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Home My WebLink About204-029MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-211 PRUDHOE BAY UN ORIN L-211 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/10/2025 L-211 50-029-23197-00-00 204-029-0 G SPT 3764 2040290 1500 1925 1928 1922 1919 624 633 636 635 4YRTST P Austin McLeod 11/2/2024 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 ORIN L-211 Inspection Date: Tubing OA Packer Depth 3 2654 2575 2559IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241102191014 BBL Pumped:3.1 BBL Returned:2.8 Friday, January 10, 2025 Page 1 of 1 9 9 9 9 9 99 99 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 14:34:56 -09'00' MEMORANDUM TO: Jim Regg�� P.I. Supervisor / FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-211 PRUDHOE BAY UN ORIN L-211 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN ORIN L-211 API Well Number 50-029-23197-00-00 Insp Num: mitBDB201102155043 Permit Number: 204-029-0 Rel Insp Num: Inspector Name: Brian Bixby Inspection Date: 11/2/2020 - _ -- Packer Depth Pretest Initial - 15 Min 30 Min 45 Min 60 Min Well L-211 in657 -_ Type IIIJ WTVD 3764 TT u-b731 704 693 ---T - - - PTD 1 2040290 ' Type Test, SPT Test psi 1500 IA 612 1732 -- - 1681 1682 - BBL Pumped: 1 BBL Returned: 1 OA 117 120 119 119 Interval 4YRTST PX P Notes: I G` S -- 640- Oc4ve, 2ew) • u 9d - d lsCen � rti t tiJ�; 1 a Tuesday, November 3, 2020 Page I of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, October 26, 2020 9:33 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska NS - PB - Field Well Integrity; Aras Worthington; Oliver Sternicki; Stan Golis Subject: OPERABLE: Injector L-211 (PTD #2040290) ready for injection, needs AOGCC MIT -IA Mr. Wallace, WAG Injector L-211 (PTD #2040290) re -connect is complete and the well is ready for injection. The well is now classified as OPERABLE. An AOGCC MIT -IA will be scheduled when it's online and thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M:(307)399-3816 From. laska NS - PB - Field Well Integrity Sent: Satu-ftlayOctober 17, 2020 9:13 AM To: 'chris.wallace ska.gov' (chris.wallace@alaska.gov) <chris.wallace@alaska.gov> Cc:'Regg, James B (DOA) regg@alaska.gov)' (jim.regg@alaska.gov) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver SteitnWi <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: NOT OPERABLE: Injector L-211 (PTD 290) Lapse AOGCC MIT -IA Mr. Wallace, Injector L-211 (PTD # 2040290) is due for 4 year required AOGCC MIT -IA hi currently disconnected and will not be on injection by the end of the month. - OPERABLE for tracking purposes. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P:(907)659-5102 M:(907)232-1005 month of October. The well line is w,well is now classified as NOT From: AK, GWO SUPT Well Integrity Sent: Monday, October 10, 2016 7:17 PM To: AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpadLead 9bp.com>; AK, OPS Prod Controllers Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Saturday, October 17, 2020 9:13 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Oliver Sternicki; Aras Worthington Subject: NOT OPERABLE: Injector L-211 (PTD #2040290) Lapse AOGCC MIT -IA Mr. Wallace, Injector L-211 (PTD # 2040290) is due for 4 year required AOGCC MIT -IA in the month of October. The well line is currently disconnected and will not be on injection by the end of the month. The well is now classified as NOT OPERABLE for tracking purposes. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/Compliance Rya n. HoltCa@ Hi Icoro.com P:(907)659-5102 M:(907)232-1005 From: AK, GWO SUPT Well Integrity t: Monday, October 10, 2016 7:17 PM To: A OPS GC2 0SM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 ell pad Lead <AKOPSGC2WeIlpadLead@bp.com>; AK, OPS Prod Controllers <AKOPSPro ontrollers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West IIs Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWe ptEngr@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; Zoesch, Eric <zoese0@BP.com>; Rupert, C. Ryan <Ryan.Rupe BP.com>;'chris.wallace@alaska.gov' (chris.wallace@alaska.gov) <chris.wa (lace@a laska.gov> Cc: AK, GWO DHD Well Integrity <AK%CDHDW(ellintegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEngineer AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.comSUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCom ep@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgom Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGE TCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, ArasJ <Aras.Worthington@bp.com>;'Regg, James B (D (jim.regg@alaska.gov)' (jim.regg@alaska.gov) <jim. regg@alaska.gov> Subject: OPERABLE: Injector L-211 (PTD #2040290) Ready to be Brought Orlin or AOGCC MIT 0, Injector L-211 (PTD #2040290) was made Not Operable due to not being placed on injection b re its 4 -year AOGCC- witnessed MIT -IA was due. The well has no known integrity issues. The well is now ready to be placed on injection. A witnessed MIT -IA will be scheduled once injection has bilized. The well is reclassified as Operable. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,November 04,2016 P.I.Supervisor (Vc1 III i Di(L:. SUBJECT: Mechanical Integrity Tests 1 BP EXPLORATION(ALASKA)INC. L-211 FROM: Johnnie Hill PRUDHOE BAY UN ORIN L-211 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-211 API Well Number 50-029-23197-00-00 Inspector Name: Johnnie Hill Permit Number: 204-029-0 Inspection Date: 10/18/2016 Insp Num: mitJWH161018161027 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill L-211 - Type Inj W'TVD 3764 - Tubing 420 420 421 - 422 . 2040290 SPTit 1500 340 T 1797 - 1745 - 1745 PTD Type Test Test pst; � IA Interval 4YRTST P/F P__ •-" OA i 265 272- 272 - 272 Notes: 1.19 bbls diesel used - SCANNEDAPP 2 12U1Z Friday,November 04,2016 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Saturday, June 11, 2016 6:38 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 Superintendent; AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS WELL PAD W; Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey, Adrienne; Regg, James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE:Injector L-211 (PTD #2040290)Will Remain Shut In Past AOGCC MIT Test Date All, Injector L-211 (PTD#2040290) is due for an AOGCC-witnessed test by the end of June 2016.There are no plans to bring the well online until 2017.The well is reclassified as Not Operable, and should remain shut in. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0: (907)659-5102 C:(907)943-0296 H:2376 SCANNED JUN 1 7 2016 Email: AKDCWeIlIntegrityCoordinator@BP.com 1 ~ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~~°~~a.~~ :~ ~~`~'~ ~~ ~' ~~~~ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T~ 5 2009 ~IasVca t~il ~ Gas Cons. Carr~nis~ion Anchorage aa ~ - ~~9 ~.~~.11 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- 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 Expioretion (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~04) Date L pad B/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al L-Ot 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 500292310t0000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24,65 5/6/2009 L-106 2012230 50029230550000 NA 2J5 NA 28.05 5/6/2009 1-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-177 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L•121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 1-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA Y7 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-2f2 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 ~~ "~~ --~ =~"' ,..~~.-: r MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFiche\C~rPgs_Inserts~Microfilm_Marker.doc SI:IIIInIleP.... RECE.\\IEO ADG 1 0 'l.üüô co"e. comm\ssiOI\ 01\ & GaS 'I...· ~ Anc\'\oraQe Borealis Orion SC~NNEr} NO. 3916 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Camm Attn: Christine Mahnken 333 West 7th Ave, Sui1e 100 Anchorage, AK 99501 Field: Well Log Description BL Color CD Job # Date L-122 40009065 OH EDIT OF MWD/LWD 05/26/03 6 1 L-211 40010216 OH EDIT OF MWDILWD 03/08/04 2 1 L-211 PB1 40010216 OH EDIT OF MWD/LWD 03103/04 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambe" St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: UT ê- ~9ò4 -ð;:f) 1? ILIO l:5- n 08/09/06 . . i~ fJ.,('({,t~~(o DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040290 Well Name/No. PRUDHOE BAY UN ORIN L-211 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23197-00-00 MD 9130 TVD 4494 Completion Date 3/16/2004 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional surveY~ DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, USIT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr " .-~ Data Digital Dataset Log Log Run Interval OH/ G Med/Frmt Number Name Scale Media No Start Stop CH Received Comments --- ------ ---~-- -- R See Notes 5/29/2005 Black Oil Full PVT Study Report Etr-D Wrd Directional Survey 0 11200 3/30/2004 Also an Excel spreadsheet - PB 1 ~ Directional Survey 0 11200 3/30/2004 PB1 : 0 Wrd Directional Survey 0 9130 3/24/2004 Also an Excel spreadsheet : Rpt Directional Survey 0 9130 3/24/2004 !£ Pds 12624 See Notes 4034 5067 8/27/2004 FLUID CONTACT LOG , og 12624 See Notes Blu 4034 5067 8/27/2004 FLUID CONTACT LOG ~ Pds 12622 See Notes 2 5463 6447 FLUID CONTACT LOG See Notes Blu 2 5463 6447 FLUID CONTACT LOG, DSN 12622 I ¡ED C Pds 12745 Gamma Ray 6160 9000 Case 9/27/2004 LDWG, GR I~ 12745 Gamma Ray Blu 6160 9000 Case 9/27/2004 UL TRASONIC IMAGING .- TOOL, GAMMA RA Y/CCL '--- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2040290 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Well Name/No. PRUDHOE BAY UN ORIN L-211 Operator BP EXPLORATION (ALASKA) INC MD 9130 TVD 4494 ADDITIONAL INFORMATION Well Cored? Y $ Chips Received? ~ Analysis ~ Received? Completion Date 3/16/2004 Completion Status WAGIN Current Status WAGIN API No. 50-029-23197-00-00 UIC Y Comments: - ~ t~~L Daily History Received? ~ ~ Compliance Reviewed By: Formation Tops A-~ fÇ,~_ cW- M :Jr".., 0 t+ î);t; CfU ì /dyt "« r.s · ~ c.,g M.J~{IÑ,r;~~ ~ ?¡,-~)_/ Date: J71l¡t ~ þ ( -') STATE OF ALASKA \ ALASKr\ OIL AND GAS CONSERVATION COl\¡lIilSSION NOV 1 .s 2004 REPORT OF SUNDRY WELL OPERATIIO~~ .. 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development 0 ExploratoryD Stimulate D OtherO WaiverD Time ExtensionO Re~enter Suspended Well 0 5. Permit to Drill Number: 204-0290 6. API Number 50-029-23197-00-00 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 0 PluÇJ PerforationsD Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate [K] 77.00 8. Property Designation: ADL-028239 11. Present Well Condition Summary: Stratigraphic 0 ServiceŒ] 9. Well Name and Number: L-211 10. Field/Pool(s): Prudhoe Bay Field / Orion Oil Pool Total Depth measured 9130 feet measured 9034 feet true vertical 4454.0 feet Plugs (measured) Junk (measured) None true vertical 4494.0 feet Effective Depth 8833 Casing Length Size MD TVD Conductor 80 20" X 34" 215.5# A53 28 108 28.0 108.0 Production 9093 7" 26# L-80 26 - 9119 26.0 - 4489.4 Surface 4374 9-5/8" 40# L-80 29 - 4403 29.0 - 2687.3 Perforation decth: Burst Collapse 7240 5410 5750 3090 Measured depth: 8680 - 8700,8704 - 8724,8738 - 8758,8772 - 8792 True vertical depth: 4317.29 - 4324.93,4326.45 - 4334.07,4339.39 - 4346.96, 4352.24 - 4359.75 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 3-1/2" 9.3# L-80 @ 7215 4-1/2" 12.6# L-80 @ 8558 3-1/2" 9.3# L-80 @ 8565 Packers & SSSV (type & measured depth): 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer 4-1/2" Baker S-3 Hydro Set Packer 7215 8558 8565 8608 @ 7227 @ 8061 @ 8266 @ 8559 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Oil-Bbl Recresentative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure No prior Production or Injection 0 o -871 0 Tubing Pressure 13 Prior to well operation: Subsequent to operation: o 825 ! 15. Well Class atter proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJI!) WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-229 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )j~C~~ Title Production Technical Assistant Signature Phone 564-4657 Date 11/1 0/04 Form 10-404 Revised 4/2004 RBDMS BFL NOV 1 670n4 ( ) ) L-211 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/31/04 Perforate 87381-875816 SPF, 87721-87921 6 SPF 11/05/04 Perforate 86801.87001 6 SPF FLUIDS PUMPED BBlS : TOTAL No Fluids Pumped o Page 1 TREE::;., 4-1/16" CrN WELLHEAD = FMC ACTUA TOR = NA KEI. ELEv = 77.0' BF. ELEV = 48.5' KOP = 200' Max Angle = 68 @ 7868' Datum MD = 9089' Datum TV D = 4400' SS \ ) L-211 I 511FT )OTES: 9-5/8" CSG, 40#, L-80, ID = 8.835" I Minimum ID = 2.813" @ 7285' 3-1/2" HES X NIPPLE 17" MARKER JOINT WI RA TAG I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 17" MARKER JOINT W/ RA TAG l-i 8105' r- 13-1/2" MARKER JOINT WI RA TAG I 8245' PERFORA TION SUMMARY REF LOG: SWS USIT 03/12/04 ANGLE AT TOP PERF: 66 @ 7341' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 7341 - 7351 0 03/13/04 4-1/2" 5 8151 - 8221 0 03/13/04 4-1/2" 5 8291 - 8366 0 03/13/04 4-1/2" 5 8416 - 8451 0 03/13/04 2-1/2" 6 8704 - 8724 0 06/13/04 2-1/2" 6 8680 - 8700 0 11/05/04 2-1/2" 6 8736 - 8756 0 10/30104 2-1/2" 6 8770 - 8790 0 10/30104 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 8617' I PBTD I 17" CSG. 26#. L-80, ID = 6.276" I DA TE REV BY COMMENTS DA TE REV BY 03/22/04 JAF/KAK ORIGINAL COM PLETION 06/10104 JLJ/KAK FISH - SWS GUN ASSEMBLY 06/13/04 MDC/KA A DPERFS 09/11/04 LWBITLP WA TERFLOOD CORRECTIONS 11/05/04 MDClTLP ADD PERFS -i 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES X NIP, ID = 3.813" I ST MD 5 7303 4 8104 3 8227 2 8311 1 8489 4-1/2" X 3-1/2" XO, ID = 2.992" I 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" HES X NIP, ID = 2.813" I 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" I WATERFLOOD MANDRELS TVD DEV TYPE VLV LATCH PORT DATE 3793 67 MMG-W DMY RK 03/16/04 4101 68 MMG-W DMY RK 03/16/04 4148 68 MMG-W DMY RK 03/16/04 4179 68 MMG-W DMY RK 03/16/04 4245 68 MMG-W DMY RK 03/16/04 3-1/2" HES X NIP, ID = 2.813" 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" X 4-1/2" XO, ID = 2.910" I 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" X 3-1/2" XO, ID = 2.910"1 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" WLEG, ID = 2.905" I -i FISH - SWS SXAR GUN ASSEMBLY COMMENTS ORION UNIT WELL: L-211 PERMIT No: 2040290 API No: 50-029-23197-00 SEe 34, T12N, R11 E, 2540' NSL & 3816' WEL BP Exploration (Alaska) ! I" ~ ' )' J' STATE OF ALASKA ') ALASKJ.. .., L AND GAS CONSERVATION COM.. ,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2540' NSL, 3816' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2231' NSL, 1005' WEL, SEC. 28, T12N, R11E, UM Total Depth: 3413' NSL, 2157' WEL, SEC. 28, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583098 y- 5978260 Zone- ASP4 TPI: x- 580565 y- 5983203 Zone- ASP4 Total Depth: x- 579398 y- 5984373 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, US IT CASING, LINER AND CEMENTING RECORD I ..,.; ,I':,." .",..,§e¡JliI, N,,~~il. ,', , P)I. ,I;.Pf,',¡"¡, '.:MP;" ~¡:;n,"" I IN, '~,' .IIPI.I ,~~t.;I~, ,.PI, "I.:, I,H,·,'.· Q,'.... þE.....,., i,i, i:,'.I<,,:II'I':' 'I!' :lSj,il¡'"i)!:iL,." '",,~~:~'~t~, \,il,',!,i',,' ',.,1; I:, .ffll,'.',',', "",M.,...~p~~,;J7.,,:, ':, qRAQE'I' 11"1 ,"'iTop !I"II'; 18(o¡T1:0M"II,'I,ill'liO,PII,·III,:60J:T!QMI "ii,:,$iZE; I'I""¡I,",,, ii:I!I';:,:' ,¡I:' :'11, i':,t:! I' 1·:8uC~ED!1 A53 Surface 108' Surface 108' 48" 260 sx Arctic Set (Approx.) L-80 29' 4403 29' 2687' 12-1/4" 650 sx AS Lite, 384 sx Class 'G' L-80 26' 9119' 26' 4489' 8-3/4" 435 sx Class 'G' 22. :,ÇA$iNGi',il'·· , '",.,' 'I $,I?I;!i",I!I:, ) "~I' 20" x 34" 9-5/8" ;' I , ' 'I:' .', ':.~' ::,';,: ',', \ I '.:. ':, ::,::: " I ,;" 'I 'Vy,r ;'P'ERI'IË'T:;I': 215.5# 40# 26# 7" 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5 spf 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 7341' -7351' 3808' - 3813' 8680' - 8700' 4317' - 4325' 8151'-8221' 4119'-4145' 8704'-8724' 4326'-4334' 8291' - 8366' 4172' - 4200' 8736' - 8756' 4339' - 4346' 8416' - 8451' 4218' - 4231' 8770' - 8790' 4351' - 4359' 26. Date First Production: November 1, 2004 Date of Test Hours Tested One Other 5. Date Comp., Susp., or Aband. 3/16/2004 6. Date Spudded 2/24/2004 7. Date T.D. Reached 3/8/2004 8. KB Elevation (ft): 77' 9. Plug Back Depth (MD+TVD) 9034 + 4454 10. Total Depth (MD+TVD) 9130 + 4494 11. Depth where SSSV set (Nipple) 3892' MD 19. Water depth, if offshore N/A MSL Revised: 11/12/04, Add Peñs, Put on Injection 1 b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 204-029 13. API Number 50- 029-23197-00-00 14. Well Name and Number: PBU L-211 i 15. Field / Pool(s): Prudhoe Bay Field / Orion Ft Ft 16. Property Designation: ADL 028239 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 24. '",., ,I"~ ,1'11,,: ::,'" ""I" i.'· ",,':1 ,< 1',I"li'i'TLJBIN'GIRè:&ORD',:, I lilli,,' , ,.: .', ,,'. 'I '. : ,I" ','I';, ,¡:. SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 7215' 3-1/2", 9.3#, L-80 7215' - 8606' 7227' & 8061' & 8266' & 8559' "26~:'" i.:":,":'I"'I,',"""'i: ,":~êI6;:!IFRÅêTÜiRê!¡CèMeNf,SqÚÈ~;El!"ET6:,,·,i'·",i;"'::. "i:,ii'!:: ..,.... · '··.'.1·, "":," ""::' 11.'",'" ":''1,''''",:,,1,1 1"',o,I"o·T,o " " I ',I" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-Bsl GAs-McF PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ........ Oll-Bsl Press. 24-HoUR RATE""" W A TER-Bsl GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sepa~@te,,&reet, if necessary). Submit core chips; if none, state "none".; "".t :, ' None RBDMS BFL NOV 1 6 2004 n D I c. ¡ f\ I ", I _ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (\ ': NO\f 1 ?J)G4 (~ f- · "I ~ \1¡. ... ( '" 28. GEOLOGIC MARKERS 29. ¡-ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Ugnu 4610' Ugnu MB1 7340' Top Schrader Bluff / NA 7782' Schrader Bluff NB 7834' Schrader Bluff NC 7941' Schrader Bluff OA 8162' Schrader Bluff OBa 8308' Schrader Bluff OBb 8436' Schrader Bluff OBc 8579' Schrader Bluff OBd 8704' Schrader Bluff OBe 8852' Schrader Bluff OBf 8952' Base Schrader Bluff / Top Colville 9054' 2772' None 3808' 3979' 3999' 4040' 4123' 4178' 4226' 4279' 4326' 4382' 4421' 4462' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date ( I - I ~,O PBU L-211 i Well Number 204-029 Permit No. / A roval 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Thomas Schaefer, 564-4685 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: L-211 i Prudhoe Bay Unit 50-029-23197 -00-00 204-029 Accept: Spud: Release: Rig: 02/24/04 02/24/04 03/16/04 Nabors 9ES POST RIG WORK 06/07/04 RIH WITH 2.50" CENT, 2.60" BELL GUIDE & 2" JDC TO PULL THE BALL & ROD. 06/08/04 PULL DCK-2 GLV FROM STA # 6 @ 7089' SLM (7095' MD). SET 1" DGLV WIBK IN STA #6 @ 7089' SLM (7095' MD). PULL RHC @ 8572' SLM. PT TBG TO 2000 PSI. INITIAL PRESSURES TIIIO = 401850/200, PRESSURES AFTER 30 MIN TIIIO = 2000/1000/200. 06/09/04 MADE SEVERAL ATTEMPT WILlB TO BOOSTER KEPT SETTING DOWN IN GLM @ 7277' SLM. RUN LIB TO BOOSTER ASSM. @ 8599' SLM - GOOD IMPRESSION. SET FIRING HEAD @ 8597' SLM - POOH & MONITOR. RUN 3.5" BRUSH & LIB. OUT TT. SET DOWN ON TOP OF FIRING HEAD @ 8823' SLM - LIB SHOWED ROPE SOCKET. GUNS APPEAR TO HAVE FIRED. FISH FIRING HEAD FROM SPENT PERF GUNS @ 8824' SLM. SET 3.5" PXX PLUG @ 8586' SLM. OAL=42". RIH TO PULL PLUG BODY. 06/10/04 PULLED 3 1/2" PX PLUG BODY @ 8580' SLM. (1/4 CUP OF METAL SHAVINGS IN LOCK & FILL EXT.) SET 3 1/2" PX PLUG BODY @ 8041' SLM. (2.75" PORTS, 20" FILL EXT. 42" OAL). ATTEMPT TO PUMP KCL WATER. UNABLE TO ESTABLISH INJECTION. PULL PLUG BODY @ 8041' SLM. TURN WELL OVER TO DSO - LEFT WELL SHUT IN . 06/13/04 RAN PL CCL-GR JEWELRY LOG. PERFORATED 8704' TO 8724' WITH 2.5" 6 SPF 60 DEG PJ PERF GUN. ALSO RAN PL LOG AT LOW AND MEDIUM CCL GAINS TO DETERMINE IF SXAR GUNS HAD FIRED 8691' TO 8781'. NO APPARENT PERFORATIONS OVER INTERVAL, HOWEVER, PERFORATIONS APPEAR TO BE POSSIBLY PRESENT 8761' TO WELL BOTTOM, WHICH WAS TAGGED AT 8846'. WELL LEFT SHUT IN. 06/18/04 LRS PUMPED 250 BBL OF SEA WATER @ 4-5 BPM. SLB DISPLACED WI NITROGEN. SET 3 1/2" PXX TOP LOAD PLUG BODY WI 1" X 1/2" PORTS @ 8037' SLM. ATTEMPTING TO SET PX PRONG AT END OF DAY. 06/19/04 MADE ATTEMPT TO SET PLUG PRONG WOULD NOT PASS 7112'. ATTEMPTS TO RUN CK SET AND PULLING TOOL COULD NOT REACH PLUG SETTING DEPTH. RECOVERED MUD ON TOOLS, SUSPECT MUD COVERING PLUG. 06/22/04 PUMP 125 BBLS SEAWATER, PULL PX PLUG, BRUSH X NIP @ 8035'. 06/23/04 SET 3.5 PX PLUG BODY, PUMP SEAWATER & N2, SET PRONG, & TEST PLUG TO 2450, GOOD TEST, SET XN CATCHER @ 8027 SLM. LUBRICATE 12.5 BBLS S.WATER ON TOP OF PLUG. CONTINUE BLEEDING SURFACE PRESSURE. 06/24/04 MADE SEVERAL ATTEMPTS TO PULL DGLV FROM STA # 5. 06/25/04 ATTEMPT TO PULL STA # 5 FAILED. TOOLS NOT FALLING. PULL CATCHER @ 8024 SLM, PULL PRONG @ 8030' SLM. ATTEMPT TO LATCH PLUG BODY. L-211 i, Summary of Post Drilli. )ork Page 2 ") 06/26/04 BRUSH & FLUSH TUBING TO TT. DISPLACE TBG W/ NITROGEN. SET PLUG. PLUG FAILED TO TEST. 06/27/04 PULLED, RESET AND TESTED PLUG. PULLED DGLV FROM STA # 5. PLACED 9 BBLS SEA WATER ON TOP OF PLUG AND BLED TBG TO 1500 PSI. 06/28/04 CORRELATED TO SWS JEWELRY LOG RAN 6/13/04. WELL DID NOT PRODUCE AS PLANNED. DID NOT ACHIEVE THE 5 TO 10 BBL OIL INFLOW. 1ST SAMPLE = SEAWATER. 06/29/04 CORRELATED TO SWS JEWELRY LOG RAN 6/13/04. WELL DID NOT PRODUCE AS PLANNED. DID NOT ACHIEVE THE 5 TO 10 BBL OIL INFLOW. 1ST SAMPLE = SEAWATER. 2ND SAMPLE TAKEN AT 05:34 AM, 6/29/04,6061' MOVING UP 1 FPM TO STAY AT TOP OF FLUID CONTACT. DID NOT TAG TD. 07/05/04 TOOLS STILL FALLING EXTREMELY SLOW. STOP @ 6150 WHILE DHD SHOT FLUID LVL, (5900') MD. TRY TO WORK BAILER TO RETAIN SAMPLE. (NO JAR ACTION) RETAINED ABOUT 2 CUPS OF SAMPLE. BEGIN IN HOLE WI PDS LOGGING TOOLS. 07/06/04 ATTEMPTED TO RUN PDS MEMORY LOGGING TOOLS. DEVIATION & FLUID VISCOSITY MAKES GOING IN HOLE TO NECESSARY DEPTH IMPRACTICAL. JOB ABORTED. (WILL ACQUIRE DATA WITH CTU AT LATER DATE.) NOTIFIED PAD OPERATOR OF WELL STATUS. 07/11/04 MU BOT MHA, PDS INTERFACE DETECTION LOGGING TOOLS AND SLB PVT SAMPLER. RIH AND LOG DOWN FROM 5500' CTM, ENCOUNTERED FLUID LEVEL AT 6319' CTM. STOPPED AT 6450' CTM TO TAKE FIRST SAMPLE. AFTER SAMPLE WAS TAKEN ATTEMPTS WERE MADE TO RUN FURTHER INTO THE CRUDE HOWEVER HIGH VISCOSITY WOULD NOT ALLOW ADDITIONAL FOOTAGE TO BE MADE. LOGGED UP FROM 6,450' TO 6,000' CTM AND POOH. # 1 SAMPLE RECOVERED. SLB TECHNICAN TO MAKE FIELD ANALYSIS AT SHOP. 07/12/04 COLLECT APPROXIMATELY 350 CC FROM FIRST PVT SAMPLE. FIELD ANALYSIS INDICATES 60% OIL AND 40% WATER.PDS TOOLS INDICATE THE OIL/WATER @ 6094' CORRECTED. (SAMPLE AT 6,450' IS 6,447' ELMD.) RIH WI 3.5" SLlCKLlNE BAILER WITH BALL SEAT FOR ATMOSPHERIC SAMPLE TO 6550'. FIND FLUID INTERFACE AT 5999' CTM. WAIT FOR SAMPLE BAILER TO FILL AND POOH. RECOVER +1- 3 GALS OF OIL/WATER AND FINE SAND. OIL APPEARS TO BE LOW GOR AND GAS IS VERY SLOW TO BREAK OUT MAKING TOTAL VOLUME DIFFICULT TO ESTIMATE. MU BOT MHA WI SINGLE PVT SAMPLER AND 3.5" OD SIL BAILER. 07/13/04 POOH WI RUN # 2, SINGLE PVT SAMPLER AND 3.5" OD SIL BAILER. PARK TOOLS AT 6238' CTM AND WAIT FOR TIMED SAMPLER RELEASE. POOH. SL BAILER IS EMPTY, SLB PVT SAMPLER HAS APPROXIMATELY 500 CC OF FLUID. MU 2" JSN AND RIH FOR CLEANOUT. TAG SAND AT 7184' CTM, CLEANOUT BUT RAN INTO MORE SAND. RETURNS FULL OF FINE SAND. CONTINUE CLEANING OUT WISW AND FLO PRO SWEEPS. CIO TO 8045' CTM WITH 4-10 BBLS FLO PRO SWEEPS CHASE OUT OF HOLE AT 80%. SWAP WELL OVER TO FILTERED SW. 07/14/04 CIO TO 8040' CTM. RIH WIBOT WI 2.65" HYDRO DISCO & 1.75" FN. TAG UP AT 8044' MAKE SEVERAL ATTEMPTS TO STAB INTO PRONG TRY TO JET THE FILL ON THE RETRIEVING HEAD OUT. NO LUCK. FREEZE PROTECT TUBING TO 2500' WITH 50/50 METHANOL. DECISION MADE TO COME BACK FOR PLUG LATER. RDMO. L-211 i, Summary of Post Drilli. )ork Page 3 ) 08/29/04 CIO TO TOP OF PRONG AT 8052' CTM. PUMP 23 BBLS XYLENE TO SOAK MUNG AND 20 BBLS FLO-PRO CHASE OUT AT 80%. RU BOT OVERSHOT WITH BOWEN ACCELERATOR & JARS. RIH AND LATCH PRONG AT 8061' CTM AND POOH. RECOVERED PRONG. MU 3-1/2" G SPEAR AND RIH. JET FN WI 10 BBLS OF FLO PRO AND CIRCULATE OUT W/ FILTERED 1 % KCL. LATCH PLUG AND POOH. RECOVERED PLUG. FREEZE PROTECT TUBING WITH 50/50 METHANOL TO 3500' MD. FINAL INJECTIVITY RATE WAS 4.5 BPM @ 920 PSI. 09/12/04 RAN STATIC STOP @ 8189',8456' AND 8720' MD. PUMPED A TOTAL OF 120 BBLS OF HOT DIESEL, DRIFTED WITH 3 1/2" BLB, 2.75" GAUGE RING. SET X-CATCHER SUB @ 8,538' SLM. PULL 1 1/2 RK DUMMY GL V @ 8481' (SLM). 09/13/04 PULL 1.5 RK DUMMY GLV @ 8216' (SLM) STA. 3. SET 1.5 RK DUMMY GLV @ 7295' (SLM) STA. 5. 09/14/04 SET 1 112" RK FLOW SLEEVE IN STA# 1 @ 8,481' SLM. 09/15/04 SET A RK FLOW SLEEVE IN STA# 3 @ 8,211' SLM. PULLED X-CATCHER SUB @ 8,538' SLM. 09/21/04 RAN 2.50 CENT AND PETRADAT GAUGES. STOPS AT LUB 10 MIN, 8189 MD 15 MIN. 8456 MD 15 MIN 8720 MD 40 MIN AND LUB 10 MIN. GOOD DATA. 10/30/04 PERFED 8770' - 8790' AND 8736' - 8756' CORRELATED TO 6/12/04 SWS JEWELRY LOG WITH 2.5" HSD 6 SPF PJ GUNS. COMPLETED TWO OF REQUESTED THREE PERFORATION RUNS. THIRD RUN TO BE COMPLETED 11/01. PAD OPERATOR AND PCC NOTIFIED TO PUT WELL ON INJECTION. 11/05/04 PERFORATED 8680' TO 8700' WITH 2.5" HSD PJ GUN, 6 SPF. SHUT WELL IN PRIOR TO AND BROUGHT WELL BACK ON INJECTION AFTER PERFORATING. JOB COMPLETE. T.REiE =', . . 4-1/16" crvv WELLHEAD = FMC ·"Ã"CTÜÄ.TÕTr;"····~m····"'·-"-NÃ "1'I'1',·w,,·,·,"f'fW·I'I'...I't'<'f\..,..,·,I¥,·,,"I''''I'Wf.'..''''I''I',·,I'I'··...~··,,...,··,.,....~.""^",,,ffl' KB. ELEV = 77.0' BF. ELEV = 48.5' KOP = 200' ,.,."'w",..",.,.·,w,·,,.,.""",,·,.,wl./Y"'...,,.,.,,,W,,y"",·...~I"..,.',·,",,,",,·m"m''',.,.',.,.,'''"'',·...."" Max Angle = 68 @ 7868' 'Õàt~~m~MÕ"W~""~,···,·~·_~"·'·_..·9Õsg. ·õ~ïv D';--·~·..44ÕÕ~Š L-211 I SAFT )OTES: ) 3892' 1-1 4-1/2" HES X NIP, ID = 3.813" I 3-1/2" HES X NIP, ID = 2.813" 1 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" 1 WA TERFLOOD MANDRELS TVD DEV TYÆ VLV LATCH PORT DATE 3793 67 MMG-W DMY RK 03/16/04 4101 68 MMG-W DMY RK 03/16/04 4148 68 MMG-W OMY RK 03/16/04 4179 68 MMG-W OMY RK 03/16/04 4245 68 MMG-W OMY RK 03/16/04 9-5/8" CSG, 40#, L-80, ID = 8.835" I Minimum ID = 2.813" @ 7285' 3-1/2" HES X NIPPLE 17" MARKER JOINT W/ RA TAG 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 17" MARKERJOINTW/ RA TAG 1--1 8105' ST MO 5 7303 4 8104 3 8227 2 8311 1 8489 13-1/2" MARKER JOINT W/ RA TAG 1 ÆRFORA TION SUMMARY REF LOG: SWS USIT 03/12/04 ANGLE AT TOP ÆRF: 66 @ 7341' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 4-1/2" 5 7341 - 7351 0 03/13/04 4-1/2" 5 8151 - 8221 0 03/13/04 4-1/2" 5 8291 - 8366 0 03/13/04 4-1/2" 5 8416 - 8451 0 03/13/04 2-1/2" 6 8704 - 8724 0 06/13/04 2-1/2" 6 8680 - 8700 0 11/05/04 2-1/2" 6 8736 - 8756 0 10/30/04 2-1/2" 6 8770 - 8790 0 10/30/04 13-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I I PBTO I I 7" CSG, 26#, L-80, 10 = 6.276" I 9033' 9119' DA TE REV BY COMMENTS OA TE REV BY 03/22/04 JAF/KAK ORIGINAL COM PLETION 06/10/04 JLJ/KAK FISH - SWS GUN ASSEMBLY 06/13/04 MOC/KA AOÆRFS 09/11/04 LWBrrLP WA TERFLOOO CORRECTIONS 11/05/04 MOCrrLP AOO ÆRFS COMMENTS 4-1/2" HES X NIP, 10 = 3.813" I 4-1/2" X 3-1/2" XO, 10 = 2.992" I 7" X 3-1/2" BKR PREMIER PKR, ID = 2.8"/" 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" HES X NIP, 10 = 2.813" 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" X 4-1/2" XO, 10 = 2.910"1 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 4-1/2" X 3-1/2" XO, 10 = 2.910" I 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" WLEG, 10 = 2.905" I -i FISH - SWS SXAR GUN ASSEMBLY ORION UNIT W8.L: L-211 ÆRMIT No: 2040290 API No: 50-029-23197-00 SEC 34, T12N, R11 E, 2540' NSL & 3816' WEL BP Exploration (Alaska) ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg V;1tì \O~ 'l~)D+ P.I. Supervisor \ 'ff( l DATE: Wednesday, October 27,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-211 PRUDHOE BAY UN ORIN L-211 ~oy..-o~q FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .::::Y.:>ß- Comm NON~CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN L-211 API Well Number: 50-029-23197-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS041022172453 Permit Number: 204-029-0 Inspection Date: 10/22/2004 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-211 Type Inj. P TVD 3764 IA 650 1980 1950 1940 P.T. 2040290 TypeTest SPT Test psi 941 OA 650 740 720 720 Interval INIT AL P/F P Tubing 1100 1100 1100 1100 Notes: Wednesday, October 27,2004 Page 1 of 1 ((~! 09/27/04 Schlumberger NO. 3219 Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm . Attn. ,(8"'.11 Wllõõa:=tUII 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Borealis Orion Polaris Color CD ~f) JJ -I If. ;z.Dzr- I :ø '-D 2- 2.03 -" , ,2,~...I.3I~ '~ .....-114A 10662970 SCMT 11(17(03 1 b< V-213 10877764 USIT 07(25(04 1 V-213 10877764 CH EDIT PDC-GR (USIT) 07(25/04 1 'Ii L-211 10679059 USIT 03(12104 1 ....-211 10679059 CH EDIT PDC-GR (USIT) 03(12104 1 /' W-215 10662954 USIT 09(20/03 1 W-215 10662954 CH EDIT PDC-GR (USIT) 09120/03 1 W-215 40009586 OH EDIT MWD DATA 09/09-16(03 2 1 W-215 PB1 40009586 OH EDIT MWD GR DATA 09/09-10(03 2 1 -' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: 9h.71o f I I .~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 J ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate III 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development D ExploratoryD Stimulate D OtherO WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 204-0290 6. API Number 50-029-23197-00-00 77.00 8. Property Designation: ADL-028239 11. Present Well Condition Summary: Total Depth measured 9130 feet true vertical 4494.0 feet Effective Depth measured 9034 feet true vertical 4454.0 feet StratigraphicD ServiceŒ 9. Well Name and Number: L-211 10. Field/Pool(s): Prudhoe Bay Field I Orion Oil Pool Plugs (measured) Junk (measured) None 8833 Casing Conductor Production Surface Length 80 9093 4374 Size 20" X 34" 215.5# A53 7" 26# L-80 9-5/8" 40# L-80 MD 28 - 108 26 - 9119 29 - 4403 TVD 28.0 - 108.0 26.0 - 4489.4 29.0 - 2687.3 Burst Collapse 7240 5750 5410 3090 Perforation depth: Measured depth: 8704 - 8724 True vertical depth: 4326.45 - 4334.07 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-112" 12.6# L-80 @ 24 3-112" 9.3# L-80 @ 7215 4-1/2" 12.6# L-80 @ 8558 3-1/2" 9.3# L-80 @ 8565 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer 3-112" Baker Premier TCII Packer 4-1/2" Baker S-3 Hydro Set Packer - 7215 :::: RECEIVED 8608e @ 7227 .¡jEf) 0 9 2IJØ4 @ 8061A~~ f\;j @ 8266~1 vu & Gas Coos. ~ @ 8559 AnctøCf8gt· .. - - - 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Dailv Averaae Production or Iniection Data I Gas-Met I Water-Bbl I Casing Pressure I Tubing Pressure New Well Well Shut-in Prior to well operation: Subsequent to operation: Copies of Logs and Surveys run _ Daily Report of Well Operations. ~ 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: Printed Nam e Garry Catron Garry Catron 1:1 ~ Cr~T;¡-~ fI WAG D GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: I 304-229 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Title Production Technical Assistant Signature Phone 564-4657 Date 8/27/04 - " Form 10-404 Revised 4/2004 ORIGINAL ("'\)~\D) 1.'\ I.:".,~ -0)\[,'f .' \~j) ) ) L-211 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/14/04 Perforate 87041-87241 6 SPF BBLS o FLUIDS PUMPED :TOT AL No Fluids Pumped Page 1 ) ') TREE = WELLHEAD = A CTUA TOR = KB. B...EV = BF. ELEV = KOP= Max An Ie = Datum MO = OatumTVD = 4-1/16" CIW FMC NA 77.0' 48.5' 200' 7868' 9089' 4400' SS L-211 I SAFETY NOlES: 1 PBTO 4-1/2" HES X NIP, 10 = 3.813" 9-5/8" CSG, 40#, L-80, 10 = 8.835" I Minimum ID = 2.813" @ 7285' 3-1/2" HES X NIPPLE PORT DA TE o 03/16/04 o 03/16/04 o 03/16/04 o 03/16/04 o 03/16/04 4-1/2" HES X NIP, 10 = 3.813" 17" MARKER JOINT W/ RA TAG 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID =3.958" 4-1/2" X 3-1/2" XO, 10 = 2.992" 7" X 3-1/2" BKR PR8v1IER A<R, 10 = 2.87" 3-1/2"HES X NIP, 10= 2.813" 17" MA.RKER JOINTW/ RA TAG ( 3-1/2" HES X NIP, 10 = 2.813" 3-1/2" HES X NIP. 10 = 2.813" 3-1/2" MA.RKERJOINTW/RA TAG 3-1/2" HES X NIp, 10 = 2.813" 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: SWS US IT 03/12/04 ANGLE AT TOP PERF: 66 @ 7341' t'>bte: Refer to Production DB for historical perf data SIZE SPF INTERv' AL Opn/Sqz DA TE 4-1/2" 5 7341 - 7351 0 03/13/04 4-1/2" 5 8151 - 8221 0 03/13/04 4-1/2" 5 8291 - 8366 0 03/13/04 4-1/2" 5 8416 - 8451 0 03/13/04 2-1/2" 6 8704 - 8724 0 06113/04 4-1/2" X 3-1/2" XO, 10 = 2.910" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" HES X NIP. 10 = 2.813" 3-1/2" WLEG, 10= 2.905" 3-1/2" TBG. 9.3#, L-80, .0087 bpf. 10 = 2.992" -1 RSH - SWS SXA R GUN ASSEMBLY 7" CSG, 26#. L-80.10 = 6.276" 9119' DATE REV BY COM'v1ENTS 03/22/04 JAF/KAK ORIGINAL COMPLETION 06110/04 JLJIKAK RSH - SWS GUN ASSEMBLY 06/13/04 rvÐC'KAK ADÆRFS DA TE REV BY COM'v18'JTS ORON UNIf WB...L: L-211 PERrv11T No: 2040290 API No: 50-029-23197-00 SEC 34, T12N. R11 E. 2540' NSL & 3816' WEL BP Exploration (Alaska) ) WELL LOG TRANSMITTAL O(o¥- 02-? ])s~ 12." 2..4 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Atten: Robin Deason 333 W. 7th Street Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG Electronic BLUE LINE REPORT WELL DATE TYPE Data PRINT(S) OR Images COLOR Open Hole 1 1 Res. Eva!. CH 1 1 L-211 i 7 -6-04 Mech. CH 1 1 Signed: Date: C¡}3!o/ I PRoAcTivE DiAGNOSTic SmvÎcES, INC., PO Box 1 }69 STAffoRd TX 77477 Phone:(281) 565-9085 FCLx:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com \¡J6Æ· G,/¡&/¿oof ) . rt/t7-S r; //~ / <7-. . STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV AL 20 AAC 25.280 j. 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate[K WaiverD Annular Disposal 0 StimulateD Time ExtensionD OtherD Re-enter Suspended WellO 5. Permit to Drill Number: 204-0290 / BP Exploration (Alaska), Inc. Development D Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 77.00 KB 8. Property Designation: ADL-028239 6. API Number /' StratigraphicD Service [!] ,,/ 50-029-23197-00-00 9. Well Name and Number: L-211 /' 10. Field/Pool(s): Prudhoe Ba Field / Orion Oil Pool JU PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9034 4377.0 Size MD TVD 11. Total Depth MD (ft): 9130 Casing Total Depth TVD (ft): 4494.0 Length Conductor 80 Production 9093 Surface 4374 Perforation Depth MD (ft): to 28 26 29 bottom to 108 28.0 9119 26.0 4403 29.0 Tubing Size: 3.5 " 9.3 # 3.5 " 9.3 # 4.5 " 12.6 # 4.5 " 12.6 # Packers and SSSV MD (ft): 20" X 34" 215.5# A53 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): Packers and SSSV Type: 3-1/2" Baker Premier TCII Packer 3-1/2" Baker Premier TCII Packer 3-112" Baker Premier TCII Packer 4-112" Baker S-3 H dro Set Packer 12. Attachments: Description Summary of Proposal ŒJ bottom 108.0 4489.4 2687.3 Tubing Grade: L-80 L-80 L-80 L-80 7240 5750 Tubing MD (ft): 7215 8565 24 8558 5410 3090 8558 8608 7215 8565 7227 8061 8266 8559 Detailed Operations Program D BOP Sketch D 13. Well Class after proposed work: Exploratory D Development D Service ŒI /' 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasO PluggedO AþandonedD WAG D GINJD WINJŒ] / WDSPLn Prepared by Gar~atron 564-4657. June 18, 2004 /' Printed Name Signature Taylor West 77~úI~ Title Phone Commission Use nl Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP TestO Mechanciallntegrity Test D Other: Subsequen ~ 4 [)4 '. 1'4,1 Form 1 0-403 Revised 12/2003 Contact Taylor West Petroleum En ineer 564-4647 6/11/04 Location Clearance 0 BY ORDER OF THE COMMISSION Date: \Ø)ØS, \aft SUBMIT IN DUPLICATE ') PERFORATING PROCEDURE ') f Well: Date: L-211 ------ 6/11/04 API #: 50-029-23197-00 Prod Engr Taylor West Office Ph: Home Ph: Cell/Pager: 564-4647 337-2028 632-0111 .................................................................................................................... CC or AFE: ...................º.~P?M.ª.?4.?.:.º WBL Entries lOR .. ........TVPE3 Work Desciption í·· . . .., E ···IJ~;~ï~·ï~~ï~~rl2(Y . . ....... .. ...., I .¡ .. I ...... ... ·······1 l=.~:.=~~~.._.~=~L._._~~~=~.=.L___~=:=~~~~~..~==~=:=.~:~.___=~:=:~:.~:~=~:~::~~:~~===-...__.~J Well Ob'ectives and Perforatin Notes: Add perfs needed due to no injectivity after firing of SXAR guns. Suspect guns did not fire properly. Please log a PL GR/CCL jewelry log from the top of the gun fish to 7100' md. Log several passes over the SXAR perf depth 8691-8781 to look for any evidence of perf holes. Make several passes in the liner at different gains if possible. Please produce a separate GR/Jewelry log from top of gun fish to 7100' md for future correlation. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: US IT USIT Date: 3/12/2004 3/12/2004 Company: ·~.$.y!.$..·:.·.·.·.n...nn...n..n. :$Yf/$~:::.·:~~:.....nn......n Depths (from-to) Depths (from-to) Feet SPF Orient. _~704' __ ...-ª¿~~~ _8..!.zº~..._ _.._8~24~___ 20 ____~__._ _..B~Q.~~.__. Add.......... ...........º to the tie-in log to be on depth with the reference log. feet Phasing Zone Ad/Re/lperf __~-º__~_~g____.. ...9b9__ A~E..~.rL__.__. ................................................. ............................................ ............................................. .............................................. .................................. ....................................................... .......................................................................... ............................................................................................ ._..~-_..__._~..._--_...._. -.-----.......-.-..-..-.-.. ._.._...~---_.._._.- ----..---.-..-...---....-.-. --....--....-....-....- .._.._...._.~----~.__.. _._----_.._..-._.__.__..__._.._.~ ..----.-..------.--..-..-----.---- ................................................. ............................................ ............................................ ............................................. .................................. ....................................................... ........................................................................." ............................................................................................. -...-....---...---.-...-. -..-.-.----.- ---_._..._~-~ ~~~ -..--.--- -~- -.-----.-.- ---...----.....-..-...-.----.....--.....-. Requested Gun Size: 2.5" Charge: Power Enerjet / Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Unnecessary -ª-E~~~~~~~~~===~==.=~~~~~~=~==~.=_~~~~=~=~~~~.........._.~=_.~..._ Last Tag: 8,823 ft MD on ........f?(~f.?ºg4........ Est Res. Pres. @ nª.!.~.~.Q....u.....u.... MD is 1 915 psi Perforation Summary API#: 50-029-23197-00 Prod Engr: Summary Dist Town: ....................................................... ........... Anch Prod Engr P.O. Center Well: Date: L-211 ......................................................... ,..............................."...... PBTD General Comments: .................................. .................................... ............................................................. ............................................ Balance O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf ........~~-_. -_....._-,,~... ................-..-............-....... -- ----..-.-..--...- ---..------ --.............--.-..............-.......-...... ~~._--~.. ..- ..~¥ -' ._~-~.._...- '._-y-,y-".-- .~ ~-~--- ~~....,._~ y---- -y.~--",--- ..---,...---,..--..--......- ~._..-..~. '---"'~----.- _._-~,-"-- -_..~ '-"~Y_--' - '..' _"'.' - .___~~ ,.,_.._. __¥ - ._~ ..-................~ .....~...._..............._- ..............-..........................................,...................................................... ...' ~ ~- ..--..,.......---.-....,.....-.-.... .\ ) TREE = 4-1/16"CIW WELLHEAD = FMC A Cfl..V\ TOR = NA KB. B..EV = 77.0' BF. ELEV = 48.5' KOP = 200' Max An Ie = 7868' Datum MD = 9089' Datum TVD = 4400' SS L - 211 I SAFETY NOleS: T' CSG, 26#, L-80, ID = 6.276" 4-1/2" HES X NIP, ID= 3.813" 9-5/8" CSG, 40#, L-80, ID = 8.835" 1 PORT DA. TE o 03/16/04 o 03/16/04 o 03/16/04 o 03/16/04 o 03/16/04 Minimum ID = 2.813" @ 7285' 3-1/2" HES X NIPPLE 4-1/2" HES X NIP, ID = 3.813" 17" MARKER JOINT WI RA TA G 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 4-1/2"X 3-112" XO, ID =2.992" 7" X 3-112" BKR PRBVlIER R<R, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" IT' MA.RKER JOINTW/ RA TAG I 8105' 3-1/2" HES X NIP, ID = 2.813" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" MA.RKER JOINT W/ RA TAG 3-1/2" HES X NIP, ID = 2.813" 7" X 3-112" BKR PRBVlIER R<R, ID = 2.87" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" X4-112" XO, ID = 2.910" 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" PERFORATION SUIVtv1ARY REF LOG: SWS US IT 03/12/04 ANGLE AT TOP PERF: 66 @ 7341' t\bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL n/S DA. TE 4-1/2" 5 7341 - 7351 0 03/13/04 4-1/2" 5 8151 - 8221 0 03/13/04 4-1/2" 5 8291 - 8366 0 03/13/04 4-1/2" 5 8416 - 8451 0 03/13/04 4-1/2" 5 8691 - 8781 notfired 03/13/04 4-1/2" X 3-112" XO, ID = 2.910" 3-112" I-ESX NIP, ID= 2.813" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" WLEG, ID= 2.905" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 8833' RS H - SW S SXA R G J\J ASSEMBLY DATE REV BY OOIVtv1ENTS 03/22/04 JAF/KAK ORIGINAL COMPLETION 06110/04 JLJtKAK RSH - SWS GJ\J ASSEMBLY DA. TE RBI BY CO IVtv1ENTS ORON UNrr WELL: L-211 PERMIT No: 2040290 AA No: 50-029-23197-00 SEe 34, T12N, R11 E, 2540' NSL & 3816' WEL BP Exploration (Alaska) .) STATE OF ALASKA 1 RECEIVED ALASKAv.t AND GAS CONSERVATION COMM.~SION . . WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAY 042004 Alaska Oil & Ga!t r."n~ r 1a. Well Status: 0 Oil DGas o Plugged o Abandoned o Suspended a WAG 1 b. Well C1aWOchorage 20AAC 25.105 20AAC 25.110 o Development 0 Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic Test a Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/16/2004 204-029 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/24/2004 50- 029-23197-00-00 4a. Location of Well (Governmental Section): 7. Date T. D. Reached 14. Well Name and Number: Surface: 3/8/2004 PBU L-211 i 2540' NSL, 3816'WEL, SEC. 34, T12N, R11E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2231' NSL, 1005' WEL, SEC. 28, T12N, R11E, UM 77' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD+TVD) 3413' NSL, 2157' WEL, SEC. 28, T12N, R11E, UM 9034 + 4454 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 583098 y- 5978260 Zone- ASP4 9130 + 4494 Ft ADL 028239 -".-.._-~-,---_.._._-_...., --..---..-.-------... -,--~--,----_.- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 580565 y- 5983203 Zone- ASP4 ~,-_._._._~._---_.__.__..." ._-_.,-_..,._~..._-_. -~--,---- (Nipple) 3892' MD Total Depth: x- 579398 y- 5984373 Zone- ASP4 - ...- . - . - .... 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aYes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING .... ." SETTING DEPTH MD SETTING DEPTH TVD HoL.E '.. : ..... ..' ',"" ,....:.' , AMOUN'r,¡ SIZE WT. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE ,CEMENTING RECORD ."PLJLLED ':¡ 20" x 34" 215.5# A53 Surface 108' Surface 108' 48" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 4403 29' 2687' 12-1/4" 650 sx AS Lite, 384 sx Class 'G' 7" 26# L-80 26' 9119' 26' 4489' 8-3/4" 435 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. .. .. TUBING RECORD ,. " " " .,.,'>"..... '.'..' ","i, Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 4-1/2" Gun Diameter, 5 spf 4-1/2", 12.6#, L-80 7215' MD TVD MD TVD 3-1/2",9.3#, L-80 7215' - 8606' 7227' & 8061' & 8266' & 8559' 7341' -7351' 3808' - 3813' Gun Assembly 25. ACID,. FRACTURE, CE~ENT SOUEEZE,ETC.... , ,...'....., <:'......, 8151' - 8221' 4119' - 4145' attached to ". .... 8291' - 8366' 4172' - 4200' bottom of tubing, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8416' - 8451' 4218' - 4231' Not Fired Yet Freeze Protect with 130 Bbls of Diesel 8691' - 8781' 4321' - 4356' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF W ATER-BsL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED -+ OIL-BBL GAs-McF W ATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ... -- ~ --. None ."$~2~:9 ORIGINAL .~. ; -, ',- :.::.1 :, ~ . It . -"-~"'''' ! ~ . . . .. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE _BFL .-/ MAY 1 u '200~ G ~ 28~ GEOLOGIC MARKERS NAME MD TVD Top Ugnu 4610' 2772' Ugnu MB1 7340' 3808' Top Schrader Bluff I NA 7782' 3979' Schrader Bluff NB 7834' 3999' Schrader Bluff NC 7941' 4040' Schrader Bluff OA 8162' 4123' Schrader Bluff OBa 8308' 4178' Schrader Bluff OBb 8436' 4226' Schrader Bluff OBc 8579' 4279' Schrader Bluff OBd 8704' 4326' Schrader Bluff OBe 8852' 4382' Schrader Bluff OBf 8952' 4421' Base Schrader Bluff I Top Colville 9054' 4462' 29. t=ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED MAY 0 4 2004 Alaska 0\\ &. Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys Signed Title 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date OS-ò3"0 Technical Assistant 204-029 Permit No. / A roval 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. Terrie Hubble PBU L-211 i Well Number Prepared By Name/Number: Drilling Engineer : Terrie Hubble, 564-4628 Thomas Schaefer, 564-4685 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Name: Common Name: Test Date 3/1/2004 LOT L-211 L-211 Test Type Test Depth (TMD) 4,403.0 (ft) Test Depth (TVD) 2,686.0 (ft) Surface Pressure Leak Off Pressure (BHP) 800 (psi) 2,098 (psi) EMW 15.03 (ppg) AMW 9.30 (ppg) Printed: 3/22/2004 8:05:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES ) Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 2/23/2004 12:00 - 16:00 16:00 - 18:00 18:00 - 20:30 20:30 - 21 :30 2/24/2004 21 :30 - 00:00 00:00 - 01 :00 01 :00 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 2/25/2004 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:30 02:30 - 03:00 4.00 MOB N WAIT PRE 2.00 MOB P PRE 2.50 MOB N WAIT PRE 1.00 RIGU P PRE 2.50 RIGU P 1.00 RIGU P PRE PRE 11.00 RIGU P PRE 3.00 RIGU P 1.00 RIGU P 0.50 RIGU P 1.50 RIGU P 1.00 1.00 RIGU P 1.00 DRILL P PRE PRE PRE PRE PRE PRE SURF 1.00 DRILL P SURF 2.00 DRILL P SURF 0.50 DRILL P SURF 1.00 DRILL P SURF 1.00 DRILL N DPRB SURF 0.50 DRILL N DPRB SURF Description ofOþ~ratiqris Wait on well house removal and location preparation. Have been unable to remove well houses due to temps below -35 degrees and winds in excess of 20 mph Hang surface stack and riser off bridge crane. Move rig sub off of L-200 Injection wells adjacent to L-211 i froze when shut in, wait on pad operator to thaw wells. Lay mats around cellar. Move diverter and well head equipment behind cellar. Lay mats and herculite. Spot rig sub over L-211. Spot sub. Spot and level pits. ACCEPT RIG @ MIDNIGHT Take on water and build spud mud. NU diverter, riser and Hydril. Function test diverter and knife valve, witness of diverter test waived by John Crisp with AOGCC Continue build spud mud. Load BHA #1 in pipe shed MU bit, bit-sub and 1 stand of HWDP Clean ice out of conductor from 45' to 108' Stand back HWDP. LD bit and XO MU BHA #1 RU Sperry unit and GyroData for gyro surveys. RIH and tag up at 108'. Drill 12-1/4" hole from 108' to 268'. SPUD @ 20:00 Stand back stand of HWDP to PU jar stand. TAG up on fill at 258'. LD single, MU DP sub and wash down to 268'. Continue drilling from 268' to 356' WOB = 2-20 klbs RPM = 60 Torque off Btm = 1 k FtLb, Torque on Btm = 1.2k FtLb GPM = 550 @ 923 psi on Btm, 765 psi off Btm P/U 55k S/O 55k ROT 55k Run gyro survey every stand drilled. AST = 0.33 hrs ART = 0.69 hrs Drill 12-114" surface hole from 356' to 447'. sliding 100% to build angle WOB = 2-20 klbs RPM = 60 Torque off Btm = 1 k FtLb, Torque on Btm = 1.2k FtLb GPM = 550 @ 923 psi on Btm, 765 psi off Btm P/U 64k S/O 60k ROT 61 k Run gyro survey. Getting erratic tool face, gryo tool not seating in UBHO sub. Ciculate hole to clear UBHO and re-attempt gyro survey. Gryo tool still not seating. Pull 4 stands. Check UBHO sub for debris and check MWD orientation. RIH, wash last stand to bottom at 447' Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 2/25/2004 03:00 - 05:00 2.00 DRILL N DPRB SURF 05:00 - 07:30 2.50 DRILL P SURF 07:30 - 08:00 0.50 DRILL P SURF 08:00 - 09:00 1.00 DRILL N DPRB SURF 09:00 - 10:00 1.00 DRILL N DPRB SURF 10:00 - 10:30 0.50 DRILL N DPRB SURF 10:30 - 11 :00 0.50 DRILL N DPRB SURF 11 :00 - 12:00 1.00 DRILL N DPRB SURF 12:00 - 00:00 12.00 DRILL P SURF 2/26/2004 00:00 - 01 :00 01 :00 - 02:00 1.00 DRILL P 1.00 DRILL P SURF SURF 02:00 - 03:30 1.50 DRILL P SURF 03:30 - 04:00 0.50 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 05:00 0.50 DRILL P SURF 05:00 - 05:30 0.50 DRILL P SURF 05:30 - 06:30 1.00 DRILL P SURF 06:30 - 07:00 0.50 DRILL P SURF 07:00 - 00:00 17.00 DRILL P SURF ·Öescriptiönof Operations Run gyro survey, tool face still erratic. Gyro tool not seating in UBHO sub. Pull gryo tool and change to smaller OD mule shoe. run gyro tool and re-attempt survey, still not seating. Pull gyro tool and change to mule shoe with hole locator. Run gyro survey, tool seating and surveys look good. Drill 12-1/4" surface hole from 447' to 723'. sliding 100% to build angle and azimuth WOB = 2-20 klbs GPM = 550 @ 1080 psi on Btm, 880 psi off Btm P/U 64k S/O 60k ROT 61 k Run gryo survey. Not able to build angle as per directional plan. Circulate hole clean to POH and dial up motor and CO bit. POH and stand back jars and collars. PU new HTC 12-114" MX-C1and dial motor up to 1.83 degrees clean and clear rig floor. Service top drive and blocks. RIH and wash last stand to bottom at 723' Drill 12-114" surface hole from 723' to 1654'. sliding 1 00% to build angle and azimuth WOB = 20-35 klbs GPM = 550 @ 1704 psi on Btm, 1441 psi off Btm P/U 78k S/O 71 k Run gyro surveys. Circulate and condition mud for bit trip. Circulate 2.5 X BU volume, 650 gpm @ 1900 psi, 40 rpm Monitor well - static. POH for new bit. Work through tight spot at 1530' P/U 75 klbs S/O 71 klbs Stand back jars and DC's. PU New HTC 12-1/4" MX-C1. Clean and clear rig floor. Service top drive and blocks. RIH,washing down with last stand to 1644',10' of fill Stage pumps to 650 gpm @ 1780 psi. Wash to bottom at 1654' Drill 12-114" surface hole from 1654' to 3986'. Sliding as required to build inclination to 67 degrees, landed well at 2247'. Below 2247' sliding as required to maintain inclination of 67 degrees in tangent section. WOB = 25-35klbs RPM = 50 Torque off Btm = 4-5k FtLb, Torque on Btm = 9-10k FtLb GPM = 670 @ 3134 psi on Btm, 3007 psi off Btm P/U 99k S/O 61k ROT 77k Formation tops: Base of permafrost - 2040' MD SV3 - 2965' MD SV2 - 3357' MD Printed: 3/22/2004 8:05:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 NPT 2/26/2004 2/27/2004 07:00 - 00:00 00:00 - 03:00 17.00 DRILL P 3.00 DRILL P SURF SURF 03:00 - 04:00 1.00 DRILL P SURF 04:00 - 06:30 2.50 DRILL P SURF 06:30 - 09:00 2.50 DRILL P SURF 09:00 - 13:30 4.50 DRILL P SURF 13:30 - 15:00 1.50 DRILL P SURF 15:00 - 16:00 1.00 DRILL P SURF 16:00 - 16:30 0.50 DRILL P SURF 16:30 - 17:00 0.50 DRILL P SURF 17:00 - 20:00 3.00 DRILL P SURF 20:00 - 22:30 2.50 DRILL P SURF ART = 5.13 Hrs AST = 4.80 Hrs. Drill 12-1/4" surface hole from 3986' to 4297'. Sliding as required to maintain inclination of 67 degrees in tangent section. WOB = 25-35klbs RPM = 50 Torque off Btm = 4-5k FtLb, Torque on Btm = 9-10k FtLb GPM = 670 @ 3134 psi on Btm, 3007 psi off Btm P/U 99k S/O 61 k ROT 77k SV1 top @ 4177' MD, fault #1 (estimated at 3580' MD) came in below the top of the SV1. Will drill ahead until geology can correlate the amount of throw and pick a competent shale for the surface casing shoe. Circulate and condition mud while geology correlates logs. 640 gpm @ 3160 psi. Reduce rate to 600 gpm @ 2860 psi while hydrates breaking out of mud. Drill 12-1/4" surface hole from 4927' to TD at 4411'. Sliding as required to maintain inclination of 67 degrees in tangent section. WOB = 25klbs RPM = 50 Torque off Btm = 7-8k FtLb, Torque on Btm = 9-11 k FtLb GPM = 600 @ 3140 psi on Btm, 2870 psi off Btm P/U 113k S/O 60k ROT 79k Backream each stand at 50 rpm and 650 gpm, reducing rate on the down stroke to 500 gpm. ART = 1.30 Hrs AST = 2.22 Hrs. Circulate BU volume X 2.5. 675 gpm @ 3207 psi, reciprocate DP at 50 rpm Monitor well - static. POH from 4411. Unable to work past tight spot at 3370'. Backream out from 3370' to 1680'. 600 gpm @ 2360 psi and 50 rpm. POH from 1680'. Tight spot at 1050', RIH 1 stand. Stage up pumps and backream from 1120' tp 990'.550 gpm @ 1530 psi and 50 rpm. Able to POH without pumps from 990'. Stand back jars and DC's. Dial motor down to 1.5 degrees to allow the DP to be rotated at higher RPM's while circulating at TD. Service top drive, blocks and crown. RIH with DC's, jars and HWDP. RIH, work through and wipe intermittent tight spots from 1420' to 4318'. Wash last stand to bottom at 4411'. stage up pumps and circulate BU volume X 3, adjusting rate as necessary to control losses over the shakers. 670 gpm @ 3310 psi and 110 rpm. P/U 113k S/O 60k ROT 79k No pumps: P/U 121k S/O 60k Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 NPT 2/27/2004 22:30 - 00:00 1.50 DRILL P SURF 2/28/2004 00:00 - 01 :30 1.50 DRILL P SURF 01 :30 - 04:00 2.50 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 07:00 2.50 CASE P SURF 07:00 - 13:30 6.50 CASE P SURF 13:30 - 14:00 0.50 CASE P SURF 14:00 - 17:00 3.00 CEMT P SURF 17:00 - 17:15 0.25 CEMT P SURF 17:15 -19:00 1.75 CEMT P SURF 19:00 - 20:00 1.00 CEMT P SURF 20:00 - 21 :00 1.00 CEMT P SURF 21 :00 - 21 :30 0.50 CASE P SURF 21 :30 - 00:00 2.50 DIVRTR P SURF 2/29/2004 00:00 - 02:00 2.00 DIVRTR P SURF 02:00 - 03:30 1.50 WHSUR P SURF 03:30 - 05:00 1.50 BOPSU P SURF 05:00 - 05:30 0.50 BOPSU P SURF 05:30 - 09:00 3.50 BOPSU P SURF 09:00 - 09:30 0.50 BOPSU P SURF 09:30 - 15:30 6.00 BOPSU P SURF 15:30 - 17:30 2.00 BOPSU P SURF 17:30 - 18:00 I 0.50 I DRILL P INT1 I POH to run 9-5/8" casing from 4411' Midnight depth: 3511' Continue POH, wipe through tight spot at 3680'. No other problems hole looks good, Stand back HWDP, DC's and jars. LD BHA #3 Clean and clear rig floor. CO bails, MU landing joint and make dummy run. RU 9-5/8" casing equipment. PU and Baker-Lok shoe track, fill and check floats. Run 114 joints of 9-5/8",40#, L-80 surface casing. Landed at 4403'. Work through tight spot 4000'. Centralizers: 1 on stop ring 10' above shoe on joint #1 1 on stop ring mid way on joint #2 23 on the collars of joints #3-25 Circulate last joint to bottom at 4403'. RD fill-up tool and blow down top drive. RU cement head. Circulate and condition hole for cement. Stage pumps to 9 bpm @ 436 psi. Reciprocate csg 5-10', P/U 225k Ibs S/O 78k Ibs. Pump 5 bbl water to flush lines then pressure test cement lines to 4000 psi. Pump 80 bbls 10.1 ppg mud push. Drop bottom plug and pump 515 bbls (650 sxs) 10.7 ppg Arctic Set Lite lead cement at 7 bpm. Pump 80 bbls (384 sxs) 15.8 ppg Class G tail cement at 7 bpm. Reciprocate casing 5-10', landed when pumping tail cement. Full returns throughout cement job. Drop top plug and kick out with 10 bbls water from cementers to flush lines. Switch to rig pumps and displace with rig pumps. Displace at 10 bpm slowing rate to 2 bpm for the last 10 bbls to bump. Good cement to surface 1635 strokes into the displacement, total returns 200 bbls cement. Bump plugs on calculated strokes and pressure up to 3000 psi, hold for 10 minutes. Floats holding. CI P @ 20:00 hrs. Flush stack and flow line. Break out and LD landing joint. RD csg equipment. CO bails. RD stabbing board. NO diverter, riser and Hydril Continue ND diverter, riser and Hydril. NU base flange and tbg spool. Test metal to metal seal to 1000 psi. NU BOPE RU BOP test equipment. Install test plug Test BOPE 4000/250 psi, Hydri13500/250 psi. Witness of BOP test waived by John Spaulding with AOGCC. RD BOP test equipment. Install wear bushing. Blow down surface lines. PU DP from pipe shed and stand back stands Clean and clear rig floor. Cut and slip 70' of drill line. Service top drive and blocks. Bring BHA #4 up to rig floor. Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 2/29/2004 18:00 - 20:00 2.00 DRILL P INT1 PU and MU BHA #4, 8-3/4" directional assembly 20:00 - 20:30 0.50 DRILL P INT1 PJSM with Anadrill and all rig personnel on loading RA source. Load RA source and RIH with BHA #4 20:30 - 21 :00 0.50 DRILL P INT1 Shallow test MWD, 530 gpm @ 446 psi. 21 :00 - 00:00 3.00 DRILL P INT1 RIH picking up DP from pipe shed. Midnight depth 3150' 3/1/2004 00:00 - 00:30 0.50 DRILL P INT1 Continue RIH to 4200' picking up DP from pipe shed. 00:30 - 01 :30 1.00 CASE P SURF Break circulation and circulate air out of system. Test 9-5/8". 40# surface casing to 3500 psi for 30 minutes. 01 :30 - 02:30 1.00 DRILL P INT1 Wash down and tag cement at 4317', Drill cement and float equipment from 4317' to 4403'. Drill rathole and 20' of new hole to 4431' WOB = 0-5k Ibs RPM = 50 Torque off Btm = 8.5k FtLb, Torque on Btm = 8.5k FtLb G PM = 550 @ 2430 psi on Btm, 2150 psi off Btm P/U 128k S/O 64k ROT 80k 02:30 - 03:30 1.00 DRILL P INT1 Displace to new 9.3 ppg LSND mud 03:30 - 04:00 0.50 DRILL P INT1 Perform LOT, 15.0 ppg EMW. 800 psi surface pressure with 9.3 ppg mud in the hole at 2686' TVD. 04:00 - 04:30 0.50 DRILL P INT1 Establish baseline ECD of 10.1 ppg 04:30 - 00:00 19.50 DRILL P INT1 Drill 8-3/4" intermediate hole from 4431' to 7763'. Sliding as required for inclination and azimuth. WOB = 10-15klbs RPM = 80 Torque off Btm = 9.5k FtLb, Torque on Btm = 11.3k FtLb GPM = 590 @ 3280 psi on Btm, 3120 psi off Btm P/U 134k S/O 70k ROT 92k Backream each stand at 100 rpm and 550 gpm, reducing rate to 450 gpm on down stroke. Pump a lo/hi vis sweep around every 300' - 500' drilled calculated ECD = 10.89 ppg Actual ECD = 11.41 ppg Circulate as need to maintain ECD's within 0.9 ppg of calculated AST = 2.20 hrs. ART = 5.22 hrs Formation tops: UG4 - 4626' MD UG3 - 5950' MD UG1 - 7583' MD 3/212004 00:00 - 12:30 12.50 DRILL P INT1 Drill 8-3/4" intermediate hole from 7763' to 9817'. Sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 100 Torque off Btm = 14-15k FtLb, Torque on Btm = 14k FtLb GPM = 590 @ 3800 psi on Btm, 3480 psi off Btm Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 . .. .. . . . Døscri ptiÖriQf Ope ra.tions· 3/2/2004 00:00 - 12:30 12.50 DRILL P INT1 P/U 189k S/O 67k ROT 101 k Backream each stand at 100 rpm and 550 gpm, reducing rate to 475 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled 12:30 - 13:00 0.50 DRILL P INT1 Calculated ECD = 10.81 ppg Actual ECD = 11.41 ppg Circulate as need to maintain ECD's within 0.9 ppg of calculated Rotary torque increased to a unacceptable level. Pump sweep + adding Lube-Tex to mud. Reciprocate & rotate (100 RPM) drill string while circulating (590 gpm). Torque decreased to 12.8k FtLb. Continue drilling 8-3/4" intermediate hole from 9817' to 10377'. Sliding as required for inclination and azimuth. 13:00 - 17:30 4.50 DRILL P INT1 17:30 - 18:30 1.00 DRILL P INT1 WOB = 10-20klbs RPM = 100 Torque off Btm = 14-15k FtLb, Torque on Btm = 14k FtLb GPM = 570 @ 3800 psi on Btm, 3480 psi off Btm P/U 189k S/O 67k ROT 101 k Rotary torque increased to 17k FtLb. Pump sweep + adding Lube-Tex to mud system. Circulate & condition mud/hole. Torque reduced to 15k FtLb. Continue drilling 8-3/4" intermediate hole from 10377' to 10975". Sliding as required for inclination and azimuth. 18:30 - 00:00 5.50 DRILL P INT1 WOB = 10-20klbs RPM = 100 Torque off Btm = 14-15k FtLb, Torque on Btm = 14k FtLb GPM = 550 @ 3920 psi on Btm, 3620 psi off Btm P/U 165k S/O 72k ROT 102k Backream each stand at 100 rpm and 550 gpm, reducing rate to 475 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 10.68 ppg Actual ECD = 11.36 ppg Circulate as need to maintain ECD's within 0.9 ppg of calculated 3/3/2004 00:00 - 01 :00 1.00 DRILL P Drilling Time last 24 Hrs: ART = 9.42 Hrs AST = 1.66 Hrs. Survey & Connection time = 11.42 Hrs Drill 8-3/4" intermediate hole from 10975' to 11200' MDTD / 4728' KBTVD . Sliding as required for inclination and azimuth. INT1 WOB = 10-20klbs RPM = 100 Torque off Btm = 14-15k FtLb, Torque on Btm = 14k FtLb GPM = 550 @ 3920 psi on Btm, 3620 psi off Btm P/U 161 k S/O 76k ROT 105k I Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Task· Cöde .. DesëtiptiOn of Operåtions 3/3/2004 00:00 - 01 :00 1.00 DRILL P INT1 01 :00 - 04:00 3.00 DRILL P INT1 04:00 - 04:45 0.75 DRILL P INT1 04:45 - 14:30 9.75 DRILL P INT1 14:30 - 15:30 1.00 DRILL P INT1 15:30 - 17:00 1.50 DRILL P INT1 17:00 - 20:00 3.00 DRILL P INn 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 22:00 1.50 DRILL P INT1 22:00 - 23:00 1.00 DRILL P INT1 ! I Backream each stand at 100 rpm and 550 gpm, reducing rate to 475 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 10.73 ppg Actual ECD = 11.43 ppg Circulate as need to maintain ECD's within 0.9 ppg of calculated ART = 0.50 Hrs AST = 0 Hrs. Survey & Connection time = 0.50 Hrs Formation tops: OA @ 9925' MD / 4229' KBTVD OBa @ 10128' MD /4295' KBTVD OBb @ 10281' MD /4345' KBTVD OBc @ 10453' MD /4402' KBTVD OBd @ 10608' MD /4454' KBTVD OBe @ 10788' MD /4513' KBTVD OBf @ 10905' MD /4552' KBTVD Pump Lo-vis sweep followed by Hi-vis sweep. Circulate & condition mud/hole (3.2 x Btm-up) from 11200'. Reciprocate & rotate (120 rpm) while circulating (560 gpm). Calculated ECD = 10.73 ppg Actual ECD = 11.10 ppg Monitor well-static. POOH with 20-25k drag to 10730'. Pull one more stand to 10640', drag increasing. RIH to 10730'. Establish circulation. Start backreaming from 10730' to 5161' (POOH without backreaming F/10200'-9700', 8400'-7000' & 5724'-5161'· hole tight @ 5161'). GPM = 550 @ 3750 psi RPM = 100 Torque = 7-12k FtLb TIH to 5330'. Pump sweep. Circulate & condition mud/hole at a reduced pump rate of 269 gpm with 730 psi (Number 1 mud pump down due to cracked fluid end module). Reciprocate & rotate (100 rpm) drill string while circulating. Continue backreaming from 5330' to 4732'. Encountered tight hole with erratic torque @ 4732'. Hole packed-off. Work pipe down to 4895'. Pipe free. Circulate btms-up from 4895'. GPM = 269 @ 730 psi RPM = 100 Torque = 7-12k FtLb Continue backreaming from 4895' up to the 9-5/8" casing shoe @ 4403'. GPM = 269 @ 730 psi RPM = 100-110 Torque = 7-12k FtLb CBU from 4403' with 269 gpm @ 720 psi. Reciprocate & rotate (110 rpm) while circulating. Slip & cut 58' of drill line. Reset & check C-O-M. Service TDS Pump a 25 bbl sweep. Circulate hole clean from 4403' with 590 gpm @ 2290 psi (Number 1 mud pump back on line). Reciprocate & rotate drill string (100 rpm) while circulating. Had Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Ho tJ rs NPT phase 3/3/2004 22:00 - 23:00 1.00 DRILL P INT1 a excessive amount of cuttings come over shakers from bottoms up from 4403'. 23:00 - 00:00 1.00 DRILL P INT1 TIH with drill string to 5336' (midnight depth) with no problems. 3/4/2004 00:00 - 02:30 2.50 DRILL P INT1 TI H with drill string from 5336' to 11125' with no problems. 02:30 - 05:00 2.50 DRILL P INT1 Establish circulation. Precautionary wash & ream last stand to bottom @ 11,200'. No fill. Pump 15 bbl Lo-vis sweep followed by 20 bbl Hi-vis sweep. Circulate & condition mud/hole with 580 gpm @ 3740 psi. Reciprocate & rotate (120 rpm) while circulating. Had a fair amount of cuttings come over shakers on bottoms up. Circulated a total of 2055 bbl. Calculated ECD after circulating = 10.43 ppg Actual ECD = 10.50 ppg 05:00 - 08:00 3.00 DRILL P INT1 Monitor well-static. POOH to 9-5/8" casing shoe @ 4403' with no problems. Max drag 15k. Monitor well- static. 08:00 - 09:30 1.50 DRILL P INT1 Continue POOH to top of BHA. 09:30 - 09:45 0.25 DRILL P INT1 SAFETY --- Held PJSM with Anadrill and all rig personnel on removing RA source and UD BHA. 09:45 - 12:30 2.75 DRILL P INT1 Finish POOH. Stand back 4" HWDP. UD MWD/LWD, Mud-motor & bit. Clear rig floor. 12:30 - 13:00 0.50 DRILL P INT1 Down-load MWD/LWD in pipe shed, then remove MWD tools from pipe shed. 13:00 - 13:30 0.50 PXA P ABAN Load 3-1/2" tubing stinger in pipe shed. R/U Tubing handling equipment on TDS & Rig Floor. 13:30 - 13:45 0.25 PXA P ABAN SAFETY--- Held PJSM with rig crew on P/U 3-1/2" tbg. 13:45 - 16:30 2.75 PXA P ABAN P/U 46 Jts of 3-1/2" 9.2# NSCT Tubing cement stinger (1429'). 16:30 - 22:00 5.50 PXA P ABAN TIH with 3-1/2" Tubing stinger on 4" DP to 11155' with no problems. 22:00 - 23:30 1.50 PXA P ABAN M/U TDS. Establish circulation with full returns - Wash to bottom @ 11200' - Reciprocate string & condition mud with 588 gpm @ 3445 psi. P/U 150k S/O 70k. Held PJSM with all personal regarding cementing operations & job procedure. 23:30 - 00:00 0.50 PXA P ABAN Stop pumps. Blow down TDS. P/U one Joint of 4" DP with safety valve, pup joint & Pump-in sub. Install cement hose. Dowell pump 5 bbl water & test lines to 3500 psi. 3/5/2004 00:00 - 01 :00 1.00 PXA P ABAN EOT @ 11200'. Set cement plug #1 as follows: Pump 10 bbl water ahead + 96.7 bbl (468 Sacks) 15.8 ppg Class "G" Tail Cement at 5 bpm + 2.4 BBLS water behind - Swap over to Rig pumps & displace with 90 bbl 9.3 ppg LSND Mud @ 6.5 bpm with 1450 psi - CIP @ 00:50 hrs - R/D cementing line & related equipment Cement Plug #1 Theoretically spotted From 11200'-10200' 01 :00 - 02:15 1.25 PXA P ABAN POOH to 10000'. 02: 15 - 04:00 1.75 PXA P ABAN M/U TDS. Establish circulation. Stage pumps to 580 gpm with 3500 psi ICP. Observed cement contaminated mud 34 bbl prior to having btms-up. Discard 150 bbl total of contaminated mud. Continue circulating & condition the mud for second cement plug. FCP = 2700 psi @ 580 gpm. Reciprocate & rotate (20 rpm) string while circulating. 104:00 - 04:30 0.50 PXA P Stop pumps. Blow down TDS. P/U 4" DP Pup Jt with safety valve & Pump-in sub. Install cement hose. Dowell pump 5 bbl Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Phase\ 3/5/2004 04:00 - 04:30 04:30 - 05: 15 0.50 PXA 0.75 PXA P P ABAN ABAN 05:15 - 06:00 06:00 - 08:30 0.75 PXA 2.50 PXA P P ABAN ABAN 08:30 - 09:00 0.50 PXA P ABAN 09:00 - 09:30 0.50 PXA P ABAN 09:30 - 10:30 10:30 - 12:00 1.00 PXA P 1.50 PXA P ABAN ABAN 12:00 - 12:30 0.50 PXA P ABAN 12:30 - 15:00 2.50 PXA P ABAN 15:00 - 18:30 3.50 PXA P ABAN 18:30 - 19:00 0.50 BOPSU P ABAN 19:00 - 22:00 3.00 BOPSU P ABAN 22:00 - 22:30 0.50 BOPSU P ABAN 22:30 - 00:00 1.50 CLEAN P ABAN 3/6/2004 00:00 - 00:30 0.50 CLEAN P ABAN 00:30 - 03:30 3.00 CLEAN P ABAN 03:30 - 08:00 4.50 CLEAN P ABAN 08:00 - 10:00 I 2.00 CLEAN P IABAN I Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 water & test lines to 3500 psi. EOT @ 10000'. Set cement plug #2 as follows: Pump 5 bbl water ahead + 96.7 bbl (468 Sacks) 15.8 ppg Class "G" Tail Cement at 5 bpm + 2.4 BBLS water behind - Swap over to Rig pumps & displace with 78.1 bb19.3 ppg LSND Mud @ 6 bpm with 1375 psi - CI P @ 05: 10 hrs - R/D cementing line & related equipment Cement Plug #2 Theoretically spotted From 10000'-9000' POOH to 8800'. Drop DP wiper dart down 4" DP. M/U TDS. Establish circulation. Stage pumps to 570 gpm with 2200 psi. Discard 180 bbl total of contaminated mud. Continue circulating & condition the mud for third cement plug. Reciprocate & rotate (20 rpm) string while circulating. Stop pumps. Blow down TDS. P/U 4" DP Pup Jt with safety valve & Pump-in sub. Install cement hose. Dowell pump 5 bbl water & test lines to 3500 psi. EOT @ 8800'. Set cement plug #3 as follows: Pump 5 bbl water ahead + 96.7 bbl (468 Sacks) 15.8 ppg Class "G" Tail Cement at 5 bpm + 2.4 BBLS water behind - Swap over to Rig pumps & displace with 64 bbl 9.3 ppg LSND Mud @ 10 bpm with 2300 psi - CIP @ 09:25 hrs - R/D cementing line & related equipment Cement Plug #3 Theoretically spotted From 8800'-7800" POOH to 7600'. Drop DP wiper dart down 4" DP. M/U TDS. Establish circulation. Stage pumps to 560 gpm with 2200 psi. Discard 165 bbl total of contaminated mud. Circulate & condition mud. Reciprocate & rotate (20 rpm) string while circulating. Monitor well-static. Pump slug. Blow down TDS. POOH with 4" DP to top of 3-1/2" tubing cement stinger. Finish POOH. UD 46 jts of 3-1/2" tubing. R/D 3-1/2" tubing handling equipment. Clear rig floor. Pull wear bushing. M/U Ported sub on 4" DP. RIH & flush out BOP Stack. UD Ported sub. R/U to test BOP's. M/U test plug on 4" DP and RIH. Test BOP rams, C/K Manifold + all surface related equipment to 4000/250 psi. Test Hydril Annular BOP to 3500/250 psi. Witness of BOP test waived by Chuck Scheeve with AOGCC. P/U test plug. Run & install wear bushing. Slip & cut 60' of drill line. Reset & check C-O-M. Service TDS. SAFETY --- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. M/U 8-3/4" Steerable Drilling assembly. Shallow Test MWD-OK. TIH with 8-314" Steerable Drilling assembly on 4" DP. Tag up @ 4430'. Work drill string down to 4500' (Hole tight). M/U TDS & establish circlation. Wash down to 4680'. Continue TIH. Tag up solid on obstruction @ 7090'. M/U TDS & establish circlation. Wash & ream from 7090' to 7605'. Hard cement encountered @ 7605'. Set down 20k on Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 NPT 3/6/2004 08:00 - 10:00 10:00 - 12:30 2.00 CLEAN P 2.50 CLEAN P ABAN ABAN 12:30 - 14:00 1 .50 CLEAN P ABAN 14:00 - 15:30 1.50 CLEAN P ABAN 15:30 - 16:30 1.00 CLEAN P ABAN 16:30 - 16:45 0.25 DRILL P INT1 16:45 - 18:30 1.75 DRILL P INT1 18:30 - 19:00 0.50 DRILL P INT1 19:00 - 20:30 1.50 DRILL P INT1 20:30 - 20:45 0.25 DRILL P INT1 20:45 - 00:00 3.25 DRILL P INT1 plug. Circulate to clean hole @ 7605' with 550 gpm at 2560 psi. Reciprocate & rotate (80 rpm) while circulating. Calculated ECD = 10.06 ppg Actual ECD = 10.39 ppg POOH to 4776' with no problems. Displace hole with fresh 9.3 ppg LSND mud with 400 gpm at 1100 psi (Had to displace slowly due to shortage of Vac Trucks). POOH to 9-5/8" casing shoe (4 stds) @ 4403'. CBU. Take ECD Baseline readings @ 590 gpm + 80 rpm = 9.78 ppg. TIH to 4510'. Stage pumps to 580 gpm wI 2900 psi. Orient TF to low side for Open Hole Sidetrack. Trenching hole from 4490'-4510'. Drill 8-3/4" intermediate hole (01 ST) from 4510' to 4683'. Sliding as required for inclination and azimuth. WOB = 10-15klbs RPM = 80 Torque off Btm = 6.5k FtLb, Torque on Btm = 7k FtLb GPM = 590 @ 2800 psi on Btm, 2650 psi off Btm P/U 101 k S/O 67k ROT 82k Backream each stand at 100 rpm and 550 gpm, reducing rate to 410 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 9.8 ppg Actual ECD = 10.5 ppg @ 4683'. ECD 0.70 ppg over calculated values. Circulate & condition mud/hole to reduce ECD's to below max allowable ECD value of 0.6 ppg over calculated. Drill 8-3/4" intermediate hole (01 ST) from 4683' to 5055'. Sliding as required for inclination and azimuth. WOB = 10-15klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 7.5k FtLb GPM = 590 @ 2800 psi on Btm, 2650 psi off Btm P/U 104k S/O 68k ROT 84k Backream each stand at 100 rpm and 550 gpm, reducing rate to 410 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 10.09 ppg Actual ECD = 10.8 ppg @ 5055'. ECD 0.71 ppg over calculated values. Circulate & condition mud/hole to reduce ECD's to below max allowable ECD value of 0.6 ppg over calculated. Drill 8-3/4" intermediate hole (01 ST) from 5055' to 5430'. Rotate & sliding as required for inclination and azimuth. IWOB = 10-15klbs !RPM = 80 i Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 3/6/2004 20:45 - 00:00 3.25 DRILL P INT1 Torque off Btm = 7k FtLb, Torque on Btm = 7.5k FtLb GPM = 590 @ 2800 psi on Btm, 2650 psi off Btm P/U 11 Ok S/O 70k ROT 86k Backream each stand at 100 rpm and 550 gpm, reducing rate to 410 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 10.13 ppg Actual ECD = 10.26 ppg @ 5430'. Drilling Time last 24 Hrs: ART = 1.65 Hrs AST = 0.83 Hrs. Survey & Connection time = 4.05 Hrs Formation tops: UG 4 @ 4610' MD UG 4A @ 4722' MD UG 3 @ 5605' MD 3n /2004 00:00 - 20:00 20.00 DRILL P INT1 Drill 8-3/4" intermediate hole (01 ST) from 5430' to 8264'. Rotate & sliding as required for inclination and azimuth. Note: Increase mud to 9.4 ppg @ 6400'. WOB = 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 8.8k FtLb GPM = 590 @ 3440 psi on Btm, 3240 psi off Btm P/U 135k S/O 79k ROT 101k Backream each stand at 80 rpm and 590 gpm, reducing rate to 440 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled Calculated ECD = 10.43 ppg Actual ECD = 11.23 ppg @ 8264'. 20:00 - 20:45 0.75 DRILL P INT1 Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3550 psi. Reciprocate & rotate (80 rpm) while circulating. 20:45-21:15 0.50 DRILL P INT1 Drill 8-3/4" intermediate hole (01 ST) from 8264' to 8329'. Rotate & sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 8.8k FtLb GPM = 590 @ 3750 psi on Btm, 3550 psi off Btm P/U 135k S/O 79k ROT 101k Calculated ECD = 10.43 ppg Actual ECD = 11.11 ppg @ 8329'. 21:15-21:45 0.50 DRILL P INT1 Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3550 psi. Reciprocate & rotate (80 rpm) while circulating. 21 :45 - 23:15 1.50 DRILL P INT1 Drill 8-3/4" intermediate hole (01 ST) from 8329' to 8515'. Rotate & sliding as required for inclination and azimuth. Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Descripti()hofOp~raÜQns: . . .. . ...... . HoÜrsTask Code NPT Phase 3/7/2004 21 :45 - 23:15 1.50 DRILL P INT1 WOB == 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm == 8.8k FtLb GPM = 590 @ 3750 psi on Btm, 3550 psi off Btm P/U 135k S/O 79k ROT 101 k 23: 15 - 00:00 0.75 DRILL P INT1 Calculated ECD = 10.43 ppg Actual ECD = 11.07 ppg @ 8515'. Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3550 psi. Reciprocate & rotate (80 rpm) while circulating. Drilling Time last 24 Hrs: ART = 7.48 Hrs AST = 4.02 Hrs. Survey & Connection time = 10.5 Hrs Formation tops: Fault #2 / UG 1 @ 6637' MD / 3540' KBTVD Ma @ 7233' MD /3766' KBTVD Mb1 @ 7337' MD / 3807' KBTVD Mb2 @ 7517' MD /3880' KBTVD Me @ 7680' MD / 3942' KBTVD Na @ 7780' MD /3979' KBTVD Nb @ 7830' MD / 3998' KBTVD Nc @ 7937' MD /4039' KBTVD OA @ 8158' MD /4122' KBTVD 3/8/2004 00:00 - 00:45 0.75 DRILL P INT1 Drill 8-3/4" intermediate hole (01 ST) from 8515' to 8608'. Rotate & sliding as required for inclination and azimuth. WOB == 10-20klbs RPM == 80 Torque off Btm = 7k FtLb, Torque on Btm == 8.1 k FtLb GPM = 590 @ 3780 psi on Btm, 3520 psi off Btm P/U 138k 8/0 79k ROT 103k Backream each stand at 80 rpm and 590 gpm, reducing rate to 440 gpm on down stroke. Pump a Lo/Hi vis sweep around every 300' - 500' drilled 00:45 - 01 :00 0.25 DRILL P INT1 Calculated ECD = 10.40 ppg Actual ECD == 11.00 ppg @ 8608'. Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3520 psi. Reciprocate & rotate (80 rpm) while circulating. Drill 8-3/4" intermediate hole (01 ST) from 8608' to 8702'. Rotate & sliding as required for inclination and azimuth. 01 :00 - 02:00 1.00 DRILL P INT1 WOB == 10-20klbs RPM == 80 Torque off Btm = 7k FtLb, Torque on Btm == 8.1 k FtLb GPM = 590 @ 3780 psi on Btm, 3520 psi off Btm P/U 138k S/O 79k ROT 103k Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 ··.Hours 3/8/2004 01 :00 - 02:00 1.00 DRILL P INT1 02:00 - 02:15 0.25 DRILL P INT1 02: 15 - 03:45 1.50 DRILL P INT1 03:45 - 04: 15 0.50 DRILL P INT1 04:15 - 05:15 1.00 DRILL P INT1 05:15 - 06:15 1.00 DRILL P INT1 06:15 - 07:00 0.75 DRILL P INT1 07:00 - 07:30 0.50 DRILL P INT1 07:30 - 10:00 2.50 DRILL P INT1 Calculated ECD = 10.39 ppg Actual ECD = 11.00 ppg @ 8702'. Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3520 psi. Reciprocate & rotate (80 rpm) while circulating. Drill 8-3/4" intermediate hole (01 ST) from 8702' to 8795'. Rotate & sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 8.1 k FtLb GPM = 590 @ 3780 psi on Btm, 3520 psi off Btm P/U 138k S/O 79k ROT 103k Calculated ECD = 10.39 ppg Actual ECD = 11.00 ppg @ 8795'. Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3520 psi. Reciprocate & rotate (80 rpm) while circulating. Drill 8-314" intermediate hole (01 ST) from 8795' to 8848'. Rotate & sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 8.1 k FtLb GPM = 590 @ 3780 psi on Btm, 3520 psi off Btm P/U 138k S/O 79k ROT 103k Calculated ECD = 10.63 ppg Actual ECD = 11.23 ppg @ 8848'. Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3520 psi. Reciprocate & rotate (80 rpm) while circulating. Drill 8-314" intermediate hole (01 ST) from 8848' to 8937'. Rotate & sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 80 Torque off Btm = 7k FtLb, Torque on Btm = 8.1 k FtLb GPM = 590 @ 3780 psi on Btm, 3520 psi off Btm P/U 138k S/O 79k ROT 103k Calculated ECD = 10.63 ppg Actual ECD = 11.12 ppg @ 8937' . Circulate & condition mud/hole to reduce ECD's with 590 gpm @ 3520 psi. Reciprocate & rotate (80 rpm) while circulating. Drill 8-3/4" intermediate hole (01 ST) from 8937' to 9130' TD. Rotate & sliding as required for inclination and azimuth. WOB = 10-20klbs RPM = 80 Torque off Btm = 7.5k FtLb, Torque on Btm = 9k FtLb G PM = 590 @ 3850 psi on Btm, 3725 psi off Btm P/U 140k S/O 79k ROT 105k Calculated ECD = 10.64 ppg Actual ECD = 11.16 ppg @ Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 From- To Hours 3/8/2004 07:30 - 10:00 2.50 DRILL P INT1 10:00 - 14:30 4.50 DRILL P INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 16:30 1.50 DRILL P INT1 16:30 - 20:00 3.50 DRILL P INT1 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 22:30 2.00 DRILL P INT1 22:30 - 23:30 1.00 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 3/9/2004 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 03:00 1.00 DRILL P INT1 03:00 - 06:00 3.00 DRILL P INT1 I 06:00 - 07:00 ! 1.00 I DRILL P INT1 I 9130'. Drilling Time last 24 Hrs: ART = 3.25 Hrs AST = 0.6 Hrs. Survey & Connection time = 3.65 Hrs Formation tops: OBa @ 8304' MD /4178' KBTVD OBb @ 8430' MD / 4225' KBTVD OBc @ 8577' MD / 4280' KBTVD OBd @ 8701' MD /4327' KBTVD Pump Lo-Hi Sweep + Lo-vis + Weighted sweep. Circulate & condition mud/hole (7 x Btm-up) with 590 gpm @ 3800 psi. Reciprocate & rotate (110 rpm) while circulating. Calculated ECD after circulating = 10.63 ppg Actual ECD = 10.90 ppg @ 9130'. Flow check-well static. POOH to 8720' (4 std). Hole started to swab + 20k overpull. TIH to 8813'. Establish circulation with partial returns only. TIH to bottom @ 9130'. Establish circulation. Stage pumps up very slowly to 590 gpm with 3800 psi + 100 rpm. Circulate & condition mud @ 9130'. Calculated ECD after circulating = 10.64 ppg Actual ECD = 10.90 ppg Backream out of hole from 9130' to 8047'. ECD = 11.20 ppg. 590 gpm with 3700 psi + 110 rpm. Mud viscosity increased to 150 while backreaming out (MBT increased from a 10 ppb to 15 ppb). Circulate & condition mud/hole to reduce mud viscosity with 590 gpm @ 3625 psi. Reciprocate & rotate (110 rpm) while circulating. Continue backream out of hole from 8047' to 6925' with 590 gpm with 3550 psi + 110 rpm. Mud viscosity increased to 170 while backreaming out. Circulate & condition mud/hole to reduce mud viscosity with 590 gpm @ 3550 psi. Reciprocate & rotate (110 rpm) while circulating. POOH to 6741' (2 std) with partial swabbing. Continue backreaming from 6741' to 6554' with 590 gpm with 3500 psi + 110 rpm. Continue backreaming from 6554' to 5709' with 590 gpm with 2850 psi + 110 rpm. Calculated ECD = 10.38 ppg Actual ECD = 11.42 ppg @ 5709'. Mud viscosity increased to 180 while backreaming out. Circulate & condition mud/hole to reduce mud viscosity with 550 gpm @ 2650 psi. Reciprocate & rotate (110 rpm) while circulating. ECD after circulating = 10.91 ppg. Continue backreaming from 5709' to 4403' with 550 gpm with 2650 psi + 110 rpm. Calculated ECD = 10.38 ppg Actual ECD = 10.64 ppg @ 4403'. Circulate & condition mud/hole @ 9-5/8" casing shoe with 550 Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: L-211 Common Well Name: L-211 Spud Date: 2/24/2004 Event Name: DRILL+COMPLETE Start: 2/23/2004 End: 3/13/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/16/2004 Rig Name: NABORS 9ES Rig Number: Date ·Froi11 ~.To 3/9/2004 06:00 - 07:00 1.00 DRILL P INT1 gpm @ 2150 psi. Reciprocate & rotate (100 rpm) while circulating. Baseball size clay balls obseved coming over shakers on Btms-up. ECD after circulating = 10.30 ppg. 07:00 - 07:30 0.50 DRILL P INT1 Service TDS. 07:30 - 10:00 2.50 DRILL P INT1 TIH to 9045' with no problems. Hole slick. 10:00 - 10: 15 0.25 DRILL P INT1 M/U TDS & establish circlation. Precautionary wash & ream from 9045' to 9130' TD. No fill on bottom. 10:15 - 13:00 2.75 DRILL P INT1 Pump Lo-Hi Sweep. Circulate & condition mud/hole (4 x Btm-up) with 590 gpm @ 3715 psi. Reciprocate & rotate (110 rpm) while circulating. Spot 284 bbl with 10 ppb G-Seal in open hole section. Calculated ECD after circulating = 9.94 ppg Actual ECD = 10.18 ppg @ 9130'. 13:00 - 17:00 4.00 DRILL P INT1 POOH to 9-5/8" casing shoe with no problems. Monitor well-static. Continue POOH to top of 4" HWDP. 17:00 - 17:15 0.25 DRILL P INT1 SAFETY n_ Held PJSM with Anadrill and all rig personnel regarding laying down BHA & unloading RA source from LWD tool.. 17:15 - 19:30 2.25 DRILL P INT1 Flush BHA with water. Stand back HWDP. L/D Anadrill directional equipment. 19:30 - 20:00 0.50 DRILL P INT1 Clear & clean rig floor. 20:00 - 20:30 0.50 BOPSU P COMP Flush BOP with water. Pull wear bushing. Install test plug. 20:30 - 22:00 1.50 BOPSU P COMP Change out top set of rams from 3.5" x 6" VBR to 7" casing rams. Test ram bonnet seals to 3500 psi. Pull test plug. 22:00 - 00:00 2.00 CASE P COMP Change elevator bails. R/U 7" casing Equipment. 3/1 0/2004 00:00 - 00:45 0.75 CASE P COMP Make dummy run with 7" casing hanger & landing joint. M/U Franks Fill-up tool onto TDS. 00:45 - 01 :00 0.25 CASE P COMP SAFETY--- Held PJSM with rig crew on casing running operations. 01 :00 - 07:00 6.00 CASE P COMP M/U 7" Shoetrack and check float equipment-OK. Run 7", 26 Ib/ft, L-80, BTC-M casing (48 Jts) to 2200' with full returns. Started pushing mud away beginning at approx 2200' - only getting back about 1/2 casing displacement. Average make-up torque = 7500 FtLb. 07:00 - 07:30 0.50 CASE P COMP CBU from 2200' with 5 bpm @ 200 psi. Had full returns while circulating. 07:30 - 12:30 5.00 CASE P COMP Continue running 7" casing (106 Jts) to 4400' (csg shoe) at 2 minutes/joint breaking circulation every other joint - getting approx 1/2 casing displacement volume back while running in. 12:30 - 13:30 1.00 CASE P COMP Establish circulation. Stage pumps to 5 bpm with 270 psi. CBU from 4400' with full returns while circulating. 13:30 - 00:00 10.50 CASE P COMP Continue running 7" casing (199 Jts) to 8261' at 2 minutes/joint breaking circulation every third joint - getting approx 1/2 casing displacement volume back while running in. CBU every 2000' @ 5 bpm while RIH with casing. 3/11/2004 00:00 - 03:30 3.50 CASE P COMP Finish running 7" 26 ppf L-80 BTCM casing (219 Jts total) to 9090' at 2 minutes/Joint breaking circulation every third Joint getting 1/2 casing displacement volume back while running in. Wash down last 6 Joints @ 5 bpm from 8842' to 9090'. Full returns while circulating. I 03:30 - 03:45 0.25 CASE P COMP M/U FMC Casing Hanger & Landing Joint. Break circulation. Stage pumps to 5 bpm @ 475 psi. Wash casing to bottom with Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Cöde 3/11/2004 03:30 - 03:45 0.25 CASE P COMP 03:45 - 04:00 0.25 CASE P COMP 04:00 - 06:00 2.00 CEMT P COMP 06:00 - 06: 15 06: 15 - 07:00 07:00 - 07:50 07:50 - 08:10 08:10 - 09:15 0.25 CEMT P 0.75 CEMT P COMP COMP 0.83 CEMT P COMP 0.33 CEMT P COMP 1.08 CEMT P COMP 09:15 - 12:00 2.75 CEMT P COMP 12:00 - 13:00 1.00 WHSUR P COMP 13:00 - 17:30 4.50 CLEAN P COMP 17:30 - 18:30 1.00 CLEAN P COMP 18:30 - 00:00 3/12/2004 00:00 - 01 :00 01 :00 - 02:00 ,02:00 - 03:00 5.50 CLEAN P COMP 1.00 CLEAN P 1.00 I CLEAN P 1.001 CLEAN ¡p COMP COMP ICOMP shoe at 9119' - full returns. Land out hanger. Hole slick. P/U 212k. SIO 84k. Note: Float Colar @ 9033'. RID Franks Tool. Install Dowell cement head & circulating lines. Break circulation. Stage pumps to 3 bpm with 350 psi for 10 minutes. Stage pumps to 5 bpm with 475 psi for 10 minutes. Stage pumps to 7 bpm with 610 psi. Circulating with full returns. Reciprocate casing 10'-15'. Circulate 3 x Btms-up (Annular vol = 251 bbl) & condition mud for cement job. PJSM with Nabors, OS, BP, Veco for cement operations. Continue circulating 7 bpm @ 550 psi while cementers mix slurry in batch mixer. No losses. 230 klbs up. 82 klbs dn. Switch to cementers. Pump 5 bbl CW100. Test lines to 4000 psi. Isolate leaking valve in standpipe manifold. Re-test to 4000 psi - OK. Pump 15 bbl CW100 followed by 35 bbls Mudpush II spacer @ 10.3 ppg - 3.5 bpm @ 400 psi. Release bottom plug. Pump 93.2 bbls (435 sx) Class G GasBlok slurry at 15.8 ppg. 5.5 bpm @ 550 psi.240 klbs up. 95 klbs dn. Flush cement line with 10 bbl water down flowline. Release top plug and switch to rig pumps. Displace with seawater at 7.5 bpm @ 260 psi initial. 7.5 bpm @ 700 psi @ 5000 stks away. Stop reciprocating at 5400 stks away - getting sticky. Land on ring. Slow to 2.5 bpm @ 710 psi at 5800 stks. Bump plug on schedule with 6020 stks (345.5 bbls). Full returns throughout cementing and displacing. Pressure up to 3500 psi and hold for 5 min to confirm casing integrity. CIP at 09:10 hrs. Blow Down All Lines, R/D Cement Head, UD Landing Jt, R/D Cement Equipment, Change elevator bails, flush BOP, clear rig floor of excess casing equipment. FMC installed 7' x 9 5/8" Pack-off, RILDS, torque to 450 ftlbs & test to 5000 PSI For 10 Minutes, OK. M/U 6-1/8" bit + 7" casing scraper. TIH on 4" DP to 8995'. Establish circulation. Wash down & tag up on 7" float collar @ 9033'. Pump HV sweep. Displace well with clean 9.3 ppg NaCI brine water. Pump rate 10 bpm with 1830 psi. Rotate (40 rpm) & reciprocate drill string while displacing well. P/U 170k S/O 81k Rot Wt 110k. Drill string torque = 10000 FtLb. POOH. UD 228 Jts of 4" DP from 9033' to 1900'. Note: Performed the following while UD 4" DP.: R/U 9ES mud pump on 7" x 9-5/8" annulus. Test lines to 3500 psi. Bullhead 100 bbls of 9.4ppg mud down annulus. Start at 0.5 bpm @ 300 psi. - complete at 2 bpm @ 600 psi. POOH. UD 4" DP to top of HWDP. TIH with 21 std of excess 4" DP from derrick. Slip & cut drill line. Reset & check crown-o-matic. Check Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Hours Task 3/12/2004 02:00 - 03:00 03:00 - 05:30 1.00 CLEAN P 2.50 CLEAN P COMP COMP 05:30 - 09:00 3.50 CLEAN P CaMP 09:00 - 09:15 0.25 EVAL P COMP 09:15 - 10:00 0.75 EVAL P COMP 10:00 - 15:30 5.50 EVAL P COMP 15:30 - 16:30 1.00 EVAL P COMP 16:30 - 16:45 0.25 EVAL P COMP 16:45 - 19:00 2.25 PERF P COMP 19:00 - 19:15 0.25 PERF P COMP 19:15 - 23:00 3.75 PERF P COMP 23:00 - 00:00 1.00 PERF P COMP 3/13/2004 00:00 - 00:15 0.25 PERF P COMP 00:15 - 01 :00 0.75 PERF P COMP 01 :00 - 03:00 2.00 PERF P COMP 03:00 - 04:30 1.50 PERF P COMP 04:30 - 05:30 1.00 PERF P COMP 05:30 - 07:30 2.00 PERF P COMP brakes. Finish LID 4" DP, HWDP, bit & casing scraper. Note: R/U Little Reds hot oiler and test lines to 3500 psi. Freeze protect 7" x 9-5/8" annulus. Bullhead 80 bbls of dead crude + 10 bbl of diesel @ 3 bpm with 950 psi FCP. Shut-in & secure wellhead wing valves. Pull wear bushing. R/U to test BOP's. M/U test plug on 4" DP and RIH. Test BOP rams (Did not test top rams-dressed with 7" csg rams), C/K Manifold + all surface related equipment to 250/4000 psi. Test Hydril Annular BOP to 250/3500 psi. Witness of BOP test waived by Lou Gramaldi with AOGCC. R/D test equipment. Pull test plug. Install wear bushing. SAFETY --- Held PJSM with Rig Crew & Schlumberger E-line crew regarding rigging up e-line logging equipment & lubricator. R/U Schlumberger e-line sheaves & related equipment. Install 7" lubricator in BOP. RIH with USIT log to 9013' WLM. Log up with USIT from 9013' to 6020' (TOC @ +/- 6750'). POOH. LID USIT logging tool. R/U test equipment. Pressure test 7" casing to 4000 psi for 30 minutes. Test was API. RID test equipment. Blow down lines. SAFETY ---. Held PJSM with Rig Crew & Schlumberger E-line crew regarding rigging up lubricator & the pressure testing of lubricator. R/U E-line BOP's & Pack-off on 7" lubricator. Pressure test to 1 000 psi-OK. SAFETY on Held PJSM with Rig Crew & Schlumberger E-line crew regarding P/U perf guns & perforating operations. M/U GR-CCL tool + Perf Guns for run #1. (35' of 4-1/2" HSD PowerJet charge guns @ 5 spf 72 degree phasing). Start RIH @ 21 :00 hrs. Log on depth. Perforate 7" casing (OBb sand zone) FI 8416'-8451' based on US IT log -Dated March 12, 2004. Monitor well after firing guns. Initial fluid losses 4 bph. NOTE: There is -19 between USIT log & MWD log. POOH with e-line & perf guns from 8451'. Well took 4 bbl fluid while pulling out. SAFETY _u Held PJSM with on coming Rig Crew & Schlumberger E-line crew regarding perforating operations. Fluid losses reduced to 0.8 bph. LID spent perf guns. 100% detonation on perf guns. M/U CCL tool + Perf Guns (40' of 4-1/2" HSD PowerJet charge guns @ 5 spf 72 degree phasing) for run #2. RIH. Log on depth. Peforate 7" casing (OBa sand zone will have 75' of perfs) FI 8326'-8366' based on USIT log -Dated March 12, 2004. Monitor well after firing guns. Initial fluid losses at 12 bph reducing to 4 bph. POOH with e-line. LID spent guns. Had 1 00% detonation. SWS re-head MH-22 type logging head into rope socket. Fluid losses to well @ 4 bph. Total losses = 10 bbl. M/U CCL tool + Perf Guns (35' Perf Guns) for run #3. RIH. Log on depth. Peforate 7" casing (OBa sand zone) F/8291'-8326'. Monitor well after firing guns. Fluid losses at 2 bph. Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 3/13/2004 07:30 - 08:30 08:30 - 09:30 09:30 - 11 :30 11 :30 - 13:00 13:00 - 14:30 14:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 3/14/2004 00:00 - 00:30 00:30 - 12:30 1.00 PERF P 1.00 PERF P COMP COMP 2.00 PERF P COMP 1.50 PERF P 1.50 PERF P COMP COMP 4.50 PERF P COMP 1.00 PERF P 1.00 PERF P COMP COMP 2.00 PERF P COMP 1.00 PERF P COMP 0.50 PERF P COMP 12.00 CLEAN P COMP 12:30-14:00 1.50 CLEAN COMP 14:00 - 14:30 0.50 BOPSU COMP 14:30 - 15:30 1.00 BOPSU COMP 15:30 - 16:30 1.00 BOPSU COMP 16:30 - 18:00 COMP 18:00-18:15 COMP 18:15 - 19:00 COMP . .... ... ... ..... . D~scriptibnof oþeration~. POOH with e-line. UD spent guns. Had 100% detonation. SWS re-head MH-22 type logging head into rope socket. M/U CCL tool + Perf Guns (40' Perf Guns) for run #4. RIH. Log on depth. Peforate 7" casing (OA sand zone will have 70' of perfs) F/ 8181'-8221'. Monitor well after firing guns. Fluid losses at 2 bph. POOH with e-line. L/D spent guns. Had 100% detonation. SWS re-head MH-22 type logging head into rope socket. Fluid losses at 2 bph. M/U CCL tool + Perf Guns (30' Perf Guns) for run #5. RIH. Log on depth. Peforate 7" casing (OA sand zone) F/8151'-8181'. Monitor well after firing guns. Fluid losses remained constant at 2 bph. Note: Had to make several correlation passes before a clear indication of the casing collars was picked up on the CCL log due to excess gun debris in hole. POOH with e-line. L/D spent guns. Had 100% detonation. SWS re-head MH-22 type logging head into rope socket. Fluid losses at 2 bph. M/U CCL tool + Perf Guns (10' Perf Guns) for run #6 (Final Run). RIH. Log on depth. Peforate 7" casing (Mb1 sand zone) F/ 7341'-7351'. Monitor well after firing guns. Fluid losses remaining constant at 2 bph. POOH with e-line. Fluid losses to well remaining constant at 2 bph. Total fluid losses to perfs = 47 bbl. Finish POOH with e-line. UD spent perf guns. Had 100% detonation. M/U 6.0" GR-Junk Basket. RIH to 9021'. POOH. Recovered a significant amount of gun debris. Made an additional 4 GR-JB runs, recovering a total of 22 Lbs of gun debris with metal fragments. Fluid losses to well remaining constant at 2 bph. RID SWS e-line & lubricator equipment. Drain BOP stack. Pull wear bushing. Install test plug. Change top rams from 7" casing rams to 3.5" x 6" VBR. R/U to test top pipe rams with 4" DP. Test top pipe rams to 250/4000 psi. Test C/K HCR's & Manual valves to 250/4000 psi. All test were API. R/D test equipment. Pull test plug. Change elevator bails. Make dummy run with 4.5" x 11" FMC tubing hanger. R/U to run 3.5" x 4.5" completion string. R/U Nabors tubing running & Torque-Turn equipment. SAFETY--- Held PJSM with Rig Crew, SChlumbergerTCP, Baker Oil Tools Rep & Nabors Tubing Tong Service Rep regarding picking up TCP guns & tubing running operations. M/U Schlumberger SXAR Gun Drop assembly consisting of 90' x 4-1/2" HSD PowerJet 4505 HMX 38.8 5 spf @ 72 deg phasing + 78' of blanks + Auto-release SXAR + TCF Firing Printed: 3/22/2004 8:05:32 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/14/2004 18:15-19:00 19:00 - 00:00 3/15/2004 00:00 - 10:00 10:00 - 10:30 10:30 - 10:45 10:45 - 11 :30 11 :30 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 21 :00 i 121 :00 - 21 :30 L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours Task Code NPT Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 . Descriptionqf.QperatiÒns·· COMP COMP Head + Debris Sub. Total length = 179.99'. Change over to run 3.5" tubing. RIH with 3.5" Tail-pipe & X-nipple assembly + 3.5" 9.3# L-80 TCII tubing with Baker 7" Production Packers & GLM assemblies. Total length = 1388.76'. MIU Torque on 3.5" Tubing = 2300 Ft/Lb using JetLube Seal Guard pipe dope. 10.00 RUNCO P Fluid losses to well decreased to 1.6 bph. Total fluid losses to perfs = 90 bbl. COMP Change over tubing handling equipment to run 4.5" tubing. Continue RIH to 8777' with the SXAR Gun Drop assembly + 3.5" tubing wi 7" Production Packer assemblies on 4.5" 12.6# L-80 TC-II production tubing. M/U torque on 4.5" tubing = 3850 FtlLb using Jet-Lube Seal Guard pipe dope. COMP M/U FMC 11" x 4.5" Tubing Hanger. Land tubing hanger placing bottom of production string assembly @ 8801' RKB. NOTE: Top connection on tubing hager is 4-1/2" TCII. Held PJSM with Drill Crew & SWS e-line crew. COMP SAFETY--- Held PJSM with Rig Crew & SWS personnel on rigging up e-line, lubricator & related pressure control equipment. COMP R/U SWS e-line & lubricator equipment. COMP SWS RIH with GR-CCL tool to 8334'. Run correlation pass from 8334' to 7158'. POOH with e-line. Correlation log indicates that the tubing string needs to be moved up +/- 16' to place TCP guns on depth for perforating 7" casing in the OBd zone from 8691' to 8781' based on US IT log dated March 12,2004 COMP R/D SWS e-line & related equipment. COMP Pull tubing hanger to rig floor. LID 2 each 4.5" 12.6# L-80 TCII tubing pup joints (15.50' total) from string. M/U & Land tubing hanger in wellhead. Run in Lock Down screws. Note: Bottom of production string assembly @ 8785.95' RKB. P/U 105k S/O 65k Fluid losses to well @ 1.6 bph Total fluid losses to perfs = 109 bbl. COMP R/D Tubing running equipment. COMP Rig up to reverse circulate. Reverse circulate down 7" annulus & up tubing string with 160 bbl of clean 9.3 ppg NaCI followed by 6 bbls of 9.3 ppg corrosion inhibited brine followed by 137 bbl clean 9.3 ppg NaCI @ 3 bpm w/300 psi. COMP R/D tubing pump-in sub. Drop Ball-rod w/ rollers & allow to gravitate on seat while LID the 4.5" Tubing Landing Jt. COMP Pressure up on tubing to 2800 psi to set lower "S-3" packer. Continue pressuring tubing to 4200 psi to set the three "Premier" packers. Hold test for 30 minutes. Test was API. Manually bled off tubing pressure to 2000 psi. Pressure up 4.5 x 7" annulus to 4000 psi. Hold test for 30 minutes. Test was API. Manually bled off pressure on both tubing & annulus to 0 psi. Pressure up 4.5" x 7" annulus to 2700 psi & sheared DCK valve in the 4.5" GLM @ 7094'. Manually bled off pressure to 0 psi on tubing & annulus. COMP Pump out BOP. FMC install TWCV. Test TWCV from below to 1.00 1.00 0.50 RUNCO 2.00 RUNCO 0.50 2.00 0.50 RUNCO Printed: 3/22/2004 8:05:32 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-211 L-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/23/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 2/24/2004 End: 3/13/2004 Hours Task. 3/15/2004 21 :00 - 21 :30 0.50 P COMP 21 :30 - 22:30 1.00 BOPSU P COMP 22:30 - 00:00 1.50 WHSUR P COMP 3/16/2004 00:00 - 03:30 3.50 WHSUR P COMP 03:30 - 04:00 0.50 WHSUR P COMP 04:00 - 09:00 5.00 WHSUR P COMP 09:00 - 10:00 1.00 WHSUR P COMP 1000 psi-OK. PJSM. N/D BOP's. Set back & secure. Snake tree & adapter flange into cellar, thaw-out same. N/U FMC 11" 5K x 4-1/16" 5K Tubing head adapter & CIW 4-1/16" 5K Production Tree. Test tubing head adapter & tree to 5000 psi. R/U DSM lubricator & pull TWCV. Held PJSM with Rig Crew & Little Red Hot Oil Service rep regarding freeze protecting operations. R/U Hot Oil & test lines to 3000 psi. Freeze protect 4.5" x 7" annulus. Reverse circulate 130 bbl of diesel down 4.5" x 7" annulus @ 2 bpm with 1050 psi. Let well U-Tube & equalize. RU DSM lubricator, install BPV and VR plugs in upper annulus valves Secure tree and prepare cellar for rig move. 10:00 - 12:00 2.00 WHSUR P COMP RIG RELEASED @ 12:00 hrs Printed: 3/22/2004 8:05:32 AM Generated 3/23/2004 11 :31 AM Page 1 of 2 L-211\L-211\L-211\L-211 SurveyEditor Ver 3.1 RT -SP3.03-HF4.00 Sld( do31 rt-546 ) 500.00 1.07 68.63 499.85 422.85 -1.19 10.45 4.98 9.18 1.16 -1.13 9.94 5978265.01 583107.41 N 70 212.129 W 149 1930.898 600.00 0.40 2.21 599.85 522.85 -1.13 11.62 5.67 10.06 0.98 -0.67 -66.42 5978265.71 583108.29 N 70212.135 W 149 1930.873 700.00 1.41 324.59 699.83 622.83 0.38 13.16 7.02 9.36 1.12 1.01 -37.62 5978267.05 583107.58 N 70 212.149 W 149 1930.893 800.00 3.96 320.38 799.72 722.72 5.05 17.84 10.68 6.45 2.56 2.55 -4.21 5978270.68 583104.62 N 70 212.185 W 1491930.978 900.00 7.10 318.48 899.24 822.24 14.64 27.48 17.97 0.15 3.14 3.14 -1.90 5978277.90 583098.24 N 70 21 2.256 W 149 1931.162 1000.00 10.69 321.47 998.02 921.02 30.04 42.93 29.86 -9.73 3.62 3.59 2.99 5978289.68 583088.23 N 70 21 2.373 W 149 1931.451 1100.00 16.08 324.12 1095;27 1018.27 53.16 66.07 48.35 -23.63 5.42 5.39 2.65 5978308.01 583074.12 N 70 21 2.555 W 1491931.857 1200.00 22.27 330.16 1189.68 1112.68 85.92 98.87 76.04 -41.20 6.49 6.19 6:04 5978335.50 583056.26 N 7021 2.827 W 1491932.371 1300.00 27.33 333.54 1280.44 1203.44 127.52 140.80 113.05 -60.87 5.25 5.06 3.38 5978372.29 583036.18 N 70 21 3.191 W 149 1932.946 1400.00 31.81 335.40 1367.39 1290.39 176.17 190.13 157.59 -82.08 4.57 4.48 1.86 5978416.58 583014.48 N 70 21 3.629 W 149 1933.565 1500.00 38.93 335.56 1448.88 1371.88 233.05 247.98 210.22 -1 06.08 7.12 7.12 0.16 5978468.94 582989.90 N 70 214.147 W 1491934.267 1592.82 46.63 336.25 1516.96 1439.96 294.90 310.97 267.74 -131.77 8.31 8.30 0.74 5978526.17 582963.57 N 70214.713 W 149 1935.018 1685.52 53.63 330.82 1576.37 1499.37 365.19 382.05 331.27 -163.59 8.78 7.55 -5.86 5978589.34 582931.05 N 70 21 5.338 W 149 1935.948 1779.00 61.65 328.10 1626.37 1549.37 443.85 460.95 399.17 -203.75 8.92 8.58 -2.91 5978656.78 582890.15 N 70 216.005 W 149 1937.122 1873.02 60.15 328.95 1672.10 1595.10 525.84 543.10 469.23 -246.64 1.78 -1.60 0.90 5978726.35 582846.48 N 70 21 6.694 W 149 19 38.375 1966.40 61.91 328.75 1717.32 1640.32 607.35 624.79 539.14 -288.90 1.89 1.88 -0.21 5978795.79 582803.45 N 70 217.382 W 149 1939.610 2060.26 64.99 329.38 1759.27 1682.27 691.09 708.74 611.16 -332.05 3.34 3.28 0.67 5978867.31 582759.51 N 70 218.090 W 149 1940.872 2154.46 65.57 330.59 1798.67 1721.67 776.33 794.31 685.25 -374.85 1.32 0.62 1.28 5978940.91 582715.90 N 70218.819 W 1491942.123 2247.57 66.78 330.94 1836.28 1759.28 861.07 879.48 759.57 -416.45 1.34 1.30 0.38 5979014.77 582673.48 N 70219.550 W 149 1943.339 2342.11 65.62 331.08 1874.43 1797.43 947.10 965.98 835.23 -458.37 1.23 -1.23 0.15 5979089.95 582630.73 N 70 21 10.294 W 149 1944.564 2434.98 65.67 331.02 1912.73 1835.73 1031.23 1050.58 909.27 -499.33 0.08 0.05 -0.06 5979163.52 582588.96 N 70 21 11.022 W 149 1945.761 2528.59 66.95 331.20 1950.34 1873.34 1116.46 1136.30 984.32 -540.74 1.38 1.37 0.19 5979238.10 582546.72 N 70 21 11.760 W 149 1946.972 2621.30 68.05 330.91 1985.81 1908.81 1201.64 1221.96 1059.27 -582.19 1.22 1.19 -0.31 5979312.58 582504.44 N 70 21 12.497 W 149 1948.184 2714.89 67.42 330.84 2021.27 1944.27 1287.79 1308.57 1134.93 -624.35 0.68 -0.67 -0.07 5979387.76 582461.45 N 70 21 13.241 W 149 1949.416 2808.25 66.70 330.82 2057.66 1980.66 1373.32 1394.54 1210.00 -666.25 0.77 -0.77 -0.02 5979462.36 582418.72 N 70 21 13.979 W 149 1950.641 2900.68 67.27 331.55 2093.80 2016.80 1457.90 1479.62 1284.54 -707.26 0.95 0.62 0.79 5979536.43 582376.90 N 70 21 14.713 W 149 1951.840 2993.04 66.57 331.86 2130.01 2053.01 1542.29 1564.58 1359.36 -747.53 0.82 -0.76 0.34 5979610.79 582335.80 N 70 21 15.448 W 149 1953.017 3086.65 67.43 332.47 2166.58 2089.58 1627.78 1650.75 1435.56 -787.76 1.10 0.92 0.65 5979686.53 582294.73 N 7021 16.198 W 149 1954.193 3180.77 66.94 332.60 2203.08 2126.08 1713.79 1737.51 1512.53 -827.78 0.54 -0.52 0.14 5979763.05 582253.87 N 70 21 16.955 W 149 1955.363 3273.33 66.36 332.10 2239.77 2162.77 1798.07 1822.49 1587.81 -867.21 0.80 -0.63 -0.54 5979837.87 582213.61 N 70 21 17.695 W 149 1956.516 3366.79 67.09 332.65 2276.70 2199.70 1883.21 1908.34 1663.87 -907.02 0.95 0.78 0.59 5979913.49 582172.96 N 70 21 18.443 W 149 19 57.680 3459.72 66.65 332.45 2313.20 2236.20 1967.93 1993.80 1739.71 -946.41 0.51 -0.47 -0.22 5979988.88 582132.73 N 70 2119.189 W 1491958.832 3554.01 66.00 331.97 2351.06 2274.06 2053.60 2080.15 1816.11 -986.67 0.83 -0.69 -0.51 5980064.81 582091.63 N 70 21 19.940 W 149200.009 3646.99 66.44 333.24 2388.56 2311.56 2137.93 2165.24 1891.65 -1025.82 1.34 0.47 1.37 5980139.91 582051.65 N 70 21 20.683 W 149201.154 3741.39 65.89 333.10 2426.70 2349.70 2223.41 2251.59 1968.70 -1064.79 0.60 -0.58 -0.15 5980216.52 582011.83 N 70 2121.441 W 149 20 2.293 3834.88 67.59 334.06 2463.62 2386.62 2308.33 2337.47 2045.62 -1103.00 2.05 1.82 1.03 5980293.00 581972.77 N 70 21 22.197 W 149203.411 3927.92 67.20 334.76 2499.38 2422.38 2393.07 2423.37 2123.09 -1140.10 0.81 -0.42 0.75 5980370.04 581934.82 N 70 21 22.959 W 149204.496 4019.69 66.35 334.70 2535.57 2458.57 2476.19 2507.70 2199.35 -1176.10 0.93 -0.93 -0.Q7 5980445.90 581897.98 N 70 21 23.709 W 149 20 5.548 4112.33 67.14 334.49 2572.15 2495.15 2560.11 2592.81 2276.23 -1212.62 0.88 0.85 -0.23 5980522.36 581860.62 N 70 21 24.465 W 149206.616 4206.36 66.52 334.82 2609.15 2532.15 2645.33 2679.26 2354.36 -1249.62 0.73 -0.66 0.35 5980600.06 581822.75 N 70 21 25.233 W 149207.698 4299.34 66.44 335.11 2646.25 2569.25 2729.30 2764.51 2431.60 -1285.70 0.30 -0.09 0.31 5980676.90 581785.83 N 70 21 25.993 W 149208.753 4354.49 67.13 335.69 2667.99 2590.99 2779.15 2815.20 2477.68 -1306.80 1.58 1.25 1.05 5980722.74 581764.22 N 70 21 26.446 W 149 20 9.370 4439.26 65.00 336.71 2702.38 2625.38 2855.15 2892.67 2548.57 -1338.07 2.74 -2.51 1.20 5980793.26 581732.17 N 70 21 27.143 W 14920 10.285 4515.13 66.14 335.36 2733.76 2656.76 2922.95 2961.75 2611.69 -1366.13 2.21 1.50 -1.78 5980856.06 581703.41 N702127.764 W 14920 11.106 4608.83 65.96 336.05 2771.80 2694.80 3007.09 3047.38 2689.73 -1401.36 0.70 -0.19 0.74 5980933.71 581667.32 N 70 21 28.531 W 1492012.136 Minimum Curvature 1 Lubinski 325.000' N 0.000 ft, E 0.000 ft Rotary Table 77.00 ft relative to MSL 48.50 ft relative to MSL 25.040' 57558.303 nT 80.821 ' March 08, 2004 BGGM 2003 True North +25.040' Well Head Survey 1 DLS Computation Method: Vertical Section Azimuth: Vertlcel Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed / Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Modal: North Reference: Totel Corr Mag North .> True North: Local Coordinates Referenced To: Report Date: 10·Mar·04 Client: BP Exploration Alaska Field: Prudhoe Bay Unit· WOA Structure/Slot: L·PAD/L·211 Well: L·211 Borehole: L -211 UWI/API#: 500292319700 Survey Name / Date: L·211 1 March 10, 2004 TortI AHD/DDI/ERD ratio: 160.979' 17227.33 ft 16.374/1.608 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70 21 2.080, W 14919 31.167 Location Grid N/E Y/X: N 5978259.930 ftUS, E 583098.290 ftUS Grid Convergence Angle: +0.63539136' Grid Scale Factor: 0.99990784 Schlumberuep L-211 Survey Report bp ) ) Generated 3/23/2004 11 :31 AM Page 2 of 2 L-211\L-211\L-211\L-211 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) 5172.08 68.19 337.35 2988.47 2911.47 3513.99 3567.17 3170.90 -1597.95 0.46 -0.21 -0.44 5981412.62 581465.43 N 70 21 33.263 W 149 20 17.886 5264.65 67.86 336.43 3023.11 2946.11 3598.00 3653.01 3249.86 -1631.64 0.99 -0.36 -0.99 5981491.19 581430.87 N 70 21 34.040 W 1492018.872 5358.04 68.23 334.45 3058.03 2981.03 3683.17 3739.63 3328.63 -1667.64 2.01 0.40 -2.12 5981569.55 581394.00 N 70 21 34.814 W 1492019.925 5450.86 67.61 334.31 3092.92 3015.92 3768.04 3825.64 3406.19 -1704.83 0.68 -0.67 -0.15 5981646.68 581355.95 N 70 21 35.577 W 149 20 21.013 5544.52 67.49 333.86 3128.69 3051.69 3853.51 3912.20 3484.04 -1742.66 0.46 -0.13 -0.48 5981724.11 581317.27 N 70 2136.343 W 1492022.120 5637.63 68.26 333.71 3163.76 3086.76 3938.75 3998.46 3561.42 -1780.76 0.84 0.83 -0.16 5981801.05 581278.31 N 70 21 37.104 W 1492023.234 5730.08 68.14 332.55 3198.09 3121.09 4023.73 4084.30 3637.99 -1819.56 1.17 -0.13 -1.25 5981877.18 581238.67 N 70 2137.857 W 149 2024.369 5823.98 68.05 333.65 3233.12 3156.12 4109.98 4171.42 3715.69 -1858.97 1.09 -0.10 1.17 5981954.43 581198.40 N 70 21 38.621 W 1492025.522 5917.88 68.11 334.27 3268.18 3191.18 4196.02 4258.53 3793.95 -1897.22 0.62 0.06 0.66 5982032.26 581159.30 N 70 21 39.390 W 1492026.641 6010.83 67.52 335.03 3303.28 3226.28 4280.87 4344.60 3871.73 -1934.07 0.99 -0.63 0.82 5982109.62 581121.59 N 70 2140.155 W 1492027.719 I 6105.14 67.90 334.57 3339.05 3262.05 4366.86 4431.86 3950.69 -1971.22 0.60 0.40 -0.49 5982188.15 581083.57 N 702140.932 W 1492028.806 6199.56 67.77 334.73 3374.67 3297.67 4453.07 4519.30 4029.71 -2008.66 0.21 -0.14 0.17 5982266.74 581045.26 N 7021 41.709 W 1492029.901 6292.81 67.83 333.87 3409.90 3332.90 4538.27 4605.64 4107.51 -2046.10 0.86 0.06 -0.92 5982344.11 581006.96 N 70 21 42.474 W 1492030.997 6386.89 67.31 333.79 3445.80 3368.80 4624.20 4692.60 4185.56 -2084.45 0.56 -0.55 -0.09 5982421.72 580967.75 N702143.241 W 1492032.119 6481.19 68.07 333.54 3481.60 3404.60 4710.45 4779.84 4263.74 -2123.16 0.84 0.81 -0.27 5982499.47 580928.19 N 70 2144.010 W 1492033.251 6575.78 68.23 335.09 3516.80 3439.80 4797.08 4867.63 4342.86 -2161.21 1.53 0.17 1.64 5982578.15 580889.26 N 7021 44.788 W 1492034.364 6668.81 67.62 336.06 3551.77 3474.77 4881.82 4953.84 4421.35 -2196.85 1.17 -0.66 1.04 5982656.23 580852.75 N 70 21 45.560 W 149 20 35.407 6762.78 68.27 337.04 3587.05 3510.05 4967.15 5040.94 4501.25 -2231.51 1.19 0.69 1.04 5982735.74 580817.21 N 70 21 46.345 W 1492036.422 6856.15 68.04 337.80 3621.80 3544.80 5051.79 5127.60 4581.27 -2264.79 0.79 -0.25 0.81 5982815.38 580783.05 N 70 2147.132 W 1492037.395 6950.27 67.77 336.57 3657.20 3580.20 5137.03 5214.81 4661.66 -2298.60 1.24 -0.29 -1.31 5982895.37 580748.35 N 70 2147.923 W 1492038.385 7043.11 67.21 334.15 3692.75 3615.75 5221.39 5300.57 4739.61 -2334.35 2.48 -0.60 -2.61 5982972.92 580711.75 N 70 21 48.689 W 149 20 39.431 7135.60 67.22 329.92 3728.58 3651.58 5305.99 5385.84 4814.90 -2374.33 4.22 0.01 -4.57 5983047.75 580670.94 N 70 21 49.430 W 1492040.601 7228.74 67.69 326.54 3764.30 3687.30 5391.86 5471.86 4888.02 -2419.62 3.39 0.50 -3.63 5983120.36 580624.85 N 70 21 50.149 W 1492041.926 7321.96 66.29 321.69 3800.76 3723.76 5477.62 5557.65 4957.52 -2469.87 5.02 -1.50 -5.20 5983189.29 580573.83 N 70 21 50.832 W 1492043.396 7415.27 65.44 317.71 3838.92 3761.92 5562.39 5642.80 5022.45 -2524.93 4.00 -0.91 -4.27 5983253.60 580518.07 N 702151.470 W 1492045.007 7508.97 67.82 317.54 3876.09 3799.09 5647.68 5728.81 5085.99 -2582.89 2.55 2.54 -0.18 5983316.48 580459.40 N 70 21 52.095 W 1492046.703 7602.31 67.70 315.97 3911.42 3834.42 5733.18 5815.20 5148.92 -2642.08 1.56 -0.13 -1.68 5983378.75 580399.52 N 70 21 52.714 W 1492048.434 7694.70 67.62 315.84 3946.53 3869.53 5817.56 5900.66 5210.29 -2701.55 0.16 -0.09 -0.14 5983439.45 580339.39 N 7021 53.317 W 1492050.174 7788.97 68.13 315.09 3982.04 3905.04 5903.69 5987.98 5272.54 -2762.80 0.91 0.54 -0.80 5983501.01 580277.46 N 70 2153.929 W 1492051.966 7882.22 67.15 315.71 4017.51 3940.51 5988.71 6074.22 5333.94 -2823.35 1.22 -1.05 0.66 5983561.73 580216.24 N 70 2154.533 W 149 20 53.738 7976.10 68.17 314.17 4053.20 3976.20 6074.21 6161.05 5395.27 -2884.81 1.87 1.09 -1.64 5983622.37 580154.10 N 70 2155.136 W 1492055.536 8068.61 67.99 314.66 4087.73 4010.73 6158.57 6246.88 5455.33 -2946.11 0.53 -0.19 0.53 5983681.75 580092.14 N 70 21 55.726 W 1492057.329 8162.57 67.71 315.38 4123.16 4046.16 6244.28 6333.90 5516.89 -3007.63 0.77 -0.30 0.77 5983742.61 580029.96 N 70 2156.331 W 1492059.129 8256.76 67.84 315.97 4158.79 4081.79 6330.32 6421.09 5579.27 -3068.55 0.60 0.14 0.63 5983804.30 579968.35 N 70 21 56.945 W 14921 0.912 8349.97 68.27 316.63 4193.62 4116.62 6415.78 6507.55 5641.77 -3128.28 0.80 0.46 0.71 5983866.14 579907.94 N 70 2157.559 W 149 21 2.659 8441.73 68.11 314.97 4227.72 4150.72 6499.87 6592.74 5702.84 -3187.67 1.69 -0.17 -1.81 5983926.54 579847.88 N 70 2158.160 W 149214.397 8535.77 68.29 314.50 4262.64 4185.64 6585.79 6680.05 5764.30 -3249.70 0.50 0.19 -0.50 5983987.30 579785.18 N 70 2158.764 W 14921 6.212 8629.64 67.44 314.75 4298.01 4221.01 6671.32 6767.01 5825.38 -3311.58 0.94 -0.91 0.27 5984047.68 579722.63 N 70 21 59.364 W 149 21 8.023 8722.62 67.62 314.46 4333.55 4256.55 6755.83 6852.93 5885.71 -3372.76 0.35 0.19 -0.31 5984107.33 579660.80 N 70 21 59.957 W 149219.813 8815.42 68.12 315.57 4368.51 4291.51 6840.49 6938.89 5946.51 -3433.52 1.23 0.54 1.20 5984167.45 579599.36 N 70 22 0.555 W 14921 11.591 8908.53 67.27 315.69 4403.84 4326.84 6925.48 7025.03 6008.09 -3493.76 0.92 -0.91 0.13 5984228.35 579538.45 N70221.160 W1492113.353 9002.05 66.06 315.81 4440.89 4363.89 7010.23 7110.90 6069.60 -3553.68 1.30 -1.29 0.13 5984289.18 579477.86 N 70 221.765 W 1492115.107 9057.32 65.34 315.27 4463.63 4386.63 7059.92 7161.27 6105.55 -3588.96 1.58 -1.30 -0.98 5984324.74 579442.19 N70222.118 W1492116.139 9130.00 65.34 315.27 4493.96 4416.96 7125.02 7227.33 6152.48 -3635.45 0.00 0.00 0.00 5984371.14 579395.19 N 70 22 2.580 W 14921 17.500 Leaal DescriDtion: Northina IV} rftUSl Eastina (XI rftUSl Surface: 2539 FSL 3816 FEL S34 T12N R11E UM 5978259.93 583098.29 BHL: 3410FSL2160FELS28T12NR11EUM 5984371.14 579395.19 ) .) ) TREE = WELLHEAD = A CTUA TOR = KB. B..EV ::: BF. ELEV ::: KOP= Max An Ie = Datum MD = Datum TVD = 4-1/16" CIW FMC NA 77.0' 48.5' 200' 7868' xxxx' xxxx' SS L-211 SAFETY NOTES: GLM'S @ STA#1- #5 ARE 3-1/2" X 1-1/2" MMG-W WHICH ARE W ATERFLOOD MANDRELS. DRAFT - FROM DRILLING I 3-1/2"TBG W/RA I\1A..RKffil 4-1/2" HES X NIP, 10= 3.813" Minimum ID = 2.813" 3-1/2" HES X NIPPLE MO 7095 7303 8104 8227 8311 8489 TVO 3713 3793 4101 4148 4179 4245 WATERFLOOO MANDRB..S OEV TYÆ VLV LATCH 67 KBG2 OCK BEK 67 MMG-W DUM RK 68 MMG-W DUM RK 68 MMG- W DUM RK 68 MMG- W DUM RK 68 MMG- W DUM RK FúRT DATE YES 03/16/04 03/16/04 03/16/04 03/16/04 03/16/04 03/16/04 9-5/8" CSG, 40#, L-80, ID = 8.835" I 4-1/2" HES X NIP, 10= 3.813" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 17" I\1A..RKERJOINTW/RA TAG 4-1/2" X 3-112" XO, 10 = 2.992" 7" X 3-1/2" BKR PRBV1lffi A<R, 10 = 2.87" 3-1/2" HES X NIP, ID = 2.813" I 17" MARKffi JOIf\IT W/ RA TAG I 3-1/2" HES X NIP, 10 = 2.813" 7" X 3-1/2" BKR PRBV1lffi A<R, ID = 2.87" '. t -" 3-1/2" HES X NIP, ID = 2.813" I 3-112" HES X NIP, 10 = 2.813" I 7" X 3-1/2" BKR ffiBV1IERPKR, 10 =2.87" 3-1/2" HES X NIP, 10 = 2.813" I 3-112" HESXNIP, 10= 2.813" I 3-1/2" X 4-112" XO, 10=2.910"1 7" X 4-1/2" BKRS-3 PKR, ID = 3.875" 4-1/2" X 3-1/2" XO, 10 = 2.910" I 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" HES X NIP, ID = 2.813" 3-1/2" WLEG, 10 = 3.00" I -1SWS SXAR GUN ASSEtvBL Y I 13-1/2"TBG, 9.2#, L-80, .0087 bpf, ID =2.992" I PffiFORA TION SUMMARY REF LOG: SWS US IT 03/12/04 A NGLE AT TOP PERF: 66° @ 7341' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 4.5" 5 7341 - 7351 Open 03/13/04 4.5" 5 8151 - 8221 Open 03/13/04 4.5" 5 8291 - 8366 Open 03/13/04 4.5" 5 8416 - 8451 Open 03/13/04 4.5" 5 8691 - 8781 I\bt Fired 03/14/04 7" CSG, 26#, L-80, 10 = 6.276" 9119' DATE 02/16/04 REV BY COrvTv1Ef\ITS DIv1 ORIGINAL COrvPLEfION DATE REV BY COrviv1S\JTS ORON UNff WELL: L-211i PERMIT No: 204-029 AA No: 50-029-23197-00 SEe 34, T12N, R11 E, 2540' NSL & 3816' WEL BP Exploration (Alaska) ) ) ¡Yo1J -œ? Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-211i PB1 Date Dispatched: 23-Mar-04 Installation/Rig Nabors 9ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 1 'i .' 0'" ~pß. ~,~~jJ Received By: -~\~ ~ Please sign and return to: James H. Johnson y) .£. c""'r ~à BP Exploration (Alaska) Inc. 'Y\ Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private "~~\\,~ ) ) 801-03/ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-211i/L-211i PB1 Date Dispatched: 23-Mar-04 Installation/Rig Nabors 9ES Dispatched By: F.Alabi Data No Of Prints No of Floppies Surveys 2 1 RE CEIVEI ) ~1¡\ ~ 24-2004 ;:,;ï,ß~ke Oil & ( ¡as Cons.Comm sian J nr.:horage \- ~ Please sign and return to: James H. Johnson Received By: ~D\'ì..Å . ,-C~....¡'D""- BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsoih@bp.com lWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ~--:~~,\\ c~-:~ SCRLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: L-211i API number...............: 50-029-23197-00 Engineer......... ........: St. Amour / Perdomo RIG:.............. .......: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.50 ft KB above permanent.......: N/A (Topdrive) DF above permanent.......: 77.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 325.00 degrees -~ .--....'''-- '"'..... ~ ()é)Lj_{)OJ 8-Mar-2004 15:41: 5 1 of 5 Page Spud date................: Last survey date... ......: Total accepted surveys...: MD of first survey.. .....: MD of last survey... .....: 24-Feb-04 08-Mar-04 99 0.00 ft 9130.00 ft .-- ----- Geomagnetic data --------------------- Magnetic model...... .....: BGGM version 2003 Magnetic date.... ........: 28-Feb-2004 Magnetic field strength..: 1151.17 RCNT Magnetic dec (+E/W-) .....: 25.05 degrees Magnetic dip....... ......: 80.82 degrees ----- MWD survey Refere ce Reference G... ........ ...: Reference R.... ..........: Reference Dip.. .... ......: Tolerance of G. .... ......: Tolerance of R..... ......: Tolerance of Dip.... .....: Criteria --------- 1002.68 mGal 1151.17 RCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 25.05 degrees '~ Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.05 degrees (Total az corr = magn tic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Incl·nation M=Schlumberger Magne ic Correction S=Shell Magnetic Cor ection F=Failed Axis Correc ion RECEIVe·D R=Magnetic Resonance Tool Correction. -- - . . --- - D=Dmag Magnetic Corr ction t·1¡\R 2 ,.: 2004 ~.ta3ka on & Gas Cons. Comn1iIion Anchorage SCHLUMBERGER Survey Report 8-Mar-2004 15:41:05 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ----------------- --------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.44 67.60 100.00 100.00 -0.08 0.15 0.35 67.60 0.44 GYRO None 3 200.00 0.92 60.62 100.00 199.99 -0.25 0.69 1.41 64.03 0.49 GYRO None 4 300.00 1.90 61.83 100.00 299.96 -0.52 1.86 3.57 62.45 0.98 GYRO None 5 400.00 2.20 58.69 100.00 399.90 -0.84 3.64 6.67 61.36 0.32 GYRO None 6 500.00 1.07 68.63 100.00 499.85 -1.19 4.98 9.18 61.52 1.16 GYRO None 7 600.00 0.40 2.21 100.00 599.85 -1.13 5.67 10.06 60.60 0.98 GYRO None ~ 8 700.00 1.41 324.59 100.00 699.83 0.38 7.02 9.36 53.14 1.12 GYRO None 9 800.00 3.96 320.38 100.00 799.72 5.05 10.68 6.45 31.12 2.56 GYRO None 10 900.00 7.10 318.48 100.00 899.24 14.64 17.97 0.15 0.48 3.14 GYRO None 11 1000.00 10.69 321.47 100.00 998.02 30.04 29.86 -9.73 341.96 3.62 GYRO None 12 1100.00 16.08 324.12 100.00 1095.27 53.16 48.35 -23.63 333.95 5.42 GYRO None 13 1200.00 22.27 330.16 100.00 1189.68 85.92 76.04 -41.20 331.55 6.49 GYRO None 14 1300.00 27.33 333.54 100.00 1280.44 127.52 113.05 -60.87 331.70 5.25 GYRO None 15 1400.00 31.81 335.40 100.00 1367.39 176.17 157.59 -82.08 332.49 4.57 GYRO None 16 1500.00 38.93 335.56 100.00 1448.88 233.05 210.22 -106.08 333.22 7.12 GYRO None 17 1592.82 46.63 336.25 92.82 1516.96 294.90 267.74 -131.77 333.80 8.31 MWD GMAG 18 1685.52 53.63 330.82 92.70 1576.37 365.19 331.27 -163.59 333.72 8.78 MWD GMAG 19 1779.00 61.65 328.10 93.48 1626.37 443.85 399.17 -203.75 332.96 8.92 MWD GMAG 20 1873.02 60.15 328.95 94.02 1672.10 525.84 469.23 -246.64 332.27 1.78 MWD GMAG 21 1966.40 61.91 328.75 93.38 1717.32 607.35 539.14 -288.90 331.82 1.89 MWD GMAG 22 2060.26 64.99 329.38 93.86 1759.27 691.09 611.16 -332.05 331.48 3.34 MWD GMAG .~ 23 2154.46 65.57 330.59 94.20 1798.67 776.33 685.25 ~374.85 331.32 1.32 MWD GMAG 24 2247.57 66.78 330.94 93.11 1836.28 861.07 759.57 -416.45 331.27 1.34 MWD GMAG 25 2342.11 65.62 331.08 94.54 1874.43 947.10 835.23 -458.37 331.24 1.23 MWD GMAG 26 2434.98 65.67 331.02 92.87 1912.73 1031.23 909.27 -499.33 1037.3 331.23 0.08 MWD GMAG 27 2528.59 66.95 331.20 93.61 1950.34 1116.46 984.32 -540.74 1123.0 331.22 1.38 MWD GMAG 28 2621.30 68.05 330.91 92.71 1985.81 1201.64 1059.27 -582.19 1208.7 331.21 1.22 MWD GMAG 29 2714.89 67.42 330.84 93.59 2021.27 1287.79 1134.93 -624.35 1295.3 331.18 0.68 MWD GMAG 30 2808.25 66.70 330.82 93.36 2057.66 1373.32 1210.00 -666.25 1381.3 331.16 0.77 MWD GMAG SCHLUMBERGER Survey Report 8-Mar-2004 15:41:05 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ 31 2900.68 67.27 331.55 92.43 2093.80 1457.90 1284.54 -707.26 331.16 0.95 MWD GMAG 32 2993.04 66.57 331.86 92.36 2130.01 1542.29 1359.36 -747.53 331.19 0.82 MWD GMAG 33 3086.65 67.43 332.47 93.61 2166.58 1627.78 1435.56 -787.76 331.24 1.10 MWD GMAG 34 3180.77 66.94 332.60 94.12 2203.08 1713.79 1512.53 -827.78 331.31 0.54 MWD GMAG 35 3273.33 66.36 332.10 92.56 2239.77 1798.07 1587.81 -867.21 331.36 0.80 MWD GMAG 36 3366.79 67.09 332.65 93.46 2276.70 1883.21 1663.87 -907.02 331.40 0.95 MWD GMAG 37 3459.72 66.65 332.45 92.93 2313.20 1967.93 1739.71 -946.41 331.45 0.51 MWD GMAG "-" 38 3554.01 66.00 331.97 94.29 2351.06 2053.60 1816.11 -986.67 331.49 0.83 MWD GMAG 39 3646.99 66.44 333.24 92.98 2388.56 2137.93 1891.65 -1025.82 331.53 1.34 MWD GMAG 40 3741.39 65.89 333.10 94.40 2426.70 2223.41 1968.70 -1064.79 331.59 0.60 MWD GMAG 41 3834.88 67.59 334.06 93.49 2463.62 2308.33 2045.62 -1103.01 331.67 2.05 MWD GMAG 42 3927.92 67.20 334.76 93.04 2499.38 2393.07 2123.09 -1140.10 331.76 0.81 MWD GMAG 43 4019.69 66.35 334.70 91.77 2535.57 2476.19 2199.35 -1176.10 331.86 0.93 MWD GMAG 44 4112.33 67.14 334.49 92.64 2572.15 2560.11 2276.23 -1212.62 331.95 0.88 MWD GMAG 45 4206.36 66.52 334.82 94.03 2609.15 2645.33 2354.36 -1249.62 332.04 0.73 MWD GMAG 46 4299.34 66.44 335.11 92.98 2646.25 2729.30 2431.60 -1285.70 2750.5 332.13 0.30 MWD GMAG 47 4354.49 67.13 335.69 55.15 2667.99 2779.15 2477.69 -1306.80 2801.1 332.19 1.58 MWD GMAG 48 4436.09 65.00 336.71 81.60 2701.09 2852.31 2545.92 -1336.90 2875.5 332.30 2.85 MWD GMAG 49 4511.96 66.14 335.36 75.87 2732.47 2920.11 2609.04 -1364.96 2944.5 332.38 2.21 MWD GMAG 50 4605.66 65.96 336.05 93.70 2770.51 3004.25 2687.08 -1400.19 3030.0 332.48 0.70 MWD GMAG 51 4699.96 66.90 338.05 94.30 2808.22 3088.77 2766.67 -1433.89 3116.1 332.60 2.18 MWD GMAG 52 4794.26 65.35 338.02 94.30 2846.39 3172.77 2846.64 -1466.14 3202.0 332.75 1.64 MWD GMAG ~ 53 4887.96 67.60 337.96 93.70 2883.78 3256.48 2926.29 -1498.34 3287.5 332.89 2.40 MWD GMAG 54 4981.44 68.93 338.17 93.48 2918.40 3341.07 3006.83 -1530.77 3374.0 333.02 1.44 MWD GMAG 55 5074.98 68.39 337.76 93.54 2952.44 3425.97 3087.59 -1563.46 3460.8 333.14 0.71 MWD GMAG 56 5168.91 68.19 337.35 93.93 2987.19 3511.15 3168.25 -1596.78 3547.8 333.25 0.46 MWD GMAG 57 5261.48 67.86 336.43 92.57 3021.83 3595.15 3247.21 -1630.47 3633.5 333.34 0.99 MWD GMAG 58 5354.87 68.23 334.45 93.39 3056.75 3680.33 3325.98 -1666.47 3720.1 333.39 2.01 MWD GMAG 59 5447.69 67.61 334.31 92.82 3091.64 3765.19 3403.54 -1703.66 3806.1 333.41 0.68 MWD GMAG 60 5541.35 67.49 333.86 93.66 3127.40 3850.67 3481.39 -1741.49 3892.6 333.42 0.46 MWD GMAG SCHLUMBERGER Survey Report 8-Mar-2004 15:41:05 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ 61 5634.46 68.26 333.71 93.11 3162.47 3935.91 3558.77 -1779.59 333.43 0.84 MWD GMAG 62 5726.91 68.14 332.55 92.45 3196.80 4020.88 3635.34 -1818.39 333.43 1.17 MWD GMAG 63 5820.81 68.05 333.65 93.90 3231.84 4107.13 3713.04 -1857.81 333.42 1.09 MWD GMAG 64 5914.71 68.11 334.27 93.90 3266.89 4193.18 3791.30 -1896.05 333.43 0.62 MWD GMAG 65 6007.66 67.52 335.03 92.95 3301.99 4278.03 3869.08 -1932.90 333.45 0.99 MWD GMAG 66 6101.97 67.90 334.57 94.31 3337.76 4364.02 3948.04 -1970.05 333.48 0.60 MWD GMAG 67 6196.39 67.77 334.73 94.42 3373.38 4450.23 4027.06 -2007.49 333.50 0.21 MWD GMAG 3408.62 .~ 68 6289.64 67.83 333.87 93.25 4535.43 4104.86 -2044.93 333.52 0.86 MWD GMAG 69 6383.72 67.31 333.79 94.08 3444.51 4621.36 4182.91 -2083.28 333.52 0.56 MWD GMAG 70 6478.02 68.07 333.54 94.30 3480.31 4707.60 4261.09 -2121.99 333.53 0.84 MWD GMAG 71 6572.61 68.23 335.09 94.59 3515.52 4794.24 4340.21 -2160.04 333.54 1.53 MWD GMAG 72 6665.64 67.62 336.06 93.03 3550.48 4878.98 4418.70 -2195.69 333.58 1.17 MWD GMAG 73 6759.61 68.27 337.04 93.97 3585.77 4964.31 4498.60 -2230.34 333.63 1.19 MWD GMAG 74 6852.98 68.04 337.80 93.37 3620.51 5048.95 4578.62 -2263.62 333.69 0.79 MWD GMAG 75 6947.10 67.77 336.57 94.12 3655.91 5134.19 4659.00 -2297.43 333.75 1.24 MWD GMAG 76 7039.94 67.21 334.15 92.84 3691.46 5218.55 4736.96 -2333.18 333.78 2.48 MWD GMAG 77 7132.43 67.22 329.92 92.49 3727.29 5303.15 4812.25 -2373.16 333.75 4.22 MWD GMAG 78 7225.57 67.69 326.54 93.14 3763.01 5389.02 4885.37 -2418.45 333.66 3.39 MWD GMAG 79 7318.79 66.29 321.69 93.22 3799.47 5474.78 4954.87 -2468.70 333.52 5.02 MWD GMAG 80 7412.10 65.44 317.71 93.31 3837.64 5559.54 5019.80 -2523.76 333.31 4.00 MWD GMAG 81 7505.80 67.82 317.54 93.70 3874.80 5644.84 5083.33 -2581.72 333.07 2.55 MWD GMAG 82 7599.14 67.70 315.97 93.34 3910.13 5730.34 5146.27 -2640.91 332.83 1.56 MWD GMAG ~. 83 7691.53 67.62 315.84 92.39 3945.25 5814.72 5207.64 -2700.38 332.59 0.16 MWD GMAG 84 7785.80 68.13 315.09 94.27 3980.75 5900.84 5269.89 -2761.63 332.34 0.91 MWD GMAG 85 7879.05 67.15 315.71 93.25 4016.23 5985.87 5331.29 -2822.18 332.11 1.22 MWD GMAG 86 7972.93 68.17 314.17 93.88 4051.91 6071.36 5392.62 -2883.64 331.86 1.87 MWD GMAG 87 8065.44 67.99 314.66 92.51 4086.45 6155.73 5452.68 -2944.94 331.63 0.53 MWD GMAG 88 8159.40 67.71 315.38 93.96 4121.87 6241.43 5514.24 -3006.46 331.40 0.77 MWD GMAG 89 8253.59 67.84 315.97 94.19 4157.50 6327.47 5576.61 -3067.38 331.19 0.60 MWD GMAG 90 8346.80 68.27 316.63 93.21 4192.34 6412.93 5639.12 -3127.11 330.99 0.80 MWD GMAG SCHLUMBERGER Survey Report 8-Mar-2004 15:41:05 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Tota At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- disp Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------- ------ 91 8438.56 68.11 314.97 91.76 4226.43 6497.03 5700.19 -3186.50 6530.3 330.79 1.69 MWD GMAG 92 8532.60 68.29 314.50 94.04 4261.35 6582.94 5761.65 -3248.53 6614.3 330.58 0.50 MWD GMAG 93 8626.47 67.44 314.75 93.87 4296.72 6668.47 5822.73 -3310.41 6697.9 330.38 0.94 MWD GMAG 94 8719.45 67.62 314.46 92.98 4332.26 6752.98 5883.06 -3371.59 6780.7 330.18 0.35 MWD GMAG 95 8812.25 68.12 315.57 92.80 4367.22 6837.64 5943.86 -3432.35 6863.7 330.00 1.23 MWD GMAG 96 8905.36 67.27 315.69 93.11 4402.56 6922.64 6005.44 -3492.59 6947.1 329.82 0.92 MWD GMAG 97 8998.88 66.06 315.81 93.52 4439.60 7007.39 6066.95 -3552.51 7030.5 329.65 1.30 MWD GMAG ~. 98 9054.15 65.34 315.27 55.27 4462.35 7057.08 6102.90 -3587.79 7079.3 329.55 1.58 MWD GMAG 99 9130.00 65.34 315.27 75.85 4493.99 7125.02 6151.87 -3636.30 7146.20 329.41 0.00 Projected to TD [(c)2004 IDEAL ID8_1C_02] -- ..... SCHLUMBERGER Survey report Client........... ........: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well.. . .. . . . ... .. . ... .. ..: L-211i PBl API number.. ...... ... ....: 50-029-23197-70 Engineer.. ....... .... ....: Perdomo/ St. Amour RIG:.................. ...: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.. .........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. ...... ...: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.50 ft KB above permanent.. .....: N/A (Top Drive) DF above permanent.. .....: 77.00 ft ----- Vertical section origin---------------- Latitude (+N/S-)....... ..: 0.00 ft Departure (+E/W-)..... ...: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-)....... ..: -999.25 ft Departure (+E/W-) ..... ...: -999.25 ft Azimuth from rotary table to target: 325.00 degrees RECEIVED ~~, .~" '- MAR 3 0 2004 Aj~ka Oil & Gas Cons.Cornmision flJtChorage 3-Mar-2004 06:50:10 Spud date. . . . . . . . . . . . . . . . : Last survey date.... .....: Total accepted surveys...: MD of first survey.. .....: MD of last survey... .....: au, -Ud--, Page 1 of 5 24-Feb-04 03-Mar-04 120 0.00 ft 11200.00 ft ,,-~.r ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2003 Magnetic date... .........: 28-Feb-2004 Magnetic field strength..: 1151.17 HCNT Magnetic dec (+E/W-) .....: 25.05 degrees Magnetic dip.... ...... ...: 80.82 degrees ----- MWD survey Reference Reference G. .... .... .....: Reference H......... .....: Reference Dip. ...... .....: Tolerance of G...... ... ..: Tolerance of H...... .....: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.17 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.05 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.05 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~' SCHLUMBERGER Survey Report 3-Mar-2004 06:50:10 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type ( deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.44 67.60 100.00 100.00 -0.08 0.15 0.35 0.38 67.60 0.44 GYRO None 3 200.00 0.92 60.62 100.00 199.99 -0.25 0.69 1.41 1.57 64.03 0.49 GYRO None 4 300.00 1.90 61.83 100.00 299.96 -0.52 1.86 3.57 4.03 62.45 0.98 GYRO None 5 400.00 2.20 58.69 100.00 399.90 -0.84 3.64 6.67 7.60 61.36 0.32 GYRO None 6 500.00 1.07 68.63 100.00 499.85 -1.19 4.98 9.18 10.45 61.52 1.16 GYRO None 7 600.00 0.40 2.21 100.00 599.85 -1.13 5.67 10.06 11.55 60.60 0.98 GYRO None c~ 8 700.00 1.41 324.59 100.00 699.83 0.38 7.02 9.36 11.70 53.14 1.12 GYRO None 9 800.00 3.96 320.38 100.00 799.72 5.05 10.68 6.45 12.48 31.12 2.56 GYRO None 10 900.00 7.10 318.48 100.00 899.24 14.64 17.97 0.15 17.97 0.48 3.14 GYRO None 11 1000.00 10.69 321.47 100.00 998.02 30.04 29.86 -9.73 31.40 341.96 3.62 GYRO None 12 1100.00 16.08 324.12 100.00 1095.27 53.16 48.35 -23.63 53.82 333.95 5.42 GYRO None 13 1200.00 22.27 330.16 100.00 1189.68 85.92 76.04 -41.20 86.48 331.55 6.49 GYRO None 14 1300.00 27.33 333.54 100.00 1280.44 127.52 113.05 -60.87 128.40 331.70 5.25 GYRO None 15 1400.00 31.81 335.40 100.00 1367.39 176.17 157.59 -82.08 177.68 332.49 4.57 GYRO None 16 1500.00 38.93 335.56 100.00 1448.88 233.05 210.22 -106.08 235.47 333.22 7.12 GYRO None 17 1592.82 46.63 336.25 92.82 1516.96 294.90 267.74 -131.77 298.41 333.80 8.31 MWD GMAG 18 1685.52 53.63 330.82 92.70 1576.37 365.19 331.27 -163.59 369.46 333.72 8.78 MWD GMAG 19 1779.00 61.65 328.10 93.48 1626.37 443.85 399.17 -203.75 448.16 332.96 8.92 MWD GMAG 20 1873.02 60.15 328.95 94.02 1672.10 525.84 469.23 -246.64 530.10 332.27 1.78 MWD GMAG 21 1966.40 61.91 328.75 93.38 1717.32 607.35 539.14 -288.90 611.67 331.82 1.89 MWD GMAG 22 2060.26 64.99 329.38 93.86 1759.27 691.09 611.16 -332.05 695.54 331.48 3.34 MWD GMAG '_./ 23 2154.46 65.57 330.59 94.20 1798.67 776.33 685.25 -374.85 781.08 331.32 1.32 MWD GMAG 24 2247.57 66.78 330.94 93.11 1836.28 861.07 759.57 -416.45 866.25 331.27 1.34 MWD GMAG 25 2342.11 65.62 331.08 94.54 1874.43 947.10 835.23 -458.37 952.74 331.24 1.23 MWD GMAG 26 2434.98 65.67 331.02 92.87 1912.73 1031.23 909.27 -499.33 1037.35 331.23 0.08 MWD GMAG 27 2528.59 66.95 331.20 93.61 1950.34 1116.46 984.32 -540.74 1123.07 331.22 1.38 MWD GMAG 28 2621.30 68.05 330.91 92.71 1985.81 1201.64 1059.27 -582.19 1208.72 331.21 1.22 MWD GMAG 29 2714.89 67.42 330.84 93.59 2021.27 1287.79 1134.93 -624.35 1295.33 331.18 0.68 MWD GMAG 30 2808.25 66.70 330.82 93.36 2057.66 1373.32 1210.00 -666.25 1381.31 331.16 0.77 MWD GMAG SCHLUMBERGER Survey Report 3-Mar-2004 06:50:10 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2900.68 67.27 331.55 92.43 2093.80 1457.90 1284.54 -707.26 1466.38 331.16 0.95 MWD GMAG 32 2993.04 66.57 331.86 92.36 2130.01 1542.29 1359.36 -747.53 1551.34 331.19 0.82 MWD GMAG 33 3086.65 67.43 332.47 93.61 2166.58 1627.78 1435.56 -787.76 1637.50 331.24 1.10 MWD GMAG 34 3180.77 66.94 332.60 94.12 2203.08 1713.79 1512.53 -827.78 1724.23 331.31 0.54 MWD GMAG 35 3273.33 66.36 332.10 92.56 2239.77 1798.07 1587.81 -867.21 1809.20 331.36 0.80 MWD GMAG 36 3366.79 67.09 332.65 93.46 2276.70 1883.21 1663.87 -907.02 1895.04 331.40 0.95 MWD GMAG 37 3459.72 66.65 332.45 92.93 2313.20 1967.93 1739.71 -946.41 1980.48 331.45 0.51 MWD GMAG ~~ 38 3554.01 66.00 331.97 94.29 2351.06 2053.60 1816.11 -986.67 2066.83 331.49 0.83 MWD GMAG 39 3646.99 66.44 333.24 92.98 2388.56 2137.93 1891.65 -1025.82 2151.89 331.53 1.34 MWD GMAG 40 3741.39 65.89 333.10 94.40 2426.70 2223.41 1968.70 -1064.79 2238.21 331.59 0.60 MWD GMAG 41 3834.88 67.59 334.06 93.49 2463.62 2308.33 2045.62 -1103.01 2324.04 331.67 2.05 MWD GMAG 42 3927.92 67.20 334.76 93.04 2499.38 2393.07 2123.09 -1140.10 2409.84 331.76 0.81 MWD GMAG 43 4019.69 66.35 334.70 91.77 2535.57 2476.19 2199.35 -1176.10 2494.06 331.86 0.93 MWD GMAG 44 4112.33 67.14 334.49 92.64 2572.15 2560.11 2276.23 -1212.62 2579.08 331.95 0.88 MWD GMAG 45 4206.36 66.52 334.82 94.03 2609.15 2645.33 2354.36 -1249.62 2665.44 332.04 0.73 MWD GMAG 46 4299.34 66.44 335.11 92.98 2646.25 2729.30 2431.60 -1285.70 2750.58 332.13 0.30 MWD GMAG 47 4354.49 67.13 335.69 55.15 2667.99 2779.15 2477.69 -1306.80 2801.19 332.19 1.58 MWD GMAG 48 4511.11 67.78 332.32 156.62 2728.05 2921.99 2607.67 -1370.20 2945.74 332.28 2.03 MWD GMAG 49 4604.85 72.03 326.23 93.74 2760.28 3009.71 2683.25 -1415.19 3033.58 332.19 7.60 MWD GMAG 50 4698.43 75.36 322.60 93.58 2786.56 3099.50 2756.26 -1467.46 3122.56 331.97 5.15 MWD GMAG 51 4792.19 74.98 318.52 93.76 2810.56 3189.84 2826.24 -1525.02 3211.44 331.65 4.23 MWD GMAG 52 4885.73 71.49 316.35 93.54 2837.55 3278.61 2892.20 -1585.58 3298.32 331.27 4.34 MWD GMAG ~/ 53 4978.87 72.79 314.55 93.14 2866.11 3366.02 2955.37 -1647.77 3383.69 330.86 2.31 MWD GMAG 54 5072.05 74.95 314.33 93.18 2892.00 3454.01 3018.04 -1711.68 3469.64 330.44 2.33 MWD GMAG 55 5165.50 74.57 314.58 93.45 2916.56 3542.65 3081.19 -1776.04 3556.40 330.04 0.48 MWD GMAG 56 5259.94 74.44 314.62 94.44 2941.79 3632.17 3145.09 -1840.84 3644.21 329.66 0.14 MWD GMAG 57 5353.24 73.91 314.64 93.30 2967.24 3720.46 3208.15 -1904.72 3730.97 329.30 0.57 MWD GMAG 58 5446.87 73.56 314.90 93.63 2993.46 3808.92 3271.45 -1968.53 3818.05 328.96 0.46 MWD GMAG 59 5539.03 74.04 313.64 92.16 3019.17 3895.87 3333.22 -2031.90 3903.72 328.63 1.41 MWD GMAG 60 5631.89 73.94 313.41 92.86 3044.78 3983.34 3394.69 -2096.62 3989.96 328.30 0.26 MWD GMAG "'" SCHLUMBERGER Survey Report 3-Mar-2004 06:50:10 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5727.00 73.49 312.16 95.11 3071.45 4072.57 3456.70 -2163.62 4077.99 327.96 1.35 MWD GMAG 62 5819.89 73.41 311.42 92.89 3097.91 4159.25 3516.04 -2230.01 4163.59 327.62 0.77 MWD GMAG 63 5914.14 72.72 312.51 94.25 3125.37 4247.09 3576.33 -2297.05 4250.48 327.29 1.33 MWD GMAG 64 6006.62 74.15 310.68 92.48 3151.74 4333.31 3635.17 -2363.34 4335.87 326.97 2.45 MWD GMAG 65 6100.70 74.21 311.30 94.08 3177.38 4421.13 3694.54 -2431.66 4422.96 326.65 0.64 MWD GMAG 66 6195.30 72.66 309.57 94.60 3204.36 4508.89 3753.35 -2500.67 4510.09 326.33 2.40 MWD GMAG 67 6288.24 73.26 308.06 92.94 3231.59 4594.22 3809.04 -2569.90 4594.91 325.99 1.68 MWD GMAG '--' 68 6381.58 73.11 308.44 93.34 3258.59 4679.78 3864.36 -2640.07 4680.09 325.66 0.42 MWD GMAG 69 6476.23 73.32 309.08 94.65 3285.93 4766.78 3921.09 -2710.73 4766.86 325.34 0.68 MWD GMAG 70 6570.36 72.28 309.37 94.13 3313.76 4853.31 3977.95 -2780.39 4853.31 325.05 1.14 MWD GMAG 71 6663.31 72.58 308.05 92.95 3341.82 4938.37 4033.36 -2849.53 4938.41 324.76 1.39 MWD GMAG 72 6757.64 72.63 308.57 94.33 3370.02 5024.59 4089.17 -2920.17 5024.80 324.47 0.53 MWD GMAG 73 6851.06 71.75 309.02 93.42 3398.60 5110.00 4144.89 -2989.49 5110.50 324.20 1.05 MWD GMAG 74 6944.76 73.21 307.64 93.70 3426.80 5195.59 4200.30 -3059.58 5196.50 323.93 2.10 MWD GMAG 75 7037.97 73.43 308.34 93.21 3453.56 5280.97 4255.26 -3129.95 5282.41 323.66 0.76 MWD GMAG 76 7129.46 72.87 307.94 91.49 3480.08 5364.77 4309.34 -3198.82 5366.82 323.41 0.74 MWD GMAG 77 7222.88 71.95 308.45 93.42 3508.31 5450.02 4364.40 -3268.80 5452.80 323.17 1.11 MWD GMAG 78 7316.04 72.64 308.80 93.16 3536.64 5535.16 4419.80 -3338.14 5538.75 322.94 0.82 MWD GMAG 79 7409.54 72.79 309.70 93.50 3564.42 5621.09 4476.28 -3407.27 5625.53 322.72 0.93 MWD GMAG 80 7502.47 71.82 309.56 92.93 3592.67 5706.45 4532.75 -3475.46 5711.80 322.52 1.05 MWD GMAG 81 7596.49 71.62 310.35 94.02 3622.16 5792.67 4590.08 -3543.89 5798.97 322.33 0.83 MWD GMAG 82 7689.36 72.31 310.27 92.87 3650.91 5878.09 4647.21 -3611.23 5885.37 322.15 0.75 MWD GMAG ---" 83 7784.11 74.28 310.57 94.75 3678.15 5965.91 4706.05 -3680.31 5974.25 321.97 2.10 MWD GMAG 84 7877.52 76.74 311.32 93.41 3701.52 6053.64 4765.31 -3748.62 6063.03 321.81 2.75 MWD GMAG 85 7971.23 75.96 311.09 93.71 3723.63 6142.07 4825.30 -3817.13 6152.56 321.65 0.87 MWD GMAG 86 8063.58 74.96 311.44 92.35 3746.82 6228.91 4884.26 -3884.32 6240.51 321.51 1.14 MWD GMAG 87 8157.79 74.21 311.64 94.21 3771.86 6317.23 4944.49 -3952.30 6329.98 321.36 0.82 MWD GMAG 88 8251.16 73.65 312.17 93.37 3797.70 6404.62 5004.41 -4019.08 6418.50 321.23 0.81 MWD GMAG 89 8344.28 73.32 312.34 93.12 3824.17 6491.70 5064.44 -4085.16 6506.70 321.11 0.40 MWD GMAG 90 8437.51 73.23 312.80 93.23 3851.00 6578.89 5124.84 -4150.91 6595.00 320.99 0.48 MWD GMAG SCHLUMBERGER Survey Report 3-Mar-2004 06:50:10 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Beg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Az i m (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8530.77 73.05 313.59 93.26 3878.05 6666.25 5185.93 -4215.98 6683.44 320.89 0.83 MWD GMAG 92 8624.48 72.90 313.57 93.71 3905.49 6754.08 5247.70 -4280.89 6772.33 320.79 0.16 MWD GMAG 93 8717.36 72.58 313.72 92.88 3933.05 6841.05 5308.92 -4345.07 6860.34 320.70 0.38 MWD GMAG 94 8810.59 72.87 314.75 93.23 3960.73 6928.50 5371.02 -4408.85 6948.81 320.62 1.10 MWD GMAG 95 8903.52 73.38 315.01 92.93 3987.71 7016.05 5433.77 -4471.87 7037.29 320.55 0.61 MWD GMAG 96 8998.29 73.65 316.94 94.77 4014.61 7105.79 5499.11 -4535.02 7127.88 320.49 1.97 MWD GMAG 97 9091.78 73.32 320.64 93.49 4041.19 7194.88 5566.53 -4594.06 7217.45 320.47 3.81 MWD GMAG ,,-,/ 98 9185.55 71.74 323.95 93.77 4069.35 7284.21 5637.28 -4648.76 7306.84 320.49 3.77 MWD GMAG 99 9279.18 72.09 326.95 93.63 4098.42 7373.20 5710.57 -4699.23 7395.50 320.55 3.07 MWD GMAG 100 9372.34 71.08 328.83 93.16 4127.85 7461.47 5785.43 -4746.21 7483.17 320.64 2.20 MWD GMAG 101 9464.64 70.89 329.96 92.30 4157.92 7548.47 5860.54 -4790.64 7569.42 320.74 1.18 MWD GMAG 102 9558.52 70.68 330.88 93.88 4188.82 7636.72 5937.63 -4834.40 7656.82 320.85 0.95 MWD GMAG 103 9650.84 71.19 333.00 92.32 4218.98 7723.33 6014.63 -4875.44 7742.46 320.97 2.24 MWD GMAG 104 9742.66 71.80 335.32 91.82 4248.13 7809.29 6092.99 -4913.39 7827.25 321.12 2.49 MWD GMAG 105 9835.79 71.40 333.06 93.13 4277.53 7896.54 6172.54 -4951.86 7913.35 321.26 2.34 MWD GMAG 106 9929.61 71.05 332.99 93.82 4307.72 7984.47 6251.70 -4992.15 8000.33 321.39 0.38 MWD GMAG 107 10023.04 70.86 333.08 93.43 4338.21 8071.92 6330.42 -5032.19 8086.85 321.52 0.22 MWD GMAG 108 10116.28 71.10 334.04 93.24 4368.60 8159.09 6409.35 -5071.44 8173.08 321.65 1.01 MWD GMAG 109 10209.10 70.73 334.34 92.82 4398.94 8245.68 6488.31 -5109.63 8258.73 321.78 0.50 MWD GMAG 110 10303.18 70.83 334.24 94.08 4429.92 8333.35 6568.35 -5148.17 8345.48 321.91 0.15 MWD GMAG- 111 10396.70 70.56 334.75 93.52 4460.83 8420.41 6648.01 -5186.18 8431.64 322.04 0.59 MWD GMAG 112 10490.52 70.50 334.48 93.82 4492.10 8507.62 6727.93 -5224.10 8517.99 322.17 0.28 MWD GMAG ~/ 113 10584.43 70.76 334.69 93.91 4523.25 8594.97 6807.95 -5262.12 8604.54 322.30 0.35 MWD GMAG 114 10678.15 70.59 335.01 93.72 4554.27 8682.11 6888.00 -5299.71 8690.89 322.42 0.37 MWD GMAG 115 10770.12 70.68 335.01 91.97 4584.76 8767.56 6966.65 -5336.36 8775.59 322.55 0.10 MWD GMAG 116 10862.27 70.74 335.00 92.15 4615.20 8853.21 7045.48 -5373.11 8860.54 322.67 0.07 MWD GMAG 117 10957.03 70.80 335.13 94.76 4646.41 8941.31 7126.61 -5410.83 8947.95 322.79 0.14 MWD GMAG 118 11050.55 70.41 335.00 93.52 4677.47 9028.16 7206.60 -5448.02 9034.16 322.91 0.44 MWD GMAG 119 11127.01 70.10 333.77 76.46 4703.30 9099.16 7271.49 -5479.13 9104.70 323.00 1.57 MWD GMAG 120 11200.00 70.10 333.77 72.99 4728.15 9166.99 7333.06 -5509.47 9172.13 323.08 0.00 Projected To TD [(c)2004 IDEAL ID8_1C_02] L-211 i M sand fluid sample ) ì Subject: L-211i M sand fluid sample From: "Schmohr, Donn R" <SchmohDR@BP.com> l)ate:. Wed, 11 Feb 200408:30:.3, 2 -0900 To.:::bob__çraIJ(lall@a<irniri.~t~~ej~k~Üs. .,' , . .,.. , . _ _. : ÇC'::· '~Sphaefer,·;Thól11as·:J (COlSIT~ ç'TfR.O~J3SSIQNMS)" :: <7:schatj@BP~corh>,'~Hûff,.Brian D"·<HuffBD@}BP.co# _'., . M Sand Fluid Sampling Well L-211i will be configured to allow a combined Mbl/Mb2 sand fluid sample to be taken in cased hole, either as a downhole sample or a surface sample from flowback to a tank depending on whether the fluids will flow to the surface or not. Testing of the M sands will be facilitated by perforating the Mbl and Mb2 sands at the time the 0 sands are completed, and setting an additional packer and two mandrels to isolate the M sands from the underlying 0 sands. The M sand testing is planned to be conducted after the drilling rig has moved off location, prior to the start of 0 sand water injection. L-211i provides a unique M sand fluid sampling opportunity due to the following: 1. The well location is in an area w/ a significant thickness of M sand pay (125 feet net pay in L-117 and 224 feet net pay in NWE4-01¡ and 2. the well will likely be the last Polygon 1 well drilled in 2004 and early 2005 in which an M sand fluid sample could be taken to aid in future decisions. There currently are no Orion area M sand fluid quality data. Analytical data on viscosity, density, GC light vs. heavy ends, emulsion/asphaltene tendencies, and GOR can be gained by M sand fluid sampling. While the M sand fluid sample is taken there will be plugs (dummy valves) isolating the injection mandrels to the 0 sands. The 0 sands will not be produced. After the M sand fluid sample is obtained, the M sand will be isolated using a plug (dummy valve) or a sliding sleeve and pressure tested to ensure that when the 0 sands are put on injection, no water will be injected into the M sand zones. There is no intent on injecting into the M sands in L-211i in the near future. Donn R. Schmohr Orion Sr. Petroleum Engineer 1 of 1 2/11/2004 8:53 AM t, ) ,\ li""[-.']".\,I -:.,) ·1''',1 LL-:I ((ù \,~) t~L' FRANK H. MURKOWSKI, GOVERNOR AIfA~KA OIL AND GAS CONSERVATION COMMISSION 333 W. "pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-211 i BP Exploration (Alaska) Inc. Permit No: 204-029 Surface Location: 2540'NSL, 3816' WEL, SEC. 34, T12N, RIlE, UM Bottomhole Location: 3538' NSL, 2288' WEL, SEC. 28, T12N, R11E,UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name PBU L-211i PH and API number (50-029-23197-70) from records, data and logs acquired for well PBU L-21li. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t ·tness any required test. Contact the Commission's North Slope petroleum fiel· tor 65 -3607 (pager). BY ORDER OF THE COMMISSION DATED thisJl day of February, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,'~ ~A- t.../,olUJO*-/ ) STATE OF ALASKA ') RECEIVE'D ALASKA OIL AND GAS CONSERVATION COMMISSIO~' . PERMIT TO DRILL FEB 0 5 2004 20 AAC 25 005 AI~~Ii~ níl & Gas Cons. Comm¡~sion 11 b. Current Well Class 0 Exploratory 0 Developmen~Q¡¡'hoE3rtf\ultiple Zone 1 0 Stratigraphic Test III Service /" 0 Developmenrn~s D'Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU L·211i /.. 6. Proposed Depth: 12. Field / Pool(s): MD 9272 TVD 4567 Prudhoe Bay Field / Orion 7. Property Designation: ADL 028239 III Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2540' NSL, 3816'WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2900' NSL, 1652' WEL, SEC. 28, T12N, R11E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3538' NSL, 2288' WEL, SEC. 28, T12N, R11E, UM 2560 7810' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-583098 Y-5978260 Zone-ASP4 (Height above GL): Plan 72.6 feet 1001' 16. D~viated Wells:. 17. Maximum Anticipated ~ressures in psig (see 20 MC 25335) Kickoff Depth 4400 ft Maximum Hole Angle 730 Downhole: 2000 pSlg Surface: 1537 psig 18>: :Cft. S.ihg'p~dgråm,lli' 1',',1.:'·"11',. ,.,'\I:"i;.'~",',1 ~,I""," ,":·1,1"", 1I":'i;,,:¡I,!,:.' ',:,"':;,i , ii"I,:llli 'I ,'.il.'.·.:"""'li::."":.",,,I.i:'I",:1 'II'S. ß.'tt. . it¡J.. P.· ".'~. '~,Pthll.li:':I:'¡II':i'!:II:li'lll, :';:;¡",:",'I"I' :"::,,1:::.:1,",,1':"; ,'I' i" ,'.1,", " ',>', ¡",:,'"';I:,,,:Siz~:,':';: ',1\:',;';, ":"';:;,,:11.,",,',, "<",:',.'." -''T;-' ,i:>"I' "~I '."i:·' :',,:1'<,,:,'; "::'.:','I:,i:":troò'(,\,¡,':::,:;:,I,,I',i;:,i'::,:,:",,:',;:!'Bbttò'åii:,II~~!i,:!:I!I,:':I,,,,,'I,i",.. .1", :,',:,1' " ".'." " ."" II"~, Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD includina staae data 48" 20" x 34" 215.5# A53 Welded 80' 29' 29' 109' 109' 260 sx Arctic Set (ADDroX.) 12-1/4" 9-5/8" 40# L-80 BTC 4506' 29' 29' 4081' 2597' 6~x AS Lite, 348 sx Class 'G' /' 8-3/4" 7" 26# L-80 BTC-M 9348' 29' 29' 9272' 4567'(~sx Class 'G' / '-" 'rt./2.l./ NÇ.¡T 8. Land Use Permit: 13. Approximate Spud Date: 02/28/04 ./ 19.'1.' ,ii: , .:. .",', 'i. ,. <, ,111,"8FUSSENT:;,W,e~I:.~:PON~llrli¢)'N'$¡µM~Äg¥(I(rQI',:~'e"¢~roÞI~t~d'~0~~~ariO,:'I~~pIIRei~nt",Øp~~~~i~".I::',," "¡'i'::,, '1'1":'1'""",',: 1:.',,;,11:,1::, Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): Casing.··.·.··. ... ..; Lenath . ..... ..... Size;>·..· ..... .'. ........ ............. >CementVolÜme " ..... .... MD,' > ,i. ..ND·.. ..;.... Structural ('nn~1 "...tor Surface Intermediate Production Liner Perforation Depth MD (ft): IPerforation Depth TVD (ft): 20. Attachments 181 Filing Fee 0 BOP Sketch 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 181 Property Plat 0 Diverter Sketch 0 Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Low#Crane _ Title Senior Drilling Engineer Signature ,~~ ~ __ Phone 564-4089 ./ Commission Use Only Permit To Drill IAPI Number: / C17 I Permit Approvah Ilbd-lsee cover.letter for Number: 209 - 0 ¿7 50- 02... 9 - 2. 3 I Date: 1/1 ILf other reqUirements Conditions of Approval: sa1}Ples quired 0 Yes ~ No Mud Log Required' I ' 0 Yes ø No . . Hydro n ulfide Measures 0 Yes ~ No Dire. ctiona.1 Survey Required ß Y~s ~ No Other: Te s t ~ Q E . ~ 10°.° (J S i. M. r. T) u, W<- ~ t '/;tla.. {i t¡ L ¡;J j l' eÓ....... r-e d . Ao~ ~ \J.~I· ¡ulor lJÁJIe. pl4 tro..t-t!-11<Lt1· ðÂ0 / BY ORDER OF II ð (£ ADDrove B ./ I J -"'" '""'" 1 " I to. I ^ 1 THE COMMISSION Date 7 Form 10-401~ised 1~ "- U K \ Ll \ I\! 1-\ L SUbm(ln Duplicate Date: Contact Thomas Schaefer, 564-4685 Date "2 -5"- cJ-./ Prepared By Name/Number: Terrie Hubble, 564-4628 AOGCC L - 211 (Proposed) SSTVD gf4_bmapz4 PBU west None Project name Map name: Map type Surface name Description Datum : -.I o N N o o Z 1492000 W ~.. o o 4 NAD27 Alaska State 5004 Clarke - 1866 Feet Zone: Spheroid Units: ¡ I o _C ('...1 CD CD 000 1 7920 February 09, 2004 02:06 Feet § 500 1 Scale o Prepared Plot creation date ~ (tJ 1492200 W 580,000 . _ter Prudhoe Bay Orion L-211 i Permit Well Plan SUmmary I Type of Well (producer or injector): I USH Injector Surface Location: 2,539' FSL, 1,463' FWL, Sec. 34, T12N, R11E ./ X = 583,098 Y = 5,978,260 * L-211 i Polygon 4 Target 4,007' FSL, 1,482' FWL, Sec. 28, T12N, R11E (Pilot Hole) Top OBd: X = 577,750 Y = 5,984,950 Z = 4430' TVDss L-211 i Polygon 4 BHL 4,554' FSL, 1,175' FWL, Sec. 28, T12N, R11E (Pilot Hole): X = 577,436 Y = 5,985,494 Z = 4618' TVDss L-211 i Polygon 1 Target 1 2,900' FSL, 3,628' FWL, Sec. 28, T12N, R11 E Top OA: X = 579,910 Y = 5,983,866 Z = 4,120' TVDss L-211 i Polygon 1 Target 2 3,374' FSL, 3,154' FWL, Sec. 28, T12N, R11E Top OBe: X = 579,430 Y = 5,984,335 Z = 4,395' TVDss L-211 i Polygon 1 BHL: 1,742' FNL, 2,288' FEL, Sec. 28, T12N, R11E / X = 579,265 Y = 5,984,497 Z = -4,490' TVDss I AFE Number: 15M3542 I Rig: I Nabors 9ES / I Operating days to complete: 119.75 I Estimated Start Date: I Feb 28m 2004 Pilot MD 11,167' (Pilot) Inj KOP 4,400' Inj MD 9,272' TVDrkb: TD 4,696' TVDrkb: TD 2,718' TVDrkb: TD 4,567' Max Inc. 73° Inc. 68° Max Inc. 68° KBE 72.60' KBE 72.60' KBE 72.60' Well Design: USH Grassroots Schrader Injector with appraisal pilot hole. "'-. 4-%" X 3-%" TCII Completion. The Mb1 & Mb2 sands will be completed in addition to Schrader 0 sands to facilitate acquisition of an M sand oil sample after the riq has moved off. * Current Well Information General L-211iPB1: Distance to Nearest Property: -7,959' at TD to the nearest PBU property line ? (Ir Distance to Nearest Well in Pool: 1,160' from PB1 top of OA at 9,831' MD to NWEILEEN-1 top OA at /" 4,352' MD L-211 i Mainbore: Distance to Nearest Property: -7,810' at TD to the nearest PBU property line ~ k k Distance to Nearest Well in Pool: 1,001' from L-211 i top of OA at 8,297' MD to NWEILEEN-1 top OA /' at 4,352'MD API Number: Well Type: Current Status: BHP (PB1): BHP (Mainbore): BHT: 50-029- ????? ' Development - Orion Schrader Injector I New well, 20" X 34" insulated conductor 2,040 psi @ 4,575' TVDss (8.6 ppg EMW). Normal pressure gradient. / 2,000 psi @ 4,473' TVDss (8.6 ppg EMW). Normal pressure gradient. 96°F @ 4,567' TVDss Estimated (from L-pad Temp Log) Final Mechanical Condition L-211 i: Nabors 9ES: Conductor: . .ter Prudhoe Bay Orion L-211 i Permit Cellar Box above MSL = 44.1' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB 1A Mile Well bore Near Wellbore Mechanical Integrity Summary: The NWEILEEN exploration well penetrates the Top of the OA structure 1,160' from the top of the L-211 i top . f( OA and 1,001' from the top of the PB1 top OA. Furthermore the L-211 i Pilot hole will drill within 236' to the * ~ ~ NWEILEEN-1 while at 8,588' MD. There are no wellbore mechanical integrity issues as records indicate that the NWEILEEN-1 was satisfactorily cemented across the Schrader and M sands during primary cementing operations. It was then perforated across the M, Nand 0 sands, tested, and subsequently had the perforations squeezed. This well is scheduled to be P&A'd prior to drilling of the L-211 i. ..--- Target Estimates Estimated Reserves: Materials Needed Surface Casing: Intermediate Casing: L-80 Completion: 7,560 mstb 4,081' 1 each 1 each 25 each 1 assembly 1 lot 9-%",40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 W' Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10',20'. 9,270' 1 each 75 each 2 lots 2 each 2 each 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8 W' Rigid Straight Blade Centralizers 7" casing pups 5',10',20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 4 W' 12.60 Ib/ft, L-80, TCII tubing 3 W' 9.30 Ib/tt, L-80, TCII tubing Baker PRM Production Packer 7" X 3-%" Baker S-3 Production Packer 7" X 3-112" Halliburton 4-%" X-Nipple (3.813" ID) Halliburton 3-%" X-Nipple (2.813" ID) 11" X 4- W' FMC tubing hanger 4-1/'6", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 3-%" x 1-112" MMG GLM 3 W' RA Tag 3-%" WLEG 7,400' 1,600' 3 each 1 each 2 each 7 each 1 each 1 each 1 each 6 each 1 each 1 each 2 . eter Prudhoe Bay Orion L-211 i Permit Surface and Anti-Collision Issues Surface Shut-in Wells: Nearby Wells L-122 L~115i L117i Distance to Target Well 15.06 14.99 29.99 RiQ N9ES Wellhead Separation -14.94 -15.01 4.99 / Separation of the target wellhead from nearest well is 14.99 feet. Surface close approach limit for Nabors 9ES is 60 feet separation from rig structure to wellhead. Maximum rig width from centerline is 30'. Smallest rig to wellhead separation is therefore -15.01'. L-122 & L-115i will therefore require surface shut-in and wellhouse removal in order to move over well. L-117i should be evaluated before rig move as to whether it will require wellhouse removal and shut in for rig move. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. ./ Survey and Logging Program 12-W' Hole Section: Surface Gvro will be needed (run to 700-800' as conditions dictate) Open Hole: MWD I GR Cased hole: None 8-%" Hole Section: MWD / GR / Res I Den / Neu / PWD (Den Neu recorded only) Cased Hole: USIT Bond LOQ / Mud Program 12 %" Surface Hole Mud Properties: I Spud - Freshwater Mud Interval Density (PPQ) Funnel vis YP PH FL Initial 8.5-9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm 9 11- 9.5 200-250 30-45 8.5-9.0 8.0 Interval TD ¡!j.f V(rnax) 200-250 30-40 8.5-9.0 5.0-7.0 l,'t ill ~ 8 %" Intermediate Hole Mud Properties: I Freshwater Mud (LSND) PH: 9.0-9.5 <600 Chlorides Interval Density (ppg) YP PV API Filtrate MBT Pilot Hole 11,150' MD 9.3 25-30 12-20 6-8 <20 Mainbore 9,272' MD 9.3 38-50 12-18 4-6 <20 3 . .ter Prudhoe Bay Orion L-211 i Permit Formation Markers (Based on Schlumberger WP6/P11) 0/ SV6 -890 975 967 409 8.8 No SV5 -1545 1745 1622 711 8.8 No SV4 -1655 1915 1732 761 8.8 Poss. Gas Hvdrates Base Permafrost -1680 1957 1757 773 8.8 No SV3 -1995 2697 2072 918 8.8 Poss. Gas Hvdrates SV2 -2145 3093 2222 987 8.8 Poss. Gas Hvdrates Fault 1 -2330 3580 2407 1072 SVl -2420 3818 2497 1113 8.8 Poss. Free Gas UG4 -2725 4627 2837 1260 8.9 Thin coal UG4A -2760 4727 2837 1275 8.9 Heavy Oil betw 2780 and 2900' SS -3115 5720 3192 1412 8.7 Thin coals/poss. UG3 Heavy oil UGl -3600 7618 3677 1625 8.7 Heavy Oil betw 3730 - 3855' SS Top Schrader Bluff/Ma -3855 8511 3932 1735 8.7 Possible Heavy Oil Sand betw 3855 - 3890' SS Mbl -3890 8633 3967 1750 8.7 No -3950 8842 4027 1780 8.7 Possible Heavy Oil Mb2 betw 3950 - 3990' SS Mc -4015 9066 4092 1810 8.7 No Na -4100 9360 4177 1850 8.7 No Nb -4120 9430 4197 1860 8.7 No Nc -4150 9535 4227 1870 8.7 No OA -4235 9831 4312 1905 8.7 No OBa -4295 10040 4372 1925 8.6 No OBb -4340 10198 4417 1940 8.6 No OBc -4385 10355 4462 1955 8.6 No OBd -4430 10512 4507 1970 8.6 No OBe -4490 10721 4567 2000 8.6 Yes OBf -4530 10860 4607 2015 8.6 Yes OBf Base -4575 11017 4652 2040 8.6 no T.D. -4618 11167 4695 Injection Le2 UG4 . -2810 4845 2887 1300 8.9 No UG4A -2835 4911 2912 1305 8.9 Heavy Oil betw 2780 and 2900' SS UG3 -3130 5689 3207 1420 8.7 Thin coals/poss. Heavv oil Fault 2 -3520 6717 3597 UGl- Faulted Top -3525 6730 3602 1620 8.8 Heavy Oil betw 3530 - 3730' SS Top Schrader Bluff/Ma -3730 7270 3807 1680 8.7 Sand Yes Mbl -3775 7388 3852 1700 8.7 Yes Mb2 -3835 7546 3912 1740 8.7 Yes Mc -3885 7678 3962 1770 8.8 Possible Na -3960 7875 4037 1790 8.7 No Nb -3985 7941 4062 1800 8.7 Yes Nc -4025 8048 4102 1815 8.7 Yes OA -4120 8297 4197 1845 8.6 Yes OBa -4180 8455 4257 1875 8.6 Yes OBb -4220 8561 4297 1895 8.6 Yes OBc -4270 8693 4347 1915 8.6 Yes 9·& q.'S t 4 . .ter Prudhoe Bay Orion L-211 i Permit OBd -4325 8837 4402 1945 8.6 Yes OBe - Base injection -4390 9009 4467 1970 8.6 interval Yes OBf -4425 9101 4502 1985 8.6 Yes OBf Base -4473 9227 4550 2000 8.6 no T.D. -4490 9272 4567 CasinglTubing Program 20" X 34" 9-%" 7" 4 Y2" 3 Y2" 29' / 29' 109' /109' 5,750 3,090 29' / 29' 4,081' /2,597' 7,240 5,410 29' / 29' 9,272' /4,567' 8,430 7,500 29' / 29' 7,300' /3,818' 10,160 10,530 7,300' /3,818' 8,800' / 4,388' Cement Calculations In the event that cement is not circulated to suñace during the initial suñace casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to suñace. *" 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,506' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement 5 . .ter Prudhoe Bay Orion L-211 i Permit a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 7,549' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations 0' -1,913' 1,913'-4,081' 4,081' - 11,167'/9,272' Motors and Required Doglegs 1&2 3&4 400 - 700 gpm 500 - 600 60-120 gpm 1.5°/100' initial build 3.5°/100' final build 73° Max in Pilot Hole 68° Tan ent in Mainbore 6 . .ter Prudhoe Bay Orion L-211 i Permit Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. /. Due to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,000 psi @ 4,465' TVDss - Schrader · Maximum surface pressure: 1,537 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) / Estimated 9.3 ppg Brine /6.8 ppg Diesel 4,000/250 psi Rams & Valves 3,500/250 si Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. . .ter Prudhoe Bay Orion L-211 i Permit DrillinQ Hazards and ContinQencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 1 and 4 fault blocks are expected to be normal pressured at 8.6-8.7 ppg /' EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at L-pad and have been encountered in wells as close as L-117i and 115 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole, however recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to L-211 i (L-117i & L-115) had to have the mud treated and were able to drill to section TO. III. Lost Circulation/Breathing A. Lost circulation is possible due to the shallow angle that the wellbore will cross Fault #2. A PBL sub will be run in the string to allow for pumping large concentrations of LCM if losses are encountered. · Note: Massive losses were encountered in L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. Again in L-119 losses prevented circulation and continuous returns while cementing the 7". B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8Ib/9~1 !a1t ement to 600' MO above the Ma sand -7,549' MO. C. The Kick Tolerance for the surface casing is á.,~ÞIS with 9.3 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. If the LOT is 10.63 ppg or I EMW, then the kick tolerance will be < 50 bbls. ~. O. Integrity Testing V. Stuck Pipe A. We do not expect stuck pipe. L-119 did however stick pipe while reaming tight hole at 2,687 TVO in the intermediate section due to hole not being adequately clean. The pipe was backed off and recovered. Care should be taken when drilling through Fault 2 in the mainbore section as stuck pipe could be due to losses while drilling through the rubble zone. VI. Hydrogen Sulfide L Pad is .r(,t~eSignated as an H2S site, however Standard Operating Procedures for H2S precautions should be follo~~t all times. No measurable H2S is being produced from the formation at this time. However 10 ppm has been measured as recently as January 2003 at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: a. Adjacent producers at Surface: L-122 10 ppm L-117i 10 ppm b. Adjacent producers at TO: L -117i 10 ppm NWE4-01 10 ppm 8 . .ter Prudhoe Bay Orion L-211 i Permit VII. Faults A. Fault 1 is the 'L-Pad Fault' and has been intersected in the surface hole by most wells drilled from L Pad to date. Fault #2 is a large throw fault (-175') and has been previously crossed by L-117, L-115, and NWE4- 01. Due to location of the target polygon just upthrown to this fault, it is not possible to cross this fault at a high angle. The well plan will cross the fault at a shallow angle and pass thru any damage zone (if present) as quickly as the target restrictions allow. Losses are possible as a result of this fault crossing, and therefore contingencies should be in place. The fault details are listed below for reference: Fault 1 (SV2): 3580' MD 2407' TVD 2330' TVDss Throw: 60' West Fault 2 (Ugnu UG3): 6,717' MD 3,597' TVD 3,520' TVDss Throw: 175' Southwest CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 9 . _ter Prudhoe Bay Orion L-211 i Permit Drill and Complete Procedure Summary Pre-Rig Work: 1. Set conductor for L-211 i. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in L-122 and L-115i. ***AII pre-rig work should be charged off against the predrill AFE # ORD5M3542*** Rig Operations: 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. ,,- 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4,081' MD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar or stage tool should be on location. If losses are encountered while drilling surface or large washouts are anticipated the port collarlstage tool will be run in the casing string to allow secondary cementing, (in the event cement is not circulated to surface during primary cementing operations). /" .. 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4,000 psi. ./ 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.3 ppg mud . 8. Drill new formation to 20' below 9-%" shoe and perfor,9) LOT (minimum 11.5 ppg EMW). /' 9. Drill ahead to Polygon 4 Pilot Hole TD at 11,167' MD, the base of Schrader formation. 10. Condition the hole for P&A plug. POOH to LD BHA standing back the 4" DP. 11. RIH wI 3 1/2" cement stinger and plug catching sub on 4" DP to TD, spot 1,000' balanced 15.8 ppg Class G / cement abandonment plug from TD to 10, 167'MD. 12. POOH to 10, 167'MD and circulate out drill pipe and cement. Spot second 1,000' balance 15.8 ppg Class G / cement abandonment plug from 10, 167'MD to 9,167' MD. 13. POOH to 9, 167'MD and circulate out drill pipe and cement. Spot third 1,000' balance 15.8 ppg Class G cement",... abandonment plug from 9, 167'MD to 8,167' (344' above Schrader Ma sand). 14. POOH to 3 stands above plug, circulate out drill pipe and contaminated mud, POOH. 15. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH reaming and washing to top .v- of cement plug. Place "sufficient weight on the plug to confirm its location and to confirm that the plug has set 7'- and a competent plug is in place" (AÇ).COO). AóGLC \fJ.CO\- 16. POOH to 4,400' MD and lowside existing wellbore to continue with drilling the Polygon 1 Schrader injection mainbore. Drill ahead to 9,272' MD (base of OBd target plus 250'). /' 17. Circulate and condition hole, make a short trip, TOOH to run casing. 18. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace / the casing with 9.3 ppg mud or seawater during cementing operations and freeze protect the 7" x 9-%" annulus. 19. Test casing at plug bump to 4,000 psi for 30 minutes. 20. PU used bit and scraper and RIH with 4" DP while waiting on cement to PBTD ±9,180' MD. Displace out the mud I seawater with 9.3 ppg brine. POOH and LD BHA. 21. RU Schlumberger E-line and run a USIT/GR log. / ~Gk 22. RU Schlumberger and perforate Mb1, Mb2, OA, OBa, :inQ o Dd'"wl 155' of 4.5" Power Jet Guns set at 5 spf in 6 runs. Depths based on USIT/GR logging run. (GR only used on first run if 30' guns are used.) 23. RIH wI gage ring and junk basket to recover any perf debris. Repeat until clean. 24. M/U Schlumberger SXAR Gun Drop assembly consisting of 75' of 4-1/2" PowerJet Guns at 5 spf. / 25. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-W' straddle packer assembly and injection mandrels (torque turn connections). 10 . .ter Prudhoe Bay Orion L-211 i Permit 26. Make GR e-line correlation run, correct gun setting depth and tubing hanger spaceout. 27. Run in the lockdown screws and set the packers. Test the production casingltubing allr1Úlus and tubing to 4,000 psi each. Shear the DCK shear valve. /" 28. Install FMC TWCV. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 29. Freeze protect the well to -2,200' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-W' annulus valve and secure the well. 30. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod I RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GL V. 3. Install firing head on SXAR system and fire guns. 4. Pull dummy valves in injection mandrels and replace with injection valves. 5. Pull VR plug. 11 . wter Prudhoe Bay Orion L-211 i Permit Job 1: MIRU Hazards and Contingencies: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ L-122 and L-115i will have to be shut in and require wellhouse removal before rig can be moved over the well. Job 2: Drill 12W' Surface Hole Hazards and Contingencies: ~ At L-Pad, no significant surface hole drilling problems have been identified. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In only one case has an obstruction caused the well to be sidetracked. Lost circulation has not been a problem on L-pad. Some minor tight hole has also been encountered below the Permafrost. ~ Hydrates: Hydrates are present at L-pad from the base of the Permafrost all the way through the SV-1 sand and should be treated with conventional practices: pretreating mud, cooling mud, increasing weight, etc as per MI program recommendations. On the L-115 hydrates were encountered at 1667' SS at the base of the Permafrost with gas showing as high as 2400 units. The section was TD'd without incident after traditional methods for treating hydrates were incorporated. The mud did however remain light after drilling through the hydrates. ~ Close Approach: The L-115i and L-122 are required to be shut in and have their wellhouses removed due to surface location proximity to the L-211 i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder I no-go plot per established procedures. A gyro should be run to at least 700'-800'. ~ Directional: Every effort should be made to ensure a 'smooth' well profile, especially in the mainbore, that will benefit torque I drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are pushed ahead of plan on the surface hole, (but no higher than ±5 deg/100), so as to lower the tangent angle and facilitate post well work. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.50 motor bend. Vary flow rates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. 12 . .ter Prudhoe Bay Orion L-211 i Permit Job3: Install Surface Casina Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-%" bit, i.e. float equipment, casing hanger, etc. ~ Cement to suñace: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar can be placed at 1,OOO-ft MD if losses are encountered or indications are that gravel is running or the whole is washing out. (Port Collar was run on L-210i, but not used due to higher shale content on surface hole section. L-211 i will have similar lithology). ~ Losses during cement job: At L-Pad lost circulation has not been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Job 4: Dril/8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.8 ppg, 9.3 ppg mud, and an 11.5 ppg leak-off will provide over 98 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off-set drilling data on L-Pad, a minimum leak-off of 13.3 ppg is expected at the 9-%" shoe. ~ Penetration Rate: It is possible to drill with cumulative penetration rates up to 400 fph in this interval as long as good connection practices are performed and the well is circulated adequately at TD to lower the ECD before tripping ~ Mud Contamination: Mud contamination by plug cement may be cause problems after dressing off the pilot hole abandonment plug and attempting low side sidetrack to drill mainbore. On the L-210i blinding of shaker screens caused 3+ hours rig NPT. ~ Plugging Pilot Hole: A 3 1/2" cement stinger and plug catching sub should be used to facilitate cement placement. This should allow for less mud contamination of the plug and lower the impact of sticking pipe while cementing. The hole should be circulated until returns are free of cement and cement contaminated mud after pulling above the final cement plug. This should assure a quicker dress off and set down for plug confirmation. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the base OBd sand. After seeing the base OBd, TD will be picked 13 . .ter Prudhoe Bay Orion L-211 i Permit based on drilling 250' MD past this base. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that high torque values, as high as 12,000 ft-Ibs can be expected by section TD. Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the intermediate hole sections. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Faults: Two faults will be crossed in the L-211 i with one in the SV2 and one in the Ugnu UG3. Fault 1 is the 'L-Pad' fault and has been crossed in the surface hole by most wells drilled from L Pad to date. Fault 2 is a large throw fault (- 175') and has been previously crossed by L-117, L-115, and NWE4-01. The faults have been crossed on numerous wells and have not caused any drilling problems in the past. However, due to the location of the target polygon just upthrown from Fault#2, it is not possible to cross this fault at a high angle. The well plan will cross the fault at a shallow angle and pass through any damage zone (if present) as quickly as target restrictions will allow. The fault details are listed below for reference: Fault 1 (SV2): 3580' MD 2407' TVD 2330' TVDss Throw: 60' West Fault 2 (Ugnu UG3): 6,717' MD 3,597' TVD 3,520' TVDss Throw: 175' Southwest Due to the well bore's shallow angle of incidence to Fault #2, LCM should be readily available and loss contingencies should be discussed before initiating drilling. A PBL sub will be placed in the BHA. ~ Directional Constraints: It is critical to not let the angle get any higher than planned, due to already high angle tangent angle and the difficult slickline access. It is critical to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to ::;10 over planned. Job 6: Install 7" Production CasinQ Hazards and Contingencies: ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. ~ Centralization/Differential Sticking: See centralizer strategy on page 5. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. 14 . ,.ter Prudhoe Bay Orion L-211 i Permit Þ> Mud Requirements: Thin the mud as per Ml's Mud Program before cementing. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. Þ> Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. Þ> 7" Casing Specifications: 7", 26#, L-80 BTC ID Collapse Burst Tensile 100% 6.276 5,410psi 7,240psi 667,OOOlbs 80% 6.151 (drift) 4,328psi 5,792psi 533,6001bs Þ> TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor for casing running. Job 10: Perforate Well fDPC/SXAR) Hazards and Contingencies Þ> The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Þ> It should be stressed that while picking up and running the perforating guns, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Schlumberger hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. Þ> Contact Schlumberger to prepare for approximately 155' of 4-1/2" Power Jet guns at 5 spf to be run on wire, and 75' of 4 W' Power Jet guns at 5 spf to be run with the completion using the SXAR gun drop system. Exact perforation depths will be provided after reviewing the lWD logs. Þ> Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with lCM if necessary. Follow the lCM decision tree for "After Perforating". Þ> Perf guns should be logged on depth initially using GR and subsequently only with CCl so as to lessen the stress on the tools and prevent failure. Position guns by E-line measurement from USIT run for e-line perforating and by utilizing the Schlumberger GR tool in the string and RA tags for SXAR perforating. Reference RP: .:. 'Schlumberger E-line and SXAR Procedures' Job 12: Run Comø/etion Hazards and Contingencies: Þ> Dirty Hole: It is critical to have a clean hole to run this completion due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. Þ> Torque turn TCII completion connections to help assure that it doesn't leak when the well is put on MI. Reference RP: .:. 'Completion Design and Running' RP 15 . wter Prudhoe Bay Orion L·211i Permit Job 13: ND/NU/Release Rig Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. 16 L-211 PB1 (P6) Proposal hlum puøp Report Date: January 30, 2004 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 325.000' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 fI, E 0.000 fI Structure I Slot: L-PAD / N-H 01/3~ ~/04 TVD Reference Datum: Rotary Table Well: Plan L·211 (N-H) APproved TVD Reference Elevation: 77.00 fI relative to MSL Borehole: Plan L-211 PB1 Sea Bed I Ground Level Elevation: 48.50 It relative to MSL UWI/API#: 50029 Magnetic Declination: 25.043' Survey Name I Date: L-211 PB1 (P6) / January 30, 2004 Total Field Strength: 57558.055 nT Tort I AHD I DDII ERD ratio: 111.087" /9352.34 It 16.393/1.992 Magnetic Dip: 80.821' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 05, 2004 Location LatlLong: N 70.35057765, W 149.32532407 Magnetic Declination Model: BGGM 2003 Location Grid N/E Y/X: N 5978259.930 flUS, E 583098.290 flUS North Reference: True North Grid Convergence Angle: +0.63539136' Total CorrMag North·) True North: +25.043' Grid Scale Factor: 0.99990784 Local Coordinates Referenced To: Well Head . Comments RTE KOP Bid 1.5/100 Bid 2.5/100 700.00 9.00 . 333.53 698.52 621.52 28.42 28.74 25.73 -12.81 2.50 2.50 0.00 O.OOG 5978285.51 583085.20 N 70.35064794 W 149.32542807 800.00 11.50 333.53 796.91 719.91 46.02 46.53 41.65 -20.74 2.50 2.50 0.00 O.OOG 5978301.35 583077.09 N 70.35069145 W 149.32549245 900.00 14.00 333.53 894.44 817.44 67.84 68.60 61.41 -30.58 2.50 2.50 0.00 O.OOG 5978320.99 583067.04 N 70.35074542 W 149.32557230 SV6 975.10 15.88 333.53 967.00 890.00 86.99 87.96 78.74 -39.21 2.50 2.50 0.00 O.OOG 5978338.22 583058.22 N 70.35079276 W 149.32564236 1000.00 16.50 333.53 990.91 913.91 93.85 94.90 84.95 -42.30 2.50 2.50 0.00 O.OOG 5978344.40 583055.05 N 70.35080974 W 149.32566747 Bid 4/100 1020.00 17.00 333.53 1010.06 933.06 99.55 100.67 90.11 -44.87 2.50 2.50 0.00 O.OOG 5978349.53 583052.43 N 70.35082383 W 149.32568833 1100.00 20.20 333.53 1085.87 1008.87 124.78 126.18 112.95 -56.24 4.00 4.00 0.00 O.OOG 5978372.24 583040.80 N 70.35088622 W 149.325_ 1200.00 24.20 333.53 1178.44 1101.44 162.14 163.96 146.77 -73.08 4.00 4.00 0.00 O.OOG 5978405.86 583023.59 N 70.35097861 W 149.325 1300.00 28.20 333.53 1268.15 1191.15 205.80 208.10 186.28 -92.76 4.00 4.00 0.00 O.OOG 5978445.15 583003.48 N 70.35108655 W 149.3260 9 1400.00 32.20 333.53 1354.56 1277.56 255.53 258.39 231.30 -115.17 4.00 4.00 0.00 O.OOG 5978489.92 582980.57 N 70.35120954 W 149.32625908 1500.00 36.20 333.53 1437.25 1360.25 311.11 314.59 281.61 -140.22 4.00 4.00 0.00 O.OOG 5978539.94 582954.97 N 70.35134697 W 149.32646245 1600.00 40.20 333.53 1515.82 1438.82 372.25 376.41 336.95 -167.78 4.00 4.00 0.00 O.OOG 5978594.97 582926.80 N 70.35149817 W 149.32668620 1700.00 44.20 333.53 1589.89 1512.89 438.67 443.57 397.07 -197.72 4.00 4.00 0.00 O.OOG 5978654.74 582896.20 N 70.35166240 W 149.32692925 SV5 1745.51 46.02 333.53 1622.00 1545.00 470.55 475.81 425.93 -212.09 4.00 4.00 0.00 O.OOG 5978683.44 582881.51 N 70.35174124 W 149.32704592 1800.00 48.20 333.53 1659.09 1582.09 510.03 515.73 461.66 -229.89 4.00 4.00 0.00 O.OOG 5978718.97 582863.32 N 70.35183887 W 149.32719041 1900.00 52.20 333.53 1723.08 1646.08 585.99 592.55 530.42 -264.13 4.00 4.00 0.00 O.OOG 5978787.34 582828.32 N 70.35202671 W 149.32746840 SV4 1914.64 52.79 333.53 1732.00 1655.00 597.48 604.16 540.82 -269.30 4.00 4.00 0.00 O.OOG 5978797.68 582823.03 N 70.35205512 W 149.32751044 Base Perm 1956.80 54.47 333.53 1757.00 1680.00 631.05 638. 11 571.21 -284.43 4.00 4.00 0.00 O.OOG 5978827.90 582807.57 N 70.35213813 W 149.32763330 2000.00 56.20 333.53 1781.57 1704.57 666.19 673.64 603.01 -300.27 4.00 4.00 0.00 O.OOG 5978859.52 582791.38 N 70.35222501 W 149.32776188 2100.00 60.20 333.53 1834.25 1757.25 750.22 758.61 679.07 -338.15 4.00 4.00 0.00 O.OOG 5978935.15 582752.66 N 70.35243280 W 149.32806942 2200.00 64.20 333.53 1880.88 1803.88 837.68 847.05 758.24 -377.57 4.00 4.00 0.00 O.OOG 5979013.87 582712.37 N 70.35264907 W 149.32838952 End Bid 2287.61 67.70 333.53 1916.58 1839.58 916.79 927.05 829.85 -413.23 4.00 4.00 0.00 O.OOG 5979085.07 582675.92 N 70.35284470 W 149.32867907 SV3 2697.28 67.70 333.53 2072.00 1995.00 1291.65 1306.09 1169.15 -582. 19 0.00 0.00 0.00 O.OOG 5979422.44 582503.22 N 70.35377161 W149.33005107 SV2 3092.66 67.70 333.53 2222.00 2145.00 1653.42 1671.91 1496.62 -745.26 0.00 0.00 0.00 O.OOG 5979748.05 582336.55 N 70.35466617 W149.33137534 Fault Crossing 3580.30 67.70 333.53 2407.00 2330.00 2099.61 2123.09 1900.49 -946.38 0.00 0.00 0.00 O.OOG 5980149.63 582130.99 N 70.35576946 W 149.33300876 Well Design Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) N-HIPlan L-211 (N-H)IPlan L-211 PB1\L-211 PB1 (P6) Generated 1/30/2004 2:39 PM Page 1 012 Comments SV1 3817.52 67.70 333.53 2497.00 2420.00 2316.68 2342.58 2096.97 -1044.22 0.00 0.00 0.00 O.OOG 5980345.00 582030.98 N 70.35630618 W 149.33380346 9-518" Csg pt 4081.11 67.70 333.53 2597.00 2520.00 2557.86 2586.46 2315.28 -1152.93 0.00 0.00 0.00 O.OOG 5980562.07 581919.86 N 70.35690254 W 149.33468651 Cry 3/100 4400.00 67.70 333.53 2717.98 2640.98 2849.65 2881.51 2579.40 -1284.45 0.00 0.00 0.00 -80.05G 5980824.68 581785.44 N 70.35762402 W 149.33575490 4500.00 68.25 330.35 2755.48 2678.48 2941.66 2974.21 2661.19 -1328.06 3.00 0.55 -3.18 -78.86G 5980905.97 581740.93 N 70.35784744 W 149.33610915 4600.00 68.86 327.19 2792.05 2715.05 3034.52 3067.29 2740.76 -1376.32 3.00 0.61 -3.16 -77.70G 5980985.00 581691.79 N 70.35806481 W 149.33650117 UG4 4627.72 69.04 326.32 2802.00 2725.00 3060.38 3093. 15 2762.39 -1390.50 3.00 0.65 -3.14 -77.39G 5981006.48 581677.38 N 70.35812390 W149.33661637 4700.00 69.53 324.06 2827.57 2750.57 3127.98 3160.76 2817.90 -1429.09 3.00 0.68 -3.12 -76.59G 5981061.55 581638.17 N 70.35827552 W 149.33692987 UG4A 4727.09 69.72 323.22 2837.00 2760.00 3153.37 3186.16 2838.35 -1444.15 3.00 0.70 -3.11 -76.30G 5981081.83 581622.89 N 70.35833139 W 149.33705218 4800.00 70.25 320.96 2861.95 2784.95 3221.78 3254.67 2892.40 -1486.24 3.00 0.73 -3.10 -75.52G 5981135.40 581580.21 N 70.35847901 W 149.33739408 4900.00 71.03 317.89 2895.11 2818.11 3315.67 3349.01 2964.04 -1547.60 3.00 0.78 -3.07 -74.51G 5981206.35 581518.06 N 70.35867471 W 149.337~. 5000.00 71.86 314.85 2926.94 2849.94 3409.38 3443.81 3032.64 -1613.01 3.00 0.83 -3.04 -73.54G 5981274.22 581451.90 N 70.35886208 W 149.33842 5100.00 72.73 311.83 2957.36 2880.36 3502.66 3539.07 3098.01 -1682.29 3.00 0.87 -3.01 -72.62G 5981338.81 581381.91 N 70.35904062 W 149.33898659 End Cry 5173.82 73.40 309.63 2978.86 2901.86 3571.10 3609.68 3144.09 -1735.80 3.00 0.91 -2.99 O.OOG 5981384.28 581327.90 N 70.35916646 W 149.33942125 UG3 5919.99 73.40 309.63 3192.00 3115.00 4260.60 4324.77 3600.18 -2286.55 0.00 0.00 0.00 O.OOG 5981834.19 580772.18 N 70.36041205 W149.34389526 UG1 7617.93 73.40 309.63 3677.00 3600.00 5829.59 5951.96 4638.03 -3539.79 0.00 0.00 0.00 O.OOG 5982857.99 579507.62 N 70.36324604 W149.35407805 Ma 8510.66 73.40 309.63 3932.00 3855.00 6654.53 6807.50 5183.70 -4198.72 0.00 0.00 0.00 O.OOG 5983396.27 578842.75 N 70.36473584 W 149.35943302 Mb1 8633.19 73.40 309.63 3967.00 3890.00 6767.75 6924.92 5258.60 -4289.16 0.00 0.00 0.00 O.OOG 5983470.15 578751.49 N 70.36494031 W 149.36016807 Cry 3/100 8668.20 73.40 309.63 3977.00 3900.00 6800.11 6958.48 5280.00 -4315.00 0.00 0.00 0.00 93.21G 5983491.26 578725.41 N 70.36499873 W 149.36037809 8700.00 73.35 310.62 3986.10 3909.10 6829.56 6988.95 5299.64 -4338.30 3.00 -0.16 3.13 92.92G 5983510.64 578701.90 N 70.36505234 W 149.36056747 8800.00 73.22 313.75 4014.86 3937.86 6922.93 7084.72 5363.95 -4409.25 3.00 -0.13 3.13 92.02G 5983574.15 578630.24 N 70.36522792 W 149.36114420 Mb2 8842.00 73.18 315.07 4027.00 3950.00 6962.46 7124.93 5392.08 -4437.98 3.00 -0.10 3.13 91.64G 5983601.97 578601.22 N 70.36530474 W149.36137766 8900.00 73.14 316.89 4043.80 3966.80 7017 .28 7180.44 5432.00 -4476.55 3.00 -0.07 3.13 91.12G 5983641.45 578562.20 N 70.36541372 W 149.36169125 9000.00 73.11 320.02 4072.84 3995.84 7112.33 7276.13 5503.61 -4540.01 3.00 -0.03 3.13 90.21G 5983712.34 578497.96 N 70.36560924 W 149.36220713 Me 9065.92 73.11 322.09 4092.00 4015.00 7175.26 7339.21 5552.66 -4579.66 3.00 0.00 3.14 89.60G 5983760.95 578457.77 N 70.36574319 W 149.36252948 9100.00 73.12 323.16 4101.90 4024.90 7207.84 7371.82 5578.57 -4599.45 3.00 0.03 3.14 89.29G 5983786.64 578437.69 N 70.36581394 W 149.36269042 9200.00 73.18 326.29 4130.89 4053.89 7303.53 7467.52 5656.69 -4654.72 3.00 0.06 3.13 88.39G 5983864.13 578381.57 N 70.36602727 W 149.36313979 9300.00 73.29 329.42 4159.75 4082.75 7399.15 7563.27 5737.75 -4705.65 3.00 0.11 3.13 87.48G 5983944.61 578329.75 N 70.36624863 W 149.36355401 End Cry 9340.4 7 73.34 330.69 4171.37 4094.37 7437.76 7602.04 5771.35 -4725.01 3.00 0.14 3.13 O.OOG 5983977.99 578310.02 N 70.36634037 W 149.36371141 Na 9360. 13 73.34 330.69 4177.00 4100.00 7456.50 7620.87 5787.77 -4734.23 0.00 0.00 0.00 O.OOG 5983994.30 578300.62 N 70.36638521 W 149.363. Nb 9429.91 73.34 330.69 4197.00 4120.00 7523.02 7687.72 5846.06 -4766.96 0.00 0.00 0.00 O.OOG 5984052.22 578267.25 N 70.36654440 W 149.364 Ne 9534.58 73.34 330.69 4227.00 4150.00 7622.81 7788.00 5933.50 -4816.05 0.00 0.00 0.00 O.OOG 5984139.10 578217.20 N 70.36678319 W 149.36445192 OA 9831.15 73.34 330.69 4312.00 4235.00 7905.54 8072.13 6181.24 -4955.15 0.00 0.00 0.00 O.OOG 5984385.27 578075.37 N 70.36745976 W 149.36558338 OSa 10040.49 73.34 330.69 4372.00 4295.00 8105.11 8272.69 6356.12 -5053.34 0.00 0.00 0.00 O.OOG 5984559.03 577975.26 N 70.36793734 W149.36638210 OSb 10197.50 73.34 330.69 4417.00 4340.00 8254.79 8423.11 6487.28 -5126.98 0.00 0.00 0.00 O.OOG 5984689.35 577900.17 N 70.36829552 W149.36698117 OSe 10354.50 73.34 330.69 4462.00 4385.00 8404.47 8573.53 6618.44 -5200.63 0.00 0.00 0.00 O.OOG 5984819.68 577825.09 N 70.36865369 W149.36758025 Target 10511.51 73.34 330.69 4507.00 4430.00 8554.15 8723.95 6749.60 -5274.27 0.00 0.00 0.00 O.OOG 5984950.00 577750.00 N 70.36901187 W149.36817936 OSd 10511.54 73.34 330.69 4507.01 4430.01 8554.18 8723.98 6749.63 -5274.28 0.00 0.00 0.00 O.OOG 5984950.03 577749.98 N 70.36901195 W 149.36817950 OSe 10720.85 73.34 330.69 4567.00 4490.00 8753.72 8924.50 6924.48 -5372.46 0.00 0.00 0.00 O.OOG 5985123.76 577649.89 N 70.36948943 W 149.36897821 OSf 10860.41 73.34 330.69 4607.00 4530.00 8886.77 9058.21 7041.07 -5437.92 0.00 0.00 0.00 O.OOG 5985239.61 577583.14 N 70.36980781 W 149.36951079 OSf Sase 1101 73.34 330.69 4652.00 4575.00 9036.45 9208.63 7172.23 -5511.56 0.00 0.00 0.00 O.OOG 5985369.93 577508.06 N 70.37016598 W 149.37010997 TO 73.34 330.69 4694.99 4617.99 9179.45 9352.34 7297.54 -5581.92 0.00 0.00 0.00 O.OOG 5985494.44 577436.32 N 70.37050816 W 149.37068242 Leqal Description: Northinq (VI IftUS] Eastinq (XI IftUS] Surface 2539 FSL 3816 FEL S34 T12N R11E UM 5978259.93 583098.29 Target 4007 FSL 3798 FEL S28 T12N R11 E UM 5984950.00 577750.00 BHL 4554 FSL 4104 FEL S28 T12N R11E UM 5985494.44 577436.32 WellDesign Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) N-HIPlan L-211 (N-H)\Plan L-211 PB1\L-211PB1 (P6) Generated 1/30/20042:39 PM Page 2 of 2 L-211 (P11) Proposal Schlumberger Report Date: January 30, 2004 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Expioration Alaska Vertical Section Azimuth: 325.000' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 II, E 0.000 II Structure I Slot: L-PAD / N-H 01/3~ ;/04 TVD Reference Datum: Rotary Table Well: Plan L-211 (N-H) APproved TVD Reference Elevation: no II relative to MSL Borehole: Pian L-211 Sea Bed I Ground Level Elevation: 44.100 II relative to MSL UWUAPI#: 50029 Magnetic Declination: 25.028' Survey Name I Date: L-211 (P11) / March 18, 2004 Total Field Strength: 57559.131 nT Tort I AHD I DDII ERD ratio: 84.881'/7388.9811/6.105/1.618 Magnetic Dip: 80.822' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 18, 2004 Location LatlLong: N 70.35057765, W 149.32532407 Magnetic Declination Model: BGGM 2003 Location Grid NIE YIX: N 5978259.930 IIUS, E 583098.290 IIUS North Reference: True North Grid Convergence Angle: ..0.63539136' Total Corr Mag North .) True North: +25.028' Grid Scale Factor: 0.99990784 Local Coordinates Referenced To: Well Head . Comments KOP Drill Ahead UG4 UG4A UG3 Fault Crossing 6716.97 67.70 333.53 3597.00 3520.00 4969.67 5025.27 4498.49 -2239.84 0.00 0.00 0.00 O.OOG 5982732.89 580808.92 N 70.36286620 W 149.34351806 UG1 6730.15 67.70 333.53 3602.00 3525.00 4981.73 5037.46 4509.41 -2245.27 0.00 0.00 0.00 O.OOG 5982743.74 580803.37 N 70.36289602 W 149.34356223 Cry 4/100 7119.21 67.70 333.53 3749.60 3672.60 5337.72 5397.44 4831.66 -2405.70 0.00 0.00 0.00 -91.28G 5983064.16 580639.39 N 70.36377624 W 149.34486620 7200.00 67.67 330.04 3780.28 3703.28 5411.91 5472.17 4897.50 -2441.02 4.00 -0.04 -4.32 -89.96G 5983129.61 580603.34 N 70.36395609 W 149.34515331 7270.35 67.70 327.00 3807.00 3730.00 5476.86 5537.25 4953.00 -2475.00 4.00 0.04 -4.32 -92.29G 5983184.72 580568.75 N 70.36410767 W 149.34542949 Ma 7270.38 67.70 327.00 3807.01 3730.01 5476.89 5537.27 4953.02 -2475.01 4.00 -0.16 -4.32 -92.29G 5983184.74 580568.74 N 70.36410772 W 149.34542960 7300.00 67.66 325.72 3818.26 3741.26 5504.28 5564.68 4975.83 -2490.19 4.00 -0.14 -4.32 -91.81G 5983207.38 580553.31 N 70.36417004 W 149.345. Mb1 7388.60 67.59 321.89 3852.00 3775.00 5586. 17 5646.60 5041.93 -2538.57 4.00 -0.08 -4.33 -90.35G 5983272.93 580504.21 N 70.36435057 W149.345 7400.00 67.59 321.39 3856.35 3779.35 5596.69 5657.14 5050.20 -2545.11 4.00 -0.02 -4.33 -90.16G 5983281.12 580497.58 N 70.36437314 W 149.34599 7 7500.00 67.64 317.07 3894.45 3817.45 5688.66 5749.60 5120.20 -2605.47 4.00 0.05 -4.33 -88.51G 5983350.44 580436.45 N 70.36456433 W 149.34648982 Mb2 7546.18 67.70 315.07 3912.00 3835.00 5730.85 5792.31 5150.96 -2635.10 4.00 0.13 -4.32 -87.75G 5983380.87 580406.48 N 70.36464834 W 149.34673063 End Cry 7548.49 67.70 314.97 3912.88 3835.88 5732.96 5794.44 5152.47 -2636.61 4.00 0.16 -4.32 O.OOG 5983382.36 580404.96 N 70.36465246 W 149.34674289 Me 7677.94 67.70 314.97 3962.00 3885.00 5850.90 5914.22 5237. 12 -2721.34 0.00 0.00 0.00 O.OOG 5983466.06 580319.30 N 70.36488364 W 149.34743149 Na 7875.59 67.70 314.97 4037.00 3960.00 6030.97 6097.08 5366.36 -2850.71 0.00 0.00 0.00 O.OOG 5983593.85 580188.52 N 70.36523657 W149.34848281 Nb 7941.47 67.70 314.97 4062.00 3985.00 6090.99 6158.03 5409.44 -2893.83 0.00 0.00 0.00 O.OOG 5983636.44 580144.93 N 70.36535422 W 149.34883326 Ne 8046.88 67.70 314.97 4102.00 4025.00 6187.03 6255.56 5478.37 -2962.83 0.00 0.00 0.00 O.OOG 5983704.59 580075.18 N 70.36554245 W 149.34939399 OA 8297.23 67.70 314.97 4197.00 4120.00 6415.11 6487. 18 5642.07 -3126.69 0.00 0.00 0.00 O.OOG 5983866.45 579909.52 N 70.36598949 W149.35072577 OBa 8455.34 67.70 314.97 4257.00 4180.00 6559.17 6633.4 7 5745.46 -3230. 18 0.00 0.00 0.00 O.OOG 5983968.68 579804.90 N 70.36627182 W149.35156692 OBb 8560.75 67.70 314.97 4297.00 4220.00 6655.20 6731.00 5814.39 -3299.18 0.00 0.00 0.00 O.OOG 5984036.83 579735.15 N 70.36646004 W 149.35212770 OBe 8692.52 67.70 314.97 4347.00 4270.00 6775.25 6852.91 5900.55 -3385.42 0.00 0.00 0.00 O.OOG 5984122.02 579647.97 N 70.36669532 W 149.35282869 OBd 8837.45 67.70 314.97 4402.00 4325.00 6907.30 6987.00 5995.33 -3480.29 0.00 0.00 0.00 O.OOG 5984215.73 579552.06 N 70.36695412 W 149.35359979 WellDesign Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) N-HIPlan L-211 (N-H)IPlan L-211IL-211 (P11) Generated 1/30/2004 2:37 PM Page 1 of 2 OBe Target OBf OBf Base TD / 1" Csg Lellal Description: Comments 67.70 314.97 4566.87 4489.87 7303.13 7388.98 6279.42 -3764.66 Surface 2539 FSL3816 FELS34 T12N R11E UM Target 3374 FSL 2126 FEL S28 T12N R11E UM BHL 3537 FSL 2289 FEL S28 T12N R11E UM North)na IVI rftUSl 5978259.93 5984335.00 5984496.63 Well Design Ver 3.1 RT-SP3.03-HF2.03 Bld( do31 rt-546 ) Eastina IXI rftUSl 583098.29 579430.00 579264.58 0.00 N-H\Plan L-211 (N-H)\Plan L-211\L-211 (P11) 0.00 0.00 O.OOG 5984496.63 latitude N 70.36725997 W 149.35451113 N 70.36728349 W 149.35458123 N 70.36742465 W149.35500186 N 70.36765050 W149.35567487 579264.58 N 70.36772987 W 149.35591137 . e Generated 1/30/2004 2:37 PM Page 2 of 2 iE" Õ o o ~ g ~ II (1) -¡¡; u C/) o ~ . . . ........................ ........................ ...................... ................u.........:.".................................~..........···........,.............·.z....................... .................,...... .........."............. J. , ··5"·-..-····i····ËñéjBid·..···-···..-··t·····-·····-..-··-"-··-"·i·-···..-··-··-..-..-··-··-·t···..-..···-..-···..······-¡-·-··-..-······..-·····-..-t·..·..-··-·····-···..-..-·"t··-··-..-..-··-··-······..1·-·····-···..-..-··-··-··-·1-···..·..- i : ~ Fault Crossing ; ~ ~ ~ 1 ~ 1 ::t::~::~::~::~::~::~::~:J:::::.~::~::~::~::~::_......::~::~::"..::~::_._.._.._...........-1...'-....._.····-..····..·..r·····-··-·····-··-·····-··1···..-..-··-·····-··-·····-·t·..·..···-········-·······-r··-···..·········-··-···..-t·······-··-..······-··-··-·j-········- -1:~~----:::t--------t--------+---------t--------I---------1---- ...........................""..""...",............................"....................................".......,................. ..."....~...."......."......................~............""...................._.1.¡,::..._.............~............................!,:::, I':,.: r !lm_lm'~-·~lmm'~.'.',..,"- - - ~~. : ¡ ! i . I I -··'''~l:;;;;;·-- " . ~ . ~ ¡ : . . L.~1PB1(P6) .................."..H.......""........~.........«.........................~........'''....'''....................~............'''..........".........~...............,.....................~..........h...,....................~....,............,...,.......H.....-:.............................,.......i:.....................................}H.'........ WELL Magnetk:Parametera Model: BGGM 2003 o o 1000 2000 3000 4000 5000 o Schlumberger L-211 PB1/L-211 (P6-11) FIELD STRUCTURE L-PAD Prudhoe Bay Unit - WOA Dip: 80.822" Mag Dee: +25.028" Date: March18,2004 FS: 57559.1nT Surface Location Lal: N7021 2.080 Lon: W1491931.167 Mi$OØllaneous Slot N-H Plan: L.211 (P11) TVDRef: Rotary Table (77.00ftabove MSL) Srvy Date: March 18, 2004 NAD27 Alaska Stale Planes, Zone 04, US Feel Northing: 5978259.93 flUS Grid Conv: +0.63539138" Easling: S83098.29ftUS Scale Fact: 0.9999078443 1000 5000 7000 . o 8000 9000 6000 2000 3000 4000 1000 2000 e 3000 4000 5000 1000 2000 3000 4000 5000 6000 Vertical Section (ft) Azim = 325°, Scale = 1(in):1000(ft) Origin = 0 Nt-S, 0 E/-W 7000 8000 9000 . . Schlumberger WEU. L-211 PB1/L-211 (P6-11) FIELD Prudhoe Bay Unit - WOA smucTl'" L-PAD MagneIiç PamneteB Model: BGGM 2003 Dip: 80.822" Mag Dee: +25.028" Date: MardI 18, 2004 FS: 57559.1 nT Surface Location Lat N70 21 2.080 Lon: W1491931.167 NAD21 Alaska State PMnes, Zone 04, us Feet Norttmg: 5978259.93ftUS GridConv: +0.63539136" Easting: 58309B29 ft\JS Scale Fact: 0.9999018443 -~ Slot N.Ii Plan: L-211(P11) TVDRet. RotaryTable(77.00ftabowMSl.) SrvyDate: Mareh18,2004 -5000 -4000 -3000 -2000 -1000 o 7000 7000 6000 6000 5000 5000 ^ ^ ^ z 2" 0 4000 4000 0 0 T"" §: T"" II Q) 13 CI) CI) 3000 3000 V V V o 2000 2000 1000 1000 o -5000 -4000 -3000 -2000 <<< W Scale = 1(in):1000(ft) E >>> -1000 o . . Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 3940 Arctic Blvd, Site 300 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Friday, January 30, 2004 Thomas Schaefer Prudhoe Bay L-211 PB1 (P6) BP Exploration Alaska Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survev Proaram: Instrument Type MWD+ IFR+ MS Start Depth 28.50'md End Depth 11,167.42'md Close Approach Analvsis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillina Aids to be provided: A Drilling Map and Traveling Cylinder will be provided. Checked by: Scott Delapp 01/30104 . BPX AK Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 11167.42 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 1/23/2004 Validated: No Planned From To Survey ft ft 28.50 11167.42 Planned: Plan #6 V2 Version: Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points EX NWE#1 NWE1-01A NWE1-01A V4 249.99 250.00 218.04 4.64 213.39 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01 V3 249.99 250.00 218.03 4.64 213.39 Pass: Major Risk PB L Pad L-01 L-01 V14 300.00 300.00 214.19 4.71 209.47 Pass: Major Risk PB L Pad L-01 L-01 L 1 V2 Plan: Plan # 300.00 300.00 214.19 4.71 209.47 Pass: Major Risk PB L Pad L-02 L-02 V1 593.84 600.00 41.88 9.47 32.41 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 593.84 600.00 41.88 9.58 32.30 Pass: Major Risk PB L Pad L-102 L-102 V2 248.00 250.00 333.24 3.90 329.35 Pass: Major Risk PB L Pad L-102 L-102PB1 V10 248.00 250.00 333.24 3.99 329.25 Pass: Major Risk PB L Pad L-102 L-102PB2 V2 248.00 250.00 333.24 3.99 329.25 Pass: Major Risk PB L Pad L-103 L-103 V23 397.42 400.00 206.12 6.35 199.77 Pass: Major Risk PB L Pad L-104 L-104 V7 345.20 350.00 306.44 5.67 300.77 Pass: Major Risk PB L Pad L-105 L-105 V4 345.55 350.00 275.55 6.01 269.55 Pass: Major Risk PB L Pad L-106 L-106 V14 575.66 600.00 280.73 9.18 271.55 Pass: Major Risk PB L Pad L-107 L-107 V14 199.68 200.00 222.93 4.28 218.65 Pass: Major Risk PB L Pad L-108 L-108 V18 530.91 550.00 257.73 9.29 248.45 Pass: Major Risk PB L Pad L-109 L-109 V12 300.00 300.00 184.86 6.04 178.82 Pass: Major Risk PB L Pad L-110 L-110V11 299.89 300.00 181.54 5.29 176.25 Pass: Major Risk PB L Pad L-111 L-111 V24 300.00 300.00 210.24 5.14 205.10 Pass: Major Risk PB L Pad L-112 L-112 V8 445.29 450.00 63.83 8.79 55.04 Pass: Major Risk PB L Pad L-114 L-114 V15 396.69 400.00 193.29 6.02 187.26 Pass: Major Risk PB L Pad L-114 Plan L-114A V1 Plan: P 396.69 400.00 193.29 6.07 187.22 Pass: Major Risk PB L Pad L-115 L-115V7 299.99 300.00 15.95 5.04 10.91 Pass: Major Risk PB L Pad L-116 L-116V10 396.17 400.00 184.13 5.79 178.35 Pass: Major Risk PB L Pad L-117 L-117V11 499.31 500.00 30.48 7.65 22.82 Pass: Major Risk PB L Pad L-118 L-118V9 250.07 250.00 47.25 4.48 42.77 Pass: Major Risk PB L Pad L-119 L-119V9 396.77 400.00 252.28 6.35 245.93 Pass: Major Risk PB L Pad L-120 L-120 V8 297.88 300.00 282.14 4.93 277.21 Pass: Major Risk PB L Pad L-121 L-121 V14 200.59 200.00 184.43 3.53 180.90 Pass: Major Risk PB L Pad L-121 L-121A V1 200.59 200.00 184.43 3.53 180.90 Pass: Major Risk PB L Pad L-122 L-122 V5 400.07 400.00 16.50 6.33 10.17 Pass: Major Risk PB L Pad L-200 L-200 OBd V3 398.63 400.00 115.29 6.75 108.54 Pass: Major Risk PB L Pad L-200 Plan L-200L2 OBa V3 PI 448.26 450.00 115.82 7.86 107.96 Pass: Major Risk PB L Pad L-200 Plan L-200L3 OA V3 Pia 448.26 450.00 115.82 7.86 107.96 Pass: Major Risk PB L Pad L-21 0 L-21 0 V6 247.69 250.00 265.23 4.04 261.18 Pass: Major Risk PB L Pad L-210 L-210PB1 V8 247.69 250.00 265.23 4.04 261.18 Pass: Major Risk PB L Pad Plan L-113 (N-B) Plan L-113 V5 Plan: PI 404.91 400.00 90.81 8.40 82.41 Pass: Major Risk PB L Pad Plan L-123 (N-R) Plan L-123 V1 Plan: PI 550.52 550.00 191.70 9.39 182.31 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124 PB1 V1 Plan 857.78 850.00 71.68 14.74 56.94 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124 V1 Plan: PI 857.78 850.00 71.68 14.74 56.94 Pass: Major Risk PB L Pad Plan L-201 (N-U) Plan L-201 OBd V1 Plan 397.05 400.00 235.69 6.90 228.79 Pass: Major Risk PB L Pad Plan L-201 (N-U) Plan L-201L 1 OBb V2 PI 397.05 400.00 235.69 7.01 228.67 Pass: Major Risk PB L Pad Plan L-201 (N-U) Plan L-201L2 OBa V2 PI 397.05 400.00 235.69 7.01 228.68 Pass: Major Risk PB L Pad Plan L-201 (N-U) Plan L-201L3 OA V3 Pia 397.05 400.00 235.69 6.90 228.79 Pass: Major Risk PB NW Eileen NWEILEEN-1 NWEILEEN-1 V1 8575.67 3950.00 235.27 186.64 48.63 Pass: Major Risk . BPX AK Anticollision Report . PB NW Eileen NWEILEEN-2 NWEILEEN-2 V1 8323.72 3033.00 874.09 504.96 369.12 Pass: Major Risk 215~5 ,40 FMC Camco gas lift mandrel 4-1/2" xi" KBG-2 With DCK Shear Valve pinned to 2,500 3.813" seal bore. I -~ --C I PLANT -115'00'00" GRID L-111i. L-114 . L-SD . L-121 . L-110. L-SI . L-116 . L-109 . L-SL . L-01 . L-107 . L-108i. L-105i. L-106 . L-104 . S-W . L-102 . LOCA TED WELL NO. L-124 L-211i ~ ~~ NOTES L-PAD . . N-L (NWE-1) · N-A (NWE-2) iL-113 L-124 L-112i · L-02 iL-122 L-211i L-115i · L-117 · L-118 · L-200 D~ · L-123 · L-103i · L-201 · L-119i · L-21Oi · L-120 .<,.,' "_~_'....,'... U ,":. ,'". . _! .ã- ;..)1\: VICINITY MAP N.T.S. LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 5, 2004. 1. DATE OF SURVEY: JANUARY 5, 2004. 2. REFERENCE FIELD BOOK: W004-01 PAGES 04-05. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. F. Robert DRAWN: ObP COTTON llirn~ CHECKED:HACKLEMAN DATE: 1/08/04 DRAWlNG: GPB WOA L -P AD SHEET: FRB04 WOL 02-00 ~ ffi~~Œn~o JOB NO: SCALE: AS-BUILT CONDUCTORS o 1 06 04 ISSUEO FOR INFORMA liON JJC OAO ENClNErRSANDlANDSUft'ÆYCRS WELLS L-124 & L-211i 1 OF 1 801\IIEST F1REWEED LANE 1'= 130' NO. OAìE REVISION BY CHK ANCliORAGE. AlASKA 911~ WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION COORDINATES COORDINATES POSITION OMS POSITION 0.00 BOX ELEV. OFFSETS Y= 5,978,240.59 N= 10,000.09 70'21'01.897" 70.3505269' 48.3' 2,521' FSL X= 583,025.79 E= 5,030.01 -149'19'33.292" -149.3259142' 3,889' FEL Y= 5,978,259.93 N= 10,000.02 70'21 '02.080" 70.3505778' 48.5' 2,540' FSL X= 583,098.29 E= 5,105.05 -149'19'31.167" -149.3253242' 3,816' FEL p055218 DATE INVOICE I CREDIT MEMO DESCRIPTION DATE 1/6/2004 CHECK NO. 055218 GROSS VENDOR DISCOUNT NET 1/6/2004 PR010504B PERMIT TO DRILL L,2,\ \ ; R CEtVEl) EB 0 5 2004 Alaska 0 I & Gas Cons. Anchorage 01'1 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) ING. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, PAY: TO THE ORDER OF: BP ~~ "r . .-~..L OF ALASKA AOGCC 333 WEST 7TH AVENUE ANCHORAGE, AK 99501-3539 NATIONAl,. CITY BAN.K Ashland. Ohio No. P 055.218 56"389 412 CONSOLIDATED COMMERCIAL ACCOUNT II· 0 5 5 2 . a II· I: 0... . 2 0 ~ a ~ 5 I: o. 2 ? a ~ ¡; U· H . . . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME t!JU 1.-2/// PTD# 2oc.¡ -Ob! CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MlJL TI The permit is for a new wenbore segment of LATERAL existing well . Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function· of the original API number. stated are between 60-69) above. Pn.,OT BOLE In accordance with 20 AAC 25.005(1), an ¡/ (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) !7ß¿, t.~ I/¡' fJlI and API Dumber (50-02. 9 - z Rtt ,'l8Jtt6) from records, data and logs acquired for wen (name on permit). SPACING The permit is approved subject to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Company Name) assumes the liability of any protest to tbe spacing exception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample intervals througb target zones. 3/'1}- 7èJ Rev: 07/10/02 C\jody\templates Field & Pool PRUDHOE BAY. ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L-211 i Program SER Well bore seg PTD#: 2040290 Company BP EXPLORATION (ALASKA) INC Initial ClassfType SER 11WINJ GeoArea Unit On/Off Shore On Annular Disposal 1 P~rmitfee attache~:t _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _. . _ _ _ _ _ Y~s _ _ _ _ _ . _ _ _ _ _ _ _ _ _. . _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ 2 _Leas~number _appropriate _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . Yes _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ . _ . _ 3 _U_n[que weltn_arn~_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJlJocat~d [n_a.d_efjneJ:l-pool _ _ . . . . _ _ _ _ _ _ _ . _ _ _ _ . _ Y~s _ _ _ _ _ _ The_Schrader _Bluff_oil pool consists _of the N_and O_sands.ofthe Schrad_er 61uff forrnation, ThJs_ wellJs _ . _ _ 5 WeIlJocat~dpr_oper_distancefromdriJlingunitb_ound_ary_ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _.. _ _ _ _. Y~s_ _ _ _ _. _programedtoÞecompJe.ted_iotheMsandsas_wellasthe.D.s_ands_ _ _ _ _' _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 6 WeJlJocat~d proper _distance_ from otber wel!s_ _ _ _ _ _ _ _ _ Y~s _ _ _ the appJica_tion states this Js_ for sarnpUn.g _M sand oi] and_not producing the M sand inteIVat _ _ _ _ _ _ . _ 7 _S_uffjcientacreage_aYailablein dJilliogunjt _ _ _ _. _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _.. _ _ _ _ _ Y~s_ _ _ _ _ _ _The_aitach~de-mail,d~scribes.B~'splan_a_ndindicatesthewell will ooLbe COmiogledwithoutAOGCC_approvaJ._ . 8 Jf.d~viated, js weJlbore platincluJ:led _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ _ _ _ _ _ _ R¡:>C . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ . _ _ _ _ _ _ _ . _ _ 9 _O-per_ator only affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ 10 _O-perator bas_appropriate_bond inJorce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P~unit can be issued witbout co_nserva_tion order _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Appr Date 12 P~unit c_ao be issued witbout administrative_a-pprovaJ _ _ _ _ _ . _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ RPC 2/11/2004 13 Can permit be approved before 15-day wait Yes 14 We.IIJocat~dw[thinareaand_strata.author[zedby_lojectiooOrd_er#(PutlOtlin cornrn_eots) (For_ Yes_ _ _ AI026 _ _ _ _ _ _ _ _ _.... _ _ _ _ _ _ _ _ _ _ __ 15 Allwel!s_withtnJl4_mile_are.a_ofreyiewid~otified(ForseIVJ~_w.eUonly)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s_ _ _ _ _ _ _~WJ:;ileen_#.1_and~see.attacheçlmap_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre.-prOducediojector; _duration_ofpre--productiool~ss_than3montbs.(For_servicewelI only) _ _ NA _ _ _ _ _ _. _ _ _ . _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _. _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ __ 17 ACMPFindjng_ofConsisteocy_h_as beenJssued_fortbis proiect _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 18Cooductor string_pJovided _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ 19 _S.ur:fa~_casingpJotectsaILknownUSDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv.otadeQuateto circ_utate_o_ncond_uctor& SUJtcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .' _ _ _ Y~s _ _ _ _ _ _ .A.de_quate excess, _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . _ 21CMT v_ot adeQuateto tie-tnJong _string to_sul:f ~g _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwil! coyer_aJl koow_n_productiYe borizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 23 _C_asiog de.sigos ad_eQua_te for C,.T, B _& permafr_ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Y_es _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Adequate.tankage_oJ re_serve pit _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Y~s _ _ _ _ _ _ _ ~ab.ors_9ES, _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Jf.a re-drilt bas_ a to-403 for abandonme_nt be~o apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ NA _ _ _ _ _ _ New well. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 AdequateweUbore. separatioll_pro-posed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf.diver::ter Jeq_uired, does it meet reguJations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Appr Date 28 _DJilIiogfJuid_programsc.hematic_&ect-uipJistadequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es_ _ _ _ _ _ . MaxMW_9Jipp.g. _ _ _ _ _... . _ _ _ _. _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. __ WGA 2/10/2004 29 BOPEs..d_othey meetregu.laJion . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ 30 _BOPEpressra_tiog appropriate;.testto(put psig in_comments)_ _ _ _ _ _ _ _ _ _ _ _ _ . _ _Y~s. _ _ _ _ _ _ Testto4000_psi.MS~ 15_37 psi. _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . _. _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _C_hokemanifold compJies_ w/API. Rf'-53. (May 54). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occ_ur withoutoper¡¡tion_shutdo_wn_ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 .Is preseoce. of H2S gas pJobable _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ Notdesignated .H2S pad. _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecban[caLcooditiooofwe.lIsw[thin.A.ORyerified(for_selVicewel!onJy) _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s_ _ _ _ _.A.Il.A.ORweltsPM'd, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _. _ _ _ _ _ _ _ __ Administration Engineering - - - - - - - - - - - - - - -- - - - - - - - - Geology 35 Peunit cao be issued w/o hydrogen_ s_ulfide meaSJJres _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ 36 _D_atapJeseoted on_ pote_ntial oveJRressuœ _zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 37 _S~isrnic_analysJs_ of sballow gaszooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 38S~abed _conditioo survey.(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Contact namelphoneJorweekly progress_reports [exploratory .only). _ _ _ _ _ _ _ _ _ . _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr RPC Date 2/9/2004 D D . .. Geologic Commissioner: Engineering Commissioner: Date Public Commissioner Date: Date D~ ~JIlI1-- e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I I I I I I I I I I I I I I I I I I I e e ~f) If ~ D J.-C¡ Schlumberger Fluid Analysis on Bottomhole Samples BP Field: Orion Well: L-211 CONFIDENTIAL Black Oil Full PVT Study Report Prepared for Greg Bernaski BP . . , CONFIDENTIAL Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared by: Meisong Van Reviewed by: Dennis D'Cruz Schlumberger WCP Oilphase-DBR 16223 Park Row, Suite 170 Houston, Texas, 77084 (281) 829-2225 Date: 3/31/2005 Report #200400186 I e I Client Well: Installation: Field: Sand: Job #: Orion Mb1 200400186 BP L-211 Coil Tubing Unit 9 e 1.lmbIPUIP I Table of Contents List of Figures . List of Tables I EXECUTIVE SUMMARy.... Objective Introduction Scope of Work.... Results Sequence of Events. . . Chain of Sample. Custody """"....... .... ............" . "..".",,,.,,,. I .................. I RESULTS ANDOISCUSSIONS.. Fluids Preparation and Analysis Reservoir FluidAnalysis... ..................... ......... . I "............. 4 4 4 4 4 5 5 .............".... 6 6 6 I PVT Analysis on.Sample#:.1.02; SSB10713~MA; .MblSaßd;MD:;: 64.46 ftIVD:;::; 3468ft; TVDSS;:d39Ut. Constant Composition. Expansion .at. Tres. . .. ............. Reservoir Oil Viscosity at .Tres. .............. 12 12 14 I Appendix A: Nomenclature and De.finitions .. Appendix B: Molecular Weights and Densities Used.. Appendix C: EQUIPMENT... Fluid Preparation. and. Validation Fluid Volumetric (PVIJ and .Viscosity.Equipment .. Appendix 0: PROCED.URE Fluids Preparation and.Validation.. . Constant Composition Expansion Procedure. . Differential Vaporization Procedure. . . Multi-StageSeparation.TesL.. . ... ......... Liquid Phase Viscosity.and.Deasity.Measurements.During.DV.Step..... Stock-Tank Oil (S.TOl Viscosity and.Density Measurements... Asphaltene, Wax .and.Sulfur Content Measurements. . . SAR(PJA Analysis.. High- Temperature. Hjgh~Pressure. Filtration. Test. ................... I ...... ........, I I I I I I I I I WCP Oilphase-DBR . ........ . ....".. . . . . . . . . . . . . . . . .. .,.. 16 17 18 18 18 21 21 21 21 21 22 22 22 23 23 ................... Job #: 200400186 I I Client: Well: Installation: e BP L-211 Coil Tubing Unit 9 Field: Sand: Job #: Orion Mb1 200400186 e le_luRiIPUIP I List of Figures I Figure 1: Stock Tank. Oil. Chromatogram (Sample 1.02).. Figure 2: k-Plot f.or. Equilibrium.Che.ck.(Sample.1.02)....... Figure 3: Constant .C.omposition .Expaosion at 73.~F~. Relative Volume .. Figure 4: Reservoir.FIuidViscosity.73°F. I I I I I I I I I I I I I I I WCP Oilphase-DBR ............."..... 2 . . . . . . . . . . . . . . 10 10 13 15 Job #: 200400186 I e I Client: Well: Installation: Orion Mb1 200400186 BP L-211 Coil Tubing Unit 9 Field: Sand: Job #: e S_IPII I List of Tables Table 1: Well and.Samp.le .Identification....................... ..................................................................... Table 2: Sampling aDd Transfe.r. Summary.. ... ... . .. . ... .. ... ... . .. . ... ... .. . .. . ... ... .. ... .... ... .. ... ... . .. . ... .. ... ... ... . ..... .. Table 3: Reservoir fluid. Properties. .... ..... . .. ... . ... ... .. ... . .. . ... ..... ... . .. .... ..... .. ......................................... Table 4: Stock-Iank.Q.ilPlop.erties................................................... ............................................... Table 5: C36+ Composition. GOR. .oAPI..by.Singl.e.-.8.tage.Flash. (Sample. 1.02) .. Table 6: Calculated .Fluid .Ploperties.. Table 7: Summary. of.Re.sultsofSample.1.02... Table 8: Constant .CompositionExpansion at 73~F (Sample.1.02.I... Table 9: ReservoirJluidViscosityJ3°F I I I I I I I I I I I I I I I I WCP Oilphase-DBR 3 7 7 7 7 8 9 11 12 14 .............. ............ . Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Schlumbergep EXECUTIVE SUMMARY Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected from the SRS (Single-Phase Reservoir Sampler). Introduction At the request of BP, Oilphase-DBR has conducted a fluid analysis study on bottomhole fluid samples collected from the SRS (Single-Phase Reservoir Sampler) of Well L-211 drilled in the field Orion. Scope of Work . Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for five days. · Conduct preliminary evaluation on bottomhole hydrocarbon samples that includes single-stage flash Gas Oil Ratio (GOR), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. · Select a representative sample for the PVT study. · Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. · Also conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottomhole hydrocarbon and water samples: · Two bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for five days. · Sample 1.01 ran out of volume during the sample quality check. · The bottomhole sample 1.02 was validated by measuring its bubblepoint pressure at the reservoir temperature. The bubblepoint pressure is 392 psia whereas the reservoir pressure is 1254 psia. Thus, this sample was considered valid for further analyses. · The zero flash GOR was determined to be 29 SCF/STB and the STO density to be 0.991 glee. WCP Oilphase-DBR 4 Job #: 200400186 I I I I I I I I I I I I I I I I I I I -- e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Se_lumberglr Sequence of Events 07/22/04 Sample arrived and clinet was notified. 07/23/04 Project work scope discussed. 07/23/04 Work agreement approved. 08/25/04 Sample quality check finished. Sample 1.01 ran out of the volume during the quality check. 09/09/04 The sample 1.02 PVT study confirmed. 09/24/04 The invoice for the sample quality check sent.lnvoice#: 9091267408. 10/01/04 The PVT results for sample 1.02 were sent via e-mail. Chain of Sample Custody The samples collected from the well of L-211 were sent to Oilphase-DBR in Houston, Texas. The samples were used for preliminary measurements and subsequent further PVT studies. The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. WCP Oilphase-DBR 5 Job #: 200400186 I e e I Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job #: Orion Mb1 200400186 Schtllbe.,l.. RESUL IS AND DISCUSSIONS I I Fluids Preparation and Analysis Two bottom hole samples collected from the SRS were transferred to Oilphase-DBR. The well and formation data with their respective reservoir conditions for the bottom hole samples are summarized in Table 1. The quality check for the bottom hole samples was conducted and the results are summarized in Table 2. After five days of homogenization, sample validation tests were conducted to evaluate the validity of the samples, and sample 1.02 was good candidates for PVT analysis while sample 1.01 ran out of volume. Sample 1.02 was selected for Prelim and PVT analysis. The reservoir fluid and stock-tank oil properties for all the samples are presented in Table 3 and Table 4. I Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GaR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 5. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flashed gas were calculated from the compositions and are listed in Table 6. I I I I I I I I I I I I I I WCP Oilphase-DBR 6 Job #: 200400186 I e e I Client Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mbl 200400186 SchlllOlJ8'I'" Table 1: Well and Sample Identification I Client BP Job# 200400186 Field: Orion Well: L-211 Study Samples Reservoir Conditions Sample ID Cylinder # Sand Name Sampling Date Pressure Temperature MD TVD TVDSS Ipsial IOFI (ftl Iftl (ftl 1.01 SSB 10714-MA Mbl 7/11/2004 1,254 73 6,446 3,468 -3,391 102 SSB 10713-MA Mbl 7/13/2004 1.254 73 6,446 3,468 -3,391 I I I Table 2: Sampling and Transfer Summary Opening Transfer Opening Initial Final Sample ID Chamber # Sand Name conditions Cylinder conditions FS&W BS&W Sample Sample in the field 10 in the Lab Volume Volume Ipsia¡OFI (psia¡OFI Iccl (v/v%1 Iccl Iccl 1.01 SRS 240 Mbl SSB 10714-MA 5015/75 350 560 0 1.02 SRS 240 Mbl SSB 10713-MA 5015/75 140 1.5** 580 85 I I *Very high BS&W. De-emulsified 3 times and still cannot break the emulsion. Ran out of volume during the sample quality check. "Very high BS&W. De-emulsified 3 times and got 1.5 v/v% sediment from sample side up. I I Table 3: Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Viscosity of Sample ID Cylinder # Sand Name MD TVDSS GOR* Bo** Pressure monophasic Res. Fluid at Tres fluid at Pres, Tres 1ft) (ftl Iscf/bbll Ipsial (cpl 102 SSB 10713-MA Mb1 6,446 -3,391 29 1.045 392 439.5 28000 I * Flashed gas volume (scfl per barrel of stock tank liquid @ 60°F .. Volume of live oil at its bubble point pressure per flashed stock tank liquid volume @ 60°F *** Calculated from oil-based mud contamination in STO I I 1.02 SSB 10713-MA Mbl Table 4: Stock-Tank Oil Properties STO Properties MD TVDSS Molar Mass Density API (ftl (ftl (g/ccl 6,446 -3,391 484.1 0.991 11.2 I Sample ID Cylinder # Sand Name I I I I I WCP Oilphase-DBR 7 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: BP L-211 Field: Sand: Orion Mb1 Seblumberler Component MW Flashed Gas Flashed liquid Monophasic Fluid (g/mole WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 0.89 0.54 0.00 0.00 0.01 0.05 Hydroqen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 86.66 82.57 0.00 0.00 0.51 8.07 Methane 16.04 9.05 15.05 0.00 0.00 0.05 1.47 Ethane 30.07 0.68 0.60 0.00 0.00 0.00 0.06 Propane 44.10 0.72 0.44 0.00 0.03 0.01 0.07 I - Butane 58.12 0.46 0.21 0.05 0.38 0.05 0.36 N - Butane 58.12 044 0.20 0.00 003 0.01 0.05 I - Pentane 72.15 0.25 0.09 0.00 0.02 0.00 0.02 N - Pentane 72.15 0.61 0.23 0.00 003 0.01 0.05 C6 84.00 0.06 0.02 0.02 0.13 0.02 0.12 M-C-Pentane 84.16 0.04 0.01 0.00 0.01 0.00 0.01 Benzene 78.11 0.03 0.01 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.04 0.01 0.00 0.00 0.00 0.00 C7 96.00 0.02 0.01 0.02 0.10 0.02 0.09 M-C-Hexane 98.19 0.04 0.01 0.00 0.01 0.00 0.01 T 01 uene 92.14 0.02 0.01 0.00 0.01 0.00 0.01 C8 107.00 0.01 0.00 0.00 001 0.00 0.01 E-Benzene 10617 0.00 0.00 0.00 0.00 0.00 0.00 M/P-Xyle ne 106.17 0.00 0.00 0.00 0.00 0.00 0.00 O-Xylene 106.17 0.00 0.00 0.00 002 0.00 0.02 C9 121.00 0.00 0.00 0.01 0.03 0.01 0.02 C10 134.00 0.00 0.00 0.08 0.28 0.08 0.26 C11 147.00 0.00 0.00 0.24 0.79 0.24 0.71 C12 161.00 0.00 0.00 0.46 1.40 0.46 126 C13 175.00 0.00 0.00 0.78 2.16 0.78 1.95 C14 190.00 0.00 0.00 1.16 2.95 1.15 2.66 C15 206.00 0.00 0.00 1.43 3.36 1.42 103 C16 222.00 1.53 135 1.53 102 C17 237.00 171 148 1.69 114 C18 251.00 2.00 185 1.99 148 C19 26100 1.93 155 1.92 120 C20 275.00 2.14 177 2.13 140 C21 291.00 2.10 150 2.09 116 C22 300.00 2.10 139 2.09 106 C23 312.00 2.12 129 2.11 2.97 C24 324.00 1.97 2.94 1.96 2.65 C25 337.00 179 2.57 178 2.32 C26 34900 1.98 2.75 1.97 2.48 C27 36000 1.97 2.64 1.95 2.39 C28 372.00 1.98 2.57 1.97 2.32 C29 38200 1.84 2.33 1.82 2.10 C30 394.00 1.86 2.28 1.84 2.06 C31 404.00 1.82 2.18 1.81 1.97 C32 415.00 1.61 1.88 1.60 1.69 C33 426.00 1.35 1.53 1.34 138 C34 437.00 1.34 1.48 1.33 134 C35 445.00 1.23 1.34 1.22 1.21 C36+ 856.21 59.37 3157 59.02 30.29 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 26.69 484.09 439.46 MOLE RATIO 0.0976 0.9024 Table 5: C36+ Composition, GOR, °API, by Single-Stage flash (Sample 1.02) Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft WCP Oilphase-DBR 8 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: BP L-211 Field: Sand: Orion Mb1 Schlumbepger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole % C7+ 0.19 0.06 99.92 99.38 99.33 89.68 C12+ 0.00 0.00 99.56 98.11 98.97 88.53 C20+ - - 88.56 74.01 88.03 66.78 C30+ - - 68.58 44.26 68.17 39.94 Molar Mass C7+ 89.55 486.71 486.69 C12+ - 491 .22 491.22 C20+ - 579.24 579.24 C30+ - 750.00 750.00 Density C7+ - 0.9918 - C12+ - 0.9928 0.9928 C20+ - 1.0152 1.0152 C30+ 1.0607 1.0607 Fluid at 60°F 0.9913 Gas Gravity (Air = 1 0.922 I Dry Gross Heat Content (BTU/scf) 204 Wet Gross Heat Content (BTU/scf) 200 OBM Contamination Level (wt%1 - STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 485.30 I 484.09 750.00 Density (g/cm3) I 0.991 - 1.061 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 29 STO Density (g/cm3) 0.991 I STO API Gravity 11.2 OBM Density (g/cm3) @60°F Table 6: Calculated fluid Properties Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft WCP Oilphase-DBR 9 Job #: 200400186 I I I I I I I I I I I I I I I I I I I Client Well: BP L-211 Field: Sand: Orion Mb1 -3391 ft FID1 A, pA ø 500 4ûO 300 200 100 ()J) ¡¡: 10 20 30 4û 50 Figure 2: k-Plot for Equilibrium Check (Sample 1.(2) Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft 2.50 2,00 1.50 1.00 0.50 0.00 -050 -400 -3.00 + C3 . ,., C7 . C6 . C9 -2.00 -1.00 000 100 2.00 3.00 F WCP Oilphase-DBR 10 Job #:200400186 I I Client: Well: e e BP L-211 Orion Mb1 Schlulbergep Field: Sand: I I I I I I I I I I I I I I I I I Table 7: Summary of Results of Sample 1.02 Sample#: 1.02; SSB 10713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft Reservoir Conditions: Pressure: 1254 psia Temperature: 73 of Bubble Point Pressure AtT res 392 psia Gas-Oil Ratio Single-stage Flash: 29 scf/stb Total Differential Liberation: scf/stb Total Separator Flash: scf Istb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO: 11.2 0.922 Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: 28000 cP Compressibillity (Co): 10-6/psi Density: g/cc Properties at Saturation Conditions Viscosity: 19911 cP Compressibillity (Co): 3.7 1O-6/psi Density: 0.954 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.042 1.045 Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F WCP Oilphase-DBR 11 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: BP L-211 Field: Sand: Orion Mbl Scblumberger PVT Analysis on Sample#: 1.02; SSB 10713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 73.0°F and at a pressure of 10,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 8. The pressure-volume (P-V) plots of the CCE data are presented in Figure 3. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 392 psia at the reservoir temperature of 73.0 of. Also, calculated relative volume and oil compressibility is presented in Table 8. As seen in the table, the compressibility of this oil is 3.7 x 10e-6 l/psia at the saturation pressure. Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (10-6/psia) 1 10015 0.9665 0.9870 3.4 2 9015 0.9698 0.9837 3.4 3 6017 0.9799 0.9735 3.5 4 5015 0.9834 0.9701 3.5 5 4014 0.9869 0.9666 3.6 6 3016 0.9905 0.9632 3.6 7 2416 0.9926 0.9611 36 8 2215 0.9933 0.9604 3.6 9 2017 0.9941 0.9597 3.6 10 1818 0.9948 0.9590 3.7 11 1517 0.9959 0.9579 3.7 Pi 1254 0.9968 0.9570 3.7 13 1053 0.9976 0.9563 3.7 14 795 0.9985 0.9554 3.7 15 583 0.9993 0.9547 3.7 Pb 392 1.0000 100.0 100.0 0.9540 3.7 17 344 1.0144 99.9 98.5 9.6 18 305 1.0307 99.9 96.9 9.2 19 266 1.0527 99.8 94.8 9.0 20 178 1.1449 99.7 87.1 8.3 21 115 1.3131 99.6 75.9 n 22 84 1.4975 99.6 66.5 7.4 23 66 1.6806 99.6 59.3 7.2 24 49 1.9710 99.6 50.5 7.2 Table 8: Constant Composition Expansion at 73°F (Sample 1.02) Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft WCP Oilphase-DBR 12 Job #: 200400186 I I I I I I I I I I I I I I I I I I I Client: Well: BP L-211 e e Field: Sand: Orion Mb1 Schlulberger WCP Oilphase-DBR Figure 3: Constant Composition Expansion at 73°F - Relative Volume Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft 2.2 1-- -- 1---- ) -- -~~~---- "-~ -- I--- --- ~ 20 1.8 :¡; a.. ~ 1.6 ~ G) e = õ > .~ 14 .. co 'ii cc 1.2 10 0.8 o 2000 4000 6000 8000 1D000 12000 Pressure (psia) 13 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: BP L-211 Field: Sand: Orion Mb1 Schlumbepglr Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 73°F. These values as a function of selected pressure steps are summarized in Table 9. The liquid phase viscosity values are graphically presented in Figure 4. As seen in the figures and as expected. the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 9: Reservoir fluid Viscosity 73°f Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MO = 6446 ft; TVO = 3468 ft; TVOSS = -3391 ft Pressure Viscosity @ Tres (psia) (cP) 1 2530 41612 2 2015 36065 3 1521 30793 Pi 1254 28000 5 978 25142 6 878 24140 7 773 23111 8 715 22558 9 632 21793 10 586 21385 11 517 20806 12 448 20281 Pb 392 19911 14 366 20500 15 323 22300 16 283 23800 17 251 25300 18 199 28000 19 157 30300 20 146 31200 21 102 34200 STO 14.696 44344 WCP Oilphase-DBR 14 Job #: 200400186 I I I I I I I I I I I I I I I I I I I Client: Well: e e BP L-211 Field: Sand: Orion Mb1 Scblumberger 50000 45000 40000 A:" 35000 E. ~ '¡;¡ CI U UI :;: 30000 25000 20000 15000 o WCP Oilphase-DBR figure 4: Reservoir fluid Viscosity 73°f Sample#: 1.02; SSB 1 0713-MA; Mb1 Sand; MD = 6446 ft; TVD = 3468 ft; TVDSS = -3391 ft 500 3000 1000 1500 Pressure (psia) 2000 2500 15 Job #: 200400186 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: e e BP L-211 Coil Tubing Unit 9 Orion Mb1 200400186 Field: Sand: Job#: Sc~lumbergep API Gravity Bg Bo CCE DV GLR GOR LO n OBM P Pb PV Pi R Rs T V Vr STL STO %,w/w Z Appendix A: Nomenclature and Definitions American Petroleum Institute gravity Gas formation volume factor Oil formation volume factor Constant composition Expansion Differential Vaporization Gas Liquid Ratio Gas Oil Ratio Live Oil Number of moles Oil Based Mud Absolute pressure Bubble point pressure Pressure-Volume Method Initial Reservoir Pressure Universal gas constant Solution gas oil ratio Temperature Volume Relative volume Stock Tank Liquid Stock Tank Oil Weight Percent Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from the CRC Handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing. Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=1). The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. · A positive index indicates scaling tendencies. · A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. WCP Oilphase-DBR 16 Job #: 200400186 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: WCP Oilphase-DBR e e BP Field: Orion S hi b L-211 Sand: Mb1 C um erger Coil Tubìng Unit 9 Job#: 200400186 Appendix B: Molecular Weights and Densities Used Components MW Density (glee) CO2 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 O-XYLENE 106.17 0.884 C9 121 0.768 ClO 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C16 222 0.843 C17 237 0.851 C18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 C30 394 0.910 C31 404 0.912 C32 415 0.915 C33 426 0.917 C34 437 0.919 C35 445 0.937 17 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e CIi ent: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Scblulberger Appendix C: EQUIPMENT Ruid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using a water-glycol mixture at the bottomside of the piston cylinder. A custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analyses follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR and density at sampling P& T corrected to standard conditions. The JEFRI Gasometer consists of a motor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranges from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and the evolved gas phase is conducted using gas chromatography (GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID). In this system, separation of individual components is carried out in a 30m long, 530um diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60°C to 400°C. Over this temperature range, the components eluted are from C1 to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C'2+' along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed using an FID detector. The instrument has programmable air actuated multi port valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allows for the correct separation and analysis of the injected gas. WCP Oilphase-DBR 18 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Scblumberger RUld Volumetric (PVT) and Viscosity Equipment The preliminary saturation pressure, constant composition expansion (CCE), differential vaporization (OV) and multi- stage separation tests (MSST) are measured using a pressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. A specially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allows quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket. which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTO) and displayed on a digital indicator with an accuracy of O.zoF. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high- resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using a Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allows gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. WCP Oilphase-DBR 19 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: BP Field: Orion S hi b Well: L-211 Sand: Mb1 ell um BrIer Installation: Coil Tubing Unit 9 Job #: 200400186 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onset of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS). High-pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. WCP Oilphase-DBR 20 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Schlumberger Appendix D: PROCEDURE Ruids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-Ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure and at reservoir temperature into an atmospheric Gasometer, measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using the gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The GGE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieves equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, a pressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponds to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the GGE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allows the gas phase to evolve. A typical pressure stage in a DV test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the DV test. · The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section). · The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. WCP Oilphase-DBR 21 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Schlumberger Multi-Stage Separation Test Subsequent to the completion of the DV experiment another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allows the gas phase to evolve. A typical pressure stage in a separation test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. · The temperature of the PVT cell is then reduced to the first-stage separation test temperature allowing the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section). The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point the piston was allowed to run back and forth for a sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upward and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compare very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock- Tank OJ! (STO) Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. WCP Oilphase-DBR 22 Job #: 200400186 I I I I I I I I I I I I I I I I I I I e e Client: Well: Installation: BP L-211 Coil Tubing Unit 9 Field: Sand: Job#: Orion Mb1 200400186 Scblumberger Asphaltene, Wax and Sulfur Content Measurements Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using the UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using the ASTM D 2494 procedure. All other STO analyses are measured according to industry standards. SAR(PjA Analysis A spinning band distillation is carried out on the original sample to establish two fractions. The initial boiling point to 300cC fraction is then analyzed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300cC fraction is first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene. Then 40 volumes of pentane are added to precipitate the insoluble portion of the sample. The precipitate is filtered, dried and weighed. The solvent is removed from the soluble portion of the sample, which is referred to as the maltenes. The maltenes are then redissolved in pentane and are chromatographically separated into saturates, aromatics and resins (polars) fractions by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents are then removed from each fraction and the amount of material weighed. The data from the three methods are combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High-Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high-pressure nitrogen is used on the back side of the filter so that equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 23 Job #: 200400186