% MOL% MOL% MOL% MOL% MOL% BTU@14.696PSIA BTU@14.65 PSIA BTU@14.73PSIA BTU@14.696PSIA MOL% at 10:14 AM on 06/12/07 PC06837 05/13/07 V-PAD OA@V-I00 Combination Result 500 98.625 0.003 0.003 0.000 0.001 0.000 0.001 0.067 0.018 1.282 16.270 1000.5 999.3 985.4 900.0 0.5626 2.876 V-lOO (PTD #2010590) IA repressurization . Hello Jim and Tom, Well V-100 (PTD #2010590) is exhibiting indications of possible gas hydrates in the OA. The field Operator bled the OA from 960 psi to 400 psi on 05/09/07 with all gas returns. Also, the IA has exhibited pressure spikes on a few occasions over the course of the past 3 months. The current plan forward is to perform an MITIA and MITOA and sample the OA to evaluate for a possible hydrate formation. Depending on the results, we will pursue a AA for injection with a known cause of sustained casing pressure. During this evaluation the well will remain on injection and the IA will be monitored for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. «V-100 TIO plot.jpg» «V-100.pdf» Thank you - $CANNED MAY 1 8 2007 Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 Content-Description: V-IOO no plot.jpg TIO plot.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: V-IOO.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/16/2007 10:35 AM V-lOO TlO 640x259 J of! 6/2007 AM . TREE = 4-1/16"5MCIW WELLHEAD= 11" FMC AClUA TOR = KB. B.BI = 85.1' V-100 I SAFETY NOTES: BF. B.EV = 59.39' KOP= 3100' : "H 958' 1-19-5/8" TAM PORT COLLAR tv'ax Angle = 53 @ 4618' H7"TAM PORTCOLLAR I Datum MD - 7941' . I 2021' Datum lV D - 6600' SS . 2211' LJ4-1/2" t-ES X NIP, ID - 3.813" I 19-5/8" CSG, 40#, L-80 BTC, ID= 8.835" LJ 2735' ~ .. I Minimum ID = 3.725" @ 7787' I I 5073' 7" Mð.RKERJT(18') WI RA TAG I 4-112" HES XN NIPPLE GAS LIFT Mð.NDRB.S U I STI MD IND I DEV I TYÆ I VLV I LATCH PORT I DATE I 11 17556163071 13 I KBG-21 DMY I BK I 0 I 05/23/04 I . . I 7622' 1-14-112" HES X NIP, ID = 3.813" 1 ~ "" 7643' 1--7" x 4-1/2" BKR PREM PKR, D - 3.875" I ~ I I I 7671' 1-14-112" HESX NIP, ID =3.813" 1 I 7692' L J4-112" HES X NIP, ID - 3.813" I 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID- 3.813" lJ 7703' I , 1~4-112" UNIQUE OVERSHOT 1 I I I 7703' PERFORATION SUMMARY 7732' 1--4-1/2" HES X NIP, ID - 3.813" 1 REF LOG: I ANGLE AT TOP ÆRF: 11 @ 7944' 1-17" X 4-1/2" BKR 53 PKR, ID = 3.875" I f\bte: Refer to Production DB for historical perf data ~ ..:::, 7743' SIZE SPF NTERV A L Opn/Sqz DATE 2-1/2" 6 7944 - 7990 0 03/12/02 1--4-1/2 HESX NIP, D=3.813" I 2-1/2" 6 7998 - 8003 C 03/12/02 I 7767' 2-7115' 6 8080 - 8082 C 09/30/01 I 7787' 1-14-1/2" HES XN NIp' ID = 3.725" I 14-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 7798' 7800' r-l4-1/2" WLEG I [ I 7798' H ELMDTT LOGGED 09/30/01 I r[--i 7979' TOP OF SANDI 8039' 1-17" Mð.RKER JT (20') W/RA TAG 1 I FBTD 8303' 17" CSG, 26#, L-80, ID = 6.276" 8388' [)A. TE RBI BY COMMENTS 05130/01 CI-VTLH ORIGINAL COM PLETION 04/25/04 KAK RWO 09130/01 CWS/TLH A DD PERFS 03/12/02 TMN'TLH A DD PERFS 03120/02 CJS/KK SAND DUMP 05123/04 [)A.V/KAK GLV C/O 06/18/04 BJMcNIK PULL R.UGS [)A. TE REV BY COMMENTS BOREA LIS UNIT WELL: V-100 PERIII1IT No: 2010590 AA No: 50-029-23008 SEC 11, T11N, R11 E, 4714' NSL & 1531'WEL BP Exploration (Alaska) e e ~~, . ~,-.\ ' MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inscrts\Microfilm _ Marker. doc ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg y ql .~ P.I. Supervisor ~~~ Z(,1DIt DATE: Thursday, September 16, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-IOO PRUDHOE BAY UN BORE V-IOO ;tOI-o51 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: "'O/) P.I. Suprv .;j~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-1O API Well Number: 50-029-23008-00-00 Inspector Name: Lou Grimaldi f\ Insp Num: mttLGO40916100800 Permit Number: 201-059-0 Inspection Date: 9/14/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-lOO Type Inj. G TVD 6392 IA 0 4000 3970 3960 P.T. 2010590 TypeTest SPT Test psi 1598 OA 500 520 520 520 Interval !NIT AL P/F P Tubing 1200 1225 1275 1300 Notes: Thursday, September 16, 2004 Page 1 of 1 ,~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimulate 0 Abandon 0 OtherŒ) Convert to MI Alter CasingD Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate D Re-enter Suspended WeliD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D Exploratory 0 ~1-O5an 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ] 50-029-23008-00-00 7. KB Elevation (ft): 9. Well Name and Number: 83.60 V-100 8. Property Designation: 10. Field/Pool(s): ADL-o028240 Prudhoe Bay Field / Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 8405 feet true vertical 7138.5 feet Plugs (measured) None Effective Depth measured 8200 feet Junk (measured) None true vertical 6937.8 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Production 8362 7" 26# L-80 26 - 8388 26.0 - 7121.8 7240 5410 Sur1ace 2709 9-5/8" 40# L-80 28 - 2737 28.0 - 2736.7 5750 3090 Perforation depth: Measured depth: 7944 - 7979, 7979 - 7990, 7998 - 8003, 8080 - 8082 True vertical depth: 6686.79 - 6721.11,6721.11 - 6731.9, 6739.75 - 6744.65,6820.16 - 6822.12 RECEIVED Tubing ( size, grade. and measured depth): 4-1/2" 12.6# L-80 @ 23 - 7799 Packers & SSSV (type & measured depth): ~:';'~!'?/'I1 4-112" Baker PAM Packer @ 7643 I" ,4 4-112" Baker S-3 Perm Packer @ 7743 AIaata Oil & ,,- ~ " 12. Stimulation or cement squeeze summary: ~ -""" Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 0 0 -5620 Subsequent to operation: 0 -2.8 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations, ! OilD GasD WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1SUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-248 Printed Name Garry Catron Title Production Technical Assistant Signature Y1n ,. (.--~' Phone 564-4657 Date 9/7/04 n " Form 10-404 Revised 4/2004 OR\G\NAL RBDMS Bf L SEP 1 3 160~ ~ ~ V-100 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/30/04 Begin MI Pilot Program FLUIDS PUMPED BBLS :TOT AL No Fluids Pumped 0 Page 1 ~ 1REE = 4-1/16" 5M CrN WELLHEAD = 11" Ff\C ACTUATOR = 1<8. B.BI = 85.1' BF. B.EV = 59.39' KOP= 3100' MIx Angle - 53 @ 4618' Datum MD = 7941' Datum lVD = 6600'SS 9-5/fr' CSG, 40#, L-80 BTC, ID = 8.835" 2735' Minimum ID = 3.725" @ 7787' 4-112" HES XN NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpI, ID = 3.813" 7703' PERFORATION SUMMARY REF LOG: ANGLEATTOPFERF: 11 @7944' IIbte: Refer to Produetion DB lor historical perf data SIZE SA" NTERVAL Opn/Sqz DATE 2-1/2' 6 7944 - 7990 a 03112102 2-1/2' 6 7998 - 8003 C 03112102 2-7/fr' 6 8080 - 8082 C 09130/01 4-1/2" TBG. 12.6#, L-80, .0152 bpl,ID = 3.958" 7798' 8303' 8388' 7" CSG, 26#, L-80, ID = 6.276" ~ V-100 I SAFETY NOTES: 2211' 5073' 7732' 7743' 7767' 7787' 7800' 7798' O<\TE RBI BY COMMENTS O<\TE REV BY COMMENTS 05130/01 CIflLH ORIGINAL COM PLETION 04/25/04 KAK RWO 09130/01 CWSITLH ADD PERFS 03/12/02 TMN'TLH ADD PERFS 03/20/02 CJS/KK SA\{) DUMP OS/23/04 0<\ V/KAK GLV C/O 06/18/04 BJMcNA<~ PULL R.UGS 9-518" TAM PORT COLLAR 7"TAM PORTCŒ.LAR 4-1/2" HES X f',IP.lD = 3.813" 7" M<\RKERJT(18') W/ RA TAG 4-1/2" HES X f',IP,lD = 3.813" 7' X 4-1/2" BKR PREM PKR, D = 3.875" 4-1/2" HES X f',IP,lD = 3.813" 4-1/2" HESX f',IP,lD =3.813" 4-1/2" UNIQUE OVERSHOT 4-1/2" HES X f',IP,lD = 3.813" 7" X 4-1/2" BKR 53 A<R, ID = 3.875" 4-1/2 HES X f',IP, D = 3.813" 4-1/2" HES XN NIP, ID = 3.725" BOREALIS UNrr WELL: V-100 PERMrrNo: 2010590 AA No: 50-029-23008 SEC 11, T11N, R11 E. 4714' NSL & 1531'WEL BP Exploration (Alaska) \¡ i~ A- 47/3'0 J 'U'04. l:r'~1'JI'~:~~~ ~~~:l:'¡J' L':~ ',~ (>,' ,It..., ~K !:"""!J!J"~"~ :',' ¡r"," '""'$1:: \~,!? iC"" u " ( ['I ~;, ", . I' \ \V' ¡J I! 'I f STATE OF ALASKA ( '\""""",~" """"""6"/'30 ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 '3 2004 Ic:¡ APPLICATION FOR SUNDRY APPRQ,Y:AL::,;~~: 20 AAC 25.280 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend D RepairWell D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool 0 4. Current Well Class: PerforateD WaiverD Annular DisposalD StimulateD Time ExtensionD OtherOO Re-enter Suspended WellD Convert to Mllnj ~ 5. Permit to Drill Number: 201-0590 /- BP Exploration (Alaska), Inc. Development D Exploratory D StratigraphicD Service ŒJ / 9. Well Name and Number: V-100 ./ 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 8304 6956.1 Size MD TVD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 83.60 KB 8. Property Designation: ADL-028240 11. Total Depth MD (ft): 8405 Casing I Total Depth TVD (ft): 7138.5 Length Conductor Production Surface 80 8362 2709 top bottom top 20" 91.5# H-40 28 - 108 28.0 7" 26# L-80 26 - 8388 26.0 9-5/8" 40# L-80 28 - 2737 28.0 Perforation Depth MD (ft): 7944 - 7979 7979 - 7990 7998 - 8003 8080 - 8082 Packers and SSSV Type: 4.1/2" Baker PRM Packer 4-1/2" Baker S-3 Perm Packer Perforation Depth TVD (ft): 6686.79 - 6721.1 6721.11 - 6731.9 6739.75 - 6744.7 6820.16 - 6822.1 Tubing Size: 4.5 " 6. API Number / 50-029-23008-00-00 Plugs (md): Junk (md): None None Burst Collapse bottom 108.0 7121.8 2736.7 1490 7240 5750 470 5410 3090 12.6 # Tubing Grade: Tubing MD (ft): L-80 23 7799 Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: ExploratoryD DevelopmentD Detailed Operations Program ŒJ BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 7643 7743 Service ŒJ I Date: 15. Well Status after proposed work: Oil 0 1/ GasD PluggedD AbandonedD WAG '6ZJ GINJ~ WINJ D WDSPLD Prepared by Garry Catron 564-4657. BY ORDER OF ~~ J: THE COMMISSION Date: ~J~ ~, If' / ~ Bfl J-L ~ 6 7Ó04 June 30, 2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Bruce Smith Ú-)~ ~ Title Phone Petroleum Engineer 564-5093 ~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integri~ BOP TestO Other: Subsequen' ~ Approved by: I - / V - '" -- V Mechanciallntegrity Test 0 Location Clearance D ORIGINAL Form 10-403 Revised 06/2004 Bruce Smith 6/29/04 I Sundry Number: , ( / V--" 3D fL'-¿;)- yeJ SUBMIT IN DUPLICATE ( 1REE= 4-1/16"5MCIW WELLHEAD = 11" Frvc , ' , AClUA TOR = KB. 8..BJ = 'SF. Ëi.i3i= " KÒP= ' rv'ax Angle = ' Datum tvD "= oatum lV b'; 85.1' '59.39" 3100" , 53 @ 46"18" 7941' , 6600' SS 19-5/8" CSG, 40#, L-80 BTC, 10 = 8.835" U 2735' Minimum ID = 3.725" @ 7787' 4-112" HES XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.813" 1j 7703' PERFORATION SUMMARY REF LOG: ANGLE AT TOP ÆRF: 11 @7944' I\bte: Refer to Production DB for historical perf data SIZE SFF NTERVAL Opn/Sqz DA TE 2-1/2" 6 7944 - 7990 0 03/12/02 2-1/2" 6 7998 - 8003 C 03/12102 2-7/8" 6 8080 - 8082 C 09/30/01 ~~lBGJ--l2._6j¡!L-L~8_0, .0152 bpf, 10 =3.958" 1-1 7798' 1 RHO 1-1 8303' 17" CSG, 26#, L-80, 10 = 6.276" 1-1 8388' DA TE RBJ BY COMMENTS 05130/01 CHlTLH ORIGINAL COM PLETION 04/25/04 KAK RWO 09130/01 CWS/TLH A DO PERFS 03112/02 TMN'TLH A DO PERFS 03/20/02 CJS/KK SA NO DUrvP OS/23/04 DA V IKAK GL V C/O 06/18/04 BJMcNiKK PULL FLUGS ( ( V-100 ,/ I SAFEfYNOTES: I ~ 1 1 ~ . L I I ~ g I~ ~ I z z I , j II ~ DA TE REV BY COMMENTS 958' H9-5I8" TAM PORT COLLAR 2021' H7" TAM PORT COLLAR I 2211' 1-J4-1/2" I-ES X NIP, 10 = 3.81 3" I ~ 5073' H7" ~RKERJT(18') W/ RA TAG I GAS LIFT ~NDR8...S I STI MD I TVD I DEV I TYÆ I VLV I LATQ-II PORT I DATE I 1 7556 6307 13 KBG-2 DMY BK 0 OS/23/04 7622' U4-1/2" HES X NIP, 10 = 3.813" I 7643' 1'1 T' X 4-1/2" BKR PREM PKR, D = 3.875" I 7671' Ij4-1/2" HESX NIP, 10 =3.813" 1 7692' 1~4-1/2" HES X NIP, 10 = 3.813" 1 7703' Ij4-1/2" UNIQUE OVERSHOT I 7732' 1'14-1/2" HES X NIP, 10 = 3.813" 1 7743' 1-17" X 4-1/2" BKR S3 R<R, 10 = 3.875" 1 7767' 1-14-1/2 I-ES X NIP, D = 3.813" I 7787' 1-i4-1/2" HESXN NIP, 10= 3.725" I 7800' 1'14-1/2" WLFG 1 7798' 1-1 EUvOTT LOGGED 09/30101 I 7979' 1-1 TOP OF SA NO I 8039' H7" ~RKERJT(20') W/RA TAG I BOREA LIS UNIT WELL: V-100 PERMIT No: 2010590 AA No: 50-029-23008 SEC 11, T11N, R11 E, 4714' NSL & 1531' WEL BP Exploration (Alas ka) ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONI\ECEIVED M^Y 182004 0 Perforate A¡~tif& Gas Cons. Commission 0 Stimulate ~T¡me F~hchorage 0 Re-Enter Suspended Well 0 Annular Di 0 Suspend 0 Operation Shutdown II Repair Well 0 Plug Perforations II Pull Tubing 0 Perforate New Pool .. 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage. Alaska 7. KB Elevation (ft): 99519-6612 83.6' 4. Current Well Class: 5. Permit To Drill Number 0 Development 0 Exploratory 201-059 0 Stratigraphic Test lID Service 6. API Number: 50-029-23008-00-00 9. Well Name and Number: PBU V-100 8. Property Designation: 10. Field / Pool(s): ADL 028240 Prudhoe Bay Field / Borealis Pool 11. Present well condition summary Total depth: measured 8405 feet true vertical 7138 feet Plugs (measured) 7979 Effective depth: measured 7979 feet Junk (measured) None true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2709' 9-5/8" 2737' 2737' 5750 3090 Intermediate Production 8362' 7" 8388' 7122' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7944' - 8082' 6687' - 6822' Tubing Size (size. grade. and measured depth): Packers and SSSV (type and measured depth): 4-1/2". 12.6# L-80 7800' 4-1/2' Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 7743' 2209' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run lID Daily Report of Well Operations !HI Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development lID Service 16. Well Status after proposed work: 0 Oil 0 Gas 0 WAG lID GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Jim Smith. 564-5773 N/A Printed Name Terrie Hubble Signature ~!tI1;L. M~ Form 10-404 Revised 12/2003 Title Technical Assistant O~J B /, Prepared By Name/Number: Phoneo ~iGiN A ræ 7 ~;~ H"~.;4~. 8 ~ Well: Field: API: Permit: V-100 RWe Prudhoe Bay Field 50-029-23008-00-00 201-059 Accept: Spud: Release: Rig: 04/20/04 N/A 04/24/04 Nabors 7ES PRE-RIG WORK 04/05/04 T/I/O = 2100/2400/520 LOS/POT = ALL OK 450 FT-LBS. PPPOT-IC = 3500 PSI GOOD TEST. PPPOT-T = 5000 PSI GOOD TEST. 04/12/04 PULLED ECLIPSE PATCHES FROM 5870' SLM AND 7619' SLM. 04/13/04 PULL ECLIPSE BOTTOM SEAL ASSEMBLY FROM 7652 SLM. SET 41/2 XXN PLUG @ 7760 SLM, FLUID LEVEL @ 100' SLM, 750 PSI ON WELL WHEN SET. SET 41/2 XX PLUG @ 7740 SLM. FLUID @ 200' SLM, 700 PSI WHEN SET, BLED DOWN TO 200 PSI, AND HOLDING. PULL 41/2 XX PLUG @ 7740 SLM. PRESSURE TEST XXN PLUG, SET 41/2 XX @ 7740 SLM, SET JUNK BASKET. RIGGING DOWN. 04/14/04 FIRED TUBING PUNCHER FROM 7684-7686 AND SHOT STRINGSHOT FROM 7691-7703 IN PREPARATION FOR CHEMICAL CUTTER. TAGGED TD @ 7760 W/ TUBING PUNCHER. NO PROBLEMS RIH OR POOH. 04/15/04 CHEMICAL CUT TUBING AT 7702' MD IN THE MIDDLE OF THE ONLY FULL JOINT BETWEEN THE NIPPLE AT 7732 AND THE MANDREL AT 7666' MD. DID NOT TAG TO, NO PROBLEMS RIH OR POOH. LEFT WELL SHUT IN. 04/16/04 TIO=100/0/500 CIRC OUT WELL FOR RWO. PUMPED 10 BBLS NEAT METHANOL, 357 BBLS SEA WATER, 80 BBLS DIESEL DOWN TUBING TAKING RETURNS UP I.A. TO FLOWLINE ON V-117. U-TUBE DIESEL FOR ONE HOUR. FREEZE PROTECTED JUMPER LINE WITH 5 BBLS NEAT METHANOL. CANNOT BLEED GAS OFF O.A. BECAUSE WIND IS BLOWING DIRECTLY AT NABORS RIG 7ES. CMIT TBG X I.A. TO 3000 PSI. PUMPED 3.4 BBLS DIESEL TO TEST, LOSS OF 50 PSI 1ST 15 MIN & 50 PSI IN 2ND 15 MIN.FAIL. 2ND TEST PASSED WITH A LOSS OF 30 PSI 1ST 15 MIN. AND A LOSS OF 10 PSI 2ND 15 MIN. RIGGED UP TO O.A. TO MIT TO 2000 PSI. 1 ST TEST FAILED WITH A LOSS OF 600 PSI 1 ST 15 MIN. 2ND TEST FAILED WITH A LOSS OF 300 PSI 1ST 15 MIN. 3RD TEST FAILED WITH A LOSS OF 200 PSI 1ST 15 MIN. 4TH TEST FAILED WITH A LOSS OF 200 PSI. 1ST 15 MIN. 5TH TEST FAILED WITH A LOSS OF 200 PSI 1ST 15 MIN. 6TH TEST FAILED WITH A LOSS OF 200 PSI 1ST 15 MIN., 7TH TEST FAILED WITH A LOSS OF 200 PSI 1ST 15 MIN., 8TH TEST PASSED 1ST 15 MIN. WITH A LOSS OF 80 PSI., FAILED 2ND 15 MIN WITH A LOSS OF 60 PSI., 9TH TEST PASSED WITH A LOSS OF 40 PSI 1ST 15 MIN., AN 0 A LOSS OF 20 PSI 2ND 15 MIN.PASS. BLEED OA BACK TO 500 PSI. FW'p= 0/0/150 04/18/04 T/I/O = BPV/0/380, TEMP = SI. BLEED OA PRE-RIG. WIND DIRECTION IS DIRECTLY TOWARD RIG - UNABLE TO BLEED TO ATMOSPHERE. OA FL @ 145'. 04/19/04 T/I/O = SSV+BPV/0/390, TEMP = SI. BLEED OA (PRE-RIG). BLED OA FROM 390 PSI TO 190 PSI IN 1 HOUR 30 MINUTES (WENT TO FLUID IN 30 MINUTES) - RETURNED 5.5 BBLS. MONITORED WHPS 20 MINUTES DURING RIG DOWN. OAP INCREASED 25 PSI. FINAL WHPS = SSV+BPV/0/215. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-100 V-100 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 4/15/2004 Rig Release: 4/24/2004 Rig Number: 7ES Spud Date: 4/29/2001 End: 4/24/2004 4/20/2004 12:00 - 13:30 1.50 MOB P PRE 13:30 - 15:30 2.00 MOB P PRE 15:30 - 19:30 4.00 MOB P PRE 19:30 - 20:00 0.50 RIGU P PRE 20:00 - 21 :00 1.00 RIGU P PRE 21 :00 - 23:00 2.00 RIGU P PRE 23:00 - 00:00 1.00 WHSUR P DECOMP 4/21/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 04:00 3.00 CLEAN P DECOMP 04:00 - 04:30 0.50 WHSUR P DECOMP 04:30 - 06:00 1.50 WHSUR P DECOMP 06:00 - 08:30 2.50 BOPSUF P DECOMP 08:30 - 11 :30 3.00 BOPSUF N RREP DECOMP 11 :30 - 13:00 1.50 BOPSUF P DECOMP 13:00 -19:30 6.50 BOPSUP P DECOMP 19:30 - 20:00 0.50 BOPSUF P DECOMP 20:00 - 21 :00 1.00 DHB P DECOMP 21 :00 - 22:00 1.00 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:30 1.00 CASE P DECOMP 23:30 - 00:00 0.50 PULL P DECOMP 4/22/2004 00:00 - 01 :00 1.00 PULL P DECOMP 01 :00 - 08:00 7.00 PULL P DECOMP Prepare for Rig Move. Disconnect Fluid & Electrical connections to Pit Complex. Clean out Cuttings tank. Move Pit complex. Set Mats & Herculite for V-1 00. Move Rig from V-119 to V-100. Spot Sub. Remove ladder from V-115 well house. Set Pit Complex. Berm Cellar. Hook up all interconnects to Pit Complex. Set Cuttings Tank & Mud Shack. ACCEPT RIG @ 21 :00 HRS 4/20/2004. Take on Heated seawater to Pits. Rig up Circulating Lines to Tree. Check pressures: '0' on lA, 200 psi on OA. R/U DSM Lubricator. Pull BPV. RID DSM Lubricator. '0' Pressure on Tubing. Rig Up Drip Pan in Cellar. Complete RlU Circ Lines. Pressure Test Line to Annulus to 3500 psi. Reverse Circulate 44 Bbls. Diesel out of Tubing. Switch Pumps & pressure test Line to Tubing to 3500 psi. Circulate Annulus free of diesel and continue to circulate - 275 Bbls. Total Pumped On Annulus @ 3 BPM 1 300 psi. Pumped On Tubing 3 BPM 1100 psi. Pumped heated seawater. Monitor Well - Static - Dead. FMC Rep Dry Rod TWC. Test to 1000 psi from below. N/D Adapter Flange & Tree. Inspect Hanger & Lifting Threads. N/U BOPE Change out Door on Lower Pipe Rams - Operating Fluid Leaking through Weephole. R/U Kill Line, Hook up Turnbuckles, Fill Stack & Choke Manifold. Test BOPE. 250 psi. Low 14000 psi High, Annular to 3500 psi. Test Witnessed by Lou Grimaldi, AOGCC. Blow Down Choke & Kill Lines. RID Test Equipment. RlU DSM Lubricator & Pull TWC. RID Lubricator C/O Elevators, R/U TO Hose. M/U XO's to DP and screw into Hanger. M/U to Top Drive. Pull Tubing hanger to Floor. P/U Weight - 110K. Monitor Well - Static. Pump down tubing 5 BPM 1 300 psi to clear air from lines. Fill Kill Line. Close Upper pipe Rams & Test 7" Casing to 4000 psi. Hold & Chart Test for 30 Minutes. Bleed pressure. Pump Slug. B/O & UD Landing Jt. & XO's. UD Hanger, 1st Jt & 3 Space out pup Jts. R/U Compensator & Single Jt. Elevators. POH Laying Down 4.5",12.6#, L-80, NSCT Tubing. NORM inspecting on Location. 1 to 5 Rems 1 Hr. Trucking to Tuboscope for cleaning, inspection & re-doping. Total 189 Jts, 2 GLM's, 1 'X' Nipple, 3 Space - out Pups & 19.24" Cut-Off Jt. Printed: 4/30/2004 1:48:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-100 V-100 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 4/15/2004 Rig Release: 4/24/2004 Rig Number: 7ES Spud Date: 4/29/2001 End: 4/24/2004 4/22/2004 08:00 - 08:30 0.50 PULL P DECOMP RID 4.5 Tbg Equip., c/o Bails. 08:30 - 09:30 1.00 BOPSUF P DECOMP R/U & Test Lower Pipe Rams to 250 psi-Low & 4000 psi High. RID Test Equip. 09:30 - 11 :00 1.50 CLEAN P DECOMP PJSM. Bring Baker Dressing Mill, 7" Scraper & other BHA Tools to Floor. M/U BHA & RIH. 11 :00 - 12:30 1.50 CLEAN P DECOMP RIH, P/U 21 Jts HWDP from Shed. 12:30 - 15:30 3.00 CLEAN P DECOMP RIH to 7700 SLM. No Problems. 15:30-16:00 0.50 CLEAN P DECOMP Break Circulation. Work over & Dress Tubing Stub @ 7702' wI 80 RPM @ 500 GPM & 2570 psi. Work down to 7710'. Work on and off with no rotation & no pump. 16:00 - 17:00 1.00 CLEAN P DECOMP Circulate Hi - Vis sweep. Pumping @ 495 GPM 12400 psi wI 100 RPM. Shut down & went over stub twice again. Set down 10K. No Problems. 17:00 - 23:00 6.00 CLEAN P DECOMP POH, LID all 4" DP. 23:00 - 00:00 1.00 CLEAN P DECOMP Continue POH LID HWDP. 4/23/2004 00:00 - 01 :30 1.50 CLEAN P DECOMP Break out & LID Baker Mill, Scraper, Bumper Sub, Jars & other BHA Tools. Clear Rig Floor. Pull Wear Bushing 01 :30 - 05:30 4.00 RUNCOIvP COMP R/U to run 4.5" Completion. Load pipe shed wI Tubing. Number, Drift & Strap 99 Jts on ODS of Shed. 05:30 - 18:30 13.00 RUNCOIvP COMP P/U Unique Overshot Tail Assy. Run 4.5" 12.6#, L-80, NSCT Completion String as per program. Up Weight = 110,000 Lbs. Slack Off = 85,000 Ibs. 18:30 - 19:00 0.50 RUNCOIvP COMP R/U and Circulate overshot down over tubing Stub. Good indication when bottomed out. 19:00 - 20:30 1.50 RUNCOIvP COMP Measure out for space out. M/U space out Pup, Hanger & Landing Jt.. 20:30 - 22:00 1.50 RUNCOIvP COMP Displace with Clean Filtered Seawater & spot Corrosion Inhibitor. 22:00 - 00:00 2.00 RUNCOIvP COMP Land Hanger, R.I.L.D.S. & Torque to 450 ftllbs. Drop Roller BallI Rod Assy. Pressure tubing to 4500 psi. to Set Premier packer. bleed to 4000 psi. Hold and Chart for 30 minute Test. Bleed tubing to 2000 psi. Pressure Annulus to 4000 psi. - Hold & Chart for 30 minute Test Bleed Annulus tto '0', the tubing to '0'. Pressure Annulus to 3000 psi to shear DCK valve. 4/24/2004 00:00 - 00:30 0.50 RUNCOIvP COMP BIO Landing Jt and LID. Blow down lines 00:30 - 01 :00 0.50 BOPSUF P COMP Dry Rod TWC and test to 1000 psi from Below. 01 :00 - 02:30 1.50 BOPSUF P COMP Nipple Down BOPE. 02:30 - 04:30 2.00 WHSUR P COMP N/U Adapter Flange & Tree. 04:30 - 05:00 0.50 WHSUR P CaMP Test Adapter flange & Tree to 5000 psi. 05:00 - 05:30 0.50 WHSUR P COMP R/U DSM Lubricator. Pull TWC. RID DSM Lubricator. 05:30 - 06:30 1.00 RUNCOIvP COMP R/U Little Red. Test Lines to 3500 psi. Reverse Circulate spotting 74 Bbls. Diesel in Annulus. 06:30 - 07:30 1.00 RUNCOIvP COMP Allow diesel to U-Tube: Frereze Protecting Tubing & Annulus to Printed' 4/30/2004 1:48:37 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-100 V-100 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 4/15/2004 Rig Release: 4/24/2004 Rig Number: 7ES Spud Date: 4/29/2001 End: 4/24/2004 4/24/2004 06:30 - 07:30 07:30 - 08:00 08:00 - 09:00 1.00 RUNCOtvP 0.50 RUNCOtvP 1.00 RUNCOtvP COMP COMP COMP 2200' MD Set BPV. Test from Below to 1000 psi. Suck out Pits, Secure Tree & Cellar. RELEASE RIG @ 09:00 Hrs. 4/24/2004 Pnnted. 4/30/2004 1 :48:37 PM lREE= 4-1/16"5MCIW WELLHE;AD = 11" FfItC AClUA TOR = 1<8. 8..81 = BF. 8..EV = KOP= Max Angle = Ißtum M) = Ißtum 1VD= V-100 I SAFEl'YNOTES: 85.1' 59.39' 3100' 53 @ 4618' 7941' 6600' SS From Drllin~ ~ ~~ 958' 2021' H9-5I8" TAM PORT COLLAR H7"TAM PORT COLLAR I 2210' H4-1/~" I-ESX NlP,ID = 3.813" 19-518" CSG, 40# L-80 BlC, 10 = 8.835" H 2735' r---- ~ Minimum ID = 2.24" @ 5925' ECLIPSE PATCH FERFORA lION Sllv1MARY RB= LOG: --- ANGLE AT TOPPffiF: 11 @7944' Note: Refer to Production œ for historical perf data SIZE SPF INlERVAL OpnlSqz DATE 2-112" 6 7944 - 7990 0' 03/12/02 2-112" 6 7998 - 8003 C 03/12/02 2-718" 6 8080 - 8082 C 09/30/01 . 5073' H7" MAR<ERJT(18') W/ RA TAG I L GAS LIFT MAI'DR8..S ISTI M) IlVDDBlITYÆ VLV ILATQ;PORT DATE I 1 7555 6306 12 KBG-2 CCK BEK 0 04/24/04 r l I 77(12.' LJ Q;EM aJT lBG I ~ 7709' LJUNCUEOVER:)I-OT I 7732' H4-1/2" I-ES X NIP, 10 = 3.813" I :8: :& 7743' H7" X 4-1/2" BKR 5-3 FRK, 10 = 3.875" I 7767' H4-1/2 I-ES X NIP, D = 3.813" I 7787' H4-1/2" I-ES XN NIp, 10 = 3.725" I 14-1/2" lBG, 12.6#, L-80 NSCT, H .0152bpf,ID= 3.958" I 7798' I 7800' H4-1/2"WLB31 7798' H ELM)TT LOGGBJ 09/30101 I 7979' HTOPOF SANDI 8039' H7" MAR<ERJT(20') W/RA TAG I ~ 8303' I ~ 8388' ~ 17" CSG, 26#, L-80, 10 = 6.276" H I)!\ TE RBI BY COMl.18'1TS 05130/01 CWTLH ORIGINAL COM PlErION 09130/01 CWSITLH A DO PffiFS 03/12/02 TMi'VTLH A DO PffiFS 03120/02 CJS/KK SAI'D [XJtvP 04,Q1/02 JBlKAK GLV C/O 04/16/02 TUflLH ÆRF CORRECTIONS 04/10/03 DRS/lP lV D'MD CORREClIONS I)!\ lE REV BY COMM:NTS 08108103 JCMIlLP GLV C/O 09/13/03 DACIlLP GLV CHANGES 11/01/03 CJSIlLP EO-IPSE FV\ lCHES 03/11/04 MJAIlLH PlU,RESET PA lCH (03/01/04) 04114104 JLJ/KA K PU..L PA lCl-ES 04114104 LOOKAK TBG RJNQ;; CHEM aJTTBG 04124104 AM TBG swap. Overshot and packer BOREALIS LNIT WELL: V-100 PERMIT No: 20 10590 AR No: 50-029-23008 SEC 11, T11N, R11 Eo 4714' NSL & 1531'WEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I'""" ~ 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 2. Operator SuspendD Repair Well 0 Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New PoolD 4. Current Well Class: Perforate 0 WaiverD OtherŒJ Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 Convert to Injector 5. Permit to Drill Number: 201-0590 Name: BP Exploration (Alaska), Inc. 83.60 8. Property Designation: ADL-o028240 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: V-100 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ExploratoryD ServiceŒ 6. API Number 50-029-23008-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 8405 feet true vertical 7138.5 feet Plugs (measured) None Effective Depth measured 8200 feet Junk (measured) None true vertical 6937.8 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 108 28.0 - 108.0 1490 470 Production 8362 7" 26# L-80 26 - 8388 26.0 - 7121.8 7240 5410 Surface 2709 9.5/8" 40# L-80 28 - 2737 28.0 - 2736.7 5750 3090 Perforation depth: Measured depth: 7944 - 7979, 7979 - 7990, 7998 - 8003, 8080 - 8082 Tubing ( size. grade. and measured depth): 4-1/2" 12.6# L-80 @ 23 7799 RECE\VED APR 2 9 1004 Commission 0'\ & Gas Cons. A\aska' Anthoragl True vertical depth: 6686.79 - 6721.11,6721.11 - 6731.9,6739.75 - 6744.65, 6820.16 - 6822.12 Packers & SSSV (type & measured depth): 4-1/2" Baker 5-3 Perm Packer @ 7743 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 399 Representative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0 0.2 0 119 -1732 2100 Tubing Pressure 328 1732 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development 0 ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilD GasD WAG 0 GINJD WINJOO WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: 303-359 Daily Report of Well Operations. .. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron l3a¡- ~ Title Production Technical Assistant Signature Phone 564-4657 Date 4/29/04 Form 10-404 Revised 12/2003 RBDMS Sf L ~~ 3 0 zou~ " ,-...., ~ BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp 0 April 9 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: V-100 (PTD 2010590) Cancel Sundry #303-350 Dear Mr. Aubert: Attached is Report of Sundry Well Operations form 10-403 for well V-100. This request is to cancel Sundry number 303-350 allowing injection with tubing by inner annulus communication. The well has been shut-in and a rig workover is scheduled for late April. If you require any additional information or clarification, please contact either Anna Dube or Joe Anders at (907) 659-5102. Sincerely, J¡£ (L~ Joe Anders, P.E. Well Integrity Coordinator Attachments 1) Report of Sundry Well Operations form 10-403 RECEIVED APR 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage . "......., r'\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator SuspendD Repair WeliD Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionD Re-enter Suspended WeliD OtherlXl Cancel Sundry Name: BP Exploration (Alaska), Inc. 5. Permit to Drill Number: 201-0590 83.60 8. Property Designation: ADL-o028240 11. Present Well Condition Summary: Development D StratigraphicD 9. Well Name and Number: V.100 10. Field/Pool(s): Prudhoe Bay Field I Borealis Oil Pool ExploratoryD ServiceŒj 6. API Number 50-029-23008.00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 8405 feet true vertical 7138.5 feet Effective Depth measured 8200 feet Plugs (measured) Junk (measured) None None true vertical 6937.8 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 . 108 28.0 . 108.0 1490 470 Production 8362 7" 26# L-80 26 - 8388 26.0 - 7121.8 7240 5410 Surface 2709 9-5/8" 40# L-80 28 - 2737 28.0 - 2736.7 5750 3090 Perforation depth: Measured depth: 7944 . 7979, 7979 . 7990, 7998 . 8003, 8080 . 8082 True vertical depth: 6686.79.6721.11,6721.11 - 6731.9,6739.75.6744.65,6820.16.6822.12 Packers & SSSV (type & measured depth): 4.1/2" 12.6# L-80 @ 24 2.3/8" 4.7# L.80 @ 5897 2-3/8" 4.7# L-80 @ 7648 4-1/2" Baker 5-3 Perm Packer @ 4.1/2" Eclipse Patch Packer @ 4.1/2" Eclipse Patch Packer @ 4.1/2" Eclipse Patch Packer @ 4.1/2" Eclipse Patch Packer @ 7800 5927 7678 RECEIVED APR 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage Tubing ( size, grade, and measured depth): 7743 5897 5923 7648 7674 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS Sf L APR 1 3 10"~ Oil-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Met I Water-Bbl Casing Pressure Well Shut.ln Tubing Pressure 13 Prior to well operation: Subsequent to operation: Well Shut-In 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 QilD GasD WAG D GINJD WINJŒJ WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: 303-350 Title Well Integrity Coordinator Daily Report of Well Operations - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders 1 Anna Dube Printed Name Joe Anders, PE Jtd ~ Form 10-404 Revised 12/2003 Phone (907) 659.5102 O!i I GI NAL Date 4/8/04 Signature STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Suspend 0 Repair WellŒ Pull Tubing D Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 VarianceD Annular DisposalD Stimulate D Time Extension 0 OtherD Re-enter Suspended WellO 5. Permit to Drill Number: 201-0590 2. Operator E Name: BP Exploration (Alaska), Inc. 3. Address: I P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 83.60 8. Property Designation: ADL-0028240 11. Present Well Condition Summary: Total Depth measured 8388 true vertical Effective Depth measured true vertical Casing Conductor Liner Production Length 80 8362 2109 1121.8 feet 8200 6931.8 feet Development ŒJ Stratigraphic D 9. Well Name and Number: V-100 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool Exploratory D Service D 6. API Number 50-029-23008-00-00 feet Plugs (measured) None feet None Junk (measured) Size 20" 91.5# H-40 1" 26# L-80 9-5/8" 40# L-80 MD TVD Burst Collapse 28 - 108 28.0 - 108.0 1490 410 26 - 8388 26.0 - 1121.8 1240 5410 28 - 2131 28.0 - 2136.1 5150 3090 Perforation deDth: Measured depth: 1944 - 1919, 1919 - 1990, 1998 - 8003,8080 - 8082 True vertical depth: 6686.19 - 6121.11, 6121.11 - 6131.9, 6139.15 - 6144.65, 6820.16 - 6822.12 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 2-3/8" 4.1# L-80 2-3/8" 4.1# L-80 @ @ @ RECEIVED DEC - 4 .ZO03 24 - 5891 - 7648 - 1800 5921 1618 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" Baker $-3 Perm Packer @ @ @ @ @ 5891 5923 1648 Alaska Oil & Gas Cons. Commission 1614" 1143 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Daily Averaqe Production or Injection Data Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 399 226 119 0 2161 0 0 0 150 1400 Copies of Logs and Surveys run - 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ] Service D 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. un ry um er or Daily Report of Well Operations - ! 17. I hereby certify that the foreQoinQ is true and correct to the best of my knowledQe. . . xempt: Contact Printed Name Signature Title Production Technical Assistant Phone 564-4657 te 12/3/03 RBDMS BFL V-100 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/03/03 Sand plug removed @ 78881-8200' 08/05/03 DfT W /3.5 CENT TEL SB to 8064 08/05/03 Perform Static Survey 08/07/03 T/I/O=0/1300/550n- Load and Test IA for Slickline (Did Not Pressure Up-nFinal WHp1s= 700/1 00/600 08/07/03 Dummy off Station 1,2 10/03/03 DRIFT W/ 362in CENT & S. BAILER TO T.D 80121 SLM. (DESIRED WAS 79791) (S. BAILER EMPTY) 10/03/03 T/I/O=750/125/570 Well SI on arrival. Assist Slickline with brush & Flush. Pumped 54 bbls of diesel down tubing @ 180*. After slickline set D&D Holefinder pumped 4 bbls of diesel to MIT. Three consecutive CMITs TxlA failed Fourth MIT passed. Slickline reset D&D Holefinder, MIT- T PASSED @ 1000 psi. Final WHp1s- 200/175/600. 10/09/03 T/I/O = SI/40/550. Bleed OAP to <300 psi. (Remove From High lAP Report). OA FL @ 401. Bled OA from 550 psi to 180 psi in 35 min. Bled all gas until OAP reached 180 psi. Some fluid to surface. SI bleed and monitored for 30 min. OAP increased 40 psi during monitor. Final WHpis = SI/40/220. 10/11/03 T/I/O=SI/200/520. MONITOR WHpIS. POST BLEED. (CONVERT TO INJ). lAP INCREASED 160 PSI, AND OAP DECREASED 30 PSI IN TWO DAYS. WELL HAS DOUBLE VALVE ON THE lA, AND HAS NO WELL HOUSE. 10/12/03 T/I/O = 325/200/500. MIT OA @ 2000 PSI W/ 19.3 BBLS OF DSL FAILED. LLRT = 0.35 BPM @ 2000 PSI W/ 10 BBLS OF DSL. T/I/O = 325/200/380. 10/13/03 T/I/O = SSV/11 0/300. MONITOR WHPS POST MITOA. OAP DROPPED 80 PSI OVERNIGHT. 1 0/21 /03 WELL SHUT IN PRIOR TO ARRIVAL DRIFT W/4.5" DUMMY PATCH - SET DOWN IN "XN" NIPPLE @ 77831SLM *****TARGET DEPTH IS (76511-76781) ***** LEFT WELL SHUT IN** 10/31/03 SET THE FIRST OF TWO ECLIPSE 4.5" TUBING PATCHES FROM 76481-76781 (DEPTHS REF'D TO TUBING TALLY DATED 19-MAY-2003) MIN ID THRU PATCH: 2.2411. NO TA. **** LEAVE SI FOR 2ND PATCH SET. **** 11/01/03 SET ECLIPSE 4.5" TUBING PATCH FROM 5897'-59271 (SECOND PATCH), DEPTH REFERENCED TO TUBING TALLY DATED 19-MAY-2003. PATCH ID: 2.24". DID NOT TAG TD. PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 11/02/03 T/I/O=440/280/420. TEMP=SI. IA FL POST PATCH. (PREP FOR MITIA). IA FL @ SURFACE. BLED 1 GALLON OF FLUID (LOOKED LIKE METHANOL, AND SOME GREASE) IN TO A BUCKET. WELL HAS AIL SI, AND NO WELL HOUSE. 11/03/03 TIO= 450/200/400. IA FL @ SURFACE. 11/03/03 TIO=500/200/400 MIT LA. TO 3000 PSI. FAILED PUMPED 2.8 BBLS CRUDE TO REACH 3000 PSI AND PATCH LET GO. FINAL PRESSURES TIO=550/360/400 11/04/03 TIO=460/200/400 INJECTIVITY TEST ON LA. TO 3000 PSI. PUMPED 50 BBLS DIESEL @ 4.6 BPM = 3000 PSI FOR 25 BBLS . FINAL PRESSURES=650/500/400 Page 1 V-100 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/09/03 LOG BASELINE DOWN PASS FROM SURFACE TO 79801. LOGGED UP 79801 TO 50001 PUMPING DIESEL DOWN IA @ 1 BPM AFTER 25 BBLS AWAY. LEAK FOUND AT THE BOTTOM OF THE UPPER PATCH, 5927'. 1 DEGF CHANGE AT 80' PUP JOIN, SUSPECT CONDUCTOR PIPE EFFECT. RDMO. WELL LEFT SHUT IN. LOG BASELINE DOWN PASS FROM SURFACE TO 79801. LOGGED UP 7980' TO 50001 PUMPING DIESEL DOWN IA @ 1 BPM AFTER 25 BBLS AWAY. LEAK FOUND AT THE BOTTOM OF THE UPPER PATCH, 5927'. 1 DEGF CHANGE AT 80' PUP JOIN, SUSPECT CONDUCTOR PIPE EFFECT. RDMO. WELL LEFT SHUT IN. BBLS 651 2% XS KCL 80 FlaPra 349 Methanal 158 Inhibited Seawater 394 Diesel 2.8 Crude 1634.8 TOTAL FLUIDS PUMPED Page 2 lREE = 4-1/16" 5M crvv WELLHEAD = 11" FMC AClUA TOR = KB. B..B.! = 85.1' BF. B..EV = 59.39' KOP= 3100' Max Angle = 53 @ 4618' Datum M) = 7941' Datum lV D = 6600'SS V-100 19-5/8" CSG, 40# L-80 BTC, ID = 8.835" I 2735' Minimum ID = 2.24" @ 5925' EC LlPSE PATCH ÆRFORA 1l0N SUMtv\I\RY REF LOG: ---------- ANGLE AT TOP PERF: 11 @ 7944' Note: Refer to Produetion 00 for historieal perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-112" 6 7944 - 7990 0 03/12/02 2-112" 6 7998 - 8003 C 03/12/02 2-718" 6 8080 - 8082 C 09/30/01 4-1/2"lBG, 12.6#, L-80 NSCT, .0152bpf, ID = 3.958" 7798' I A31D I 8303' 17" CSG, 26#, L-80, ID = 6.276" I 8388' I SAFETY NOTES: 958' 9-5/8" TAM PORT OOLLAR 2021' 7" TAM PORT COLLAR 2209' 4-112" HES X NIP, ID = 3.813" GAS LIFT tv\I\NDRB..S ST M) TVD DB.! TYPE VL V LA Ta-I PORT 2 5915 4931 50 KBG-2 *DMY BK 0 1 7666 6329 14 KBG-2 *DMY BK 0 ** STA 1l0N # 1 & 2 = Dlv1Ys HAVE EXTENDED PACKING DATE -..08/07/03 -08/07/03 5073' 5897'-5927 7648'-7678' 7732' 7743' 7767' 7787' 7" tv\I\ RKER JT (18') W/ RA TA G 4-1/2" EO-IPSE PA TCH, ID= 2.24" SET 11/01/03 4-1/2" EO-IPSE PA TCH, ID = 2.24" SET 11/01/03 --14-1/2" HES X NIP, ID = 3.813" I -17" X 4-1/2" BKR 5-3 ffiK, ID = 3.875" I --14-1/2 I-ES X NIP, D = 3.813" I -14-1/2" HES XN NIP, ID = 3.725" I 7800' --14-1/2" WLEG I 7798' 1-1 ELMD TT LOGGB:> 09/30/01 I 7979' --I TOP OF SAND I 8039' -17" tv\I\RKERJT (20') W/RA TAG I DATE REV BY COMMENTS DATE REV BY OOMMENTS 05/30/01 CHltlh ORIGINAL COMPLETION 04/10/03 DRS/TP lV [}IMD CORREC1l0NS 09/30/01 ON S/tlh ADD PERFS 08/08/03 JCM'TLP GL V C/O 03/12/02 TMf\Vtlh ADD PERFS 09/13/03 DA CJTLP GL V CI-V\ NGES 03/20/02 CJSiKK SAND DUMP 11/01/03 CJSlTLP ECUPSEPATa-IES 04/01/02 JB/KA K GL V C/O 04/16/02 1LHffLH PERF CORREC1l0 NS BOREALIS UNIT WB..L: V-100 ÆRMT No: 201059 API No: 50-029-23008 SEC11, T11N, R11E,4714' NSL& 1531' WEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 W61t I 2-/ lIP I ZOO 3 D rJ5 I 2/1 /;'/3 '?f (~f 17 1. Type of Request: D Suspend D Operation Shutdown 0 PerforateD VarianceD Annular Disposal D Abandon Alter Casinq 0 Repair Well 0 Pluq Perforations 0 StimulateD Time Extension 0 OtherŒJ Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 Injector Conversion 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 201-0590 Development 00 Exploratory D 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 Service D 50-029-23008-00-00 7. KB Elevation (ft): 9. Well Name and Number: 83.60 KB V-1 00 8. Property Designation: 10. Field/Pool(s): AD L-0028240 Prudhoe Bay Field I Borealis Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 8388 7121.8 8303 6955.1 None None Casing Length Size MD TVD Burst Collapse too bottom top bottom Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Production 8362 7" 26# L-80 26 - 8388 26.0 - 7121.8 7240 5410 Surface 2709 9-5/811 40# L-80 28 - 2737 28.0 - 2736.7 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7944 - 7979 6687 - 6721.1 4.5 II 12.6 # L-80 24 - 7800 7979 - 7990 6721 - 6731.9 2.375 II 4.7 # 5897 - 5927 7998 - 8003 6740 - 6744.7 2.375 II 4.7 # 7648 - 7678 8080 - 8082 6820 - 6822.1 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/211 Baker S-3 Perm Packer 7743 4-1/2" Eclipse Patch Packer 5897 4-1/2" Eclipse Patch Packer 5923 4-1/2" Eclipse Patch Packer 7648 4-1/2" Eclipse Patch Packer 7674 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D DevelopmentD Service ŒI 14. Estimated Date for December 3, 2003 15. Well Status after proposed work: Commencina ODeration: Oil 0 GasD Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAGD GINJD WINJ ŒI WDSPLD Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bruce Smith Printed Name Bruce Smith ~ Title Petroleum Engineer .. Signature ~A_ð ÞtJ Phone 564-5093 12/3/03 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness - - 3ð3-~q Plug Integrity 0 BOP TestD Mechanciallntegrity Test 0 Location Clearance ð 1-, (.; I::. , VE D Other: ~ jut w tlVt-€.,r ()-r\.., ~ . DEC - 4 2.003 Subsequent Form Required: J 0 - '-104 Alaska Oil & Gas Cons. Commission Original Signed By BY ORDER OF Anchorage tZ//1/()3 Approved by: THE COMMISSION Date: - - - -- - L ft_I:.- ~(( . ~,. . .', fJ ~:- It Qj)QlI lU Uj , -~,~ , ~;:;."""<l"" "":J~t!,;u",. L .'" b' ) ..I . .;,' Form 1 0-403 Revised 2/2003 '\ r") , G I N A L : ~ ;,~;t I \--I;\d 16f;L IDEC 1 '1 IJJiJ SUBMIT IN DUPLICATE lREE = 4-1/16"5M CIW WELLHEAD = 11" FMC ACTUA TOR = KB. B...B/ = 85.1' BF. B...EV = 59.39' KOP= 3100' Max Angle = 53 @ 4618' EÆltum fv[) = 7941' EÆltum 1VD = 6600' SS V-100 19-5/8" CSG, 40# L-BO BTC, ID = 8.835" I 2735' Minimu m ID = 2.24" @ 5925' EC LlPSE PATCH ÆRFORA llON Sllv1MA RY REF LOG: ---------- ANGLE AT TOP PERF: 11 @ 7944' Note: Refer to Produetion DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 7944 - 7990 0 03/12/02 2-112" 6 7998 - 8003 C 03/12/02 2-718" 6 8080 - 8082 C 09/30/01 4-1/2"lBG, 12.6#, L-80 NSCT, .0152bpf, ID= 3.958" 7798' I F£1D I 8303' 17" CSG, 26#, L-80, ID = 6.276" I 8388' I SAFETY NOTES: 958' 9-518" TAM PORT" COLLAR 2021' 7" TAM PORT COLLAR 2209' 4-1/2" HES X NIP, ID = 3.813" GA S LIFT MA NDRB...S ST fvD TVD DB/ TYPE VL V LA TCH PORT 2 5915 4931 50 KBG-2 *Drv1Y BK 0 1 7666 6329 14 KBG-2 *Drv1Y BK 0 ** STA llON # 1 & 2 = DMYs HAVE EXTENDED PACKING 5073' 5897'-5927 7648'-7678' 7732' 7743' 7767' 7787' DATE 08/07/03 08/07/03 7" MARKERJT (18') W/ RA TAG 4-1/2" EQ.IPSE PA TCH, ID = 2.24" SEr 11/01/03 4-1/2" EQ.IPSE PA TCH, ID = 2.24" SEr 11/01/03 -i4-1/2" I-£S X NIP, ID = 3.813" I -17" X 4-1/2" BKR 5-3 FRK, ID = 3.875" I -i4-1/2 I-ES X NIP, D = 3.813" I -14-1/2" HES XN NIP, ID = 3.725" I 7800' -i4-1/2" WLEG I 7798' H EU,,[)TT LOGG8) 09/30/01 I 7979' -iTOPOF SANDI 8039' -17" MARKERJT (20') W/RA TAG I DATE REV BY COMMENTS DATE REV BY COMMENTS 05/30/01 CHltlh ORIGINAL COMPLETION 04/10/03 DRS/TP 1V D'MD CORRECllONS 09/30101 ON Sltlh ADD PERFS 08/08/03 JCrvvTLP GL V C/O 03/12/02 TMN'tlh ADD PERFS 09/13/03 DA OTLP GLV CHANGES 03/20/02 CJSiKK SAND DUMP 11/01/03 CJSlTLP ECUPSEPATCHES 04/01/02 JB/KA K GL V C/O 04/16/02 TLHffLH PERF CORRECllONS BOREALIS UNIT WB...L: V -100 ÆRMT No: 201059 API No: 50-029-2300B SEC11, T11N, R11E,4714' NSL& 1531' WEL BP Exploration (Alask'a) 12-16-03 V-100 Conversion: Well is within the Area Injection Order Number 24, in Prudhoe Bay Field Borealis Oil Pool dated May 29, 2002. V-I 00 primary cement job went very well, no noted problems, USIT were run and attached showing perforated interval. Very good ./ cement response. V-100 has a tubing leak, a sundry has been generated requesting permission to inject water only; casing has been proven has having integrity. Gas lift mandrels were found to be damaged and not capable of being isolated with standard dummy valves, two tubing patches were run and set, the low packer provided full isolation and was tested as good, the upper patch leaked at the lower packer point, it is planned on pulling this patch and redressing it in the future. Wellhead has been tested and total wellbore integrity has been proven. This well is planned to be used for MI service in the future, once the patch has been re-dressed and tested for full integrity, and MI has been installed on V -pad, another Sundry and request will be made to the Commission to switch to WAG service. One well is present within Y4 mile, V-Ill. V-Ill is a High Angle; Horizontal producing ,./ well, cement job was noted as good, without problems, no cement evaluation log was run. .;I No annulus problems have been noted on this well. Full USIT log has been provided to the commission and should be on file there. en ¡;¡. co '-:-"'~ 83or-~"'" ~(")~~ B~i!BC'§ Z~ '" ~ ;¡_. ~ C)"tJ ~ ;¡¡" f= ;c~ c 0 :¡; 0 m ~ °b""tJ en~ ~(C§ §5¡;: .,. " ;¡:: .". ... ~)o~~~ ~æ :II' -c ::: "a m r- ¡¡¡¡¡ C;; :~d.:i? 5 ~ !II ~g:. ¡¡¡ ." Ë (")!:D po opo en~IÇ!IÇ!83!ž¡D !!!. ~ëJ~ ~-: 1:1" ¡B ~~ ~ë:!IÇ!83Bm;¡:: ~ ë3 ~ 0 s .. ,;" i:!. ;1:~~~=- '" . ~ z:JJ.;I '" ~ ~ - - !¡j ;c ;c ;¡:: "=I þþèn :n:nr- ~ Ii! en ..... C m c¡o r- ~ ~(") ~ ~::j 3: ~ 0 Z ~ en I 0 to..) -< ~~ me ~ .. 0 -e ::~ =-:. ~..... 0 Zen i: .. ;¡; '" 0 !=,!')7' "tJ ~= :nr~ » co (j) "tJ ~¡J::~ m .. ~ ;:u ? m~m ::~ ;[ =-==- r- 0 mC) " (j) m 3 ~~~~~ ~!1¡~3(") ~ ~ co ~ (/ a -< m£::E = 4-1.'113" 5MCrl\' WEllHEAD = 11" H.C ACTUATOR = K8. B.Eo/ - BF. ElEV = 3~, l' 59.:W -s,'e: CSG. of(\\! L-'.") 81(.. D = ~.ro'3' 2735' Mil"limll In 10 = 2.24" @ 5925' EC LlPSE PATCH 2- r ß' ',\-1.7 lEG, 12.>3#. L-OO !\SCT, .0052b~. D= 3.9~" n9g ro03' :' CSI"l 26#. I.,..!IO, [j = '12m" 8388' Æ'V BY CC+.~tt:NrS CH.\lh ælGINAL COMPLETÐN CII'SU.. ArC! ÆR="S lMt.,'lh AW ÆR=S V -1 00 t I S.~ETY NOTES: -s,'e: TAM P:JRl o......LAR r"TIf.1 PORT COLLAR 2209' .1.7J-I:SXI\IP.I)= 3.313' p: oR1 ~ 1 i'œe '3329 14 KBG.2 '[MY BK I) .,. SJATÞ:'N# 1 & 2 = DtfY!i HAVEEXTEtKEDPACKN3 507~' .," r.~~¡;;RJTI'11::'1 W,' PA TAG 5897'-5927' 4-1."2" EQ.PS: R6. TC~I. ID = 22.r SET 11,'01,'03 7648'-7678' .1.1,'2" EQ. PS: R6. TC~I. ID = 2_2-f SET 11,'01.'03 7732' 4.1.7' U;S X !\P, [I = 3.813" 7743' .,. XII-H2" Bta:!!';..3 ¡:¡;;j(, D= 3.3i'5" 7767' 4.1.'2 I-ES X tIP, [j = 3.81 3' 7787' 4.1.'2" I-ES XN NP. D = .3.:25" 7800' 7798' 7919' TOP OF SAI'D T" r.~ ~ERJI (20'! '-\','RA lAG RI;;'\!' BY COM.'E~nS r.:R3.'1P TI,'.DIiIDO::tRÆC1K)tß J:þ¡,'1LP Q.v c'a DAG'TLP a...o,'. CH6.N3ES 8CAE/tJ...1S un WElL: V -11)(0 R:rn..n No: 201l)~.g API No: 51)-029-2,;(1)8 SEC 11, 111N R111:.. 4T 1.1' I\EL & 1531' 'AU . . MECHANICAL INTEGRITY REPORT' , ~ ? U D D A ~:.: : 4/ ?rf! 0 { --C ..,....--.,...- c/7.njol :. ~ - r-.. .:..l.., .:. r.': .:.: ..:::.J tov OPER & FIELD ~r.. ípß/ Bvv ~~LL NllliBER V - 100 t(/ I - OS9 Cê-si~g: 7 tl TD: gs~.g .HD.. 1 J t ~ TVD; ?BTD: -.J3D3 HI? &QS'5 TVD . Shoe: f3~f HD 1/2.1.. TVD¡ DV: - l1D . Tv!) : -¡::-LL D ^ T }. .~ ,..,.. 1:'.. -:'- :....:':1e-:-: Shoe: ill) 'T~lD' ~r:"? - I - v.I. . l.m ,....,.. -7"\ .:. .¡ !..J :~bi::£: '-' I J " 4- /2. Packer ~HD TVTI; Set ê. t: 7 7t/ J ::. ole S iz e 8 - 'SIt/- It 7 9t./ t/ to ~Ofz. . . . ana Perfs ~CP~ANIC;'..L INTEGRITY - PART ¡ 1 Annulus Press Test: -1) 3 .!..- OO() 15 mill Z.q (l r::; j 3 0 mill 2 G-s 0 C OIIï:men t s: C--lllrr ~, LA / MECHJÜ'~ICþ.~ INTEGRTTY - PART f 2 -"'--'--.'. C emen 1: Volumes:. þ...mt. Liner Cillt: 701 to cover Der=s QJ.'~?I C;:. . " " ~heoretical TOe Jrot J {e; ~~O &v'l.. u~r.r Cement Bond Log (Yes or No) 'V ;;E.n AOGCC File . Lf . CBL Evaluation, ::.one above perfs LA~I-r' (s/rfj7.>oo,'\ i~'lJ1Cd. Þ:~ ~tll4út. Cwt.:r btJ\.tJ ~bo~.(J,. /2L...¡tv~,.J J'kte_-Nc~.l. , Proàuc.tion Log: Type ¡Evaluation ¡ j . j ¡ 1 i I I CONG;LUSIONS: ,:¡: .,' ". ~ I ? art n: M L't : . (CLt¡~ ~d. (!C. . . e..J- w .¡..,~V (AI" t~ I ? a r ~ : z : . - V,O t . ~ ~vd .i ÇL\f' I ~, , ~ C~"" l,1 , . . Ú~I (t, ' ~ l I \.",' ~' . t¡i' t ~tM,." i . '{ \ t. d ¿ d ~ . t- t f ( J _-1'." - ' V ,.. , n 241 ~ .. I. O'~ J ~'" . f'e,.f.,ð t ,.,( V\. ..t Ú),.(.. W\.,€.!.Þ....a '4.{"CtJI" lÞL 1f"-:~'vi 1-<-7 .. .. . ~Æ-- - . - - -- BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 November 20, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: V-100 (PTD 2010590) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well V-1 00. This request is . for approval to inject water into a well exhibiting rapid Tubing x IA communication. A / description summary of proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sinc~~ hn Cubbon Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic I.~ h 0 " ORIGINAL t¡J G í\- I 2.. (I &.[2-00"3 STATE OF ALASKA I) 7r 1¿/lb!3 ALASKA OIL AND GAS CONSERVATION COMMISSION ?() IZ-J 7 APPLICATION FOR SUNDRY APPROVAL J 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Operation Shutdown 0 PerforateD Variance[XJ Annular Disposal D Alter Casing 0 Repair Well 0 Plug Perforations 0 StimulateD Time ExtensionD OtherD ChanQe Approved ProQram 0 Pull TubinQ 0 Perforate New Pool 0 Re-enter Suspended WellO 2. Operator 4. Current Well Class: 5. Permit to Drill N~ber: Name: BP Exploration (Alaska), Inc. Development 0 Exploratory D 201-0590 3. Address: P.O. Box 196612 6. API Number / Anchorage, Ak 99519-6612 Stratigraphic 0 Service ŒJ 50-029-23008-00-00 7. KB Elevation (ft): 9. Well Name and Num,r: 83.60 KB V-100 8. Property Designation: 10. Field/Pool(s): ADL-0028240 Prudhoe Bay Field I Borealis Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 8388 7121.8 8303 6955.1 None None Casing Length Size MD TVD Burst Collapse top bottom toD bottom Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Production 8362 7" 26# L-80 26 - 8388 26.0 - 7121.8 7240 5410 Surface 2709 9-5/8" 40# L-80 28 - 2737 28.0 - 2736.7 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7944 - 7979 6687 - 6721.1 4.5 " 12.6 # L-80 24 . 7800 7979 . 7990 6721 - 6731.9 2.375" 4.7 # 5897 - 5927 7998 - 8003 6740 - 6744.7 2.375" 4.7 # 7648 - 7678 8080 - 8082 6820 - 6822.1 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker S-3 Perm Packer 7743 4-1/2" Eclipse Patch Packer 5897 4.1/2" Eclipse Patch Packer 5923 4-1/2" Eclipse Patch Packer 7648 4.1/2" Eclipse Patch Packer 7674 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory 0 Development 0 Service [XI .r 14. Estimated Date for November 20, 2003 15. Well Status after proposed work: Commencina Operation: OUO GasD PluggedD Abandoned 0 16. Verbal Approval: Date: WAGD GINJD WINJ r&J .,/ WDSPLD Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Cubbon I Joe Anders Printed Name AJohn .cut~n Title Well Integrity Engineer Signature 1/ P' { ..~r~ V Phone 659-5102 11/20/03 (/ Commission Use Only v Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -:?o -=< - ~£Õ Plug Integrity 0 BOP TestD Mechanciallntegrlty TestD Location Clearance D Other: ~ ut ..0 CI- t<>-r "",-l 't. P W~ f I4A. £:A!L 1: T ~h ~)( LA w ~ 1 two l.)2li;r~. ~ ~lt rvuJV\,+J¡,-Il.{ Y't.fovt of- d.CL-Llvl 1'vt¡U flY'- rcJ-fS C-LNtJ f~~UtNÇ.. , Subsequent Form Required: Original Signed By BY ORDER OF i/~I ,'1,04; ",,~pp'r9'yecj .~y:.. ".' ~, ' .;;. - ,.... THE COMMISSION Date: \?J~(r~1J ~ 0' I JJi~ ~ ~. QiJ ¿IJUj , '"" ,- """fj , Ii " Form 1 0-403 Revised 2/2003 OR\G\NAl ~afL DEe 1 ,,¡mlJ SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleekenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay 1 PBU 1 V 08/08/03 Boyles Paeker Depth Pretest Initial 15 Min. 30 Min. Well V-100 Type Inj. S TVD 6,490' Tubing 750 3,050 2,950 2,900 Interval I P.T.D. Type test P Test psi 1622.5 Casing 0 3,000 2,900 2,850 P/F P Notes: CMIT T x IA performed to assure produetion easing integrity. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casinq P/F Notes: Well Type Inj. TVD Tubinq Interval P.T.D. Type test Test psi Casing P/F Notes: /' Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injeeting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioaetive Traeer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cyele V = Required by Variance T = Test during Workover 0 = Other (deseribe in notes) MIT Report Form Revised: 06/19/02 MIT PBU V-100 CMIT 08-08-03.xls V-I00 Description Summary of Proposal 11/20/03 Problem: Injector with Rapid TxIA communication Well History and Status Well V-100 (PTD 2010590) is a permitted water injector that failed a pre-A~CC witnessed MIT-IA on 11/03/03. This well has not yet been put on injection. Following the failed MITIA a LLR of 4.6 BPM at 3000 psi was established. A subsequent LDL showed that the tubing patch located from 5897' -5927' is leaking. Recent events: > 08/07/03: Pulled GLV's both were flow cut, DGLV was cut in half. Ran DGLV's, MITIA Failed, no pressure increase. I > 08/08/03: Set SV, CMIT Tx IA passed to 3000 psi, pulled SV. > 10/03/03: D&D found leak @ sta #2 - 5915' > 10/12/03: MITDA Failed, LLR.35 bpm @2000# /' > 10/31/03: Set patch #1 7648-7678' > 11/01/03: Set patch #2 5897-5927' , > 11/03/03: MITIA FAILED. /' > 11/04/03: LLR-IA - 4.6 bpm @ 3000 psi. > 11/09/03: LDL shows upper patch leaking. This sundry request is to allow for injection of water. The following supports the request: . A CMIT - TxIA passed on 8/08/08 to 3000 psi against a standing valve, ~/ demonstrating competent production casing. . Pressures and injection rates will be monitored and recorded daily and checked /" for indications of a production casing leak. . A CMIT TxIA against a TIP will be conducted every 2 years to confirm /~ production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. /~ 2. Record wellhead pressures and injection rates daily. /' 3. Submit a monthly report of daily pressures and injection rates. 4. Perform combination MIT Tubing x IA against a plug every 2 years. ,",,", 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. bp Date: 12-01-2003 Transmittal Number: 92631A BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date IContractor Log Run Depth Depth Lo9 Type ,S-102L1 11-02-2003 REEVES 1 11500 14377 CML MEASURED DEPTH ARRAY INDUCTION SHALLOW FOCUSSED LOG; S-102L1 11-02-2003 REEVES I 11500 14334 CML MEASURED DEPTH PHOTO DENSITY DUAL SPACED NEUTRON LOG; S-102L1 11-02-2003 REEVES 1 11500 14356 CML MEASURED DEPTH COMPENSATED SONIC LOG; S-102L1 11-02-2003 REEVES 1 6674 6684 CML TVD ARRAY INDUCTION SHALLOW FOCUSSED LOG S-102L1 11-02-2003 REEVES 1 6674 6684 CML TVD COMPENSATED iSONIC LOG; ~-102L1 11-02-2003 REEVES 1 6674 6684 CML TVD PHOTO DENSITY DUAL SPACED NEUTRON LOG; V-100 11-09-2003 SCH 1 0 7980 LEAK DETECTION LOG; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Howard Oakland (DNR) Attn: Kristin Dirks (DNR) Attn: Sandy Lemke (ConocoPhillips) Attn: Phillip Thibodeaux Jr. (Exxon Mobil Production Co.) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Permit to Drill 2010590 DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. PRUDHOE BAY UNIT V-100 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23008-00-00 MD 8405 'I'VD 7138 Completion Dat 5/20/2001 Completion Statu SUSP Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log N__~o Sample N_.Qo Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments ~ Well Report FINAL c~'(~R RES 7'1/1'5 5 FINAL .~I~D GR ROP/RES 5 FINAL v'~)ipole Shear 5 FINAL c/Platform/Array 5 FINAL Induction Tool t.,.'I~/D Platform Subsea 5 FINAL ~;~atform/DEN/NEU 5 FINAL ~.ST Cores Report 5 FINAL T~E DTFORM/DYN 5 FINAL ~lEatform/Triple Combo 5 FINAL ~ Sprectroscopy 5 FINAL /...-Ultrasonic Imager/Color 5 FINAL Ultrasonic Imager/ 5 FINAL Color ~t0118 FINAL ~"0117 FINAL '"MwD Survey FINAL ~" Directional Survey FINAL 109 2602 109 109 109 2650 2650 2650 2650 2650 3163 2650 2650 5470 5470 .2602 109 8405 8392 8406 8405 8405 8395 8365 8312 8312 8312 7951 8312 8312 8282 8282 8392 8406 Open 8/8/2001 ~_..1J3233 ~109-8405 Open 6/1/2001 ~:)118 v2'602-8392 Case 6/1/2001 (-.~13'117 ~109-8406 CH 6/6/2001 End of Well Report OH 6/6/2001 109-8405 BL, Sepia OH 6/6/2001 109-8405 BL, Sepia CH 6/6/2001 2650-8395 BL, Sepia CH 6/6/2001 2650-8365 BL, Sepia CH 6/6/2001 2650-8312 BL, Sepia CH 6/6/2001 2650-8312 BL, Sepia CH 6/6/2001 2650-8312 BL, Sepia CH 6/6/2001 3163-7951 BL, Sepia CH 6/6/2001 2650-8312 BL, Sepia CH 6/6/2001 2650-8312 BL, Sepia CH 6/6/2001 ..-5'470-8282 CH 6/6/2001 5470-8282 BL, Sepia oh 6/1/2001 ~:Ll18 ~2602-8392 Digital Data oh 6/1/2001 ~1.e~'7 '/109-8406 Digital Data CH 5/15/2001 MWD Survey, Digital Data OH 5/15/2001 Directional Survey, Paper Copy Permit to Drill 2010590 MD 8405 TVD DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. PRUDHOE BAY UNIT V-100 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23008-00-00 7138 Completion Dat 5/20/2001 CompletiOn Statu SUSP Current Status WAGIN UIC Y FINAL 3850 5750 CH 7/26/2001 3850-5750 BL r..,Dipole Sonic 2 [,,(~C Plot- DSI 2 C'Elan Global Solver ~al L/Elan Global Solver ~uf/~l vZ/oned Impact- R. oxan 2 for FracCA ~Elan Global Solver~,~,~_ v~Zoned Impact-Roxan 2 for FracCAD f~orned Impact-Roxan ~_ 2 FracCAD ~,! FINAL 7370 8350 CH 7/26/2001 FINAL 2600 8350 CH 7/26/2001 FINAL 2920 3120 CH 8/6/2001 FINAL 6560 7100 CH 8/6/2001 FINAL 3900 4800 CH 8/6/2001 FINAL 3900 4800 CH 8/6/2001 FINAL 2950 3100 CH 8/6/2001 FINAL 6600 7100 CH 8/6/2001 FINAL 109 8405 oh 7/13/2001 ~1-0233 7370-8350 BL 2600-8350 BL 2920-3120 BL 6560-7100 BL 3900-4800 BL 3900-4800 BL 2950-3100 BL 6600-7100 BL 109-8405 Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ~or3 ADDITIONAL INFORMATION Well Cored? (~N Received? ~/N Chips Analysis (~ / N Re c~.ivP, d ? Comments: Daily History Received? '~/N Formation Tops ~/N Compliance Reviewed By: Date: BP Exploration (Alaska), Inc. Borealis V-100 West End Field Prudhoe Bay, Alaska SIDEWALL CORE ANALYSIS SMPL. REC DEPTH Kair POR Sco Stw PROB Sand NO. (in) CQI (ft) (mD)* (%) (%) (%) PROD LITHOLOGY Ugnu 1 0.8 B3 3006.0 2240.0 28.3 7.5 70.3 Oil Sd mg cln Ugnu 2 0.8 A3 3051.0 770.0 29.6 6.9 74.9 Oil Sd mg cln Ugnu 3 1.1 A4 4098.0 335.0 26.3 34.7 54.1 Oil Sd f-mg sshy Ugnu 4 1.1 A4 4206.0 775.0 25.7 48.6 38.9 Oil Sd mg cln Ugnu 5 1.2 A4 4253.0 570.0 26.4 43.9 38.7 Oil Sd mg sshy lam (3) Ma 6 1.2 A4 4339.0 660.0 28.1 35.3 53.6 Oil Sd mg sshylam (3) Mb1 7 1.2 A4 4429.0 1400.0 30.1 3.2 83.2 Wtr Sd mgcln Mbl 8 1.0 A3 4487.0 1050.0 28.9 26.9 55.6 Oil Sd mg shylam (2) Mb2 9 0.9 B3 4553.0 2100.0 28.4 3.6 74.6 Wtr Sd mgcln Mc 10 1.0 A3 4660.0 2640.0 30.7 0.0 76.2 Wtr Sdmgcln Na 11 0.8 A3 4741.0 2.4 22.9 0.0 76.3 (6) Sd fg shy Na 12 1.0 A3 4757.0 310.0 24.4 23.9 48.4 Oil Sd f-mg sshy Nb 13 0.7 C3 4784.0 13.3 19.4 25.4 29.1 Oil Sd mg vlig Nb 14 1.1 A4 4793.0 2.6 21.4 0.0 89.1 (6) Sd vfg slty shy Nc 15 1.0 A3 4860.0 57.0 23.3 9.0 61.2 Oil Sd vfg slty shy calc OA 16 1.1 A4 5021.0 280.0 25.9 26.9 51.6 Oil Sd fg sslty sshy OA 17 1.3 A4 5031.0 630.0 28.8 40.6 45.3 Oil Sd fg cln OA 18 1.3 A4 5047.0 710.0 26.9 23.3 51.5 Oil Sd fg cln OA 19 1.3 A4 5063.0 765.0 27.4 23.4 56.9 Oil Sd fg sslty FLU dl gld dl gld dl gld dl gld dl gld dl gld no dl gld dl gld no stk gld dl gld stk gld no ft gld ev gld ev gld ev gld ev gld Sand Ugnu Ugnu Ugnu Ugnu Ugnu Ma Mb1 Mbl Mb2 Mc Na Na Nb Nb Nc OA OA OA OA ¢cUC~ Sand OA OA OBa OBa OBa OBa OBb OBb Obc Obc OBd OBd OBd OBd OBd OBe OBe OBe OBf OBf OBf OBf BP Exploration (Alaska), Inc. Borealis V-100 West End Field Prudhoe Bay, Alaska SMPL. REC DEPTH Kair NO. (in) CQI (ft) (mD)* 20 1.3 A4 5079.0 175.0 21 1.0 A3 5085.0 55.0 22 1.3 A4 5138.0 600.0 23 1.2 A4 5145.0 350.0 24 1.3 B4 5154.0 475.0 25 1.3 A4 5171.0 120.0 26 1.2 A4 5204.0 75.0 27 1.4 A4 5222.0 450.0 28 1.3 A4 5304.0 310.0 29 1.4 A4 5319.0 7.2 30 1.3 A4 5382.0 8.7 31 1.5 A4 5394.0 325.0 32 1.2 C4 5403.0 950.0 33 1.3 B4 5414.0 1050.0 34 0.8 C3 5432.0 6.8 35 1.0 A3 5494.0 25.0 36 1.1 A4 5508.0 150.0 37 1.3 A4 5519.0 350.0 38 1.2 B4 5557.0 125.0 39 1,4 A4 5565,0 95.0 40 1.4 A4 5574.0 9.0 41 1.4 A4 5583.0 5.6 SIDEWALL CORE ANALYSIS POR Sco Stw PROB (%) (%) (%) PROD LITHOLOGY 25.5 16.1 63.3 Oil Sd fg sslty sshy 23.1 10.8 68.5 Oil Sd fg slty shy 31.5 20.1 34.7 Oil Sd vf-fg sshy sslty 28.5 19.1 45.5 Oil Sd vf-fg sshy sslty 31.1 21.9 43.4 Oil Sd vf-fg sshy sslty scalc 26.6 9.5 66.1 Oil Sd vf-fg shy sslty 24.8 11.5 68.9 Oil Sd vf-fg vshy sslty 29.4 24.3 48.3 Oil Sd fg sshy sslty 30.7 15.2 48.5 19.4 12.2 54.9 Oil Sd vf-fg sshy sslty (6) Sd vfg shy-vshy lam(2,3) slty 16.3 36.1 27.0 (6) Sd vf-fg shy-vshy vslty 26.9 17.2 39.8 Oil Sd vf-fg sshy sslty 29.5 17.2 49.4 Oil Sd fg sshy sslty 31.5 31.4 32.1 Oil Sd fg sshy sslty 22.1 8.6 56.1 (6) Sd vfg shy slty vcalc 22.9 12.3 50.9 Oil Sd fg shy sslty scalc 25.3 17.8 68.3 Oil Sd fg shy 26.3 16.5 51.3 Oil Sd fg sshy-shy scalc 25.5 10.6 69.0 Oil Sd fg shy Imy 24.2 7.4 72.8 Oil Sd fg shy scalc 22.6 3.9 77.0 (6) Sd fg shy-vshy lam(2) 22.2 0.0 82.5 (6) Sd vf-fg vshy lam(2) FLU ev gld stk gld ev gld ev gld ev gld mort gld mott gld ev gld ev gld stks gld mott gld ev gld ev gld ev gld spts gld mott gld ev gld ev gld ev gld mort gld stks gld no Sand OA OA OBa OBa OBa OBa OBb OBb Obc Obc OBd OBd OBd OBd OBd OBe OBe OBe OBf OBf OBf OBf 0.9 B3 6173.0 Shale slty calc no , . BP Exploration (Alaska), Inc. Borealis V-100 West End Field Prudhoe Bay, Alaska SIDEWALL CORE ANALYSIS SMPL. REC DEPTH Sand NO. (in) CQI (ft) Kair POR Sco Stw PROB (mD)* (%) (%) (%) PROD LITHOLOGY FLU Sand 42 0.8 C3 8137.0 43 0.6 F3 8141.0 44 0.6 F3 8143.0 9.8 22.1 7.6 69.7 575.0 28.0 3.8 66.4 705.0 28.5 3.3 70.3 · (6) denotes Iow permeability. (6) Sd vf-fg vshy lam(2,3) scalc stks dl gld Oil Sd vf-fg cln wcem vft Oil Sd vf-fg cln mwcem scalc vft BP Exploration (Alaska), Inc. Borealis V-100 West End Field Prudhoe Bay, Alaska FORMATION: Schrader Bluff DRLG FLUID: Water Base Mud LOCATION: CORES: Schlumberger SIDEWALL CORE ANALYSIS - CORE QUALITY INDEX FILE NO.: Hou-0'I0415 DATE · May 22, 2001 APl NO. · ANALYSTS · AC, TW RECOVERY EFFICIENCY Total cores attempted = 45 Total cores recovered = 45 Recovery Efficiency = 100% CORE QUALITY A Excellent 33 73% B Good 6 13% C Fair 4 9% D Poor 0 0% F Muddy/Insufficient 2 4% CORE BULLET INFO Bullet diameter: Bullet type: Retaining wire length: Retaining wire type: Charge: CORE RECOVERY SIZE 4 Full recovery ( > 1") 29 64% 3 Good recovery ( >0.5"- 1") 16 36% 2 Fair recovery (0.25"- .5") 0 0% 1 Poor recovery (<0.25") 0 0% NR No recovery 0 0% Note: Core Quality Index (CQI) is a visual rescription of core grain recovery based upon two measures: 1) Core quality - Affected by mud invasion, shattering of grains, ability to use core for additional tests. 2) Core recovery size - Amount of core recovered. 100% 80% 60% 40% 20% 0% lO0% 8o% 60% 40% 20% o% Core Quality A B C D F Core Recovery 4 3 2 1 NR Page 1 of 1 BP Exploration (Alaska), Inc. Borealis V-100 West End Field Prudhoe Bay, Alaska DESCRIPTION CODE KEY AND ABBREVIATIONS LITHOLOGY ^nhy Anhydrite Cgl Conglomerate Dol Dolomite Glauc Glauconite H Halite Lig Lignite Ls Limestone Pyr Pyrite Sd Sand Sh Shale Sit Silt Sf Shell Fragments GRAIN SIZE vfg very fine grain fg fine grain mg medium grain cg coarse grain FLUORESCENCE INTENSITY ev even bt bright stk streaks(ed) ff faint spt spots(ed) dl dull mott mottled vff very faint COLOR MODIFIERS b blue u unconsolidated b-w blue-white vs very slightly bz bronze s slightly gld gold m moderately w white mw moderately well y yellow v very w well OTHER calc calcareous ha high angle cln clean hd hard carb carbonaceous lam laminated(ion) cem cementation mic micaceous con consolidated ms mudshot dns dense shy shaley flu fluorescence slty silty foss fossiliferous tr trace frc fractured(s) vug vuggy fl flushed vt vertical PRODUCTION CODES OTHER ABBREVIATIONS Gas gas Por Oil oil Gb Cond condensate Ob Water water Sco (1) altered core Stw (2) exposed core Sciw (3) insufficient sample Vsh (4) contaminated core Cs (5) Mean (6) Iow permeability FOOTNOTES * permeability values determined empirically porosity, % gas saturation, % bulk volume oil saturation, % bulk volume core oil saturation, % pore volume total water saturation, % pore volume critical water saturation, % pore volume volume of shale, % bulk volume surface area (m'/cc) mean grain size, microns Sciw values after Granberry, R.J. and Keelan, D.K., 1977 samples interpreted without knowledge of depth or intervals PAGE 6 FILE NO.: Hou-010415 DATE: June 7, 2001 APl NO.: ANALYSTS: AC, TW INTERLAMsm THIN BED SAMPLE DESCRIPTIONI TYPE 1 TYPE 2 SHALE LAMINATIONS < 1 mm SHALE LAMINATIONS 1-5 mm TYPE 3 TYPE 4 SHALE LAMINATIONS 5-10 mm SHALE LAMINATIONS > 10 mm CORE LABOt~4 TORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Company · BP EXPLORATION (Alaska), Inc. Well · Borealis V-100 Field · West End Location - Prudhoe Bay, Alaska ~r~ CL File No · HOU-010394 Date · June 29, 2001 Analysts' ML-LA-JH-RC-MM CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth 800 psi Net Confining Stress 1660 psi Net Confinin~l Stress Grain Number PorosityI Permeability(mD) PorosityI Permeability(mD) Density ft % KlinkenbergI Kair % Klinkenber~l J Kair ~llcm3 1 7939.79 13.27 .631 .682 12.68 .119 .141 2.698 2 7940.70 20.75 1.17 1.57 20.29 .880 1.20 2.683 3 7941.20 21.51 1.35 1.76 21.13 1.08 1.42 2.742 4 7942.70 24.18 .637 .781 23.99 .592 .739 3.041 5 7943.40 20.83 2.34 2.97 20.52 2.14 2.73 2.875 5V 7943.70 23.36 4.80 5.86 23.18 4.60 5.65 2.958 6 7944.20 23.04 6.21 7.51 22.82 5.89 7.13 2.778 7 7945.20 25.67 8.17 9.85 25.39 7.85 9.50 2.877 8 7946.29 19.52 4.34 5.21 19.23 3.98 4.80 2.719 53 7947.20 21.12 8.82 10.3 20.80 8.27 9.66 2.698 53V 7947.39 22.76 12.3 14.3 22.43 11.7 13.6 2.668 9 7948.20 24.87 90.9 97.6 24.59 88.2 94.5 2.643 54 7949.00 25.73 104 111 25.41 101 108 2.646 54V 7949.25 26.03 64.1 69.7 25.56 61.9 67.4 2.646 10 7950.20 22.43 21.6 24.6 22.14 20.7 23.6 2.643 11 7951.10 20.80 8.48 10.2 20.49 8.11 9.67 2.640 12 7952.10 20.67 4.87 6.07 20.37 4.53 5.59 2.677 12V 7952.25 20.67 2.66 3.45 20.38 2.50 3.24 2.681 13 7953.30 11.34 .196 .290 11.14 .183 .271 2.751 14 7954.10 19.04 2.45 3.11 18.77 2.34 2.96 2.693 15 7955.10 18.77 2.60 3.26 18.47 2.42 3.04 2.647 15V 7955.25 22.19 2.41 3.10 21.41 2.23 2.87 2.642 16 7956.10 19.81 4.36 5.46 19.49 4.12 5.14 2.647 17 7957.10 19.83 3.79 4.67 19.50 3.58 4.39 2.648 18 7958.10 18.88 2.51 3.24 18.59 2.32 3.00 2.650 18V 7958.25 21.26 4.04 5.05 20.92 3.79 4.74 2.648 PRELIMINARY REPORT Page CORE LABORATORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Company · BP EXPLORATION (Alaska), Inc. Well · Borealis V-100 Field · West End · Prudhoe Bay, Alaska Location CL File No · HOU-010394 Date · June 29, 2001 Analysts· ML-LA-JH-RC-MM CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth 800 psi Net Confining Stress 1660 psi Net Confining Stress Grain Number Porosity I Permeability (mD) Porosity I Permeability {mD) Density ft %I Klinkenberg I Kair %I KlinkenbergI Kair glcm3 19 7959.30 22.28 12.5 14.7 21.96 12.0 14,1 2.658 20 7960.10 20.73 7.20 8.77 20.41 6.83 8.30 2.646 21 7961.10 21.35 9.77 11.6 21.04 9.39 11.1 2.644 21V 7961.25 22.15 4.98 6.20 21.76 4.68 5.83 2.646 22 7962.10 21.42 12.2 14.6 21.11 11.6 13.8 2.643 23 7963.10 22.30 15.4 17.8 21.96 14.7 16.9 2.644 24 7964.10 5.15 .007 .014 4.90 .004 .008 2.798 25 7965.10 22.78 21.6 24.7 22.47 20.8 23.7 2.641 25V 7965.25 22.79 7.16 8.71 22.42 6.82 8.29 2.648 26 7966.10 22.13 12.6 14.8 21.82 12.0 14.1 2.643 27 7967.30 19.60 4.39 5.48 19.27 4.13 5.16 2.645 28 7968.10 20.01 4.37 5.50 19.68 4.08 5.14 2.641 28V 7968.25 20.33 1.74 2.31 19.99 1.60 2.10 2.645 29 7969.10 19.96 3.39 4.25 19.62 3.18 3.99 2.644 30 7970.10 17.80 .901 1.29 17.45 .808 1.16 2.647 31 7971.10 18.90 2.14 2.77 18.56 1.99 2.57 2.646 31V 7971.25 18.89 .462 .694 18.54 .399 .601 2.649 32 7972.10 18.46 1.43 1.96 18.14 1.29 1.77 2.645 33 7973.10 18.18 1.15 1.61 17.81 1.03 1.44 2.651 34 7974.10 18.55 1.58 2.09 18.21 1.46 1.92 2.649 35 7975.10 18.12 1.07 1.49 17.80 .958 1.34 2.644 35V 7975.25 17.38 .176 .295 17.02 .144 .244 2.645 36 7976.10 18.92 1.58 2.09 18.59 1.44 1.90 2.643 37V 7977.25 21.12 1.64 2.20 20.12 1.88 2.54 2.639 37 7977.70 20.45 2.06 2.77 20.76 1.50 2.01 2.643 38 7978.10 20.29 2.94 3.74 19.99 2.74 3.50 2.664 PRELIMINARY REPORT Page 2 CORE LABORATORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Company : BP EXPLORATION (Alaska), Inc. Well · Borealis V-100 Field · West End · Prudhoe Bay, Alaska Location CL File No: HOU-010394 Date: June 29, 2001 Analysts: ML-LA-JH-RC-MM CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth 800 psi Net Confining Stress 1660 psi Net Confinin~l Stress Grain Number PorosityI Permeability(mD) PorosityI Permeability(mD) Density ft % Klinkenberg I Kair % Klinkenber~l I Kair ~llcm3 39 7979.10 20.56 1.95 2.57 20.26 1.83 2.40 2.661 40 7980.10 18.22 .650 .947 17.87 .575 .840 2.648 40V 7980.25 19.01 .319 .516 18.59 .646 .692 2.648 41 7981.10 18.48 1.26 1.72 18.16 1.16 1.57 2.646 42 7982.29 20.36 3.06 3.92 20.03 2.85 3.65 2.647 42V 7982.39 19.82 .872 1.27 19.49 .793 1.14 2.644 43 7983.10 20.29 3.61 4.47 19.90 3.33 4.15 2.644 44 7984.10 22.09 6.54 8.12 21.76 6.20 7.71 2.649 45 7985.10 19.80 2.39 3.11 19.45 2.24 2.91 2.662 46 7986.10 19.10 1.81 2.39 18.76 1.69 2.22 2.655 46V 7986.25 19.15 .395 .613 18.77 .351 .545 2.653 47 7987.10 16.95 .618 .760 16.60 .578 .694 2.684 48 7988.10 16.74 .549 .720 16.34 .465 .611 2.667 49 7989.10 14.53 .119 .204 14.16 .080 .143 2.641 49V 7989.25 15.12 .037 .086 14.71 .023 .057 2.634 50 7990.10 14.96 .163 .272 14.50 .119 .202 2.651 51 7991.20 15.24 .502 .653 14.74 .180 .281 2.641 52 7992.20 16.83 8.62 9.79 16.19 3.76 4.26 2.645 55V 7995.50 15.58 .039 .092 15.19 .028 .064 2.642 55 7995.70 15.85 .271 .435 15.36 .152 .266 2.643 56V 7996.50 14.68 .029 .067 14.32 .016 .042 2.642 56 7996.60 16.54 .305 .465 16.14 .191 .312 2.638 57V 7997.39 18.53 .242 .395 18.01 .189 .314 2.650 57 7997.60 18.84 1.21 1.67 18.48 1.07 1.48 2.651 58V 7998.50 19.64 .719 1.05 19.20 .588 .864 2.646 58 7998.60 19.60 1.36 1.86 19.25 1.22 1.67 2.648 PRELIMINARY REPORT Page 3 CORE LABORATORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Company · BP EXPLORATION (Alaska), Inc. Well · Borealis V-100 Field · West End Location · Prudhoe Bay, Alaska CL File No · HOU-010394 Date · June 29, 2001 Analysts' ML-LA-JH-RC-MM CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth 800 psi Net Confining Stress 1660 psi Net Confinin~l Stress Grain Number PorosityI Permeability(mD) PorosityI Permeability(mD) Density ft % Klinkenber9 I Kair % Klinkenber~l I Kair ~llcm3 59 7999.60 21.37 4.95 6.12 21.03 4.64 5.74 2.649 59V 7999.70 22.29 3.09 3.95 21.96 2.93 3.70 2.648 60 8000.60 23.76 9.79 11.7 23.40 9.28 11.2 2.658 60V 8000.70 23.72 5.62 7.00 23.40 5.22 6.51 2.667 61V 8001.50 23.51 4.93 6.41 23.20 4.26 5.56 2.656 61 8001.60 23.66 9.79 11.7 23.30 9.37 11.2 2.648 62 8002.20 20.87 1.89 2.54 20.48 1.62 2.19 2.645 62V 8002.39 15.70 .033 .075 15.34 .025 .054 2.651 63V 8003.50 12.50 .010 .022 12.02 .006 .014 2.664 63 8003.60 13.82 .061 .115 13.46 .029 .062 2.655 64 8004.60 17.78 .505 .747 17.31 .383 .579 2.651 65 8005.60 14.16 .217 .315 13.64 .081 .150 2.657 65V 8005.79 13.07 .021 .040 12.58 .008 .022 2.665 66 8006.60 5.12 .003 .008 4.92 .002 .005 2.788 67 8007.60 15.53 .094 .183 15.11 .056 .120 2.659 68 8008.60 19.91 1.47 2.00 19.51 1.28 1.74 2.659 68V 8008.80 21.58 1.05 1.52 21.20 .886 1.30 2.656 69 8009.60 19.36 1.20 1.69 18.96 .974 1.39 2.667 70 8010.60 17.34 .231 .386 16.94 .167 .292 2.670 71 8011.29 20.57 2.20 2.83 20.20 1.92 2.49 2.685 72 8012.20 17.05 .468 .586 16.67 .201 .308 2.737 73 8013.50 14.15 .086 .144 13.95 .048 .089 2.810 74 8014.70 15.05 .061 .121 14.68 .031 .070 2.688 75 8015.60 15.83 .091 .172 15.43 .047 .101 2.696 76V 8016.39 19.30 .398 .606 18.79 .481 .576 2.681 76 8016.60 19.00 .844 1.18 18.58 .687 .968 2.669 PRELIMINARY REPORT Page 4 CORE LABORATORIES LP HOUSTON ADVANCED TECHNOLOGY CENTER Company · BP EXPLORATION (Alaska), Inc. Well · Borealis V-100 Field · West End Location · Prudhoe Bay, Alaska CL File No · HOU-010394 Date · June 29, 2001 Analysts' ML-LA-,JH-RC-MM CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth 800 psi Net Confining Stress 1660 psi Net Confinin~l Stress Grain Number Porosity I Permeability (mD) Porosity I Permeability (mD) Density ft %I KlinkenbergI Kair %I Klinkenber~l I Kair ~llcm3 77 8017.20 17.72 .813 1.16 17.20 .612 .882 2.695 78 8018.20 17.24 .225 .334 16.92 .146 .235 2.939 79 8019.60 21.73 22.4 24.9 21.11 19.6 21.8 2.668 80 8020.30 20.37 18.7 21.3 19.77 16.5 18.7 2.801 81 8022.10 16.24 1.42 1.76 15.78 .810 1.07 2.642 82 8024.79 13.68 1.41 1.61 13.19 .457 .576 2.625 83 8025.79 16.18 2.98 3.49 15.85 2.12 2.56 2.662 84 8027.70 14.15 1.73 2.01 13.71 .702 .875 2.664 85 8031.20 8.74 .003 .007 8.42 .002 .004 3.069 86 8035.50 17.81 8.81 10.5 17.49 8.32 9.90 2.643 87 8048.29 16.56 3.83 4.03 16.05 1.15 1.29 2.773 88 8054.10 13.26 .471 .610 12.75 .183 .267 2.633 89 8057.20 13.82 1.19 1.40 13.32 .430 .547 2.648 90 8071.50 13.48 .942 1.11 12.97 .295 .385 2.631 91 8093.39 17.78 1.32 1.62 17.41 .734 1.00 2.666 92 8105.39 15.34 2.31 2.62 14.88 1.87 2.09 2.662 PRELIMINARY REPORT Page 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WEL.L. COMPL.ETION OR RECOMPL.ETION REPORT AND LOG Revised: 04116102, Start Production "1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-059 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23008-00 '4. Location of well at surface ,! .... .~';":::: ¥.:;;?'-~ ~.~¥t~ 9. Unit or Lease Name 4714' NSL, 1531' WEL, SEC. 11, T11 N, R11 E, UM .~ .~.,.:.--:. , ~ Prudhoe Bay Unit 5271' NSL, 1429' EWL, SEC. 12, T11N, R11E, UM : ,, .... ~...-~, At total depth ~ .,,~:.,~.~...~,. ~_"~ ~~,_.._..__.... -.., 10. Well Number 5266' NSL, 1521' EWL, SEC. 12, T11N, R11E, UM !:.. ,__....,~5'~ ........ . , V.100 '"'? ........................ 11. Field and Pool '~5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool KBE = 83.60' ADL 028240 (Undefined) 12. Date Spudded4/29/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'5/11/2001 9/30/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne '17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 8405 7138 FTI 8304 7040 FT} [] Yes r-I NoI (Nipple) 2209' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, DIR, RES, AlT, DT, BHC, CNL, LDL, Caliper, SP, MRES, CUR, MDT, ECS, USIT 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 2737' 12-1/4" ¢27 sx AS Lite 3~ 202 sx Class 'G' 7" 26# L-80 26' 8388' 8-3/4" 392 sx Lite Crete 'G', 336 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , 2-7/8" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 7800' 7743' MD TVD MD TVD 8080' - 8082' 6820' - 6822' 7944' - 7990' 6687' - 6732' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ----,~, --,,9~1~ ~3' 6740' - 6745' ,, .. i-{l::Ul=lVl::l .....DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 77 bbls Diesel APR ~. 6 Z00Z ..... 7944' '7990' F~ac;d; Placed 220,150# of 16/20& '12/18 Carbolite behind pipe ---~-__: -..- -.AI~If~i~II&GAsCQII~,~ 3500' . Freeze Protected with 70 Bbls MeOH 27. A ~ PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 4, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/7/2002 4 TEST PERIOD 1792 .677 -0- 176I 378 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 18.8 28, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 3ore 1: 7930-7992.5' MD (62.5' total). 7930-7940.5', Kalubik Formation, dark gray shale, becoming medium gray and sandy shale at the base. 7940.5-7989' MD, Kuparuk C sandstone, very fine to fine grained, 3ioturbated, slightly to very shaly, with patchy siderite cement and patchy medium to dark brown oil stain, fair porosity. 7989-7992.5' MD, very shaly sandstone or siltstone, very Iow perm, very little oil stain. ,?,ore 2: 7995'-8117' MD (122' total). 7995'-8019. 5 MD, Kuparuk C siltstone and very fine grained sandstone, bioturt)ated, w/patchy siderite cement, poor to fair porosity (fair porosity has medium brown oil stain). ~,019.5'-8117' MD, Kuparuk B, burrowed, Interbedded, fine laminae of dark gray shale, light gray siitstone, and light to medium brown, oil stained, very fine grained sandstone. Sidewall Cores: 45 sidewall cores attempted, 45 recovered. Depths (MD): 3006', 3051', 4098', 4206', 4253', 4339', 4429', 4487', 4553', 4660', 4741', 4757', 4784', 4793', 4860', 5021', 5031', 5047', 5063', 5079', 5085', 5138', 5145', 5154', 5171', 5204', 5222', 5304', 5319', 5382', 5394', 5403', 5414', 5432.', 5494', 5508', 5519', 5557', 5565', 5574', 5583', 6173', 8137', 8141', and 8143'. Form 10-407 Rev. 07-01-80 ~/~y 3 ~02ubmit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Base Gubik 330' 330' SV5 1637' 1637' SV4 1767' 1767' SV3 2161' 2161' SV2 2334' 2334' SV1 2655' 2655' Top Ugnu 2946' 2946' UG4A 2978' 2978' UG3 3311' 3300' UG1 3886' 3751' Schrader Bluff M 4319' 4024' Schrader Bluff N 4734' 4284' Schrader Bluff OA 5016' 4454' Schrader Bluff OB 5130' 4524' Base Schrader Bluff / Top 5621' 4829' Colville Mudstone RECEIVED Top HRZ 7666' 6414' Top Kalubik 7842' 6587' KuparukC 7941' 6685' APR I 6 200Z Kuparuk B 8017' 6758' Kuparuk A 8122' 6861' Base Kupaurk/Top Miluveach 8197' 6935' 31. List of Attachments: Summary of Post-Rig and completion Work Previously Submitted: Summary of Daily Drilling Reports, Surveys, Leak Off Test Sumary, V-100 Core Information Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble-.~~/~ ~ Title Technical Assistant Date V- 100 201-059 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. 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 ~' ~, '., ~ .... Well: V-100 Rig Accept: 04/28/01 Field: Prudhoe Bay Unit Rig Spud: 04/29/01 APl: 50-029-23008-00 Rig Release: 05/20/01 Permit: 201-059 Drilling Rig: Nabors 7ES POST RIG WORK 09/23/01 PULL BPV, FOUND ICE IN TUBING @ 246' SLM. RDMO. WELL SHUT IN. 09/29/01 MIRU DS CTU #5. RIH WITH 2.50" DOWN JET NOZZLE. USING 50/50 METHANOL, JET THROUGH OBSTRUCTIONS @ 265' AND 315' TO 324'. RIH TO 7750' CTMD WITHOUT SEEING ANY MORE OBSTRUCTIONS. POOH. LAY IN 50/50 METHANOL FROM 2500' TO SURFACE TO FREEZE PROTECT TUBING. RD DS CTU #5. 09/30/01 PULL B&R FROM 7772' SLM. PULL 1" RPV FROM STA#2 (5903' SLM). SET 1" DGLV IN STA #2 W/BK LATCH. PULL RHC FROM 7769' SLM. TAG TD @ 8305' CORR TO MD W/2 7/8 DG. RDMO. JEWELRY LOG DONE. 2 7/8" HSD 2906 PJ, 6 SPF. SHOOTING INTERVALS: 8080 FT - 8082 FT. CCL-T. SHOT 9 FT. CCL STOP @ 8071 FT. SHOT SUCCESSFUL. STOP COUNTS BEFORE AND AFTER PUMPING AT 8099 FT. 5507 PSI MAX PRESSURE RECORDERED BEFORE BREAK DOWN. 3 UP TEMP PASSES @ 100 FPM. DONE STEP RATE TEST. TAGGED TD 8301 FT. I 0/05/01 SET 4 1/2 XX PLUG IN BVN @ 2192' WLM W/4 1/2 EQ. DEVICE AND 650 PSI OF FLUID PRESSURE BELOW PLUG. 02/13~O2 PULL BPV. PULL 4 1/2" XX PLUG @ 2192' SLM D/T W/3 3/8 DG TEL SB TAG TD @ 8307' CORR. TO MD RDMO. WELL SHUT IN. RDMO 0311 2/02 PERFED INTERVAL 7944'-7990' & 7998'-8003' USING 2 1/2" HSD POWERFLOW CHARGES - 6 SPF - 60 DEG PHASING, SHOTS ORIENTED 10 DEG OFF BOTTOM. EH = 0.6", PENE = 5.25'. ALL SHOTS FIRED. NOTIFIED PAD OPER OF STATUS - WELL SHUT IN. 03/14/02 RUN PETRODAT STATIC GAUGE. PULL DGLV FROM STA#1 SET DGLV IN STA#1. 03119/02 MIRU COIL #8. VERY TIGHT LOCATION W/NORCON ON SIGHT. TAG TD 8307' CORRECTED. PUMPED 7800# 8 PPA SAND PLUG (38 BBLS) 1 FOR 1. SAND OUT OF COIL AT 6500'. PULL TO SAFETY 5000'. WAIT 3 HOURS AND TAG SAND. TAGGED SAND TOP AT 8052' CTMD. PU @ 8050' CTMD. PUH TO 7700' WHILE PUMPING DOWN COIL. WAIT 1 HR. RIH AND TAGGED SAND TOP AT 8035' CTMD. PU @ 8032' CTMD. PUH TO 7700'. PUMPED DOWN BACKSIDE. RBIH AND TAGGED SAND TOP AT 7979' CTMD. REPEAT PUMPING DOWN BACKSIDE AND CONFIRMED TAG AT 7979'. FP COIL WHILE POOH MAINTAINING 2100 PSIG WHP. 03/20/02 POOH. FP WELL WHILE DOING INJECTIVITY TEST. BULLHEADED 3 BPM @ 2380 PSIG WHP. FP WITH 60/40 METHANOL TO 3000'. SECURE WELL. RD DS CTU #8. 03/21102 D/T W/3.625" CENT, TEL, & SAMPLE BAILER. V-100, Post Drilling Work Page 2 03/22/02 D/T W/3.625' CENT. AND TEL TO 7980' CORRECTED TD. DUMP BAIL 5 GAL LAYTEX ON SAND TOP. SET 4 1/2" XN C-SUB. PULLED STA# 1 DGLV. SET STA# 1 BTM LATCH SPMG. MITIA TO 3500 PSI. PASS. PULL 4 1/2 XN C-SUB. LEFT WELL SHUT IN. O3~24~O2 FRAC'D PERFS 7944'-80' WITH YF125LG SYSTEM AND 220.15 K# C-LITE BEHIND PIPE. SCREENED OUT 81 BBLS INTO FLUSH TO 7379 PSI. PLACED 184 K# 16/20 AND 36.5 K# 12/18 IN PERFS LEAVING 12.7K# (21 BBLS) 12/18 IN TBG/CSG. EST TOS IS +-4500'. AVG TREATING PRESSURE WAS 4800 PSI. LOAD TO RECOVER IS 1365 BBLS. ALL TREESAVER CUPS WERE RECOVERED. WELL IS NOT FREEZE PROTECTED, HEATER IS APPLIED TO WELLHEAD. 03/26/02 MIRU DOCT #3. THAW TREE AND JET THRU ICE PLUG W/2.5" DJN TO 160' W/METH. 03~27~02 CON'T DOWN JETTING HARD ICE PLUG W/CRUDE THEN SLICK 1% KCL. TO 880' CTMD, STRINGERS TO 1070' CTMD. DRIFT TO 3000'. POOH. WEEKLY BOP TEST. RIH. TAG TOP OF SAND @ 6558.1' (CTM). REVERSE CLEAN OUT TO 7700'. CLEAN OUT TO 8133'. CHASE TO SURFACE AT 80%. PUMP FP TO 3500' (20 BBLS NEAT, 50 BBLS 60/40). LEAVE WELL SI. 03/30/02 D/T 3.53" CENT TO 8033' ELM COR = 59' OPEN PERFS & 49' OF FILL. - WELL LEFT SI. 03/31102 SET 4-1/2" WHIDDIN CATCHER @ 7764' WLMD -- PULL SPMG FROM GLM # 1 @ 7666' MD -- PULL DGLV FROM GLM # 2 @ 5915' MD. SET NEW 16/64" 1821 TRO LGLV IN GLM # 2. SET NEW 20/64" OGLV IN GLM# 1. PULL CATCHER FROM 7764' WLMD. 04101/02 PULLED CATCHER SUB. WELL READY TO BE POP. 04102/02 LOAD IA WITH 180° F CRUDE TO HEAT WELLBORE. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X INITIAL PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 565' FNL, 1531' FEL, Sec. 11, T11 N, R11 E, UM At top of productive interval 8' FNL, 3850' FEL, Sec. 12, T11N, R11E, UM At effective depth 11' FNL, 3778' FEL, Sec. 12, T11N, R11E, UM At total depth 13' FNL, 3757' FWL, Sec. 12, T11 N, R11E, UM 5. Type of Well: Development _ Exploratory__ Stratigraphic__ Service_X (asp's 590771, 5969964) (asp's 593724, 5970557) (asp's 593796, 5970556) (asp's 593817, 5970554) 6. Datum elevation (DF or KB feet) RKB 84 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number V-100 9. Permit number / approval number 201-059 10. APl number 50-029-23008 11. Field / Pool Prudhoe Bay Field / Borealis Pool 12. Present well condition summary Total depth: measured true vertical 8405 feet 7139 feet Plugs (measured) Effective depth: measured 8303 feet true vertical 7039 feet Junk (measured) Casing Length Size Conductor 80' 20" Surface 2706' 9-5/8" Production 8359' 7" Cemented Measured Depth True Vertical Depth 260 SX Arctic Set (Approx 164' 164' 400 sx AS Lite 3, 234 sx Class 'G' 2735' 2735' 428 sx Lite Crete 'G', 8388' 7122' 278 sx Class 'G' Perforation depth: measured Open Perfs 8080'- 8082' true vertical Open Perfs 6821' - 6823' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 TBG @ 7743'. 4-1/2" 12.6~ Tubing Tail to 7800'. Packers & SSSV (type & measured depth) 7" x 4-1/2" BKR S-3 Packer @ 7743'. 4-1/2" HES 'X' Nipple @ 2209'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure (see attached) 14. Prior to well operation 09/29/2001 Subsequent to operation 11/09/2001 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In Well Shut-In Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil__ Gas __ Suspended_ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schndt'r ~ Form 10-404 Rev 06/15/88 · Date November 11, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 2 2 2002 bp L Obo q Date: 12-07-2001 Transmittal Number:92354 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type V-100 09-30-2001 SCH I 7000 8301 PRESSURE LOG; TEMPERATURE LOG; STRESS TEST; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Kim Lawrence MB6-4 Attn: BP North Slope Wells Tech Aide Attn: Phillips Alaska (Vault) Attn: Susan Nisbet (Exxon Mobil Production CO. Attn: Margaret Wong (Exxon Mobil Production CO. Attn: Tim Ryherd (DNR) Attn: Lisa Weepie (AOGCC) RECEIVED DEC 0 7 ;;'.~r"~l Alaska 011 & Gas Cons. Oommissio~ Anchorage Petrotechnical 'Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA I' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service ~ ~USP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-059 '3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23008-00 4. Location of well at surface ~:'~'i!';~.~.'."i'~:'~.:i. i.i'i:..~,~~ 9. Unit or Lease Name 4714' NSL, 1531' WEL, SEC. 11, T11N, R11E, UM ~ ?~.::.;; Prudhoe Bay Unit At top of productive interval~{ ----~--' ~,?-'.___ 5271' NSL, 1429' EWL, SEC. 12, T11N, R11E, UM At total depth i__]i~ ..... :' 10. Well Number 5266' NSL, 1521' EWL, SEC. 12, T11N, R11E, UM· -- ........................... ,. V-100 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) ;6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool KBE = 83.60' ADL 028240 (Undefined) 12. Date Spudded 4/29/2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'5/11/2001 5/20/2001 115' Water depth' if °fish°re N/A MSL 110' N°' °f c°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 8405 7138 FTI 8304 7040 FTI [] Yes [] NoI (Nipple) 2209' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, DIR, RES, AlT, DT, BHC, CNL, LDL, Caliper, SP, MRES, CMR, MDT, ECS, USIT 23. , CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 2737' 12-1/4" 427 sx AS Lite 3~ 202 sx Class 'G' 7" 26# L-80 26' 8388' 8-3/4" 392 sx Lite Crete 'G', 336 sx Class 'G' , , , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) NONE 4-1/2", 12.6#, L-80 7800' 7743' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 77 bbls Diesel , 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not On Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Sul~t~,~s, .~ ~ SEP 1 .Alaska Oil & Gas Cons. Comrnis$io~ Anchorage Form 10-407 Rev. 07-01-80 ORiGiNAL NOV 21 2001 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Base Gubik 330' 330' SV5 1637' 1637' SV4 1767' 1767' SV3/" 2161' 2161' SV2 2334' 2334' SVl 2655' 2655' Top Ugnu 2946' 2946' UG4A f 2978' 2978' UG3 3311' 3300' UG 1 3886' 3751' Schrader Bluff M 4319' 4024' Schrader Bluff N 4734' 4284' Schrader Bluff OA 5016' 4454' Schrader Bluff OB 5130' 4524' Base Schrader Bluff / Top 5621' 4829' Colville Mudstone CMl 7068' 5851' Top H RZ 7666' 6414' Top Kalubik 7842' 6587' Kuparuk C 7941' 6685' Kuparuk B 8017' 6758' Kuparuk A 8122' 6861' Base Kupaurk / Top Miluveach 8197' 6935' 31. List of Attachments: Summary of Daily Drilling Reports, SUrveys, Leak Off Test Sumary, V-100 Core Information Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~'~.~ .~~ Title TechnicalAssistant Date 0?'~l~-OI V- 100 201-059 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. /Approval No. INSTRUCTIONS GE,E;,nL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IT£M 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 ORIGINAL V-1 O0 Core Information for State Completion Report Conventional Core Core 1: 7930-7992.5' MD (62.5' total). 7930-7940.5', Kalubik Formation, dark gray shale, becoming medium gray and sandy shale at the base. 7940.5-7989' MD, Kuparuk C sandstone, very fine to fine grained, bioturbated, slightly to very shaly, with patchy siderite cement and patchy medium to dark brown oil stain, fair porosity. 7989-7992.5' MD, very shaly sandstone or siltstone, very low perm, very little oil stain. Core 2: 7995'-8117' MD (122' total). 7995'-8019.5 MD, Kuparuk C siltstone and very fine grained sandstone, bioturbated, w/patchy siderite cement, poor to fair porosity (fair porosity has medium brown oil stain). 8019.5'-8117' MD, Kupamk B, burrowed, interbedded, fine laminae of dark gray shale, light gray siltstone, and light to medium brown, oil stained, very fine grained sandstone. Sidewall Cores: 45 sidewall cores attempted, 45 recovered. Depths (MD): 3006', 3051', 4098', 4206', 4253', 4339', 4429', 4487', 4553', 4660', 4741', 4757', 4784', 4793', 4860', 5021', 5031', 5047', 5063', 5079', 5085', 5138', 5145', 5154', 5171', 5204', 5222', 5304', 5319', 5382', 5394', 5403', 5414', 5432', 5494', 5508', 5519', 5557', 5565', 5574', 5583', 6173', 8137', 8141', and 8143'. " " .... ': ..." :..'::.... '. ".' BP"EXPLORATIO Page lofl .:...... '.'i:'.': .:Leak'Off'Test.'"S. umm~:~ Legal Name: V-100 Common Name: V-100 TeSt Date. 'Test Type .'. Test DePth(TMD) TeSt. DePth (TVD) AMW' ~surface Pressure Leak Off Pressure (BHP) EMW 5/4/2001 LOT 2,781.0 (ft) 2,781.0 (ft) 9.10 (ppg) 1,055 (psi) 2,370 (psi) 16.40 (ppg) Printed: 5/24/2001 2:47:12 PM BP EXPLORATION Page 1 of 6 Operations Summa Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4/27/2001 00:00 - 00:00 24.00 MOB 3 'PRE 'Moving Nabor's 7 ES from DS-16-23A to V-100 location. 4/28/2001 00:00 - 16:30 16.50 MOB ~ PRE Spot Rig, Pits and camp. 16:30 - 00:00 7.50 MOB ~ PRE Continue RU. Nipple up diverter and diverter line. RIG ACCEPTED 17:00 hrs, 4/28/01. 4/29/2001 00:00 - 03:00 3.00 MOB 3 PRE Continue to RU the Diverter system, function test same. John Crisp - AOGCC waived the requirment to witness. 03:00 - 09:00 6.00 DRILL ~ SURF PJSM, PU, and stand back 1,960' of 4" DP. PU and stand back 647', 5" HWDP. 09:00 - 10:00 1.00 DRILL P SURF Service the Top Drive. 10:00- 12:00 2.00 DRILL P SURF PJSM, PU/MU BHA #1, check crown-o-matic. 12:00 - 13:00 1.00 DRILL P SURF PJSM, Held pre-spud meeting with both crews. 13:00 - 16:00 3.00 DRILL P SURF MU directional tools and orient, fill conductor pipe, and check for leaks - ok. 16:00 - 00:00 8.00 DRILL P SURF Drill out from Conductor to 600'. 4/30/2001 00:00 - 05:30 5.50 DRILL P SURF Continue control drlg 600-884' 05:30 - 06:00 0.50 DRILL P SURF Circ. btms up, monitor well - okay. 06:00 - 08:00 2.00 DRILL ;P SURF POOH, no over pull probs., monitor well - stable. Inspect bit-in guage, bearings good. RIH picking up 5" HWDP. 08:00 - 12:00 4.00 DRILL P SURF Control drill 884'-1,300' (wob=12, rpm=100, flow=507 gpm) 12:00 - 17:30 5.50 DRILL P SURF Control drill 1,300'-1,998'. 17:30 - 18:00 0.50 DRILL P SURF Circ. Btms up. 18:00 - 19:30 1.50 DRILL P SURF Short trip to 782' - no probs. 19:30 - 00:00 4.50 DRILL P SURF Cont. Control drlg to 2,361' (wob=10-15, rpm=150, flow=598 gpm). 5/1/2001 00:00 - 07:00 7.00 DRILL P SURF Con't ~ Control drlg f/2361' to 2761' ( wob = 10-15 k, rpm = 150 @ 598 gpm) ART = 5.25 Hrs. 07:00 - 08:00 1.00 DRILL P SURF Circulate bottoms up. Monitor well - static. 08:00 - 09:30 1.50 DRILL P SURF Short trip f/2761' to 1650'. 20 k operpull f/2174' - 2118', 2060' to 1990'. Monitor well - static. RIH f/1650' to TD @ 2761' with no problems. 09:30 - 11:30 2.00 DRILL P SURF Circ & condition hole. pump dry job. Monitor well - static. 11:30 - 15:30 4.00 DRILL P SURF POH & L/D BHA.Bit & stabilizer balled up. No drag on trip out. ESS check shots @ 2593', 2487', 2407'. 15:30 - 16:00 0.50 DRILL P SURF Clear floor & secure handling tools. 16:00 - 17:30 1.50 DRILL P SURF Slip & Cut drilling line, & adjust brakes. 17:30 - 18:30 1.00 DRILL P SURF P/U & M/U Csg hanger & landing it. Dummy run. 18:30 - 21:00 2.50 DRILL P SURF R/U casing equipment & handling tools, & R/U Franks Csg fill up tool. 21:00 - 22:00 1.00 DRILL P SURF PJSM 22:00 - 00:00 2.00 DRILL P SURF Run 9 5/8" 40#, L-80, BTC-M Csg with float shoe, float collar, & 15 cantralizers to 1497'. 5/2/2001 00:00 - 02:30 2.50 DRILL P SURF Con't ~ RIH w/9 5/8", 40#, L-80, BTC Csg F/1497' to 2736.63'. Ran 67 Jts total w/float shoe, float collar, 17 cent, & TAM port collar. (stg wt = 130 k up & 125 k dn). M/U landing jt w! hanger & land same. 02:30 - 08:00 5.50 DRILL P SURF Circulate bottoms up & condition mud for cement job while reciprocating Csg (stg wt = 135 k up & 125 k dn). 08:00 - 09:00 1.00 DRILL N SFAL SURF Manifold bypass line washed out. Replace washed out line & pressure test same to 2500 psi - OK. 09:00 - 09:30 0.50 DRILL P SURF PJSM Printed: 5/24/2001 2:47:20 PM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 5/2/2001 09:30 - 12:00 2.50 DRILL P SURF R/U Dowell & pressure test lines to 3500 psi - OK. Pump 75 Bbls 10.1 # mud push, 338 Bbls lead cmt @ 10.7#, followed by 43 Bbls tail cmt @ 15.8 #. Drop plug & displace w/203 Bbls 9.6 # mud w/rig pump. Plug bumped w/1500 psi & floats held OK. Cement in place @ 11:54 Hrs. Recovered 102 Bbls 10.7 # cmt. Reciprocate Csg during cmt job. 12:00 - 14:00 2.00 DRILL P SURF R/D Dowell-Schlumberger, & R/D cementing equipment. Pull landing jt & clean out diverter & lines. 14:00 - 19:00 5.00 DRILL P SURF R/D diverter lines, bell nipple, DSA adaptor, & hydril. ,19:00 - 22:00 3.00 DRILL P SURF N/U casing head & tubing spool. Pressure test same to 1000 3si - OK. Aligned csg/tbg head valves as per DSO Ron Zugg 22:00 - 00:00 2.00 DRILL P SURF N/U BOP stack & flow line. 5/3/2001 00:00 - 02:30 2.50 DRILL P SURF Con't ~ N/U BOPE. 02:30 - 04:00 1.50 DRILL P SURF PJSM. Pressure test choke manifold (250 psi Iow & 3500 psi high) - OK. 04:00 - 04:30 0.50 DRILL P SURF Service top drive unit. 04:30 - 05:00 0.50 DRILL P SURF Move 5" HWDP to drillers side pipe rack. 05:00 - 10:30 5.50 DRILL P SURF Con t ~ Pressure test BOP stack, etal, as per BP standards (250 psi Iow & 3500 psi high) - OK. Pull test plug & reset wear ring. 10:30 - 11:00 0.50 DRILL P SURF Pressure test rig floor manifold to BP standards (250 psi Iow & 3500 psi high) - OK. Blow down lines & secure test equipment. 11:00 - 15:30 4.50 DRILL P SURF P/U 3823' of 4" HT-40 drill pipe & stand same in derrick. 15:30 - 19:30 4.00 DRILL P SURF PJSM. P/U Bit # 2 & BHA # 2. Orient directional tools & load MWD tools. Shallow test directional ass'y - OK. RIH to 853'. 19:30 - 21:00 1.50! DRILL P SURF Change out elevators & RIH picking up 4" drill pipe. Tag top of cement @ 2642'. 21:00 - 23:00 2.00 DRILL P SURF Circulate hole & hold PJSM. Perform ClT on 9 ~58" 40#, L-80, BTC Csg to 3500 psi w/9.6 ppg mud & hold same for 30 min - OK. CIT times & pressures recorded. 23:00 - 00:00 1.00 DRILL P SURF Drill cement from TOC @ 2642' to 2673'. 5/4/2001 00:00 - 02:00 2.00 DRILL P SURF Con't ~ drill out cement f/2673' to float shoe @ 2736'. Drill out rat hole to 2761'. 02:00 - 02:30 0.50 DRILL P SURF Drill new formation f/2761' to 2781'. 02:30 - 04:00 1.50 DRILL P SURF Circulate hole clean & displace hole w/4% KCL LSND mud, as per program. 04:00 - 04:30 0.50 DRILL P SURF Perform LOT @ 2781'. LOT presure = 1055 psi w/9.1 ppg. EMW = 16.39 ppg. 04:30 - 05:00 0.50 DRILL P SURF Directional drill 8 3/4" hole w/1.22 Deg mtr fl 2781' to 2818'. MWD = GR, RES, PWD, & DIR. (stg wi: - 115 k up, 110 k dh, & 115 k rot). ART = 1/2 Hr. 05:00 - 08:30 3.50 DRILL P SURF Circulate hole & increase mud weight to 9.4 ppg. 08:30 - 22:00 13.50 DRILL P SURF Directional drill 8 3/4" hole w/1.22 Deg mtr f/2818' to 3950'. MWD = GR, RES, PWD, & DIR. (stg wt= 115 k up, 110 kdn, & 115 k rot). ART = 2 3/4 Hr & AST = 4 3/4 Hr. Increase mud weight to 9.6 ppg while drilling. 22:00 - 23:00 1.00 DRILL P SURF Circulate bottoms up. Pump hi-vis sweep & monitor well - static. 23:00-00:00 1.00 DRILL P SURF Short trip into 9 5/8" Csg @ 2735'. (stg wt = 120 k up, & 110 k dn). Monitor well - static. 5/5/2001 00:00 - 01:00 1.00 DRILL P PROD1 RIH f/2375' to TD @ 3950'. No hole problems. Printed: 5/24/2001 2:47:20 PM BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 5/5/2001 01:00 - 21:30 20.50 DRILL P PROD1 Directional drill 8 3~4" hole w/1.22 Deg mtr f/3950' to 5904'. MWD = GR, RES, PWD, & DIR. (stg wt = 135 k up, 110 k dn, & 125 k rot). ART = 13 1/4 Hr & AST + 1.0 Hr. 21:30 - 22:30 1.00 DRILL P PROD1 Pump hi vis sweep & circulate bottoms up. 22:30 - 00:00 1.50 DRILL P PROD1 Short trip f/5904' to 3886'. No hole problems, monitor well - static. 5/6/2001 00:00 - 00:30 0.50 DRILL P PROD1 RIH f/3886' to TD @ 5904" with no problems. 00:30 - 01:00 0.50 DRILL P PROD1 Circulate bottoms up. 01:00 - 00:00 23.00 DRILL P PROD1 Directional drill 8 3/4" hole w/1.22 Deg mtr f/5904' to 7280'. MWD = GR, RES, PWD, & DIR. (stg wt = 175 k up, 125 k dn, & 145 k rot). ART = 8.0 Hrs & AST + 9.0 Hr. 5/7/2001 00:00 - 10:30 10.50 DRILL P PROD1 Directional drill 8 3/4" hole w/1.22 Deg mtr f/7280' to 7679'.. MWD = GR, RES, PWD, & DIR. (stg wt = 185 k up, 130 k dn, & 155 k rot). ART =4 3/4 Hrs & AST = 3 1/2 Hr. 10:30 - 12:00 1.50 DRILL P PROD1 Circulate hole clean, monitor well - static. 12:00 - 18:30 6.50 DRILL P PROD1 POH. Stand back drill string & L/D BHA. Down load MWD information. Note - 20 - 35 k over pull @ 5950' - 5800', 5770' - 5640', 5170', & 4920'. All tight spots wiped clean. 18:30 - 20:30 2.00 DRILL P PROD1 M/U BHA # 3 with bit # 2 RR. RIH to 3300' & shallow test MWD - OK. Con't RIH to 2700'. 20:30 - 22:30 2.00 DRILL P PROD1 PJSM. S p & cut drilling line & service top drive unit. 22:30 - 00:00 1.50 DRILL P PROD1 Con't RIH f/2700' to 5497'. Fill pipe & monitor well. 5/8/2001 00:00 - 01:00 1.00 DRILL P PROD1 Con't ~ RIH f/5497' to 7613'. No hole problems. 01:00 - 01:30 0.50 DRILL P PROD1 MAD PASS f/7613' to TD @ 7679'. 01:30 - 08:30 7.00 DRILL P PROD1 Drill 8 3/4" hole f/7679' to Core Point @ 7930'. MWD = GR, RES, & PWD. (Stg wt = 200 k up, 130 k dn, & 155 k rot). 08:30 - 12:30 4.00 DRILL P PROD1 Circulate hole clean with hi-vis swep. Displace hole with coring fluid, as per program. 112:30 - 18:30 6.00 DRILL P PROD1 POH, down load MWD information, & L/D BH^ # 3. 18:30 - 19:00 0.50 DRILL P PROD1 Service top drive unit. 19:00 - 21:00 2.00 DRILL P PROD1 PJSM. P/U & M/U BHA #4 Coring Assembly. RIH to 786' & pump thru BHA # 4 - OK. 21:00-00:00 3.00 DRILL P PROD1 Con't RIH w/BHA #4 to 5400'. (Stg wt = 150 k up & 115 k dn). 5/9/2001 00:00 - 01:00 1.00 DRILL P PROD1 Con't ~ RIH f/6387' to 7835'. 01:00 - 02:00 1.00 DRILL P PROD1 Wash down f/7835' to TD @ 7930' & circulate bottoms up. 02:00 - 05:00 3.00 DRILL P PROD1 Drop ball & start 8 1/2" coring operations. (stg wt = 195 k up, 135 k dn, & 155 k rot). Core from 7930' to 7996'. 05:00 - 06:00 1.00 DRILL P PROD1 Circulate bottoms up, monitor well - static. Mix & pump dry job. 06:00 - 13:00 7.00 DRILL P PROD1 POH with 8 1/2" coring ass'y, as per program. 13:00 - 15:30 2.50 DRILL P PROD1 L/d core & stand back core barrels.. Note - drilled 65' & recovered 63' of core. 15:30 - 19:30 4.00 DRILL P PROD1 Pull wear ring & set test plug. Pressure test BOP stack, et al, as per BP standards (250 psi Iow f/5 min & 3500 psi high f/10 rain). All componants pressure tested - OK. Choke maniflod was tested during POH. All pressures charted & recorded. Recover test plug & reset wear ring. Note - AOGCC rep, Mr. Chuck Scheeve, waived to witness the pressure testing operations. 19:30 - 22:00 2.50' DRILL P PROD1 M/U BHA # 5 (coring ass'y) & RIH to 816'. Shallow test BHA # 5 - OK. Printed: 5/24/2001 2:47:20 PM BP EXPLORATION Page 4 of 6 Operations Summa Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 5/9/2001 19:30 - 22:00 2.50 DRILL ~ PROD1 22:00-00:00 2.00 DRILL P PROD1 Con't ~ RIH w/BHA # 5 to 5485'. (stg wt = 130 k up & 110 k dn). 5/10/2001 00:00 - 01:30 1.50 DRILL 3 PROD1 Con't ~ RIH w/coring ass'y to 7945'. 01:30 - 03:00 1.50 DRILL 3 PROD1 Circulate bottoms up & ream to TD @ 7996'. 03:00 - 06:30 3.50 DRILL 3 PROD1 Drop ball & core 8 1/2" hole fl 7996' to 8117'. (stg wt = 200 k up, 135 k dn, & 155 k rot). Monitor well - static. Mix & pump dry job. 06:30 - 12:30 6.00 DRILL P PROD1 POH with coring ass'y, pulling speed is as per procedure. 12:30 - 17:00 4.50 DRILL P PROD1 LID core & outer core barrels, & clear floor. Note - drilled 122' & recovered 121'of core. 17:00 - 21:00 4.00 DRILL P PROD1 PJSM. M/U BHA#6 (Rotary Pendleum ass'y) with RR bit #2 & RIH to 828'. Shallow test MWD - OK. Con't RIH to 2700'.. 21:00 - 22:30 1.50 DRILL P PROD1 PJSM. Slip & cut drilling line & service top drive unit. 22:30 - 00:00 1.50 DRILL P PROD1 Con't RIH f/2700' to 5497'. 5/11/2001 00:00 - 01:30 1.50 DRILL P PROD1 Con't ~ RIH w/8 3~4" drilling ass'y f/5497' to 7930'. 01:30 - 04:00 2.50 DRILL P PROD1 Ream 8 1/2" core interval (7930' to 8117') to 8 3/4". 04:00 - 12:30 8.50 DRILL P PROD1 : Drill 8 3/4" hole f/8117' TD @ 8405". MWD = GR, RES, & ,PWD. (Stg wt = 210 k up, 135 k dn, & 160 k rot). 12:30 - 13:30 1.00 DRILL P PROD1 Pump hi-vis sweep & circulate bottoms up. Monitor well - static. 13:30 - 14:30 1.00 DRILL P PROD1 Short trip f/TD @ 8405' to 7450' & return to TD. No hole problems. 14:30 - 16:00 1.50 DRILL P PROD1 Pump hi-vis sweep & circulate hole cleam. Monitor well - static. Drop 2 1/4" Rabbit. 16:00 - 20:00 4.00 DRILL :P PROD1 PJSM. POH (SLM) for open hole logs. 20:00 - 22:00 2.00 DRILL 'P PROD1 Break bit, down load MWD information, & LJD BHA # 6. Clear floor & secure handling tools. 22:00 - 00:00 2.001 EVAL i P PROD1 PJSM. Rig up Schlumberger & pick up open hole logging tools. 5/12/2001 00:00 - 01:00 1.00 EVAL P PROD1 Con't pick up Schlumberger open hole tools for run @ 1. 01:00 - 13:00 12.00: EVAL P . PROD1 Run # 1 with Schlumberger's Platform Express package (Spectral GR, Array Induction & SP, Lith Density, Thermal Neu, Microresistivity, & DSl), as per procedure. Loggers TD = 8406'. 13:00 - 14:00 1.00 EVAL P PROD1 RID & LID logging tools from Run # 1. 14:00 - 18:00 4.00 EVAL P PROD1 P/U & M/U Schlumberger's drill pipe conveyed open hole logging tools for run # 2. Run # 2 = CMR, MDT, GR, & ECS, with pressures & samples in the Schrader & Kuparuk formations (as per Bob Dawson). 18:00 - 20:00 2.00 EVAL N SFAL PROD1 Trouble shoot Schlumber tool failure in drill pipe conveyed logging package & wait on replacement tools. 20:00 - 21:30 1.50 EVAL P PROD1 Con't P/U & M/U Schlumberger's drill pipe conveyed open hole logging tools for run # 2. 21:30 - 23:30 2.00 EVAL P PROD1 RIH to 2675', filling drill pipe every 1500' (stg wt = 90 k up & 90 k dn). 23:30 - 00:00 0.50 EVAL P PROD1 PJSM & hang sheave in derrick. 5/13/2001 00:00 - 08:00 8.00 EVAL P PROD1 Con't ~ RIH w/Schlumberger's drill pipe conveyed open hole 'logging tools for run # 2. Run # 2 -- CMR, MDT, GR, & ECS, with pressures & samples in the Schrader & Kuparuk iformations (as per Bob Dawson). RIH f/2675' to 7680'. 00:00 - 08:00 8.00 EVAL P PROD1 Con't ~ RIH with Schlumberger's drill pipe conveyed open hole :logging tools for run # 2. Run # 2 = CMR, MDT, GR, & ECS, .with pressures & samples in the Schrader & Kuparuk formations (as per Bob Dawson). RIH to 7680'. Printed: 5/24/2001 2:47:20 PM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/13/2001 08:00 - 10:30 2.50 EVAL P PROD1 M/U side entry sub & R/U Schlumberger. RIH with wireline to 7200'. Pump down & latch into wet connect @ 7680'. Test wireline tools - OK. 08:00 - 10:30 2.50 EVAL P PROD1 M/U side entry sub & RJU Schlumberger. RIH w/latching tool to 7200'. Pump down wireline tool & latch on @ 7680'. Test logging tools - OK. 10:30 - 22:30 12.00 EVAL P PROD1 Log down f/7980' to 8374'. Log up f/8374' to 8000' taking 3ressures & samples. 10:30 - 22:30 12.00 EVAL P PROD1 Log down from 7680' to 8374' & log up 8374' to 8000'. (Samples taken as per instructions from Bob Dawson). 22:30 - 00:00 1.50 EVAL P PROD1 POH f/8000' to 7680'. POH with wireline, LID side entry sub, & clear floor of Schlumberger tools. Note - CMT tool failed on run # 2 & will have to be re-run on additional wireline run. 22:30 - 23:30 1.00 EVAL P PROD1 POH with drill string f/8000' to7680'. 23:30 - 00:00 0.50 EVAL P PROD1 POH with wireline, RID side entry sub, & lay down E-line tools. Note - CMR tool failed & will have to be run on an additional wireline run. 5/14/2001 00:00 - 01:30 1.50 EVAL P PROD1 Con't POH w/wireline. RID side entry sub & clear floor of Schlumberger equipment. 01:30 - 04:00 2.50 EVAL P PROD1 ;Monitor well - static. Mix & pump dry job. POH f/7680' to 3018'. 04:00 - 05:30 1.50 EVAL P PROD1 , R/U Schlumberger equipment on floor. R/U side entry sub& RIH w/wireline wet connect ass'y. Latch into logging tools & check tools - OK. 05:30 - 20:30 15.00 EVAL P PROD1 ! Con't logging down fl 3018' to 5414' w/Schlumberger's drill !pipe conveyed open hole logging tools for run # 2. Run # 2 = 'CMR, MDT, GR, & ECS, with pressures & samples in the Schrader & Kuparuk formations (as per Bob Dawson). 20:30 - 23:00 2.50 EVAL P PROD1 Log up f/5414' to 5031' (stg wt = 140 k up & 105 k dn). 23:00 - 00:00 1.00 EVAL P PROD1 RIH f/5031' to 5600'. 5/15/2001 00:00 - 04:30 4.50 EVAL P PROD1 Continue DPC logging f/5600' to 3018'. 04:30 - 06:00 1.50 EVAL P PROD1 POH w/wireline. LID side entry sub. 06:00 - 07:00 1.00 EVAL P PROD1 TOH w/logging tools on drill pipe. 07:00 - 11:00 4.00 EVAL P PROD1 L/D tools, samples. 11:00 - 12:30 1.50 EVAL P PROD1 R/U wireline tools, FMI/CMR/GR. 12:30 - 15:30 3.00 EVAL P PROD1 RIH w/wireline. Unable to get below 4995' WLM. POH. Decision made to abandon FMI/CMR logging run. 15:30 - 17:30 2.00 EVAL P PROD1 Load charges in side wall coring tools. 17:30 - 22:00 4.50 EVAL P PROD1 RIH to 8300', no obstructions. Logging sidewall cores. 22:00 - 00:00 2.00 EVAL P PROD1 Removed 45 sidewall cores, 100% recovery. PJD wireline 5/16/2001 00:00 - 05:00 5.00 BOPSUF:P PROD1 Pull wear ring. Tested BOP 250~3500 psi. (Tested choke while wirelining.) Witness of test waived by Chuck Scheeve, AOGCC. 05:00 - 06:30 1.50 CASE P PROD1 RIH w/cleanout BHA to 2650'. 06:30 - 08:00 1.50 CASE P PROD1 Slip and cut drilling line. Service top drive. 08:00 - 08:30 0.50 CASE P PROD1 Circ and condition mud. 08:30 - 11:00 2.50 CASE P PROD1 i Finish RIH to TD @ 8405'. No hole problems. 11:00 - 13:30 2.50 CASE P PROD1 Pump viscous sweep. Circ and cond mud. No escessive : cuttings in returns. 13:30 - 17:00 3.50 CASE P PROD1 POH. Wipe 35 K overpull @ 7975'. Finish POH to BHA. 17:00 - 19:00 2.00 CASE P PROD1 ~L/D HWDP, bit. 19:00 - 21:00 2.00 BOPSUE P PROD1 'Pulled wear bushing and installed test plug. Changed top pipe :rams to 7" Printed: 5/24/2001 2:47:20 PM BP EXPLORATION Page 6 of 6 Operations Summa Report Legal Well Name: V-100 Common Well Name: V-100 Spud Date: 4/29/2001 Event Name: DRILL+COMPLETE Start: 4/27/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations '5/16/2001 21:00 - 23:00 2.00 CASE 3 PROD1 Make dummy run w/landing jt. R/U casing equipment. 23:00 - 00:00 1.00 CASE P PROD1 Run 7" 26~ L-80 BTCM casing. 5/17/2001 00:00 - 03:30 3.50 CASE ~ PROD1 RIH w/7" 26# L-80 BTC-M casing to 2727'. 03:30 - 04:00 0.50 CASE 3 PROD1 Circ. 04:00 - 12:00 8.00 CASE 3 PROD1 RIH to 8388'. PJU landing jt to circ. (Started loosing returns on Jt #133. RIH, displacing pipe volume to formation.) 12:00 - 16:00 4.00 CASE 3 PROD1 Stage up pumps to 3 bpm, loosing 50% returns. Reciprocate csg. Slowed pumps to 2 bpm, lost 241 bbls mud while circ. PJSM. Batch mix tail cement. : 16:00 - 21:00 5.00 CASE 3 PROD1 Pump 5 bbls CWl00, test lines to 4000 psi. Pmp 35 bbls CW 100. Prop 60 bbls Mudpush XL @ 10.8 ppg. Pmp 200 bbls lead cmt @ 11.0 ppg. Drop btm plug. Pmp 72 bbls tail cmt @ 15.8 ppg. Clear lines. Drop plug and displace w/seawater. Reciprocated thru entire job w/minimal returns. Displaced cmt @ 3.5 bbl/min, bumped plug at calc'd volume, ClP 2100 hrs. 21:00 - 23:00 2.00~ CASE P PROD1 LID landing jt. RID casing equipment. 23:00 - 00:00 1.00 WHSUR P PROD1 Installed packoff and tested to 5000 psi. Installed wear bushing. 5/18/2001 00:00 - 01:30 1.50 CEMT P PROD1 RID casing equipment from rig floor. 01:30 - 02:00 0.50 CEMT P PROD1 Service top drive. 02:00 - 07:00 5.00 CEMT P PROD1 P/U RR bit and csg scraper. RIH to 8303' PBTD. 07:00 - 09:30 2.50 CEMT P PROD1 Displace wellbore to clean seawater. 09:30- 14:00 4.50 CEMT P PROD1 POH LDDP. 14:00 - 15:00 1.00 CEMT P PROD1 Cut and slip drilling line. 15:00 - 17:00 2.00 CEMT P PROD1 Finish POH LDDP. LID casing scraper. 17:00 - 18:00 1.00 CEMT I p PROD1 Closed blind rams and tested casing to 3500 psi for 30 rain, OK. 18:00 - 22:30 4.50 CEMT P PROD1 R/U wireline and run cased hole USIT (cement bond) log. Good cement below 6850'. R/D Schlumberger. 22:30 - 23:00 0.50 CEMT P PROD1 Pulled wear bushing. 23:00 - 00:00 1.00 CEMT P PROD1 R/U tubing handling equipment. 5/19/2001 00:00 - 01:00 1.00 RUNCO~ 13 COMP R/U to run 4-1/2" tubing completion. 01:00 - 07:00 6.00 RUNCO~ 13 COMP Ran 190 jts 4-1/2" L-80 NSCT tubing and 2 GLM. 07:00 - 09:30 2.50 RUNCO~ 13 COMP Reverse circulate seawater and corrosion inhibitor. 09:30 - 11:00 1.50 RUNCO~ 13 COMP Landed tubing. RILDS. Dropped ball/rod assembly. 11:00 - 12:30 1.50 RUNCO~ 13 COMP Pressure tubing to 3500 psi, set packer. Hold for 30 min tubing test. Bleed tubing to 1500 psi. Pressure annulus to 3500 psi for packer test, ok. Bleed off tubing pressure and sheared RP. 12:30 - 13:30 1.00 BOPSUF P COMP L/D landing jr, set TWC. Test to 2500 psi. 13:30 - 23:00 9.50 BOPSUF P COMP Install VBR rams in top cavity. Install blind/shear rams in middle cavity. Change upper riser. N/D BOP stack. 23:00 - 00:00 1.00 BOPSUF P COMP N/U adapter and tree. 5/20/2001 00:00 - 01:00 1.00 WHSUR P COMP Finished N/U adapter and tree. Tested to 5000 psi, OK. 01:00 - 02:30 1.50 WHSUR P COMP R/U DSM and pulled TWC w/lubricator. 02:30 - 04:00 1.50 RUNCOk13 COMP Reverse circulated 77 bbls diesel, U-tube to freeze protect to 2200'. 04:00 - 04:30 0.50 RUNCOk13 COMP Installed BPV and tested to 2500 psi. Rig released for move to W-201 @ 0430 hrs 5/20/2001. Printed: 5/24/2001 2:47:20 PM I IIIllllllllllllllllllllll~lllllllllllllllllllllllllllll"lllll 10202635016 North Slepe Alaska Alaska Drilling & Wells PBU WOA V. Pad, Slot V-lO0 V-~O0 Job No. AKMM~0129, Surveyed: 11 May, 200'I SURVEY REPORT 2f May, 200f Your Ref: API.5002923008 Surface Coordinates: 5969964.37 N, 590770.34 E (70° 19' 39.6167" N, 149° 15' 49.8804" W) Kelly Bushing: 83.60ft above Mean Sea Level DRiL. L. iNI~ .EiI~FIVICIE:= A Halliburton Company Survey Ref: svy10822 0.00 1~2.73 196.57 300.56 389.58 486.49 581.11 674.71 767.61 860.46 946.77 1042.44 1135. gg 1229.81 1322.72 1413.70 1506.82 1600.02 1692.40 1786.15 1881.11 1973.81 2063.83 2160.72 2255.28 2348.23 2428.84 2534.72 2629.53 2722.38 2843.15 2935.17 3028.50 3122.22 3216.10 3310.82 3404.06 349~20 3590.66 3684.23 O. 000 0.090 0.330 O. 79O O. 700 O, 820 0,800 0.670 O. 530 0.440 0.490 0.370 O. 140 O_ 190 0.310 0.640 0.570 0.910 O. 840 0.880 O. 780 0.890 1.260 1.140 1.220 1.270 1.290 1.310 1.290 1.150 1.990 2.510 7.470 12.120 16.800 21.970 26.930 32.850 37.120 41.490 0.000 196.720 216.510 156.000 176.780 175.450 168.420 184.310 170.060 158.240 155.270 183.630 138.450 138.420 158.860 209.050 206.510 203.900 221.950 221.430 233.410 230.570 240.040 257.330 256.870 252.590 260.850 261.210 263.990 266.040 225.690 92.170 78.570 73.090 71.470 73.420 77.530 77.310 75.890 79.420 -83.60 59.13 112.97 216.95 305.97 402.87 497.48 591.07 683.97 776.81 863.12 958.79 1052.34 1146.16 1239.07 1330.04 1423.16 1516.35 1608.72 1702.46 1797.41 1890.10 1980.10 2076.97 2171.51 2264.44 2345.03 2450.88 2545.67 2638.50 2759. 22 2851.21 2944.16 3036.49 3127.37 3216.69 3301.55 3382.27 3458.82 3531.22 0.00 142. 73 196.57 300.55 389.57 486.47 581.08 674.67 767.57 860.41 946.72 1042.39 1135.94 1229.76 1322.67 1413.64 1506.76 1599.95 1692.32 1786.06 1881.01 1973.70 2063.70 2160.57 2255.11 2348.04 2428.63 2534.48 2629,27 2722.10 2842.82 2934.81 3027.76 3120.09 3210.97 3300.29 3385.15 3465.87 3542.42 3614.82 0.00 N 0.11S 0.27 S 1.17S 2.27S 3.55 S 4.88 S 6.06 S 7.03S 7.78 S 8.42 S 9.10S 9.49 S 9.69 S 10.04 S 10.72 S 11.59 S 12. 68 S 13.85 S 14.90 S 15.83 S 16.67 S 17.61 S 18.35 S 18.78 S 19.32 S 19.73 S 20.10 S 20.38 S 20.55 S 22,10 S 23.30 S 22.17 S 18.10 S 10.92 S 1.50 S 8.04 N 18.15N 30. 60 N 43.18 N 0.00 E 0.03 W 0.14 W O. 02 W 0.26 E 0.35 E 0.53E 0.62 E 0.65 E 0.86 E 1.14 E 1.29 E 1.35 E 1.53 E 1,72E 1.50 E 1.10E 0.59 E 0.16W 1.09 W 2.09 W 3.16W 4.55 W 6.42 W 8.31 W 1~26W 12.01W 14.38W 16.51W 18.48W 2I. 19 W 20.32 W 12.33 W 3.07 E 25.37 E 55.35 E 92.71 E 137.99 E 190.09 E 247.98 E 59699..C~.37 N. 5969964.26 N 5969964.10 N 5969963.20 N 5969962.10 N 5969960.82 N 5969959.50 N 596995&32 N 596995~35 N 5969956.60 N 596995&96 N 5969955.28 N 5969954.90 N 5969954.70N 5969954.35 N 5969953.67N 5969952.80 N 5969951.70 N 5969950.52 N 5969949.46 N 596994&51N 595994~67N 596994&71N 5969945.94 N 596994649 N 5969944.93 N 5969944.50 N 5969944.09 N 5969943.79N 5969943.59 N 5969942.01N 596994~83 N 5969942.05 N 5969946.31N 5969953.76 N 5969963.54 N 5969973.53 N 5969984.19 N 596999~27 N 5970010.55 N 590770.34 E 590770.31E 590770.21E 59077G33 E 590770.62 E 590770.73E 590770.93 E 590771.03E 590771.08 E 590771.30 E 590771.58 E 590771.74E 590771.80 E 590771.98 E 590772.18 E 590772.03E 590771.58 E 590771.09 E 59077~35 E 590769.43 E 590768.44 E 59076~39 E 590766.00 E 590764.15 E 590762.25 E 59076~31E 59075&57 E 590756.20 E 590754.07 E 590752.11E 590749.42 E 590750.30 E 590758.28 E 590773. 62 E 590795. 84 E 590825.71E 590862.95 E 590908.10 E 590960.05 E 591017.78 E 0.003 0.459 0.664 ~318 0.125 0.107 0.257 0.219 ~144 0.064 0.252 0.309 0.053 O. 159 0.551 ~080 0.367 0.306 0.043 0.210 0.127 0.455 0.392 0.085 ~114 0.230 0.020 0.070 0.158 1,109 4.499 5.427 5.055 5,003 5.500 5.621 6.357 4.65f 5.245 0.00 -0.05 -0. f9 -0.24 -0. f8 -0.33 -0.40 -0. 53 -0.68 -0.62 -0.47 -0.45 -0.47 -0.33 -0.20 -0.49 -1.10 -1.80 -2. 76 -3.88 -5.04 -6.24 -7. 79 -9.76 -11.70 -13. 72 -15.51 -17.91 -20.06 -22.02 -24.98 -24.35 -16.28 -0.40 22.86 54.08 92.57 138.94 192.46 251.67 MWD Magnetic CONFIDENT/Al_ 3778.64 386'9.63 3965.05 4057.64 4149.50 4234.40 4336.17 4429.77 4523.30 4617.81 4710.31 4773.29 4898.93 4991.62 5077_12 5177.54 5258.39 5357.5O 5449.86 5548.13 5634.53 5731.87 5822.49 5917.59 5010.68 6103.73 6196.63 6289.97 6382.95 6477.31 6572.05 6666.95 6759.22 6854,04 6947.75 7040.13 7133,66 7226.29 73f8.77 7413.03 47.670 · 52.100 51.840 51.61o 50.560 49.310 49.620 49.720 49.640 53.480 53.320 53.380 52.810 52.630 52.180 51.690 51.640 51.710 51.620 51.460 51,040 50.580 50.400 50.110 49.900 49,700 49.540 49.220 49.000 47.050 44.190 4O92O 37.560 33.920 30.480 29.390 25.840 22.830 20.730 17.120 82.030 81.760 81.230 81.520 80.880 80.950 80.810 80.000 79.840 78.890 78.200 77.430 77.820 78.620 78.610 78.420 77. 740 77. 270 77. 790 77.23O 77.030 77. 070 76.450 76.390 76.070 75.440 75.660 79.040 77.950 77.810 79.070 82.040 81.190 80.470 82.020 81.060 81.130 75.430 76.120 85.240 3598.44 365705 3715.84 3773.19 3830.89 3885.54 3951.68 4012.26 4072.78 4131.52 4186.67 4224.27 4299.71 4355.86 4408.02 4469.93 4520.08 4581.54 4638.83 4699.95 4754.03 4815.54 4873.19 4934.00 4993.83 5053.89 5114.07 5174.85 5235.72 5298.82 5365.08 5434.98 5506.44 5583.39 5662.67 5742.73 5825.59 5909.99 5995.87 6085.04 3682.04 3740.65 3799.44 3856.79 3914.49 3969.14 4035.28 4095. 86 4156.38 4215.12 4270.27 430787 4383.31 4439.46 4491.62 4553. 53 4603. 68 4665.14 4722.43 4783.55 4837.63 4899.14 4956.79 501~60 5O77.43 5137.49 5197.67 5258.45 5319.32 5382.42 5448.68 5518.58 5590.04 5666.99 5746.27 5826.33 5909.19 5993.59 6079.47 6168.64 53.77 N 63.59 N 74.70N 85.60 N 96.54N 106.80 N 119.06 N 130.95 N 143.43 N 15710 N 171.85 N 182.52 N 204.05 N 219.11N 232.48 N 248.22 N 261.32 N 278.14 N 293. 78 N 310.43 N 325.43 N 342.34 N 358.35 N 375.52 N 392. 50 N 409.99 N 427. 64 N 443.16 N 457.18 N 471.91 N 485.49 N 496.07 N 504.56 N 513.37 N 521.00 N 527. 78 N 534.49 N 542.13 N 550.57 N 555. 72 N 313.35 E 382.22 E 456.56 E 528.42 E 599.05 E 663.21E 739.58 E 809.93 E 880.15 E 952.88 E 1025.66 E 1075.05 E 1173.18E 1245.38 E 1311.79 E 1389.27 E I451.32 E 1527.23 E 1597.97 E 1673.10 E 1738.79 E 1812.31 E 1880.37 E 1951.44 E 2020. 71 E 2089.60 E 2158.13 E 222~23 E 2296.11E 2364.69 E 2431.02 E 2494,30 E 2552.03 E 2606.70 E 2656.04 E 2701.64 E 2744.46 E 278f.81E 2815.07 E 2845,11E 5970Q~;93 N-. 5970032.58 N 5970044.59 N 5970056.36 N 5970068.15N 5970079.18 N 597009Z36 N 5970105.11N 597011&44 N 5970132. gg N 597014&62 N 5970159.88N 5970182.60 N 5970198.53 N 5970212.70 N 5970229.38 N 5970243.23 N 5970260.97 N 5970277.47 N 5970295.01 N 597031~82 N 5970328.61N 5970345.45 N 5970363.47 N 5970381.29 N 5970399.61N 597041&OgN 5970434.44N 5970449.29 N 5970464.85N 5970479.24 N 597049~58 N 5970499.77 N 5970509.24 N 597051~47 N 5970524.80 N 5970532.03 N 597054~11N 5970548.95 N 5970554.47 N 591083,02 E 591151.76 E 591225.96 E 591297.69 £ 591368.18 E 591432.21E 591508.43 E 591578.63 E 591648.69 E 591721.25 E 591793.85 E 591843.10 E 59194~97 E 59201Z98 E 592079.22 E 592156.51E 592218.39 E 592294.09 E 592364.64 E 592439.56 E 592505.06 E 592578.38 E 592646.23 E 59271710 E 592786. I5 E 592854.82 E 592923.13 E 592992.05 E 59306~75E 593129.15 E 593195.31E 593258.45 E 593316.08 E 593370.64 E 593419.89 E 593465.40 E 593508.14 E 593545.39 E 593578.55 E 593608.52 E 6.826 4.874 0.515 0,350 1.265 1.474 0.322 0.668 O. 156 4.139 0.623 0.986 ~517 0.714 ~526 0,510 O. 663 0.379 0.452 0.475 0.519 0.474 0.564 0.309 0.347 0.560 0,249 2.770 0.917 2.069 3.165 4.043 3.688 3.864 3. 775 1.289 3. 796 4,118 2.288 4.941 317.87 387.36 462.45 535.09 606.51 671.46 748.77 820.10 891.41 965.42 1039,67 1090.19 1190.62 1264.36 1332.10 1411.16 1474.56 1552.28 1624.7O 1701, 62 1768.96 1844.35 1914.21 1987.25 2058.47 2129.42 2200.05 2270.84 2341.13 2411.26 2478.95 2543.09 2601.39 2656.74 2706.64 2752.69 2796.01 2834.14 2868.39 2898.86 75O5. 87 7599.39 7697.66 7793. 07 7884.35 7976. 42 8069.71 8163.42 8258.19 8352.77 8405.00 ~3.270 87.440 6174.61 6258.21 557.33N 2869.38 E 12.510 87.410 6265.78 6349.38 558.27 N 2890.22 E 11.810 89.290 6361.84 6445.44 558.88 N 2910.91E 11.700 90.270 6455.25 6538.85 558.95 N 2930.35 E 11.280 91.870 6544.70 6628.30 558.62N 2948.53 E 597055&'38N'-' 593632.77E 597055~57 N 593653.60 E 5970558.42 N 593674.28 E 597055&73N 593693.71E 597055&62N 593711.89 E 11.280 91.930 6634.99 6718.59 558.02N 2966.52 E 5970558.24 N 593729.90 E 11.300 91.620 6726.48 6810.08 55~46 N 2984.78 E 597055~89 N 593748.16 E 11.340 92.390 6818.36 6901.96 556.81N 3003.16 E 597055~47 N 593766.55 E 11.740 94.910 6911.22 6994.82 555.60N 3022.08 E 5970556.49 N 593785.48 E 11.990 94.820 7003.78 708~38 553.95 N 3041.45 E 5970555.07N 593804.87 E 11.990 94.820 7054.87 7138.47 553.04 N 3052.27 E 5970554.29 N 593815.69 E 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. Magnetic Declination at Surface is 26.386° (25-Apr-01) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well and calculated along an Azimuth of 79.140" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8405.00ft., The Bottom Hole Displacement is 3101.96ft., in the Direction of 79.730" (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8405.00 7138.47 553.04 N 3052.27 E Comment Projected Survey 4.192 0.813 0.818 0.239 0.578 0.013 0.068 0.167 0.079 0.265 0.000 2923.00 2943.64 2964,08 2983.18 3000.97 3018.53 3036.35 3054.29 3072.63 3091.35 3101.80 Projecled Survey . Su~'-vey tool program for V-fO0 I From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 8405.00 Vertical Depth (ft) 7138.47 Survey Tool Description MWD Magnetic bp Date: 08-06-2001 Transmittal Number:92192 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 Top SW Name Date Contractor Locj Run Depth Bottom Depth Log Type (/-100 05-11-2001 SCH 1 3900 4800 ELAN GLOBAL SOLVER; SCHRADER SECTION TVD- ". SS; ~-100 05-11-2001 SCH 1 2920 3120 ELAN GLOBAL SOLVER; UGNU SECTION TVD- SS; d-100 06-11-2001 SCH I 6560 7100 ELAN GLOBAL SOLVER; KUARUK SECTION TVD- SS; ~'-100 06-14-2001 SCH 1 3900 4800 ZONED IMPACT ROXAN -. FOR FRACCADE; SCHRADER SECTION; rVD-SS ~-100" 06-14-2001 SCH 1 2950 ,3100 ZONED IMPACT ROXAN FOR FRACCADE UGNU SECTION; TVD SS V-100 06-11-2001 SCH 1 6600 7100 ZONED IMPACT ROXAN FOR FRACCADE; KUPARUK SECTION; TVD- SS ,/ Please s~n and Return o-n~ c~)~y-of tti,s transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Kim Lawrence MB5-3 Attn: BP North Slope Wells Tech-Aide Attn: Phillips Alaska, Inc (Vault) Attn: Susan Nisbet (Exxon Mobil Production Co.) Attn: Margaret Wong (Exxon Mobil Production Co.) Attn: Tim Ryherd (DNR) .A,ttn:..Lisa Weepie (AOGCC~~' RECEIVED ~l~a Oit & ~as Ce~. Commla~r~ /~araga Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp CONrlD NTIAL Date: 07-24-2001 Transmittal Number:92178 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have an, :uestions, ~lease contact me in the PDC at 564-409 Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type V-100 05-25-2001 SCH 1 7370 8350 DIPOLE SONIC; KUPARUK INTERVAL; DIPOLE SONIC; SCHRADER BLUFF V-100 05-11-2001 SCH 1 3850 5750 INTERVAL; QC PLOT-DSI; V-100 05-11-2001 SCH I 2600 8350 SONIC PROCESSING; Please Sign and Return one copy of this transmittal. Thank You, ]'ames H. Johnson Petrotechnical Data Center Attn: Kim Lawrence MB5-3 Attn: BP North Slope Wells Tech Aide Attn: Phillips (Vault) Attn: Susan Nisbet (Exxon Mobil, Houston) Attn: Margaret Wong (Exxon Mobil, Anchorage) Attn: Tim Ryherd (DNR) At:tn Lisa Weepie (AOGC~) RECEIVED JUL 26 2001 Ala~a 011 & Gas Cons. Commileen Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp CONrlD£NTLAL Date: 07-13-2001 Transmittal Number:92171 BPXA WELL DATA TRANSMITTAL Please replace the digital data in you files with this update. This is a reissue; some files on the previous CD may have been unreadable. This data is being sent separate because of the confidential nature. If you have an~ uestions, ~lease contact me in the PDC at 564-4091 Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type 1 LDWG FORMATTED DISC WITH VERIFICATION V-100 05-11-2001 SPERRY 1 109.00 8,405.00 LISTIG; (CD) · ~si~tn and Ret~s transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: D. Schwartz (Phillips Alaska Inc) Attn: Susan Nisbet (Exxon Mobil Production Co.) Attn: Tim Ryherd (DNR) Attn: Lisa Weepie (AOGCC) RECEIVED JUL15 ; 001 Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp CONFIDENTIAL Date: 05-30-2001 Transmittal Number:92125 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the connaenuat nature, l~, 'ou nave any quesuons, p~ease contact me ~n tne r~,c. at >ty4-,~uv i. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type V-100 05-01-2001 SPERRY 1-4 i109.00 8,405.00 ReP; RATE OF PENETRATION; / DGR; DUAL GAMMA RAY; EWR; ELECTROMAGNETIC WAVE RESISTIVITY; (MD) V-100 05-01-2001 SPERRY 1-4 108.00 7,138.48 DGR; DUAL GAMMA RAY; ! EWR; ELECTROMAGNETIC WAVE RESISTIVITY; (TVD) )/-100 05-10-2001 BPX - - - MUD LOG DATA BP EXPLORATION (ALASKA), INC (NOTEBOOK) , , I~-100 05-01-2001 SPERRY - - MWD WELL DATA; (lEA CD) V-100 04-20-2001 STATE OF .... PERMIT TO DRILL; '- ALASKA y-100 05-11-2001 SPERRY - - - ~ ~URVEY REPORT; (HARD COPY) " MWD REPORT; (DISKETTE) ~.-100 05-18-2001 $CH 1 5470 8282 ULTRASONIC IMAGER LOG; (COLOR) )/-100 05-11-2001 SCH I 2650 8395 DIPOLE SHEAR SONIC IMAGER; ~-100 05-11-2001 SCH I 2650 8312 PLATFORM EXPRESS; SOBSEA '!'~, TVD LOG; X/-100 05-11-2001 SCH I 2650 8312 PLATFORM EXPRESS; TRIPLE COMBO; ~-100 05-11-2001 SCH I 2650 8312 PLATFORM EXPRESS; DENSITYNEUTRON; ¥-100 05-11-2001 SCH I 2650 8395 PLATFORM EXPRESS; ARRAY INDUCTION TOOL; ,V-100 95-11-2001 SCH 1 2650 8312 NATURAL GAMMA RAY; SPECTROSCOPY LOG; (/-100 )i~15-2001 SCH I 2650 8312 CST CORES REPORT; V-100 05-11-2001 SCH 1 3163 7951 MODULAR FORMATION; DYNAMICS TESTER; ~/-100 05-11-2001 SCH 1 2602.0 8392.0 WIRELINE DIGITAL DATA (CD) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp BPXA WELL DATA TRANSMITTAL ~e~gn and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Date: 05-30-2001 Transmittal Number:92125 Alea Otto MB5-3 BP North Slope Wells Tech Aide Phillips Alaska Inc. Attn: Sandy Lemke Phillips Alaska, Inc. (Vault) Phillips Alaska, Inc. (D. Schwartz) Exxon Mobil Production Co. (Houston) Exxon Mobil Production Co. (Anchorage) Alaska Department of Natural Resources (DNR) Attn: Timothy J. Ryherd AOGCC. Attn: Lisa Weepie RECEIVED JUN 0 1 2001 Alaak8 Oil & Gas Cons. Comm~ion Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ALASKA OIL AND GAS CONSERVATION COMMISSION Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, Alaska 99519 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re; Prudhoe Bay Unit V-100 BP Exploration (Alaska) Inc. Permit No: 201-059 Sur. Loc. 4714' NSL, 1531, WEL, SEC. 11, TllN, RllE, UM Btmhole Loc. 36' NSL, 1609' EWL, SEC. 01, TllN, R11E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt You from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's intemal use. 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. eamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~/~ ~ day of April, 2001 jjc/Enclosures cc; Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '" ,.. STATE OF ALASKA I. ALASK,{ .,ILAND GAS CONSERVATION COM .SION PERMIT TO DRILL ~"~-'~'-~ 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work ~ Ddll [] Reddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 60' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028240 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 4714' NSL, 1531' WEL, SEC. 11, T11 N, R11E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 15' NSL, 1497' EWL, SEC. 01, T11N, R11E, UM V-100 Number 2S100302630-277 At total depth 9. Approximate spud date 36' NSL, 1609' EWL, SEC. 01, T11N, R11E, UM 04/20/2001 Amount $200,000.00 12. Distance to nearest property line 113. Distance to neJ~rest well' 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028238, 36' MDI No Close Approach 2560 8355' MD / 7119' TVD 16. To be completed for deviated wells ' 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}' Kick Off Depth 2676' MD Maximum Hole Angle 49.6 ° Maximum surface 2614 psig, At total depth (TVD) 6635' / 3278 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casinq Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 2626' Surface Surface 2626' 2626' 400 sx AS Lite 3r 234 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 8355' Surface Surface 8355' 7119' 428 sx Lite Crete 'G', 278 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD -I-VD Structural Conductor Surface Intermediate Production LinerRECEIVED Perforation depth: measured Alaska 0ii & Gas Cons. Commission true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ! Signed Dan Stone ~------~--~.._ -~,-.~, ~ Title Senior Drilling Engineer Date ~J.~-') pe'rmit 'Nun~i:)'er" '"'~ "'" .... '' 'l"'/~'Pi N~mi~er'"""' i.... ,. ,., .,, ,..,,,, ......,,..,i . ............ ,, .i,. '",'~D~roval i~'~e"" ' '" "i 's~ c~v~'r'l'etier' "' I so- - o I H. r .01 I for other requirements Conditions of A~-proval: Samples Required ~ Yes ~ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures [] Yes J~ No Directional Survey Required ,~ Yes [] No Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~1~3.5K psi fer.,,~q~ Required Working Other: ORIGINAL SIGNED By by order of Approved By D Taylor SP.~r.q,-,,,,-,, Commissioner the commission Date . . · Form 10-401 Rev. 12-01-85 Submit In Triplicate V-100 Rigsite Summary_ of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE There are no close approach issues, while drilling V-100. Moving to new location with possible ongoing construction operations. Plan to coordinate rig move with activity. An additional conductor will be set 30' to the east of V-100. Secure cellar to prevent accident or incidents. v' No faults are expected to be penetrated by V-100 in the surface interval. Expect gas hydrate problems in the surface and possibly the intermediate sections. See mud property and flow rate information in the mud program to minimize problems V-100 is expected to penetrate a 150' offset fault @ -3260' TVD. This fault is not anticipated to cause any problems in drilling this well. There are no other prognosed faults in the intermediate/production interval. The kick tolerance for the 8 ~" open hole section is predicted at 51 bbls. If a + 13.5 ppg EMW LOT is not achieved, calculate actual kick tolerance and contact Drilling Superintendent for approval to drill ahead. The coring BHA will be a stiff packed assembly, it is important that the hole be in good condition (e.g. smooth drag free tripping with drilling BHA, no cavings, no severe doglegs ) before running the core barrel. It is recommended that the Baker coring engineer be on site for the last day or so of drilling & tripping to assess hole conditions for coring. Core lay-down is not a routine activity - The coring engineer will lead a briefing and discussion with the rig crew involved to ensure that safe and effective procedures are used before beginning core lay-down. The core barrel will be checked for gas at surface before breakdown. Normal precautions for heavy lifting must be followed. After freeze protecting the 7" x 9-5/8" casing annulus with dead crude, the hydrostatic pressure alone will be less than the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. I Well Name: IV-100 Drill and Complete Plan Summary Type of Well (service / producer /injector): I Pre-Producer/Injector Surface Location: As-Staked Target Location: Kuparuk "C" sands Bottom Hole Location: X = 590,770.7' Y = 5,969,964.5' 4714' FSL (565' FNL), 1531' FEL (3747' FWL), Sec. 11, T11 N, R11E Umiat X = 593,792.0' Y = 5,970,582.0' 15' FSL (5264' FNL), 3782' FEL (1497' FWL), Sec. 01, T11 N, R11E Umiat X = 593,903.4' Y = 5,970,604.8' 36' FSL (5242' FNL), 3670' FEL (1609' FWL), Sec. 01, T11 N, R11E Umiat I AFENumber: 15M4010 I I Rig: I Nabors9ES I Estimated Start Date:14/20/2001 I I Operating days to complete: 121.3 I MD: 18,355' I I TVD: 17,~9' I I BF/MS: 131.9' I I RKB' 1 60.0' I Well Design (conventional, slimhole, etc.): I Ultra Slimhole Longstring I Obiective: I Kuparuk Formation (Target zones C sands) Mud Program: 12-1/4" Surface Hole (0-2626'): Fresh Water Surface Hole Mud Density Viscosity Yield Point tauo APl FL PH (ppg) (seconds) (lb/100ftz) (I b/"~-~'6ft2) (mls/3Omin) Initial 9.4 - 9.8 200 - 300 50 - 70 > 9 15 - 20 8.5 - 9.5 below -2000' MD 10.2' 150 - 200 30 - 45 > 7 < 10 8.5 - 9.5 interval TD 10.2 max. 75 - 100 25 - 35 > 6 < 10 8.5 - 9.5 8-3/4" Upper Intermediate Hole (2626' - 7900'): 4% KCl Interva'l ' Density Viscosit~ YP 'PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 9.0- 9.8 42-52 15-25 10-19 9.0-9.5 6cc to <5 <14 by shoe to HRZ HRZ 8-3~4" Production Zone (7900'-8355') Bland Coring Fluid + 4% KCI Interval Density ~Jiscosity Y'P PV pH ' APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.2 40-50 18-28 28-38 8.0-8.5 <5 <7.5 Hole **Keep drilled LGS <12ppb V-100 Permit to Drill Final Page 1 Directional: Var. Sperry WP-05 Draft KOP: 2676' Maximum Hole Angle: 49.6° at 3916' MD Close Approach Wells: No Close Approach issues. First well on V-Pad. Logging Program: Surface Intermediate Hole Drilling' MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res Coring: 180' of 4" core across Kuparuk C-sands. Open Hole: PEX / Sonic / CMR / MDT / SWC Cased Hole: USIT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, Base Permafrost 1860 1800 SV3 2185 2125 SV2 2318 2258 SV1 2526 2466 UG4A 2878 2818 UG3 3225 3152 UG1 3815 3639 WS2 Schrader N 4632 sand 4171 8.9 WS1 Schrader O 4979 sand 4396 8.9 CM3 5388 4661 CM2 K-10 6087 5114 HRZ 7579 6310 Kuparuk Top 7916 6635 Target Sand 9.5 Miluveach 8155 6866 TD 8355 706O Casin /Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/I'VD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC-M 2626' GL 2626'/2626' 8-3/4" 7" 26# L-80 BTC-M 8355' GL 8355'/7119' Tubing 4-1/2" 12.6# L-80 NSCT 7766' GL 7766'/6551' V-lO0 Permit to Drill Final Page 2 Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casin.c Basis: Size 1 9-5/8" Surface Lead: Based on 1860' of annulus in the permafrost @ 175% excess and 266' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2126' MD (2126' TVDbkb). Lead 317 bbl / 1776 f¢ / 400 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 48 bbl / 269 f¢ / 234 sks of Dowell Premium 'G' at 15.8 ppg and 1.15 cf/sk. Casin~, Size 17" Intermediate Longstring I Basis: Lead: Based on TOC 500' above top of Ugnu formation and 30% excess above top of Tail Lead TOC: 2378' MD, 2378' TVDbkb Tail: Based on TOC 1439' above top of 7" shoe and 30% excess + 80' shoe volume Tail TOC~ 6916' MD, 5765' TVDbkb i Total Cement Volume: i Lead i 182 bbls / 1024 f¢/428 sks of Dowell Lite CRETE ,G, at112.0 ppg and 2.39 cf/sk. Tail 1 57 bbls / 320 f¢/278 sks of Dowell Premium 'G' at 15.8 ppg and 1.15 cf/sk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, 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. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: 3278 psi @ 6635' TVDss - Kuparuk C -Sands 2614 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOPtest pressure: 3500 psi · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel V-100 Permit to Drill Final Page 3 Drilling Hazards/Contingencies: (See also hazards identified following the Procedure Summary) HYDROGEN SULFIDE - H2S · There are no existing wells on V-Pad, or wells in close proximity to the BHL to V- 100. DRILLING CLOSE APPROACH: There are no close approach issues, while drilling V-100. Well should be drilled to plan to allow for future wells to be drilled on 15' spacing. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. 4. Operations: MIRU Nabors 9ES. Nipple up and function test 16" diverter system. PU 4" DP as required and stand back in derrick. MU 12 ~/~" drilling assembly and drill surface hole to +/-100' TVD below the SV1 sand top. Run and cement the 9 5/8", 40# surface casing back to surface. A TAM port collar will be positioned at _+1000' as contingency in the event cement does no fully circulate to surface. 5. ND diverter spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 8 3~,, drilling assembly and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 4% KCI drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a FIT to 12.5 ppg EMW. 8. Drill per directional plan through the secondary target at the Schrader Bluff and to within 10' of the top of the Kuparuk reservoir sands. 9. POH and change the BHA for an 8 Y2" core head with 60' core barrel. Change mud system to 4% KCI bland and core 60' through the Kuparuk shale/sand interface. 10. POH, LD core and PU additional 120' core barrel and core 120' through the Kuparuk C sands. 11. RIH with 8 3,4" BHA, ream core interval and drill to TD at 150' below the base of Kuparuk A sands. TD: 8355' MD / 7119' TVDbkb. POOH. 12. Wireline log the Kuparuk 3 runs. DP convey if necessary. 13. Wiper trip the entire hole section. POH, standback 4" DP. 14. Run 7" 26#/ft long string casing to TD and cement to 500' above the Ugnu UG4A, set on mandrel hanger. Displace cement with mud. V-lO0 Permit to Drill Final Page 4 ,r 15. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000' TVD through 7" TAM port collar set at 2000' MD. 16. RIH with 6-1/8" cleanout assembly and cleanout to PBTD (+80' from TD). Test casing to 3500 psi, Change well over to filtered seawater 8.6 ppg. 17. RU Schlumberger USIT log and log entire 7" casing to the top of cement above the Ugnu formation. 18. Run 4-1/2", 12.6# L-80 completion string placing the tubing tail 150' above the top of Kuparuk, -7766'MD/6551 'TVD. 19. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 20. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 21. Freeze protect the well to ~2200' and secure the well. 22. Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 4-20-2001 Allen Sherritt Alaska Drilling & Wells 564--5204 mailto:sherriia @ BP.com Job 1: MIRU Hazards and Contingencies ~ Moving to new location with possible ongoing construction operations. Plan to coordinate rig move with activity. An additional conductor will be set 30' to the east of V- 100. Secure cellar to prevent accident or incidents. Reference RPs Operational Specifics Job 2: Drillinq Surface Hole Hazards and Contingencies Y No faults are expected to be penetrated by V-100 in the surface interval. ~ The first V-Pad surface casing will be set in the SV1 to minimize possible gas hydrate problems. The closest offset pad, Z Pad, has a history of gas hydrate problems while drilling both the surface and intermediate hole sections. On the three most recent Z Pad wells gas hydrate problems were minimized in the surface hole and basically eliminated from the intermediate section. This was accomplished by setting the surface casing below the SV1 sands rather than above the SV2 sands, subsequent hydrate problems were eliminated from the intermediate hole. In the surface hole, hydrate gas was minimized by bringing the mud weight to 10.2 ppg by the base permafrost and by pre- treating the mud system with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. Reference RPs V-100 Permit to Drill Final Page 5 Operational Specifics Job 3: Install Surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 9-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs Operational Specifics Job 4: Drillinq Intermediate Hole Hazards and Contingencies ~ V-100 is expected to penetrate a 150' offset fault @ -3260' TVD. This fault is not anticipated to cause any problems in drilling this well. There are no other prognosed faults in the intermediate/production interval. The kick tolerance for the 8 3A" open hole section would be 51 bbls assuming an influx from the Kuparuk interval at -7916' MD/6695' TVD. This is a worst case scenario based on a 9.5 ppg pore pressure gradient, a fracture gradient of 13.5 ppg at the surface casing shoe, and 10.0 ppg mud in the hole. Rig will perform LOT after drilling 20ft of new formation. If a +13.5 ppg EMW LOT is not achieved, calculate actual kick tolerance and contact Drilling Superintendent for approval to drill ahead. Reference RPs Operational Specifics Job 5: Core and Loq Intermediate Open Hole: Hazards and Contingencies ~ The reservoir sections at Kuparuk V-100 may be penetrated with 0.3 - 0.5 ppg overbalance. Good procedure to avoid differential sticking of the drilling BHA is essential V-100 will be drilled to core point in 8 3A" hole and with 8 ~" coring assembly. The coring BHA will be a stiff packed assembly, it is important that the hole be in good condition (e.g. smooth drag free tripping with drilling BHA, no cavings, no severe doglegs ) before running the core barrel. It is recommended that the Baker coring engineer be on site for the last day or so of drilling & tripping to assess hole conditions for coring. V-100 Permit to Drill Final Page 6 Core lay-down is not a routine activity - The coring engineer will lead a briefing and discussion with the rig crew involved to ensure that safe and effective procedures are used before beginning core lay-down. The core barrel will be checked for gas at surface before breakdown. Normal precautions for heavy lifting must be followed. Reference RPs Operational Specifics Job 6: Install Lon.qstrin.q Casin.q Hazards and Contingencies ~ The Ugnu 4A will be oil bearing. For this reason the 7" casing will be cemented to 500' above the Ugnu 4A sand (the uppermost significant hydrocarbon). ~ The 7" x 9 5/8" casing annulus will use a TAM port collar set @ -2000' TVD to circulate freeze protection fluid. > After freeze protecting the 7" x 9-5/8" casing annulus with dead crude, the hydrostatic pressure alone will be less than the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. V-100 Permit to Drill Final Page 7 Reference RPs Operational Specifics V-100 Permit to Drill Final Page 8 Borealis V-100 Proposed Co pletion TREE: 4-1/16 "- 5M ClW L-80 WELLHEAD: 11" - 5M FMC G5 9-5/8", 40 #/ft, L-80, BTC I I L L I 7", 26 #/ft, L-80, BTC-Mod Cellar Elevation = TBD' Nabors 9ES RKB = TBD' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' 4-1/2" x 1" Camco 'KBG-2' Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS 1 / TBD 1" RP Shear 2 / TBD 1" DV 3 / TBD 1" DV 4 TBD 1" DV 4-1/2" 12.6# L-80, NSCT Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-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 ID. 4-1/2" WireLine Entry Guide set at +/-7766' (-150' above the Kuparuk Formation). Date Rev By Comments 11/29/00 WSI Proposed Completion 3-14-01 JAS Proposed Completion Borealis WELL: V-100 APl NO- 50-029-????? BP Alaska Drilling & Wells i s;~m-r'~-Sl.~. North SIope~,aska """"~°,.,...~...,"m"='; IAlaska Drilling & Wells Begin DIr · 4.00v100fl: 2676.00ft MD, 2676.00ft TVD vo^ v.,= I DrillQuest V-100 WP05 :VWE 03-01 . 500 : 8354.97ftMD,7119.18ftTVD / I ! ~ 41 : 7527.82ftMD,6320.22ffTVD / I/ " ' / I/ ~ 0 [ Il [ Iii ~'~' '~"-~--239}]~TYD, 7.t. OO:~;400.#OE I I 44~O. OOTVO, 20~.~2N. lO77.27E I I I I 0 500 1000 1500 2000 2500 3000 Scale: 1 inch = 500ff Eastings Reference is True North 1200 2400 0,00 2626.00 2676,00 3916.09 4985.60 6374.37 7527.82 7915.82 8154.97 8354.97 ...................................................................... S¥5 1508.00' TVD ...................................................................... SV4 1703.00' TVD ...................................................................... Ba~ Pormafroat 1860,00'TVD NWE 03-01 T1 (fault) 2395.00 TVD, 75.00 N, 400.00 E 2318.00' TVD . .I~. !n...l:)J.r.? .41..09*/J..o~t. 1 .:.2, .6T.6: .~..n .M.D., .2.6,716.: .0~t...Ty.D' ......... ~¥ :tr~ ts~.o~' 13 3/8" Casing 2626.00' MD : 2626..Q0':TV~ ..................................................... u~K~ $ 2821.0o, ..................................................... UG4A/Top Ugnu 2878.00' TVD End DIr, Start Sail · 49.604°: 3916.09ftMD,3766.88ftTVD ' ........................................................ UG1 / Schreder Ma 3699,00' TVD Proposal Data for V-100 Wp05 Vedicel Odgin: Wel Horizontal O~n: Wel Meamxemer* Urlts:ft Norlh Reference: True Noflh Dogk~g sevedty: Degrees per 100 feet Vertical Sestbn Azlm~h: 79.142~ Vedk=al Sestk~n Desc~ptk~n: We~ Vertk~.al Sectk~n Odgin: 0.00 N,0.00 E IneL Azlm. VMtICAl Nodhlng~ Ealtlngi VerUoll 3600 48OO 6000 II '~ 7200 Scale:linch = 1200ff 0,000 0,693 0l~ 01~ N 01~ E 0,~ 0,000 0.693 2626.00 0,00 N 0,00 E 0,00 0.00 0,000 0.693 2676.00 0,00 N 0.00 E 0,00 0.00 49,604 79,142 3766,88 94,96 N 495,08 E 504,10 4.00 49,604 79.142 4460.00 248,40 N 1295,01 E 1318,62 0.00 49.604 79.142 5360.02 447.63 N 2333,73 E 2376,28 0.00 15,000 79.142 6320.22 561.99 N 2929,93 E 2983,34 3.00 15.000 79.142 6695.00 580,90 N 3028,55 E 3083,76 0.00 15,000 79.142 6926,00 592.56 N 3089,34 E 3145,65 0.00 15,000 79.142 7119.18 602.31 N 3140.17 E 3197,42 0.00 · WS2/Top WS/Schrader Ne 4231,00' TVD 'WS1/SCllrader O~1 4456.00'TVD Schrader Target / R-- l~lIllll~llllllUl 4460.00 TVD, 206.62 N, 1077.27 E ............................................ ~ ........................ C~10 5174'00' TVD ~ Current Well Properties Begin Dlre3.OO°/166ft :6374.37ftMD, 5360.02ftTVD X ~-~: -- ~-~'0~ ........................................................ '~7~ ~ ....... cm,xs s?~s.oo' TV~ Horizontal Coordinates: End DIr Start Sail · 15 nt~o. 7no't t~f~Mn r,_'a~a o~m,rvn ~ ' Ref. Global Coordinates: 5969964.50 N 590770.70 E .................... ~ ~ Rof. Structure: 8439.81 S, 74~4,14 E ~ Ref. Geographical Coordinates: 700 19' 39.5006" N, 1490 15' 49.9086" W NWE 03-01 6695.00 TVD 580.90 N, 3028.55 E .. ~ lop HRZ 637o.oo' IFVD RKB Elevation · 60 00ff above Mean Sea Level ....................... ~.... '.' .... ~ : '~ uaso HRZ 6510 00' TVD ' ' ...... ~ .......... : ~''~:, ' ....... ~ ~ ' 'K1 656O.00'TVD 60.00ft above Structure ....................................................... ~'~ ..... ~.~1.... KUPC4B 6695.00'"i"VD .......................................................... :%x.- - ~,,k - KUP C4A 8722 00' TVD · .......................... ~[' ~ ;~ KUP caA 6730'00' TVD No~lh Reference. True North ............................... ~ ............. -~*- ~'~' KUP Cl 6751.0'~' TVD Units: Feet ........ :::::::::::::::::::::::::: KUP AS 6864.0D' I~/D t" KUPA4 M84.00' TV D 0o.oo MIL / BASE KUP $926,00' TVD Total Depth: 8354.97ftMD.7119.18ft'rVD I I 0 1200 2400 Vertical Section Section Azimuth: 79.142° O'rue North) DrillOuest 2.00.08,001 Sper, y-Sun Drilling Se, vices Proposal Data - V- 100 - V- 100 Wp05 Draft Copy MD Delta Inclin. Azimuth TVD Delta Northings Eastings Dogleg Toolface VS (79°) (fl) MD (ft) (°) (°) (fi) TVD (fi) (ft) (fi) (°/lOOft) (°) (fi) I 0.00 0.000 0.000 0.00 0.00 0.00 0.00 2' 2626.00 2626100. 0.000 ..... ~,00~ 2626.00 ....2626100 0.00 0.00 .... 61000 ......0.000 0.00 3 2676.00 50.00 0.000 0.000 2676.00 50.00 0.00 0.00 0.000 0.000 0.00 4t '~9i~.09~ 1240.09-~4~).60~ ...... -791i~"*'3:7~8~-~"'~'~)9~88~ .... 9~.'g6'i~1 ..... ~49~08'~' 4.000 ..... ~'-gii-~t-2 504.10 5 498~i(~0" ~06g~5i~ 49.604 79.142 ~'~6~3.~00 .....6~3'1i~ .... ~48140"N'~ 'i-2~3~i0-i~*E* 0.000 ..... 0~i 1318.62 6 6374.37 2458.27 49.604 79.142' '5360.(~2 ..... 1'~9~'i'3' ....... 4~4~;.~'~N-~3~:~i~7~' ........... i~(X~i .......... 01~)I 2376.28 7 7527.82 '1-~53.',~6 15.00o 79.142*~ 63-~(~i~ ........ ~6~ .... *5~i-i~9~**i~"***2~2~)ig3'*E ........... ~i~006 ...... ~i"8(~i 2983.34 8 :79i~.82 3~81(~ 15.o0o~ 79.142"-66~)-5~6'0 ...... ',~*.-~ .... ~)8~6.~)._~i..~.~6~.~5~.~ . 0,0o01 ........... .0~t 3083.76 9; ...... S~'~ig7 ..... 239.i~* "*'1'5.~)~i ..... 7~i:;!~4~ 6926.001 ....... ~;~;i'~ ~592.56 El 3089.34 E ......... ~.~0~3 .......... 0~] 3145.65 10 ' 8354~.9-7 ....20~%~"i5~(~ ...... 7~'.:i-4~; 7119.18 .....i~31i'8 ..... 60~13'i N'**' :~1~°1i7'E o.oo0 ..... 01'°00 3197.42 8 March, 2001 - 10:56 - 1 - DrillQuest North Slope Alaska Alaska Drilling & PBU WOA ~ P POSAL REPORT 8 March, 2001 Surface Coordinates: 5969964.50 N, 590770.70 E (70° 19' 39.5006" N, 149° 15' 49.9086" W) Kelly Bushing: 60.OOft above Mean Sea Level DRILI--INB ;:; E RV I (:: B Proposal Ref: pro 10767 A Halliburton Company Sperry-Sun Drilling Services Proposal Report for V-100 Wp05 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.90 0.000 0.000 -60.00 0.03 100.00 0.000 0.000 40.00 100.00 200.00 0.000 0.000 140.00 200.00 300.00 0.000 0.000 240.00 300.00 400.00 0.000 0.003 340.00 400.00 0.000 440.00 0.000 540.00 0.000 640.00 0.000 740.00 0.000 640.00 0.030 940.~ 1~ o.ooo ~o40.oo% ~% 0.003 1140.00 ~-12~ 0.003 1240.00 ~00 0.000 1340,00 ~400.00 500.00 0.000 600.00 0.000 700.00 0.000 800.00 0.000 900.00 0.000 1000.00 0.000 1103.00 0.000 1200.00 0.000 1300.00 0.000 1400.00 0.003 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 8oo.oo . ~o.~__ ~ 900.00 ...... ~.~ 0.00 N 0.00 N 0.00 N 1500.00 0.000 0.000 1440.00 1500.00 1508.00 0.000 0.000 1448.00 1508.00 1600.00 0.000 0.000 1540.00 1600.00 1700.00 0.000 0.000 1640.00 1700.00 1703.00 0.000 0.000 1643.00 1703.00 1800.00 0.000 0.000 1740.00 1803.00 1860.03 0.000 0.000 1800.00 1860.00 1900.00 0.000 0.000 1840.00 1903.00 2000.00 0.000 0.900 1940.00 2000.00 2100.03 0.000 0.000 2040.00 21 03.00 2185.00 0.000 0.900 2125~00 2185.00 2200.00 0.000 0.000 2140.00 2203.00 2300.00 0.000 0.000 2240.00 2303.00 2318.00 0.000 0.000 2258.00 2318.00 2400.00 0.000 0.000 2340.00 2400.00 0.00 E 0.00 E ~96~___.50 ~ ~~E ~ 5~~N ~ 0.00 E~~64.~ ~~ 5969964.5O N ~ 5969964.50 N 0.00 E 5969964.50 N 0.00 E 5969964.50 N 0.00 E 5969964.50 N Global Coordinates Northings ~stings (ft)_ ~%~ (ft) 5969~ ~770.70 E 5~70.70 E 51~0770.70 E 590770.70 E 590770.70 E 590770.70 E 59O770.70 E 590770.70 E 590770.70 E 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.03 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E 0.00 E 5969964.50 N 590770.70 E Dogleg Rate (°ll00ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA V-Pad Vertical Section Comment 0.00 o.oo o.oo 0.00 0.00 0.00 o.oo 0.o0 0.00 o.o0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 SV5 SV4 Base Permafrost SV3/T5 SV2 8 March, 2001 - 11:12 Page 2 of 9 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for V-100 Wp05 North Slope Alaska Measured Depth Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2500.00 0.000 0.000 2440.00 2500.00 2526.00 0.000 0.000 2466.00 2526.00 2600.00 0.000 0.000 2540.00 2600.00 2626.00 0.000 0.000 2566.00 2626.00 2676.00 0.000 0.000 2616.00 2676.00 79.142 2640.00 2700.00 79.142 2739.85 79.142 2761.00 79.142 2818.00 79.142 2839.09 79.142 2937.24 ~_ 209~ 79.142 3128.39 ~~39 79.142 3152.00 ~212.00 79.142 3220.45 3280.45 2700.00 0.960 2800.00 4.960 2821.24 5.810 2878.68 8.107 2900.00 8.960 3000.00 12.980 3100.00 16.960 3200.00 20.960 3225.37 21.975 33(X).00 24.960 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N _. 2799.85 2821.00 2878.00__ ~ ~-~.7~ -~.~ ~ .~9 N 6.87 N 11.74 N 17.85 N 19.60 N 25.20 N 3400.00 28.960 79.142 3309.56 3369.56 3500.00 32.960 79.142 3395.30 3455.30 3600.00 36.960 79.142 3477.24 3537.24 3700.00 40.960 79.142 3554.98 3614.98 3800.00 44.980 79.142 3628.15 3688.15 3815.42 45.577 79.142 3639.00 3699.00 3900.00 48.960 79.142 3696.39 3756.39 3916.09 49.604 79.142 3706.88 3766.88 Global Coordinates Northings ~stings ...... ~(ft) 0.00 E 5989~. '~770.70 E 0.00 E __.59~.50 ~ 59J)7__ 70.70 E _D~(~.._ E ~ ~70.70 E ~~ ~ 5~N 5~770.70 E ~' 0.~ E~ ~.~ 5~770.70 E -~ 5~.~ N 5~770.90 E 5.27 E 5~9965.57 N 5~775.~ E 7.23 E 5~.97 N 5~7~.91 E 14.~ E 5~9967.37 N 5~7~.73 E 17.17 E 5~9~.~ N 5~787.~ E ~.83 E 5~9971.81 N 5~.45 E 61.18 E 5~76.97 N 5~1.74 E 93.~ E 5~99~.~ N 5~.~ E 102.20 E 5~99~.~ N 5~72.66 E 131.39 E 5~1.29 N 5~1.77 E 4000.00 49.604 79.142 3761.26 3821.26 4100.00 49.604 79.142 3826.07 3886.07 33.74 N 43.43 N 54.22 N 66.06 N 78.90 N 175.90 E 5970000.37 N 590946.18 E 226.42 E 5970010.66 N 590998.57 E 282.68 E 5970022.14 N 591052.70 E 344.42 E 5970034.72 N 591114,?.9 E 411.33 E 5970048.37 N 591181.05 E 80.98 92.66 94.96 422.09 E 5970050.56 N 591191.78 E 483.10 E 5970063.00 N 591252.64 E 495.08 E 5970065.44 N 591264.59 E 107.00 N 121.34 N 557.84 E 5970078.24 N 591327.20 E 632.63 E 5970093.49 N 591401.82 E Dogleg Rate (°/100fl) 0.00 0.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA V-Pad Vertical Section Comment 0.00 0.00 SV1/T3 ~-- 0.00 0.00 13 3/8" Casing 0.00 Begin Dir @ 4.00°/100ft: 2676.00ff MD, 2676.00ft 'I'VD 0.20 5.36 7.36 UG4/K15 14.32 UG4A/Top Ugnu 17.48 36.49 62.30 94.78 104.07 UG3 133.78 179.11 230.54 287.83 350.70 418.83 429.78 491.90 504.10 568.00 644.16 UG1 / Schrader Ma End Dir, Start Sail @ 49.604° · 3916.09ftMD,3766.88ftTVD 8 March, 2001 - 11:12 Page 3 of 9 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for V-100 Wp05 North Slope Alaska Measured Depth (fi) Incl. AzJm. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4200.00 49.604 79.142 3890.88 3950.88 4300.00 49.604 79.142 3955.68 4015.68 4400.00 49.604 79.142 4020.49 4080.49 4500.00 49.604 79.142 4085.30 4145.30 4600.00 49.604 79.142 4150.10 4210.10 79.142 4171.00 79.142 4214.91 79.142 4279.72 79.142 4344.52 79.142 4396.00 79.142 4400.0~-- ~ 79.142 4409.33~ 446~-~ ~- 79.142 4474.14 ~534~4 79.142 4538.95 ~95 79.142 4603.75 ~663.75 4632.24 49.604 4700.00 49.604 4800.00 49.604 4900.00 49.604 4979.43 49.604 4985.60 49.604 50(X).00 49.604 5100.00 49.604 5200.00 49.604 5300.00 49.604 135.69 N 150.04 N 164.38 N 178.73 N 193.08 N 4231.00 1 ~~ 4274.91 2~~ ~ N~< 4339.72 __ 2~ -_-~ _ 4404.52 ~~.~ .... ~ 4456.00 ?_: ~_-~.5~ ~48.40 N 250.46 N 264.81 N 279.15 N 293.50 N 5,388.34 49.604 79.142 4661.00 4721.00 5400.00 49.604 79.142 4668.56 4728.56 5500.00 49.604 79.142 4733.37 4793.37 5600.00 49.604 79.142 4798.17 4358.17 5700.00 49.604 79.142 4862.98 4922.98 5800.00 49.604 79.142 4927.79 4987.79 5900.00 49.604 79.142 4992.59 5052.59 6000.00 49.604 79.142 5057.40 5117.40 6087.33 49.604 79.142 5114.00 5174.00 61 03.00 49.604 79.142 5122.21 5182.21 6200.00 49.604 79.142 5187.02 5247.02 6300.00 49.604 79.142 5251.82 5311.82 6374.37 49.604 79.142 5300.02 5360.02 6400.00 48.835 79.142 5316.76 5376.76 6500.00 45.835 79.142 5384.52 5444.52 707.42 E 7822.2 E .5_97~0~.99 ~ 8,57~,Q~ E ~~~~ ~ ~_59~5~_~N ~.60 S__~ ~~ 69.~ 1~ 5970174.66 N 1~~ 59701 ~.~ N 11 ~.19 E 59702~.24 N 12~.~ E 5970215.49 N 12~.39 E 5970227.~ N Global Coordinates Northings ~stings (ft) ~ ~-~ (ft) 597~ ~476.43 E b'q~{551.05 E ~625.66 E 591700.28 E 591774.89 E 591798.95 E 591849.51 E 591924.12 E 591998.74 E 592058.00 E 1295.01 E 5970228.54 N 592062.61 E 1305.78 E 5970230.74 N 592073.36 E 1380.58 E 5970245.99 N 592147.97 E 1455.37 E 5970261.24 N 592222.59 E 1530.17 E 5970276.49 N 592297.20 E 306.17 N 307.85 N 322.19 N 336.54 N 350.88 N 1596,~4 E 5970289.96 N 592363.12 E 1604.96 E 5970291.74 N 592371.82 E 1679.75 E 5970306.99 N 592446.43 E 1754.55 E 5970322.24 N 592521.05 E 1829.34 E 5970337.49 N 592595.66 E 365.23 N 1904.14 E 5970352.74 N 592670.28 E 379.58 N 1978.93 E 5970367.99 N 592744.90 E 393.92 N 2053.73 E 5970363.24 N 592819.51 E 406.45 N 2119.04 E 5970396.56 N 592884.67 E 408.27 N 2128.52 E 5970398.49 N 592894.13 E 422.62 N 2203.32 E 5970413.74 N 592968.74 E 436.96 N 2278.11 E 5970428.99 N 593043.36 E 447.63 N 2333.73 E 5970440.33 N 593098.85 E 451.29 N 2352.80 E 5970444.22 N 593117.86 E 465.14 N 2425.00 E 5970458.94 N 593189.90 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 Alaska Drilling & Wells PBU_WOA V-Pad Vertical Section Comment 720.32 796.48 872.64 948.79 1024.95 1049.51 1101.11 1177.27 1253.43 1313.92 1318.62 1329.58 1405.74 1481.90 1558.06 1625.33 1634.22 1710.38 1786.53 1862.69 1938.85 2015.01 2091.1 7 2157.67 2167.32 2243.48 2319.64 2376.28 2395.69 2469.21 WS2/Top WS/Schrader Na WSl / Schrader Oa CM3/K12/Top Colville Mdstn CM2/K10 Begin Dir @ 3.00°/100ft · 6374.37ft MD, 5360.02ft 'rVD 8 March, 2001 - 11:12 Page 4 of 9 DrillQuest 2.00,08,001 Sperry-Sun Drilling Services Proposal Report for V-lO0 Wp05 North Slope Alaska Measured Depth (ft) Incl. 6600.00 42.835 79.142 6700.00 39.835 79.142 6800.00 36.835 79.142 6880.53 34.419 79.142 6900.00 33.835 79.142 7000.00 30.835 79.142 7100.00 27.835 79.142 7200.00 24.835 79.142 7300.00 21.835 79.142 7400.00 18.835 79.142 7500.00 15.835 79.142 7527.82 15.000 79.142 7579.36 15.000 79.142 7600.00 15.000 79.142 7700.00 15.000 79.142 7724.30 15.000 79.142 7780.20 15.000 79.142 7800.00 15.000 79.142 7900.00 15.000 79.142 7915.82 15.000 79.142 7943.78 15.000 79.142 7952.06 15.000 79.142 7973.80 15.000 79.142 7991.40 15.000 79.142 8000.00 15.000 79.142 Sub-Sea Vertical Local Coordinates Depth Depth Northings (ft) (ft) (ft) 5456.04 5516.04 478.30 N 5531.1 2 5591.12 490.74 N 5609.55 5669.55 502.42 N 5675.00 5735.00 511.26 N 5691.12 5751.12 513.32 N 5775.60 5835.60 5862.77 5922.77 5952.38 6012.38 6044.19 6104.19 6137.95 6197.95 ~ ~ -.~i$~.9~ 6233.4~~.~ ':~-' ~ -~. ....... "~-%'-560.59 N 6260.22~ 632~ ~. 561.99 N 6310.00 ~00 564.50 N 6329.94 ~9.94 565.51 N 6426.53 6486.53 570.38 N Global Coordinates Eastings Northings ~stings (ft) (ft) (ft) 2493.63 E 597~ -~258.36 E $~_9~_ 23.06 E 59&383.82 E 593429.78 E 593440.48 E 2558.49 E _~597~16 ~ 26!~(~ E ~~ ~76.19 E ~~10.~ 2~ 5970520.1~ ~ 2~ 59m5~.67 N 5970539.~ N 5970~7.49 N 597~.~ N _- 532~;6 -~ 540~7~ N ~ ..... 2820.38 E 28~.40 E 593492.88 E 593540.87 E 593584.33 E 593623.13 E 593657.18 E 2922.66 E 5970560.41 N 593686.36 E 2929.93 E 5970561.89 N 593693.61 E 2943.02 E 5970564.56 N 593706.68 E 2948,~7 E 5970565.63 N 593711.91 E 2973.69 E 5970570.81 N 593737.27 E 6450.00 6510.00 571.57 N 6504.00 6564.00 574.29 N 6523.12 6583.12 575.26 N 6619.71 6679.71 580.13 N 6635.00 6695.00 580.90 N 2979.87 E 5970572.07 N 593743.43 E 2994.08 E 5970574.97 N 593757.61 E 2999.11 E 5970576.00 N 593762.63 E 3024.53 E 5970581.18 N 593787.99 E 3028.55 E 5970582.00 N 593792.00 E 6662.00 6722.00 582.27 N 6670.00 6730.00 582.67 N 6691.00 6751.00 583.73 N 6708.00 6768.00 564.59 N 6716.31 6776.31 585.01 N 3035.65 E 5970563.45 N 593799.09 E 3037.76 E 5970583.88 N 593801.1 9 E 304329 E 5970565.00 N 593806.70 E 3047.76 E 5970585.92 N 593811.1 6 E 3049.95 E 5970586.36 N 593813.34 E Dogleg Rate (°/100fi) 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA V-Pad vertical Section Comment 2539.09 2605.13 2667.14 2714.05 2724.97 2778.45 2827.44 2871.79 2911.40 2946.15 2975.94 2983.34 2996.67 3002.02 3027.90 3034.19 3048.65 3053.78 3079.66 3083.76 3090.99 3093.14 3098.76 3103.32 3105.54 CMl/K5 End Dir, Start Sail @ 15.000°' 7527.82ftMD,6320.22ftTVD TOP HRZ Base HRZ K1 KUP C4B Target - NWE 03-01 KUP C4A KUP C3A KUP C1 LCU/KUP B 8 March, 2001 - 11:12 Page 5 of 9 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for V- 100 Wp05 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings (ft) (ft) (fi) (ft) Global Coordinates Eastings Northings ~stings (ft) (ft) (ft) 8082.50 15.000 79.142 6796.00 6856.00 589.03 N 3070.92 E 597Q~ --~34.27 E 8090.79 15.000 79.142 6804.00 6864.00 589.43 N 3073.02 E _~970~07 ~ ~.37 E 8100.00 15.000 79.142 6812.90 6872.90 589.88 N 307.5~6 E ~~~ ~38.70 E 8111.50 15.000 79.142 6824.00 6884.00 590.44 N ~15 ~ 59~9~N 593841.62 E 8154.97 15.000 79.142 6866.00 6926.00 592.56 N ~.34 E ~ ~~94.~ 593852.64 E __ 8200.00 15.000 79.142 6909.49 6969.49 5~~ 3,-~? 5970596.73 N 8300.00 15.000 79.142 7006.08 7068.08 5~ 31~ 5970601.91 N 8354.97 15.000 79.142 7059.18 7119.18 ~ N~ ~ 3140.17 E 5970604.76 N All data is in Feet unless otherwise stated.~~d ~tes are relative to True North. Vertical depths are relative to Well. NorttJ _~S a~l~a-~gs~re relative to Well. Magnetic Declination at Surface is 26.835° (~-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 79.142° (True). 593854.06 E 593889.42 E 593903.36 E Based upon Minimum Curvature type calculations, at a Measured Depth of 8354.97ft., The Bottom Hole Displacement is 3197.42ft., in the Direction of 79.142° (True). Dogleg Rate (°/lOOft) Alaska Drilling & Wells PBU_WOA V-Pad vertical section Comment 0.00 3126.90 KUP A6 0.00 3129.04 KUP A5 0.00 3131.43 0.00 3134.40 KUP A4 0.00 3145.65 MIL / BASE KUP 0.00 0.00 0.00 3157.31 3183.19 3197.42 TolaJ Del;dh' 8354.97ftld D,7119.18ftTVD 8 March, 2001 - 11:12 Page 6 of 9 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for V-lO0 Wp05 North Slope Alaska Alaska Drilling & Wells PBU_WOA V-Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (fi) 2676.00 2676.00 0.00 N 3916.09 3766.88 94.96 N 6374.37 5360.02 447.63 N 7527.82 6320.22 561.99 N 8354.97 7119.18 602.31 N Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (fi) 1508.00 1508.00 1448.00 1703.00 1703.00 1643.00 1860.00 1860.03 1800.00 2185.00 2185.00 2125.00 2318.00 2318.00 2256.00 2526.00 2526.03 2466.00 2821.2.4 2821.00 2761.00 2878.68 2878.00 2818.00 3225.37 3212.00 3152.00 3815.42 3699.03 3639.00 4632.24 4231.00 4171.00 4979.43 4456.03 4396.03 5388.34 4721.00 4661.00 6087.33 5174.00 5114.00 6880.53 5735.00 5675.00 0.00 E Begin Dir @ ~~: ~.~M~-2676.00ft TVD 495.08 E End Dir, Slart ~ ¢~ 4~~6.09ft~D,3766.88ftTVD_ 23,33.73 E _B~Dk ¢~ 3~~ 6374.37fl MD, 5360.02fl TVD 2929.93 E ~lart Sai~.° - 7527.82ftMD,6320.22ftTVD 3140.17 E ~ ~: 8354.97ftMD,7119.18ftTVD -- Nort~~~ ~stings _ (ft) ~ (fi) Dip Dip Dir. Formation Name Deg. Deg. 0.00 N 0.00 E 0.000 0.000 SV5 0.00 N 0.00 E 0.000 0.000 SV4 0.00 N 0.00 E 0.000 0.000 Base Permafrost 0.00 N 0.00 E 0.000 0.000 SV3/T5 0.00 N 0.00 E 0.000 0.000 SV2 0.00 N 0.00 E 0.000 0.000 SV1/T3 1.39 N 7.23 E 0.000 0.000 UG4/K15 2.70 N 14.06 E 0.000 0.000 UG4A/Top Ugnu 19.60 N 102.20 E 0.000 0.000 UG3 80.96 N 422.09 E 0.000 0.000 UG1 / Schrader Ma 197.70 N 1030.72 E 247.51 N 1290.39 E 306.17 N 1596.24 E 406.45 N 2119.04 E 511.26 N 2665.46 E 0.000 0.000 WS2/Top WS/Schrader Na 0.O00 0.000 WS1 / Schrader Oa 0.000 O.0(X) CM3/K12/Top Colville Mdstn 0.000 0.000 CM2/K10 0.000 O.03O CMl/K5 8 March, 2001 - 11:12 Page 7 of 9 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for V-lO0 Wp05 North Slope Alaska Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (~t) Formation Tops (Continued) 7579.36 6370.00 6310.00 7724.30 6510.00 6450.00 7780.20 6564.00 6504.00 7915.82 6695.00 6635.00 7943.78 6722.00 6662.00 7952.06 6730.00 6670.00 7973.80 6751.00 6691.00 7991.40 6768.00 6708.00 8082.50 6856.00 6796.00 8090.79 6864.00 6804.00 8111.50 6884.00 6824.00 8154.97 6926.00 6866.00 Northings (ft) Eastings (ft) 564.50 N 571.57 N 574.29 N 580.90 N 3028.~ ~.000 ~ KUP C4B 58227 N 3035.~ ~00 0.000 KUP C4A -- 582.67 N ~ ~3~.Ed- 0.000 0.693 KUP C3A ~ ~i~3[~.~ 0.000 0.000 KUPC1 ~~= ~=E 0.000 0.000 LCU/KUPB ~.03 ~_ ~ 3070.92 E 0.000 0.000 KUP A6 ~ N~ ~-3073.02 E 0.000 0.000 KUP A5 - ~ 590~ 3078.29 E 0.000 0.000 KUP A4 592.56 N 3089.34 E 0.000 0.000 MIL/BASE KUP Dip Dip Dir. Formation Name .... -- Deg. Deg. ~ ~__~ 2043.02 E 0.000~000 ~~ % 2979.e7 E 0.000~_ 0.~ ~RZ 2994.08E ~. 0.000 ~.~ K1 Alaska Drilling & Wells PBU_WOA V-Pad Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 2626.00 2626.00 Casing Detail 13 3/8" Casing 8 March, 2001 - 11:12 Page 8 of 9 DrillQuest 2,00,08,001 Sperry-Sun Drilling Services Proposal Report for V-100 Wp05 North Slope Alaska Alaska Drilling & Wells PBU_WOA V-Pad Targets associated with this wellpath Target Name NWE 03-01 NWE 03-01 T1 (fault) Schrader Target Mean Sea Level/Global ~rdinat~ ~.00 G__=_e~_. _ ical ~n~ Mean S~~ Coordinates: 2335.00 :.:-.--- ---~~ Coordi~es: __ ~~%_ ~eographical Coordinates: T a~~r y ~ ~ ~hings _~~ ~(ft) 580.90 N 5970582.00 N 70° 19' 45.2083" N 75.00 N 5970044.33 N 70° 19' 40.2382" N 206.62 N 5970184.14 N 70° 19' 41.5322" N Coordinates Eaatinga (ft) Target Target Shape Type 3028.55 E Point 593792.00 E 149° 14' 21.4836" W 400.00 E Point 591169.76 E 149° 15' 38.2305" W 1077.27 E Point 591845.39 E 149° 15' 18.4570" W 8 March, 2001 - 11:12 Page 9 of 9 DriliQuest 2.00.08.001 Sperry-Sun Anticoilision Report Comlmn~: BP Amooo Referenee Sac: PB V Pad Referenee Well: Platt: V-108 Referenee We~pa~h: V-lO0 ])a~: 03/08/2081 'Time: 14:20:08 l~e: 1 Co-or~aae(NE) Ibtemaee: Well: Plan: V-lO0, True North Vertleal tTVD) l~'m~ee: Planmd r~ $0.0 Db: Oracle GLOBAL SCAN APPLIED: All welipaths within 200'+ 100/1000 of reference - There are ~H~usdls in this IIidll! V-100 WP5 & NOT PLANNED PRd' Xnterlmlaflon Methea: MD later~al: 100.00 ft Em'or Mead: ISCWSA Ellipse ! Depth P, au~e: 60.00 to 8354.97 ft Scan Methea: Trav Cylinder North Mhd-i-mm Rnains: 1029.50 ff Error Sari'ace: Ellipse + Casing Casing Points MD TVD Diameter Hok Ske : Name ff fl in in .. 2626.00 2626.00 9.62 12.25 Case2 8354.97 7119.35 7.00 8.50 Case3 Plan: V-100 WP5 Date Comlmsea: 03/08/2001 Version-- 1 Princtpah Yes Tied-to: From Well Ref. Point Summary · '. " .',".:'"'. ff".:' '.' ft''' '"..'lt.'":': .ft:" tt'. ' PB V Pad Plan V-(z-10a)??? Plan V-(z-10a) Vl Plan 999.37 1000.08 122.02 21.28 100.74 Pass: Major Risk Site: PB V Pad Well= Plan V-(z-10a)??? Wellpaa= Plan V-(z.10a) Vl Plan: V-(z-10a) wp01 V1 Rule Asd~ned: Major Risk Inter-Site Error: 0.00 ff ' Reference'. . .,. ,"Offset. , :, '. Semi. Major AS~ ' "' ', ' ' .. Ctr. C'tr NO-GO Allowable' MD" =' "TVD :' :' ""' 'MD "' .. "T~D" Ret":: ~"' 'TFo~AZI' TFo. HS 'CaNing. 'Di~ee"AFe,'.'. ~tlon...Wamb~ .' ' ft .ft :' ' ft , ft. ' .ff ' ". tt · .'deg''...'deg. in,.,... .'..:ff' , .:,ff' ff..' ..:.. .. ' 60.00 60.00 60.00 60.00 0.00 0.00 255.68 255.68 9.62 120.11 0.91 119.20 Pass 100.00 100.00 100.00 100.00 0.04 0.13 255.68 255.68 9.62 120.11 1.85 118.26 Pass 200.00 200.00 200.00 200.00 0.16 0.76 255.68 255.68 9.62 120.11 5,06 115.05 Pass 300.00 300.00 300.00 300.00 0.27 1.29 255.68 255.68 9.62 120.11 7.98 112.13 Pass 400.00 400.00 400.00 400.00 0.38 1.80 255.68 255.68 9.62 120.11 10.87 109.24 Pass 500.00 500.00 500.00 500.00 0.49 2.32 255.68 255.68 9.62 120.11 13.75 108.36 Pass 599.99 599.99 600.00 599.99 0.61 2.57 255.27 255.27 9.62 120.11 15.83 104.28 Pass 699.98 699.96 700.00 699.98 0.72 2.57 254.02 254.02 9.62 120.15 17.17 102.98 Pass 799.86 799.86 800.00 799.86 0.83 2.57 251.94 251.94 9.62 120.34 18.51 101.83 Pass 899.68 899.68 900.00 899.68 0.94 2.58 249.05 249.05 9.62 120.88 19.88 101.01 Pass 999.37 999.37 1000.00 999.37 1.06 2.60 245.39 245.39 9.62 122.02 21.28 100.74 Pass 1098.90 1098.90 1100.00 1098.90 1,17 2.64 241.03 241.03 9.62 124.08 22.72 101.36 Pass 1198.21 1198.21 1200.00 1198.21 1.28 2.69 235.91 235,91 9.62 127.52 24.22 103.34 Pass 1297.17 1297.17 1300.00 1297.17 1.39 2.77 230.08 230.08 9.62 133.03 25.80 107.32 Pass 1395.72 1395.72 1400.00 1395.72 1.50 2.89 223.86 223.86 9.62 141.14 27.47 113.87 Pass 1493.80 1493.80 1500.00 1493.80 1.61 3.04 217.60 217.60 9.62 152.29 29.26 123.44 Pass 1591.33 1591.33 1600.00 1591.33 1.72 3.24 211.61 211.61 9.62 166.77 31.17 136.33 Pass 1688.25 1688.25 1700.00 1688,25 1.83 3,49 206.10 206.10 9.62 184.70 33.22 152.68 Pass 1784.53 1784.53 1800.00 1784.53 1.94 3.78 201.21 201.21 9.62 205,96 35.41 172.37 Pass 1880.66 1880.66 1900.00 1880.66 2.05 4.10 197.19 197.19 9.62 228.92 37.69 193.78 Pass 1976.71 1976.71 2000.00 1976.71 2.15 4.44 193.89 193.89 9,62 253.04 40.03 216.37 Pass 2071.19 2071.19 2100.00 2071.19 2,26 4.86 190.86 190.86 9,62 282.55 42.57 244.33 Pass 2163.17 2163.17 2200.00 2163.17 2.36 5.37 188.12 188.12 9.62 319.00 45.39 279.24 Pass 2252,21 2252.21 2300.00 2252.21 2.46 5.98 185.73 185.73 9.62 362.21 46.49 320.94 Pass 2337.92 2337.92 2400.00 2337.92 2.56 6.69 183.71 183.71 9.62 4tl.86 51.86 369.09 Pass 2422.36 2422.36 2500.00 2422.36 2.65 7.46 182.09 182,09 9.62 463.99 55.38 419.76 Pass 2506.80 2506.80 2600.00 2506.80 2.75 8.23 180.80 180.80 7.00 516.41 58.83 470.82 Pass 2591.24 2591.24 2700.00 2591.24 2.84 9.02 179.75 179.75 7.00 569.04 62.42 521.97 Pass 2675.69 2675.69 2800.00 2675.69 2.94 9.82 178.87 178.87 7.00 621.83 66.04 573.28 Pass 2754.28 2754.24 2900.00 2760.13 2.97 10.61 178.33 99.19 7.00 675.11 69.22 625.44 Pass 2832.35 2832.04 3(X)0.00 2844.57 3.00 11.37 178.22 99.08 7.00 729.15 72.40 678.15 Pass 2909.45 2908.42 3100.00 2929.01 3.04 12.09 178.46 99.32 7.00 783.92 75.46 731.50 Pass RAM WELl. DETAKS Nan~ +N/-S +E/-W No,ling F,a~g La.nde Lon~tnde Slot Plan: V-I~O 0.~0 Ct{~} 59~r~f~4.50 ~70 70= 19'?&61~ 149= lY49.8'KflV N/A ANTM2OLLISION SETTINGS l~h P,m~e Fron~ ~0.00 To: $354_97 !t~n.~n:mm Range: 1 (~)~0 Refeazoce: Pim~ V-100 WP5 --799 --750 --250 -0 --250 -5OO COMPANY DE~AILS SURVEY PROGRAM Bi'Amoco DepthFm Dep~hTo Sm-~-ey/Phn Cat-ulak~Mefls~d- : h~mCu~,me ~0.008354.97 Phnmd:V-IC~WPSVI Em~ Systat ISCWSA Scm i&:~od: Troy C)ladex No~h 8000 21t L50 From Colour To MD 0 1000 1000 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 90OO 10000 12000 14000 18000 19000 Tool 9O 120 WHIJ'AIH V. I(10 '~9_14' O~O 0.00 0.00 ~ I~l¥-{~l~)"F~ftlqm V4t-IOa)), NOi-~RRORS ~ ¥-I~, -- ¥-I~O W'I~ --750 --799 V-(z-lOa)??? (Plan V-(z-lOa)) m _ :-=~- ~_ '% / %.r~~g ~linder ~imu~O~)=Ceg]~Centr~o Ce~ ~~n [5~] V-lO0 Surface hole mud logging. Subject: V.100 Surface hol mud logging. Date: Tue, 20 Mar 2001 18:34:17 -0600 From: "Sherritt, Allen" <SherriJA@BP.com> To: "Smith, Phil G (FAIR)" <SmithPGl@BP.com>, "Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak. us>, "Bob Crandall (E-mail)" <bob_crandall@admin.state.ak.us> CC: "Bunch, Anthony S" <bunchas@BP.com>, "Stone, Dan M" <StoneDM@BP.com>, "Smith, Bruce W" <SmithBW@BP.com> Mr. Crandall, As per our phone conversation, (phone messages), mud logging will be added to the V-100 program, as this well will be the first well drilled from the new V-Pad location. EPOCH will provide mud logging services, (mud logs, gas detection, sample gathering, etc.), while drilling V-100. If there are any questions or concerns, please contact myself or Phil Smith, (564-4897.) Thanks, Allen Sherritt BP Alaska Drilling and Wells * (907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrija@bp.com * (907) 564-4040 (Fax) * MB 6-3/681B 1 of 1 4J18/01 7:16 AM H 1, 1295 VENDOR ALASKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122100G 100. O0 100. O0 PYMT 30MMENTS: Per~ait to drill Fee HANDL[NC INST: S/H - Sondra X4'750 ~i~JOtl', u0jee!mmo0 'suoo ~.e9 ~ !!0 :Fi RST':~'ATIO~E.:BA N K::~F ASH!gAND !.<;:-i!i 2: !'i: '~'~i'~F~dATE:O~ -:i.::ii" :' ::::.' . :::::::::.! ::-.-::': ': NA'~ON~,t'-'C "FY. BJ~';,/K : '!:' .'!:i 'i-..; ;: 'i:-:.:::; ..:: ;: '~EEv~i~D O'HiO i: i :'. ?:.::". 'i ::.ii '.-<.::. ::: .. :..:.::. ;: :: ..i. · -.' %_ .;i' ..: . :::i: .." :: ' - '- '-: 412 PAY .... :" .... ~ "I'" ....... °l/°3/°l I ! .... - ~°°! ::::'::'. ~-:':~:~' : ~::' - .... )..~'.::':~' NO~:~VALID A~ER 120 DAYS .. '. .: '.::'. -~ ~ ': WELL PERMIT CHECKLIST FIELD & POOL ~~i~r'' ~.O/$¢JNIT CLASS COMPANY ,/~/o WELL NAME 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 ........... PROGRAM: exp der .. redril, serv ~ wellbore seg ann. disposal para req GEOL AREA o~'~ UNIT# //x~_5'~ ON/OFF SHORE o,,,J N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. · 25. ~[~;~ DATE 26. ~'~/ ~ [ ~ (-,~ 27. 28. 29. GEOLOGY 3O. 31. 32. 34. 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 .............. ~ N . If diVerter required, does it meet regulations .......... ~ N Drilling ·fluid program schematic & equip list adequate ..... ~ N . · BOPEs, do they meet regulation ................ (~ N , BOPE press rating appropriate; test to '~.~O~ psig. (~ ~ N ~,A,~,c~.~, ~:.¥~;\ ~.,,c~"~( ~ ~C, ~L ~ ~, Choke manifold complies w/APl RP-53 (May 84) ........ ~ ) N Work will occur without operation shutdown ........... ~ )N., ' Is presence of H2S gas probable ................. Y~'J Permit can be issued wlo hydrogen sulfide measures ..... Y~_,..~.,,N... Data presented on Potential overpressure zones ....... Y N / ,/ I Seismic analysis of shallow gas zones ............. Y/N" /~,,~.,'/),~?'~ Seabed condition survey (if off-shore) ............. ~ N Contact name/phone for weekly progress reports [exploratory~] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a Suitable receiving zonei .... . . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and · . .. (E)...,will n.o..t, circumvent.. 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING:. ' UIC/Annular N COMMISSION: GEOLOGY: Commentsllnstrucfions: O Z O -I bp BP EXPL ORA TI O N (ALASKA), INC. V-lO0 PRUDHOE BAY FIELD Section 11-TI IN. RI rE, UM North Slope Borough, Alaska May 10, 2001 Tim Smith - Sr. Logging Geologist Brian O'Fallon- Sr. Logging Geologist DIGITAL WELL DA TA EPOCH V-lO0 BP EXPLORATION (ALASKA), INC. V-lO0 Prudhoe Bay Field North Slope Borough, Alaska TABLE OF CONTENTS TABLE OF CONTENTS ........................................................................................................ 1 WELL RESUME .................................................................................................................... 2 FORMATION SUMMARY ................................. 3 MUD RECORD ..................................... 26 EPOCH 1 bp ~"t~V,= V-100 WELL RESUME Operator: Well Name: Location: Coordinates: Elevation: County: State: APl Index: Spud Date: Contractor: Foremen: Rig: Logging Unit: Geologists: Company Geologist: Log Interval: Dates: Mud Types: Hole Size: BP Exploration (Alaska), inc. V-lO0 North Slope Borough, Alaska BP Exploration (Alaska), Inc. V-100 Sec. 35, TllN, R10E, UM 4715' FSL, 1532' FEL RKB: 60' AMSL North Slope Borough Alaska 50-029-23008 412912001 Nabors AK Drilling Richard Bordes, John Raul #7ES - Land #12 Tim Smith Brian O'Fallon Kip Cerveney 110' to 7996' 4/2912001 to 51912001 Spud Mud to 276t' 4% KCI to 7996' 12 1/4" to 2761' 8 %" to 7996' EPOCH 2 FORMATION SUMMARY BP Exploration (Alaska), Inc. V-lO0 North Slope Borough, Alaska 110 Conglomerate = medium gray to medium dark gray overall, with individual are predominantly metalithics and possibly volcanics and minor quartz and trace quartzite; grains are often rounded to sub rounded pebbles and angular rock fragments; size mostly coarse grained to pebble and some larger up to 30 mm in sample; slight clay matrix; estimate mostly good porosity and permeability; no hydrocarbons indicated. 175 Conglomeratic Sand = medium dark gray to dark gray overall; mostly coarse grains and pebbles and rock fragments up to 5 mm; common medium grains and some rocks and fragments up to 35 mm in sample; mostly sub rounded to rounded and some to abundant angular fragments some with rounded edges; clasts are predominantly metalithics including mostly black to dark gray dense grains with no visible crystals; some varicolored grains mostly dark and dense with no visible crystal; occasional metalithics dark gray to black streaked with white quartz; occasional quartz, chert, and meta-sandstone; estimate some good porosity; no hydrocarbons indicated. 270 Conglomerate = dark gray to medium dark gray overall; abundant pebbles and boulders up to 70 mm in sample in mostly coarse sandy matrix; mostly metalithics including dark gray to black clasts and some white quartz; some varicolored grains; some clay in matrix easily soluble and poorly cohesive; estimate mostly fair to good porosity; no hydrocarbons are indicated. 330 Conglomerate = dark gray to medium dark gray overall; abundant pebbles and boulders up to 50 mm in sample in coarse to fine sandy matrix; mostly metalithics including dark gray to black clasts and some white quartz; some varicolored grains; some clay in matrix easily soluble and poorly cohesive; occasional shell fragment some in sandy calcareous matrix; estimate mostly fair to good porosity; estimate poor permafrost permeability; no hydrocarbons are indicated. 400 Conglomeratic Sand = medium dark gray overall; fine to coarse grains with moderate to abundant pebbles and rocks up to 20 mm in sample; locally increase in fine to medium EPOCH 3 ¢: ;k ¥-100 grains; mostly sub angular to rounded and some angular fragments; mostly metasediments and some igneous clasts; includes mostly dark gray to very dark gray grains, some quartz increasing in finer fraction, and occasional chert and varicolored grains; occasional shell fragments and rare petrified wood fragments with abundant pyrite replacement; slight increase in clay matrix especially conglomerate; estimate mostly fair to good porosity; estimate Iow permafrost permeability; no hydrocarbons indicated. 495 Pebble Conglomerate = medium dark gray overall; medium to very coarse grains and moderate to abundant pebbles mostly less than 5 mm; locally increase in conglomerate up to 30 mm in sample; sub angular to sub rounded; Iow to moderately high sphericity; estimate moderately sorted in slight to variable clay matrix; increased clay in samples easily soluble and slightly to moderate cohesive; predominantly metalithics and minor igneous and shell fragments; trace carbonaceous matter and micropyritic lithics; estimate some fair to good porosity; estimate iow permafrost permeability; no hydrocarbons indicated. 600 Conglomerate = medium dark gray to dark gray overall; medium to very coarse grains, and abundant pebbles and larger grains mostly to 5 mm up to 25 mm in sample; sub angular to rounded; mostly metasediments including dark mafics, some quartz, and minor chert; slight to locally increasing carbonaceous matter mostly wood often with micropyrite replacement; very slight shell fragments; variable clay matrix grading to claystone; estimate some poor to fair porosity and Iow permafrost permeability; no hydrocarbons indicated. 680 Carbonaceous Matter = dark brown to brownish black; wood; moderately soft to some firm to hard; fibrous to rotten to partially petrified; some with medium to coarse grained imbedded sand; some with moderate to abundant micropyrite replacement. 720 Claystone = medium gray to medium dark gray; moderately soft and soluble; stiff cohesive consistency; slightly to moderately gritty feel; variably sandy grading conglomeratic sand and conglomerate; trace disseminated micas; slightly calcareous; moderately expansive rehydrated. 765 Conglomeratic Sand = dark gray to medium dark gray overall; medium to very coarse grains with moderate to abundant pebbles and rocks mostly up to 5 mm to scattered up to 18 mm in sample; sub angular to rounded; Iow to high sphericity; estimate moderately to poorly sorted in variable clay matrix; mostly metalithics including dark mafics and some quarts and minor chert; slight carbonaceous clasts mostly wood and commonly [::1 EPOCH 4 :~ ; V-lO0 with micropyrite alteration; estimate some good to fair porosity; estimate poor permafrost permeability; no hydrocarbons indicated 845 Claystone/Clay = medium dark gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; moderate adhesion; Iow soluble; mushy to pasty; massive cuttings habit; possibly thin interbedded with conglomeratic sand and sand and/or clay matrix material; non to slightly calcareous. 915 Conglomeratic sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black; predominantly coarse to very coarse, abundant grains ranging down to fine; well to fair sorted; predominantly angular to sub angular; moderate spheroidal sphericity; 100% unconsolidated dominated by metalithic grains with some quartz and chert; abundant woody and carbonaceous material; moderate trace pyrite aggregate and nodules inferred grain supported with possible clay matrix support; good to very good visual estimated porosity; no sample fluorescence; no cut; no other hydrocarbon indicators. 1000 Claystone/Clay = medium dark gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; moderate adhesion; Iow soluble; mushy to pasty; massive cuttings habit; possibly thin interbedded with conglomeratic sand and sand and/or clay matrix material; non to slightly calcareous. 1050 Conglomerate = varicolored with' shades of gray dominant; pebble and bit broken pebble sized ranging up to 23 mm; well rounded where not bit broken; 100% unconsolidated; predominantly metalithic pebbles and fragments (phyllite, argillite), lesser amounts quartz and undifferentiated chert; trace pyrite overgrowths and loose aggregate and nodules sample associated with abundant clay/claystone, interbedded with and/or matrix packing; very good visual estimated porosity; no hydrocarbon indicators. 1125 Claystone/Clay = medium dark gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; moderate adhesion; Iow soluble; mushy to pasty; massive cuttings habit; possibly thin interbedded with conglomeratic sand and sand and/or clay matrix material; non to slightly calcareous. 1170 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black; predominantly medium to very coarse, abundant grains ranging down to fine; well to fair sorted; predominantly angular to sub angular; moderate spheroidal sphericity; 100% unconsolidated dominated by metalithic EPOCH 5 grains with some quartz and chert; trace of woody and carbonaceous material; moderate trace pyrite overgrowth and loose nodules; inferred grain support with undetermined amount of possible clay matrix support; good to very good visual estimated porosity; no hydrocarbon indicators. 1260 Conglomerate = varicolored with shades of gray dominant; pebble and bit broken pebble sized ranging up to 15 mm; well rounded where not bit broken; 100% unconsolidated; predominantly metalithic pebbles and fragments (phyllite, argillite), lesser amounts quartz and undifferentiated chert; trace pyrite overgrowths and loose aggregate and nodule; sample associated with abundant clay/claystone, interbedded with and/or matrix packing; very good visual estimated porosity; no hydrocarbon indicators. 1330 Woody/Plant Material = dark yellowish brown to moderate olive brown; moderately firm to slightly firm; predominantly fibrous to woody, occasionally rotted; sand packed boreholes and wood grain partings; moderate trace of pyritization. 1370 Claystone/Clay = brownish gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; Iow adhesion; Iow soluble; pasty to mushy; massive cuffings habit; silty to gritty texture; possibly thin interbedded with silicates and/or clay matrix material; predominantly non to slightly calcareous, occasionally moderately calcareous. 1430 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black; predominantly medium to very coarse, abundant grains ranging down to lower medium; fair sorted; predominantly angular to sub angular; moderate spheroidal sphericity; 100% unconsolidated dominated by metalithic grains With some quartz and chert; abundant loose pyrite aggregate and nodules; abundant grains with pyrite overgrowth; good to very good visual estimated porosity; no sample fluorescence; no cut; no other hydrocarbon indicators. 1510 Sand = individual grains light gray to translucent white to transparent, occasional varicolored yellowish gray to reddish gray hues; lower medium to upper fine; well sorted; sub angular to angular, occasionally sub rounded; moderate to high spheroidal sphericity; 100% unconsolidated; grain/matrix support inferred; 50-60% quartz, 30-40% chert, 10-20% metalithic fragments; good to fair visual estimated porosity; no discernible sample fluorescence; no cut; no other hydrocarbon indicators. EPOCH 6 ..... V-lO0 1580 Conglomerate = varicolored with shades of gray dominant; pebble and bit broken pebble sized ranging up to 20 mm; rounded to well rounded where not bit broken; 100% unconsolidated; 40-50% metalithic pebbles and bit broken fragments, 20-30% chert, 30- 40% quartz, trace pyrite overgrowths and loose aggregate and nodule; very good to good visual estimated porosity; no hydrocarbon indicators. 1635 Claystone/Clay = medium dark gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; moderate adhesion; Iow soluble; mushy to pasty; massive cuttings habit; possibly thin interbedded with conglomeratic sand and sand and/or clay matrix material; non to slightly calcareous. 1680 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black; predominantly medium to very coarse, abundant grains ranging down to lower medium; fair sorted; predominantly angular to sub angular; moderate spheroidal sphericity; 100% unconsolidated dominated by metalithic grains with some quartz and chert; abundant loose pyrite aggregate and nodules; abundant grains with pyrite overgrowth; good to very good visual estimated porosity; no sample fluorescence; no cut; no other hydrocarbon indicators. 1760 Sand = individual grains light gray to translucent white to transparent; lower medium to upper fine; well sorted; sub angular to angular, occasionally sub rounded; moderate to high spheroidal sphericity, rare Iow discoidal sphericity locally; 100% unconsolidated; grain support with some possible clay matrix support inferred; 40-50% quartz, 40-50% chert, 10% to trace fine to medium grain metalithic fragments; good to fair visual estimated porosity; no discernible sample fluorescence; no cut; no other hydrocarbon indicators. 1835 Claystone/Clay = brownish gray to olive gray; soft to very soft, occasionally slightly firm; Iow to moderate cohesion; Iow adhesion; Iow soluble; pasty to mushy; massive cuttings habit; silty to gritty texture; possibly thin interbedded with silicates and/or clay matrix material; predominantly non to slightly calcareous, occasionally moderately calcareous. 1890 Claystone/Clay = medium gray; very soluble and soft and mushy; expands slightly rehydrated; slightly silty possibly with thinly bedded clayey siltstone; slight to very slight fine to pebble sized sand to scattered rocks up to 35 mm in sample; sand and silt mostly quartz with some dark mafics increasing with grain size; slight disseminated dark brown to black carbonaceous matter; trace micas and very finely disseminated calcareous matter. EPOCH 7 1980 Claystone/Clay = medium gray; very soluble and soft and mushy; expands slightly rehydrated; slightly silty possibly with thinly bedded clayey siltstone; very slight very fine to fine sand to scattered pebbles and rocks up to 30 mm in sample; sand and silt mostly quartz with some dark mafics increasing with grain size; slight disseminated dark brown to black carbonaceous matter; trace micas and very finely disseminated calcareous matter. 2045 Sand = medium gray overall; upper fine to medium grains; sub angular; moderate sphericity; estimate well sorted with possible slight overall clay matrix; 80% quartz; 20% dark gray to black to brownish black mostly hard siliceous grains probably dark mafics and minor soft carbonaceous matter; <1% white to translucent calcareous grains; overall salt and pepper appearance; estimate mostly good porosity and permeability; no oil indicators. 2110 Claystone/Clay = medium gray; soluble and very soft and mushy; expands slightly rehydrated; slight to moderate mostly fine to very fine sand and slight silt in sample; scattered pebbles and rocks possibly cavings; sand and silt mostly quartz and some hard dark gray to black grains; very slight very finely disseminated carbonaceous matter and occasional flakes; trace very finely disseminated micas; noncalcareous. 2170 Conglomeratic Sand = medium gray to medium dark gray overall; very fine to very coarse grains and some pebbles and rocks mostly up to 5 mm to scattered up to 25 mm in sample; mostly sub angular with some bimodal rounded coarse and pebble fraction; moderately to poorly sorted; probable variable clay matrix grading claystone; varicolored grains including black to dark gray to translucent to white to dark brown to yellow to gray; grains hard and siliceous metalithics including dark mafics, quartz, metasediments, and chert; quartz fraction and sorting increasing in finer fraction; estimate fair to good porosity and permeability; no oil indicators. 2280 Clay/Claystone = medium dark gray to medium gray; soluble and soft and mushy; expands slightly rehydrated; slight to moderate loose sand and silt in sample; grains mostly medium to very coarse, and include black to dark gray metalithics and quartz; some minor varicolored grains and plant (woody) matter; probably grading poorly to moderately sorted sand, pebble conglomerate and conglomerate; trace calcareous matter. 2360 Conglomeratic Sand = medium dark gray to medium gray; mostly medium grained to pebble, some fine grains and scattered rocks up to 40 mm in sample; bimodal with rounded to sub rounded in coarse and conglomeratic fraction and sub angular in finer EPOCH 8 bp fraction; estimate moderately to poorly sorted with probable variable clay matrix grading to and interbedded with claystone; grains are mostly dark gray to black and translucent to white; mostly metalithics including quartz, chert, metasediments, and dark mafics; slight carbonaceous matter including fibrous to slightly siliceous wood splinters; rare calcareous grains and trace micropyrite replacement clusters; estimate some good to fair porosity and permeability in cleaner sands; no oil indicators. 2465 Clay/Claystone = medium dark gray to medium gray; soluble and soft and mushy; expands slightly rehydrated; moderate to slight loose sand and silt; grains mostly medium to some coarse and pebble; scattered rocks up to 30 mm in sample; sub angular overall with common bimodal sub rounded to rounded in coarse to conglomeratic fraction; grains mostly dark gray to black and translucent to white; mostly metalithics including quartz, chert, metasediments, and dark mafics; slight calcareous matter and trace carbonaceous/woody matter; trace micas; probably grading conglomeratic sand and conglomerate. 2550 Conglomeratic Sand = medium gray overall; mostly medium to coarse and slight to moderate very coarse and pebble, with scattered larger grains; sub angular in finer fraction and mostly sub rounded to rounded in coarser fraction; grains dark gray to black and translucent to white; mostly metalithics including quartz, chert, metasediments, and dark mafics; slight calcareous matter and trace carbonaceous/woody matter; moderately well to poorly sorted in probable variable clay matrix; estimate some good to fair porosity and permeability; no oil indicators. 2630 Clay/Claystone = medium light gray to light gray; very soft to soft, rarely slightly firm; Iow cohesion; moderate to high adhesion; Iow soluble; mushy; massive cuttings habit; dull to waxy luster; silty to gritty texture; non calcareous. 2670 Conglomeratic Sand = individual grains range from translucent white and yellowish gray to grayish black with some brownish hues; overall sample obscured with adhesive light gray clay; medium to very coarse with abundant pebble fragments; poorly sorted overall; large grains predominantly rounded to subrounded, finer grains subangular to subrounded; moderate to high spheroidal sphericity; 100% unconsolidated; metalithic fragments with lesser amounts of quartz and chert; possibly matrix supported; trace bright yellow mineral fluorescence; no cut. 2780 Carbonaceous Matter = black, pliable to slightly brittle; flaky to splintery; slightly fibrous; probably wood/plant matter; slight micropyrite alteration and occasional pyrite clusters. EPOCH 9 2820 Sand = overall sample brownish gray to dark yellowish brown, individual grains translucent white to transparent, occasionally pale red to light brownish gray; lower medium to upper fine, occasionally lower fine; fair to well sorted; angular to subangular; moderate spheroidal sphericity; 100% unconsolidated; grain/clay matrix supported; 40- 60% quartz, 40-60% chert, trace to 10% other lithic fragments; good to fair visual estimated porosity; no discernible sample fluorescence; no cut. 289O Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; possibly thin interbedded claystone with clay matrix sands; slightly calcareous. 2945 Sand = overall sample medium light gray to light olive gray, individual grains translucent white to medium gray to transparent; lower medium to upper fine, occasionally upper medium and lower fine fair sorted; angular to subangular, coarser grains subangular to subrounded; moderate to Iow spheroidal sphericity; 100% unconsolidated; grain/matrix supported; 20-30% quartz, 20-30% chert, 40-60% metalithic fragments, fair to good visual estimated porosity; 40% very faint dull orange-brown sample fluorescence; moderate bluish white fast streaming cut; dull pale yellow residual fluorescence. 3O30 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to subtabular cuttings habit; dull to earthy luster; silty to gritty texture; interbedded with and grading to claystone; no discernible sample fluorescence; no cut. 3075 Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; interbedded and grading to siltstone; slightly calcareous. 3150 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black, abundant yellowish brown to brown hues; clasts range from 5mm to upper fine grained; moderately sorted; larger grains subrounded to rounded, finer grains sub angular to subrounded; moderate to high spheroidal sphericity; 100% unconsolidated; grain supported with some possible matrix support; predominantly metalithic fragments with secondary amounts of quartz and chert; good visual estimated porosity; no sample fluorescence; no cut. EPOCH 10 3220 Carbonaceous Material = blackish red to dusky brown to black; firm; crumbly to subbrittle; earthy to slightly splintery fracture; predominantly platy to flaky cuttings habit, occasionally wedgelike; waxy to resinous luster; smooth to matte texture; predominantly appears fibrous to woody, locally appears subbituminous in part. 3270 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to subtabular cuttings habit; dull to earthy luster; silty to gritty texture; interbedded with and grading to claystone; no discernible sample fluorescence; no cut. 3315 Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; interbedded and grading to siltstone; slightly calcareous. 3375 Sand = medium gray overall, individual grains transparent to translucent white to medium dark gray; upper fine to lower fine; well sorted; subangular to subrounded; high to moderate spheroidal sphericity, rare Iow to moderate discoidal sphericity; 100% unconsolidated; grain support inferred with some possible clay matrix support; 40% metalithic fragments, 30% quartz, 30% chert; good visual estimated porosity; no discernible sample fluorescence; no cut. 3440 Coal = black; moderately hard to slightly hard; brittle to dense; conchoidal to splintery fracture; wedgelike cuttings habit; dull luster; smooth to matte texture; bituminous to subbituminous. 3470 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from translucent white to grayish black, abundant yellowish brown to brown hues; clasts range from 7mm to lower fine grained; moderately sorted; larger grains subrounded to rounded, finer grains subangular to subrounded; moderate to high spheroidal sphericity; 100% unconsolidated; grain supported with some possible matrix support; predominantly metalithic fragments with secondary amounts of quartz and chert; good visual estimated porosity; no sample fluorescence; no cut. 3550 Sand = medium gray overall, individual grains transparent to translucent white to medium dark gray; upper fine to lower fine; well sorted; subangular to subrounded;. moderate to high spheroidal sphericity; 100% unconsolidated; grain/matrix support EPOCH 11 ~ ~ V-lO0 inferred; 40% quartz, 30% metalithic fragments, 30% chert; good to fair visual estimated porosity; 10-40% rust to dull orange sample fluorescence; moderate streaming pale yellow white cut; no visible light cut; no visible staining on cuttings. 3620 Conglomeratic Sand = medium light gray overall; medium to coarse lower, to some very coarse and pebble up to 15 mm in sample; subangular to subrounded; pebble fraction often bimodal and rounded to subrounded; estimate well to moderately well sorted; estimate mostly slight clay matrix; salt and pepper appearance with 80% clear to translucent quartz, 20% very dark gray to dark brown gray siliceous lithics including occasional chert and dark mafics, and minor white calcareous debris; estimate some very good to good porosity and permeability; no oil indicated. 3700 Claystone = brownish gray to grayish brown to light gray to dark brownish gray to black; smooth to silty texture; amorphous to subplaty with irregular fracture and some weak planar bedding; slightly firm and slightly soluble, increasing to soft and moderate to very hydrophilic in some light gray clays as grading to ash; some bedded as carbonaceous matter to commonly with slight included carbonaceous matter and flakes; often very slight to occasionally moderate disseminated mica; mostly non calcareous to some with slightly scattered calcareous matter. 3785 Carbonaceous Shale = black to brownish black; mostly moderately soft and pliable to some slightly firm and brittle; flaky to subplaty with visible fissility; layered carbonaceous flaky matter grading in part to Iow grade coal; massive to thinly bedded with flakes often included in interbedded claystone and siltstone. 3835 Siltstone = very light gray to light gray; very soft and moderately to very hydrophilic; amorphous to subblocky; very clayey grading claystone; silty texture from silt to very fine grains mostly quartz and slight micas and carbonaceous matter; grains angular to subrounded; occasional carbonaceous flakes and partings; some sandy and interbedded with sand; clays and silts probably derived in part from ash fall tuffs; some with slight calcareous matter. 3905 Sand = light gray overall; medium to fine and scattered coarse grains; subangular to angular; estimate moderatelY well sorted overall with probable variable clay and silt to very fine sand matrix; salt and pepper with 80% quartz, 20% dark brownish gray to dark gray mostly siliceous carbonaceous lithics, trace micas and other siliceous lithics; estimate some fair to good porosity and permeability; no oil indicators. EPOCH 12 4015 Sand = light gray overall; medium to fine grained; subrounded to subangular; moderate to high sphericity; estimate well sorted with probable slight to variable clay and some silt to very fine sand matrix; salt and pepper with 85% quartz, and 15% dark gray to dark brown gray partially siliceous mostly carbonaceous lithics; trace calcareous and chloritic lithics; estimate good to fair overall porosity and permeability; trace brown stain and yellow gold fluorescence absorbed in clays. 4085 Sand = very light gray; medium grained and some fine upper and coarse lower; subangular to angular; moderate sphericity; estimate well sorted with probable overall slight clay matrix; 75% quartz, 25% dark gray to gray hard lithics including metasediments, chert, and siliceous and trace carbonaceous lithics, and trace feldspar and calcareous lithics; estimate some good to fair porosity and permeability; 40% visible brown to light brown stain on individual grains; 70% moderate to dull orange fluorescence with cut; oil fluorescence, cut, and possible stain obscured by mud additives. 4170 Sand = very light gray to light gray; medium to fine upper grained; subangular to subrounded; moderate sphericity; estimate well sorted with slight overall clay and very slight silt matrix; 75% quartz, 25% dark gray to gray hard lithics including metasediments, chert, and siliceous and trace carbonaceous lithics, and trace feldspar and calcareous lithics; estimate good to fair porosity; 20% faint visible brown oil stain on grains; 50% dull orange fluorescence and light yellow to orange cut: oil properties obscured by mud additives contamination. 4250 Sand = light gray to very light gray; fine to medium grained and some very fine grained; subangular; moderate sphericity; estimate well to moderately well sorted with slight to variable clay and slight silt matrix; probably interbedded with sandy claystone; 80% quartz, 20% dark gray to gray hard lithics including metasediments, chert, and siliceous and trace carbonaceous lithics, and trace feldspar and calcareous lithics; estimate good to fair porosity and permeability; 30% faint light brown to brown stain; 70% dull to moderate orange yellow fluorescence and light yellow cut; oil properties obscured by mud additives. 4340 Tuff/Tuffaceous Claystone = very light gray to yellowish gray; very soft; curdy to clotted consistency; amorphous; massive cuttings habit; waxy to dull luster silty to smooth texture; sample ranges from apparent clean ashfall tuff interbedding to detrital tuffaceous material grading to claystone; predominantly contains flecks of carbonaceous material and sand grains possibly due to mixing in annulus; non calcareous. EPOCH 13 , V-lO0 4400 Carbonaceous Material = blackish red to dusky brown to black; firm; crumbly to subbrittle; earthy to slightly splintery fracture; predominantly platy to flaky cuttings habit, occasionally wedgelike; waxy to resinous luster; smooth to matte texture; predominantly appears fibrous to woody, locally appears subbituminous in part. 4450 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from medium gray to light olive gray to pale brown, occasionally light gray to translucent white to transparent; trace bit broken pebble size up to 15mm, otherwise upper fine to upper medium predominant; moderately to well sorted; subangular to angular with angularity increasing as grain size decreases, occasionally subrounded high to moderate spheroidal sphericity; no visible cementation; grain supported with abundant clay in sample possibly matrix material; 50% metalithic fragment 30% quartz, 20% chert; good visual estimated porosity if not matrix supported; no sample fluorescence; no cut. 4545 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to subtabular cuttings habit; dull to earthy luster; silty to gritty texture; interbedded with and grading to claystone; no discernible sample fluorescence; no cut. 4590 Sand = medium gray overall, individual grains medium dark gray to translucent white, occasionally transparent, olive gray, rarely moderate red, pale green; upper fine to upper medium, occasionally upper coarse, lower fine; well to moderate sorted; subangular to angular, occasionally subrounded; moderate to high spheroidal sphericity; unconsolidated with no visible cementation; variable amounts of clay in samples, variable grain/matrix support proportions inferred; local traces carbonaceous material possibly as thin interbeds or detrital fragments; good visual estimated porosity; no discernible sample fluorescence; no cut. 4680 Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; interbedded and grading to siltstone; non calcareous. 4740 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from medium gray to light olive gray to pale brown, occasionally light gray to translucent white to transparent; predominantly upper fine to upper medium grained; moderately sorted; subangular to angular; moderate spheroidal sphericity, occasionally EPOCH 14 broken coarser grains highly discoidal; unconsolidated with no visible cementation; variable grain/matrix support inferred due to constant soft clay in sample, inferred in part to be matrix material; 40% chert, 30% quartz, 30% metalithic fragments; good to very good visual estimated porosity; no discernible sample fluorescence; no cut. 4835 Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; interbedded and grading to siltstone; non calcareous. 4895 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to subtabular cuttings habit; dull to earthy luster; silty to gritty texture; interbedded with and grading to claystone; no discernible sample fluorescence; no cut. 4940 Sand = medium light gray to medium gray overall, individual grains translucent white to medium gray with various gray and brownish gray hues in between, occasionally transparent, yellowish gray; lower medium to upper fine grained; moderately to well sorted; subangular to angular, occasionally subrounded; moderate to high spheroidal sphericity; unconsolidated with no visible cementation grain/matrix support inferred; good visual estimated porosity; no sample fluorescence discernible over mud additive contamination. 5015 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from medium gray to light olive gray to pale brown, occasionally light gray to translucent white to transparent; predominantly upper fine to upper medium grained; moderately sorted; subangular to angular; moderate spheroidal sphericity, occasionally broken coarser grains highly discoidal; unconsolidated with no visible cementation; variable grain/matrix support inferred due to constant soft clay in sample, inferred in part to be matrix material; 40% chert, 30% quartz, 30% metalithic fragments; good to very good visual estimated porosity; 100% bright medium yellow sample fluorescence; flash to fast streaming bluish white cut; dull yellow residual fluorescence. 5120 Sand = medium light gray to medium gray overall, individual grains translucent white to medium gray with various gray and brownish gray hues in between, occasionally transparent, yellowish gray; lower medium to upper fine grained; moderately to well sorted; subangular to angular, occasionally subrounded; moderate to high spheroidal sphericity; unconsolidated with no visible cementation grain/matrix support inferred; good visual estimated porosity; 80% sample fluorescence, medium yellow to dull yellow; EPOCH 15 very fast streaming to flash bluish white cut; possible combination of formational and mud contamination fluorescence. 5210 Conglomeratic Sand = medium dark gray to medium gray overall with individual grains ranging from medium gray to light olive gray to pale brown, occasionally light gray to translucent white to transparent; predominantly upper fine to upper medium grained; moderately sorted; subangular to angular; moderate spheroidal sphericity; unconsolidated with no visible cementation; grain matrix support inferred; good to fair visual estimated porosity; predominantly metalithic fragments with secondary amounts of chert and quartz; no discernible sample fluorescence over mud additive fluorescence after 5270' sample no definitive cut. 5300 Claystone = light gray to light brownish gray; soft to very soft, rarely consolidated in sample; moderate to Iow cohesion; moderate to high adhesion; Iow to moderate soluble; irregular to subblocky fracture for more consolidated cuttings; massive cuttings habit; dull luster; predominantly silty to gritty texture, occasionally smooth; interbedded and grading to siltstone; moderately calcareous and/or encapsulating calcareous material. 5365 Siltstone = medium gray; slightly firm; subblocky; very, clayey and mostly coarse silt grading very fine grained argillaceous sandstone; slightly carbonaceous with silt sized disseminated matter; very poor porosity and permeability; abundant light brown stain absorbed in matrix indistinguishable from mud additives; slight petroleum odor; 50% moderate orange yellow fluorescence and instantaneous to slow streaming blue white to light yellow cut. 5430 Carbonate = medium gray to reddish brown to tan to cream; moderately soft to firm; crumbly to brittle; dense cryptocrystalline to micritic; some flaky to platy; dissolves quickly as limestone or effervesces slowly as dolomitic; possibly altered shell fragments in part as occasional platy piece with slight laminated arc; possibly grading siderite in part; some included in claystone. 5490 Sandstone = medium gray to medium light gray; fine to very fine grained some grading to siltstone; subangular; poorly to moderately well sorted with slight to moderate clay matrix and mostly slight to moderate calcareous cement; some loose grains in sample mostly fine; 75% quartz, 25% dark gray to gray to dark brownish black mostly siliceous lithics and possible dark mafics and minor carbonaceous matter, and minor calcareous matter; estimate some poor to fair porosity and permeability; visible brown to light brown stain in 15% of sandstone; 40% dull to moderate orange yellow fluorescence; instantaneous to slow streaming light blue white cut; oil indistinguishable from mud additives. EPOCH 16 v- oo 559O Tuff = light gray to light greenish gray; moderately soft and crumbly; smooth greasy luster; nonexpansive and non soluble in water; trace micropyrite crystals. 5620 Sandstone = white to gray; very fine to fine grained to silty; angular to subangular; moderately to poorly sorted; slight to moderate white calcareous cement grading to argillaceous matrix; moderately well consolidated to friable; grading siltstone and claystone; mostly quartz and slight carbonaceous matter; estimate some very poor to poor porosity and permeability; 20% visible brown stain predominantly on surface to some absorbed in fragment; 40% moderate orange yellow fluorescence and cut; oil obscured by mud additives. 5695 Claystone = medium light gray to light gray to medium gray; soft and soluble to slightly firm and slightly soluble; some slight planar bedding with poor fissility grading shale especially firm; slightly to moderately silty/gritty texture as thinly interbedded with argillaceous siitstone and sandstone; slight very finely disseminated to flaky carbonaceous matter with flakes randomly oriented to weakly lineated along bedding planes; trace very finely disseminated micas; very slightly calcareous overall; 30% dull to moderate orange yellow to yellow fluorescence especially in silty/sandy cuttings; oil obscured by mud additives contamination. 5790 Sandstone = medium light gray to medium gray; very fine grained to silty to scattered fine grains; subangular; poorly to moderately sorted; often slightly to occasionally moderately consolidated with calcareous cement; mostly friable with non to trace calcareous cement; slightly to moderately argillaceous including very slight to slight carbonaceous matter and flakes; thinly bedded in claystone and siltstone; occasional brown stain; 30% cut and fluorescence obscured by mud additives contamination. 5865 Claystone = medium gray to medium light gray; soft and soluble to slightly firm and soluble; some slight bedding plane structure grading shale; slightly to moderately silty/gritty as interbedded with argillaceous siltstone to fine sand stone; dull to slightly sparkly luster often with trace to slight micas; slight carbonaceous matter; predominantly non to slightly calcareous and occasionally calcareous. 5945 Claystone = medium light gray; soft to occasionally slightly firm; moderately hydrophilic except calcareous; occasionally subplaty with some planar structure grading shale; smooth to fine silty texture; some grading siltstone to occasional very fine sandstone; non to very slight to occasionally moderately calcareous; trace to slight finely disseminated carbonaceous matter; trace mica; very dull yellow orange fluorescence from mud additives. EPOCH 17 "' V-lO0 6015 Siltstone = medium light gray to medium gray; soft and hydrophilic to occasionally slightly firm and calcareous; argillaceous and thinly bedded with claystone; very fine sandy in part; very slight carbonaceous matter and trace micas; dull orange yellow fluorescence from mud contamination. 6060 Claystone = medium light gray to medium gray; soft to slightly firm; hydrophilic to slightly hydrophilic; subblocky to subplaty with occasional planar fracture grading to shale; smooth to silty/slight gritty texture; slight to occasional moderate calcareous including disseminated calcareous matter; occasional firm pieces very calcareous; very slight to locally slight carbonaceous matter; some thinly interbedded argillaceous siltstone to very fine sandstone. 6130 Claystone = medium light gray to medium gray; soft to slightly firm; hydrophilic to slightly hydrophilic; subblocky to subplaty with occasional planar fracture grading to shale; smooth to silty/gritty texture; slight to some moderate calcareous debris mostly disseminated; occasional firm pieces very calcareous; very slight to locally slight carbonaceous matter; some thinly interbedded argillaceous siltstone; some very fine ~to fine sand including subrounded to subangular grains of mostly quartz and some gray to black hard lithics; slight yellow mineral fluorescence; dull yellow orange fluorescence on grains with trace visible stain probably from mud additives. 6225 Carbonaceous shale = grayish red to dusky brown; moderately firm; crumbly to subbrittle; planar to blocky fracture; platy to flaky cuttings habit; earthy luster; smooth texture; subfissile. 6260 Sandstone = generally medium gray to brownish gray, often mottled with gray, brown, olive, blackish hues; friable to easy friable, occasionally firm friable; lower fine to lower very fine grading to silt; well to moderately sorted; subangular to subrounded; high to moderate spheroidal sphericity; weakly to moderately calcareous cemented; abundant argillaceous matrix, tuffaceous in part; predominantly matrix supported; poor visual estimated porosity; locally abundant carbonaceous flakes in sandstone cuttings; moderately abundant grains secondary calcite in overall sample; no discernible hydrocarbon fluorescence over constant mud additive fluorescence background and mineral fluorescence. 6360 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to nodular cuttings habit; silty to gritty texture; dull luster; grading to claystone and to sandy siltstone, possibly very fine grained [::1 EPOCH 18 bp .:$~%=; v-loo sandstone; locally abundant carbonaceous flakes; moderately to highly calcareous; fluoresces dull to bright yellow with cut consistent to mud additive cut. 6425 Claystone = light gray to medium light gray; soft very soft, occasionally slightly firm; moderate to Iow cohesion; moderate to high adhesion; Iow soluble; predominantly amorphous, irregular fracture for firmer cuffings; dull to earthy luster; smooth to silty texture as grades to siltstone and from annular mixing; moderately calcareous. 6475 Sandstone = generally medium gray to brownish gray, often mottled with gray, brown, olive, blackish hues; friable to easy friable, occasionally firm friable; lower fine to lower very fine grading to silt; well to moderately sorted; subangular to subrounded; high to moderate spheroidal sphericity; weakly to moderately calcareous cemented; abundant argillaceous matrix, tuffaceous in part; predominantly matrix supported; poor visual estimated porosity; locally abundant carbonaceous flakes in sandstone cu~ings; moderately abundant grains secondary calcite in overall sample; no discernible hydrocarbon fluorescence over constant mud additive fluorescence background and mineral fluorescence. 6575 Shale = medium gray to medium light gray moderately firm to slightly hard; subbrittle to brittle, occasionally crumbly blocky to irregular fracture; platy to tabular cuffings habit; dull luster; smooth texture; micromicaceous; thin interbedded with claystone and siltstone subfissile; slightly to moderately calcareous. 6625 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to nodular cuffings habit; silty to gritty texture; dull luster; grading to claystone and to sandy siltstone, possibly very fine grained sandstone; locally abundant carbonaceous flakes; moderately to highly calcareous; fluoresces dull to bright yellow with cut consistent to mud additive cut. 6690 Sandstone = brownish gray to medium gray; firm friable to friable; lower fine to lower very fine grading to silt; well to moderately sorted; subangular to angular, occasionally subrounded; moderate spheroidal sphericity; moderately to highly calcareous cemented; moderately argillaceous; grain/matrix supported; poor to fair visual estimated porosity; trace carbonaceous material; predominantly quartz and light gray metalithic fragments, some chert; 10-15% canary yellow sample fluorescence; slow to moderate multistreaming pale bluish white cut; possible visible oil staining within sandstone cuffings. EPOCH 19 6770 Siltstone = medium light gray to light brownish gray; slightly firm to soft; crumbly; irregular to subblocky fracture; wedgelike to nodular cuttings habit; silty to gritty texture; dull luster; grading to claystone and to sandy siltstone, possibly very fine grained sandstone; locally abundant carbonaceous flakes; moderately to highly calcareous; fluoresces dull to bright yellow with cut consistent to mud additive cut. 6840 Sandstone = brownish gray to medium gray; firm friable to friable; lower fine to lower very fine grading to silt; well to moderately sorted; subangular to angular, occasionally subrounded; moderate spheroidal sphericity; moderately to highly calcareous cemented; moderately argillaceous; grain/matrix supported; poor to fair visual estimated porosity; trace carbonaceous material; predominantly quartz and light gray metalithic fragments, some chert; 15-20% canary yellow sample fluorescence; slow to moderate multistreaming pale bluish white cut; possible visible oil staining within sandstone cuttings. 6935 Shale = medium gray to medium light gray moderately firm to slightly hard; subbrittle to brittle, occasionally crumbly blocky to irregular fracture; platy to tabular cuttings habit; dull luster; smooth texture; micromicaceous; thin interbedded with claystone and siltstone subfissile; slightly to moderately calcareous. 6975 Claystone = medium gray to medium dark gray to brownish gray; slightly firm to moderately soft; subblocky to fissile with fissility increasing with micro thin carbonaceous partings; grading carbonaceous shale; smooth to earthy to occasionally silty texture; slightly to very slightly calcareous; occasionally thinly interlaminated with white to very light gray nonorganic tuffaceous claystone; some debris and thin partings white calcite; some calcite silty. 7040 Tuffaceous Claystone = very light gray to cream; moderately soft; greasy when wet to chalky dry; slightly hydrophilic; malleable to flaky and crumbly; non calcareous; nonorganic; some transparent to white cubic to elongate translucent crystals after soaked in HCI and dried under lamp; thin laminations in overall organic medium gray to brownish gray claystone and shale. 7095 Calcite = white; soft and amorphous with locally some silt to fine grained sized transparent crystals; effervesces rapidly in HCI; scattered debris in sample and occasionally as thin partings or laminations. EPOCH 20 7130 Carbonaceous shale/claystone = medium dark gray to dark gray; slightly firm to moderately soft; very slightly hydrophilic; subplaty to fissile; smooth to occasional slightly silty texture; rare thinly bedded argillaceous siltstone and sandstone; common blackish patches on bedding plane partings from carbonaceous matter; predominantly non calcareous; occasionally slightly calcareous and some scattered calcite debris and thin calcite partings; some thinly bedded to interlaminated medium to light gray claystone and tuffaceous claystone. 7205 Carbonaceous shale = dark gray to dark brownish gray to medium dark gray; subplaty to fissile; smooth and earthy to some slightly silty texture; abundant micro thin carbonaceous partings; overall moderately to some slightly organic grading claystone; some thinly interbedded cream to light gray tuffaceous claystone; slightly calcareous overall with occasional calcite. 7260 Tuffaceous Claystone = cream to light gray; soft to slightly firm; moderately soluble to very slightly hydrophilic; chalky to waxy texture; occasionally calcareous in part; interbedded with carbonaceous shale. 7315 Carbonaceous Shale = dark gray to dark brownish gray to medium dark gray; subplaty to fissile; mostly moderately soft to slightly firm; some firm to hard and siliceous rare grading to chert; abundant blackish carbonaceous patches on fissile partings and bedding planes; moderately organic overall; some slightly calcareous; rare calcite; often interbedded to interlaminated and grading to cream to light gray tuffaceous claystone. 7375 Carbonaceous Shale = dark gray to dark brownish gray to medium dark gray; subplaty to fissile; mostly moderately soft to slightly firm; some firm to hard and siliceous; abundant blackish to dark brown carbonaceous patches and flakes on fissile partings and bedding planes; moderately organic overall; some slightly calcareous; rare calcite; some interbedded to interlaminated to occasionally grading cream to light gray tuffaceous claystone. 7435 Tuffaceous Claystone = light gray to yellowish gray; slightly firm to very firm; dense to crumbly; irregular fracture; wedgelike to nodular cuttings habit; waxy to dull luster; smooth texture; thin interbedded with shale and occasional ashy tuff. 7480 Shale = medium gray to medium light gray; moderately firm to very firm; brittle to subbrittle, occasionally crumbly; blocky to planar fracture; tabular to elongated cuttings EPOCH 21 habit; dull luster; smooth to clayey texture; gradational from carbonaceous shale; non calcareous. 7525 Carbonaceous Shale = brownish gray to medium dark gray; moderately firm, occasionally very firm; crumbly to subbrittle; irregular to blocky fracture, occasionally platy; wedgelike to tabular cuttings habit; earthy to dull luster; smooth to matte texture; fissile to subfissile; abundant carbonaceous laminae locally; grades to thin non- carbonaceous shale in part; occasional secondary calcite crystallization along parting planes all sample cuttings moderately calcareous. 76OO Tuffaceous Claystone = light gray to yellowish gray to light bluish gray; slightly firm to very firm; dense to crumbly; irregular fracture; wedgelike to nodular cuttings habit; waxy to dull luster; smooth texture; thin interbedded with shale and occasional ashy tuff. 7640 Shale = medium light gray to light gray, occasionally medium gray to brownish gray; moderately firm to very firm; sub brittle to crumbly; blocky to planar fracture; tabular to elongated cuttings habit; dull luster; smooth texture; micromicaceous in part; gradational from carbonaceous shale; slightly to moderately calcareous. 7725 Carbonaceous Shale = dark gray to brownish gray; moderately soft to slightly firm; mostly slightly organic claystone with moderate to abundant carbonaceous partings; carbonaceous matter brownish to blackish and pliable and immature as apparently poorly altered plant matter; brassy specks of micropyrite scattered on carbonaceous matter; clays are soluble and mostly non calcareous; occasional thin silty to sandy beds commonly calcareous including trace calcite crystals; trace calcite laminae; occasional tuffaceous claystone and ash. 7805 Carbonaceous Shale = medium gray to brownish gray; very firm to moderately firm, occasionally hard; brittle to subbrittle; blocky to planar fracture; wedgelike to elongated cuttings habit; dull to earthy luster; smooth to matte texture; thick bedded with thin tuffaceous interbeds, locally grades to Iow carbonaceous content and becomes more indurated; fissile to subfissile; non to slightly calcareous. 7865 Carbonaceous Shale = medium light gray to medium gray to brownish gray; moderately firm to slightly hard, occasionally soft; subbrittle to crumbly; irregular to blocky fracture; wedgelike to elongated cuttings habit; dull to earthy luster; smooth to matte texture; thick bedded with thin tuffaceous interbeds, locally grades to Iow carbonaceous content and becomes more indurated; subfissile to fissile; moderate trace pyrite overgrowths, abundant loose pyrite aggregate in sample; slightly calcareous. [::1 EPOCH 22 ~ V-lOO 7960 Sand = medium gray overall; fine to medium grained; subrounded to subangular; estimate moderately well sorted; predominantly quartz and carbonaceous debris; estimate some good porosity and permeability; abundant orange fluorescence on sand grains. EPOCH 23 RIG ACTIVITIES BP Exploration (Alaska), Inc. V-lO0 North Slope Borough, Alaska 4128101 Rigged up Epoch mudlogging Unit 12. 4/29101 Finished rigging up logging unit while rig personnel picked up and laid back 1960' of 4" drill pipe. Finished picking up drill pipe and picked up 647' of 5" HWDP. Picked up BHA and new bit, held spud meeting, and drilled ahead from 110', bottom of conductor pipe, to 588'. 4130101 Drilled ahead from 588' to 884', circulated out and pulled out of hole, bit okay. Ran in hole to 884', and drilled ahead, no trip gas. Drilled ahead from 884' to 1998', circulated out, and pulled out of hole to 782'. Tripped in hole, washed to bottom on final stand, and began drilling. Trip gas 854 units lagged to begin drilling and probably methane hydrate. Drilled ahead from 1998' to 2349'. 5101101 Drilled from 2349' to 2761', circulated bottoms up, and short tripped to 1650'. Tripped to bottom and circulated bottoms up. Circulated and conditioned hole, and pulled out and laid down BHA. Cut and slipped drill line, rigged up for 9 5/8" casing, and ran in hole with casing. 5102101 Finished running casing, circulated and conditioned mud, cemented casing, rigged down cement equipment, and began to nipple up BOPs. 5103101 Finished nippling up BOPs and tested choke. Moved HWDP and drill string in pipe rack, and tested BOPs and manifold. Picked up new BHA, and picked up and ran in hole with 4" drill pipe until tagged cement at 2632'. Tested casing to 3500 psi, and began drilling cement. 5104101 Picked up drill pipe while drilling cement, float, shoe, and rathole down to 2761' Drilled new formation from 2761' to 2781', circulated out, and displaced mud. Rigged up and ran leak off test, 16.4 EMW. Drilled ahead from 2781' to 2818' and circulated out for high gas, 1764 units and a 9.1 to 8.4 mud cut. Continued circulating while weighting up EPOCH 24 v4oo to 9.4 ppg. Drilled ahead from 2818' to 3950', circulated bottoms up and pumped sweep, and tripped out to the shoe. 5/05101 Tripped to bottom at 3950', washing down on last stand, with 1520 units of trip gas. Drilled ahead from 3950' to 5904', and tripped out of hole to 3886'. Began tripping in hole. 5106101 Tripped in hole to bottom at 5904', washing down on last stand, with 550 units of trip gas. Drilled ahead, rotating and sliding, from 5904' to 7283', raising mud weight from 9.7 to 10.3 ppg. 5107101 Finished tripping to bottom at 5904' and circulated bottoms up. Drilled ahead, rotating and sliding, from 5904' to 7283', raising mud weight from 9.7 to 10.3. 5108101 Drill from 7283' to 7679', circulate bottoms up and pump sweep. Pull out of hole, lay down BH^, and download MWD. Make up BH^ #3, run in hole to 2700', test MWD, and cut and slip drill line. Run in hole to 5497', fill pipe. 5109101 Trip to bottom, washing down with last stand, 1090 units of trip gas. Drill ahead from 7679' to 7930', and circulate bottoms up while pump sweep around. Displace hole with coring fluid while cleaning shakers. Pump dry job and trip out of hole. Lay down BH^ and pick up coring assembly. Trip in hole. 5110101 Finish trip in hole, and circulate and clean hole. Core from 7930' to 7995', break off core and circulate. Pull out of hole with core barrel. Epoch mudloggers released. [:1 EPOCH 25 OV-100 MUD RECORD BP Exploration (Alaska), Inc. Prudhoe Bay Field ~ ~ ~ . , DATE DEPTH WEIGHT VIS PV YP GELS FILTRATE CAKE SOLIDS SAND pH Pm PflMf Cl Ca 4/29/01 603 9.1 285 21 56 60/66 11.5 3/0 6.0 2.00 10.1 0.00 .20/.50 (~00 20 4/30/01 2361 9.6 121 18 38 45/67 11.4 3/0 10.0 2.50 10.0 0.00 .15/.40 550 20 5/1/01 2761 9.6 55 19 20 4/15 7.4 2/0 10.0 2.75 9.1 0.00 .10/.40 500 20 5/2/01 2761 9.1 55 10 14 10/14 11.0 2/0 6.0 2.00 6.2 0.00 .00/2.50 600 800 5/3/01 2761 9.0 66 12 26 11/13 5.5 2/0 4.4 2.00 9.2 0.00 .00/.65 22000 80 5/4/01 3950 9.6 50 7 23 10/12 5.5 2/2 10.0 0.10 9.2 0.00 .01/.45 22000 400 5/5/01 5955 9.7 56 t0 26 11/13 5.0 2/2 10.8 0.20 8.9 0.00 .20/1.25 22000 100 5/6/01 7305 10.3 52 11 29 21/32 6.0 2/2 15.0 0.15 9.1 0.00 .25/1.80 26000 80 5/7/01 7680 10.3 46 11 27 16/30 7.0 2/2 15.0 0.25 8.9 0.00 .05/1.50 22000 60 5/8/01 7931 10.3 83 24 17 3/7 3.0 2/2 7.8 NA 7.5 0.00 0/.3 23000 200 BPO?H 26 SURVEY RECORD BP Exploration (Alaska), Inc. V-lO0 Prudhoe Bay Field - Borealis Pool EPOCH SURVEY SUMMARY Data from Spe: 'ry Sun MEASURED ' HOLE COURSE VERTICAL COORDINATES DOGLEG DEPTH ANGLE AZIMUTH LENGTH TVD SECTION LATITUDE DEPARTURE SEVERITY 1 0.00 0.0¢ 0.0(; 0.00 0.00 0.00 0.00S 0.00E TIE-IN 2 142.73 0.0c~ 196.72 142.73 142.73 -0.05 0.10S 0.03W 0.06 :3 196.57 0.331 216.51 53.84 196.57 -0.18 0.27S 0.14W 0.47 4 300.56 0.79 156.0(; 103.99 300.55 -0.24 1.16S 0.02W 0.66 5 389.58 0.70 176.78' 89.02 389.57 -0.18 2.27S 0.26E 0.32 6 486.49 0.82 175.45' 96.91 486.47 -0.33 3.55S 0.34E 0.12 7 581.11 0.80 168.42 94.62 581.08 -0.40 4.87S 0.53E 0.11 It 674.71 0.67 184.31 93.6(~ 674.67 -0.53 6.06S 0.62E 0.26 g 767.61 0.53 170.06 92.90 767.57 -0.68 7.01S 0.65E 0.22 1(I 860.46 0.44 158.24 92.85 860.41 -0.62 7.76S 0.86E 0.14 11 946.77 0.49 155.27 86.31 946.72 -0.47 8.40S 1.13E 0.07 12 1042.44 0.37 183.63 95.67 1042.39 -0.45 9.09S 1.29E 0.25 13 1135.99 0.14 138.45 93.55 1135.94 -0.47 9.48S 1.34E 0.31 14 1229.81 0.19 138.42 93.82 1229.7(~ -0.33 9.68S 1.52E 0.06 15 1322.72 0.31 158.86 92.91 1322.67 -0.20 10.04S 1.72E 0.16 16: 1413.70 0.64 209.05 90.98 1413.64 -0.48 10.71S 1.56E 0.55 17! 1506.82 0.57 206.51 93.12 1506.7~ -1.10 11.58S 1.10E 0.09 18: 1600.02 0.91 203.90 93.2C 1599.95 -1.80 12.68S 0.59E 0.37 19 1692.40 0.84 221.95 92.38 1692.32 -2.76 13.85S 0.16W 0.31 20 1786.15 0.88 221.43 93.7~ 1786.0(~ -3.88 14.90S 1.09W 0.05 21 1881.11 0.78 233.41 94.9(~ 1881.01 -5.04 15.83S 2.09W 0.21 22 1973.81 0.89 230.57 92.7C 1973.7C -6.23 16.67S 3.15V~ 0.13 23 2063.83 1.26 240.04 90.02i 2063.7(2 -7.78 17.60S 4.55W 0.46 24 2160.72 1.14 257.33 96.8,c 2160.57 -9.75 18.358 6.41W 0.39 25 2255.28 1.22 256.87 94.56 2255.11 -11.69 18.78S 8.30W 0.09 26 2348.23 1.27 252.59 92.95: 2348.04 -13.70 19.31S 10.25W 0.11 27 2428.84 1.29 260.85 80.61 2428.63 -15.50 19.73S 12.00W 0.23 28 2534.72 1.31 261.21 105.88 2534.48 -17.90 20.10S 14.38W 0.02 29 2629.53 1.29 263.99 94.81 2629.27 -20.05 20.385 16.51W 0.07 30 2722.38 1.15 266.04 92.85 2722.10 -22.02 20.55S 18.48W 0.17 31 2843.15 1.99 225.69 120.77 2842.82 -24.96 22.10S 21.18W 1.11 32 2935.17 2.51 92.17 92.02 2934.81 -24.33 23.29S 20.31W 4.50 33 3028.50 7.47 78.57 93.33 3027.76 -16.26 22.16S 12.31W 5.43 34 3122.22 12.1; 73.09 93.72 3120.09 -0.37 18.09S 3.09E 5.06 35 3216.10 16.80 71.47 93.88 3210.97 22.90 10.90S 25.41E 5.00 36 3310.82 21.97 73.42 94.72 3300.29 54.12 1.49S 55.39E 5.50 37 3404.06 26.93 77.53 93.24 3385.15 92.61 8.05N 92.75E 5.61 38 3497.20 32.85 77.31 93.14 3465.87 138.97 18.17N 138.02E 6.36 39 3590.66 37.12 75.89 93.46 3542.42 192.49 30.61N 190.13E 4.66 EPOCH 27 v4oo BP Exploration (Alaska), Inc. V-lO0 Prudhoe Bay Field - Borealis Pool EPOCH SURVEY SUMMARY Data from S Sun MEASURED HOLE COURSE VERTICAL COORDINATES DOGLEG DEPTH ANGLE AZIMUTH LENGTH TVD SECTION N (+) orS (-) E (+) orW (-)SEVERITY 4(I3684.23 41.49 79.42 93.57 3614.82 251.71 53.78N 313.38E 6.83 41 3778.64 47.67 82.03 94.41 3682.04 317.90 63.60N 382.25E 4.88 42 3869.63 52.10 81.76 90.99 3740.65 387.39 74.71N' 456.59E 0.52 43 3965.05 51.84 81.23 95.42 3799.44 462.49 85.61N 528.45E 0.35 44 4057,64 51.61 81.52 92.59 3856.79 535.12 96.55N 599.09E 1.26 45 4149.50 50.56 80.88 91.86 3914.49 606.55 106.81N 663.25E 1.47 46 4234.40 49.31 80.95 84.9(; 3969.13 671.5(; 119.06N 739.62E 0.31 47 4336.17 49.62 80.81 101.77 4035.27 748.81 130.96N 809.97E 0.67 48 4429.77 49.72 80.00 93.6(; 4095.85 820.14 143.44N 880.12E 0.16 4!~4523.30 49.64 79.84 93.53 4156.37 891.44 157.11N 952.91E 4.14 5C 4617.81 53.48 78.89 94.51 4215.1; 965.45 171.86N 1025.69E 0.63 51,4710.31 53.32 78.20 92.50 4270.27 1039.7(; 182.53N 1075.08E 0.99 52:4773.29 53.38 77.43 62.98 4307.87 1090.22 204.06N 1173.21E 0.52 53 4898.93 52.81 77.82 125.64 4383.32 1190.64 219.12N 1245.40E 0.71 54 4991.62 52.63 78.62 92.69 4439.47 1264.38 232.49N 1311.81E 0.52 55 5077.12 52.18 78.61 85.50 4491.63 1332.12 248.23N 1389.29E 0.51 56 5177.54 51.69 78.42 100.42 4553.54 1411.181 261.34N 1451.34E 0.67 57 5258.39 51.64 77.74 80.85 4603.69 1474.59 278.16N 1527.25E 0.38 58 5357.5(; 51.71 77.27 99.11 4665.15 1552.31 293.80N 1597.99E 0.45 59 5449.86 51.62 77.79 92.36 4722.44 1624.73 310.44N 1673.12E 0.48 60 5548.13 51.46 77.23 98.27 4783.56 1701.65 325.45N 1738.81E 0.52 61 5634.53 51.04 77.03 86.40 4837.64 1768.99 342.36N 1812.33E 0.48 62 5731.87 50.58 77.07 97.34 4899.15 1844.38 358.37N 1880.39E 0.56 63 5822.4c~ 50.4(; 76,45 90.62 4956.8(; 1914.23 375.54N 1951.46E 0.30 64 5917.5c~ 50.11 76.39 95.10 5017.61 1987.27 392.52N 2020.73E 0.34 65 6010.68 49.9(; 76.07 93.09 5077.44 2058.50 410.00N 2089.62E 0.56 66 6103.73 49.7(; 75.44 93.05 5137.4c~ 2129.45 427.66N 2158.15E 0.25 67 6196.63 49.54 75.6( 92.90 5197.68 2200.07 443.17N 2227.26E 2.77 68 6289.97 49.22 79.04 93.34 5258.46 2270.87 457.19N 2296.13E 0.92 69 6382.95 49.0(; 77.95 92.98 5319.33 2341.15 471.92N 2364.72E 2.07 70 6477.31 47.05 77.81 94.36 5382.43! 2411.28 485.51N 2431.04E 3.17 71 6572.05 44.19; 79.07 94.74 5448.69' 2478.98 496.09N 2494.32E 4.04 72 6666.95 40.921 82.04 94.90 5518.591 2543.12 504.58N 2552.05E 3.69 73 6759.22 37.56 81.1§ 92.27 5590.05 2601.42 513.39N 2606.73E 3.86 74 6854.04 33.92 80.47 94.82 5667.00 2656.77 521.02N 2656.07E 3.78 75 6947.75 30.48 82.02 93.71 5746.28 2706.66 527.79N 2701.66E 1.29 76 7040.13 29.39 81.06 92.38 5826.34 2752.72 534.50N 2744.49E 3.8C 77 7133.66 25.84 81.13 93.53 5909.20 2834.16 542.14N 2781.84E 4.12 78 7226.29 22.83 75.43 92.63 5993.60 2868.41 550.58N 2815.09E 2.22 [:1 EI OCH 28 ~?~% V-lO0 BP Exploration (Alaska), Inc. V-lO0 Prudhoe Bay Field - Borealis Pool EPOCH SURVEY SUMMARY Data from S Sun MEASURED HOLE COURSE VERTICAL COORDINATES, DOGLEG DEPTH ANGLE AZIMUTH LENGTH TVD SECTION N (+) or S (-) E (+) or W (-)!SEVERITY 79 7318.77 20.73 76.12 92.48 679.4a 2868.41 550.58N 2815.09E 2.29 8l~ 7413.03 17.12 85.24 94.26 6168.65 2898.8~ 555.73N 2845.13E 4.93 81 7505.87 13.27 87.44 92.84 6258.22 2923.02 557.34N 2869.40E 4.20 82 7599.39 12.51 87.41 93.52 6349.39 2943.66 558.28N 2890.24E 0.81 83 7697.66' 11.81 89.29 98.27 6445.45 2964.09' 558.88N 2910.93E 0.82 84 7793.07 11.70 90.27 95.41 6538.86 2983.20 558.96N 2930.36E 0.23 85! 7884.35 11.28 91.87 91.28 6628,31 3000.99 558.62N 2948.54E 0.58 [:1 EPOCH 29 ~ v-~oo BIT RECORD EPOCH JETS TOTAL AVG BIT SERIAL SIZE (in 32nds) DEPTH DEPTH FEET BIT AVG AVG AVG PUMP NUMBER NUMBER INCHES MAKE TYPE 1 2 3 4 IN POOH DRILLED HOURS FTIHR WOB RPM PSI MXCl 13118118118 110 2761 2651 27 98.18 14.9 137 1353 1 Y26ZY 12.25 HTC 2 200376 8.75 HYCA DS79FNPV 6x16 2761 7930 5169 60 86.15 5.3 56 2708 3 4508509 8.5 lC ARC412C3 TFA 0.77 7930 SIH i £:1 EPOOH 30